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

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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

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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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118,

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107,

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impl

e C

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8,17

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36

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Ste

am fr

om O

ther

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rces

503

3,54

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7

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E24

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9,84

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94

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91

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93

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0

To

tal F

uel E

xpen

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068,

880,

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5

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0,98

3,29

4

31

0,98

3,29

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3,67

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Net

Pow

er C

ost

1,28

1,81

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1,55

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6,76

6

1,56

2,70

1,67

1

1,49

5,80

7,96

5

1,49

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1,50

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7

314,

339,

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382,

301,

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384,

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Liqu

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es A

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t(4

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(4

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SG

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(106

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216

Set

tlem

ent A

djus

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tal N

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f Adj

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1,23

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Rat

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$ C

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e to

load

var

ianc

e fro

m U

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ecov

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of N

PC

in R

ates

324,

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319,

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In

crea

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clud

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Load

Cha

nge

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Var

ianc

e fro

m S

ettle

men

t Agr

eem

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1,81

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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

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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

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50

.41

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90

.38

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00

.14

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80

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5

Ma

y-1

20

.53

20

.69

60

.42

20

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50

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40

.69

00

.26

70

.45

80

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50

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00

.42

10

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2

Ju

n-1

20

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30

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20

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00

.65

90

.53

70

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40

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90

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60

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10

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20

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50

.68

5

Ju

l-1

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.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

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9-0

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0-1

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9-0

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8-1

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7-0

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1-1

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6-1

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1-0

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9

Se

p-1

2-1

.28

6-0

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8-0

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1-1

.50

8-1

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6-1

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2-0

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4-1

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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

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4-1

.23

2-1

.05

3-1

.08

6-1

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9-1

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6

De

c-1

2-1

.21

9-1

.21

5-1

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0-1

.20

2-1

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3-1

.22

7-1

.45

3-1

.44

4-1

.27

8-1

.30

2-1

.32

3-1

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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

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50

.30

3-0

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90

.24

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20

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6

Ma

y-1

20

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00

.56

1-0

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50

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30

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20

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10

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90

.54

50

.30

70

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10

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70

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6

Ju

n-1

20

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80

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80

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20

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90

.49

50

.68

80

.37

00

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90

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70

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10

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00

.61

3

Ju

l-1

2-0

.64

4-0

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80

.33

0-0

.27

6-0

.59

1-0

.21

8-0

.72

2-0

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9-0

.72

3-0

.35

4-0

.66

6-0

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3

Au

g-1

2-1

.74

0-0

.73

3-0

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2-0

.81

2-1

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6-0

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2-1

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9-0

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1-1

.74

2-0

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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