20131227PAC to Staff 7-16.pdf

ROCKY MOUNTAIN 20!South Main,Suite 2300‘POWER Salt Lake City,Utah 84!
ADIVSION OFPACIFICOFP
rr .P 1:fJ
-IDecember24,20li -
Jean Jewel!
Idaho Public Utilities Commission
472 W.Washington
Boise,ID 83702-5918
jean.jewelltpuc.Idaho.gov (C)
RE:ID PAC-E-13-15
IPUC 2”Set Data Request (7-16)
Please find enclosed Rocky Mountain Power’s responses to IPUC 2nd Set Data Requests 7-16.
Also provided are Attachments IPUC 16 —(1-3).
If you have any questions,please feel free to call me at [phone].
Sincerely,
Z
J.Ted Weston
Manager,Regulation
PAC-E-13-15/Rocky Mountain Power
December 24,2013
IPUC Data Request 7
IPUC Data Request 7
Please state whether the Company calculates cost-effectiveness of each DSM
program based upon a program’s annual gross benefits rather than net benefits.
Please explain the Company’s rationale.
Response to IPUC Data Request 7
Cadmus calculated costs-effectiveness following the California Standard Practice
Manual methodology.Gross benefits are used only for the Participant Cost Test,
while all other test perspectives use net benefits to determine cost-effectiveness.
Recordholder:Esther Giezendanner
Sponsor:To Be Determined
PAC-E-13-15/Rocky Mountain Power
December 24,2013
IPUC Data Request 8
IPUC Data Request $
Please provide all assumptions,and corresponding sources,used to calculate net
benefits and gross benefits for each DSM program.
Response to IPUC Data Request 8
Cost effectiveness calculations during 2011 and 2012 used avoided cost
decrements,line losses,armual measure energy savings,low income non-energy
benefits,measure life,and the net-to-gross ratio to calculate benefits for each
DSM program.
Table 1 shows these inputs and their sources.
Table 1 Innut Sources
Inputs Source
Avoided Costs PacifiCorp’s 2011 IRP Avoided Cost Decrements
Program Specific Annual Energy Program Administrators /Evaluations/Planning
Savings
Low Income Non-Energy Benefits Health,Safety and Repair Costs
Residential and C&I Line Losses PacifiCorp Electric Operations Loss Study
Program Specific Measure Life Multiple Sources Including Regional Technical
forum
Program Specific Net-to-Gross Ratio Annual Impact Evaluations
Recordholder:Esther Giezendanner
Sponsor:To Be Determined
PAC-E-13-15/Rocky Mountain Power
December 24,2013
IPUC Data Request 9
IPUC Data Request 9
Please provide the amount of low-income energy conservation kits distributed
during 2012.
Response to IPUC Data Request 9
151 kits were distributed in 2012.This number is included in the 2012 Annual
Report on page 24.
Recordholder:Becky Eberle
Sponsor:To Be Determined
PAC-E-13-15/Rocky Mountain Power
December 24,2013
IPUC Data Request 10
IPUC Data Request 10
For 2011 and 2012,please provide the number of Participants,Units and/or
Projects that were reported for the Agricultural Energy Services,Home Energy
Savings,and FinAnswer Express programs.
Response to IPUC Data Request 10
Agricultural Energy Services Home Energy Savings finAnswer Express
2011 219 7,606 72
2012 206 8,778 $1
Recordholder:Esther Giezendaimer
Sponsor:To Be Determined
PAC-E-13-15/Rocky Mountain Power
December 24,2013
IPUC Data Request 11
IPUC Data Request ii
In 2012,were any Office of Energy Resources projects reported?If so,did the
Company claim savings and expenditures?
Response to IPUC Data Request 11
There were no Office of Energy Resources projects reported in 2012.
Recordholder:Lisa Romney
Sponsor:To Be Determined
PAC-E-13-15/Rocky Mountain Power
December 24,2013
IPUC Data Request 12
IPUC Data Request 12
Please provide the number of workshops the Company conducted and the amount
of participants for each commercial/industrial/agricultural program in 2010,2011
and 2012.
Response to IPUC Data Request 12
Golden West 2/24/2010 Idaho 30 Overview of program
Irrigation Pivot FaIls,ID offerings &VFD energy
School savings presentation.
Rain For Rent 2/25/2010 Idaho 30 Overview of program
Customer Falls,ID offerings &VFD energy
Appreciation Day savings presentation.
Valley Implement 2/25/2010 Preston,50 Operated a booth and
Customer ID presented program
Appreciation Day information.
NW TAN Hands on 05/06/2010 Idaho 80 Workshop and
lighting controls Falls,ID presentation
RMP Program 05/06/2010 Idaho 80 Program update
Review/Incentive Falls,ID presentation
Review
NW Food 10/19/2010 CaIdwell Unknown Workshop and
Processor Idaho presentation
NW Food 10/20/2010 Twin Unknown Workshop and
Processor Falls,ID presentation
Eastern Idaho Ag 1/18/2011 Pocatello,50 Operated a booth and
Expo ID presented program
information.
Eastern Idaho Ag 1/19/2011 Pocatello,50 Operated a booth and
Expo ID presented program
information.
Eastern Idaho Ag 1/20/2011 Pocatello,50 Operated a booth and
Expo ID presented program
information.
Rain For Rent 2/24/2011 Idaho 40 Operated a booth and
2/23/2010 Idaho
Falls,ID
30GoldenWest Overview of program
Irrigation Pivot offerings &VFD energy
School savings presentation.
PAC-E-13-15/Rocky Mountain Power
December24,2013
IPUC Data Request 12
Valley Implement 2/24/2011 Preston,50 Operated a booth and
Customer ID presented program
Appreciation Day information.
Idaho Energy 05/03/2011 Idaho 70 Workshop/Presentation
Efficiency Alliance Falls,ID
Training
IIEA —Irrigation 1/5/2012 Idaho 30 Presentation on program
Show &Falls,ID offerings and custom
Conference projects.
Eastern Idaho Ag 1/17/2012 Pocatello,50 Operated a booth and
Expo ID presented program
information.
Eastern Idaho Ag 1/18/2012 Pocatello,50 Operated a booth and
Expo ID presented program
information.
Eastern Idaho Ag 1/19/2012 Pocatello,50 Operated a booth and
Expo ID presented program
information.
New tariff 08/08/2012 Idaho 50 Presentation
workshop Falls,ID
Lighting Workshop 02/14/2012 Idaho 50 Workshop/presentation
Falls,ID
Note:the number of participants at each event is estimated.The total number was not
recorded at the time of the event.
Recordholder:Nancy Goddard
Sponsor:To Be Determined
Customer
Appreciation Day
Falls,ID presented program
information.
PAC-E-13-1 5/Rocky Mountain Power
December 24,2013
IPUC Data Request 13
IPUC Data Request 13
Please provide the 2010 and 2011 Annual Performance and Activity Results in a
manner identical to the 2012 DSM Annual Report.
Response to IPUC Data Request 13
The Company does not have this information available.Please refer to the Annual
Reports that are posted online at:http://www.pacificorp.com/es/dsmlidaho.html
Recordholder:Lisa Romney
Sponsor:To Be Determined
PAC-E-13-15/Rocky Mountain Power
December 24,2013
IPUC Data Request 14
IPUC Data Request 14
Please provide the savings goats from the Company’s Conservation Potential
Assessment (CPA)and Integrated Resource Plan (IRP)for each year 2010-2015
for Idaho.Please delineate by program.If the forecast(s)were not attained,
please provide a detailed description as to why.
Response to IPUC Data Request 14
for Class 2 energy efficiency energy resources the CPA and IRP do not assess
opportunities or economically screen and select targets at a specific program level
(CPA and IRP assess and model at a measure and bundled measure level,
respectively)so providing this level of delineation is not possible.The table
below details JRP targets for the years requested,results achieved (if available),
and general variance explanation.
IRP Achieved Variance Explanation
Selection Results
(MWh)(MWh)(MWh)
2010 l&$24’13,0962 -3,728 In smaller less diverse service areas
variations are normal year to year;
company seeks to acquire identified and
selected opportunities over time (down in
2010 and 2011,up in 2012 and 2013).No
outstanding issue identified other than the
company ceased funding and reporting
savings associated with NEEA beginning
in 2010.
2011 15,650 9,513 -6,137 See note above
2012 9,3755 12,6156 3,240 Seenoteabove
2013 7,165 15,615g 8,450 Seenoteabove
‘200$IRP Update (March 2010)Energy Efficiency Selections.Run —BPV2 Study with 8/31/09 Loads $45
C02 (BP1001920_DSM)
200$IRP Update (March 2010)2011 BPVI Study with 04/01/10 Loads $45 C02 ($54 T&D Credit)
2011 Energy Efficiency and Peak Reduction AnnuaL Report —Idaho —(Revised August 2,2012)
20I1 IRP Preferred Portfolio with 09/02/10 Loads $19 C02 ($54 T&D Credit)
Idaho Energy Efficiency and Peak Reduction Annual Report January 1,2012 December 31,2012 (April
30,2013)
2011 IRP update 2013 Business Plan Vi (Preliminary)$54 T&D Credit
PAC-E-13-1 5/Rocky Mountain Power
December 24,2013
IPUC Data Request 14
2014 11,090w tbd tbd
2015 11,470’°tbd tbd
Recordholder:Jeff Bumgarner
Sponsor:To Be Determined
8 Preliminary 2013 forecast.November,2013 GAP/Forecast Report.
p2013 IRP (April 30,2013)
102013 IRP (April 30,2013)
PAC-E-i3-15/Rocky Mountain Power
December 24,2013
IPUC Data Request 15
IPUC Data Request 15
Please provide the projected annual cost-effectiveness,participation,expenditure
level,and energy savings for each DSM program in 2013,2014,and 2015?If the
projection is greater or less than the CPA and IRP forecast,please explain why.
Response to IPUC Data Request 15
Projected annual cost-effectiveness and program participation for 2013,2014 and
2015 are not available at this time.2013 results will be available concurrent with
the filing of the Company’s 2013 annual report to by April 30,2014.
Projected annual expenditures by approved/existing program for 2013 are based
on actuals through November and estimated forecast for December.Years 2014
and 2015 are based on the Company’s 10-year business plan and are as follows’:
Programs 2013 2014 2015
Low Income $235,000 $380,000 $380,000
Home Energy Savings $660,000 $860,730 $1,000,642
Refrigerator Recycling $99,900 $101,964 $102,036
Energy finAnswer $376,100 $473,400 $263,064
finAnswer Express $868,000 $695,400 $730,800
Irrigation Energy $975,000 $600,000 $600,000
Savers
Irrigation Load Control2 $5,075,000 $7,100,000 $7,100,000
Projected energy savings for 2013 by program in the following table is provided
based on the information available at this time:actual results through October,
2013,and forecasted results for November through December3.final results for
2013 will be provided concurrent with the filing of the Company’s 2013 annual
report by April 30,2014.
‘2013-2015 business case budgets (June,2013),approved/existing programs only.
2 Costs are expensed and not recovered through Schedule 191,Customer Efficiency Services Rate
Adjustment.
Preliminary 2013 forecast.November,2013 GAP/forecast Report.
PAC-E-13-1 5/Rocky Mountain Power
December 24,2013
IPUC Data Request 15
Programs 2013 Forecasted Savings (MWh)
Low Income 171
Home Energy Savings 2,850
Refrigerator Recycling 800
Energy FinAnswer 2,552
FinAnswer Express 5,638
Irrigation Energy Savers 3,605
Irrigation Load Control 0
Projected energy savings at a program level for 2014 and 2015 are expected to be
similar to 2013 however are not available at this time.The CPA identifies
resource opportunity at a measure level and the IRP screens those resource
opportunities for economic viability/initial cost-effectiveness.IRP resource
selections of energy resources are screened at a bundled measure level,not by
program (see PacifiCorp’s 2013 IRP,Volume I,page 142,“Class 2 DSM,Energy
Supply Curves”).As a result,it’s not possible to provide variance comparisons
between IRP selections and Company energy savings forecasts at a program level.
Recordholder:Jeff Bumgarner
Sponsor:To Be Determined
PAC-E-13-15!Rocky Mountain Power
December 24,2013
IPUC Data Request 16
IPUC Data Request 16
Please provide all attachments and exhibits contained in the Company’s
application and production requests in electronic format with all formulas intact.
Response to IPUC Data Request 16
Please see Attachments IPUC 16-1,IPUC 16-2,and IPUC 16-3.
Recordholder:Esther Giezendanner
Sponsor:To Be Determined
ID
PA
C
-
E
-
1
3
-
1
5
At
t
a
c
h
m
e
n
t
IP
U
C
16
-
1
IP
U
C
16
AT
T
A
C
H
M
E
N
T
1
ES
T
I
M
A
T
E
D
RE
V
E
N
U
E
FR
O
M
SC
H
E
D
U
L
E
19
1
FR
O
M
EL
E
C
T
R
I
C
SA
L
E
S
TO
UL
T
I
M
A
T
E
CU
S
T
O
M
E
R
S
DI
S
T
R
I
B
U
T
E
D
BY
RA
T
E
SC
H
E
D
U
L
E
S
IN
ID
A
H
O
HI
S
T
O
R
I
C
12
MO
N
T
H
S
EN
D
E
D
DE
C
E
M
B
E
R
20
1
2
Pr
e
s
e
n
t
DS
M
Re
v
e
n
u
e
Li
n
e
Av
e
r
a
g
e
Re
v
Ra
t
e
Re
v
No
.
De
s
c
r
i
p
t
i
o
n
Sc
h
.
Cu
s
t
MW
H
($
0
0
0
)
*
%
($
0
0
0
)
(1
)
(2
)
(3
)
(4
)
(5
)
(6
)
(7
)
Re
s
i
d
e
n
t
i
a
l
Sa
l
e
s
I
Re
s
i
d
e
n
t
i
a
l
Se
r
v
i
c
e
1
43
,
6
8
5
42
4
,
8
6
6
$4
9
,
0
8
1
2.
1
%
$1
,
0
3
1
2
Re
s
i
d
e
n
t
i
a
l
Op
t
i
o
n
a
l
TO
D
36
14
,
2
7
9
26
0
,
6
1
2
$2
5
,
7
2
3
2.
1
%
$5
4
0
3
AG
A
Re
v
e
n
u
e
$3
4
To
t
a
l
Re
s
i
d
e
n
t
i
a
l
57
,
9
6
4
68
5
,
4
7
7
$7
4
,
8
0
7
__
_
_
_
_
_
_
_
_
_
_
_
_
$1
,
5
7
1
5
Co
m
m
e
r
c
i
a
l
&
In
d
u
s
t
r
i
a
l
6
Ge
n
e
r
a
l
Se
r
v
i
c
e
-
La
r
g
e
Po
w
e
r
6
1,
0
4
8
28
1
,
8
9
9
$2
4
,
1
5
7
2.
1
%
$5
0
7
7
Ge
n
e
r
a
l
Sv
c
.
-
Lg
.
Po
w
e
r
(R
&
F
)
6A
21
9
32
,
3
9
6
$2
,
9
4
5
2.
1
%
$6
2
8
St
t
h
t
o
t
a
l
-
S
c
h
e
d
u
l
e
6
1,
2
6
7
31
4
,
2
9
5
$2
7
,
1
0
1
$5
6
9
9
Ge
n
e
r
a
l
Se
r
v
i
c
e
-
Hi
g
h
Vo
l
t
a
g
e
9
15
11
8
,
8
3
7
$7
,
8
3
7
2.
1
%
$1
6
5
10
Ir
r
i
g
a
t
i
o
n
10
4,
8
9
4
65
8
,
3
2
5
$6
0
,
4
9
8
2.
1
%
$1
,
2
7
0
11
Co
m
m
.
&
In
d
.
Sp
a
c
e
He
a
t
i
n
g
19
11
6
8,
5
5
9
$7
2
6
2.
1
%
$1
5
12
Ge
n
e
r
a
l
Se
r
v
i
c
e
23
6,
8
4
1
14
5
,
1
7
3
$1
4
,
7
0
9
2.
1
%
$3
0
9
13
Ge
n
e
r
a
l
Se
r
v
i
c
e
(R
&
F
)
23
A
1,
8
2
3
24
,
2
8
1
$2
,
5
7
0
2.
1
%
$5
4
14
Su
b
t
o
t
a
l
-
S
c
h
e
d
u
l
e
23
8,
6
6
4
16
9
,
4
5
4
$1
7
,
2
7
9
$3
6
3
15
Ge
n
e
r
a
l
Se
r
v
i
c
e
Op
t
i
o
n
a
l
TO
O
35
3
1,
1
4
4
$9
8
2.
1
%
$2
16
Sp
e
c
i
a
l
Co
n
t
r
a
c
t
1
40
0
1
1,
4
0
0
,
1
1
4
$8
3
,
3
7
5
0.
0
%
$0
17
Sp
e
c
i
a
l
Co
n
t
r
a
c
t
2
40
1
1
10
6
,
6
4
6
$6
,
2
9
0
0.
0
%
$0
18
AG
A
Re
v
e
n
u
e
$5
9
9
19
To
t
a
l
Co
m
m
e
r
c
i
a
l
&
In
d
u
s
t
r
i
a
l
14
,
9
6
1
2,
7
7
7
,
3
7
4
$2
0
3
,
8
0
2
__
_
_
_
_
_
_
_
_
_
_
_
_
$2
,
3
8
4
20
Pu
b
l
i
c
St
r
e
e
t
Li
g
h
t
i
n
g
21
Se
c
u
r
i
t
y
Ar
e
a
Li
g
h
t
i
n
g
7
19
4
25
6
$9
9
2.
1
%
$2
22
Se
c
u
r
i
t
y
A
r
e
a
L
i
g
h
t
i
n
g
(
R
&
F
)
7A
13
4
10
8
$4
5
2.
1
%
$1
23
St
r
e
e
t
Li
g
h
t
i
n
g
-
Co
m
p
a
n
y
11
30
71
$3
2
2.
1
%
$1
24
St
r
e
e
t
L
i
g
h
t
i
n
g
-
C
u
s
t
o
m
e
r
12
27
6
2,
4
4
4
$4
4
6
2.
1
%
$9
25
AG
A
Re
v
e
n
u
e
$0
26
To
t
a
l
Pu
b
l
i
c
St
r
e
e
t
Li
g
h
t
i
n
g
63
4
2,
8
7
8
$6
2
1
__
_
_
_
_
_
_
_
_
_
_
_
_
$1
3
27
To
t
a
l
Sa
l
e
s
to
Ul
t
i
m
a
t
e
Cu
s
t
o
m
e
r
s
73
,
5
5
9
3,
4
6
5
,
7
2
9
$2
7
9
,
2
3
0
__
_
_
_
_
_
_
_
_
_
_
_
_
$3
,
9
6
8
al
n
c
l
u
d
i
n
g
th
e
or
d
e
r
e
d
ba
s
e
re
v
e
n
u
e
in
c
r
e
a
s
e
in
20
1
4
an
d
es
t
i
m
a
t
e
d
EC
A
M
re
v
e
n
u
e
.
Pr
o
p
o
s
e
d
DS
M
Cr
e
d
i
t
Ca
l
c
u
l
a
t
i
o
n
Pr
o
p
o
s
e
d
on
e
-
t
i
me
cr
e
d
i
t
$1
,
4
0
0
,
0
0
0
To
t
a
l
Sc
h
e
d
u
l
e
19
1
ch
a
r
g
e
s
fr
o
m
Oc
t
o
b
e
r
20
1
2
to
Se
p
t
e
m
b
e
r
20
1
3
fo
r
cu
r
r
e
n
t
l
y
ac
t
i
v
e
cu
s
t
o
m
e
r
s
$3
,
7
8
6
,
6
5
6
Pr
o
p
o
s
e
d
on
e
ti
m
e
DS
M
Cr
e
d
i
t
37
.
0
%
An
n
u
a
l
ne
t
re
v
im
p
a
c
t
ex
c
l
u
d
i
n
g
AG
A
an
d
Sc
h
40
0
&
40
1
0.
7
3
%
Av
g
.
re
s
i
d
e
n
t
i
a
l
re
f
u
n
d
pe
r
cu
s
t
o
m
e
r
$8
.
3
2
At
t
a
c
h
IP
U
C
16
-
1
.
x
l
s
x
pa
g
e
1
of
1
IDAHO DSM
SCHEDULE 191 BALANCING ACCOUNT
Monthly Program Accrued CostsCosts-Fixed BalanceAssets
Rate Recovery
Cash BasisCarryingAccumulatedChargeBalance
Accrual Basis
Accumulated
Balance
2011 totals
1 January
2 February
3 March
4 April
5 May
6 June
7 July
8 August
9 September
10 October
11 November
12 December
2012 totals
1 January
2 February
3 March
4 April
5 May
6 June
7 July
8 August
9 September
10 October
11 November
12 December
2013 totals
897,419.48
764,123.40
666,213.77
563,623.39
478,597.93
47,328.91
(550,777.59)
(898,989.04)
(842,616.74)
(840,821.92)
(675,441.27)
(690,166.89)
(770,340.02)
(637,327.79)
(585,871.55)
(456,132.24)
(584,267.68)
(900,498.90)
(1,184,678.38)
(1,475,929.15)
(1,634,799.36)
(1674445.73)
(1,707,228.02)
(1,768,625.71)
1,371,372.05
1,178,052.57
1,099,973.24
1,025,117.46
921,779.64
519,558.87
38,214.56
(312,398.59)
(399,715.66)
(488,709.04)
(331,352.31)
(370,752.86)
(359,235.15)
(259,097.17)
(171,868.56)
(97,752.93)
(316,649.34)
(654,810.24)
(941,492.89)
(1,210,012.77)
(1,376,916.23)
(1,416,562.60)
(1,449,344.89)
(1,510,742.58)
2006 totals
2007 totals
2008 totals
2009 totals
2010 totals
$1,524,295.02 $-$(1,374,343.46)$6,053.00
$2,120,643.37 $-$(2,048,020.29)$11,692.00
$4,767,955.02 $-$(4,287,059.82)$49,236.00
$6,432,685.21 $-$(5,010,485.78)$46,170.00
$7,515,026.38 $-$(5,939,833.12)$31,829.00
$2,669,984.25 $380,980.18 $(5,356,975.10)$24,350.00
105,440.79 92,972.39 (392,089.99)867.00
221,185.20 (60,023.40)(355,173.28)692.00
238,009.53 19,830.30 (336,515.16)596.00
203,097.08 27,734.60 (306,199.46)512.00
366,808.41 (18,312.36)(452,267.87)434.00
277,172.96 29,048.25 (708,660.98)219.00
306,786.59 116,762.19 (904,683.09)(210.00)
339,573.56 (2,401.70)(687,181.01)(604.00)
463,651.28 (143,689.37)(406,553.98)(725.00)
259,877.05 (90,788.20)(257,381.23)(701.00)
382,425.80 (8,023.92)(216,413.15)(632.00)
207,728.96 (24,674.93)(221,885.58)(569.00)
$3,371,757.21 $(61,566.15)$(5,245,004.78)$(121.00)
187,387.34 91,690.84 (266,990.47)(570.00)
386,781.98 (32,874.25)(253,183.75)(586.00)
278,520.13 35,772.37 (226,554.89)(509.00)
327,008.97 (55,623.68)(196,835.66)(434.00)
159,913.93 (90,760.97)(287,578.37)(471.00)
148,490.26 (21,929.68)(464,103.48)(618.00)
350,916.53 (2,503.17)(634,228.01)(868.00)
232,358.90 22,730.89 (522,501.67)(1,108.00)
246,269.20 (8,033.25)(403,843.41)(1,296.00)
207,700.00 -(246,000,00)(1,346.37)
202,200.00 -(233,600.00)(1,382.29)
196,000.00 -ç256 000 00,(1.397.69)
$2,923,547.24 $(61,530.90)$(3,991,419.71)$(10,586.35)
Page 1 of 2
IDAHO DSM
SCHEDULE 791 BALANCING ACCOUNT
$$-$
Monthly Program Cash Basis Accrual Basis
.Accrued Costs CarryingCosts-Fixed Rate Recovery Accumulated AccumulatedBalanceChargeAssetsBalanceBalance
1 January 247,50000 -(265,100.00)(1,466.52)(1,787,692.23)(1,529,809.10)
2 February 252,300.00 1,148400.00 (2,073.37)(389,065.60)(131,182.47)
3 March 253,200.00 -(225,000.00)(335.97)(361,201.57)(103,318.44)
4 April 260,600.00 (195,600.00)(328.08)(296,529.66)(38,646.53)
5 May 269,200.00 (285,700.00)(240.23)(313,269.89)(55,386.76)
6 June 272,000.00 (461,100.00)(182.27)(502,552.16)(244,669.03)
7 July 287,300.00 (630,500.00)(275,79)(846,027.95)(588,144.82)
8 August 290,500.00 (519,000.00)(609.81)(1,075,137.77)(817,254.64)
9 September 273,300.00 (401,200.00)(842.66)(1,203,880.42)(945,997.29)
10 October 263,700.00 -(244,400.00)(1,011.28)(1,185,591.70)(927,708.57)
11 November 258,000.00 -(232,100.00)(998.78)(1,160,690.48)(902,807.35)
12 December 253,900.00 (256,700.00)(966.08)(1,164,456.56)(906,573.43)
2014 totals 3,181,500.00 (2,568,000.00)(9,330.85)
1 January 316,600.00 -(265,100.00)(991.84)(1,113,948.40)(856,065.27)
2 February 322,800.00 -(251,600.00)(957.96)(1,043,706.35)(785,823.22)
3 March 324,000.00 -(225,000.00)(911.01)(945,617.36)(687,734.23)
4 April 333,300.00 -(195,600.00)(845.39)(808,762.75)(550,879.62)
5 May 344,300.00 -(285,700.00)(698.39)(750,861.13)(492,978.00)
6 June 348,000.00 -(461,100.00)(578.59)(864,539.73)(606,656.60)
7 July 367,500.00 -(630,500.00)(610.87)(1,128,150.59)(870,267.46)
8 August 371,600.00 -(519,000.00)(878.71)(1,276,429.30)(1,018,546.17)
9 September 349,600.00 -(401,200.00)(1,042.19)(1,329,071.49)(1,071,188.36)
10 October 337,400.00 (244,400.00)(1,146.31)(1,237,217.80)(979,334.67)
11 November 330,100.00 -(232,100.00)(1,071.85)(1,140,289.65)(882,406.52)
12 December 324,800.00 (256,700.00)(978.62)(1,073,168.27)(815,285.14)
2075 totals 4,070,000.00 (3,968,000.00)(10,711.71)
$
$$-$..$
Page 2 of 2
ID PAC-E-13-15
IPUC 16 Attachment IPUC 16-3
ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICORP
2!P j:9I.P.U.C.No.1 1
‘Original Sheet No.95
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.95
STATE OF IDAHO
Demand Side Management (DSM)Credit
PURPOSE:The DSM Credit is designed to provide a one-time credit to currently active
retail tariff Customers who were subject to electric service Schedule 191.
AVAILABILITY:At any point on the Company’s interconnected system.
APPLICATION:This Schedule shall be applicable to currently active retail tariff
Customers who were subject to Schedule 191 Customer Efficiency Services rate anytime from
October 2012 through September 2013.
ONE-TIME BILL CREDIT:In addition to the Monthly Charges contained in the
Customer’s applicable schedule,all qualifying currently active customers shall receive a one-time
credit to their bill.The credit will be 37.0 percent of the Customer’s total Schedule l9lcharges
from October 2012 to September 2013.A single bill credit will be applied to each qualifying
customer bill.Bill credit processing will commence on February 1,2014 and will end no later than
March 31,2014.
Submitted Under Case No.PAC-E-1 3-15
FILED:November 7,2013 EFFECTIVE:February 1,2014
Page 1 of 1