20140228Comments.pdf

KRISTINE A. SASSER
DEPUTY ATTORNEY GENERAL .:.:: .-:_.F: 'IDAHO PUBLIC UTILITIES COMMISSION I..; i ' -i .. ., ,, ; !i: i.lJ
PO BOX 83720
BOISE, IDAHO 83720-0074
(208) 334-03s7
BAR NO. 6618
Street Address for Express Mail:
472W, WASHINGTON
BOISE, IDAHO 83702-5918
Attorneys for the Commission Staff
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION )oF PACTFTCORP DBA ROCKY MOUNTAIN ) CASE NO. PAC-E,-13-12
POWER FOR APPROVAL OF ITS )
CAPACITY DEFICIENCY PERIOD TO BE )
UTILIZED IN THE COMPANY'S SAR ) COMMENTS OF THE
METHODOLOGy. ) COMMISSION STAFF
COMES NOW the Staff of the Idaho Public Utilities Commission, by and through its
Attorney of record, Kristine A. Sasser, Deputy Attorney General, to submit the following
comments in response to the Notice of Modified Procedure issued on January 24,2074, Order
No.32970.
BACKGROUND
In Order No. 32697, the Commission directed that a case be initiated outside of each utility's
Integrated Resource Plan (IRP) filing to establish a capacity deficiency period to be utilized in the
utility's Surrogate Avoided Resource (SAR) methodology for computing avoided cost rates to be
included in PURPA power purchase agreements. On October 15, 2013, PacifiCorp dba Rocky
Mountain Power (Rocky Mountain Power) filed an Application requesting that the Commission
approve its updated capacity deficiency periods to be utilized in its SAR avoided cost methodology.
STAFF COMMENTS FEBRUARY 28,2014
STAF'F ANALYSIS
On April 30,2013, Rocky Mountain Power filed its 2013 IRP with the Commission. The
Commission accepted and acknowledged the Company's 2013 IRP on September 11,2013. (See
Order No. 32890).
Attachment A is a copy of Table 5.12 from PacifiCorp's 2013 IRP showing the results of the
Company's capacity balance. The capacity balance is calculated for summer peak loads only. The
capacity balance is developed by determining firm resource capacity available at the annual system
peak load hour, plus a 13 percent planning reserye margin. The capacity balance shows that the
Company is capacity deficit beginning in 2013. The capacity deficit is 824 MW startingin2}l3
with the deficit increasing to 2,308 MW by 2022.
Attachment B is a copy of Figure 5.5 from the 2013 IRP showing the Company's energy
balance. The figure shows a snapshot of how existing system resources could be used to meet
forecasted load across on-peak and off-peak periods given IRP planning assumptions and wholesale
power and natural gas prices. It shows expected monthly energy production from resources in
relation to load assuming no additional resources are added to PacifiCorp's system. Periods where
all available resource energy falls below forecasted loads are indicative of short energy positions
absent the addition of incremental resources to the portfolio. The Company states, "During on-peak
periods, the first energy shortfall appears in July 201 8 and by 2022 available system energy falls
short of monthly loads in January, July, August, and October." (See p.102 of the 2013 IRP).
In its Application, PacifiCorp states that updating the peak and energy balances to reflect the
Company's most recent load forecast and for recent changes in long-term contracts would not alter
the identified deficit years. Consequently, Staff s analysis focused on the information contained in
the IRP, described above.
Staff reviewed the capacity and energy deficits proposed by the Company, and agrees that
they are accurate and correctly determined for purposes of avoided cost computations. Using the
proposed capacity and energy deficits, Staff computed the SAR methodology avoided cost rates.
The rates are shown on Attachment C for wind, solar, non-seasonal hydro, seasonal hydro, and
other project types.
STAFF RECOMMENDATION
Staff recommends approval of a 201 3 first deficit year assumption for capacity and a 20 I 8
first deficit year assumption for energy as proposed by the Company. Staff further recommends
STAFF COMMENTS FEBRUARY 28,201,4
approval of the SAR Methodology avoided cost rates as contained in Attachment C to Staff s
comments. Finally, Staffrecommends that the rates be effective as of the date of Commission
approval.
Respecttully submitted this 2gg day of Feb ruary 2014.
Technical Staff: Rick Sterling
i:umisc:comments/pacel3. l2ksrps commcnts
STAFF COMMENTS FEBRUARY 28,2014
PACIFICORP _ 20 I3 IRP CHAPTER 5 _ RESoURCE NEEDS ASSESSMENT
Table 5.12 - Updated Format: System Capacity Loads and Resources without Resource
Additions
Calendar Year 20t3 2014 20ls 2016 2017 2018 2019 2020 2021 2022
Thermal
Hydroelectric
Renemble
Purchase
Qualifoing Facilrties
Sale
Non-Owned Reserues
Transfers
East Existing Resources
had
Existing Resources:
lntemrptible
DSM
F-"t obligation
Planning Reserves (13%)
frst Reserrrs
East Obligation + Reserrts
fast Position
6,4fi 6,454 6,454 6,454
140 135 135 13283 83 83 83
611 398 285 285
T3 73 73 73
( Tjirr ( 7j1t it;-il: i{,j6 i
il.isl (l:is) ililrr fi.;tt)
737 672 678 683
7 ?36 6,953 6,932 6,934
7,188 6,994 7,105 7,2t7
6,200 6,626
137 14085 85
1,005 6l I
83 73
! 1.0:,ll { 73.:l
i i{lll { l{)lr
750 829
7,125 7,529
6,920 7,061
(1,]i1 (i]-i)
il?9r (:\?er
6,400 6539
832 850
832 850
7232 7189(1r)?) 140't1.3v" ts.lv.
(1.-s:1 (li5r {li5)(i79r (j7)) ri7(,)
6,654 6,460 6571
865 840 854
865 840 854
7 519 7,300 7,425(283} Qli ) ({e3 }8.7/. 7.6v" 55V"
6,454 6,454
l3s 13583 83
285 285T3 73
r (>-lS; (irj,) trl.ll) al.l8)
t,t24 1,122
7378 7375
7,337 7,455
flSi) (155'I
i3-,, t.i71r)
6,803 6921
884 900
884 900
7,687 7821(109) ({116)
8.5y. 6.60/o
6,454 6,454
135 13582 80
zs1 25773 25
rli$i {li$r
tl.lS,r ililt
1,t24 706
7,829 7 361
7,5U 7,697
al-ti) il5:)ii79i (.i79)
7,0s0 7,163
917 931
917 931
7 967 8,094
(138) (71:l)
ll.U/. 2.8o/o
{1i.5)
i -i7rr )
6,683
869
869
7,552
((r I lt)
3.8o/"East
Thennal
Hydroelectric
Renemble
Purchase
Qualifring Facilities
Sale
Non-Owned Reserves
Transfers
Wes t Existing Resources
Load
Existing Resources:
Intemrptible
DSM
West obligrtion
Planning Reserves (13%)
West Reserr,ts
West OHigation + Reserr,ts
West Position
2,s24 2,s24776 75t36 36482 22s8898
i26{)) (26t11
ii)) (())
i?-i-l) (li.i(r)
2,885 2,536
3216 3,269
00
1)ll) (l8j
3,188 3241
414 421
414 421
3,602 3,662
li11) (1,r2(il
2,503 2,503723 n636 362288 89
illli) tlli))
il) i(r.,
il,l.l.:li (t[i)
2,109 2,1 t3
3,479 3,516
00
i:8) (iSr
3,451 3,488
449 453
449 453
3,900 3,941
(,.791) (1,821,)
{3S.rqi,) (._1()".19n)
2,503 2,500&7 650
36 19
2289 89
ili^)i ila).i)
(it i.l)
i 1.,,_1.:lr ij{)t))z,ot5 2,442
3,549 3,583
2,s24 2,520 2,503 2,5037'16 782 780 780
36 36 36 36
231 13 13 1399 89 89 89
il(:rlr (llil) rlji:_r (lii)l
(i); (t)l i9 t i9 r
i7)7) (:'i'.i) 16,=S) {6t,1)
2,760 2,649 2,624 2,619
3,3W 3,365 3,407 3,470
0000(l8i (18) i2si (2s|
3279 3337 3)79 3,442
426 434 439 447
426 434 439 447
3,705 3,771 3,818 3,889(rx5) (1,122) tr,l94) tt,2i0l
00
tl8) (llJ)
3521 3Ss5
458 462
458 462
3,979 4,017
(1,e.1.1) (r,s7s)
t Reserw llilarsin rr.5,',.i,1 12l.Eqi,l 1a.8,)i,j {"10(),ri,) (12.3Yi,) (li ()9i,)(+-l:4.i,) (ll.-lrL;)
Total Resources
Obligation
Reserrrcs
10,010 10,065
9,588 9,7W
1246 1,27'l
9,fi2 9,556 9,553
9,n7 9,950 10,125
t,274 1,294 1,316
9,487 9,488
t0,2s4 10,4091.333 1.353
9.%4 9,803
10.571 10,718
1,3'74 I,393
9,96
9,933
t,291
SystemPosition t'614\ t98(:) (1.12&i t1.469) (i,6Elt) (1,8381 (2 l{X)) (:,27,1) \)-.(.}Bl) l;..)()ltl
Figures 5.2 through 5.4 charts the table above for annual capacity position (resource surplus or
deficits) for the system, west balancing area, and east balancing area, respectively. The east
increase in 2014 is primarily due to the addition of Lake Side 2 natural gas plant.
Attachment A
Staff Comments
Case No. PAC-E-I3-12
2128lt4
99
PncrrConp-2013 IRP CHAPTER 5 _ RESoTJRCE NEEDS ASSESSMENT
Figure 5.5 - System Average Monthly and Annual Energy Positions
On-Peak Energy Balance
5,000
4,500
4,000
3,500
3.000
i z.soo
2,000
1,500
1,000
500
0
O 6 o.a d =f t < h h h n \O\O \O \O F- r F- a- € € @ €O\ O\ O\ O.O O O O * ol N N 6lf f aaf :f i:if ::i=i:I=:::f i:If :tIIi!|qiii1t
E 5E IE 5EIE 5EIE€=IEF=IE 5=IE €EIE 5EIE EEIEEEI
r System Energy at or Below Load r Net Balancing Sale sse Net Balancing Purchase
-Load
System Energy Availablei rEnergy Shortfall
IL__*_-_. _._-___
I
1 Off-Peak Energy Balance
5,000
4,500
4,000
3,500
3.000
B z.soo
2,000
1,500
1,000
500
0
6.n.t cr.+ < * <f, h n h h €\O \O \O F- r F- a'- € € € € O' O, O\ O\ O O O O * c.l N N c.lr(\olNc]NNNNdNC{O1rtrllllrllllll
E 5E I E 5= 8,E 5= I E 5= I E t= 8,E 5E I E tE I E t= 8 E E = I E 5E I
r $ys166 Energy at or Below Load
rEngygy Shortfall
rNet Balancing Sale
'r,r':,r"" System Energy Available
w Net Balancing Purchase
-Load
Attachment B
Staff Comments
Case No. PAC-E-13-12
2128lt4
103
PACIFICORP
AVOIDED COST RATES FOR WIND PROJECTS
March XX, 2014
$/MWh
New Contracts and Replacement Contracts without Full Capacity Payments
Eligibility for these rates is limited to projects 100 kW or smaller.
LEVELIZED NON.LEVELIZEO
CONTRACI
LENGTH
/YFAFIS\
ON-LINE YEAR
CONTRACT
YEAR
NON-LEVELIZED
RATES2014 2015 2016 2017 2018 2019
1
2
3
4
5
6
7I
9
10
11
12
13
14
15
't6
17
18
19
20
31.88
32.52
34.26
35.7,|
37.1 6
38.45
39.59
40.73
41.89
43.01
44.00
44.89
45.70
46.43
47.12
47.77
48.40
49.O2
49.64
50.24
33.21
35.59
37.19
38.75
40.1 0
41.26
42.43
43.63
44.79
45.80
46.71
47.54
48.27
48.96
49.63
50.27
50.90
51.53
52.15
52.79
38.16
39.42
40.90
42.18
43.27
44.42
45.63
46.80
47.82
48.72
49.54
50.26
50.95
51.62
52.26
52.89
53.53
54.17
54.83
55.52
40.79
42.44
43.74
44.82
45.99
47.24
48.46
49.50
50.41
51.23
51.96
52.65
53.32
53.97
54.61
55.27
55.92
56.6'l
57.33
58.08
44.22 46.66
45.39 47.60
46.38 48.8547.55 50.25
4E.85 51.6050.12 52.6751.17 s3.6052.09 54.42
52.91 55.1 3
53.62 55.81
54.31 56.4954.98 57.1555.63 57.8256.29 58.5056.96 59.2057.63 59.93
58.34 60.72
59.09 61.54
59.88 62.4060.69 63.30
2014
2015
201 6
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
31.88
33.21
38.16
40.79
44.22
46.66
48.61
51.66
55.1 8
58.1 3
59.48
60.92
62.30
63.28
65.05
67.01
69.02
71.50
74.37
77.39
81.39
86.4'l
91.67
97 .11
103.33
107.02
Note: These rates will be further adjusted with the applicable integration charge.
Note: The rates shown in this table have been computed using the U.S. Energy Information Administration (ElA)'s Annual Energy
Outlook 2013 released May 2,2013. See'Annual Energy Outlook 2013, All Tables, Energy Prices by Sector and Source, Mountain,
Reference case" at http://www.eia.gov/oiaf/aeo/tablebrowser/.
'ACIFICOR'
page 1
Attachment C
Staff Comments
Case No. PAC-E-13-12
2l28ll4 Page I of 5
PACIFlCORP
AVOIDED COST RATES FOR SOLAR PROJECTS
March XX, 2014
$/MWh
New Contracts and Replacement Gontracts without Full Capacity Payments
Eligibility for these rates is limited to projects 100 kW or smaller.
LEVELIZED NON.LEVELIZEO
30NTMCT
LENGTH
lYFARS]
ON.LINE YEAR
CONTRACT
YEAR
NON.LEVELIZED
RATES2014 2015 2016 2017 2018 2019
1
2
4
R
6
7
8
9
10
11
12
13
14
15
16
17
'18
19
20
57.72
58.54
60.46
62.08
63.7'l
65.1 7
66.47
67.77
69.09
70.37
71 .51
72.55
73.50
74.37
75.20
75.99
76.75
77.49
78.23
78.96
59.43
61.99
63.78
65.51
67.O4
68.37
69.70
71.07
72.39
73.56
74.62
75.60
76.48
77.31
78.12
78.90
79.66
80.41
81 .16
81.93
64.76
66.21
67.87
69.33
70.60
71.92
73.30
74.64
75.82
76.89
77.86
78.74
79.57
80.38
81.17
81.94
82.71
83.48
84.27
85.08
67.78
69.62
71.10
72.37
73.71
7s.15
76.54
77.75
78.83
79.81
80.69
81.54
82.36
83.15
83.95
84.74
85.53
86.34
87.19
88.07
71.60 74.4472.97 75.5874.15 77.0275.51 78.6176.99 80.14
78.43 81.4079.66 82.5080.75 83.5081.73 84.3882.62 85.2383.46 86.0784.29 86.89
85. 10 87 .71
85.90 88.5586.72 89.3987.53 90.2788.38 91.2089.26 92j6
90 18 93.15
91 .12 94.1 I
2014
2015
2016
2017
2018
201 9
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
57.72
59.43
64.76
67.78
71.60
74.44
76.80
80.26
84.21
87.58
89.36
91.23
93.06
94.49
96.71
99.1 4
101.62
104.58
107.94
111.44
115.94
121.47
127.25
133.21
139.96
144.19
Note: These rates will be further adjusted with the applicable integration charge.
Note: The rates shown in this table have been computed using the U.S. Energy lnformation Administration (ElA)'s Annual Energy
Outlook 2013 released May 2, 2013. See "Annual Energy Outlook 2013, All Tables, Energy Prices by Sector and Source, Mountain,
Reference case" at http://www.eia.gov/oiaf/aeo/tablebrowser/.
PACIFICORP Page 2
Attachment C
Staff Comments
Case No. PAC-E-I3-12
2l28l14 Page2 of 5
PACIF!CORP
AVOIDED COST RATES FOR NON-SEASONAL HYDRO PROJECTS
March XX, 2014
$/MWh
New Contracts and Replacement Contracts without Full Caoacitv Pavments
Eligibility for these rates is limited to projects smaller than 10 aMW.
LEVELIZED NON.LEVELIZED
CONTRAC]
LENGTH
lYFAFI.SI
ON.LINE YEAR
CONTRACT
YEAR
NON.LEVELIZED
RATES2014 2015 2016 2017 2018 2019
1
2
3
4
5
6
7I
o
10
11
12
13
14
15
16
17
18
19
20
55.21
56.02
57.91
59.52
61.13
62.58
63.86
65.15
66.45
67.71
68.84
69.86
70.81
71.66
72.47
73.25
74.OO
74.73
75.45
76.17
56.89
59.43
61 . '19
62.92
64.42
65.74
67.05
68.40
69.71
70.87
71.91
72.87
73.74
74.56
75.35
76.12
76.87
77.61
78.35
79.1 0
62.17
63.61
65.25
66.69
67.95
69.25
70.61
71.94
73.10
74.15
75.'t1
75.97
76.80
77.59
78.36
79.12
79.88
80.64
81.41
82.21
65.1 6
66.98
68.45
69.69
71.02
72.44
73.81
75.00
76.07
77.04
77.90
78.73
79.54
80.32
81 .10
81.8E
82.66
83.46
84.29
85.1 6
68.94 71.74
70.29 72.8671.45 74.2872.79 75.8674.26 77.3775.68 78.6'l76.89 79.70
77.97 80.67
78.94 81.5479.80 82.3780.63 83.1981.45 84.0082.24 84.8183.03 85.63
83.83 86.46
84.63 87.32
85.46 88.24
86.33 89.'t9
87.24 90.'1788.17 9'l '18
2014
2015
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
55.21
56.89
62.'17
65.16
68.94
71.74
74.06
77.48
81.39
84.72
86.46
88.29
90.07
91.46
93.64
96.02
98.45
101.37
104.68
108.14
112.59
'l 18.07
123.79
129.71
136.40
140.58
Note: The rates shown in this table have been computed using the U.S. Energy lnformation Administrataon (ElA)'s Annual Energy
Outlook 2013 released May 2, 2Q13. See 'Annual Energy Outlook 2013, All Tables, Energy Prices by Sector and Source, Mountain,
Reference case" at http:i/www.eia.gov/oiaf/aeo/tablebrowser/. pACIFICORp page 3
Attachment C
Staff Comments
Case No. PAC-E-13-12
2128114 Page 3 of 5
PACIFIGORP
AVOIDED COST RATES FOR SEASONAL HYDRO PROJECTS
March XX, 2014
$/MWh
New Contracts and Replacement Contracts without Full Capacitv Pavments
Eligibility for these rates is limited to projects smaller than 10 aMW.
LEVELIZED NON.LEVELIZED
CONTRACT
LENGTH
/YFARS\
ON-LINE YEAR
CONTRACT
YEAR
NON.LEVELIZED
RATES2014 2015 2016 2017 2018 2019
1
2
3
4
5
7
8
I
'10
11
12
13
14
15
16
17
18
'19
20
72.79
73.72
75.74
77.47
79,1 I
80,75
82,1 5
83.55
84.96
86.32
87.55
88.68
89.72
90.67
91.58
92.44
93.28
94.10
94.91
95.71
74.73
77.39
79.28
81.12
82.75
84.18
85.61
87.07
88.49
89.75
90.91
91.97
92.93
93.8s
94.74
95.59
96.43
97.26
98.09
98.92
80.27
8'1.84
83.60
85.1 7
86,55
87.96
89.44
90.88
92.16
93.31
94.38
95.34
96.27
97.16
98.03
98.88
99.73
1 00.58
101.44
102.32
83.s2
85.47
87.07
88.44
89.89
91.42
92.92
94.22
95.40
96.48
97.45
98.39
99.30
1 00.1 I
101 .05
101 .93
102.80
103.69
104.62
1 05.57
87.58 90.65
89.05 9'1.90
90.34 93.45
91 .81 95.1693.40 96.7994.95 98.1696.28 99.36
97 .47 100.46
98.55 101.44
99.53 102.39100.47 103.32101.39 104.23102.28 105.15103.18 106.07
104.08 107.00
104.97 107.97
105.90 108.97106.86 110.O2107.86 1 1 1.09108.87 112.19
2014
2015
2016
2017
2018
201 I
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
72.79
74.73
80.27
83.52
87.58
90.65
93.25
96.95
1o1.14
t04.75
t06.79
t08.91
t11.00
112.70
I 15.18
I 17.89
t20.63
123.87
127.52
t31.31
136.10
141.92
t48.00
154.27
161.32
t65.87
Note: A "seasonal hydro project" is defined as a generation facility which produces at least 55% of its annual generation during the
months ofJune, July, and August. Order 32802.
Note: The rates shown in this table have been computed using the U.S. Energy lnformation Administration (ElA)'s Annual Energy
Outlook 2013 released May 2,2013. See "Annual Energy Outlook 2013, All Tables, Energy Prices by Sector and Source, Mountain,
Reference case" at http:/ ,vww.eia.govloiallaeollablebrowser/.
'ACIFICOR'
page 4
Attachment C
Staff Comments
Case No. PAC-E-13-12
2/28/14 Page 4 of 5
PACIFICORP
AVOIDED COST RATES FOR OTHER PROJECTS
March XX, 2014
$/MWh
New Contracts and Replacement Contracts without Full Capacity Payments
Eligibility for these rates is limited to projects smalter than 10 aMW.
LEVELIZED NON.LEVELIZED
SONTRACI
LENGTH
(YEARS)
ON-LINE YEAR
CONTMCT
YtrAR
NON.LEVELIZED
RATES2014 2015 2016 2017 2018 2019
1
2
3
4(
6
7
II
10
11
12
13
14
15
16
17
18
19
20
48.40
49.1 6
s1.01
52.57
54.1 3
55.54
56.78
58.02
59.28
60.50
61.59
62.58
63.48
64.30
65.07
65.82
66.53
67.23
67.92
68.60
49.98
52.47
54.1 9
55.86
57.32
58.59
59.87
61.17
62.44
63.55
64.56
65.48
66.31
67.09
67.85
68.s7
69.29
70.00
70.70
71.42
55.1 7
56.55
58.1 5
59.54
60.75
62.00
63.32
64.60
65.73
66.73
67.6s
68.47
69.26
70.01
70.74
71.47
72.19
72.91
73.65
74.42
58.05
59.82
61.24
62.44
63.72
65.08
66.42
67.56
68.58
69.51
70.33
71 .12
71.89
72.63
73.37
74.11
74.86
75.62
76.42
77.26
61.73 64.4263.02 65.4964.14 66.8665.43 68.3966.85 69.8568.23 71.0469.39 72.0870.41 73.0171.34 73.8372.16 74.6272.95 75.4073.72 76.1674.47 76.9375.23 77.7175.99 78.5176.75 79.3377.55 80.2178.38 81.1279.25 82.0780.15 83.04
2014
2015
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
48.40
49.98
55.1 7
58.05
61.73
64.42
66.64
69.95
73.74
76.96
78.59
80.30
81.97
83.24
85.30
87.56
89.86
92.65
95.84
99.16
103.48
108.83
114.42
120.20
126.75
130.78
Note: "Other projects" refers to pro.iects other than wind, solar, non-seasonal hydro, and seasonal hydro projects. These "Other projects"
may include (but are not limited to): cogeneration, biomass, biogas, landfill gas, or geothermal projects.
Note: The rates shown in this table have been computed using the U.S. Energy lnformation Administration (ElA)'s Annual Energy
Outlook 2013 released May 2, 2013. See 'Annual Energy Outlook 20'13, All Tables, Energy Prices by Sector and Source, Mountain,
Reference case" at http://www,eia.gov/oiaf/aeo/tablebrowser/.
'ACIFICOR'
page s
Attachment C
Staff Comments
Case No. PAC-E-13-12
2128114 Page 5 of 5
CERTIFICATE OF SERVICE
I HEREBY CERTIFY THAT I HAVE THIS 28TH DAY OF FEBRUARY 2014,
SERVED THE FOREGOING COMMENTS OF THE COMMISSION STAFF, IN CASE
NO. PAC.E.13.12, BY MAILING A COPY THEREOF, POSTAGE PREPAID, TO THE
FOLLOWING:
TED WESTON
ID REG AFFAIRS MANAGER
ROCKY MOUNTAIN POWER
201 S MAIN ST STE 23OO
SALT LAKE CITY UT 84I I I
DATA REQUEST RESPONSE CENTER
E-MAIL ONLY:
datare o u e s t(d.o acifrc orD. c om
DANIEL E SOLANDER
SENIOR COUNSEL
ROCKY MOUNTAIN POWER
2OI S MAIN ST STE 23OO
SALT LAKE CITY UT 841I I
SECRETARY
CERTIFICATE OF SERVICE