and overnight delivery net power cost indicative update ...enclosed for filing by pacificorp d/b/a...
TRANSCRIPT
PACIFIC POWER A DIVISION OF PACIFICORP
November 8, 2011
VIA ELECTRONIC FILING AND OVERNIGHT DELIVERY
Oregon Public Utility Commission 550 Capitol Street NE, Suite 215 Salem, OR 97310-2551
RE: Docket UE 227 - 2012 Transition Adjustment Mechanism Net Power Cost Indicative Update for 2012
825 NE Multnomah, Suite 2000 Portland, Oregon 97232
Enclosed for filing by PacifiCorp d/b/a Pacific Power is the updated 2012 net power cost forecast for posting indicative transition adjustments. This filing shows the 2012 net power cost forecast at $1,230.5 million, total Company. Based on this indicative forecast, Oregon-allocated net power costs are $305.3 million after reflecting the adjustments agreed upon in the settlement stipulation in this docket. This is an approximate $390,000 increase over the July Rebuttal Update.
In support of this filing, the following exhibits are attached:
• Exhibit A - Summary of the updates since the August Surrebuttal Update filing and impacts on net power costs.
• Exhibit B - Description of the updates. • Exhibit C - Attestation of Stefan A. Bird, pursuant to paragraph 13 in the Stipulation
adopted by Order No. 10-363 (Docket UE 216). • Exhibit D - Update of Attachment A to Stipulation for Oregon allocation. • Exhibit E - Copy of the indicative transition adjustments and Schedule 201 rates posted
on the Company's website November 8, 2011.
Attached are CDs with the net power cost GRID project, report and workpapers supporting this filing, as required by the TAM Guidelines. The confidential material is provided subject to the protective order issued in this proceeding.
If you have any questions, please contract Joelle Steward, Regulatory Manager, at (503) 813-5542.
Very truly yours,
{m Andrea L. Kelly Vice President, Regulation
Enclosure cc: UE 227 Service List
CERTIFICATE OF SERVICE
I hereby certify that on this 8th of November, 2011, I caused to be served, via email and/or overnight delivery, a true and correct copy of the foregoing document on the following named person(s) at his or her last-known addressees) indicated below.
SERVICE LIST
Gordon Feighner (C) (HC) (W) Citizens' Utility Board of Oregon 610 Broadway, Suite 308 Portland, OR 97205
G. Catriona McCracken (C) (HC) (W) Citizens' Utility Board of Oregon 610 Broadway, Suite 308 Portland, OR 97205
Kevin Higgins (C) (W) Energy Strategies LLC 215 State Street, Suite 200 Salt Lake City, UT 84111-2322
Katherine A. McDowell (C) (W) McDowell & Rackner PC 520 SW Sixth Ave, Suite 830 Portland, OR 97204
Oregon Dockets (W) PacifiCorp 825 NE Multnomah, Suite 2000 Portland, OR 97232
Jason W. Jones (C) (HC) (W) Department of Justice Regulated Utility & Business Section 1162 Court St, NE Salem, OR 97301-4096
UE-227 Robert Jenks (C) (HC) (W) Citizens' Utility Board of Oregon 610 Broadway, Suite 308 Portland, OR 97205
Irion A. Sanger (C) (HC) (W) Davison VanCleve PC 333 SW Taylor, Suite 400 Portland, OR 97204
Amie Jamieson (C) (W) McDowell & Rackner PC 520 SW Sixth Ave, Suite 830 Portland, OR 97204
Greg Bass (W) Noble Americas Energy Solutions LLC 401 West A St., Suite 500 San Diego, CA 92101
Maury Galbraith (C) (HC) (W) Oregon Public Utility Commission P.O. Box 2148 Salem, OR 97308-2148
Donald W. Schoenbeck (C) (HC) (W) Regulatory & Cogeneration Services, Inc. 900 Washington Street, Suite 780 Vancouver, W A 98660 (503) 232-6155 Ext:222
Gregory M. Adams (C) (W) Richardson & O'Leary PO Box 7218 Boise, ID 83702
Coordinator, Regulatory Operations
Exhibit A
Oregon TAM 2012 (Surrebuttal Filing) NPC ($) = 1,495,807,965$/MWh = 24.74$
Oregon TAM 2012 (November 2011 Indicative Filing):Impact ($) NPC ($)
Update, one-off1 Updated for Gem State's budget 26,8002 Updated for Small QF Contracts 397,7103 Updated Grant PUD Proforma (2,438,898)4 Updated BPA Wheeling Rate per Final Record of Decision 147,6475 Updated for Douglas PUD Revised Preliminary Proforma 25,8806 Updated for Amended Power County QF Contracts (289,065)7 Updated for Roseburg Dillard QF contract 120,0048 Add New West Valley Tolling Contract 745,0069 Updated for Monsanto Payment per Idaho GRC Settlement 1,509,43910 Add New Kennecott Incentive Contract 1,784,29311 Add New US Magnesium QF Contract (505,532)12 Add New Kennecott Smelter and Refinery QF Contracts (79,177)13 Add New Tesoro QF Contract 98,42214 Updated NuCor Rate for Impact of Utah GRC 459,00015 Updated for October 31, 2011 Official Forward Price Curve 1,048,662
Total Adjustments from Updated = 3,050,190
System balancing impact of all adjustments 2,229,812
Total Adjustments from Surrebuttal Filing = 5,280,003
Oregon TAM 2011 November Indicative NPC 1,501,087,967
Exhibit B
1
Oregon November 2011 Transition Adjustment Mechanism (TAM) Update
Update Explanations (Indicative) Update 1 — Gem State.
This update incorporates the City of Idaho Falls Gem State power purchase agreement’s estimated budget for the period ending September 30, 2012, received on August 3, 2011. The impact of the 2012 budget increases net power costs by approximately $0.03 million on a total Company basis. Supporting documents provided on September 30, 2011: Idaho_Falls_Corr_-_Notice_of_Gem_State_split_&_generation_forecast_for_oper_yr_2011-12.pdf.
Update 2 — New Small Qualified Facilities.
This update incorporates several new and revised QF contracts: 1. Lower Valley Energy QF: This update incorporates the 2nd Amended and
Restated Power Purchase Agreement signed on May 6, 2011 and approved by Idaho Public Utilities Commission on August 10, 2011. Supporting documents provided on September 30, 2011:
• Lower Valley Energy 5-17-11 TT 3854 QF 2nd Amended + Restated PPA.pdf and
• Lower Valley IPUC Approval 8-10-2011 FINAL _ORDER _NO _32323.pdf.
2. J Bar 9 Ranch: new Wyoming QF power purchase agreement signed on August 15, 2011. Supporting documents provided on September 30, 2011: J Bar 9 Ranch PPA EXECUTED August 15 2011.pdf
3. Threemile Canyon Wind QF contract extended through March 31, 2012. Supporting documents provided with this filing: Threemile Canyon PPA Amend 6.pdf.
The impact of the new and revised QF contracts increases net power costs by approximately $0.4 million on a total Company basis.
Update 3 —Updated Grant County Preliminary 2012 Pro-forma.
This update incorporates the preliminary 2012 pro-forma published by the Grant Public Utility district on September 10, 2011, and a final Estimated Unserved District Load (EUDL) projection provided by the Grant Public Utility District on October 11, 2011. The impact of this update decreases net power costs by approximately $2.4 million on a total Company basis. The following supporting document was provided on September 30, 2011:
• Grant PUD Corr - Prelim 2012 Priest Rapids Proforma, 9-9-11.pdf Supporting document provided with this filing:
• Grant PUD - Final EUDL calculation for 2012 from Priest Rapids + Wanapum projects.pdf
Update 4 — Bonneville Power Administration’s Final Record of Decision (ROD).
This update incorporates the Bonneville Power Administration’s Final Record of Decision (ROD) finalized on July 26, 2011. The impact of this update increases net
Exhibit B
2
power costs by approximately $0.1 million on a total Company basis. The supporting workpapers are available online at: http://www.bpa.gov/corporate/ratecase/2012/docs/BP-12-A-02C.pdf and http://www.bpa.gov/corporate/ratecase/2012/docs/BP-12-A-02B.pdf
Update 5 — Douglas PUD Revised Preliminary Pro-forma. This update incorporates the fiscal year September 1, 2011 – August 31, 2012 revised preliminary pro-forma published by the Douglas Public Utility district on August 23, 2011. The impact of this update increases net power costs by approximately $0.03 million on a total Company basis. Supporting documents provided on September 30, 2011: Douglas_PUD_Corr_-_Wells_Fiscal_Year_2011-2012_REVISED_Preliminary_Proforma_Statement_Endur_PA_20625[1].pdf
Update 6 — Updated Power County Wind Park North and Power County Wind
Park South QFs. This update incorporates the First Revised and Restated Power Purchase Agreements signed on June 2, 2011 and approved by the Idaho Public Utility Commission on August 3, 2011. The impact of this update decreases net power costs by approximately $0.3 million on a total Company basis. Supporting documents provided on September 30, 2011:
• Power County Wind Park North 6-16-11 TT3857 QF PPA Amend 1 - Final.pdf
• Power County Wind North FINAL_ORDER_NO_32314.pdf • Power County Wind Park South 6-16-11 TT3856 QF PPA Amend 1 -
Final.pdf • Power County Wind Park South FINAL_ORDER_NO_32314.pdf
Update 7 — Roseburg Forest Products QF (Dillard Facility). This update incorporates a new Roseburg Forest Products QF contract for 2012 signed on July 29, 2011. The impact of this new contract increases net power costs by approximately $0.1 million on a total Company basis. Supporting documents provided on September 30, 2011: Roseburg Forest Products - Dillard Facility QF PPA.pdf.
Update 8 — West Valley Tolling Agreement. This update incorporates a new West Valley Tolling Agreement for 2012 signed on August 12, 2011. The impact of this new contract increases net power costs by approximately $0.7 million on a total Company basis. Supporting documents provided on September 30, 2011: CER Generation II, LLC 8-15-11 TT3575 Physical Tolling Agreement for West Valley Endur PA ID 20909.pdf.
Update 9 — Update Monsanto rate. This update incorporates the payment for Monsanto’s curtailment products for 2012 per the Idaho PAC-E-11-12 GRC Settlement filed on October 17, 2011. The impact of the stipulated curtailment product cost increases net power costs by approximately
Exhibit B
3
$1.5 million on a total Company basis. Supporting documents provided with this filing: ID PAC-E-11-12 Stipulation CONF (10-17-11).pdf.
Update 10 — New Kennecott Generation Incentive.
This update includes the new contract for the Kennecott Generation Incentive contract for 2012. The impact of this new contract increases net power costs by approximately $1.8 million on a total Company basis. Supporting documents provided with this filing: Kennecott 2012 GCA.PDF
Update 11 — New US Magnesium QF Contract.
This update incorporates a new US Magnesium QF contract for 2012. The impact of this new contract decreases net power costs by approximately $0.5 million on a total Company basis. Supporting documents provided with this filing: US Magnesium 10-25-2011.pdf
Update 12 — New Kennecott QF Contracts.
This update incorporates the new Kennecott Smelter and Kennecott Refinery QF contracts for 2012. The impact of these new contracts decreases net power costs by approximately $0.08 million on a total Company basis. Supporting documents provided with this filing: • Kennecott 2012 ESA.pdf and • Kennecott 2012 MOU.pdf
Update 13 — New Tesoro QF Contract.
This update incorporates a new Tesoro QF contract for 2012. The impact of this new contract increases net power costs by approximately $0.1 million on a total Company basis. Supporting documents provided with this filing: • Tesoro QF 10-25-2011.pdf
Update 14 – Update NuCor Rate.
This update incorporates the updated NuCor rate based on the impact of the Utah GRC 10-035-124, which was authorized by the Public Service Commission of Utah on September 13, 2011. The impact increases net power costs by approximately $0.5 million on a total Company basis.
Update 15 — October 31, 2011 Forward Price Curve and October 31, 2011 STF Transactions.
This update incorporates the Company’s forward price curves as of October 31, 2011 and new wholesale short term firm transactions for electricity and natural gas, both physical and financial transactions as of October 31, 2011. The impact of this update increases net power costs by approximately $1.0 million on a total Company basis.
System balancing impact of all adjustments.
This update recalculates net power costs based on the inclusion of updates 1 through 15, along with the final screening of gas-fired units. The impact of this update increases net power costs by approximately $2.2 million on a total Company basis.
Exhibit B
4
The total impact of all adjustments listed above increases net power costs by approximately $5.3 million from the Company’s August surrebuttal on a total Company basis.
Exhibit C
1
2
3
BEFORE THE PUBLIC UTILITY COMMISSION OF OREGON
UE 227
4 In the Matter of:
5 PACIFICORP, dba PACIFIC POWER ATTESTATION OF STEFAN A. BIRD
6 2012 Transition Ad'ustment Mechanism
7 STATE OF OREGON ) ) ss
8 County of Multnomah )
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
I, Stefan A. Bird, being first duly sworn on oath, depose and say:
1. My full name is Stefan A. Bird. I am employed by PacifiCorp. My present
position is Senior Vice President, Commercial and Trading for PacifiCorp Energy. \
2. I am making this attestation in compliance with Paragraph 13 of the Stipulation
adopted by the Public Utility Commission of Oregon in Order No. 10-363 in Docket UE 216 on
September 16,2010.
3. I understand that this attestation will be filed concurrently with the Indicative
Filing of the Company's net power costs (NPC) on November 8, 2011 consistent with
Paragraph 11 of the Stipulation filed in this docket on September 20, 2011.
4. I attest that all NPC contracts executed prior to the contract lockdown date of
October 31 1, 2011 are included in the Indicative Filing, with the following exception:
• The 1.1 MW C-Drop Hydro qualifying facility purchase is not included in the
Indicative Filing because the new contract was not processed by the contract
lockdown date of October 31, 2011.
PAGE 1 - ATTESTATION OF STEFAN A. BIRD
Exhibit C
1 I declare under penalty of perjury under the laws of the state of Oregon that the
2 foregoing is true and correct based on my information and belief as of the date of this
3 attestation. ih
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
Page 2
SIGNED this ~ day of November, 2011, at Portland, Oregon.
---"--~~--
Sigrre;:-=, ==~
SUBSCRIBED AND SWORN to before me this V"1h'--rt
OFFICIAL SEAL DIANNE C. BALCH
NOTARY PUBUC-OREGON COMMISSION NO. 462355
~ COMMISstON EXPIRES DECEMBER 26. 2015
ATTESTATION OF STEFAN A. BIRD
Notary Public, State of Oregon .-My Commission Expires lo.~.:u..-;l()JS
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2,59
6
S
E24
.283
%24
.336
%24
.796
%88
,662
,546
118,
019,
633
107,
853,
384
108,
737,
457
108,
737,
457
103,
175,
602
S
impl
e C
ycle
Com
b. T
urbi
nes
547
8,17
8,17
9
36
,248
,503
36
,351
,436
36
,589
,196
36
,589
,196
35
,923
,794
SS
EC
T22
.403
%24
.329
%24
.788
%1,
832,
173
8,
818,
918
8,
843,
960
9,
069,
661
9,
069,
661
8,
904,
722
Ste
am fr
om O
ther
Sou
rces
503
3,54
0,88
7
3,
893,
567
3,76
0,48
9
3,
760,
489
3,76
0,48
9
3,
760,
489
S
E24
.283
%24
.336
%24
.796
%85
9,84
4
94
7,54
2
91
5,15
5
93
2,44
0
93
2,44
0
93
2,44
0
To
tal F
uel E
xpen
se1,
068,
880,
323
1,
304,
202,
445
1,
262,
327,
747
1,
252,
856,
120
1,
252,
856,
120
1,
223,
355,
185
25
9,69
8,66
6
31
7,71
4,10
0
30
7,52
9,69
5
31
0,98
3,29
4
31
0,98
3,29
4
30
3,67
3,11
2
Net
Pow
er C
ost
1,28
1,81
3,15
2
1,55
7,66
6,76
6
1,56
2,70
1,67
1
1,49
5,80
7,96
5
1,49
5,80
7,96
5
1,50
1,08
7,96
7
314,
339,
428
382,
301,
456
384,
138,
307
374,
494,
353
374,
494,
353
376,
306,
437
Liqu
idat
ed D
amag
es A
djus
tmen
t(4
05,4
89)
(4
05,4
89)
(4
05,4
89)
SG
26.3
14%
(106
,700
)
(1
06,7
00)
(106
,700
)
UE
216
Set
tlem
ent A
djus
tmen
t(4
4,85
5,79
4)
(11,
000,
000)
UE
227
Set
tlem
ent A
djus
tmen
t(3
1,95
4,09
8)
(31,
912,
462)
(8,0
00,0
00)
(8
,000
,000
)
To
tal N
et o
f Adj
ustm
ent s
1,23
6,95
7,35
8
1,55
7,66
6,76
6
1,56
2,70
1,67
1
1,49
5,40
2,47
5
1,46
3,44
8,37
7
1,46
8,77
0,01
6
303,
339,
428
382,
301,
456
384,
138,
307
374,
387,
653
366,
387,
653
368,
199,
736
In
crea
se A
bsen
t Loa
d C
hang
e78
,962
,027
80,7
98,8
79
71
,048
,225
63,0
48,2
25
64
,860
,308
Ore
gon-
allo
cate
d N
PC
Bas
elin
e in
Rat
es fr
om U
E 2
1630
3,33
9,42
8
30
3,33
9,42
8
30
3,33
9,42
8
30
3,33
9,42
8
$ C
hang
e du
e to
load
var
ianc
e fro
m U
E-2
16 fo
reca
st21
,080
,116
15,8
55,9
62
15
,855
,962
15,8
55,9
62
20
12 R
ecov
ery
of N
PC
in R
ates
324,
419,
544
319,
195,
390
319,
195,
390
319,
195,
390
In
crea
se In
clud
ing
Load
Cha
nge
57,8
81,9
11
59
,718
,763
55,1
92,2
63
47
,192
,263
49,0
04,3
46
A
dd O
ther
Rev
enue
Cha
nge
3,74
5,66
13,
745,
661
3,
508,
274
3,
508,
274
3,
508,
274
Tota
l TA
M In
crea
se61
,627
,572
63,4
64,4
24
58
,700
,537
50,7
00,5
37
52
,512
,620
Var
ianc
e fro
m S
ettle
men
t Agr
eem
ent
1,81
2,08
3
Exhibit D
PA
CIF
IC P
OW
ER
ST
AT
E O
F O
RE
GO
N
On
e-Y
ea
r O
pti
on
- T
ran
sit
ion
Ad
justm
en
ts (
ce
nts
/kW
h)
20
12
In
dic
ati
ve
Tra
nsit
ion
Ad
justm
en
ts (
No
ve
mb
er
8,
20
11
)
23
/72
3 S
eco
nd
ary
23
/72
3 P
rim
ary
28
/72
8 S
eco
nd
ary
28
/72
8 P
rim
ary
30
/73
0 S
eco
nd
ary
30
/73
0 P
rim
ary
HL
HL
LH
HL
HL
LH
HL
HL
LH
HL
HL
LH
HL
HL
LH
HL
HL
LH
Ja
n-1
2-0
.54
4-0
.58
2-0
.63
2-0
.70
2-0
.55
4-0
.58
9-0
.77
0-0
.82
4-0
.60
2-0
.66
7-0
.64
8-0
.70
9
Fe
b-1
2-0
.51
2-0
.46
1-0
.61
6-0
.69
1-0
.51
9-0
.47
3-0
.74
6-0
.72
4-0
.56
6-0
.54
8-0
.61
1-0
.60
1
Ma
r-1
2-0
.29
3-0
.21
0-0
.37
2-0
.44
6-0
.30
9-0
.23
4-0
.54
3-0
.46
8-0
.35
6-0
.29
6-0
.40
5-0
.34
7
Ap
r-1
2-0
.24
20
.43
1-0
.33
50
.41
8-0
.24
90
.38
9-0
.46
00
.14
6-0
.29
80
.36
1-0
.33
80
.32
5
Ma
y-1
20
.53
20
.69
60
.42
20
.59
50
.51
40
.69
00
.26
70
.45
80
.46
50
.65
00
.42
10
.61
2
Ju
n-1
20
.57
30
.80
20
.47
00
.65
90
.53
70
.78
40
.29
90
.55
60
.48
10
.73
20
.43
50
.68
5
Ju
l-1
2-0
.57
5-0
.22
7-0
.67
4-0
.29
9-0
.58
8-0
.28
6-0
.81
2-0
.49
9-0
.62
5-0
.30
0-0
.67
8-0
.34
9
Au
g-1
2-1
.65
4-0
.72
9-1
.72
9-0
.79
0-1
.64
9-0
.73
8-1
.84
7-0
.97
1-1
.68
3-0
.76
6-1
.73
1-0
.82
9
Se
p-1
2-1
.28
6-0
.87
9-1
.37
8-0
.87
1-1
.29
0-0
.88
1-1
.50
8-1
.17
6-1
.33
2-0
.89
4-1
.37
7-0
.99
7
Oct-
12
-0.8
19
-0.7
32
-0.9
48
-0.7
15
-0.8
32
-0.7
19
-1.0
70
-0.9
24
-0.8
81
-0.7
65
-0.9
27
-0.8
25
No
v-1
2-0
.98
8-1
.03
3-1
.10
6-1
.27
2-1
.00
7-1
.02
7-1
.24
4-1
.23
2-1
.05
3-1
.08
6-1
.09
9-1
.14
6
De
c-1
2-1
.21
9-1
.21
5-1
.33
0-1
.20
2-1
.23
3-1
.22
7-1
.45
3-1
.44
4-1
.27
8-1
.30
2-1
.32
3-1
.34
9
41
/74
1 S
eco
nd
ary
41
/74
1 P
rim
ary
47
,48
Se
co
nd
ary
47
,48
Pri
ma
ry4
7,4
8 T
ran
sm
issio
n7
47
,74
8 S
eco
nd
ary
HL
HL
LH
HL
HL
LH
HL
HL
LH
HL
HL
LH
HL
HL
LH
HL
HL
LH
Ja
n-1
2-0
.60
0-0
.75
4-0
.70
8-0
.73
7-0
.71
8-0
.73
6-0
.67
5-0
.82
9
Fe
b-1
2-0
.57
0-0
.64
1-0
.66
9-0
.60
2-0
.68
8-0
.61
4-0
.64
5-0
.71
6
Ma
r-1
2-0
.33
0-0
.42
9-0
.45
9-0
.38
0-0
.48
7-0
.36
5-0
.40
5-0
.50
4
Ap
r-1
2-0
.37
60
.20
5-0
.48
80
.12
6-0
.29
70
.32
1-0
.40
50
.30
3-0
.41
90
.24
7-0
.37
20
.24
6
Ma
y-1
20
.39
00
.56
1-0
.45
50
.48
30
.47
20
.63
10
.35
90
.54
50
.30
70
.48
10
.39
70
.55
6
Ju
n-1
20
.40
80
.63
80
.31
20
.55
90
.49
50
.68
80
.37
00
.61
90
.30
70
.56
10
.42
00
.61
3
Ju
l-1
2-0
.64
4-0
.19
80
.33
0-0
.27
6-0
.59
1-0
.21
8-0
.72
2-0
.29
9-0
.72
3-0
.35
4-0
.66
6-0
.29
3
Au
g-1
2-1
.74
0-0
.73
3-0
.72
2-0
.81
2-1
.67
6-0
.70
2-1
.78
9-0
.83
1-1
.74
2-0
.83
7-1
.75
1-0
.77
7
Se
p-1
2-1
.38
3-0
.81
2-1
.81
8-0
.89
1-1
.32
4-0
.81
7-1
.43
3-0
.94
9-1
.40
7-0
.91
8-1
.39
9-0
.89
2
Oct-
12
-0.9
67
-0.8
95
-1.4
61
-0.9
73
-0.8
94
-0.7
86
-0.9
90
-0.8
42
-0.9
97
-0.8
48
-0.9
69
-0.8
61
No
v-1
2-1
.02
5-1
.16
0-1
.15
6-1
.15
1-1
.15
8-1
.13
4-1
.10
0-1
.23
5
De
c-1
2-1
.26
8-1
.38
7-1
.38
1-1
.42
7-1
.37
6-1
.36
4-1
.34
3-1
.46
2
74
7,7
48
Pri
ma
ry7
47
,74
8 T
ran
sm
issio
n5
1/7
51
52
/75
25
3/7
53
54
/75
4
HL
HL
LH
HL
HL
LH
HL
HL
LH
HL
HL
LH
HL
HL
LH
HL
HL
LH
Ja
n-1
2-0
.78
3-0
.81
2-0
.79
3-0
.81
10
.11
80
.11
1-0
.69
8-0
.70
6-2
.22
1-2
.22
9-1
.40
9-1
.40
9
Fe
b-1
2-0
.74
4-0
.67
7-0
.76
3-0
.68
90
.15
10
.23
6-0
.66
5-0
.58
1-2
.18
8-2
.10
4-1
.28
4-1
.28
4
Ma
r-1
2-0
.53
4-0
.45
5-0
.56
2-0
.44
00
.35
90
.48
3-0
.45
8-0
.33
4-1
.98
1-1
.85
7-1
.03
7-1
.03
7
Ap
r-1
2-0
.48
00
.22
8-0
.49
40
.17
20
.41
91
.15
6-0
.39
70
.33
9-1
.92
0-1
.18
4-0
.36
4-0
.36
4
Ma
y-1
20
.28
40
.47
00
.23
20
.40
61
.18
01
.35
70
.36
30
.54
0-1
.16
0-0
.98
3-0
.16
3-0
.16
3
Ju
n-1
20
.29
50
.54
40
.23
20
.48
61
.18
51
.44
00
.36
80
.62
4-1
.15
5-0
.89
9-0
.07
9-0
.07
9
Ju
l-1
2-0
.79
7-0
.37
4-0
.79
8-0
.42
90
.11
00
.49
4-0
.70
6-0
.32
2-2
.22
9-1
.84
5-1
.02
5-1
.02
5
Au
g-1
2-1
.86
4-0
.90
6-1
.81
7-0
.91
2-0
.94
8-0
.01
6-1
.76
5-0
.83
3-3
.28
8-2
.35
6-1
.53
5-1
.53
5
Se
p-1
2-1
.50
8-1
.02
4-1
.48
2-0
.99
3-0
.59
4-0
.11
0-1
.41
1-0
.92
7-2
.93
4-2
.45
0-1
.63
0-1
.63
0
Oct-
12
-1.0
65
-0.9
17
-1.0
72
-0.9
23
-0.1
68
-0.0
15
-0.9
85
-0.8
31
-2.5
08
-2.3
54
-1.5
34
-1.5
34
No
v-1
2-1
.23
1-1
.22
6-1
.23
3-1
.20
9-0
.33
6-0
.31
3-1
.15
2-1
.13
0-2
.67
5-2
.65
3-1
.83
3-1
.83
3
De
c-1
2-1
.45
6-1
.50
2-1
.45
1-1
.43
9-0
.56
3-0
.53
6-1
.37
9-1
.35
2-2
.90
2-2
.87
5-2
.05
5-2
.05
5
Exhibit E
PA
CIF
IC P
OW
ER
ST
AT
E O
F O
RE
GO
N
Th
ree
-Ye
ar
Op
tio
n -
Tra
nsitio
n A
dju
stm
en
ts (
ce
nts
/kW
h)
Fo
r C
usto
me
rs E
lectin
g O
ptio
n D
uri
ng
th
e N
ove
mb
er
20
11
Win
do
w
20
12
In
dic
ative
Tra
nsitio
n A
dju
stm
en
ts (
No
ve
mb
er
8,
20
11
)
30
/73
0 S
eco
nd
ary
30
/73
0 P
rim
ary
HL
HL
LH
HL
HL
LH
20
12
-0.4
37
-0.5
41
-0.4
80
-0.6
13
20
13
-1.1
42
-1.0
91
-1.1
74
-1.1
62
20
14
-1.8
06
-1.6
45
-1.8
23
-1.7
17
47
/74
7,
48
/74
8 S
eco
nd
ary
47
/74
7,
48
/74
8 P
rim
ary
47
/74
7,
48
/74
8 T
ran
sm
issio
n
HL
HL
LH
HL
HL
LH
HL
HL
LH
20
12
-0.4
23
-0.3
82
-0.5
38
-0.6
24
-0.5
72
-0.6
16
20
13
-1.1
85
-0.9
27
-1.2
40
-1.1
53
-1.2
43
-1.1
24
20
14
-1.9
56
-1.5
49
-1.9
06
-1.7
01
-1.2
43
-1.6
54
Exhibit E
PACIFIC POWERSTATE OF OREGONSchedule 201 Rates to be Effective January 1, 2012 through UE 227 TAM
INDICATIVE
DeliveryService Rate Block/ Schedule 201 Rates
Schedule Lamp Type Secondary Primary Transmission4 1st Block (1,000 kWh) 2.561 per kWh
2nd Block (>1,000 kWh) 3.497 per kWh
23 1st 3,000 kWh 2.983 2.890 per kWhAll Addl kWh 2.214 2.144 per kWh
28 1st 20,000 kWh 2.827 2.620 per kWhAll Addl kWh 2.750 2.549 per kWh
30 1st 20,000 kWh 3.109 3.074 per kWhAll Addl kWh 2.696 2.658 per kWh
41 Wint 1st 100kWh/kW 3.913 3.789 per kWhWint All Addl kWh 2.666 2.582 per kWhSummer kWh 2.666 2.582 per kWh
47/48 On-Peak kWh 2.777 2.674 2.549 per kWhOff-Peak kWh 2.727 2.624 2.499 per kWh
15 2.675MV 7,000L $2.03 per lampMV 21,000L $4.60 per lampMV 55,000L $11.02 per lampHPS 5,800L $0.83 per lampHPS 22,000L $2.27 per lampHPS 50,000L $4.71 per lamp
50 2.199MV 7,000L $1.67 per lampMV 21,000L $3.78 per lampMV 55,000L $9.06 per lamp
51 3.470HPS 5,800L/70W $1.08 per lampHPS 9,500L/100W $1.53 per lampHPS 16,000L/150W $2.22 per lampHPS 22,000L/200W $2.95 per lampHPS 27,500L/250W $3.99 per lampHPS 50,000L/400W $6.11 per lampMH 9,000L/100W $1.35 per lampMH 12,000L/175W $2.36 per lampMH 19,500L/250W $3.26 per lampMH 32,000L/400W $5.17 per lamp
52 Dusk to Dawn 2.658 per kWhDusk to Midn. 2.658 per kWh
53 1.135HPS 5,800L/70W $0.35 per lampHPS 9,500L/100W $0.50 per lampHPS 16,000L/150W $0.73 per lampHPS 22,000L/200W $0.96 per lampHPS 27,500L/250W $1.31 per lampHPS 50,000L/400W $2.00 per lampMH 9,000L/100W $0.44 per lampMH 12,000L/175W $0.77 per lampMH 19,500L/250W $1.07 per lampMH 32,000L/400W $1.69 per lampMH 107,800L/1,000W $4.02 per lamp
Non-Listed 1.135 per kWh
54 All kWh 1.955 per kWh
Exhibit E