20111102Weston Stipulation Testimony and Exhibits.pdf

~~~OUNTAIN RECE 0
November 2, 2011 1011 NOV -2 AM 10: '6
201 South Main, Suite 2300
Salt Lake Cit, Utah84111
nA OVERNIGHT DELIVERY
Jean D. Jewell
Commssion Secreta
Idaho Public Utilities Commission
472 W. Washington
Boise, il 83702
Attention: Jean D. Jewell
Commssion Secreta
RE: Case No. PAC-E-1l-12 - In the Matter of the Application ofPacifCorp dba Rocky
Mountain Power for Approval of Changes to its Electrc Service Schedules and Price
Increase of $32.7 Milion, or Approximately 15.0 Percent
Enclosed please find the original and seven (7) copies of the testimony and exhibits of J. Ted
Weston in support of the Stipulation entered into by and among Rocky Mounta Power, a
division of PacifiCorp, and the following pares of record in the above captioned matter: Sta
for the Idaho Public Utilities Commssion; the Idao Irgation Pumper Association Inc.;
Monsanto Company; and PacifiCorp Idaho Industrial Customers. Communty Action Parership
Association of Idao paricipated in the settlement negotiations however they have chosen not to
be a par to the Stipulation. The Idao Conservation League also paricipated in settlement
negotiations but have since formally withdrawn from ths proceeding.
Please contact J. Ted Weston at [phone] if you have any fuer questions.
Very Truy Yours,
~o-LMW'~Jeffey K. Laren
Vice President of Regulation
Rocky Mountan Power
Enclosures
CERTIFICATE OF SERVICE
I hereby certify tht on ths 2nd of November, 2011, I caused to be served, via e-mail
and/or US mail, a tre and correct copy of th foregoing document in PAC-E-11-12 to the
following:
Eric L. Olsen
Racine, Olson, Nye, Budge & Bailey,
Charered
201 E. Center
P.O. Box 1391
Pocatello, ID 83204-1391
E-Mail: elo(ßracinelaw.net
Tim Buller (E-mail Only)
Agrium, Inc./Nu- West Industres
3010 Conda Road
Soda Springs, ID 83276
E-Mail: tbuller(ßagrum.com
Neil Prce
Deputy Attorney General
Idao Public Utilties Commssion
472 W. Washigton (83702)
POBox 83720
Boise, ID 83720-0074
E-Mail: neiLprice(ßpuc.idaho.gov
Anthony Yanel
29814 Lake Road
Bay Vilage, Ohio 44140
E-mail: tony(ßyaneLnet
James R. Smith (E-mail Only)
Monsanto Company
P.O. Box 816
Soda Sprigs, Idaho 83276
E-Mail: jim.r.smith(ßmonsanto.com
Ronad L. Willams
Wiliams Bradbur, P. C.
1015 W. Hays St.
Boise il, 83702
E-mail: ron(ßwillamsbradbur.com
Randall C. Budge
Raine, Olson, Nye, Budge & Bailey,
Charered
201 E. Center
P.O. Box 1391
Pocatello,ID 83204-1391
E-Mail: rcb(ßracinelaw.net
Bra Purdy
CAPAI
2019N.17thSt.
Boise, ID. 83702
E-mail: bmpurdy(gotmaiLcom
Benjam J. Otto
Idaho Conservation League
710 N. 6th St.
P.O. Box 844
Boise, Idaho 83702
E-mail: botto(ßidahoconservation.org
Brubaker & Associates
16690 Swigley Ridge Rd., # 140
Chesterfield, MO 63017
E-Mail: bcollns(ßconsultbai.com
Don Schoenbeck
RCS, Inc.
900 Washigton St, Suite 780
Vancouver W A, 98660
E-Mail: dws(ßr-c-s-inc.com
..~ùl~Arel"~v
Coordinator, Reguatory Operations
RECEIVED
2011 NOV -2 AM 10= 16
BEFORE THE IDAHO PUBLIC UTILITIES COMMSSION
IN THE MATTER OF THE
APPLICATION OF ROCKY
MOUNTAIN POWER FOR
. APPROVAL OF CHAGES TO ITS
ELECTRIC SERVICE SCHEDULES
AND A PRICE INCREASE OF $32.7
MILLION, OR APPROXIMATELY
15.0 PERCENT
)
) CASE NO. PAC-E-ll-12
)
) Stipulation Testimony of J. Ted Weston
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ROCKY MOUNTAIN POWER
CASE NO. PAC-E-l1-12
November 2011
1 Q.
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3 A.
Please state your name, business address and present position with Rocky
Mountain Power (the "Company"), a division of PacifiCorp.
My name is J. Ted Weston and my business address is 201 South Main, Suite
- 4 2300, Salt Lake City, Utah, 84111. I am curently employed as the Manager of
5 Idaho Regulatory Affairs for the Company.
6 Qualifications
7 Q.
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18 Q.
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Briefly describe your educational and professional background.
I received a Bachelor of Science Degree in Accounting from Utah State
University in 1983. I joined the Company in June of 1983 and I have held various
accounting and regulatory positions prior to my curent position. In addition to
formal education, I have attended various educational, professional and electric
industr related seminars durng my career with the Company.
What are your responsibilties as Manager of Regulatory Affairs?
My primary responsibilities include the coordination and management of Idaho
regulatory filings, communications with the Commission and staff, and oversight
of reporting requirements for the Company with the Idaho Public Utilities
Commission.
Have you testifed in previous regulatory proceedings?
Yes. I have testified before this Commission, the Washington Transportation and
Utilities Commission and the Wyoming Public Service Commission.
21 Purpose of Testimony
22 Q.
23 A.
What is the purpose of your testimony in this proceeding?
The purose of my testimony is to present and support the Stipulation reached in
Weston, Stip - 1
Rocky Mountain Power
1 the Company's 2011 general rate case entered into by and among Rocky
2 Mountain Power, a division of PacifiCorp ("Rocky Mountain Power" or the
3 "Company"); Staff for the Idaho Public Utilities Commission ("Staff'); the Idaho
4 Irrgation Pumpers Association, Inc. ("LIP A"); Monsanto Company
5 ("Monsanto"); and the PacifiCorp Idaho Industral Customers ("PIIC")
6 collectively referred to in my testimony as the Parties. Community Action
7 Partnership Association of Idaho ("CAP AI") participated in the settlement
8 negotiations; however, they have chosen not to be a part to the Stipulation. The
9 Idaho Conservation League also intervened in the case and participated in the
10 settlement negotiations but later formally withdrew as a part in this proceeding.
11 More specifically, my testimony provides an overview of the Company's
12 2011 Idaho general rate case and an explanation of the terms and conditions of
13 this Stipulation. I also demonstrate that this Stipulation represents a fair, just and
14 reasonable compromise of the issues in this proceeding and that this Stipulation is
15 in the public interest. My testimony supports the Parties' recommendation that the
16 Idaho Public Utilities Commission ("Commission") approve the Stipulation and
17 all of its terms and conditions.
18 Background
19 Q.What price increase did the Company request in its Application for this
20 case?
21 A.On May 27, 2011, Rocky Mountain Power filed an Application with the
22 Commission supported by the testimony of 13 witnesses with several hundreds of
23 pages of testimony and fort-nine exhibits seeking authority to increase the
Weston, Stip - 2
Rocky Mountain Power
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Company's base rates for electrc service by $32.7 millon annually, representing
an average increase of approximately 15.0 percent. In the Application Rocky
Mountain Power sought new rates effective date of June 27, 2011.
On June 8, 2011 the Commission suspended the rates that were the subject
of the Application for a period of thirt (30) days plus five (5) months making the
rate effective date December 27, 2011. Partes to the Stipulation are respectfully
requesting that the Commission approve this Stipulation.with January 1,2012, as
the rate-effective date.
Has the Company's Application been thoroughly audited and reviewed by
the intervening parties in this case?
Yes. As part of Staffs audit of this Application several meetings were held with
Company representatives durng the weeks of August 8 in Portland, Oregon and
August 15 in Salt Lake City, Utah. In addition, the intervening parties have asked
hundreds of discovery requests which the Company has responded to.
Representatives of the intervening parties met August 23 and September
22, 2011 with the Company at the Commission's offce, pursuant to IDAPA
31.01.01.271 and 272, to engage in settlement discussions with a view toward
resolving the issues raised in Rocky Mountain Power's Application in this
proceeding. Based upon the discussions between the Paries, and as a compromise
of the positions in this proceeding a settlement was reached.
What Test Period did the Company use to determine revenue requirement in
this case?
The Test Period for this Application was based on the historical 12-month period
Weston, Stip - 3
Rocky Mountain Power
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ending December 31, 2010, adjusted for known and measurable changes through
December 31, 2011. The Test Period was prepared consistent with past
3 Commission practice and the Company's general rate cases filed previously in
4 Idaho. i The Company. fied rate base on an end-of-period basis, which includes
5 the actual rate base at December 31, 2010 plus major capital additions that wil go
6 into service by December 31, 2011.
7 Stipulation
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What is the foundation for the rate increase that the Partes agreed to in this
Stipulation?
The Parties agreed that the starting point of the Stipulation was to accept all
Commission ordered adjustments from Case No. PAC-E-IO-07, Order No. 32196.
Beyond that as a starting point . and unless explicitly specified within the
Stipulation, the Parties agreed that this was a "black box" settlement, with no
agreement or acceptance by the Parties of any specific revenue requirement, cost
allocation or cost of service methodology. All Parties agree that this Stipulation
represents a fair, just and reasonable compromise of the issues in this proceeding
and that this Stipulation is in the public interest.
Please describe the terms of the Stipulation entered into by the Parties.
The Parties agree to support a two-year rate plan with annual rate increases of
$17.0 milion per year, which results in overall average anual revenue increases
of approximately 7.8 percent in 2012 and 7.2 percent in 2013. The first increase to
base rates wil occur Januar 1, 2012, and wil be comprised of $6.0 milion of
non-net power cost components (capital, operations and maintenance, and other)
i Refer to pages 9 and 10 of
the direct testimony of Mr. Steven R. McDougal in Case No. PAC-E-ll-12.
Weston, Stip - 4
Rocky Mountain Power
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and $11.0 milion of net power costs. The second increase to base rates wil occur
January 1, 2013, and wil be comprised of $6.0 milion of non-net power cost
components and $11.0 milion of net power costs.
Why did the Parties identify the revenue requirement components between
net power cost and non-net power cost?
Simply identifying the anual revenue requirement increase would not provide
clarity to the amount of net power costs included in customers base rates. The
Pares recognized that the fuction of the Energy Cost Adjustment Mechanism
("ECAM") is to track the difference between actual net power costs incured to
serve customers and the level of net power costs included in customers rates.
Therefore, it was necessary for the Stipulation to specify that $11.0 millon of
increase in 2012 and in 2013 were due to increases in net power costs. Because
the ECAM is based on monthly total Company dollars per megawatt-hour,
Paragraph 4 of the Stipulation clarfies that the $11.0 milion annual increase to
net power costs on an Idaho basis represents an increase to Commission approved
total Company net power costs in base rates of $1.025 bilion to $1.205 billon in
2012 and from $1.205 bilion to $1.385 bilion in 2013. These amounts wil
become the total Company base net power costs for futue tracking in the
Company's ECAM.
Does the Stipulation specify other ECAM related items?
Yes. The Stipulation specifies that the level of renewable energy certificate
("REC") revenue included in rates in 2012 and 2013 wil be $78.8 milion, on a
total Company basis or $6,526,622 allocated to Idaho. This Idaho allocated
Weston, Stip - 5
Rocky Mountain Power
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amount wil become the base for puroses of tracking at 100. percent in the
Company's ECAM mechanism.
The Stipulation also specifies that the Idaho base load in the 2012 ECAM
load. change adjustment revenue ("LCAR") calculation would be the 2010 load
included in Case No. PAC-E-l1-12 for the 2012 ECAM deferral calculation and
the 2011 load reported in the Anual Results of Operations Report for the 2013
ECAM deferral calculation.
The Stipulation also specifies that the LCAR unit value would be frozen
over the rate plan period at the curent rate of $5.47 per MW (Case No. PAC-E-
10-07).
Finally, the Stipulation specifies that, due to the uncertainty of the
jurisdictional treatment of the dispatchable irrgation load control program
curently being discussed by the MSP Standing Commttee, Idao's share of the
customer load control service credit wil be tracked in the ECAM. The Stipulation
identifies that $1,045,423 is Idaho's current base amount that would be tracked in
the ECAM for 2012 and 2013. There are two items that could change Idaho's
actual expense amount: first, if other states don't support system allocation of the
irrgation program; second, the agreement for the current load control service
credit expires after the 2012 program season.
What was the single largest factor that the parties took into consideration
during settlement discussions?
The key issue dealt with by the Stipulation was to address customer rate impact
from both general rate case changes and the potential changes from ECAM
Weston, Stip - 6
Rocky Mountain Power
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surcharges. Since net power costs were the single largest cost drver in this case
and with the Company expecting the 2011 ECAM deferral to be in the range of
$15 to $18 milion, it was critical the Stipulation holistically address net power
costs. Approximately 51 percent of the $32.7 millon increase requested by the
Company in this application, or $16.8 milion, was due to increases in net power
costs. On a total-Company basis, net power costs included in the Application and
supported in the testimony of Company witness of Mr. Gregory N. Duvall were
$1.311 bilion durng the test year, an increase of more than $287 milion above
the $ 1.025 bilion approved by the Commission Ìn Case No. PAC-E-IO-07 and
curently included in customer's rates. The Company expects actual net power
costs for 2011 wil be closer to $1.35 bilion, increasing to over $1.5 bilion
durng calendar year 2012.
One additional factor compounding the rate impact for Monsanto and
Agrum is that April 1,2012, will be the first time their tariff contract based load
would be subject to the ECAM.2 The Parties recognized that whatever decision
they reached regarding net power costs in the rate case had a direct impact on the
Company's ECAM.
How does the Stipulation address the rate impact of increasing net power
costs?
The Stipulation mitigates the rate impact in three ways. First, the rate plan spreads
the increase over two years for most of the Company's customers who are already
paying the ECAM rider. Second, for Agrum and Monsanto, because 2011 is the
first year that their tariff contract loads are subject to the ECAM, the Stipulation
2 All other retail taff customers were subject to Schedule 94, Energy Cost Adjustment rates, April i, 20 i O.
Weston, Stip - 7
Rocky Mountain Power
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includes an innovative tiered approach of amortizing the deferred net power cost
in the ECAM for this usage. This tiered approach allows Monsanto and Agrum to
defer paying some of the ECAM increases to futue years to smooth out the
impact the ECAM increases would have along with the general rate increases,
while at the same time continuing to allow the Company certainty of cost
recovery for these costs. Third, the Stipulation specifies that the Company won't
file another general rate case before May 31, 2013, with new rates not effective
prior to January 1, 2014. Absent this Stipulation, the Company would probably
have fied a general rate case in 2012 with rates effective in 2013 that would have
included net power costs in excess of $1.5 billion. The Stipulation only increases
net power costs to $1.385 bilion in 2013, significantly less than what the
Company projects it would be absent the Stipulation. Ultimately, 90 percent of the
difference between actual net power costs and in..rates net power costs wil be
deferred and collected in the ECAM, customers get the benefit of the delay in
paying the higher level until the costs become "actual" and also benefit from 10
percent of the incremental difference not being included in the ECAM deferraL.
Would you explain how the amortization you referred to will work?
The Stipulation specifies that the Company wil amortize and collect Agrium and
Monsanto's tariff contract share of Commission approved ECAM balances, which
includes deferred net power costs, REC revenues, LCAR, the incremental
irrgation load control credit and any other ECAM components, such as S02 sales,
over the following periods:
(1) The Commission-determined 2012 ECAM balance, based on the 2011
Weston, Stip - 8
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deferrals, wil be amortized beginning April 1, 2012 over a three-year
period ending March 31, 2015. Any over or under collection of the 2012
ECAM balance would be added to the 2015 ECAM balance.
(2) The Commission-determined 2013 ECAM balance, based on the 2012
deferrals, wil also be amortized over a thee-year period beginning April 1,
2013 though March 31, 2016, with any over or under collection of that
balance added to the 2016 ECAM balance.
(3) The Commission-determined 2014 ECAM balance, based on the 2013
deferrals, wil also be amortized, but over a two-year period beginnng
April 1,2014 though March 31,2016, with any over-collection or under-
collection of that balance added to the 2016 ECAM balance.
(4) Beginning with the Commission-determined 2015 ECAM balance,
based on the 2014 deferrals, Monsanto and Agrium wil pay new ECAM
costs based on a 12-month collection period.
(5) Any over-collection or under-collection at the end of the amortization
periods above wil be tred up for each contract customer and refuded or
collected as part of a subsequent ECAM collection period from these
contract customers and not from other retail customers.
Does the amortization apply to the small porton of Agrium's load that is
served on Schedule 6 and 9?
No. The portion of Agrum's load served on Schedule 6 and 9 have been subject
to and paying the ECAM, Schedule 94 rate, since its initial rate implementation
effective April 1, 2010. The amortization schedule only applies to Agrium and
Weston, Stip - 9
Rocky Mountain Power
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Monsanto's tariff contract load for which 2011 was the first year impacted by the
ECAM.
How wil the Company assure that Agrium, Monsanto and the other retail
customers pay only their portion of the ECAM balance?
Curently the Company provides Staff quarterly reports detailing the monthly
ECAM deferral balances. The report has a section listing actul Idaho retail load,
adjusted for line losses. This section wil be expanded to provide detail of
Agrium, Monsanto, and all other Idaho retail customers' load. The megawatt
hours for each of these customer groups wil be multiplied by the monthly net
power cost differential, between base net power costs and actual net. power costs
to determine the net power cost deferral for each group. Then the remaining
ECAM components would be spread using the same megawatt hour ratio for the
month. The Company wil track and report the monthly balances for these three
groups through the amortization period.
Does this amortization impact any other customers?
No. All other customers will continue to pay ECAM charges on a 12-month
collection period for only their portion of the deferral as they currently do.
Because the other retail customers are already paying the curent Schedule 94,
Energy Cost Adjustment rate on their monthly bil, the Company expects that they
will experience very minor rate changes associated with the ECAM over the rate
plan. The rate changes are estimated to be in the range of one to two percent
increase in 2012 and by 2013 and 2014 they possibly could experience no change
or a small reduction to their ECAM collection rate.
Weston, Stip - 10
Rocky Mountain Power
1 Other Terms of the Stipulation
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Does the Stipulation settle the value of Monsanto's curtailment products?
Yes. Paragraph 14 of the Stipulation specifies that the value of Monsanto's
curailment products wil be increased for 2012 and 2013 from the amount
approved by the Commission in Case No. PAC-E-IO-07. If this Stipulation is
approved by the Commission Monsanto and the Company wil execute a new
Electrc Service Agreement for2012 and 2013 in order to reflect the terms of the
Stipulation.
Does the Stipulation address the irrigation load control program?
Yes. The Stipulation does not change or alter the irrgation load control servce
credit in 2012 or prior agreements governing the irrgation load control program
that require the irrgation load control service credit to be renegotiated for the
2013 season and beyond. However, the Stipulation specifies that $1,045,423 wil
be Idaho's base amount associated with the system allocation of the Type 1 DSM
program costs included in customer's rates and that any incremental changes due
to allocations or revisions to the irrgation load control program costs would be
tracked in the ECAM.
Does the Stipulation address the treatment of the Populus to Terminal
transmission line?
Yes. The Parties to the Stipulation agree that the portion of the Populus to
Terminal transmission line determined in Case No. PAC-E-IO-07 to be plant held
for futue use ("PHFU") is now used and usefuL. The Parties fuher agreed that
the Commission should make a specific finding that the entire Populus to
Weston, Stip - 11
Rocky Mountain Power
1 Terminal transmission line is now used and usefuL. The Parties respectfully
2 request that the Commission make that finding in its order approving the
3 Stipulation.
4 Although the Parties agree that the Populus to Terminal transmission line
5 is used and useful, they fuher agree that the portion of the transmission line
6 deemed PHFU in Case No. PAC-E-I0-07 shall not be included in customer's
7 rates until the rate-effective date from the Company's next general rate on or after
8 Januar I, 2014. The Partes to the Stipulation agree that the Company wil
9 continue to defer the depreciation expense associated with the Populus to
10 Terminal transmission line, pursuant to Order No. 32224, until it is included in
11 rates on or after January 1, 2014, and that this accumulated deferred balance wil
12 be amortized over thee years from the date the costs are included in rates.
13 Finally, Staff, Monsanto, and the Company agree to file a Motion to
14 Suspend the Appeal on the Populus to Terminal transmission line decision now
15 pending in the Idaho Supreme Cour, docketed as Case No. 38930-2011. A
16 motion to suspend the procedural schedule was filed October 28, 2011 with the
17 Idaho Supreme Cour. If the Commission makes the findings requested in the
18 Stipulation on this issue, the Company and Parties agrees that within 10 days
19 thereof they wil file a stipulation with the Idaho Supreme Court for Dismissal of
20 the appeaL.
21 The effect of these agreements on the Populus to Terminal transmission
22 line is a reasonable compromise of the issues pending on Appeal and avoidance of
23 the costs of fuher litigation of those issues. Although the Parties agree that the
Weston, Stip - 12
Rocky Mountain Power
1 entire transmission line is curently used and useful and that the Commission
2 should make a finding to that effect, they also agree to delay recovery of the
3 portion of the costs disallowed for curent recovery in rates in Case No. PAC-E-
4 10-07 until on or after January 1,2014.
5 Hedging
6 Q.How does the Stipulation address future hedging costs?
7 A.The Stipulation specifies that the Company wil work with the Parties to establish
8 hedging limits consistent with workgroup processes established in Utah and
9 Oregon for new costs beginning January 1, 2013, and forward. These new costs
10 would be related to new hedging contracts entered into on or after that date.
11 Rate Design
12 Q.How does the Stipulation address rate design?
13 A.The Stipulation specifies that the design of rates by rate schedule (rate design)
14 wil be consistent with the Company's proposals filed in its Application, adjusted
15 for the $17.0 millon annual revenue requirement with one modification. The
16 Company's proposal increases the residential customer service charge for
17 Schedule 1 and 36 was not adopted. The customer service charge for Schedule 1
18 and 36 wil remain at $5.00 per month and $14.00 per month, respectively, durng
19 the two-year rate plan. A summary of the Stipulation rate design by rate schedule
20 is provided in the following table.
Weston, Stip - 13
Rocky Mountain Power
Stipulation Rate Design Summary
Average
Schedule Increase
1 5.88%
36 7.96%
6,35 6.70%
9 7.02%
10 8.91%
7,11,12 1.07%
19 6.40%
23 6.88%
SPC 1 8.91%
SPC2 8.91%
1 Rate Spread
Customer
Charge
Demand
Charge
Energy
Charge
collect the total
revenue
collect the total
no change
no change revenue
3% higher than collect the rest of the
average average revenue
4% higher than collect the rest of the
average average revenue
5% higher than collect the rest of the
average average revenue
uniformly percentage increase to all biling elements
uniformly percentage increase to all biling elements
uniformly percentage increase to all biling elements
uniformly percentage increase to all biling elements
uniformly percentage increase to all biling elements
2 Q.Does the Stipulation specify how the $17.0 milion revenue requirement
3 increase wil be spread between customer classes?
4 A.Yes. The Stipulation specifies how to calculate the rate spread, details of the rate
5 spread are included as Exhibit 49 of my testimony. A summar ofthe rate spread
6 is presented in the following table:
Weston, Stip - 14
Rocky Mountain Power
Rate Spread Comparison
Customer Class Proposed Settled
Residential - Schedule 1 7.92%5.88%
Residential - Schedule 36 15.9%7.96%
General Service
Schedule 23/23A 11.8%6.88%
Schedule 6/6A/8/35 10.8%6.70%
Schedule 9 11.2%7.02%
Schedule 19 9.70%6.40%
Irrgation
Schedule 10 19.9%8.91%
Public Street Lighting
Schedules 7/7A, 11, 12 0%1.07%
Schedule 400 18.7%8.91%
Schedule 401 19.9%8.91%
1 Q.How will the Stipulation impact residential customers?
2 A.Idaho's average residential customer on Schedule 1 uses 837 kWh a month. At
3 that usage level residential customers would experience a $4.84 increase per
4 month to their bils.
5 Q.Has the Company updated its tarif schedules based on the Stipulation?
6 A.Yes. Exhibit 50 contains the clean and legislative copies of the Company's Idaho
7 tariff schedules based on the terms of the Stipulation. The Paries to the
8 Stipulation respectfully request that the Commission approve the Stipulation and
9 these tarffs as fied.
10 Conclusion
11 Q.Does the Company believe the Stipulation represents a fair, just and
12 reasonable compromise of the issues and is in the public interest?
13 A.Yes. All Parties to the Stipulation negotiated in good faith to reach a reasonable
14 outcome. The Company believes that its initial request of $32.7 milion was
15 justified to meet the cost of serving its customers in Idaho. However, in an effort
Weston, Stip - 15
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to reach an agreement with Paries, the Company was wiling to reduce that
request and stipulate to $17.0 milion price increases on January 1, 2012, and
January 1, 2013. In recognition of the two-year rate plan covered by this
Stipulation, Rocky Mountain Power wil not fie another general rate case before
May 31, 2013, with new rates not effective prior to January 1, 2014. Rocky
Mountain Power wil continue to file annual Results of Operations Reports with
the Commission to enable the Commission to ensure that rates durng the two-
year rate plan continue to be just and reasonable. The Company has been prudent
in securng resources for the benefit of its Idaho customers and should be granted
cost recovery of these expenditues. The Company wil continue to work to
control its costs while implementing mechanisms and pricing proposals to help
customers use electrcity more effciently. For these reasons the Company
supports the Stipulation entered into and respectfully requests that the
Commission approve it as fied.
Does this conclude your direct testimony?
Yes.
Weston, Stip - 16
Rocky Mountain Power
Case No. PAC-E-ll-12
Exhibit No. 49
Witness: J. Ted Weston
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ROCKY MOUNTAIN POWER
Exhibit Accompanying Stipulation Testimony of J. Ted Weston
Rate Spread
November 2011
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Exhibit No. 49 Page 1 of 5
Case No. PAC-E-11-12
Witness: J. Ted Weston~ocoi.
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Rocky Mountain Power
Exibit No. 49 Page 2 of 5
Case No. PAC-E-11-12
Witness: J. Ted Weston
ROCKY MOUNTAIN POWER - STATE OF IDAHO
CASE NO. PAC-E-11-12
DETAILED RATE SPREAD
STIPULATION
Year 1 Year 2
Present 11112012 1/12013
SCHEDULE NO.1 - Residential Service
Customer Charge $5.00 $5.00 $5.00
All kWh (May - Oct)
..= 700 kWh 9.6018 rl 10.2013 rl 10.7874 rl
::700kWh 12.9624 rl 13.7717 rl 14.5630 rl
All kWh (Nov - Apr)
..= 1,000 kWh 7.3496 rl 7.8085 rl 8.2571 rl
::l,OOOkWh 9.9220 rl 10.5415 rl 11.472 rl
Seasonal Service Charge $60.00 $60.00 $60.00
SCHEDULE NO. 36 - Residential Service Optional TOD
Customer Charge $14.00 $14.00 $14.00
On-Peak kWh (May - Oct)12.2191 rl 13.3102 rl 14.4027 rl
Off-Peak kWh (May - Oct)4.1697 rl 4.5420 rl 4.9148 rl
On-Peak kWh (Nov - Apr)10.4377 rl 11.697 rl 12.3029 rl
Off-Peak kWh (Nov - Apr)3.8162 rl 4.1570 rl 4.4982 rl
Seasonal Service Charge $168.00 $168.00 $168.00
SCHEDULE NO. 6/6A - General Service - Large Power
. Customer Charge (Secondar Voltage)$33.00 $35.00 $37.00
Customer Charge (Priar Voltage)$99.00 $105.00 $11 1.00
All kW (May - Oct)$12.22 $13.28 $14.36
All kW (Nov - Apr)$10.05 $10.92 $11.81
All kWh 3.3805 rl 3.5305 rl 3.6696 rl
Seasonal Service Charge (Secondary)$396.00 $420.00 $444.00
Seasonal Service Charge (Priar)$1,188.00 $1,260.00 $1,332.00
Voltage Discount ($0.57)($0.61)($0.65)
SCHEDULE NO.7 - Customer Owned Light
Residential
Charges Per Lamp
16,000 Lumens, HPSV $14.67 $14.82 $14.91
SCHEDULE NO. 7/7A - Security Area Lighting
Chages Per Lamp
7000 Lumens, MV $26.40 $26.67 $26.83
20,000 Lumens, MV $47.09 $47.58 $47.86
5,600 Lumens, HPSV, Co Owned Pole $16.77 $16.94 $17.04
5,600 Lumens, HPSV, No Co Owned Pole $13.34 $13.48 $13.56
9,500 Lumens, HPSV, Co Owned Pole $19.20 $19.40 $19.51
9,500 Lumens, HPSV, No Co Owned Pole $15.77 $15.93 $16.02
16,000 Lumens, HPSV, Co Owned Pole $25.29 $25.55 $25.70
16,000 Lumens, HPSV, No Co Owned Pole $22.52 $22.75 $22.88
27,500 Lumens, HPSV, Co Owned Pole $36.37 $36.75 $36.97
Rocky Mountain Power
Exhibit No. 49 Page 3 of 5
Case No. PAC-E-11-12
Witness: J. Ted Weston
ROCKY MOUNTAIN POWER - STATE OF IDAHO
CASE NO. PAC-E-11-12
DETAILED RATE SPREAD
SCHEDULE NO. 11 - Company-Owned Street Lighting Service
Charges per Lamp .
5,800 Lumens, High Intensity Discharge
9,500 Lumens, High Intensity Discharge
16,000 Lumens, High Intensity Discharge
27,500 Lumens, High Intensity Discharge
50,000 Lumens, High Intensity Discharge
9,500 Lumens, High Intensity Discharge - Series 1
16,000 Lumens, High Intensity Discharge - Series 1
9,500 Lumens, High Intensity Discharge - Series 2
16,000 Lumens, High Intensity Discharge - Series 2
12,000 Metal Halide
27,500 Lumens, lISV, No Co Owned Pole
50,000 Lumens, LISV, CoOwnedPole
50,000 Lumens, LISV, No Co Owned Pole
16,000 Lumens, LIS Flood, Co Owned Pole
16,000 Lumens, LIS Flood, No Co Owned Pole
27,500 Lumens, LIS Flood, Co Owned Pole
27,500 Lumens, LIS Flood, No Co Owned Pole
50,000 Lumens, LIS Flood, Co Owned Pole
50,000 Lumens, LIS Flood, No Co Owed Pole
8,000 Lumens, LPSV, Energy Only
13,500 Lumens, LPSV, Energy Only
22,500 Lumens, LPSV, Energy Only
33,000 Lumens, LPSV, Energy Only
SCHEDULE NO.9 - General Service - High Voltage
Customer Charge
All kW (May - Oct)
All kW (Nov - Apr)
Minimum kW Summer
Minium kW Winter
All kWh
SCHEDULE NO. 10 - Irrigation
Small Customer Charge (Season)
Large Customer Charge (Season)
Post-Season Customer Charge
All kW (June 1 - Sept 15)
First 25,000 kWh (June 1 - Sept 15)
Next 225,000 kWh (June 1 - Sept 15)
All Add'l kWh (June 1 - Sept 15)
All kWh (Sept 16 - May 31)
STIPULATION
Present
$32.94
$50.84
$45.00
$25.29
$22.52
$36.37
$32.94
$50.84
$45.00
$3.60
$5.32
$7.40
$9.01
Year 1
11112012
$33.28
$51.7
$45.47
$25.55
$22.75
$36.75
$33.28
$51.7
$45.47
$3.64
$5.38
$7.48
$9.10
Year 2
111/2013
$33.48
$51.67
$45.74
$25.70
$22.88
$36.97
$33.48
$51.67
$45.74
$3.66
$5.41
$7.52
$9.15
$324.00 $347.00 $370.00
$8.48 $9.35 $10.26
$6.41 $7.06 $7.74
$8.48 $9.35 $10.26
$6.41 $7.06 $7.74
3.5006 il 3.6970 il 3.8835 il
$12.00 $13.00 $14.00
$35.00 $38.00 $41.00
$19.00 $21.00 $23;00
$4.69 $5.31 $5.98
7.3477 il 7.9434 il 8.5312 il
5.4349 il 5.8755 il 6.3103 il
4.0116 il 4.3368 il 4.6577 il
6.2144 il 6.7187 il 7.2164 il
$14.89
$18.58
$25.33
$35.38
$51.93
$30.73
$33.73
$25.29
$28.21
$27.42
$15.14
$18.89
$25.75
$35.96
$52.79
$31.25
$34.29
$25.71
$28.68
$27.88
$15.05
$18.78
$25.60
$35.75
$52.48
$31.06
$34.09
$25.56
$28.51
$27.71
SCHEDULE NO. 12F - Customer-Owned Street Lighting Service-Full Maintenance
Charges per Lamp
5,800 Lumens, HPSV
9,500 Lumens, HPSV
16,000 Lumens, HPSV
27,500 Lumens, HPSV
50,000 Lumens, HPSV
SCHEDULE NO. 12P - Customer-Owned Street Lighting Service-Partial Maintenance
Charges per Lamp
10,000 Lumens, MV
20,000 Lumens, MV
5,800 Lumens, HPSV
9,500 Lumens, HPSV
27,500 Lumens, HPSV
50,000 Lumens, HPSV
ROCKY MOUNTAIN POWER. STATE OF IDAHO
CASE NO. PAC.E-11-12
DETAILED RATE SPREAD
19,500 Metal Halide
32,000 Metal Halide
9,000 Metal Halide - Series 1
12,000 Metal Halide - Series 1
9,000 Metal Halide - Series 2
12,000 Metal Halide - Series 2
Present
$34.03
$41.28
$31.00
$35.64
$30.17
$31.85
SCHEDULE NO. 12E - Customer-Owned Street Lighting Service-Energy Only
Charges per Lamp
33,000 Lumens, LPSV
12,000 Metal Halide
19,500 Metal Halide
32,000 Metal Halide
107,800 Metal Halide
9,000 Metal Halide
5,800 Lumens, HPSV
9,500 Lumens, HPSV
16,000 Lumens, HPSV
27,500 Lumens, HPSV
50,000 Lumens,HPSV
Non-Listed Lumnaire - Energy Only
$9.01
$6.94
$9.49
$14.92
$35.72
$3.95
$2.79
$3.91
$5.81
$9.93
$15.27
10.1259 ø
$6.45
$8.22
$9.88
$12.94
$17.27
$16.15
$21.62
$5.78
$7.44
$11.94
$16.09
SCHEDULE NO. 19 - Commercial and Industrial Space HeatingCustomer Charge Seconda $21.00All kWh (May. Oct) 8.2953 øAll kWh (Nov - Apr) 6.1465 ø
Rocky Mountain Power
Exhibit No, 49 Page 4 of 5
Case No. PAC-E-11-12
Witness: J. Ted Weston
STIPULATION
Year 1 Year 2
111/2012 111/2013
$34.39 $34.60
$41.72 $41.97
$31.3 $31.52
$36.02 $36.24
$30.49 $30.67
$32.19 $32.38
$9.11
$7.01
$9.59
$15.08
$36.10
$3.99
$2.82
$3.95
$5.87
$10.04
$15.43
10.2330 ø
$9.16
$7.05
$9.65
$15.17
$36.32
$4.01
$2.84
$3.97
$5.91
$10.10
$15.52
10.2944 ø
$6.52
$8.31
$9.98
$13.08
$17.45
$6.56
$8.36
$10.04
$13.16
$17.55
$16.32
$21.85
$5.84
$7.52
$12.07
$16.26
$16.42
$21.98
$5.88
$7.57
$12.14
$16.36
$22.00
8.8093 ø
6.5274 ø
$23.00
9.3152 ø
6.9023 ø
Rocky Mountain Power
Exhibit No. 49 Page 5 of 5
Case No. PAC-E-11-12
Witness: J. Ted Weston
ROCKY MOUNTAIN POWER - STATE OF IDAHO
CASE NO. PAC-E-11.12
DETAILED RATE SPREAD
SCHEDULE NO. 23/23A - General Servce
Customer Charge Secondary
Customer Charge Primar
Total Customer Charges
All kWh (May - Oct)
All kWh (Nov - Apr)
Seasonal Service Charge (Seconda)
Seasonal Service Charge (Priar)
Voltage Discount
SCHEDULE NO. 35 - General Servce - Optional TOD
Customer Charge Secondary
Customer Charge Priar
All On-Peak kW
All kWh
Seasonal Service Charge (Seconda)
Seasonal Service Charge (Priar)
Voltage Discount
SCHEDULE 400
Firm Energy and Power
Customer Charges
kWh
kW
Excess kVar
Interruptible Energy and Power
kWh
kW
SCHEDULE 401
Customer Charges
HLH kWh (May-October)
HLH kWh (November-April)
LLH kWh (May-October)
LLH kWh (November-Apri)
All kW (May-October)
All kW (November-April)
Present
STIPULATION
Year 1 Year 2
11112012 111/2013
$14.00
$43.00
$15.00
$46.00
$16.00
$49.00
8.0585 ~
7.0345 ~
$168.00
$516.00
(0.3892) ~
8.5835 ~
7.4928 ~
$180.00
$552.00
(0.4146) ~
9.1030 ~
7.9463 ~
$192.00
$588.00
(0.4397) ~
$59.00
$145.00
$14.52
4.3260 ~
$708.00
$1,740.00
($0.74)
$63.00
$155.00
$15.49
4.6154 ~
$756.00
$1,860.00
($0.79)
$67.00
$165.00
$16.45
4.9015 ~
$804.00
$1,980.00
($0.84)
$1,345.00 $1,465.00 $1,586.00
2.6180 ~2.8515 ~3.0870 ~
$13.50 $14.70 $15.91
$0.82 $0.89 $0.96
2.6180 ~2.8515 ~3.0870 ~
$13.50 $14.70 $15.91
$375.00 $408.00 $442.00
3.0820 ~3.3565 ~3.6332 ~
2.5630 ~2.7913 ~3.0214 ~
2.3110 ~2.5168 ~2.7243 ~
2.3 110 ~2.5168 ~2.7243 ~
$14.93 $16.26 $17.60
$12.04 $13.11 $14.19
Case No. PAC-E-II-12
Exhibit No. 50
Witness: J. Ted Weston
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ROCKY MOUNTAIN POWER
Exhibit Accompanying Stipulation Testimony of J. Ted Weston
Revised Electrc Service Schedules
November 2011
~~~OUTAIN Rocky Mountain Power
Exhibit No. 50 Page 1 of 48
Case No. PAC.E.11.12
Witness: J. Ted Weston
I.P.U.C. No.1
Sixth Revision of Sheet No. 1.1
Canceling Fifth Revision of Sheet No. 1.1
ROCKY MÒUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.1
STATE OF IDAHO
Residential Servce
AVAILABILITY: At any point on the Company's interconnected system where there are facilities
of adequate capacity.
APPLICATION: This Schedule is for alternating curent electric service supplied at approximately
120 or 240 volts through one kilowatt-hour meter at a single point of delivery for all service required on the
premises for Residential puroses.
When conditions are such that service is supplied though one meter to more than one dwelling or
aparent unit, the charge for such service wil be computed by multiplying the minimum charges by the
maximum number of dwellng or aparment units that may be served.
When a portion of a dwellng is used regularly for business, professional or other gainful puroses,
the premises wil be classified as nonresidential and the appropriate schedule applied. However, if the
wiring is so arranged that the service for Residential puroses can be metered separately, this Schedule wil
be applied to such service.
MONTHLY BILL:
Customer Servce Charge:
$5.00 per Customer
Energy Charge:
(l) Biling months May
through October inclusive
10.2013t per kWh first 700 kWh
l3.77l7t per kWh all additional kWh
(Continued)
Submitted Under Case No. PAC-E. 1 1-12
ISSUED: November 2,2011 EFFECTIVE: January 1,2012
~~~OUTAIN Rock Mountain Power
Exhibit No. 50 Page 2 of 48
Case No. PAC-E-11-12
Witness: J. Ted Weston
I.P.U.C. No.1
Sixth Revision of Sheet No. 1.2
Canceling Fifth Revision of Sheet No. 1.2
ELECTRIC SERVICE SCHEDULE NO.1 - Contiued
MONTHLY BILL: (continued)
(2) Biling months November
through April inclusive
7.808SØ per kWh first 1,000 kWh
10.541SØ per kWh all additional kWh
MONTHLY BILLING REDUCTION: Rates in this schedule shall be reduced by the monthly
kilowatt-hour credit adjustment set forth under "Monthly Rates" in the curently effective Electric Service
Schedule No. 34.
SEASONAL SERVICE: When seasonal service is supplied under this Schedule, the minimum
seasonal charge wil be $60.00.
CONTRACT PERIOD: One year or longer.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule wil be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company. The Electrc Service
Regulations of the Company on fie with and approved by the Idaho Public Utilities Commssion, including
futue applicable amendments, wil be considered as formng a part of and incorporated in said Agreement.
Submitted Under Case No. PAC-E-11-12
ISSUED: November 2,2011 EFFECTIVE: January 1,2012
~~~OUNTAIN Rocky Mountain Power
Exhibit No. 50 Page 3 of 48
Case No. PAC-E-11-12
Witness: J, Ted Weston
I.P.U.C. No.1
Fourth Revision of Sheet No. 6.1
Cancelig Third Revision of Sheet No. 6.1
ROCKY MOUNTAI POWER
ELECTRIC SERVICE SCHEDULE NO.6
STATE OF IDAHO
General Service - Large Power
AVAILABILITY: At any point on the Company's interconnected system where there are facilities
of adequate capacity.
APPLICATION: This Schedule is for alternating curent, single or thee-phase electrc service
supplied at Company's available voltage though one metering installation at a single point of delivery for all
service required on the premises.
MONTHLY BILL:
Rate:
Biling Months May
through October, Inclusive
Biling Months November
though ApriL, Inclusive
Customer Service
Charge:
Secondar voltage
delivery (Less than
2300 volts) $ 35.00 per Customer $ 35.00 per Customer
Primar voltage
delivery (2300 volts
or higher) $ 105.00 per Customer $ 105.00 per Customer
Power Rate:$ 13.28 per kW for all kW $ 10.92 per kW for all kW
Energy Rate:3.5305t per kWh for all kWh 3.5305t per kWh for all kWh
(Continued)
Submitted Under Case No. PAC-E-1l-12
ISSUED: November 2,2011 EFFECTIVE: Janua 1,2012
~~~~OUNTAIN
Rocky Mountain Power
Exhibit No. 50 Page 4 of 48
Case No. PAC-E-11-12
Witness:J. Ted Weston
I.P.U.C. No.1
Third Revision of Sheet No. 6.2
Canceling Second Revision of Sheet No. 6.2
ELECTRIC SERVICE SCHEDULE NO.6 - Contiued
Power Factor:
This rate is based on the Customer maintaining at all times a power factor of 85% lagging,
or higher, as determned by measurement. If the average power factor is found to be less
than 85% lagging, the Power as recorded by the Company's meter wil be increased by 3/4
of 1 % for every 1 % that the power factor is less than 85%.
Voltage Discount:
Where Customer taes service from Company's available lines of 2300 volts or higher and
provides and maintains all transformers and other necessar equipment, the voltage discount
based on measured Power wil be:
$0.61 per kW for all kW of Power
Miíiium Bil:
The Customer Service Charge.
POWER: The kW as shown by or computed from the readings of Company's Power meter for the
15-minute period of Customer's greatest use durng the month, determned to the nearest kW.
SEASONAL SERVICE: Service for aIiually recurg periods of seasonal use where service is
normally discontinued or curiled during a par of the year may be contracted for under ths Schedule under
either of the following conditions:
(a) Customer may contract for service under this Schedule on a year-round basis paying for all
service, including transformer losses where applicable, under the rates set forth under
"Monthly Bil" above including the monthly minimum bil during those months service is
curailed or is not utilized in the Customer's operation.
(b) Customer may contract for seasonal service under this Schedule with a net minimum
seasonal payment as follows:
$ 420.00
$ 1,260.00
plus Power and Energy Charges for Customer taking service at less than
2300 volts and
plus Power and Energy Charges for Customer takng service at 2300 volts
or higher.
(Continued)
Submitted Under Case No. PAC-E-ll-12
ISSUED: November 2,2011 EFFECTIVE: January 1,2012
~~.l~OUNTAIN
Rock Mountain Power
Exhibit No. 50 Page 5 of 48
Case No, PAC-E-11-12
Witness: J, Ted Weston
I.P.U.C. No.1
Fourth Revision of Sheet No. 6A.l
Cancelig Third Revision of Sheet No. 6A.l
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 6A
STATE OF IDAHO
General Service - Large Power (Residential and Farm)
A V AILABILITY: At any point on the Company's interconnected system where there are facilities
of adequate capacity for service to any customer who qualifies as a "Residential Load" or "Far Load"
under both (1) the Pacific Northwest Electric Power Planning and Conservation Act, P.L. 96-501 as the same
may be amended, and (2) a Residential Purchase and Sale Agreement, under Section 5( c) of such Act and in
effect between the Company and the Bonnevile Power Administration.
APPLICATION: This Schedule is for altemating curent, single or thee-phase electric service
supplied at Company's available voltage through one metering installation at a single point of delivery for all
service required on the premises.
MONTHLY BILL:
Biling Months May
through October, Inclusive
Biling Months November
through ApriL, Inclusive
Customer Service
Charge:
Secondary voltage
delivery (Less than
2300 volts) $ 35.00 per Customer $ 35.00 per Customer
Primar voltage
delivery (2300 volts
or higher) $ 105.00 per Customer $ 105.00 per Customer
Power Rate: $ 13.28 per kW for all kW $ 10.92 per kW for all kW
Energy Rate: 3.5305~ per kWh for all kWh 3.5305~ per kWh for all kWh
(Continued)
Submitted Under Case No. PAC-E-ll-12
ISSUED: November 2,2011 EFFECTIVE: Janua 1,2012
~~OUNTAIN Rocky Mountain Power
Exhibit No, 50 Page 6 of 48
Case No, PAC-E-11-12
Witness: J. Ted Weston
I.P.U.C. No.1
Second Revision of Sheet No. 6A.2
Cancelig First Revision of Sheet No. 6A.2
ELECTRIC SERVICE SCHEDULE NO. 6A - Continued
Power Factor:
This rate is based on the Customer maintaining at all times a power factor of 85% lagging,
or higher, as determned by measurement. If the average power factor is found to be less
than 85% lagging, the Power as recorded by the Company's meter wil be increased by 3/4
of 1 % for every 1 % that the power factor is less than 85%.
Voltage Discount:
Where Customer taes service from Company's available lines of 2300 volts or higher and
provides and maintains all transformers and other necessar equipment, the voltage discount
based on measured Power wil be:
$0.61 per kW for all kW of Power
Minimum Bil:
The Customer Service Charge.
MONTHLY BILLING REDUCTION: Rates in ths Schedule shall be reduced by the monthly
kilowatt-hour credit adjustment set forth under "Monthly Rates" in the curently effective Electric~Service
Schedule No. 34.
POWER: The kW as shown by or computed from the readings of Company's Power meter for the
15-minute period of Customer's greatest use durng the month, determned to the nearest kW.
SEASONAL SERVICE: Service for annually recurg periods of seasonal use where service is
normally discontinued or curiled during a part of the year may be contracted for under this Schedule under
either of the following conditions:
(a) Customer may contract for service under this Schedule on a year-round basis paying for all
service, including transformer losses where applicable, under the rates set forth under
"Monthly Bil" above including the monthly minimum bil durng those months service is
curailed or is not utilized in the Customer's operation.
(Continued)
Submitted Under Case No. PAC-E-ll-12
ISSUED: November 2, 2011 EFFECTIVE: Janua 1,2012
~~;:OUNTAIN Rock Mountain Power
Exhibit No, 50 Page 7 of 48
Case No. PAC-E-11-12
Witness: J. Ted Weston
I.P.U.C. No.1
Third Revision of Sheet No. 6A.3
Canceling Second Revision of Sheet No. 6A.3
ELECTRIC SERVICE SCHEDULE NO. 6A - Continued
SEASONAL SERVICE: (continued)
(b) Customer may contract for seasonal service under this Schedule with a net minimum
seasonal payment as follows:
$ 420.00 plus Power and Energy Charges for Customer tang service at less than
2300 volts and
plus Power and Energy Charges for Customer taing service at 2300 volts
or higher.
$1,260.00
CONTRACT PERIOD: One year or longer.
SPECIAL CONDITION: Domestic use means all usual residential, apartent, seasonal dwellng,
and mobile home cour use including domestic water pumping. Far use means all usual far electrical
loads for raising of crops, livestock or pastuage and includes primary processing. necessary for safe and
efficient storage or shipment and irrgation pumping.
Contiguous parcels of land under single-ownership or leasehold shall be considered to be one Farm
and noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Far unit
when operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels.
A number of factors shall determine whether contiguous or noncontiguous parcels constitute one or
more Farms. These factors shall include, but are not limited to:
-- size
-- use
-- ownership
-- control
-- operating practices
-- distance between parcels
-- custom in the trade
-- biling treatment by the utility
Operators of Farms may be required to certify to the utility all irrigation accounts, includig
horsepower rating.
(Continued)
Submitted Under Case No. PAC-E-ll-12
ISSUED: November 2,2011 EFFECTIVE: January 1,2012
~2\l~OUNTAIN
Rocky Mountain Power
Exhibit No. 50 Page 8 of 48
Case No. PAC-E-11-12
Witness: J. Ted Weston
I.P.U.C. No.1
Fourth Revision of Sheet No. 9.2
Canceling Third Revision of Sheet No. 9.2
ELECTRIC SERVICE SCHEDULE NO.9 - Contiued
MONTHLY BILL:
Rate:
Biling Months May
through October, Inclusive
Billing Months November
through ApriL, Inclusive
Customer Service
Charge: $347.00 per Customer $347.00 per Customer
Power Rate: $ 9.35 per kW for all kW $ 7.06 per kW for all kW
Energy Rate:3.6970t per kWh for all kWh 3.6970t per kWh for all kWh
Power Factor:
This rate is based on the Customer maintaining at all times a power factor of 85% lagging,
or higher, as determined by measurement. Ifthe average power factor is found to be less
than 85% lagging, the Power as recorded by the Company's meter wil be increased by 3/4
of 1 % for every 1 % that the power factor is less than 85%.
Minimum:
The Customer Service Charge plus the minimum Power Charge and appropriate Energy
Charges.
POWER: The kW as shown by or computed from the readings of Company's Power meter for the
l5-minute period of Customer's greatest use durng the month, adjusted for power factor as specified,
determned to the nearest kW, but not less than 80 kW.
CONTRACT PERIOD: One year or longer.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule wil be in accordace with
the terms of the Electrc Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idao Public Utilities Commssion, including
futue applicable amendments, wil be considered as formng a part of and incorporated in said Agreement.
Submitted Under Case No. PAC-E-11-12
ISSUED: November 2,2011 EFFECTIVE: January 1,2012
~~l~OUNTAIN
Rocky Mountain Power
Exhibit No. 50 Page 9 of 48
Case No. PAC-E-11-12
Witness: J. Ted Weston
I.P.U.C. No.1
Fifth Revision of Sheet No. 10.1
Canceling Fourth Revision of Sheet No. 10.1
ROCKY MOUNTAI POWER
ELECTRIC SERVICE SCHEDULE NO. 10
STATE OF IDAHO
Irrigation and Soil Drainage Pumping Power Servce
AVAILABILITY: At any point on the Company's interconnected system where there are facilities
of adequate capacity.
APPLICATION: This Schedule is for alternating curent, single or three-phase electrc service
supplied at the Company's available voltage through a single point of delivery for service to motors on
pumps and machinery used for irgation and soil drainage.
IRRGATION SEASON AN POST-SEASON SERVICE: The Irrigation Season is from June 1
to September 15 each year. Service for post-season pumping may be taken by the same Customer at the
same point of delivery and through the same facilities used for supplying regular irrigation pumping service
durng months from September 16 to the following May 31.
MONTHLY BILL:
Irrigation Season Rate
Customer Service Charge:
Small Pumping Operations:
15 horsepower or less total connected horsepower
served through one service connection - $13.00 per Customer
Large Pumping Operations:
16 horsepower or more total connected horsepower
served though one service connection - $38.00 per Customer
(Continued)
Submitted Under Case No. PAC-E-11-12
ISSUED: November 2,2011 EFFECTIVE: Janua 1,2012
~~l.~OUNTAIN
Rocky Mountain Power
Exhibit No. 50 Page 10 of 48
Case No. PAC-E-11-12
Witness: J. Ted Weston
I.P.U.C. No.1
Sixth Revision of Sheet No. 10.2
Canceling Fifth Revision of Sheet No. 10.2
ELECTRIC SERVICE SCHEDULE No. 10 - Continued
MONTHLY BILL: (Continued)
Power Rate:$5.31 per kW for all kW
Energy Rate:7.9434~ per kWh for first 25,000 kWh
5.8755~ per kWh for the next 225,000 kWh
4.3368~ per kWh for all additional kWh
Power Factor: This rate is based on the Customer maintaining at all times a power factor
of 85% lagging, or higher, as determed by measurement. If the average power factor is
found to be less than 85% lagging, the power as recorded by the Company's meter wil be
increased by 3/4 of 1 % for every 1 % that the power factor is less than 85%.
Minimum:The Customer Service Charge.
Post-Season Rate
Customer Service Charge:
Energy Rate:
$21.00 per Customer
6.7187~ per kWh for all kWh
Minimum:The Customer Service Charge.
ADJUSTMENTS: All monthly bils shall be adjusted in accordance with Schedules 34 and 94.
PAYMENT: All monthly service bilings wil be due and payable when rendered and wil be
considered delinquent if not paid within fifteen (15) days. An advance payment may be required of the
Customer by the Company in accordance with Electric Service Regulation NO.9. An advance may be
required under any of the following conditions:
(1) the Customer failed to pay all amounts owed to the Company when due and
payable;
(2) the Customer paid an advance the previous season that did not adequately cover
bils for the entire season and the Customer failed to pay any balance owing by the
due date of the final biling issued for the season.
( Continued)
Submitted Under Case No. PAC-E-l1-12
ISSUED: November 2, 2011 EFFECTIVE: January 1,2012
'2t~~OUNTAIN
Rocky Mountain Power
Exhibit No. 50 Page 11 of 48
Case No. PAC-E-11-12
Witness: J, Ted Weston
I.P.U.C. No.1
Sixth Revision of Sheet No. 19.2
Canceling Fifth Revision of Sheet No. 19.2
ELECTRIC SERVICE SCHEDULE NO.19 - Continued
MONTHLY BILL:
Rate for space heatig:
Customer
Service Charge: $22.00
Biling Months May
though October, Inclusive
Biling Months November
through ApriL, Inclusive
per Customer $22.00 per Customer
Energy Rate: 8.8093~per kWh for all kWh 6.5274~per kWh for all kWh
Rate for all other service:
All other service requirements wil be supplied under Electrc Service Schedule No.6, or
Electric Service Schedule No. 6A, or Electric Service Schedule No. 23, or Electrc Service
Schedule No. 23A, or Electrc Service Schedule No.35, or Electric Service Schedule No. 35A.
SPACE HEATING: All space heating equipment shall be permanently installed and shall be the
sole means of heating the building space occupied by the Customer. All space heating equipment and
installation thereof and all supply wiring shall conform with the Company's specifications.
AIR CONDITIONING: All air conditioning equipment shall be permanently installed and shall be
the sole means of providing comfor cooling for the building space occupied by the Customer. All air
conditioning equipment and installation thereof and all supply wirig shall conform with the Company's
specifications. Electrc service for comfort cooling wil be metered and biled at the above rate only when
Customer also uses electric service for his total space heating requirements.
WATER HEATING: Water heaters served hereunder shall be insulated storage, single or multiple-
unit type of constrction approved by the Company, the heating units of which shall be noninductive and
controlled by separate thermostats. Electrc service of storage water heating wil be metered and biled at the
above rate only when Customer also uses electric service for his total space heating requirements.
(Continued)
Submitted Under Case No. PAC-E-ll-12
ISSUED: November 2,2011 EFFECTIVE: January 1,2012
~~~OUNTAIN Rocky Mountain Power
Exhibit No, 50 Page 12 of 48
Case No. PAC-E-11-12
Witness: J, Ted Weston
I.P.U.C. No.1
Fourth Revision of Sheet No. 23.1
Canceling Third Revision of Sheet No. 23.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 23
STATE OF IDAHO
General Servce
AVAILABILITY: At any point on the Company's interconnected system where there are facilities of
adequate capacity.
APPLICATION: Ths Schedule is for alternating curent, single or thee-phase electrc service
supplied at Company's available voltage though one meterig installation at a single point of delivery for all
service required on the premises.
MONTHLY BILL:
Billing Months May
through October, Inclusive
Biling Months November
through ApriL, Inclusive
Customer Service
Charge:
Secondary voltage
delivery (Less than
2300 volts) $15.00 per Customer $15.00 perCustomer
Primar voltage
delivery (2300 volts
or higher) $46.00 per Customer $46.00 per Customer
Energy Rate:8.5835t per kWh for all kWh 7.4928t per kWh for all kWh
(Continued)
Submitted Under Case No. PAC-E-11-12
ISSUED: November 2,2011 EFFECTIVE: January 1,2012
~~~OUNTAIN Rocky Mountain Power
Exhibit No. 50 Page 13 of 48
Case No. PAC-E-11-12
Witness: J. Ted Weston
I.P.U.C. No.1
Third Revision of Sheet No. 23.2
Cancelig Second Revision of Sheet No. 23.2
ELECTRIC SERVICE SCHEDULE NO. 23 - Contiued
Power Factor:
This rate is based on the Customer maintaing at all times a power factor of 85% lagging, or
higher, as determned by measurement. If the average power factor is found to be less than
85% lagging, Customer wil be biled for 3/4 of 1% of the Power recorded by the Company's
meter for every I % that the power factor is less th 85%. Ths Power will be biled at the
Power Rate stated in Electrc Service Schedule NO.6.
Voltage Discount:
Where Customer taes service from Company's available lines of 2,300 volts or higher and
provides and maintains all trsformers and other necessar equipment, the voltage discount
based on measured Energy wil be:
0.4146~ per kWh for all kWh.
Miimum Bil:
The Customer Service Charge
POWER: The kW as shown by or computed from the readigs of the Company's Power meter for
the 15-miute period of Customer' s greatest use durg the month, determed to the nearest kW.
SEASONAL SERVICE: Servce for annually recurg periods of seasonal use where servce is
normlly discontinued or curiled during a par of the year may be contrcted for under ths Schedule under
either of the following conditions:
(a) Customer may contract for service under ths Schedule on a year-round basis paying for all
service, includig trsformer losses where applicable, under the rates set fort under
"Monthy Bil" above including the monthly mium bil durg those months service is
curiled or is not utilized in the Customets operations.
(b) Customer may contrct for seasonal service under this Schedule with a net miimum seasonal
payment as follows:
$180.00 plus Energy Charges for Customer tang service at less than 2,300 volts and
$552.00 plus Energy Charges for Customer tang service at 2,300 volts or higher.
CONTRACT PERIOD: One year or longer.
(Continued)
Submitted Under Case No. PAC-E-II-12
ISSUED: November 2,2011 EFFECTIVE: January 1,2012
~~~OUNTAIN Rocky Mountain Power
Exhibit No. 50 Page 14 of 48
Case No, PAC-E-11-12
Witness: J. Ted Weston
I.P.U.C. No.1
Fourth Revision of Sheet No. 23A.l
Cancelig Third Revision of Sheet No. 23A.l
ROCKY MOUNAI POWER
ELECTRIC SERVICE SCHEDULE NO. 23A
STATE OF IDAHO
General Servce (Residential and Farm)
AVAILABILITY: At any point on the Company's interconnected system where there are facilities of
adequate capacity for service to any customer who qualifies as a "Residential Load" or "Far Load" under both
(1) the Pacific Nortwest Electrc Power Plang and Conservation Act, P.L. 96-501 as the same may be
amended, and (2) a Residential Purchase and Sale Agreement, under Section 5(c) of such Act and in effect
between the Company and the Bonnevile Power Admnistration.
APPLICATION: Ths Schedule is for alternating curent, single or thee-phase electc service
supplied at Company's available voltage though one meterig installation at a single point of delivery for all
service requied on the premises.
MONTHLY BILL:
Biling Months May
through October, Inclusive
Biling Months November
though ApriL, Inclusive
Customer Servce
Charge:
Secondary voltage
delivery (Less than
2300 volts) $15.00 per Customer $15.00 per Customer
Primary voltage
delivery (2300 volts
or higher) $46.00 per Customer $46.00 per Customer
Energy Rate:8.5835~ per kWh for all kWh 7.4928~ per kWh for all kWh
(Continued)
Submitted Under Case No. PAC-E-1 1-12
ISSUED: November 2,2011 EFFECTIVE: January 1,2012
~2!\~OUNTAIN
Rock Mountain Power
Exhibit No. 50 Page 15 of 48
Case No. PAC-E-11-12
Witness: J. Ted Weston
I.P.U.C. No.1
Third Revision of Sheet No. 23A.2
Cancelig Second Revision of Sheet No. 23A.2
ELECTRC SERVICE SCHEDULE NO. 23A - Contiued
Power Factor:
This rate is based on the Customer maintainig at all times a power factor of 85% lagging, or
higher, as determned by measurement. If the average power factor is found to be less th
85% lagging, Customer wil be biled for 3/4 of 1 % of the Power recorded by the Company's
meter for every 1 % that the power factor is less than 85%. This Power will be biled at the
Power Rate stated in Electrc Service Schedule NO.6.
Voltage Discount:
Where Customer taes service from Company's available lines of 2,300 volts or higher and
provides and maintains all tranformers and other necessar equipment, the voltage discount
based on measured Energy wil be:
0.4146~ per kWh for all kWh.
Minimum Bil:
The Customer Servce Charge
POWER: The kW as shown by or computed from the readigs of the Company's Power meter for
the 15-miute period of Customer's greatest use durg the month, determed to the nearest kW.
MONTHLY BILLING REDUCTION: Rates in ths Schedule shall be reduced by the monthly
kilowatt-hour credit adjustment set fort under "Monthly Rates" in the curently effective Electrc Service
Schedule No. 34.
SEASONAL SERVICE: Service for anually recurg periods of seasonal use where service is
normlly discontinued or curiled durg a par of the year may be contrcted for under ths Schedule under
either of the following conditions:
(a) Customer may contract for service under this Schedule on a year-round basis payig for all
service, includig transformer losses where applicable, under the rates set fort under
"Monthly Bil" above includig the monthly miimum bil durg those months service is
curiled or is not utilized in the Customer's operations.
(Continued)
Submitted Under Case No. PAC-E-11-12
ISSUED: November 2, 2011 EFFECTIVE: Janua 1,2012
~~~OUNTAIN Rocky Mountain Power
Exhibit No. 50 Page 16 of 48
Case No. PAC-E-11-12
Witness: J, Ted Weston
I.P.U.C. No.1
Second Revision of Sheet No. 23A.3
Canceling First Revision of Sheet No. 23A.3
ELECTRIC SERVICE SCHEDULE NO. 23A - Contiued
SEASONAL SERVICE: (continued)
(b) Customer may contract for seasonal service under this Schedule with a net mium seasonal
payment as follows:
$180.00 plus Energy Charges for Customer takig servce at less than 2,300 volts and
$552.00 plus Energy Charges for Customer taking service at 2,300 volts or higher.
CONTRACT PERIOD: One year or longer.
SPECIA CONDITION: Domestic use means all usual residential, aparent, seasonal dwellig,
and mobile home cour use including domestic water pumping. Farm use means all usual far electrcal loads
for raising of crops, livestock or pastuage and includes priry processing necessary for safe and effcient
storage or shipment and irgation pumping.
Contiguous parcels of land under single-ownership or leasehold shall be considered to be one Far and
noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Far unt when
operated as a single Farm, unless demonstrted otherwise by the owner or lessee of the parcels.
A number of factors shall determe whether contiguous or noncontiguous parcels constitute one or
more Fars. These factors shall include, but are not limitedto:
size
use
ownership
control
operating practices
distance between parcels
custom in the trde
biling treatment by the utility
Operators of Fars may be required to certfy to the utility all irrgation accounts, including
horsepower rating.
Customers who feel they meet the definitions of a Far wil have to make application with the
Company for review. If Customer application is denied by the Company, the Customer may appeal the
decision to the Idaho Public Utilties Commssion.
(Continued)
Submitted Under Case No. PAC-E-11-12
ISSUED: November 2,2011 EFFECTIVE: Janua 1,2012
~~,"~OUNTAIN
Rocky Mountain Power
Exhibit No. 50 Page 17 of 48
Case No. PAC-E-11-12
Witness: J. Ted Weston
I.P.U.C. No.1
Fifth Revision of Sheet No. 35.2
Cancelig Fourth Revision of Sheet No. 35.2
ELECTRIC SERVICE SCHEDULE NO. 35 - Contiued
MONTHLY BILL:
Customer Servce Charge:
Secondar voltage delivery
(Less than 2300 volts)$ 63.00 per Customer
Primary voltage delivery
(2300 volts or higher)$155.00 per Customer
Power Charge:
On-PeakkW $15.49perkW
Energy Charge:
Per kWh for all kWh 4.6154Ø
TIME PERIODS:
On-Peak
Off-Peak
7:00 a.m. to 10:00 p.m., Monday th Friday, except holidays.
All other times.
Due to the expansions of Daylight Saving Time (DST) as adopted under Section 110 of the
U.S. Energy Policy Act of 2005 the time periods shown above wil begin and end one hour, later for the
period between the second Sunday in March and the first Sunday in April, and for the period between the
last Sunday in October and the first Sunday in November.
Holidays include only New Year's Day, President's Day, Memorial Day, Independence Day,
Labor Day, Thansgiving Day, and Chrstmas Day. When a holiday falls on a Satuday or Sunday, the
Friday before the holiday (if the holiday falls on a Satuday) or the Monday following the holiday (if the
holiday falls on a Sunday) wil be considered a holiday and consequently Off-Peak.
Power Factor: This rate is based on the Customer maintaining at all times a Power factor of 85%
lagging, or higher, as determned by measurement. If the average Power factor is found to be less than 85%
lagging the Power as recorded by the Company's meter wil be increased by 3/4 of i % for every i % that the
Power factor is less than 85%.
Voltage Discount: Where Customer takes service from Company's available lines of 2,300 volts or
higher and provides and maintains all transformers and other necessar equipment, the voltage discount
based on highest measured Power during the biling cycle wil be:
$0.79 perkW
Minimum:Customer Service Charge plus applicable Demand and Energy charges.
(Continued)
Submitted Under Case No. PAC-E-II-12
ISSUED: November 2, 2011 EFFECTIVE: January 1,2012
~~~~OUNTAIN
Rocky Mountain Power
Exhibit No. 50 Page 18 of 48
Case No. PAC-E-11-12
Witness: J. Ted Weston
I.P.U.C. No.1
Third Revision of Sheet No. 35.3
Canceling Second Revision of Sheet No. 35.3
ELECTRIC SERVICE SCHEDULE NO. 35 - Continued
POWER: The On-Peak kW shall be the kW as shown by or computed from the readings of
Company's Power meter for the 15-minute period of Customer's greatest use durng the On-Peak periods
durng the month as previously defmed, adjusted for Power Factor as specified, determed to the nearest
kW.
SEASONAL SERVICE: Service for annually recurng periods of seasonal use where service
is normally discontinued or curiled during a par of the year may be contracted for under this schedule
under either of the following conditions:
(a) Customer may contract for service under this schedule on a year-round basis paying for all
service, including transformer losses where applicable, under the rates set forth under
"Monthly Bil" above including the monthly minimum bil durg those months service is
curailed or is not utilized in the Customer's operation.
(b) Customer may contract for seasonal service under this schedule with a net minium
seasonal payment as follows:
$ 756.00 plus Power and Energy Charges for Customer takng service at less than
2300 volts, and
$1,860.00 plus Power and Energy Charges for Customer takig service at 2300 volts or
higher.
CONTRACT PERIOD: One year or longer.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule wil be in
accordance with the terms of the Electrc Service Agreement between the Customer and the Company. The
Electrc Service Regulations of the Company on fie with and approved by the Idaho Public Utilities
Commssion, including futue applicable amendments, wil be considered as formg a part of and
incorporated in said Agreement.
Submitted Under Case No. PAC-E-11-12
ISSUED: November 2, 2011 EFFECTIVE: January 1,2012