20120827PAC to Staff 7-10.pdf

ROCKY MOUNTAIN
" POWER
DMSION OF MCIflCOfiP
August 27, 2012
RECEIVE t
2012UG27 PM t: 19
IDAHO FJ
UTILITIES COMMISS
201 South Main, Suite 2300
Salt Lake City, Utah 84111
VIA EMAIL
AND OVERNIGHT DELIVERY
Kristine A. Sasser
Deputy Attorney General
Idaho Public Utilities Commission
472 W. Washington
Boise, ID 83702-5918
Kris. Sasserpuc.idaho.gov
RE: ID PAC-E-12-08
IPUC Data Request (7-10)
Please find enclosed Rocky Mountain Power's responses to 1PUC Data Requests 7-10. Also
provided electronically are Attachments IPUC 7-(1-2).
If you have any questions, please feel free to call me at [phone].
Sincerely,
J. Ted Weston
Manager, Regulation
Enclosure
C.c.: Jean Jewell/IPUC Jean.jewe11puc.idaho.gov
Terri Carlock/IPUC [e-mail] (W)
PAC-E-12-08IRocky Mountain Power
August 27, 2012
IPUC Production Data Request 7
IPUC Production Data Request 7
Following up on Production Request No. 4, please provide a list of the major
projects that make up the additions in 2008 and 2009 totaling $19,674,540 and
$19,856,301 respectively. Please also include the economic analysis for each
project.
Response to IPUC Production Data Request 7
Please refer to Attachment IPUC Production 7-1 for a summary of the 2008 and
2009 additions by project. Attachment IPUC Production 7-2 includes the
economic analyses for all projects that exceed $1 million. The items labeled
"ARO Assets" represent the offset to the Asset Retirement Obligation (ARO)
liability recorded under accounting requirements. The economic analyses related
to ARO projects are prepared prior to initiating the actual removal project.
Recordholder: Gary Tawwater / Karl Mortensen
Sponsor: To Be Determined
PAC-E.-12-08/Rocky Mountain Power
August 27, 2012
IPUC Production Data Request 8
IPUC Data Request 8
On page 4 of the Application, it states that retiring the Carbon plant may pose
complications with the transmission system. Please provide details and copies of
all studies to identify those potential complications.
Response to IPUC Data Request 8
The Company is currently reviewing the draft transmission system impact study
associated with the Carbon plant. Once the study is finalized the Company will
provide it under a supplemental response, which is expected within the month.
Recordholder: Chad Teply
Sponsor: To Be Determined
PAC-E-12-08/PacifiCorp dba Rocky Mountain Power
August 27, 2012
IPUC Production Data Request No.9
IPUC Production Data Request No.9
Please provide a discussion and all analyses related to potential extensions to meet
air standards and the Carbon retirement due to reliability and/or transmission
constraints.
Response to IPUC Production Data Request No.9
Please refer to the Company's response to IPUC Data Request 8 as it pertains to
the status of the transmission system reliability reviews. Please refer to the
Company's response to IPUC 10 as it pertains to potential extensions. With
respect to the Company's ongoing analyses of air emissions compliance
alternatives for the Carbon plant, such analyses are being completed under
attorney-client privilege.
Recordholder: Irene Heng
Sponsor: To Be Determined
PAC-E-12-08/PacifiCorp dba Rocky Mountain Power
August 27, 2012
IPUC Production Data Request No. 10
IPUC Production Data Request No. 10
Please identify any and all extension request processes and the timeline for
extension requests.
Response to IPUC Production Data Request No. 10
The Company's perspective on extension processes and timelines associated with
the EPA's Mercury and Air Toxics Standards (MATS) is provided below. The
Company's perspective should not be considered a replacement or official
supplement to MATS-related information and guidance codified in the Federal
Register.
Without an approved extension, an electric generation unit (EGU) must be in
compliance with MATS on April 16,2015. MATS rules provide for two possible
extensions of up to 12-months each. The following discussion summarizes the
processes and timelines for submitting extension requests.
The first extension may be granted by the Title V permitting agency. The agency
is required to evaluate and approve each request on a case by case basis. The
permitting agency can grant an extension of 1 to 12 months based on the
owner/operator (owner) of the EGU demonstrating to the satisfaction of the
permitting agency that additional time is needed to either: 1) complete the
installation of the emissions control equipment necessary to meet the MATS; 2)
complete new offsite generation to maintain system reliability before retiring a
generation unit; or 3) accommodate transmission system reliability work that may
be necessary prior to decommissioning a generation unit.
An analysis which provides the reasons for the extension request must be included
in the request. The request must be submitted to the Title V permitting agency no
less than 120 days prior to the MATS compliance date (April 16, 2015). The
conditions of the extension will be included in a revised Title V permit. The EPA
strongly encourages sources to notify the planning authority, state regulatory
agencies and regional reliability entities as soon as possible of plans to
decommission units in order to allow such authorities to develop solutions for
possible reliability issues.
An additional extension may be granted if it is demonstrated that a generation unit
must operate in noncompliance with the MATS to resolve specific and
documented reliability concerns. This second extension requires an Approval
Order (AO) issued by the EPA and can be granted for a period of an additional 1
to 12 months.
PAC-E-12-08/PacifiCorp dba Rocky Mountain Power
August 27, 2012
IPUC Production Data Request No. 10
For units that may require this second extension, the first step is for an owner to
submit a "notice of compliance plan" to the appropriate transmission planning
authority within one year of the MATS effective date (April 16, 2013). This
notice must identify the units that the owner plans to deactivate and the
anticipated deactivation dates. It must also identify the units the owner intends to
retrofit or install pollution controls on and the anticipated completion dates. The
transmission planning authority will use this information to verify and perhaps
remedy any identified reliability issues.
In addition, the owner must file an application with the EPA's Office of
Enforcement and Compliance Assurance no less than 180 days prior to the MATS
compliance date (October 18, 2015). An owner must submit the request to the
EPA's Director of the Air Enforcement Division, the EPA Regional
Administrator, and several other interested agencies and planning authorities
located within the area where the generator is located. A copy of the request is to
also be sent to the Federal Energy Regulatory Commission (FERC).
The submittal must include a written request for an enforceable compliance
schedule and the owner must show in a written analysis, the reliability risks if the
generator unit was not to be in operation. A written concurrence with the analysis
or an equivalent analysis by the transmission planning authority must also be
included.
Recordholder: Chad Teply
Sponsor: To Be Determined
ID PAC-E-12-08 Attachment IPUC Production 7 -1
IPUC Production 7
ID Case PAC-E-12-08 Question #4
Carbon Balances 1954- 2011
FERC Accounts 310 - 317
TRANSFERS ADJUSTMENTS ENDING BAL NET BOOK VAL CY BAL FWD ADDITIONS RETIREMENTS ACCUM DEPR
1954j - 10,650,788 - - - 10,650,788
1955 10,650,788 1,197,795 - - - 11,848,584 See note regarding accumulated
1956
1957
11,848,584
11,856,684L
- 9,656
13,322,981
- (1 ,556)L
(498)1
- - -
- -
11,856,684
25,179,167
depreciation prior to 1982.
1958T 25,179,167 371,211 (10,259
-
- - 25,540,119
19591 25,540 ,119 8,316 j7 - - 25,530,647
1960 25,530,647 1 16,387 - - - 25,547,034
1961 25,547,034iii 6,453 (8,840 - - - 25,544,648 - --
1962 25544648 72,674 - - - 25,617,321 -
1963 25,617,321 36,355 (6,364) - - - 25647 312 - - -
1964 25,647,312 -
(99,458)t (2,522) - - - 25,545,333
1965 25,545,333 24,479 (3,213) - - 25,566,598 - -
1966 25,566,598 38,305 (6,451) (488) - 25,597,965
1967 25,597,965 24,959 (11,851) - - 25,611,073
1968 25,611,073 35,778 (14,862) (2,493) - 25,629,495
1969 25,629,495 12,742 (19,735) - - - - 25,622,502 - --
1970 25,622,502 196,135 (7939) - - - (1) 25,810,697
1 - (31,241) - 29,885 - 25,809,818 1971L 25,810,697 477
8,872 - 25,865,449 1972 25,809,818 53,774 (7,016)
1973 25,865,449 66,541 (25,327) - ________- -
-
25,90663
-
1974 25,906,663 5,053,211 820,180) (820,180)1-- (17,861) - 30,121,834
1975 30,121,834 523,696 (44,603) - - 30,600,927
197& 30,600,927 4,635,018 (53,682) - - 35,182,263
1977 35,182,263 886,254 (152,472) - - - 35,916,045
1978 35,916,045 71,957 (40,074) - - 35,947,927
1979 35,947,927 244,574 (48,905) - - 36,143,596
1980 36,143,596 5,097,426 - (59,174) - - 41,181,848
1981 41,181,848 1,335,242 k (815,035) 1,284 - 41,703,338
1982 - 41 ,703,338 - 397,062 (35,127) - - -- (28,264) 42037 009 (17 ,686,000) - 24,351 ,009
1983 42,037,009 492,218 (29,243) - - - 42,499,983 (19,517,000) - 22,982,983
1984, 42,499,983 1,091,203 (186,118) - - 43,405,068 (20,885,000) 22,520068
1985 43,405,068 2,647,137 (274,259) - - 45,777,945 (22,000,369) 23,777,577
1986 45,777,9451 102,486 (4,290) - - 45,876,141 (23,718,490) 22,157,651
1987 - 45,876,141 - - L 1,979,511 (101,830) - 812,175 48,565,998 (23,842,176) 24,72822
1988 48,565,998 828,911 (123,539) (13,171) - 49,258,200 (24,915,770) 24,342,429
Attach IPUC Production 7 -1 .xlsx (1954-2011 Summary) page 1 of 2
ID PAC-E-12-08 Attachment IPUC Production 7 -1
IPUC Production 7
ID Case PAC-E-12-08 Question #4
Carbon Balances 1954 -2011
CY BAL FWD ADDITIONS RETIREMENTS
FERCAccounts 310 - 317
TRANSFERS ADJUSTMENTS ENDING BAL ACCUM DEPR NET Book VAL
1989 k 49,258,200 2,077,728 (186888) - - 51 ,149,039 (26019955)L 2519085
1990j 51,149,039 1,239,415 (333,275) 12,278 - 52,067,458 (27,232,662) 24,834,796
1991 52,067,458 2,365,511 (8,136) - - 54,424,833 (28,420,168) 26,004,665
1992 54,424,833 3,839,338 (658,193) - 3,533 - 57,609,511 (2983,493) - 27,926,018
1993 57,609,511 1 ,841 ,174 (336984) - - 59,113,701 (32379748) 26,733,953
1994 59,113,701 2,921,600 (369,688) 122,366 - 61,787,978 (35,055,029) 26,732,950
1995 61,787,978 1125 996J (155,682) - (830,898) - 61 ,927,394 (37 ,882,276) 24,045,118
- 1996 61,927,394 1,515,24J (263,888) - - 63,178,749 (4814,460) 22,364,289
199711
1998
1999
2000
2001
2002
2003
2004
63,178,749
64,326,173
65,577,938
71,878,044
76,144,262
77,083,496t
78,684,163
78,988,063
1,388,624
1 ,292,095
7,880,324
5,684,319
1,493,762
2,058,226
1,195,747
7,792,724
(241,824)
(42 850)4
(1,580,218)
(1 418 102)
(554,527)
(457,559)
(891,847)
(923,324)
- 624
2,520
-
- -
-
-
-
-
-
-
- -
-
-
-
-
-
64,326,173
65,577 ,938
71,878,044
76,144 ,262
77,083,496
78,684,163
78,988,063
85,857,463
(45,025,597)
(49212947)
(50,973,958)
(49,106,673)
(50,98275)
(52,988,170)
(55,173,406)
(56,949,368)
19 ,300,576
16,364,991
20,904,086
- 27037 589
26,100,921
25,695,993
23,814,656
28,908,094
2005
2006
2007
85,857,463
90,525,317
- 91,721,153
6,781,846
2,387,919
2,407,520
(1,229,350)
(1494776)
(678,020)
(884,642)
(10615)
7,407
-
313,308
-
90,525,317
91 ,721 ,153
93,458,060
(5937,696)
(61,583,455)
(65,195,120)
31,487,621
30 137698
28,262,939
2008 93,458,060 19,674,540 (3,447,238) (28,652) - 109,656,711 (61,812,797) 47,843,913
2009 109656711 19856301 (3830896) - 68,644 125,750,760 (60,251 ,371) 65,499,389
2010J 125,750,760 1,105,307 (1,182,176) 72,021 - 38,574 125,784,487 (63,077,834) 62,706,653
2011 125,784,487 1,397,697 (262,174) - - 126,920,010 (66,954,203) 59,965,806
Note tAccumuIated depreciation and net book value are not available by p lant level for years prior to 1982. Accumulated depreciation was kept on a total steam
functional group level during those years, and was not allocated to the individual power plant.
Attach IPUC Production 7 -1 .xlsx (1954-2011 Summary) page 2 of 2
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PACIFICORP ENERGY
A DIVISION OF PACIFICOAP
INPUT GLOBAL VARIABLES
Plant: I Carbon
Maximum Analysis Time Period (In Years): 14 II
Unit Number: 2
Project Title: CARBON 2: ECONOMIZER REPLACEMENT
In-Service Date (CY Project Is Operational): 2008
Dollar Year (CV In Which Ss Are Specified): 2007
Inflation Rate (I=Yearly, 2Average):
Discount Rate: 7.1%
Analysts Period In Years (Including Dollar Year): 14
INPUT DOLLAR VARIABLES
Capital Capital Avoid. O&M
Ilxcluding Depreciable Savings or
Calendar AFUDC AFUDC Life (30 (Increases)
Year ($000) ($000) year max) ($000)
2007 $944 $41 14 $0
2008 $1,663 $51 13 $80
2009 $O 50 12 $100
2010 $0 $0 11 $130
2011 $0 $0 10 $170
2012 ($600) SO 9 $220
2013 $0 $0 8 $280
2014 $0 $0 7 $360
2015 $O $0 6 $440
2016 ($600) $0 5 $540
2017 $0 $0 4 $0
2018 $0 $0 3 $0
2019 $O $0 2 $0
2020 $0 $0 I $0
2021 $O $0 $0
2022 ** $0 $0 - $0
2023 * $0 SO $0
2024 *5 $0 $0 - $0
2025 ** $0 $0 - SO
2026 ** $0 $0 - SO
2027 ** $ $0 - $O
2028 ** $0 $0 - $O
2029 Ca $0 $0 - $O
2030 $0 $0 - $0
2031 CC $9 $0 - $0
2032 $0 $O - $0
2033 Ca $0 $0 - $O
2034 5* $ $0 - $0
2035 $0 $0 SO
2036 $0 $o - $o
2037 *
2038 •* 9
2039
2040 CC
Attach IPUC Production 7 -2.pdf page 1 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PACIFICORP ENERGY
A DIVISION OF PAGIFICORP
II INPUT MISC. VARIABLES
Forced Risk of Station Heat Rate Capability
Outage Forced Use Increase (Restore/Improve) Restore/Improv,
Calendar Benefit Outage (decrease) or Loss or (Loss)
Year (Equiv. days) (Decimal) (kw) (btu/kwh) Megawatts
2007 0.0 0% - - -
2008 4.0 50% - - -
2009 6.0 50% - - -
2010 10.0 50% - - -
2011 16.0 50% - - -
2012 24.0 50% - - -
2013 34.0 50% - - -
2014 46.0 50% - - -
2015 60.0 50% - - -
2016 72.0 50% - - -
2017 0.0 0% - - -
2018 0.0 0% - - -
2019 0.0 0% - - -
2020 0.0 0% - - -
2021 ** 0.0 0% - - -
2022 ** 0.0 0% - - -
2023 ** 0.0 0% - - -
2024 ** 0,0 0% - - -
2025 ** 0.0 0% - - -
2026 ** 0.0 0% - - -
2027 ** 0.0 0% - - -
2028 ** 0.0 0% - - -
2029 ** 0.0 0% - - -
2030 ** 0.0 0% - - -
2031 ** 0.0 0% - - -
2032 ** 0.0 0% - - -
2033 ** 0,0 0% - - -
2034 ** 0.0 0% - - -
2035 ** 0.0 0% - - -
2036 ** 0.0 0% - - -
2037 **
2038 **
2039 **
2040 **
2041 **
10
Attach IPUC Production 7 -2.pdf page 2 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PACIFICORP ENERGY
A OVISION OF PACIFICORP
SUMMARY OF RESULTS
($000)
AFTER-TAX CASH FLOW WITHOUT RETAIL REVENUE CHANGE
After-Tax Cash Flow NPV @ 7.10% > (2007 dollars)
Net Benefit to Capital Ratio = = = = = = 2.5
Simple Payback Period = = = = = 5.2 Years
Calculated Internal Rate of Return 22.2%
Incremental Earnings
Calendar Year ($1,000's)
2007 $20
2008 $23
2009 $21
2010 $109
2011 $222
Input for Internal Rate of Return Guess
Internal Rate of Return Guess = = = => 15%
After-tax Cash Flow NPV at IRR Guess> $782
Revenue Requirement NPV Benefit (Cost) @ 7.10%—> $3,949 (2007 dollars
Discounted Rev Req Breakeven -======-- = => 4.7 Years
(when cumulative PV of revenue requirement net benefit exceeds zero)
IF
Attach IPUC Production 7 -2.pdf page 3 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
Project Name:U2 Superheat Replace
(In Thousands of Dollars)
Project Economics:
Customer Cash Flows Cash Flows
Revenue Prior to Regulatory After Regulatory
Requirement Adjustment Adjustment *
PVRR Benefit or (Cost) Total Project $1,091
PVRR Benefit or (Cost) PPW Share $1,091
Project NPV $767 $90
Project H4R 159% 8.6%
Discount Rate Used 7.3% 7.3%
Capital Productivity Ratio 1.6 1.1
Payback Period (years) 7.0 Years 8.3 Years
2007 2008 2009 Q!Q 2011
Capital Spending w/o AFUDC $713 $1,012 $0 $0 $0 ($200)
Capital Spending w AFUDC $730 $1,054 $O $0 $0 ($200)
Net Cash Flow Without Regulatory Recovery
Annual ($706) ($852) $231 $263 $277 $458
Cumulative ($706) ($1,559) ($1,328) ($I,065) ($788) ($330)
Net Cash Flow With Regulatory Recovery
Annual ($619) ($811) $243 $230 $218 $382
Cumulative ($619) ($1,430) ($1,187) ($957) ($739) ($357)
Incremental Earnings Before Interest & Taxes
Without Regulatory Recovery ($57) $70 $165 $222 $250 $251
With Regulatory Recovery $84 $137 $184 $169 $154 $129
Incremental Earnings
Without Regulatory Recovery ($25) $56 $71 $109 $129 $132
With Regulatory Recovery $62 $98 $83 $76 $70 $56
Annual Revenue Requirement
Calculated $141 $67 $19 ($53) ($96) ($122)
Recovered $141 $67 $19 ($53) ($96) ($122)
* Includes regulatory lag of zero months.
APR10000685_Econ_T.xls Page 1 8/9/2012 11:36 AM
Attach IPUC Production 7 -2.pdf page 4 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PacifiCorp - Thermal Economic Analysis Model Page 1 of 2
Carbon U2: U2 Superheat Replace Offical Curve: 1212912006
Inputs; Dollar Year - 2007
In-Service Date - 2007
Average Inflation Rate - 1.9%
Discount Rate - 7.3%
Analysis Period - 14 years
Have economic model automatically add AFUDC - 0 (1 -yes)
Calendar
Year
Capital
Excluding
AFUDC
(In Thds)
AFUDC
(In Thds)
Book
Depreciable
Life
(Years)
Avoided
O&M
Savings or
(Increases)
(In Thds)
Forced
Outage
Benefit
(Equiv. Days)
Risk of
Forced
Outage
(Percent)
Incr.
Station Use
Increase or
(decrease)
(KrIV)
Heat
Rate
(Restore)
or Loss
(BtulKwh)
Capability
Restore
or(Loss)
lM( ___________
2007 $713 $1 7 14
2008 $1,012 $42 13 $20 4.0 50%
2009 12 $30 6.0 50%
2010 1 ii $40 1 8.0 50%
2011 10_ $50 10.0 50%
2012 ($200) _9 $60 12.0 50%
2013 8 $75 15.0 50%
2014 _7 $91 18.0 50%
2015 6 $106 21.0 50%
2016 ($200) 5 $121 24.0 50%
2017 4
2018
2019 2
2020
Project Assumptions:
Average HTSH tube leak outage duration = 2 days;
Average HTSH tube leak cost of repairs = $10,000
Average start up fuel use = 4,500 gal; fuel cost = $2.2519al
Number-of avoided outages In 2008=2 and increases by 1 outage per year for four years, then 3
outages per year. The risk of forced outages is assumed 50%.
Model assumes avoiding major rebuild capital cost of $200,000 to the HISH each overhaul In 2008,
2012 and 2018. The loaded capital aslue in 2008 has been reduced by 8200k.
Fixed Assumptions:
Capacity Factor 79.30%
Heat Rate 11,040 Btu/KWh
Incremental Fuel $21.89 siren
BTUIIb 11,400
MDC 105 MW
Plant Property Tax 0.73%
Total Capital Cost (Spent & Saved) $ 1,385 (in Thdnt
$/mmEtu $ 0.86902
Calendar
Year
Medium IPC
In Use
(8/lAWN)
2007 N/A
2008 $82.34
2009 $81.57
2010 $59.25
2011 $55.88
Mod Low thg
Net After-Tax Cash Flow NPV (In Thds) $767 $212 $1,321
Internal Rate of Return (IRR) 15.9% 9.9% 21.2%
Simple Payback Period of Original Investment 7.0 Years 8.2 Years 6.1 Years
Net Benefit to Capital Ratio 1.6 1.2 2.0
Present Value Revenue Requirement PVRR (In Thds) $1,091 $197 $1,985
APR10000685_EcOfl_T.xln Page 1 012 Pages 81912012 11:36 AM
Attach IPUC Production 7 -2.pdf page 5 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PacifiCorp - Thermal Economic Analysis Model Page 2 of 2
Carbon 1.12; U2 Superheat Replace Official Curve: 12129/2006
Calculated Revenue Requirement Detail in Thds) Medium Level
Calendar
Year
Capital -
Revenue
Requirement
O&M Coat
Reduction
(increase)
Neat Rate
(Coat) or
Benefit
Station Use &
Cap. Restore
or (Impact)
Outage
(Cost)
Benefit
Total
(Cost)
Benefit
Cumulative
PV Revenue
Req. Benefit
2007 $14 ($141) ($136)
2008 $21 $194 ($67) ($198)
2009 - $31 $278 ($19) ($212]
2010 $43 $322 $53 ($171)
2011 $54 $338 $96 ($101)
2012 $66 $302 $122 ($19)
2013 $85 $420 $283 $161
2014 $104 $564 $455 $429
2015 $123 $726 $652 $787
2016 $143 $923 $932 $1,265
2017 ($114) $1,210
2018 ____________ ($196) $1,163
2019 ($98) $1,123
2020 ($82) $1,091
Totals ($2,770) $670 1 $0 10 1 $4065 1 $1965
2007 NPV ($1,908) $419 1 $0 1 $0 $2561] $1091
Net After-Tax Cash Flows Without Reaulatorv , Recovery (In Thds) Official Curve: 12/2912006
Calendar
Year
Net Operating
(Coat) or
Benefit Property Tax
Income Tax
Payments
Capital
Investment
After-Tax
Cash Flow
PV After-Tax
Cash Flow
Cumulative
PV After-Tax
Cash Flow
2007 $19 ($713) ($706) ($682) ($682)
2008 $215 ($12) ($1,012) ($852) ($767) ($1,450)
2009 $309 ($11) $231 $194 ($1,256)
2010 $365 ($10) $263 $205 ($1,050)
2011 $392 ($106) $277 $202 ($848)
2012 $368 ($104) $200 $458 $311 ($537)
2013 $505 ($161) $336 $214 ($323)
2014 $665 ($224) $435 $257 ($67)
2015 $850 ($296) $549 $302 $235
2016 $1,067 (8 $200 $883 $452 $688
2017 $20 $19 $9 $697
2018 821 $20 $9 $705
2049 $21 $21 $9 1 $714
2020 $136 $136 $53 $767
Totals $4735 1672) ($1,267) ($1326) 12,071 1 $767
2007 NPV $2,999 ($54)1 (8817)1 ($1362) 1 $767
APR10000685_Econ_T.xls Page 2 of 2 Pages 8/912012 11:36 AM
Attach IPUC Production 7 -2.pdf page 6 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
Project Name:U2 Bottom Ash Conveyor Rebuild/Replace
(In Thousands of Dollars)
Project Economics:
Customer Cash Flows Cash Flows
Revenue Prior to Regulatory After Regulatory
Requirement Adjustment Adjustment *
PVRR Benefit or (Cost) Total Project $11,022
PVRR Benefit or (Cost) PPW Share $11,022
Project NPV $6,873 $33
Project IRR >100% 7.8%
Discount Rate Used 73% 73%
Capital Productivity Ratio 6.8 1.0
Payback Period (years) 1.1 Years 9.1 Years
2007 2008 2009 2010 2011 2012
Capital Spending w/o AFUDC $931 $366 $0 $0 $0 $0
Capital Spending w AFUDC $949 $395 $0 $0 $0 $0
Net Cash Flow Without Regulatory Recovery
Annual ($935) $8,381 $30 $28 $26 $24
Cumulative ($935) $7,446 $7,477 $7,505 $7,531 $7,555
Net Cash Flow With Regulatory Recovery
Annual ($931) ($191) $186 $176 $166 $157
Cumulative ($931) ($1,122) ($936) ($761) ($594) ($437)
Incremental Earnings Before Interest & Taxes
Without Regulatory Recovery ($7) $13,970 ($107) ($106) ($105) ($104)
With Regulatory Recovery $0 $154 $144 $132 $121 $110
Incremental Earnings
Without Regulatory Recovery $7 $8,668 ($90) ($88) ($86) ($84)
With Regulatory Recovery $11 $95 $65 $60 $55 $50
Annual Revenue Requirement
Calculated $7 ($13,816) $250 $238 $226 $215
Recovered $7 ($13,816) $250 $238 $226 $215
* Includes regulatory lag of zero months.
APR 0000591_Econ_T.xls Page 1 819/2012 11:40 AM
Attach IPUC Production 7 -2.pdf page 7 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PacifiCorp - Thermal Economic Analysis Model Page 1 of 2
Carbon U2: U2 Bottom Ash Conveyor Rebuild/Replace Offical Curve: 1212912006
Dollar Year - 2007
In-Service Date - 2008
Average Inflation Rate - 1.9%
Discount Rate - 7.3%
Analysis Period - 14 years
Have economic model automatically add AFUDC - 0 11 =yes)
Capital
A, ded 'M as
- - -
-
-
-
--
-
--
Project Assumptions:
Should a catastrophic failure occur Lead Time for material procurement Is 40 weeks, additionally, 10-days
would be required for installation of the new system. Potential down time: 290 days
Fixed Assumptions:
Capacity Factor 79.30%
Rest Rate 11,040 BIu/KIM1
tncremenlsl Fuel $21.69 9/Ton
BTIJ/Ib 11,400
MDC 105 MW
Plant Property Tax 0.73%
Total Capital Cost (Spent & Saved) $ 1,344 (In Thdn)
$fmmBtu $ 0.86902
Calendar
Year
Medium PC
In Use
($/MWH)
2007 N/A
2008 $62.34
2009 N/A
2010 NIA
2011 N/A
Mod Low High
Net After-Tax Cash Flow NPV (In Thds) $6,873 $4,854 $8891
Internal Rate of Return (IRR) >100% >100% >100%
Simple Payback Period of Original Investment 1.1 Years 1.2 Years 1.1 Years
Net Benefit to Capital Ratio 6.8 5.1 8.5
Present Value Revenue Requirement PVRR (In Thds) $11022 $7,769 $14275
APR10000G9I_Econj.xls Page 1 of 2 Pages 8/9/2012 11:40 AM
Attach IPUC Production 7 -2pdf page 8 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PacifiCorp - Thermal Economic Analysis Model Page 2 of 2
Carbon U2: U2 Bottom Ash Conveyor Rebuild/Replace Official Curve: 12129/2008
Calculated Revenue Reaulrement Detail (In Thds ) Medium Level
Calendar
Year -
Capital -
Revenue
Requirement
O&M Coat
Reduction
(Increase)
Heat Rate
(Coat) or
Benefit
Station Use &
Cap. Restore
or (Impact)
Outage
(Cost)
Benefit
Total
(Coot)
Benefit
Cumulative
PV Revenue
Req. Benefit
2007 ($7) ($7)
2008 $14,077 $13,818 $12,431
2009 $250 $12,221
2010 ___________ $12,035
2011 - $11,870
2012 $11,724
2013 $11,598
2014 $11,482
2015 $11,382
2016 - ($171) $11294
2017 ($16 $11,215
2018 ($15 $11,151
2019 ($13 $11,093
2020 ($18 $11,022
Totals ($2,580) $0 I $0 $0 $14,077 $11,487
2007 NPV ($1,651) $0 $0 $0 $12,673 $11022
Net After-Tax Cash Flows Without Reaulatorv Recovery (In Thds) Official Curve: 1212912006
Calendar
Year
Net Operating
(Cost) or
Benefit Property Tan
Income Tax
Payments
Capital
Investment
After-Tax
Cash Flow
PV After-Tax
Cash Flow
Cumulative
PV After-Tax
Cash Flow
2007 ($931) ($935) ($903) (9
2008 $14077 ($5 ($366) $8,381 $7,546 $6,642
2009 $30 $25 $8,668
2010 $28 $22 $6,690
2011 $28 $19 $8,709
2012 $24 $16 $8,725
2013 $23 $14 $8,739
2014 $21 $12 $6,752
2015 $20 $11 $6,763
2016 $20 $10 $6,773
2017 $20 $10 $6,783
2016 $21 $9 $8,752
2019 ________ $21 $9 $8,801
2020 $187 $186 $72 $6,873
Totals $14,077 156 9) ($4,824) ($1,297' $7887 $6,873
2007 NPV $12,673 1 ($4,521)I ($1,229)1
APRI0000691_Econ_T.xla Page 2 of 2 Pages 819/2012 11:40 AM
Attach IPUC Production 7 -2pdf page 9 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
Project Name:U2 LP Turbine Blades (L-O, L-1, L-2
(In Thousands of Dollars)
Project Economics:
Customer Cash Flows Cash Flows
Revenue Prior to Regulatory After Regulatory
Requirement Adjustment Adjustment *
PVRR Benefit or (Cost) Total Project $1,867
PVRR Benefit or (Cost) PPW Share $1,867
Project NPV $1,303 $145.
Project IRK 16.4% 8.9%
Discount Rate Used 7.3% 73%
Capital Productivity Ratio 1.7 1.1
Payback Period (years) 7.0 Years 8.5 Years
2007 2008 2009 2010 2011
Capital Spending w/o AFUDC $1,431 $646 $0 $0 $0 $0
Capital Spending w AFUDC $1,476 $687 $0 $0 $0 $0
Net Cash Flow Without Regulatory Recovery
Annual ($1,458) ($439) $278 $332 $373 $458
Cumulative ($1,458) ($1,897) ($1,618) ($1,287) ($914) ($456)
Net Cash Flow With Regulatory Recovery
Annual ($1,240) ($378) $288 $273 $258 $244
Cumulative ($1,240) ($1,617) ($1,329) ($1,057) ($799) ($555)
Incremental Earnings Before Interest & Taxes
Without Regulatory Recovery ($182) $98 $203 $296 $368 $511
With Regulatory Recovery $169 $196 $219 $201 $183 $166
Incremental Earnings
Without Regulatory Recovery ($85) $59 $89 $150 $197 $289
With Regulatory Recovery $134 $120 $99 $91 $83 $75
Annual Revenue Requirement
Calculated $352 $98 $15 ($95) ($185) ($345)
Recovered $352 $98 $15 ($95) ($185) ($345)
* Includes regulatory lag of zero months.
APR 0000662_Econ_T.xls Page 1 8/9/2012 11:34 AM
Attach IPUC Production 7 -2.pdf page 10 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PacifiCorp - Thermal Economic Analysis Model Page 1 of 2
Carbon LI2: U2 Lp Turbine Blades (L-0, L-1, L-2) Otlical Curve: 1212912006
I!tA Dollar Year- 2007
In-Service Date - 2007
Average Inflation Rate - 1.9%
Discount Rate - 7.3%
Analysis Period - 14 years
Have economic model automatically add AFUDC - 0 (11 =yes)
Risk .1
-
-
- --
-
- --
Project Assumptions:
AN AVERAGE 1.014 PERCENT ANNUAL LOSS IN TURBINE CYCLE HEAT RATE SINCE 1999 WILL
CONTINUE FOR THE REMAINING UNIT OPERATING LIFE. FUEL COST REMAINS CONSTANT. THE
ESTIMATED LOSS IN FUEL COST IS BASED ON A CAPACITY FACTOR OF 85 9/6 AND A FUEL COST OF
60.849 PER MILLION BTU (CY2004 FUEL COST). A 1% DECREASE IN TURBINE CYCLE HEAT RATE IS
ESTIMATED AT $86,479/YR IN FUEL SAVINGS. DESIGN TURBINE CYCLE EFFICIENCY 8418 BllJfK'iNH.
BOILER EFFICIENCY 67.5% GROSS UNIT HEAT RATE IS 10005 B1TJ/KWH. DEVIATION FROM DESIGN 424
BTU/KWH. FOR THE PURPOSE OF THIS MODEL WILL USE THE PUBLISHED NUMBER OF 372 BILl/KWH.
Fixed Assumptions:
Capacity Factor 79.301A
Heat Rate 11,040 9/u1KWh
Incremental Fuel $ 21.89 5/Ton
ETU/lb 11,400
MDC 105 MW
Plant Property Tax 0.73%
Total Capital Cost (Spent & Saved) $ 2,163 (In Thds)
$/mmBtu $ 0.86902
Calendar
Year
Medium IPC
In Use
2007 N/A
2008 N/A
2009 N/A
2010 N/A
2011 N/A
Mt Low that
Net After-Tax Cash Flow NPV (In Thds) $1,303 $1,303 $1,303
Internal Rate of Return (IRR) 16.4% 16.4% 16.4%
Simple Payback Period of Original Investment 7.0 Years 7.0 Years 7.0 Years
Net Benefit to Capital Ratio 1.7 11 1.7
Present Value Revenue Requirement PVRR (In Thds) $1,867 $1,887 $1,667
APR10000682_Econ_T.xls Page 1 012 Pages 819/2012 11:34 AM
Attach IPUC Production 7 -2.pdf page 11 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PacifiCorp - Thermal Economic Analysis Model Page 2 of 2
Carbon U2: U2 Lp Turbine Blades (L-0, L-1, L-2) Official Curve: 1212912006
Calculated Revenue Reauiremont Detail (In Thdsi Medium Level
Calendar
Year
Capital
Revenue
Requirement
O&M Cost
Reduction
(Increase)
Heat Rate
(Cost) or
Benefit
Station Use &
Cap. Restore
or (Impact)
Outage
(Cost)
Benefit
Total
(Cost)
Benefit
Cumulative
PV Revenue
Req. Benefit
2007 ($87) ($352) ($340)
2008 ($68) $338 ($98) ($428)
2009 $374 ($15) ($441)
2010 $466 $95 ($3671
2011 $537 $185 ($232)
2012 $679 $345 $2
2013 $893 $377 $241
2014 - $710 $412 $484
2015 $701 $420 $715
2016 $716 $452 $946
2017 $731 $484 $1,177
2018 $747 $517 $1,407
2019 $762 $550 $11635
2020 $780 $599 $1,867
Totals ($4,130) (5)35) $8,235 $0 $0 1 $3,970
2007 NPV ($2,751) 1 ($126)1 $4,744 $0 $0 $1,867
Net After-Tax Cash Flows Without Reaulatorv Recovery (In Thds) Official Curve: 12129/2006
Calendar
Year
Net Operating
(Coat) or
Benefit Property Tax
Income Tax
Payments
Capital
Investment
After-Tax
Cash Flow
PV After-Tax
Cash Flow
Cumulative
PV After-Tax
Cash Flow
2007 ($87) ($10) 650 ($1431) ($1,458) ($1,408) ($1,408)
2008 $270 ($14) ($646) ($439) ($395) ($1,803)
2009 $374 (5 $278 $234 (54,570)
2010 $466 ($ $332 $259 ($1,310)
2011 $537 (4 $373 $272 ($1,039)
2012 1 679 ($211), $458 $311 ($727)
2013 $693 $464 $294 ($434)
2014 $710 $473 $279 L$155)
2015 $701 $467 $256 $102
2016 $718 $476 $244 $346
2017 $731 $487 $232 $578
2018 $747 $497 $221 $800
2019 $763 $508 $211 $1,010
2020 $780 $758 $293 $1303
Totals $8,099 ($100) i ($2,248) 152,0771 $3,675 1 $1,303
2007 NPV $4,618 1 ($74)1 ($1277)1 ($1.963)1 $1,303
APR1 0000662_Econ_T.xta Page 2 of 2 Pages 8/912012 11:34 AM
Attach IPUC Production 7 -2.pdf page 12 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
Project Name:U2 GENERATOR ROTOR REPLACEMENT
(In Thousands of Dollars)
Project Economics:
Customer Cash Flows Cash Flows
Revenue Prior to Regulatory After Regulatory
Requirement Adjustment Adjustment *
PVRR Benefit or (Cost) Total Project $9,954
PyRE Benefit or (Coat) PPW Share $9,954
Project NPV $6,280 $103
Project IRE >100% 9.2%
Discount Rate Used 7.3% 7.3%
Capital Productivity Ratio 6.2 1.1
Payback Period (years) 0.0 Years 8.0 Years
2009 il 2012 2013
Capital Spending w/o AFUDC $1,293 $0 $O $0 $0 $0
Capital Spending w AFUDC $1,344 $0 $0 $0 $0 $0
Net Cash Flow Without Regulatory Recovery
Annual $6,244 $30 $28 $26 $24 $23
Cumulative $6,244 $6,274 $6,303 $6,329 $6,353 $6,376
Net Cash Flow With Regulatory Recovery
Annual ($1,115) $188 $178 $169 $159 $151
Cumulative ($1,115) ($927) ($749) ($580) ($421) ($270)
Incremental Earnings Before Interest & Taxes
Without Regulatory Recovery $12,013 ($111) ($ill) ($110) ($109) ($109)
With Regulatory Recovery $154 $143 $131 $120 $108 $98
Incremental Earnings
Without Regulatory Recovery $7,486 ($93) ($91) ($88) ($86) ($84)
With Regulatory Recovery $127 $65 $59 $54 $49 $44
Annual Revenue Requirement
Calculated ($11,860) $254 $242 $230 $218 $206
Recovered ($11,860) $254 $242 $230 $218 $206
* Includes regulatory lag of zero months.
APR90000048_EconT.xls Page 1 8/9/2012 11:30 AM
Attach IPUC Production 7 -2.pdf page 13 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PacifiCorp - Thermal Economic Analysis Model Page 1 of 2
Carbon U2: U2 Generator Rotor Replacement Qffidd Curve: 912812007
Dollar Year- 2008
In-Service Date - 2008
Average Inflation Rate - 1.9%
Discount Rate - 7.3%
Analysis Period - 13 years
Have economic model automatically add AFUDC - 0 (lWlea)
-
-
-
-
--
Project Assumptions:
A 75% CHANCE OF ONE FORCED OUTAGE IN A 15 YEAR PERIOD FOR A DURATION OF 6 MONTHS.
Fixed Assumptions:
Capacity Factor 79.30%
Fleet Rate 11,040 Btu/KWt
Incremental Fuel $21.89 5/Ton
BTU/lb 11,400
MDC 105 MW
Plant Property Tax 0.71%
Total Capital Cost (Spent & Saved) $ 1,344 (In Thds)
$fmmBtu $ 0.86385
Calendar
Year
Medium IPC
In Use
($/MWH)
2008 $5796
2009 N/A
2010 N/A
2011 N/A
2012 N/A
Mt Low High
Net After-Tax Cash Flow NPV (In Thds) $6,280 $4405 $8,154
Internal Rate of Return (IRR) >100% >100% >100%
Simple Payback Period of Original Investment 0.0 Years 0.0 Years 0.0 Years
Net Benefit to Capital Ratio 6.2 4.7 7.8
Present Value Revenue Requirement PVRR (In Thds) $9,954 $6,934 $12,975
APR90000048,Econ_T.xls Page 1 of 2 Pages 8/9/2012 11:30 AM
Attach IPUC Production 7 -2.pdf page 14 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
II PacifiCorp - Thermal Economic Analysis Model Page 2 of 2
Calculated Revenue Requirement Detail (In Thds) Medium Level
Calendar
Year
Capital
Revenue
Requirement
O&M Cost
Reduction
(Increase)
Heat Rate
(Cost) or
Benefit
Station Use &
Cap. Restore
or (Impact)
Outage
(Cost)
Benefit
Total
(Cost)
Benefit
Cumulative
PV Revenue
Req. Benefit
2008 ($266) ($100) $12226 $11,860 $11.4
2009 ($254 911,2
2010 811,0
2011 $10.84
2012 1 $10,687
2013 $10,547
2014 - $10.4
2015 $10.3
2016 $10.2
2017 - $10.1
2018 ($151 $10.09
2019 ($140 $1000
2020 ($119 ($11 $9.9
Totals ($2,536) ($100) $0 1 $01 $12,226 $9,590
2008 NPV ($1,7$9) ($971 so] so] $11,810 $9954
Net After-Tax Cash Flows Without Reaulatorv Recovery (In Thdsl Official Curve: 9128/2007
Calendar
Year
Net Operating
(Cost) or
Benefit Property Tax
Income Tax
Payments
Capital
Investment
After-Tax
Cash Flow
PV After-Tax
Cash Flow
Cumulative
PV After-Tax
Cash Flow
2008 $12,126 ($4, ($1,293) $6,244 $6,032 $6,032
2009 $30 $27 $6,059
2010 $28 $24 $6,093
2011 $28 $20 $6,103
2012 $24 $18 $6,121
2013 $23 $16 $6,136
921 $13 $6,150
2015 $20 $12 $6,162
2016 $20 $11 $6,173
2020
2014
2017 $21 $11 $6,183
201$ V $21 $10 $6,193
2019 $22 $21 $10 $6,203
$186 $186 $77 $6,280
Totals $12,126 1 ($57) ($4089) ($1,293( $6,686 $6,280
2008 NPV $11,713 ($4411 (94,141)1 ($1,249)I $6,280
APR90000048_Econj.xls Page 2 of 2 Pages 8/9/2012 11:30 AM
Attach IPUC Production 7 -2.pdf page 15 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
Project Name:U2 WATERWALL REBUILD CV 2008
(In Thousands of Dollars)
Project Economics:
Customer Cash Flows Cash Flows
Revenue Prior to Regulatory After Regulatory
Requirement Adjustment Adjustment *
PVRR Benefit or (Cost) Total Project $1,390
PVRR Benefit or (Cost) PPW Share $1,390
Project NPV $925 $62
Project IRk 45.7% 8.6%
Discount Rate Used 7.3% 7.3%
Capital Productivity Ratio 2.0 1.1
Payback Period (years) 3.5 Years 9.1 Years
2007 2008 2009 2010 2011 2012
Capital Spending w/o AFUDC $222 $873 $0 $0 $0 $0
Capital Spending w AFUDC $226 $904 $0 $0 $0 $0
Net Cash Flow Without Regulatory Recovery
Annual ($223) ($591) $543 $586 $588 $301
Cumulative ($223) ($814) ($271) $315 $903 $1,204
Net Cash Flow With Regulatory Recovery
Annual ($222) ($724) $158 $150 $142 $134
Cumulative ($222) ($946) ($788) ($638) ($497) ($363)
Incremental Earnings Before Interest & Taxes
Without Regulatory Recovery ($2) $344 $741 $814 $821 $362
With Regulatory Recovery ($0) $130 $120 $111 $101 $92
Incremental Earnings
Without Regulatory Recovery $2 $228 $439 $486 $492 $209
With Regulatory Recovery $3 $95 $54 $50 $46 $41
Annual Revenue Requirement
Calculated $2 ($214) ($620) ($703) ($720) ($270)
Recovered $2 ($214) ($620) ($703) ($720) ($270)
* Includes regulatory lag of zero months.
APR10000679_Econj.xs Page 1 81912012 11:35 AM
Attach IPUC Production 7 -2.pdf page 16 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PacifiCorp - Thermal Economic Analysis Model Page I of 2
Carbon 1J2: U2 Waterwall Rebuild Cy 2008 Offical Curve: 12129/2006
j$j Dollar Year- 2007
In-Service Date - 2008
Average Inflation Rate - 1.9%
Discount Rate - 7.3%
Analysis Period - 14 years
Have economic model automatically add AFUDC - 0 (1=yes)
Capability
Restore
or (Loss)
-
-
-
-
-
--
Project Assumptions:
The number of tube leaks Increase each year until 2012 when the next major overhaul occurs.
Each tube teak will result in a 2-3 day forced outage (3 days if leak is on the upper arch, 2 days for other leaks)
The probablity, of tube leaks occurring is high.
Fixed Assumptions:
Capacity Factor 79.301/.
Heat Rate 11,040 Btu1KIM1
Incremental Fuel $21.89 S/Ton
STU/Ib 11400
MDC 105 MW
Plant Property Tux 0.73%
Total Capital Cost (Spent & Saved) $ 1,131 (In Thds)
$/mmBtu $ 0.86902
Calendar
Year
Medium PC
in Use
($/MWH)
2007 N/A
2008 $6234
2009 $61.57
2010 $59.25
2011 $55.68
Mod Low thn
Net After-Tax Cash Flow NPV (In Thds) $925 $402 $1,448
Internal Rate of Return (IRR) 45.7% 23.4% 67.6%
Simple Payback Period of Original Investment 3.5 Years 4.2 Years 3.1 Years
Net Benefit to Capital Ratio 2.0 1.4 2.5
Present Value Revenue Requirement PVRR (In Thdu) $1,390 $547 $2,233
APR10000679,Econ_T.xls Page 1 of 2 Pages 819/2012 11:35 AM
Attach IPUC Production 7 -2.pdf page 17 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
E_~PacifiCorp - Thermal Economic Analysis Model Page 2 of 2
Carbon 1)2: 1)2 Waterwali Rebuild Cy 2008 Official Curve: 1212912006
Calculated Revenue Requirement Detail (In Thds) Medium Level
Calendar
Year
Capital
Revenue
Requirement
O&M Cost
Reduction
(increase)
Heat Rate
(Cost) or
Benefit
Station Use &
Cap. Restore
or (impact)
Outage
(Cost)
Benefit
Total
(Cost)
Benefit
Cumulative
PV Revenue
Req. Benefit
2007 1$ ($2) ($2)
2008 ($22 $437 $214 $191
2009 $21 $833 $620 $711
2010 $908 $703 $1,261
2011 $013 $720 $1,786
2012 $453 $270 $1,969
2013 ($173) $1860
2014 ($163) $1,784
2015 ($154) $1,679
2016 ($145) $1,604
2017 ($136) $1,540
2018 ($127) $1,483
2019 ($117) $1,435
2020 ($115) $1,390
Totals

($2,147)l $0 $0 1 $0 1 $3,542 1 $1,395
J11,38311 $0 2007 NPV

1 10 1 $0 I ,396
Net After-Tax Cash Flows Without Regulatory Recovery (In Thds) Official Curve: 12/29/2006
Calendar
Year
Net Operating
(Cost) or
Benefit Property Ten
income Tax
Payments
Capital
Investment
After-Tax
Cash Flow
PV After-Tax
Cash Flow
Cumulative
PV After-Tax
Cash Flow
2007 $1 ($222) ($223) ($215) ($215)
2008 $437 ($147) ($873) ($591) ($532) ($745)
2009 $833 ($284) $543 $455 ($292)
2010 $908 ($314) $586 $458 $160
2011 $913 ($319) $588 $429 $595
2012 $453 ($146) $301 $205 $800
2013 $24 $19 $12 $812
2014 $22 $18 $11 $822
2015 $20 $17 $9 $831
2016 $20 $17 $9 $840
2017 $19 $17 $8 $848
2018 $19 $18 $8 $856
2019 $19 $18 $7 $884
2020 $158 $158 $81 $625
Totals $3542 ($52' ($909' ($1,095' $1,485 $925
2007 NPV $2,773 ($37)I ($81 1)1 ($1,000)1 $925J
APR10000679_Econj.xls Page 2 of 2 Pages 8/9/2012 11:35 AM
Attach IPUC Production 7 -2.pdf page 18 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
Project Name:U2 TURBINE GENERATOR OVERHAUL
(In Thousands of Dollars)
Project Economies:
Customer Cash Flows Cash Flows
Revenue Prior to Regulatory After Regulatory
Requirement Adjustment Adjustment *
PVRR Benefit or (Cost) Total Project $701
PVRR Benefit or (Cost) PPW Share $701
Project NPV $478 $43
Project IRR 25.0% 7.9%
Discount Rate Used '°'°
Capital Productivity Ratio 1.3 1.0
Payback Period (years) 4.0 Years 9.5 Years
2007 2008 2009 2010 2011
Capital Spending w/o AFUDC $52 $1685 $0 $0 $0 $0
Capital Spending w AFUDC $53 $1,711 $0 $0 $0 $0
Net Cash Flow Without Regulatory Recovery
Annual ($51) ($1,075) $601 $537 $481 $33
Cumulative ($51) ($1,126) ($525) $12 $493 $526
Net Cash Flow With Regulatory Recovery
Annual ($45) ($1,514) $248 $235 $222 $210
Cumulative ($45) ($1,558) ($1,311) ($1,076) ($854) ($644)
Incremental Earnings Before interest & Taxes
Without Regulatory Recovery ($4) $808 $757 $658 $575 ($143)
With Regulatory Recovery $6 $100 $187 $172 $157 $142
Incremental Earnings
Without Regulatory Recovery ($2) $516 $438 $379 $330 ($113)
With Regulatory Recovery $4 $77 $85 $78 $71 $64
Annual Revenue Requirement
Calculated $10 ($707) ($569) ($487) ($418) $216
Recovered $10 ($707) ($569) ($487) ($411) $286
* Includes regulatory lag of zero months.
APRI 0005755_Econ_T.xls Page 1 81912012 11.47 AM
Attach IPUC Production 7 -2.pdf page 19 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
F PaciflCorp - Thermal Economic Analysis Model Page 1 of 2
N Carbon U2: U2 Turbine Generator Overhaul Offical Curve: 3/30/2007
Dollar Year - 2007
In-Service Date - 2007
LAverage Inflation Rate - 1.9%
Discount Rate - 7.3%
Analysis Period - 14 years
Have economic model automatically add APUOC - 0 (1 =yes)
Z.M Jitl
-
Project Assumptions:
ALL REPAIRS ARE A RESULT OF INSPECTiONS PERFORMED IN 1999 AND 2004. THE RISK OF A FORTY-
FIVE DAY OUTAGE IS ASSESSED AT TWENTY PERCENT OVER THE NEXT FOUR YEAR PERIOD. IF THE
TURBINE BLADES ARE NOT INSTALLED NOW, THE RISK OF A TURBINE FAILURE IS HIGH BECAUSE
THE BLADES WOULD NOT BE INSPECTED (OR REPAIRED) UNTIL THE NEXT SCHEDULED MAJOR
OVERHAUL (2012).
OPERATING LOSSES WOULD CONTINUE UNTIL THE REPAIRS ARE COMPLETED.
AN AVERAGE 1.014 PERCENT ANNUAL LOSS IN TURBINE CYCLE HEAT RATE SINCE 1999 WILL
CONTINUE FOR THE REMAINING UNIT OPERATING LIFE FUEL COST REMAINS CONSTANT. THE
ESTIMATED LOSS IN FUEL COST IS BASED ON A CAPACITY FACTOR OF 85% AND A FUEL COST OF
Fixed Assumptions:
Capacity Factor 79.30%
Heat Rate 11,040 Btu/KWI1
Incremental Fuel $21.89 $TTsn
BTU/1b 11.400
MDC 105 MW
Plant Property Tax 0.73%
Total Capital Coat (Spent & Saved) $ 1,764 (In TEds)
$/mmBtu $ 0.86902
Calendar
Year
Medium PC
In Use
($/MWH)
2007 N/A
2008 $66.01
2009 $64.56
2010 $63.31
2011 $61.50
Med Low High
Net After-Tax Cash Flow NPV (In TEds) $478 $14 $842
Internal Rate of Return (IRR) 25.0% 7.7% 49.7%
Simple Payback Period of Original Investment 4.0 Years 7.5 Years 3.4 Years
Net Benefit to Capital Ratio 1 3 1.0 1.6
Present Value Revenue Requirement PVRR (In Thda) $701 ($47) $1,449
APR 000575QEcon_T.uls Page 1 of 2 Pages 9/9/2012 11:48 AM
Attach IPUC Production 7 -2.pdf page 20 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PacifiCorp - Thermal Economic Analysis Model Page 2 of 2
Carbon U2: U2 Turbine Generator Overhaul Official Curve: 3130/2007
Calculated Revenue Reauirement Detail (In Thds) Medium Level
Calendar
Year
Capital
Revenue
Requirement
O&M Cost
Reduction
(Increase)
Heat Rate
(Cost) or
Benefit
Station Use &
Cap. Restore
or (Impact)
Outage
(Cost)
Benefit
Total
(Cost)
Benefit
Cumulative
PV Revenue
Req. Benefit
2007 ($10) ____________ ____________ ($10) ($10)
2008 ($248) $955 $707 $627
2009 ($334) $903 $569 $1105
2010 ($317 $804 $487 $1,485
2011 ($301 $719 $1,790
2012 ($286 $1,596
2013 ($270 $1425
2014 ($255 $1,274
2015 ($241 $1,142
2016 F ($226 $1,026
2017 ($21' $925
2018 ($197 $837
2019 ($183 $781
2020 ($155 $701
Totals ($3236) $0 $0 $0 $3,381 $146
2007 NPV ($2069)] $0 $0 $0 $2,770 $701
Net After-Tax Cash Flows Without Reaulatorv Recovery (In Thds ) Official Curve: 3/3012007
Calendar
Year
Net Operating
(Cost) or
Benefit Property Tax
Income Tax
Payments
Capital
Investment
After-Tax
Cash Flow
PV After-Tax
Cast' Flow
Cumulative
PV After-Tax
Cash Plow
2007 $1 ($52) ($51) ($49) ($49)
2008 $955 $ ($333) ($1,685) (91075) ($968) ($1,017)
2009 $903 1$ ($291) $601 $504 ($513)
2010 $804 ($ ($257) $537 $420 ($93)
2011 $719 ($229) $481 $351 $258
2012 $41 $33 $22 $280
2013 $37 $30 $19 $299
2014 $34 $28 $17 $316
2015 $32 $27 $15 $331
2016 $31 $27 $14 $344 -
2017 $31 $28 $13 $358
2018 $30 $28 $13 $370
2019 $30 $29 $12 $382
2020 $249 $249 $96 $478
Totals $3,381 ($771 ($5951 ($1,73711 $972 $478
2007 NPV $2,770 1 ($55)) ($669)I ($1,567)) $478
APR10005755_Econ_T.xfs Page 2 of 2 Pages 8/912012 11:48 AM
Attach IPUC Production 7 -2.pdf page 21 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
Project Name:U0 Fly Ash Handling System
(In Thousands of Dollars)
Project Economics:
Customer Cash Plows Cash Flows
Revenue Prior to Regulatory After Regulatory
Requirement Adjustment Adjustment *
PVRR Benefit or (Cost) Total Project $1,987
PVRR Benefit or (Coat) PPW Share $1,987
Project NPV $1,266 $33
Project IRR 17.3% 7.7%
Discount Rate Used 7.4% 7.4%
Capital Productivity Ratio 1.7 1.0
Payback Period (years) 6.3 Years 9.2 Years
2007 2008 2009 2010 2011 2012
Capital Spending w/o AFUDC $1,450 $629 $0 $0 $0 $0
Capital Spending w AFLJDC $1,462 $670 $0 $0 $0 $0
Net Cash Flow Without Regulatory Recovery
Annual ($1,456) ($447) $418 $491 $476 $399
Cumulative ($1,456) ($1,903) ($1,486) ($995) ($519) ($120)
Net Cash 110w With Regulatory Recovery
Annual ($1,450) ($351) $296 $280 $265 $251
Cumulative ($1,450) ($1,801) ($1,505) ($1,225) ($960) ($709)
Incremental Earnings Before Interest & Taxes
Without Regulatory Recovery ($10) $90 $425 $551 $532 $414
With Regulatory Recovery ($0) $246 $229 $211 $193 $176
Incremental Earnings
Without Regulatory Recovery $2 $53 $225 $306 $298 $227
With Regulatory Recovery $8 $149 $103 $95 $87 $79
Annual Revenue Requirement
Calculated $10 $155 ($197) ($340) ($340) ($238)
Recovered $10 $155 ($197) ($340) ($340) ($238)
* Includes regulatory lag of zero months.
APR20000468_Econ_T.xts Page 1 5/9/2012 11:20 AM
Attach IPUC Production 7 -2.pdf page 22 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PactllCorp -Thermal Economic Analysis Model Page 1 s12
Co/ban U2: UO Fly Ash Handling System 016c51 Curae: 3131/2008
1VCt.-1D mx— I.-
-
C

C4 ..Ip.idi.'g
al
Prot.]
L
—
—
:-- -- LI-- —
.2rTt1-tFtT1TT ---I r-rn----ir- w r-'r'-i-m--i- r.irrs.I
-
-
-
-

Calendar I In Use
After-Tax Cash Flaw NPV (In mdx) $1266 $337 $2194
net Rate of Return (IRR) 173% 10.3% 234%
219 Payback Period of Original Investment 6.3 Yes/a 83 Years 0.3 Years
Benefit to Capital Ratio 1,7 1.2 21
APR20000468_Ecoa_T ale Page I 002 Pages 8/5/2012 11:20 AM
Attach IPUC Production 7 -2pdf page 23 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PacifiCorp hermal Economic Analysis Model Poge 2 of 2
Corbon U2: UO T Fly Mb Hondbn Sy,Iem Official Cu- 3I3120O8
_ci_,,_ UI1 dI•I L.1
- N1 UII Lgl
I U1 NJ
111J 2I ci.I
i1 2I 4I
- liJ NJ I :.c. t•1I i__I
- •i srcii
- CI 1II 4Ii
i
4)1 1J J KrI
it1 hI iJUII
-:.2j----- i
-.i J1s.gI
Calendar
Year
tiLfil
-... NCi ti11 oL)11
-° • I tik41 Ubi1 LI IciNJl
1u88 IIIJ W1 ti11 U1 o5MiI
i8h ....J tgL91 1 fri 2.J (2~d
up :g&:I J1 i aWl J O..i (221I ZiI LSI
tIal tIiil ZI'I '2J NJ
2ii .r2I t)l (iUH J1p .801 mcii
ac. .liI tiJ1 U01 8bI [I 8i!i
21I tJl tiIil iiii ID .•i 151 (N1t8Icil __ 'III 8LOI 2J
2.1 81 21 - W1 bLciJ gA!liI
.:..1 till ILl i Ji.J
.1tfl2)il Xlt1iYri.J
APR20000468_Econ.T.xls Page 2012 Pages 81912012 11:20 AM
Attach IPUC Production 7 -2.pdf page 24 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
Project Name:UO RAW WATER LINE
(In Thousands of Dollars)
Project Economics:
Customer Cash Flows Cash Flows
Revenue Prior to Regulatory After Regulatory
Requirement Adjustment Adjustment *
PVRR Benefit or (Cost) Total Project $815
PVRR Benefit or (Cost) l'PW Share $815
Project NPV $550 $45
Project IRR 23.0% 88%
Discount Rate Used 7.3% 7.3%
Capital Productivity Ratio 1.9 1.1
Payback Period (years) 6.0 Years 9.0 Years
2007 2008 2009 2010 2011 2012
Capital Spending w/o AFUDC $71 $626 $0 $0 $0 $0
Capital Spending w AFUDC $72 $648 $0 $0 $0 $0
Net Cash Flow Without Regulatory Recovery
Annual ($71) ($513) $141 $148 $153 $145
Cumulative ($71) ($585) ($444) ($296) ($143) $3
Net Cash Flow With Regulatory Recovery
Annual ($71) ($530) $101 $95 $90 $85
Cumulative ($71) ($602) ($501) ($405) ($315) ($230)
Incremental Earnings Before interest & Taxes
Without Regulatory Recovery ($1) $110 $141 $155 $165 $155
With Regulatory Recovery $0 $82 $77 $70 $64 $58
Incremental Earnings
Without Regulatory Recovery $1 $10 $75 $84 $92 $86
With Regulatory Recovery $I $63 $35 $32 $29 $26
Annual Revenue Requirement
Calculated $1 ($27) ($65) ($85) ($101) ($97)
Recovered $1 ($27) ($65) ($85) ($101) ($97)
* Includes regulatory lag of zero months.
APR10000664_Econ_T.xls Page 1 8/9/2012 11:34 AM
Attach IPUC Production 7 -2.pdf page 25 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PacifiCorp - Thermal Economic Analysis Model Page 1 of 2
Carbon 1)2: 1)0 Raw Water Line Offical Curve: 3130/2007
DollarYear- 2007
In-Service Date - 2008
[Average Inflation Rate - 1.9%
Discount Rate - 7.3%
Analysis Period - 14 years
Have economic model automatically add AFIJDC - 0 (1=yes)
Year
Capital
AFUDC
Station Use
(decrease)
Heat
I
Re a
or Loss
--
-
-
:Ii ts
45M:
-
--
Project Assumptions:
Assumed eight (8) day forced outage equiselent due to both units being derated or offline due to waterline
faflure. Began risk at 20% increasing the flak 5% per year up to a maximum 0140%
Fixed Assumptions:
Capacity Factor 79,30%
Heat Rate 11,040 BtuIKWh
Incremental Fuel $ 21.89 $/Ion
BTU/lb 11,400
MDC 105 MW
Plant Property Tax 0.73%
Total Capital Cost (Spent & Saved) $ 720 (In Tilds)
$/mmBtu 80.86902
Calendar
Year
Medium IPC
In Use
($IMWH)
2007 N/A
2008 866.01
2009 $64.56
2010 $63.31
2011 $61.50
Mod Low thi
Net After-Tax Cash Flow NPV (In Thds) $550 $211 $889
Internal Rate of Return (IRR) 23.0% 13.7% 31.8%
Simple Payback Period of Original Investment 6.0 Years 7.9 Years 5.0 Years
Net Benefit to Capital Ratio 1.9 1.3 2.5
Present Value Revenue Requirement PVRR (In Thds) $815 $269 $1,360
APR10000664_Econ_T.xls Page 1 012 Pages 81912012 11:34 AM
Attach IPUC Production 7 -2.pdf page 26 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PacifiCorp - Thermal Economic Analysis Model Page 2012
Carbon U2: U0 Raw Water Line Official Curve: 313012007
Calculated Revenue Reaulrement Detail (in Thds Medium Level
Calendar
Year
Capital
Revenue
Requirement
O&M Cost
Reduction
(Increase)
Heat Rate
(Cost) or
Benefit
Station Use &
Cap. Restore
or (Impact)
Outage
(Cost)
Benefit
Total
(Cost)
Benefit
Cumulative
PV Revenue
Req. Benefit
2007
2008 ($142 $170 $27 $24
2009 ($136 $201 $66 $78
2010 ($129 $214 $85 $145
2011 ($123 $224 $101 $218
2012 ($117 $213 $97 $284
2013 ($110 $217 $107 $351
2014 ($104 $224 $120 $422
2015 ($98 $243 $145 $502
2016 ($92 $254 $162 $585
2017 ($8 $284 $177 $869
2018 ($81 $273 $192 $755
2019 ($75 $283 $208 $841
2020 ($69 ($69) $815
Totals ($1364) No $0
10L
$2,780 $1416
2007 NPV 1 ($880) $0 $0 $01 $1,695 1 $815
Net After-Tax Cash Flows Without Regultorv Recover (In Thds) Official Curve: 3/30/2007
Calendar
Year
Net Operating
(Cost) or
Benefit
-
Property Thu
Income Tax
Payments
Capital
Investment
After-Tax
Cash Flow
PV After-Tax
Cash Flow
Cumulative
PV After-Tax
Cash Flow
2007 $O ($71) ($71) ($69) ($69)
2008 $170 _______ ($626) ($513) ($462) ($531)
2009 $201 $141 $118 ($4131
2010 $214 $148 $116 ($287)
2011 $224 4), $153 $111 ($186)
2012 $213 $145 1 99 ($87)
$217 $147 $93 $6
2014 $224 $150 $89 $95
2015 $243 $162 $89 $184
2016 $254 $168 $86 $270
2017 P 2
2013
$264 $175 $83 $353
20/8 $273 $181 $80 $434
20/9 $283 $187 $78 $511
020 9100 $100 $39 $550
Totals $2,780 t$32' ($778' ($697> $1,273 $550
2007NPV $16951 (523)1 ($490)1 ($632)1 $550
APR10000664_Econj.xls Page 2 of 2 Pages 6/9/2012 11:34 AM
Attach IPUC Production 7 -2.pdf page 27 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
Project Name: U1 BTFR: WATER WALL REBUILD CV 2009
(In Thousands of Dollars)
Project Economics:
Customer Cash Flows Cash Flows
Revenue Prior to Regulatory After Regulatory
Requirement Adjustment Adjustment *
PVRR Benefit or (Cost) Total Project $3,524
PVRR Benefit or (Cost) PPW Share $3,524
Project NPV $2,274 $88
Project IRR 29.3% 9.0%
Discount Rate Used 7.4% 7.4%
Capital Productivity Ratio 2,8 1.1
Payback Period (years) 6.0 Years 8.8 Years
2008 2009 2010 2011 2012 2013
Capital Spending w/o AFUDC $21 $1,439 $0 $0 $0 $0
Capital Spending w AFUDC $21 $1,475 $0 $0 $0 $0
Net Cash Flow Without Regulatory Recovery
Annual ($21) ($1,297) $241 $319 $328 $411
Cumulative ($21) ($1,318) ($1,077) ($758) ($430) ($19)
Net Cash Flow With Regulatory Recovery
Annual ($21) ($1,230) $215 $204 $193 $182
Cumulative ($21) ($1,251) ($1,036) ($832) ($640) ($458)
Incremental Earnings Before Interest & Taxes
Without Regulatory Recovery ($0) $64 $200 $330 $349 $487
With Regulatory Recovery $0 $171 $158 $145 $131 $118
Incremental Earnings
Without Regulatory Recovery $0 $62 $98 $180 $195 $282
With Regulatory Recovery $0 $129 $71 $65 $59 $53
Annual Revenue Requirement
Calculated $0 $108 ($42) ($185) ($218) ($369)
Recovered $0 $108 ($42) ($185) ($218) ($369)
* Includes regulatory lag of zero months.
APR 0000701_Econ,j.xls Page 1 8/9/2012 11:45 AM
Attach IPUC Production 7 -2.pdf page 28 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
MM (InThds) BENIN _(•_
-
- --
-
--
Project Assumptions:
Economic justification is based on an increasing forced outage rate doe to tuba leaks due to soot blower
erosion, Ry ash erosion. and hydrogen damage. There is a 75% chance of the forced outages occurring as
oollinnd abuse. The nsajooty of the rooter wait tube replacements dens dosing this project should tool until the
ocelot and at tta of the unit.

Calendar I to Use I
rTax Cash Flow NPV (in Tindal $2.274 $1037 $3512
Rote of Return (IRR) 283% 19.0% 38.1%
'aybacic Period of Original Investment 80 Years 7.4 Years 5.3 Years
slit to Capital Ratio 2.8 1.8 18
APRI000070I_Econ_Tvts Page I of Pages 8/912012 1145 AM
Attach IPUC Production 7 -2.pdf page 29 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PaclflCorp Thermal Economic Analysis Model
Pag.2-f2

Carbon UI UI Silo Water Wall Rebuild Cy 2009 Official Carve 313112008
t211 t.dI
OL.J 021!41 1.191
ii t.dJ1
L1 5l.I
1 -all ZIU
I I 2.LJ
001 L2:thl
1A51 2:121L00.0
11 1
r.r EI 131
ci 22:21 I :.i1 t!i1 1II Jt21
il tol t0t2ll 001J U01J 17rb211
0Il uaiigj1 !11
Ur .dll td1 tciDI 09LJ IIOJ]
3•8 Ia01 t091 L0i)1
900 .r1 t1 t1)1 11r21 r2:A1
(2:J1 L..bOI U ZIJ
ti'31 1211l1 fJ 9PU jar ii
iaL I!iiL1 Li'11 U2:rl1 08(1
t0J1 tIE91 ud
jAj 1rJOLI
IA.011 t1221 IArZk91 t1K2i1 jA!°01 2:10fL1 u:o' i1ux1UME)1 LI
APRI000070I_EcOnj.xla Page 2012 Pegoc 81912012 1145 AM
Attach IPUC Production 7 -2.pdf page 30 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
Project Name: U! Condenser Re-Tube
(In Thousands of Dollars)
Protect Economics:
Customer Cash Flows Cash Flows
Revenue Prior to Regulatory After Regulatory
Requirement Adjustment Adjustment *
PVRR Benefit or (Cost) Total Project $3,398
PVRR Benefit or (Cost) PPW Share $3,398
Project NPV $2,223 $115
Project IRR 25.2% 8.7%
Discount Rate Used 7.4% 7.4%
Capital Productivity Ratio 2.1 1.1
Payback Period (years) 5.9 Years 8.8 Years
2008 2009 2010 2011 2012 2013
Capital Spending w/o AFUDC $262 $1,950 $0 $0 $0 $0
Capital Spending w AFUDC $265 $2,000 $0 $0 $0 $0
Net Cash Flow Without Regulatory Recovery
Annual ($263) ($1,571) $364 $465 $508 $570
Cumulative ($263) ($1,834) ($1,471) ($1,005) ($497) $73
Net Cash Flow With Regulatory Recovery
Annual ($262) ($1,595) $319 $302 $286 $270
Cumulative ($262) ($1,857) ($1,538) ($1,237) ($951) ($681)
Incremental Earnings Before Interest & Taxes
Without Regulatory Recovery ($2) $296 $307 $478 $553 $658
With Regulatory Recovery ($0) $257 $235 $215 $195 $175
Incremental Earnings
Without Regulatory Recovery $1 $210 $151 $260 $310 $378
With Regulatory Recovery $2 $185 $106 $97 $88 $79
Annual Revenue Requirement
Calculates! $2 ($39) ($72) ($263) ($359) ($483)
Recovered $2 ($39) ($72) ($263) ($359) ($483)
Includes regulatory lag of zero months.
APRI001179I_Econ_T.xls Page 1 8/912012 11:47 AM
Attach IPUC Production 7 -2.pdf page 31 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7-2
-b1---
-
-
-
Assumptions are based as an initial three lobed outages per year due In condenser tube leaks. Additional
tube leaks and associated outages are anticipated to escalate over time due to erosion associated .4th
increased seloodies. Current cleanliness factor is 20% lest than design and the number of plugged tubes is
greeter than 14%
I Calendar I In Uses I
After-Tax Cash flow NPV (to Thds)
Inst Rate of Return (IRR)
pie Payback Period of Original Investment
Benefit to Capital Ratio

$2223 $1 ,042 $3,404

25.2% 16.5% 33.1%

58 Years 73 Years 5.2 Years

21 15 26
APRI000I75I_Econ_T,ois Page 1 ot2Pages 8/912012 11.47 AM
Attach IPUC Production 7 -2.pdf page 32 of 33
ID PAC-E-12-08
IPUC Production 7 Attachment IPUC Production 7 -2
PaclflCorp - Thermal Economic Analysis Model Page 2012
Carbon UI: Ui Condenser Re-lobe Official Cor,e: 613012008
Calculated Revenue Reoulrement Detail (In Thds) Medium Level
WI WI WI
0111 901
/4.21 6k/i _901
390.1 ¶0*1 681'I
64• *021 i411
1/1111 3I il111j
6k/Il 008l190J
1441 14418AiJ
-1/141 1C41 lJ/3J
81.141 l/1b1 1901
1/I
611.1'/1JI 1.1 1i1 011i91 61/1J
14.22 i.jiThi
93/ 2/Il
4M /421 11g011 U6011 102' 01Iti324I
/4I 0411 bh}I c01/19I 0i01 6/41 84901
086 6141 111)1 990011 ¶d•3U 5101 U20111 /46 4/41 W]990L91 14/11 6II.1 U32I /•sr -011.1 WI€tkLiI 0041 1'14• 1/61
1'II. 51k/I e:/1IWlyI --9041 6141 h/in
1411 Old-I WI W3M 1411 651.-I 11/11 456 .0/4/1 )I 990/1I 4/141 651;15141J
1J1 0E9011
590I 090l tk/b1
hfl 90XlE& _1.900Ib0A/I/4I(90tiI 0*411l
SOF/441I!016 _
APRI000I791_Econ_T.xs Page 2012 Pages 8/9/2012 1147 AM
Attach IPUC Production 7 -2.pdf page 33 of 33