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Public Utility Commission 201 High St SE Suite 100 Salem, OR 97301 Mailing Address: PO Box 1088 Salem, OR 97308-1088 Consumer Services 1-800-522-2404 Local: 503-378-6600 Administrative Services 503-373-7394 February 12, 2016 Via Electronic Filing OREGON PUBLIC UTILITY COMMISSION ATTENTION: FILING CENTER PO BOX: 1088 SALEM OR 97308-1088 RE: Docket No. UE 301 – In the Matter of IDAHO POWER COMPANY's 2016 Annual Power Cost Update (APCU) Enclosed for electronic filing is Staff Opening Testimony. /s/ Mark Brown Mark Brown Utility Program Filing on Behalf of Public Utility Commission Staff (503) 378-8287 Email: [email protected]
Transcript of OREGON PUBLIC UTILITY COMMISSION ATTENTION: FILING … › efdocs › HTB › ue301htb14172.pdf ·...
Public Utility Commission 201 High St SE Suite 100
Salem, OR 97301 Mailing Address: PO Box 1088
Salem, OR 97308-1088 Consumer Services
1-800-522-2404 Local: 503-378-6600
Administrative Services 503-373-7394
February 12, 2016
Via Electronic Filing OREGON PUBLIC UTILITY COMMISSION ATTENTION: FILING CENTER PO BOX: 1088 SALEM OR 97308-1088 RE: Docket No. UE 301 – In the Matter of IDAHO POWER COMPANY's 2016 Annual Power Cost Update (APCU) Enclosed for electronic filing is Staff Opening Testimony. /s/ Mark Brown Mark Brown Utility Program Filing on Behalf of Public Utility Commission Staff (503) 378-8287 Email: [email protected]
PUBLIC UTILITY COMMISSION
OF OREGON
UE 301
STAFF OPENING TESTIMONY OF
SCOTT GIBBENS
In the Matter of IDAHO POWER COMPANY's
2016 Annual Power Cost Update (APCU)
February 12, 2016
CASE: UE 301 WITNESS: SCOTT GIBBENS
PUBLIC UTILITY COMMISSION OF
OREGON
STAFF EXHIBIT 100
Opening Testimony
February 12, 2016
Docket No. UE 301 Staff/100 Gibbens/1
Q. Please state your name, occupation, and business address. 1
A. My name is Scott Gibbens. I am a Utility Analyst for the Public Utility 2
Commission of Oregon. My business address is 201 High St. SE Ste. 100 3
Salem, Oregon 97301. 4
Q. Please describe your educational background and work experience. 5
A. My Witness Qualification Statement is found in Exhibit Staff/101. 6
Q. What is the purpose of your testimony? 7
A. The purpose of my testimony is to present Staff’s analysis and concerns 8
regarding the 2016 October Update, the first portion of Idaho Power 9
Company’s (IPC or Company) Annual Power Cost Update (APCU). 10
Q. How is your testimony organized? 11
A. My testimony is organized as follows: 12
Filing, Compliance and Model Changes .................................................... 1 13 Issues ......................................................................................................... 4 14
Filing, Compliance and Model Changes 15 Q. Did the filing conform to applicable rules and orders? 16
A. Yes, the filing follows all of the applicable rules and orders. Commission Order 17
No. 08-238 (Order) contains the majority of rules and stipulations regarding the 18
APCU October Update. The Order requires IPC to utilize the AURORA model 19
to determine the estimated net power supply expense and reprice the 20
wholesale electric prices. In addition, the Order stipulates inputs to be updated 21
annually, which will be discussed in the following section. 22
23
Docket No. UE 301 Staff/100 Gibbens/2
Q. Please describe what inputs the Company updated. 1
A. Per the Order, the Company updated the following inputs: 2
a. Fueling prices and transportation costs; 3
b. Planned outages and forced outage rates; 4
c. Heat rates; 5
d. Forecast of Normalized Load and Normalized Sales; 6
e. Contracts for wholesale power and power purchases and sales; 7
f. Forward price curve; 8
g. PURPA contract expenses; and 9
h. The Oregon state allocation factor. 10
IPC did not update wheeling expenses from the previous filing as there was no 11
update submitted by the Company’s transmission planning group due to the 12
fact that wheeling expenses had not changed since the previous filing. 13
Q. Did Staff check the validity and reasonableness of the updated input 14
parameters? 15
A. Yes, Staff reviewed every updated input used in the October Update. In 16
general, the values seem reasonable and in line with both previous filings and 17
last year’s actual parameter values. Staff currently has pending several Data 18
Requests that are intended to clarify a few outliers. Potential issues associated 19
with input parameters are discussed later in my testimony. 20
Q. Did IPC perform the prescribed calculations properly? 21
Docket No. UE 301 Staff/100 Gibbens/3
A. Yes, Staff has found no errors associated with the calculations used in the 1
APCU. Company adhered to all pertinent Commission orders in every 2
calculation. 3
4
Q. How does this projection compare with last year’s actual parameter 5
values? 6
A. Historically, the 2015 calendar year was a poor hydro year. The hydro power 7
generated was approximately 30 percent lower than the mean of the previous 8
87 years. This resulted in higher generation costs among coal, natural gas and 9
purchased power. The total “net power supply expense” NPSE for the calendar 10
year was $388,073,000. The October Update predicts an April-March NPSE of 11
$352,028,000. Staff believes that the ten percent discrepancy between these 12
two numbers is warranted given the nature of the hydro year. 13
Q. Did the Company propose any modeling changes in the APCU? 14
A. Yes, there was one major change to the model. The Company adjusted the 15
manner in which it portrays operations and maintenance (O&M) costs. These 16
costs are associated with oil, handling, administrative and general expenses 17
(OHAG) and do not vary with the amount of power generated by the plant. As 18
such, IPC removed these costs from the AURORA model and added them 19
back as a fixed cost after the model was run. This resulted in a change to the 20
“per unit” costs of coal fired plants, notably Valmy. The results of last year’s 21
and this year’s APCU modeling remain similar. Staff finds that NPSE are 22
Docket No. UE 301 Staff/100 Gibbens/4
projected to rise approximately 3.5 percent. This year’s update estimated a 1
decrease in coal-generated power of approximately 35 percent. 2
3
Q. What impact on NPSE does the model change to O&M have, according 4
to the Company? 5
A. Including O&M expenses outside of the AURORA model will more closely align 6
the projection with the actual decisions made by IPC’s dispatching department. 7
The change will ensure that these costs are recovered regardless of the 8
amount of generation by a plant. 9
Issues 10
Q. What issues does Staff have in regards to the change to modeling O&M 11
costs in AURORA? 12
A. In principal, Staff agrees that fixed costs modeled as variable costs will result in 13
misallocations and inefficiencies. However, Staff still has concerns with the 14
stated reasons and results of the model change. 15
Q. Do you agree that the main driver of the increase in per–unit cost at 16
Valmy is the change in OHAG expense modeling? 17
A. No, Idaho Power/100, Noe/8 at lines 9 through 11 states that the “change in 18
modeling and recovery of OHAG expenses (is) the main driver of the increase 19
in per-unit cost at Valmy.” This is not correct. The increase in per unit costs is 20
due to a decrease in annual energy from 2015 to 2016. However, had OHAG 21
remained as a variable cost in the modeling, annual energy would have 22
Docket No. UE 301 Staff/100 Gibbens/5
decreased even more (See Table 1 below.) Staff is continuing to investigate 1
the appropriate modeling treatment of OHAG. 2
Table 1 3
Valmy Power Cost Energy (MWh) Cost in 1000 2015 Filing1 470,994.4 $ 16,721 2016 OHAG As Variable2 89,377.5 3,450 2016 OHAG As Fixed3 276,332.7 13,037
Q. Does Staff have further questions regarding O&M costs? 4
A. Yes. Staff found that the Boardman plant O&M was over 9,000 times smaller 5
than either of IPC’s other two coal plants. In response to Staff’s stated issues, 6
IPC responded that this was due to IPC having minority ownership in the plant, 7
and thus contributing less to O&M costs. However, Staff does not believe that 8
the relative difference in ownership among plants is sufficient to explain the 9
discrepancy between O&M at the Boardman plant as compared to IPC’s two 10
other plants. Staff continues to investigate this discrepancy. 11
Q. What issue does Staff have with regard to contract costs? 12
A. Staff requested information regarding the projected PURPA contract costs for 13
calendar years 2015 and 2016. Staff has further questions following IPC’s 14
confidential response to its data request. 15
Q. Is Staff investigating any other issues? 16
A. Yes. Staff believes FERC account 501, related to recovery under the power 17
cost adjustment mechanism, includes some component of labor costs. Staff is 18 1 Exhibit Staff/102 2 Exhibit Staff/103 3 Exhibit Idaho Power/101
Docket No. UE 301 Staff/100 Gibbens/6
investigating whether these costs are appropriately included in the power cost 1
calculations. These accounts also include certain fixed costs related to 2
depreciation. Staff is investigating whether these costs are appropriately 3
included in the power cost calculations. 4
Q. Does this conclude your testimony? 5
A. Yes. 6
CASE: UE 301 WITNESS: SCOTT GIBBENS
PUBLIC UTILITY COMMISSION OF
OREGON
STAFF EXHIBIT 101
Witness Qualification Statement
February 12, 2016
Docket No. UE 301 Staff/101 Gibbens /1
WITNESS QUALIFICATION STATEMENT
NAME: Scott Gibbens EMPLOYER: Public Utility Commission Of Oregon TITLE: Utility Analyst
Energy Rates, Finance and Audit ADDRESS: 201 High St. SE Ste. 100
Salem, OR 97301-3612 EDUCATION: Bachelor of Science, Economics, University of Oregon Masters of Science, Economics, University of Oregon EXPERIENCE: I have been employed at the Oregon Public Utility Commission
(Commission) since August of 2015. My current responsibilities include analysis and technical support for electric power cost recovery proceedings with a focus in model evaluation. I also handle analysis and decision making of affiliated interest and property sale filings. Prior to working for the OPUC I was the operations director at Bracket LLC. My responsibilities at Bracket included quarterly financial analysis, product pricing, cost study analysis, new product design, and production streamlining. Previous to working for Bracket, I was a manager for US Bank in San Francisco where my responsibilities included coaching and team leadership, branch sales and campaign oversight, and customer experience management.
CASE: UE 301
WITNESS: SCOTT GIBBENS
PUBLIC UTILITY COMMISSION OF
OREGON
STAFF EXHIBIT 102
Exhibits in Support of Opening Testimony
February 12, 2016
Att
achm
ent
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to S
taff
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R 1
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as P
rices
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ro C
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AV
ER
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y O
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at $
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Apr
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Oct
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Nov
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Janu
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Febr
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4
56
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9
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86
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ger
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nerg
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Wh)
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53
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125,
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32
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079.
6
16
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2
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20
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xpen
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8
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14
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nerg
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Wh)
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skin
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nerg
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Wh)
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ower
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SP
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nerg
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ot S
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$
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$
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$
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$
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$
1,37
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l Exp
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6,
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5,
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3,
822.
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3,
140.
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54
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plus
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8
21
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14
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12
3,70
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0
29
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1
2,
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7
R
even
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clud
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smis
sion
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ts ($
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1,31
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$
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8.7
$
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$
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$
9,22
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$
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09.7
$
55
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Tr
ansm
issi
on C
osts
($ x
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$
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.8$
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$
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.7$
149.
2$
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$
12
3.7
$
11
9.1
$
29
4.5
$
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0.8
$
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R
even
ue E
xclu
ding
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osts
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3$
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1.4
$
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3.0
$
1,
266.
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4,
129.
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1,
389.
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3,
993.
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766.
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8,
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10
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$
Net
Pow
er S
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23,7
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37.3
$
16
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06.5
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3,
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13
9,39
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$
PU
RP
A ($
x 1
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759.
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8,80
7.64
$21,
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3,50
5.36
$21,
062.
57$1
8,73
6.52
$16,
919.
82$1
5,97
5.03
$15,
565.
85$1
2,04
5.69
$14,
314.
33$1
3,55
1.38
208,
893.
4$
Tota
l Net
Pow
er S
uppl
y E
xpen
ses
($ x
100
0)17
,006
.6$
20,9
57.1
$
29
,696
.1$
47,3
20.9
$
44
,852
.4$
33,2
03.5
$
26
,148
.8$
34,2
12.3
$
32
,497
.8$
26,1
52.2
$
19
,180
.0$
17,0
63.4
$
34
8,29
1.2
$
Sal
es a
t Cus
tom
er L
evel
(In
000s
MW
H)
1,02
8.40
61,
049.
929
1,23
0.50
81,
474.
064
1,55
4.05
91,
387.
063
1,11
0.59
31,
032.
641
1,15
3.60
91,
277.
132
1,21
3.38
51,
105.
482
14,6
16.8
71
Hou
rs in
Mon
th72
074
472
074
474
472
074
472
074
474
467
274
487
60 U
nit C
ost /
MW
H (f
or P
CA
M)
$16.
54$1
9.96
$24.
13$3
2.10
$28.
86$2
3.94
$23.
54$3
3.13
$28.
17$2
0.48
$15.
81$1
5.44
$23.
83
Pric
es U
sed
in P
urch
ased
Pow
er &
Sur
plus
Sal
es A
bove
:H
eavy
Loa
dP
ortio
n of
Pur
chas
ed P
ower
con
side
red
HL
P64
.25%
64.2
5%64
.25%
64.2
5%64
.25%
64.2
5%64
.25%
64.2
5%64
.25%
64.2
5%64
.25%
64.2
5%P
urch
ased
Pow
er H
L P
rice
27.2
1
26.2
3
25.5
9
35.2
1
38.4
0
36.3
1
32.9
6
35.5
3
38.5
3
37.8
5
36.4
1
32.8
2
Por
tion
of S
urpl
us S
ales
con
side
red
HL
Sur
p
62.7
0%62
.70%
62.7
0%62
.70%
62.7
0%62
.70%
62.7
0%62
.70%
62.7
0%62
.70%
62.7
0%62
.70%
Sur
plus
Sal
es H
L P
rice
25.2
4
24.3
3
23.7
5
32.6
7
35.6
3
33.6
9
30.5
8
32.9
7
35.7
4
35.1
1
33.7
8
30.4
5
Ligh
t Loa
dP
ortio
n of
Pur
chas
ed P
ower
con
side
red
LL P
35.7
5%35
.75%
35.7
5%35
.75%
35.7
5%35
.75%
35.7
5%35
.75%
35.7
5%35
.75%
35.7
5%35
.75%
Pur
chas
ed P
ower
LL
Pric
e19
.86
15
.82
14
.20
22
.59
27
.59
27
.17
29
.23
31
.16
33
.42
32
.57
31
.16
28
.59
Por
tion
of S
urpl
us S
ales
con
side
red
LL S
urp
37
.30%
37.3
0%37
.30%
37.3
0%37
.30%
37.3
0%37
.30%
37.3
0%37
.30%
37.3
0%37
.30%
37.3
0%S
urpl
us S
ales
LL
Pric
e17
.32
13
.79
12
.38
19
.70
24
.06
23
.69
25
.49
27
.17
29
.15
28
.40
27
.17
24
.93
Rep
riced
Usi
ng U
E 1
95 S
ettle
men
t Met
hodo
logy
- O
ctob
er U
pdat
e
Staff/102 Gibbens/1
CASE: UE 301
WITNESS: SCOTT GIBBENS
PUBLIC UTILITY COMMISSION OF
OREGON
STAFF EXHIBIT 103
Exhibits in Support of Opening Testimony
February 12, 2016
Idaho P
ow
er/
101
Wright/
1
IPC
O P
OW
ER
SU
PP
LY
EX
PE
NS
ES
FO
R A
PR
IL 1
, 2
01
4 -
- M
AR
CH
31
, 2
01
5 (
Mu
ltip
le G
as
Pri
ce
s/8
5 Y
ea
rs o
f H
yd
ro C
on
dit
ion
s)
AV
ER
AG
E
Ap
ril
Ma
yJu
ne
Ju
lyA
ug
ust
Se
pte
mb
er
Octo
be
rN
ove
mb
er
De
ce
mb
er
Ja
nu
ary
Fe
bru
ary
Ma
rch
An
nu
al
Hyd
roe
lectr
ic G
en
era
tio
n (
MW
h)
85
2,2
08
.0
93
5,9
56
.8
89
4,7
84
.8
67
6,5
72
.5
50
7,2
98
.0
54
0,0
92
.4
55
1,4
97
.9
46
8,5
80
.3
67
3,2
13
.8
75
3,5
42
.0
82
5,7
31
.1
84
4,2
13
.0
8,5
23
,69
0.7
Brid
ge
r
E
ne
rgy (
MW
h)
20
8,1
61
.3
28
0,9
64
.7
28
3,3
78
.6
47
3,4
92
.8
48
4,1
76
.6
45
8,3
25
.8
48
2,7
86
.1
46
7,1
09
.2
48
5,0
75
.4
45
4,9
80
.0
38
2,7
81
.3
38
0,6
27
.4
4,8
41
,85
9.1
E
xp
en
se
($
x 1
00
0)
4,9
31
.7$
6,6
08
.2$
6,6
33
.2$
10
,75
3.3
$
10
,97
6.0
$
10
,41
6.8
$
10
,95
0.7
$
10
,59
5.9
$
10
,99
1.8
$
10
,03
5.9
$
8,4
81
.4$
8,4
20
.3$
10
9,7
95
.1$
Bo
ard
ma
n
E
ne
rgy (
MW
h)
1,7
37
.5
2,9
68
.6
11
,15
9.6
31
,56
6.2
34
,82
1.6
29
,85
2.6
34
,45
7.6
30
,90
3.5
35
,11
1.3
20
,09
4.6
13
,22
9.9
17
,83
3.1
26
3,7
36
.0
E
xp
en
se
($
x 1
00
0)
47
.9$
81
.2$
31
1.9
$
81
9.9
$
89
6.4
$
77
7.1
$
88
6.8
$
80
3.3
$
90
4.1
$
58
6.9
$
39
3.5
$
52
6.2
$
7,0
35
.3$
Va
lmy
E
ne
rgy (
MW
h)
5,0
67
.0
7,7
48
.4
4,6
27
.7
57
,13
0.9
68
,92
6.2
39
,94
4.9
61
,58
3.0
59
,77
2.2
90
,61
2.8
34
,30
8.1
17
,88
8.1
23
,38
5.1
47
0,9
94
.4
E
xp
en
se
($
x 1
00
0)
18
3.9
$
28
3.7
$
16
7.7
$
2,0
02
.5$
2,4
09
.0$
1,3
98
.8$
2,1
50
.7$
2,0
97
.1$
3,1
36
.6$
1,3
09
.8$
68
4.2
$
89
6.9
$
16
,72
1.0
$
La
ng
ley G
ulc
h
E
ne
rgy (
MW
h)
13
,37
1.3
31
,44
5.7
15
,77
8.1
12
8,0
09
.0
14
0,5
33
.7
11
6,3
27
.9
12
7,1
26
.8
71
,12
1.9
11
6,3
43
.6
34
,88
3.9
14
,31
2.2
29
,77
6.8
83
9,0
31
.0
E
xp
en
se
($
x 1
00
0)
43
7.0
$
96
3.9
$
49
1.5
$
3,7
57
.9$
4,1
98
.7$
3,4
61
.5$
3,8
55
.6$
2,3
76
.9$
4,1
80
.3$
1,3
08
.4$
54
9.2
$
1,0
97
.1$
26
,67
8.0
$
Da
nskin
E
ne
rgy (
MW
h)
1.8
0.3
29
.1
1,5
45
.7
1,1
15
.6
35
1.8
20
4.2
10
.8
17
.5
22
.6
1.2
3.2
3,3
03
.8
E
xp
en
se
($
x 1
00
0)
0.1
$
0.0
$
1.5
$
74
.0$
53
.1$
17
.9$
10
.1$
0.6
$
1.0
$
1.4
$
0.1
$
0.2
$
15
9.9
$
Be
nn
ett M
ou
nta
in
E
ne
rgy (
MW
h)
-
-
2.8
16
7.2
15
8.9
95
.1
4.7
-
0.5
0.1
-
-
42
9.3
E
xp
en
se
($
x 1
00
0)
-$
-$
0.1
$
7.8
$
8.0
$
5.0
$
0.2
$
-$
0.0
$
0.0
$
-$
-$
21
.3$
F
ixe
d C
ap
acity C
ha
rge
- G
as T
ran
sp
ort
atio
n (
$ x
10
00
)7
37
.7$
76
1.7
$
74
6.7
$
78
0.3
$
78
0.3
$
75
5.7
$
76
1.7
$
73
7.7
$
76
1.7
$
76
1.7
$
68
9.6
$
76
1.7
$
9,0
36
.3$
Pu
rch
ase
d P
ow
er
(Exclu
din
g C
SP
P)
M
ark
et E
ne
rgy (
MW
h)
3,1
41
.3
11
,95
5.1
96
,93
2.1
18
4,0
27
.2
17
3,8
42
.9
23
,53
0.6
45
.5
4,4
32
.5
6,5
64
.5
31
,74
4.4
1,7
74
.0
1,0
47
.2
53
9,0
37
.2
E
lkh
orn
Win
d E
ne
rgy (
MW
h)
20
,50
2.0
18
,30
4.0
22
,11
7.6
31
,55
1.7
24
,40
5.1
19
,54
5.2
19
,38
2.1
32
,29
8.0
26
,19
3.4
33
,93
3.8
24
,18
0.5
38
,23
9.2
31
0,6
52
.6
N
ea
l H
ot S
prin
gs E
ne
rgy (
MW
h)
15
,86
7.9
16
,39
6.9
15
,86
7.9
15
,86
7.9
16
,39
6.9
15
,86
7.9
16
,39
6.9
15
,86
7.9
16
,39
6.9
7,8
25
.8
14
,81
0.1
16
,39
6.9
18
3,9
59
.8
R
aft R
ive
r G
eo
the
rma
l E
ne
rgy (
MW
h)
5,3
60
.0
5,3
16
.0
5,3
23
.0
5,7
26
.0
5,9
98
.0
6,1
11
.0
7,0
04
.0
6,9
39
.0
7,1
99
.0
7,0
56
.0
6,6
62
.0
5,6
74
.0
74
,36
7.9
T
ota
l E
ne
rgy E
xcl. C
SP
P (
MW
h)
44
,87
1.2
51
,97
2.0
14
0,2
40
.6
23
7,1
72
.8
22
0,6
42
.8
65
,05
4.7
42
,82
8.5
59
,53
7.4
56
,35
3.8
80
,55
9.9
47
,42
6.6
61
,35
7.3
1,1
08
,01
7.5
M
ark
et E
xp
en
se
($
x 1
00
0)
10
6.4
$
38
9.6
$
3,0
61
.3$
7,3
97
.8$
6,7
85
.5$
1,0
09
.2$
1.7
$
19
8.3
$
27
1.1
$
1,2
89
.0$
61
.7$
43
.5$
20
,61
5.0
$
E
lkh
orn
Win
d E
xp
en
se
($
x 1
00
0)
83
5.8
$
74
6.2
$
1,2
26
.8$
2,1
00
.1$
1,6
24
.4$
1,0
84
.1$
1,0
75
.1$
2,1
49
.8$
1,7
43
.5$
1,9
38
.7$
1,3
81
.5$
1,6
05
.7$
17
,51
1.7
$
N
ea
l H
ot S
prin
gs E
xp
en
se
($
x 1
00
0)
1,1
95
.5$
1,2
35
.3$
1,6
30
.9$
1,9
57
.1$
2,0
22
.3$
1,6
30
.9$
1,6
85
.3$
1,9
57
.1$
2,0
22
.3$
83
5.7
$
1,5
81
.6$
1,2
83
.5$
19
,03
7.4
$
R
aft R
ive
r G
eo
the
rma
l E
xp
en
se
($
x 1
00
0)
23
9.2
$
23
7.2
$
32
3.2
$
41
7.2
$
43
7.0
$
37
1.1
$
42
5.3
$
50
5.6
$
52
4.5
$
43
7.5
$
41
3.0
$
25
8.6
$
4,5
89
.5$
T
ota
l E
xp
en
se
Excl. C
SP
P (
$ x
10
00
)2
,37
6.9
$
2,6
08
.4$
6,2
42
.2$
11
,87
2.2
$
10
,86
9.3
$
4,0
95
.3$
3,1
87
.3$
4,8
10
.8$
4,5
61
.4$
4,5
00
.9$
3,4
37
.8$
3,1
91
.3$
61
,75
3.7
$
Su
rplu
s S
ale
s
E
ne
rgy (
MW
h)
29
2,9
39
.0
30
0,2
14
.9
12
5,5
44
.1
47
,73
2.4
26
,77
5.1
15
0,6
39
.2
40
4,3
47
.8
20
7,1
50
.9
20
0,4
23
.5
14
5,2
91
.3
34
9,2
47
.7
41
6,1
56
.4
2,6
66
,46
2.4
R
eve
nu
e In
clu
din
g T
ran
sm
issio
n E
xp
en
se
s (
$ x
10
00
)6
,96
9.8
$
6,6
65
.6$
2,3
15
.2$
1,1
87
.3$
76
3.6
$
4,1
68
.9$
13
,53
6.7
$
6,5
00
.3$
7,0
63
.0$
3,9
49
.6$
9,9
39
.2$
12
,06
6.0
$
75
,12
5.2
$
T
ran
sm
issio
n E
xp
en
se
s (
$ x
10
00
)2
92
.9$
30
0.2
$
12
5.5
$
47
.7$
26
.8$
15
0.6
$
40
4.3
$
20
7.2
$
20
0.4
$
14
5.3
$
34
9.2
$
41
6.2
$
2,6
66
.5$
R
eve
nu
e E
xclu
din
g T
ran
sm
issio
n E
xp
en
se
s (
$ x
10
00
)6
,67
6.9
$
6,3
65
.3$
2,1
89
.7$
1,1
39
.6$
73
6.8
$
4,0
18
.3$
13
,13
2.3
$
6,2
93
.2$
6,8
62
.5$
3,8
04
.3$
9,5
90
.0$
11
,64
9.8
$
72
,45
8.7
$
Ne
t P
ow
er
Su
pp
ly E
xp
en
se
s (
$ x
10
00
)2
,03
8.2
$
4,9
41
.6$
12
,40
5.1
$
28
,92
8.3
$
29
,45
3.9
$
16
,90
9.8
$
8,6
70
.9$
15
,12
9.1
$
17
,67
4.4
$
14
,70
0.8
$
4,6
45
.7$
3,2
43
.9$
15
8,7
41
.8$
Re
pri
ce
d U
sin
g U
E 1
95
Se
ttle
me
nt
Me
tho
do
log
y -
Oc
tob
er
Up
da
te
Staff/103 Gibbens/1
