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Home My WebLink About20080416Schwendiman Direct.pdf4: 42 BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION IN THE MATTER OF THE APPLICATION OF IDAHO POWER COMPAN FOR AUTHORITY TO IMPLEMENT POWER COST ADJUSTMENT (PCA) RATES FOR ELECTRIC SERVICE FROM MAY 16, 2 008 THROUGH MAY 15, 2009 CASE NO. IPC-E-08-07 IDAHO POWER COMPANY DIRECT TESTIMONY OF CELESTE SCHWENDIMA 1 Q.Please state your name and business address. 2 A.My name is Celeste Schwendiman, and my 3 business address is, 1221 West Idaho Street, Boise, Idaho. 4 Q.By whom are you employed and in what 5 capacity? 6 A.I am employed by Idaho Power Company (the 7 Company) as a Senior Pricing Analyst in the Pricing and 8 Regulatory Services Department. 9 Q.Please describe your educational background. 10 A.I received a Master i s degree in Business 11 Administration from Northwest Nazarene University and a 12 Bachelor of Arts degree in Psychology from Eastern Oregon 13 University. Most recently, I have attended the Center for 14 Public Utilities and National Association of Regulatory 15 Utility Commissioners' Practical Skills for a Changing 16 Utility Environment conference, two Current Issues 17 conferences, and the Edison Electric Insti tute i sElectric 18 Advanced Rate Course. 19 Q.Please describe your work experience with 20 Idaho Power Company. 21 A.I became employed by Idaho Power Company in 22 1997 as a Research Assistant II in the Pricing & Regulatory 23 Services Department. I have been promoted as follows: 24 February 1998, Entry Analyst; August 1998, Analyst; and July 25 2001, Senior Analyst. From 1998 through 2004, I assisted in Schwendiman, DI 1 Idaho Power Company 1 the preparation of the Power Cost Adjustment (PCA) filings. 2 In 2005, 2006, and 2007, I sponsored testimony in the 3 Company's annual PCA filings. In 2005 and 2007, I sponsored 4 testimony in the Company's general rate cases, and in 2006, 5 I sponsored testimony in the Company's filing to request 6 recovery of the Telocaset power purchase expense. 7 Q.What is this year's proj ection of PCA 8 expense? 9 A.The proj ection of PCA expense for the period 10 April 1, 2008, through March 31, 2009, is $108,801,005. 11 This amount is $18,709,046 less than the $127,510,051 12 normalized level of PCA expense as authorized in Order No. 13 30508. 14 Q.What is the basis for the projection of April 15 1, 2008, through March 31, 2009, PCA expense? 16 A.Through Order No. 24806, the Idaho Public 17 Utilities Commission adopted a natural logarithmic function 18 of proj ected April through July Brownlee reservoir inflow to 19 compute the proj ection of April through March PCA expense. 20 The equation was updated to be consistent with Order No. 21 30508. The current PCA regression equation is: 22 Annual PCA Expense = $3,137,598,149 $201,352, 132*ln (inflow)23 24 + $93,080,631 + $892,08425 Schwendiman, DI 2 Idaho Power Company 1 $1,427,334 2 This year i s regression was based on the water years 3 used in the calculation of the 2007 normalized power supply 4 expense, as approved through Order No. 30508. Details of 5 the regression equation are contained in Exhibit 1. 6 In this formula, $3,137,598,149 is the constant that 7 represents the prediction of annual net power supply expense 8 that would occur if there was zero April through July 9 Brownlee reservoir inflow. For each unit increase in the 10 natural logarithm of the Brownlee reservoir inflow, the 11 projection of annual power supply expense will be reduced by 12 $201,352,132, the second of the constants in the equation 13 above. The other three constants are: $93,080,631 for 14 qualifying facilities purchase expense, $892,084 for cloud 15 seeding program expense, and negative $1,427,334 for 16 associated cloud seeding program benefit. 17 Q.What is the April through July Brownlee 18 reservoir inflow forecast that you used to arrive at the 19 projection of PCA expense? 20 A.The National Weather Service i s Northwest 21 River Forecast Center (NWRFC), in its official forecast, 22 released on April 7, 2008, proj ected April through July 23 Brownlee reservoir inflow to be 5.40 million acre-feet. 24 Inserting this value into the equation, results in a 25 proj ection of net PCA expense of $108,801,005, for the Schwendiman, DI 3 Idaho Power Company 1 period April 1, 2008, through March 31, 2009. This amount 2 is $18,709,046 less than the normalized level of PCA expense 3 of $127,510,051. The forecast information supplied by the 4 NWRFC is contained on Exhibi t 2. 5 Q.You have stated that the proj ected net PCA 6 expense is less than the normalized level of PCA expense by 7 $18,709,046. What is the rate adjustment associated with 8 the proj ected decrease in PCA expense of $18,709,046, from 9 the normalized level of PCA expense? 10 A.The normalized PCA expense of $127,510,051, 11 divided by the normalized system firm sales of 14,239,221 12 Megawatt-hours, is used to arrive at the normalized base 13 power cost of 0.8955 cents per kilowatt-hour. For the 14 period April 1, 2008, through March 31, 2009, the customer- 15 level proj ected power cost of serving firm loads is 0.7641 16 cents per kilowatt-hour, which is computed by dividing the 17 projected net PCA expense of $108,801,005, by the 14,239,221 18 Megawatt-hours normalized system firm sales. Under the 19 currently approved PCA methodology, the Company adjusts its 20 rates by 90 percent of the difference between the customer- 21 level proj ected power cost of serving firm loads (0.7641 22 cents per kilowatt-hour) and the normalized base power cost 23 (0.8955 cents per kilowatt-hour). Restated, this year iS 24 computation is (.9) (0.7641 - 0.8955) = negative 0.1183. The 25 resulting adjustment is a 0.1183 cents per kilowatt-hour Schwendiman, DI 4 Idaho Power Company 1 decrease from the normalized base power cost. 2 Q.Please describe the true-up required from the 3 comparison of the April 1, 2007, through March 31, 2008, 4 actual results to last year 's proj ections. 5 A.The Deferral Expense Account report for the 6 April 1, 2007, through March 31, 2008, PCA year is attached 7 as Exhibit 3. This sheet compares the actual results to 8 last year's projections, month by month, with the 9 differences accumulated as the deferral balance. Interest 10 has been applied to the balance monthly. The balance at the 11 end of March 2008 was $132,648,878, as shown on Exhibit 3. 12 The accounting department has advised me that the deferral 13 balance will be amortized during the current PCA year. 14 Q.What is this year's true-up rate? 15 A.This year i s true-up component of the PCA is 16 the deferral balance of $132, 648,878 , divided by the 17 Company iS proj ected Idaho jurisdictional sales of 18 13,475,244, which results in a rate of 0.9844 cents per 19 kilowatt-hour. 20 Q.Have any changes been made to thi s year i s 21 true-up of the true-up calculation? 22 A.Yes, as part of last year iS PCA filing, the 23 Company recorded a credit of $49,712,488, in the Deferral 24 Expense Account report related to the after-tax benefit of 25 the 2006 sale of emissions allowances. By returning the Schwendiman, DI 5 Idaho Power Company 1 benefit of the sale to the Company's retail customers, the 2 Company realized an Idaho jurisdictional tax benefit of 3 $27,025,012 in 2007. In Order No. 30041, the Company was 4 instructed to record this amount as an additional credit for 5 its retail customers. This amount is shown in line 85, 6 column E, of the Deferral Expense Account report, as a 7 credit to the true-up of the true-up balance. 8 Q.Does the Company anticipate a credit for the 9 sale of 2007 emission allowances as part of this filing? 10 A.Yes, yesterday in Order No. 30529, dated 11 April 14, 2008, the Idaho Public Utilities Commission 12 instructed the Company to include the benefit of the 2007 13 calendar year sale of sulfur dioxide emission allowances in 14 this filing. 15 Due to time constraints, I was unable to include the 16 impact of the Commission order in my computations. However, 17 the Company will comply with the order in an expedited 18 manner to insure that the rate reduction is included in the 19 PCA rate change schedule for June 1, 2008. 20 Q.What is this year's true-up of the true-up 21 rate including the tax benefit as a result of Order No. 22 30041? 23 A.The Company collected all but $4,862,487, of 24 the 2007/2008 PCA true-up balance of $42,115,280, as shown 25 on line 99, of the Deferral Expense Account report. Schwendiman, DI 6 Idaho Power Company 1 Dividing the ending-balance of $4,862,487, by the projected 2 2007 Idaho jurisdictional sales of 13,475,244 Megawatt- 3 hours, results in 0.0361 cents per kilowatt-hour as the 4 true-up of the true-up rate. 5 Q.Where any other changes made as a result of 6 Order No. 30580, issued in the Company's last general rate 7 case? 8 A.Yes, the Company adjusted the Deferral 9 Expense Account report to reflect the stipulated load growth 10 adjustment rate of $62.79 applied to 50 percent of the 11 change in load, starting with the March 2008 entry. 12 Q.What was the total expense adjustment as a 13 result of the load change? 14 A.The total amount, not evaluated for recovery 15 through rates as a result of the load growth adjustment was 16 $34,969,279, as shown on line 14 of the Deferral Expense 17 Account report. 18 Q.Based on the traditional 90 percent sharing 19 methodology, what is the PCA rate as a result of: 1) the 20 adjustment for the 2008/2009 projected power cost of serving 21 firm loads, 2) the 2007/2008 true-up portion of the PCA, 3) 22 the true-up of the true-up, and 4) the $27 million tax 23 benefit from the 2006 sale of the emission credits? 24 A.The Company i s PCA rate, calculated under the 25 traditional 90 percent sharing methodology, for the Schwendiman, DI 7 Idaho Power Company 1 2008/2009 PCA year is 0.9022 cents per kilowatt-hour. This 2 rate is comprised of: 1) the negative o. l183 cents per 3 kilowatt-hour adjustment for 2008/2009 projected power cost 4 of serving firm loads, 2) the 0.9844 cents per kilowatt-hour 5 for the 2007/2008 true-up portion of the PCA, and 3) the 6 0.0361 cents per kilowatt-hour for the true-up of the true- 7 up which includes the $27 million customer tax-related 8 benefit from the 2006 sale of emissions credits. This 9 amount is shown on Exhibit 4, the Company's Schedule 55, 10 Power Cost Adjustment tariff, in both standard and 11 legislative format. 12 Q.Did Mr. Said instruct you to compute the PCA 13 under an alternative method? 14 A.Yes, although the true-up and the true-up of 15 the true-up components of the PCA are unaffected based upon 16 Mr. Said's instructions, the forecast component did change 17 resulting in a lower overall PCA rate. The new rate is 18 calculating by crediting 100 percent of the difference 19 between the customer-level projected power cost of serving 20 firm loads (0.7641 cents per kilowatt-hour) and the 21 normalized base power cost (0.8955 cents per kilowatt-hour) 22 to the forecast component of the PCA rate. Using the 100% 23 alternative proposed by the Company, this year's computation 24 is (1) (0.7641 - 0.8955) = negative 0.1314. The resulting 25 adjustment is a 0.1314 cents per kilowatt-hour decrease from Schwendiman, DI 8 Idaho Power Company 1 the normalized base power cost. The full rate of 0.8891 2 cents per kilowatt-hour can then be found by taking the sum 3 of the following components: 1) the negative 0.1314 cents 4 per kilowatt-hour adjustment for 2008/2009 projected power 5 cost of serving firm loads, 2) the 0.9844 cents per 6 kilowatt-hour for the 2007/2008 true-up portion of the PCA, 7 and 3) the 0.0361 cents per kilowatt-hour for the true-up of 8 the true-up which includes the $27 million customer tax- 9 related benefit from the 2006 sale of emissions credits. 10 Thi s amount is shown on Exhibi t 5, the Company's reques ted 11 Schedule 55, Power Cost Adjustment tariff, in both standard 12 and legislative format. 13 Q.How does the PCA rate of 0.8891 cents per 14 kilowatt-hour the Company is proposing compare to the 15 existing PCA rate? 16 A.The 2008/2009 PCA rate of 0.8891 cents per 17 kilowatt-hour is 0.6572 cents per kilowatt-hour greater than 18 the 0.2419 cents per kilowatt-hour PCA rate currently in 19 place for all customers. 20 Q.Has the Company made any changes to the 21 exhibits for this year i s filing? 22 A.Yes, the Company is proposing to remove the 23 PCA rate from all tariff sheets to make the format 24 consistent with the Company's other rates and fees. The 25 Company i s tariffs, in standard and legislative format, are Schwendiman, DI 9 Idaho Power Company 1 attached as Exhibi t 6. 2 Q.Does that conclude your testimony? 3 A.Yes. Schwendiman, DI 10 Idaho Power Company BEFORE THE IDAHO PUBLIC UTiliTIES COMMISSION CASE NO. IPC-E-08-07 IDAHO POWER COMPANY EXHIBIT NO.1 CELESTE SCHWENDIMAN PCA REGRESSION DERIVATION ~runoff J.d t dvY.u ~pre ie e 1 1928 6,687,539 15.72 $17,189,893 $(26,802,918) 2 1929 3,361,059 15.03 $92,476,236 $111, 725,322 3 1930 2,707,422 14.81 $172,971,827 $155,269,554 4 1931 2,222,50 14.61 $190,945,008 $195,008,729 5 1932 4,654,741 15.35 $111,428,422 $46,158,973 6 1933 4,194,946 15.25 $130,341,447 $67,100,769 7 1934 2,363,549 14.68 $243,089,879 $18,619,774 8 1935 3,087,643 14.94 $167,541,969 $128,809,638 9 1936 5,003,688 15.43 $111,481,590 $31,603,425 10 1937 2,952,686 14.90 $111,983,138 $137,808,642 11 1938 6,859,391 15.74 $(4,429,138)$(31,911,782) 12 1939 3,784,338 15.15 $79,756,880 $87,841,968 13 1940 4,188,408 15.25 $96,140,365 $67,414,812 14 1941 3,767,989 15.14 $97,777,961 $88,713,676 15 1942 4,888,149 15.40 $29,047,754 $36,307,314 16 1943 9,052,071 16.02 $(41,725,984)$(87,761,807)---017 1944 3,318,538 15.02 $88,702,045 $114,288,850 18 1945 4,671,061 15.36 $(25,761,859)$45,454,236 19 1946 6,766,869 15.73 $(10,921,664)$(29,177,377)20 1947 5,205,971 15.47 $15,955,276 $23,623,629 21 1948 5,805,875 15.57 $10,231,717 $1,663,354 22 1949 5,334,181 15.49 $24,801,384 $18,724,928 23 1950 6,400,584 15.67 $(45,420,954)$(17,972,279)24 1951 6,470,770 15.68 $(67,769,478)$(20,168,205) 25 1952 10,299,443 16.15 $(41,199,553)$(113,755,602) 26 1953 5,921,638 15.59 $(2,149,632)$(2,311,893) 27 1954 5,507,005 15.52 $75,110,354 $12,304,690 28 1955 3,483,175 15.06 $39,156,587 $104,539,431 29 1956 7,815,174 15.87 $(41,188,100)$(58,177 ,883) 30 1957 7,798,559 15.87 $(38,992,259)$(57,749,334)31 1958 7,433,507 15.82 $23,641,550 $(48,096,286) 32 1959 3,816,887 15.15 $82,706,117 $86,117,536 33 1960 4,245,918 15.26 $106,429,071 $64,668,923 34 1961 ----_..3,092,766 14.94 $139,215,366 $128,475,808 35 1962 4,484,164 15.32 $34,536,686 $53,676,293 36 1963 4,557,294 15.33 $43,305,150 $50,419,045 37 1964 5,552,348 15.53 $(53,306,546)$10,653,613 38 1965 8,419,011 15.95 $(66,232,418)$(73,163,539) 39 1966 3,496,728 15.07 $95,366,770 $103,757,477 40 1967 4,703,464 15.36 $18,769,151 $44,062,308 41 1968 3,359,176 15.03 $1,696,934 $111,838,120 42 1969 6,814,487 15.73 $10,356,900 $(30,589,313) 43 1970 6,133,178 15.63 $(80,492,393)$(9,379,352) 44 1971 10,273,883 16.15 $(125,906,235)$(113,255,300) 45 1972 7,762,679 15.86 $(52,723,819)$(56,820,817) 46 1973 3,888,739 15.17 $(4,012,612)$82,362,350 47 1974 9,594,874 16.08 $(88,828,308)$(99,487,626)48 1975 8,059,885 15.90 $(116,956,213)$(64,385,967) 49 1976 7,195,918 15.79 $10,098,008 $(41,555,581) 50 1977 2,145,455 14.58 $161, 731,594 $202,113,189 51 1978 5,101,863 15.45 $-------,-.00(8,652,777)$27,691,034 52 1979 3,888,971 15.17 $53,225,494 $82,350,334 53 1980 5,857,990 15.58 $(25,040,260)$(135,952) 54 1981 4,187,686 15.25 $25,434,888 $67,449,524 55 1982 9,300,223 16.05 $(138,449,806)$(93,207,330) 56 1983 9,961,651 16.11 $(176,232,461)$(107,041,113) 57 1984 11,380,893 16.25 $(158,377,495)$(133,859,821) 58 1985 5,536,238 15.53 $(32,979,556)$11,238,680 59 1986 8,440,084 15.95 $(82,454,515)$(73,666,892) 60 1987 3,027,757 14.92 $123,856,254 $132,753,297 61 1988 2,517,105 14.74 $155,285,763 $169,945,586 62 1989 4,313,993 15.28 $116,241,546 $61,466,208 63 1990 2,907,440 14.88 $179,928,167 $140,917,955 64 1991 2,700,662 14.81 $177,130,262 $155,772,910 65 1992 1,929,239 14.47 $225,168,594 $223,501,964 66 1993 6,041,043 15.61 $8,596,561 $(6,331,593) 67 1994 2,527,031 14.74 $147,416,813 $169,153,177 68 1995 _-_-.0_-o. ... '6;610,055 15.70 $(56,905,280)$(24,456,383)69 1996 8,090,881 15.91 $(59,006,210)$(65,158,828) 70 1997 10,046,261 16.12 $(11,991,557)$(108,744,093) 71 1998 8,405,908 15.94 $(96,666,069)$(72,849,919) 72 1999 7,707,677 15.86 $(42,915,744)$(55,389,059) 73 2000 4,302,602 15.27 $99,408,023 $61,998,588 74 2001 2,389,491 14.69 $189,029,529 $180,421,783 75 2002 3,361,015 15.03 $157,017,192 $111,727,936 76 2003 3,567,043 15.09 $15,678,063 $99,748,695 77 2004 3,147,333 14.96 $18,627,527 $124,954,301 78 2005 3,571,629 15.09 $69,005,699 $99,490,000 averages 5,390,065 35,799,289 $35,799,28915.40 $ multipler rsquare adjusted r square standard error observations regression residual total intercept x variable 1 regression statistics 0.9093 0.8268 0.8245 41,18,521 78 anova el 1 76 77 coefficients 3,137,598,149 (201,352,132) Exhibit No. 1 Case No. IPC-E-08-07 C. Schwendiman,lPC Page 1 of 1 BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION CASE NO. IPC-E-08-07 IDAHO POWER COMPANY EXHIBIT NO.2 CELESTE SCHWENDIMAN Wa t e r S u p p l y F o r e c a s t - ( B R N I l ) S N A K E - B R O W N E E D A M Pa g e 1 o f 7 ww . n w s . n o a a . g o v Or g a n i z a t i o n Wa t e r S u p p l y Fo r e c a s t In f o r m a t i o n Ma p Su m m a r y Wa t e r S u p p l y Se a s o n a l V o l u m e F o r e c a s t s (B R N I 1 ) S N A K E . B R O W N L E E D A M IC l i c k f o r N o r m a l s a n d A d j u s t m e n t s l ES P W a t e r S u p p l y ES P N a t u r a l Th e O f f i c i a l S t a t i s t i c a l W a t e r S u p p l y f o r e c a s t i s i s s u e d b e t w e e n t h e m i d d l e o f D e c e m b e r a n d J u l y 1 s t . En s e m b l e P r e d i c t e d f o r e c a s t a r e i s s u e d w e e k l y . A c o m p a r i s o n c o n t i n u e s t o b e m a d e be t w e e n t h e t w o f o r e c a s t s t h r o u g h t h e e n d o f S e p t e m b e r . Pe a k f l o w ~~ . " ' . ~ t " ' ~ U . ~ . 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I I (J ' " 0( 1 =r Z :i 0 (I . -0 5 . = o ~ ~ 3 ' Ç ) ~ CD Q ) r : ; ; N. : : 0 z o - ' r o -- 0 0 ' -. ( ) - . N ht t p : / / w w . n w d c . n o a a . g o v / w s f c s t / s t a t i o n / w s f p l o t / w s f p l o t . c g i ? B R N I 1 4/ 8 / 2 0 0 8 Wa t e r S u p p l y F o r e c a s t - ( B R N I l ) S N A K - B R O W N E E D A M P a g e 3 o f 7 i i¡t o BR O W N L E E RE S I N F L O W ( B R N J 1 ) Vl l a t e r Y e a r 2 0 0 8 . F o r c a s t P e r i o o A p r _ . J u l Xl 15 5 (l Qi t. Ow Ja n "" b Mi Ap Ma Ju " .l Au Sï p Fo t e c a $ / : E a r l y . F l l . M d n i o n t h Å Ob s e ~ d : M o n t l $ ' N o m ' t C U f f t M o l ' t l _ : Su m O b s : S u m . o J N o m i . t J s ' : : " Y e i l t o D a t e . S u m o f N o r m a l t t f o r P e r i d F o r e c a s t P e r I o d 1 0 D a l e . Cl 8 ø l : ~ A p f i 0 2 O ' , r o P M P O a J æ , N o r N u l R Ì \ t f R : e m C t i l i Fo r D a t a U s e d I n P l o t () ( ) . Q l (f ' " " ( J :: z ~ 9 "0 5 . ' õ ~ ~ ~ r Ç ) ~ CD Q ) i : ; : w. ~ 0 z o - \ f o -" 0 0 ' '1 ( ) ' 1 1 ' ht t p : / / w w . n w r f c . n o a a . g o v / w s f c s t / s t a t i o n / w s f p l o t / w s f p l o t . c g i ? B R N I 1 4/ 8 / 2 0 0 8 Wa t e r S u p p l y F o r e c a s t - ( B R N I l ) S N A K E - B R O W N E E D A M P a g e 4 o f ? i i l 1 0 8 RO W N L E E RE S I N F L O W ( B R N l 1 ) Wa t e r Y e a r 2 0 0 8 . F o r c a s l P e r i c x A p r . - A u g :¡15 5 o 0: 1 Ju So p Au g tb 0. 0 Ja n Ai b "" Ap Ma Ju " Fo r e c i ; s l : E a r y . F l t a l . M d m o n t l i ' " Ob _ i v e d : M o n t h N N o r m C U r r t M o n t h _ Su m O b s : S u m r i f f i o r m a 1 s " ) Y e M t o D a t e . S u m o / N o r m a l s . f o r P e . r l F o r e s t P e r i o d t o D a t e . ei u l ø : i . n A p f f l . 0 0 ! O P M PD l D , N o . . i I R N t l R ) I ' t . \ i l . C . i l l Fo r D a t a U s e d I n P l o t (' ( ' . a : en ( J (' ( 1 :T Z :E 0 (1 . "0 5 . i i ~ g 3 ' n S ; CD Q ) r ; ; : "' _ ~ ° z 0- q o 0 -" 0 0 ' -" ( ' - " N ht t p : / / w w . n w r f c . n o a a . g o v / w s f c s t l s t a t i o n / w s f p l o t l w s f p l o t . c g i ? B R N I 1 4/ 8 / 2 0 0 8 Wa t e r S u p p l y F o r e c a s t - ( B R N I l ) S N A K - B R O W N E E D A M P a g e 5 o f 7 i ijI D BR O W N L E E RE S I N f L O W ( B R N 1 1 ) Wa l e r Y e a r 2 0 0 8 , . F c i r e c a s t P a r i a l J a n - - A u g æ 15 5 o O: i Ja n So p Rib Ii Ap Ma Ju " Ju Au g I\ 0. " FC J l e c l J s t : E a r y . F l a l . M d m o n t l i . i Ob M l ~ d : M i l h $ ' N o m : i C U r r e n t M o n l h _ Su m O b s : S u m . c f N o i m l l $ , ) Y e a r I e D a t e . S u m o f N o r m a t s f o r P e . r i d F o r e c a s t P e r i o d t c D i i t e . C1 8 . d : i . A p f J ( l ; & P M P O l D æ . N o r t h . . e s t R r . e r F O c D t C e n l r Fo r D a t a U s e d I n P l o t () ( ) . I I cr ' " " C D :: z ~ ? "0 a. ' õ ~ ~~ : f n 2 : CD II mg ; (J . ' " 6 z 0- 9 " 0 _" 0 o . -. ( ) - . t \ ht t p : / / w w . n w r f c . n o a a . g o v / w s f c s t / s t a t i o n / w s f p l o t / w s f p l o t . c g i ? B R N I 1 4/ 8 / 2 0 0 8 Wa t e r S u p p l y F o r e c a s t - ( B R N I l ) S N A K E - B R O W N E E D A M P a g e 6 o f ? ¡f fl O BR O W N L E E RE S I N l O W ( B R N l 1 ) Wa t e r Y e a r 2 0 0 8 . f l ' c a s l P e r i o d A p r . - S s p a:15 5 o Cl t Ja n Mo l ' Ji , Ju Au g Sè p fè b Mi Ap tb i: " FO f f c u t . E a r l y . . F i r , . M d m o n t l i À Ob f t i v e d : M o n t h & , N o r t l m C u m i n t M o n t h _ Si m 0 . 1 : S i m o f N o r m s ~ ) Y e a r t o D a t e . S u m o l N O m J a t s f o r P e r i d F o æ i c a s t P e r i o d t o D a t e . CI U I e : r i n A p o r 1 J 0 0 : l i P M P O l D , N o r i t r N u l R r . $ f R l e ø t C $ n ! f Fo r D a t a U s e d I n P l o t US D e p t o f C o m m e r c e Na t i o n a l O c e a n i c a n d A t m o s p h e r i c A d m i n i s t r a t i o n Na t i o n a l W e a t h e r S e r v i c e No r t h w e s t R i v e r F o r e c a s t C e n t e r ( N W R F C ) 52 4 1 N E 1 2 2 n d A v e n u e Po r t l a n d , O r e g o n 9 7 2 3 0 - 1 0 8 9 (" ( " . D l (/ C I o C I :r Z ~ 9 i: 5 . : ¡ ~ ~ 3 ' n ~ CD Q ) r ; ; : (J . ' : 0 Z o - e p 0 -i : o . .. ( " . . N Di s c l a i m e r In f o r m a t ì o n Q u a l i t y Cr e d i t s Gl o s s a r y Se a r c h Pr i v a c y P o l i c y Fr e e d o m o f I n f o r m a t i o n A c t Ab o u t U s Ca r e e r O p p o r t u n i t i e s ht t p : / / w w . n w d c . n o a a . g o v / w s f c s t / s t a t i o n / w s f p l o t / w s f p l o t . c g i ? B R N I 1 4/ 8 / 2 0 0 8 r- ~r- (1~i: 00oo~ ~ .... ~~ ~ÇQ Cl C". '5J p; (, p; .. ~ 0;frn 0 -£ i:0 ÇQ ;frn p;~ ~00 (;0 §0Z~N .~ I'asrri(0 ..,,N .~rn ..C" ~ ..I 0: rn ~ C"tB0i:io rn (¡(J ~ ÇQ ¡¡'-c 'õ 6 i 0 0.i :2..a.00 rn (J ên ti ro ãi(,I-.5 ro (1 0 i-i: 0 cg~;:õ. ~i: 0. ~ ;:rri-Exhibit NO.2 (1~Case No. IPC-E-08-07 ~ ~C. Schwendiman, IPC 0. Page 7 of7 :i.. BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION CASE NO. IPC-E-08-07 IDAHO POWER COMPANY EXHIBIT NO.3 CELESTE SCHWENDIMAN A B C 0 E F G H I J K L M N 0 1 P o w e r C o s t A d u s t m e n t 2 A o r i l 2 0 0 7 t h r u M a r c h 2 0 0 8 Ao n l Ma v Ju n e Ju l v Au a u s t Se o t e m b e r Oc t o b e r No v e m b e r De c e m b e r Ja n u a r v Fe b r u a r v Ma r c h To t a l s 3 4 p e A R e v e n u e S N o r m l i z e d I d a h o J u r i s d i c t i o n a l S a l e s 69 7 , 4 0 0 95 4 , 6 6 6 1,0 7 4 , 2 5 2 1, 2 7 3 , 9 7 7 1, 2 9 5 , 4 6 0 1,1 5 8 , 3 6 7 99 6 , 8 1 2 91 2 , 3 3 6 1, 0 2 1 , 0 5 6 1,0 9 6 , 4 0 1 1,0 3 2 , 6 6 3 1, 0 3 0 , 3 9 3 12 , 7 5 4 , 0 2 3 6 (2 . 5 0 7 (2 . 5 0 1 ' 1.8 8 8 1.8 8 8 1. 8 8 8 1.8 8 8 1. 8 8 8 1.8 6 8 1.6 8 8 1.8 8 6 1.6 8 8 1.8 8 8 7 R . . a n " . :i i i ' i i :: : , i : , , : , (2 , 2 4 9 . 7 8 1 . H O (2 , 3 ~ ) 3 , 8 9 9 . 2 0 ) 2, 0 2 8 , 1 8 7 . 7 8 2, 4 0 5 , 2 6 8 . 5 8 2, 4 4 5 , 8 6 6 . 2 4 2, 2 0 5 . 8 7 6 . 9 0 1,8 8 1 , 9 6 1 . 0 6 1, 7 2 2 , 4 9 0 . 3 7 1,9 2 7 , 7 5 3 . 7 3 2,0 7 0 , 0 0 5 . 0 9 1,9 4 9 , 6 6 7 . 7 4 1, 9 4 5 , 3 8 1 . 9 8 15 , 9 3 8 , 7 9 8 . 4 7 8 , 9 L o a d C h a n g e A d j u s t m e n t 10 A c t u a l F i r m L o a d - A d j u s t e d Mw h 1, 0 8 4 , 6 4 2 1, 3 6 2 , 8 6 2 1, 5 2 9 , 7 7 1 1, 8 1 6 , 2 2 4 1, 6 0 1 , 8 4 8 1, 2 3 5 , 7 3 2 1,1 1 0 , 7 5 9 1,1 7 1 , 4 3 3 1, 3 6 7 , 7 6 4 1,4 0 9 , 9 7 6 1,2 1 1 , 6 9 7 1, 1 6 6 , 3 6 0 16 , 0 6 9 , 2 9 0 11 N o r m a l i z e d F i r m L o a d Mw h 1, 0 5 8 , 6 4 5 1, 2 1 4 , 5 1 8 1,3 9 5 , 6 1 7 1, 5 6 7 , 7 8 3 1, 4 8 2 , 8 9 6 1, 1 8 5 , 5 9 4 1,0 8 0 , 6 6 8 1,1 2 2 , 4 6 4 1, 2 7 4 , 1 0 8 1,2 6 5 , 0 9 1 1,0 9 2 , 6 4 5 1, 1 4 1 , 5 1 2 14 , 8 8 1 , 9 4 1 12 L o a d C h a n g e Mw h 25 , 9 9 7 14 8 , 3 4 4 13 4 , 1 5 4 24 8 , 4 4 1 11 6 , 9 5 2 50 , 1 3 6 29 , 8 9 1 46 , 9 6 9 93 , 6 5 6 14 4 , 6 8 7 11 9 , 0 5 2 24 , 8 6 8 1, 1 8 7 , 3 4 9 13 L o a d C h a n c e ( á 5 0 % 12 , 4 3 4 14 E x p e n s e A d " u s t m e n t ( ~ 2 9 . 4 1 / $ 6 2 . 7 9 M a r c h ) (/6 4 , 5 7 1 , T n (4 , 3 6 2 , 7 Ø 7 , 0 4 ) (3 , 9 4 5 , 4 6 9 . 1 4 ) (7 , ; : . \ í J ( - , 6 4 9 . H 1 i (: l A 9 8 , ~ F 8 . : . 1 2 ) (1 , 4 7 4 ; 5 5 8 . 5 H ) (H l 9 , O r . a : 3 1 ) (1 , 4 4 0 , 1 ì B . 2 9 ) '2 . 7 5 4 , 4 2 2 . 9 6 ) (4 , 2 6 1 , 1 2 6 5 7 ) 3;5 0 1 , 3 1 9 . : 1 2 ) (7 f 3 0 , 7 3 0 . 8 6 ) (3 4 , 9 6 9 , 2 9 7 . 0 7 ' 15 16 A c t u a l N o n - Q F P e A 17 E x p e n s e A d j u s t m e n t $ (7 M , 5 7 ! . 7 7 ) (4 , 3 G 2 , 7 9 7 . 0 4 ) n,9 4 5 . 4 ß 9 . 1 4 ) (3 , 4 D B , 3 7 R 3 2 ì (1 , 4 7 4 , 5 5 ß . S a ¡ (8 7 9 , 0 ) 4 . 3 1 ) (1 , 4 4 0 , 1 7 8 . 2 Q ) (2 , 7 5 4 , 4 2 2 . 9 6 ) 14 , 2 6 1 , 1 2 6 . G 7 ) n,5 0 1 , 3 1 ~ ) ' ~ ; ¡ 2 ) (7 8 0 , 7 3 0 . H 6 ) (3 4 , 9 6 9 , 2 9 7 . 0 7 ) 18 W a t e r L e a s e P u r c h a s e s $ 0. 0 0 0. 0 0 0. 0 0 0. 0 0 0. 0 0 0. 0 0 0.0 0 0. 0 0 0. 0 0 0.0 0 0.0 0 0. 0 0 0. 0 0 19 C l o u d S e e d i n g P r o g r a m $ 38 , 1 5 0 6 3 13 4 , 4 0 9 . 8 1 14 , 4 0 4 . 1 3 20 , 8 2 0 . 9 0 36 , 6 0 9 . 7 8 35 , 6 1 3 . 6 6 32 , 8 1 6 . 0 1 62 , 6 0 5 . 3 9 17 2 , 2 4 5 . 1 2 32 , 3 4 0 . 4 5 99 , 9 5 1 . 9 5 11 8 , 8 4 9 . 3 6 79 6 , 8 1 7 . 1 9 20 F u e l E X D 8 n s e ~ C o a l $ 7,0 5 4 , 6 1 6 . 3 1 6, 6 6 4 , 1 1 6 . 9 2 9,9 9 3 , 7 0 4 . 3 9 10 , 0 7 0 , 1 5 4 . 1 8 10 , 9 2 3 , 6 6 6 . 4 9 10 , 0 4 4 , 2 6 7 . 3 3 10 , 3 3 5 , 3 0 5 . 6 2 10 , 2 6 6 , 5 6 2 . 1 6 10 , 0 0 8 , 6 0 4 . 7 6 11 , 3 3 0 , 4 1 1 . 2 0 11 , 5 0 7 , 6 9 6 . 4 1 11 , 0 4 3 , 6 0 5 . 4 0 11 9 , 4 4 3 , 3 5 5 . 3 9 21 D a n s k i n - G a s $ 21 8 , 0 7 5 . 9 0 86 , 1 6 0 . 7 6 31 7 , 4 9 9 . 2 5 1, 3 3 9 , 2 9 1 . 5 8 1,1 6 2 , 4 6 3 . 2 8 10 7 , 9 9 8 . 5 9 32 7 , 8 7 4 . 9 8 65 , 8 2 8 . 7 0 72 , 1 7 6 . 3 9 26 7 , 6 8 6 . 0 0 28 , 0 6 6 . 0 9 41 1 , 1 7 8 . 9 5 4,4 4 4 , 3 2 0 . 4 7 22 B e n n e t t M o u n t a i n - - a s $ 47 6 , 4 1 0 . 4 2 1, 0 3 0 , 4 4 7 . 4 0 1,5 4 6 , 9 4 6 . 7 3,6 2 8 , 1 0 6 . 2 6 3,9 1 3 , 6 1 3 . 7 5 1, 5 0 7 , 9 3 2 . 0 2 33 0 , 9 4 5 . 9 0 27 5 , 5 0 2 . 5 5 60 2 , 3 3 0 . 2 1 1,8 9 3 , 7 9 1 . 9 8 70 4 , 8 9 1 . 1 8 26 8 , 5 3 4 . 9 6 16 , 3 7 9 , 4 5 3 . 4 0 23 N o n ~ F ¡ r m P u r c h a s e s $ 16 , 4 0 6 , 5 9 3 . 6 9 16 , 7 7 1 , 5 6 9 . 5 0 30 , 6 4 5 , 1 2 0 . 0 5 37 , 4 9 0 , 5 7 6 . 9 9 34 , 7 1 3 , 0 2 7 . 4 0 19 , 3 6 1 , 4 2 2 . 7 12 , 7 1 6 , 7 9 9 . 0 6 15 , 6 2 0 , 1 3 2 . 2 6 10 , 9 2 7 , 7 3 4 . 6 6 15 , 9 3 6 , 9 2 7 . 3 6 7, 0 6 0 , 9 1 9 . 1 7 13 , 6 1 2 , 7 2 7 . 3 8 23 3 , 4 6 5 , 5 7 2 4 9 24 T e l o c a s e t W i n d P o w e r P a r t n e r s 3, 5 4 0 . 2 2 73 7 , 6 9 2 . 0 0 1,2 5 4 , 6 6 6 . 0 8 99 1 , 4 2 0 . 3 2 68 8 , 6 7 9 . 3 5 3,6 7 6 , 4 1 7 . 9 7 25 S u r p l u s S a l e s $ ri' j , 7 8 9 , 1 3 4 . 0 2 ) í6 , 4 9 1 . 0 3 1 . 4 7 ) í1 7 , 0 0 2 . 8 2 9 . 1 1 ) 18 , 3 3 6 , 4 8 0 . 4 3 ) (1 0 , 7 8 8 , 9 0 2 . 6 6 ) (1 4 , 1 3 3 , 1 3 6 . 8 8 \ (1 3 ) 0 8 , 7 0 8 . 6 9 ) (8 , 4 3 9 , 9 1 7 - 7 1 ) (8 9 ' 1 1 0 . 5 3 ) (1 0 , 3 3 4 , 7 8 9 . 2 6 ) (5 , 3 1 7 , 4 4 4 . 6 3 ) 15 . 9 2 4 , 2 4 4 . 2 9 ) ('i 2 3 , 1 5 7 , 7 2 9 . 6 8 26 T o t a l N o n . Q F $ 11 , 6 4 0 , 3 4 1 . 1 6 16 , 0 3 2 , 8 9 7 . 6 8 21 , 5 6 9 , 3 7 6 . 3 4 36 , 9 0 5 , 8 2 1 . 6 7 36 , 4 8 2 , 3 0 1 . 7 2 15 , 4 4 9 , 5 5 8 . 9 1 9, 1 5 5 , 9 3 8 . 7 16 , 4 1 4 , 0 9 5 . 3 0 19 , 0 7 5 , 4 9 . 6 5 16 , 1 4 2 , 1 2 7 . 1 4 11 , 5 9 4 , 2 0 1 . 1 7 9,6 3 8 , 6 0 0 . 2 5 22 0 , 1 0 0 , 9 1 0 . 1 8 27 28 B A S E 29 F u e l E x p e n s e - G o a l $ 7,0 9 5 , 5 3 6 . 0 0 6,7 8 6 , 2 0 0 . 0 0 6,3 4 2 , 0 0 0 . 0 0 6,7 1 4 , 2 0 0 . 0 0 6,7 2 0 , 3 0 6 . 0 0 6,4 4 8 , 9 0 8 . 0 0 6,7 2 6 , 4 0 8 . 0 0 8,4 4 2 , 4 0 8 . 0 0 8,7 2 6 , 6 0 6 . 0 0 6,4 5 3 , 5 0 8 . 0 0 7, 3 7 2 , 8 0 6 . 0 0 9,7 6 2 , 6 6 6 . 0 0 97 , 5 9 1 , 5 6 0 . 0 0 30 D a n s k i n - G a s $ 26 4 , 8 0 0 . 0 0 27 6 , 9 0 0 . 0 0 27 5 , 7 0 0 . 0 0 27 9 , 6 0 0 . 0 0 26 0 , 8 0 0 . 0 0 25 4 , 7 0 0 . 0 0 27 2 , 3 0 0 . 0 0 26 4 , 4 0 0 . 0 0 27 3 , 1 0 0 . 0 0 27 2 , 2 0 0 . 0 0 25 7 , 5 0 0 . 0 0 24 1 , 2 1 9 . 0 0 3,2 2 3 , 2 1 9 . 0 0 31 B e n n e t t M o u n t a i n - G a s $ 32 , 2 0 0 . 0 0 25 7 , 1 0 0 . 0 0 40 6 , 1 0 0 . 0 0 25 3 , 2 0 0 . 0 0 25 6 , 7 0 0 . 0 0 20 , 9 0 0 . 0 0 22 , 4 0 0 . 0 0 6, 1 0 0 . 0 0 99 , 7 0 0 . 0 0 51 , 1 0 0 . 0 0 26 , 3 0 0 . 0 0 69 1 . 0 0 1,4 3 2 , 4 9 1 . 0 0 32 N o n - F i r m P u r c h a s e s $ 26 , 7 0 0 . 0 0 58 6 , 7 0 0 . 0 0 2,7 1 5 , 4 0 0 . 0 0 3,1 6 6 , 6 0 0 . 0 0 2,7 6 5 , 2 0 0 . 0 0 47 9 , 3 0 0 . 0 0 35 , 8 0 0 . 0 0 60 3 , 0 0 0 . 0 0 84 1 , 1 0 0 . 0 0 38 7 , 5 0 0 . 0 0 64 , 0 0 0 . 0 0 97 6 , 2 9 6 . 0 0 12 , 6 6 7 , 5 9 6 . 0 0 33 C l o u d S e e d i n g E x p e n s e $ 0.0 0 0.0 0 0.0 0 0.0 0 0. 0 0 0.0 0 16 7 , 4 2 3 . 0 0 16 7 , 4 2 3 . 0 0 16 7 , 4 2 3 . 0 0 16 7 , 4 2 3 . 0 0 16 7 , 4 2 3 . 0 0 14 8 , 6 8 0 . 6 6 98 5 , 7 9 5 . 6 6 34 C l o u d S e e d i n a B e n e f i t $ 0.0 0 0.0 0 0.0 0 0.0 0 0. 0 0 0.0 0 li 1 6 6 6 6 6 , (; ) 1 M6 6 " , (:~ 1 6 , 6 ¡ : f ¡ . 6 l ) í2 : . \ ' l , 8 ô Ð . O O ' ¡'1 , H 2 1 ) 2 2 . 3 5 ) 35 S u r p l u s S a l e s $ (9 2 3 4 . 0 0 0 . 0 0 ) (6 , 7 9 2 , 9 0 0 . 0 0 ) '4 , 8 3 1 , 5 0 0 . 0 0 ) 2,5 4 2 . 2 0 0 . 0 0 ' 13 , 6 0 1 , " ! o . o m :5 , 7 3 6 ; 2 0 0 . 0 O ' (5 , 8 8 9 , 8 0 0 . 0 0 ) (7 9 , 2 1 9 . 9 5 9 . 0 0 ' 36 N e t 9 0 % I t e m s $ (1 . 8 1 4 . 1 6 4 . 0 0 ) 1,1 1 4 , 0 0 0 . 0 0 4,9 0 7 , 7 0 0 . 0 0 9,8 7 1 , 4 0 0 . 0 0 8,4 2 1 , 9 0 8 . 0 0 3,4 7 7 , 6 0 8 . 0 0 3,6 9 5 , 4 6 4 . 3 3 7,7 4 7 , 0 6 4 . 3 3 6,3 4 7 , 4 6 4 . 3 3 3,1 2 5 , 2 6 4 . 3 3 (1 ( t 4 , 7 . 5 , 6 7 ) 34 , 8 5 9 , 4 6 0 . 3 1 37 38 "" : 13 , 4 5 5 , 1 0 5 . 1 6 14 , 9 1 8 , 8 9 7 , 8 8 16 , 6 6 1 , 6 7 6 . 3 4 27 , 0 3 4 , 4 2 1 . 6 7 26 , 0 6 0 , 3 9 3 . 7 2 11 , 9 7 1 , 9 5 0 . 9 1 5,2 6 0 , 4 7 4 . 4 4 8, 6 6 7 , 0 3 0 . 9 7 12 , 7 2 7 , 9 8 5 . 5 2 13 , 0 1 6 , 8 6 2 . 8 1 11 , 7 7 6 , 9 3 6 . 6 4 21 , 6 8 7 , 6 9 3 . 5 9 18 5 , 2 4 1 , 4 2 9 . 8 5 39 0.0 0 0.0 0 0.0 0 0.0 0 0. 0 0 0.0 0 0. 0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 40 S u b t o t a l $ 13 , 4 5 5 , 1 0 5 . 1 6 14 , 9 1 8 , 8 9 7 , 8 8 16 , 6 6 1 , 6 7 6 . 3 4 27 , 0 3 4 , 4 2 1 . 6 7 26 , 0 6 0 , 3 9 3 . 7 2 11 , 9 7 1 , 9 5 0 . 9 1 5,2 6 0 , 4 7 4 . 4 4 8, 6 6 7 , 0 3 0 . 9 7 12 , 7 2 7 , 9 8 5 . 5 2 13 , 0 1 6 , 8 6 2 . 8 1 11 , 7 7 6 , 9 3 6 . 8 4 21 , 6 6 7 , 6 9 3 . 5 9 18 5 , 2 4 1 , 4 2 9 . 6 5 41 42 S h a r i n a P e r c e n t a g e 90 . 0 % 90 . 0 % 90 . 0 % 90 . 0 % 90 . 0 % 90 . 0 % 90 . % 90 . 0 % 90 . 0 % 90 . 0 % 90 . 0 % 90 . 0 % 43 I d a h o A l l o c a t i o n 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 7 % 44 45 N o n . . F D e f e r r a l $ 11 , 3 9 5 , 1 2 8 . 5 6 12 , 6 3 4 , 8 1 4 . 6 1 14 , 1 1 0 , 7 7 3 . 6 9 22 , 6 9 5 , 4 5 1 . 7 1 23 , 7 5 4 , 3 4 7 . 4 4 10 , 1 3 9 , 0 4 5 . 2 3 4,4 5 5 , 0 9 5 . 6 0 7, 3 4 0 , 1 0 6 . 5 3 10 , 7 7 9 , 3 3 0 . 9 4 11 , 0 2 3 , 9 8 1 . 1 1 9, 9 7 5 , 5 8 1 . 6 1 18 , 8 4 , 4 2 1 . 2 5 15 6 , 9 9 8 , 0 8 0 . 4 8 46 47 A c u a l O F ( I n c l u d e s N e t M e t e r i n g ) $ 3,1 1 3 , 3 2 0 . 5 5 4,3 3 4 , 6 3 2 . 4 1 6,2 0 6 , 6 7 2 6 9 6,5 0 8 , 6 0 6 . 5 0 6,0 3 7 , 6 4 6 . 0 6 4,7 2 9 , 0 9 1 . 5 3 3,0 6 9 , 6 9 3 . 6 6 2, 2 6 3 , 4 4 6 . 6 7 2,6 0 3 , 2 1 6 . 2 4 2, 2 4 2 , 4 8 4 . 4 0 2,1 4 3 , 9 1 2 . 8 6 1,8 9 0 , 4 6 9 . 5 0 45 , 1 4 3 , 6 1 3 . 5 1 ~ Ba s a Q F 3,0 1 1 , 5 0 3 . 0 0 4,5 3 7 , 8 1 4 . 0 0 7,2 9 2 , 8 2 9 . 0 0 7,5 4 0 , 6 6 4 . 0 0 7,1 5 8 , 6 6 1 . 0 0 5,5 0 3 , 7 6 8 . 0 0 4,5 6 1 , 8 5 3 . 0 0 3, 2 3 9 , 5 9 3 . 0 0 3,4 8 3 , 6 6 3 . 0 0 3, 0 3 6 , 4 1 0 . 0 0 2, 9 5 7 , 5 9 5 . 0 0 5, 3 3 1 , 8 0 3 . 0 0 57 , 6 5 6 , 3 5 6 . 0 0 49 :I I ' : I ) ' 10 1 , 8 1 7 . 5 5 (2 0 3 , 1 8 1 . 5 9 ) (,1 , 0 8 6 , 1 5 6 . 1 1 ) (1 , 0 3 1 , 1 . 5 7 . 5 0 ) (1 , 1 2 ' 1 , 0 1 4 . 9 2 ) (7 7 4 , 6 7 ô . 4 7 ) (1 , 4 9 U l 5 9 . 1 4 ) (9 7 G , 1 4 6 . : U ) (1 3 8 0 , 6 4 6 . 7 6 ) 79 3 , 9 2 5 6 0 ) (S H ö 8 2 . 1 2 ) n,4 4 1 , 3 1 : : . 5 0 ) (1 2 , 5 1 2 , 7 4 2 . 4 9 ' 50 51 S h a r i n c P e r c e n t a a e 10 0 . 0 % 10 0 . 0 % 10 0 . 0 % 10 0 . 0 % 10 0 . 0 % 10 0 . 0 % 10 0 . 0 % 10 0 . 0 % 10 0 . 0 % 10 0 . 0 % 10 0 . 0 % 10 0 . 0 % 52 I d a h o A l l o c a t i o n 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 1 % 94 . 7 % 53 54 Q F D e f e r r a l $ 95 , 8 1 0 . 3 1 (1 9 1 , 1 9 : - . . 8 8 (1 , 0 2 2 , 0 7 2 . 9 O i (9 7 0 , 9 7 7 . ~ ) 1 j (1 , 0 5 4 , f . 7 5 . ( l 4 ) (7 2 H J Q O . 5 6 j (1 , 4 0 : : ¡ . f . ß ; ~ 5 5 j (9 1 8 ; 5 5 : ) . 7 0 ) (f . 2 8 , 6 H H . 6 0 i 17 4 7 , 0 8 3 9 9 \ Cï 6 5 J 3 7 4 . H 7 ) (3 , 2 5 0 , 9 2 3 . 8 8 (1 1 , 7 9 5 , 1 3 1 . L 5 T 55 56 57 T o t a l D e f e r r a l $ 13 , 7 4 0 , 7 2 0 . 6 7 14 , 6 3 7 , 5 1 9 . 9 3 11 , 0 6 0 , 5 1 3 . 0 1 19 , 5 1 9 , 2 0 5 . 2 2 20 , 2 6 3 , 6 0 6 . 1 6 7, 2 0 4 , 1 9 7 . 7 1, 1 6 9 , 1 6 1 . 1 9 4, 6 9 9 , 0 6 4 . 4 6 8,0 2 2 , 8 8 6 . 6 1 8, 2 0 6 , 8 9 2 . 0 3 7, 2 6 0 , 2 3 9 . 0 0 13 , 2 6 0 , 1 1 5 . 3 9 12 9 , 2 6 4 , 1 4 3 . 4 4 58 59 60 P r i n c i o a l B a l a n c e s ~62 0.0 0 13 , 7 4 0 , 7 2 0 . 6 7 28 , 5 7 8 , 2 4 0 . 6 0 39 , 6 3 6 , 7 5 3 . 6 1 59 , 1 5 7 , 9 5 6 . 6 3 79 , 4 2 1 , 5 6 4 . 9 9 86 , 6 2 5 , 7 6 2 . 7 6 87 , 7 9 4 , 9 4 3 . 9 5 92 , 4 9 4 , 0 0 8 . 4 1 10 0 , 5 1 6 , 6 9 7 . 0 2 10 8 , 7 2 3 , 7 8 9 . 0 5 11 5 , 9 8 4 , 0 2 8 . 0 5 -- 63 64 A m o u n t D e f e r r e d $ 13 , 7 4 0 , 7 2 0 , 6 7 14 , 8 3 7 , 5 1 9 . 9 3 11 , 0 6 0 , 5 1 3 . 0 1 19 , 5 1 9 , 2 0 5 . 2 2 20 , 2 6 3 , 6 0 6 . 1 6 7,2 0 4 , 1 9 7 . 7 7 1, 1 6 9 , 1 8 1 . 1 9 4, 6 9 9 , 0 6 4 . 4 6 8,0 2 2 , 8 8 8 . 6 1 6,2 0 6 , 8 9 2 . 0 3 7, 2 6 0 , 2 3 9 . 0 0 13 , 2 8 0 , 1 1 5 . 3 9 12 9 , 2 6 4 , 1 4 3 . 4 4 65 66 E n d l n a B a l a n c a $ 13 , 7 4 0 , 7 2 0 . 6 7 28 , 5 7 8 , 2 4 0 . 6 0 39 , 6 3 8 , 7 5 3 . 6 1 59 , 1 5 7 , 9 5 8 , 8 3 79 , 4 2 1 , 5 5 4 . 9 9 86 , 6 2 5 , 7 6 2 . 7 6 87 , 7 9 4 , 9 4 3 . 9 5 92 , 4 9 4 , 0 0 8 . 4 1 10 0 , 5 1 6 , 8 9 7 . 0 2 10 8 , 7 2 3 , 7 8 9 . 0 5 11 5 , 9 8 4 , 0 2 8 . 0 5 12 9 , 2 6 4 , 1 4 3 . 4 4 67 -- - - - - -- 68 I n t e r e s t B a l a n c e s ~ .~ . . , " " 70 0.0 0 0.3 8 ) 57 , 2 5 1 , 7 4 17 6 , 3 2 2 . 8 6 34 0 , 1 5 0 . 1 8 58 6 , 6 4 0 . 5 3 91 7 , 5 7 5 . 7 2 1,2 7 6 , 4 0 3 . 1 7 1 , 6 4 4 , 2 2 9 . 6 4 2,0 2 9 , 6 4 1 . 0 2, 4 4 8 , 4 5 2 . 3 0 2, 9 0 1 , 4 6 7 . 6 9 71 72 M o n t h l I n t e r e s t R a t e * * 5.0 % 5. 0 % 5. 0 % 5.0 % 5. 0 % 5.0 % 5. 0 % 5.0 % 5.0 % 5.0 % 5.0 % 5.0 % 73 74 M o n t h l I n t e r e s t I n c l E x o ) $ 0.0 0 57 , 2 5 3 . 0 0 11 9 , 0 7 6 . 0 0 16 5 , 1 6 1 . 4 7 24 6 , 9 1 . 5 0 33 0 , 9 2 3 . 1 9 36 0 , 9 4 0 . 6 8 36 5 , 8 1 2 . 2 7 38 5 , 3 9 1 . 7 0 41 8 , 8 2 0 . 4 0 45 3 , 0 1 5 . 7 9 48 3 , 2 6 6 . 7 8 3,3 8 6 , 1 5 2 . 7 8 75 P r i o r M o n t h ' s I n t e r e s t A d u s t m e n t s $ 0.3 8 \ 2. 1 2 (4 . 8 8 ) (1 , 3 3 4 . 1 5 (1 . - i 5 ) 12 . 0 0 (1 1 3 . 2 3 ) 14 . 4 0 19 . 8 6 (9 . 5 0 ) 10 4 0 1 0.0 0 U.4 1 8 . 3 1 ) 76 To t a l C u r r e n t M o n t h I n t e r e s t $ (: 3 8 ) 57 , 2 5 5 . 1 2 11 9 , 0 7 1 . 2 16 3 , 8 2 7 , 3 2 24 6 , 4 9 0 , 3 5 33 0 , 9 3 5 . 1 9 36 0 , 8 2 7 . 5 36 5 , 8 2 6 . 6 7 36 5 , 4 1 1 . 5 6 41 8 , 8 1 0 . 9 0 45 3 , 0 1 5 . 3 9 48 3 , 2 6 6 . 7 8 3, 3 8 4 , 7 3 4 . 4 7 77 78 I n t e r e s t A c c r u e d t o d a t e $ 13 . 3 8 ) 57 , 2 5 1 . 7 4 17 6 , 3 2 2 . 8 6 34 0 , 1 5 0 . 1 8 58 6 , 6 4 0 . 5 3 91 7 , 5 7 5 . 7 2 1, 2 7 6 , 4 0 3 . 1 7 1,6 4 4 , 2 2 9 . 8 4 2,0 2 9 , 8 4 1 . 4 0 2, 4 4 8 , 4 5 2 . 3 0 2, 9 0 1 , 4 6 7 . 6 9 3, 3 8 4 , 7 3 4 . 4 7 79 ,. 80 B a l a n c e I n A l l i i i : . n t s $ 13 , 7 4 0 , 7 1 7 . 2 9 28 , 8 3 5 , 4 9 2 , 3 4 39 , 8 1 5 , 0 7 6 . 4 7 59 , 4 9 8 , 1 0 9 . 0 1 80 , 0 0 6 , 2 0 5 . 5 2 67 , 5 4 3 , 3 3 6 . 4 8 89 , 0 7 3 , 3 4 7 . 1 2 94 , 1 3 6 , 2 3 6 . 2 5 10 2 , 5 4 6 , 5 3 8 . 4 2 11 1 , 1 7 2 , 2 4 1 . 3 5 11 8 , 8 8 5 , 4 9 5 . 7 4 13 2 , 6 4 8 , 8 7 7 . 9 1 13 2 , 6 4 8 , 8 7 7 9 1 ,, , - ~ C D :: Z :; 0 (! . "0 à . = t ~ ~ 3 ' n ~ (1 Q ) n t ; : .. _ ~ O z 0- C P 0 -" 0 0 ' I\ ( ) . . ( , pe A A 1 P o w e r C o s t A d ' u s t m e n t 2 A p r i l 2 0 0 7 t h r u M a r c h 2 0 0 8 Hl T r - u e : Ü o - o f T r u S : p ' - - 83 A d " u s t m e n t s : 84 2 0 0 6 ~ 0 7 p e A t r a n s f e r p e r O r d e r N o . 85 T a x s e t t e m e n t t r u e - u p p e r O r d e r N o . 3 0 0 4 1 ~1£88 89 M o n t h ! I n t e r e s t R a t e 9091 M o ~ ~ ~ ~ . ~ 92 93 94 9š M o n t h l C o l l e c t i o n A p p l i e d T o I n t e r e s t ~6 97 ~ ñ t h l y . q Ø I ~ ~ n ~ p p l i e t f T ô ' i å ~ i a n ç ! 98 99 E n d i n g T r u e - U p o f t h e T r u e - U p B a l a n c e 10 0 10 1 " N e g a t i v e a m o u n t s i n d i c a t e b e n e f i t o t h e r a t e p a y e r s . 1 0 2 U I n t e r e s t r a t e c h a n g e d p e r ¡ P U C O r d e r 2 9 9 3 2 10 3 ~ F i ó i ¡ C ö . i Ã I l T u . 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W B C F o E -- Ä o r l l Ma v Ju n e Jl. l v - -( 7 , 9 4 1 , 0 9 3 , 8 8 ) -. 3 5 . 3 9 6 . 8 8 4 . 1 6 ._ . . - . _ . . 36 . 6 3 5 . 3 1 3 . 8 4 1 0 , 5 7 0 , 5 4 2 . 7 8 42 . 1 1 5 , 2 7 9 . 6 3 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 ('2 ï , 0 2 5 , 0 1 2 . 4 9 ) 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 34 . 1 7 4 . 1 8 5 . 7 5 35 . 3 9 6 , 8 8 4 . 1 6 9.6 1 0 . 3 0 1 . 3 5 10 , 5 7 0 . 6 4 2 . 7 8 5.0 % 5.0 % 5.0 % 5.0 % 14 2 . 3 9 2 . 4 4 14 7 , 4 8 7 . 0 2 40 , 0 4 2 . 9 2 44 , 0 4 4 . 3 4 11 , 0 8 0 , 3 0 5 . 9 7 ) '1 , 0 9 0 , 9 4 2 . 6 6 ) 19 2 0 , 2 9 8 5 ' i l 1.0 8 1 . 3 0 1 . 0 2 14 2 . 3 9 2 . 4 4 14 7 . 4 8 7 . 0 2 40 , 0 4 2 . 9 2 44 , 0 4 4 . 3 4 $- a$¡- - - - r - - N : 2 2 2 ) j ~ q 8 ' . J 1 i i - - - ' - ( 1 , 2 J 8 . 4 2 9 ~ ( 9 6 0 , 3 4 1 . 4 ; : j ) r . ~ - 1 " 0 3 7 . i 5 6 . 6 8 35 , 3 9 6 . 8 8 4 . 1 6 36 , 6 3 5 . 3 1 3 . 8 4 9, 5 3 3 , 3 8 6 . 1 0 10 , 5 7 0 , 6 4 2 . 7 8 Ap r i l Ma v Ju n e Ju l v j- 0.0 0 (1 2 7 6 , 6 6 7 . 2 3 ) i- . . ~ 1 . 9 è . 3 ! 2 ~ 8 . (9 5 7 , : . \ 4 9 . 7 5 ) (1 1 , 9 1 1 . 4 8 1 13 4 , 9 8 7 . 6 0 (1 . 0 8 6 , 6 5 0 . 5 6 (1 6 3 , 8 5 4 . 8 9 72 , 9 7 4 . 6 6 (H : ~ 4 , ; U : J . 6 3 ì (3 3 0 . 9 4 7 . 1 2 ) 78 . 5 7 0 . 1 9 (9 5 7 . 3 4 0 . 7 5 \ 11 , 1 7 7 , 5 : ) 0 . ' ( 9 ) (8 : 1 4 , 2 7 : . 6 3 i ('1 . o e e , 6 5 0 . 5 6 i G H I J K Au n u s t Se n t e m b e r Oc t o b e r No v e m b e r De c e m b e r ._ - .. _ - - . - ~ ~ 9.5 3 3 . 3 8 6 . 1 0 8.7 9 1 . 0 9 0 . 2 4 8,1 3 5 . 5 1 5 . 1 1 7. 6 3 1 . 3 9 3 . 8 9 6,9 7 5 . 4 9 . 2 1 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0. 0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 9.5 3 3 . 3 8 6 . 1 0 8.7 9 1 . 0 9 0 . 2 4 8,1 3 5 . 5 1 5 . 1 1 7. 6 3 1 , 3 9 3 . 8 9 6, 9 7 5 , 4 9 1 . 2 1 5.0 % 5.0 % 5.0 % 5.0 % 5.0 % 39 , 7 2 2 . 4 4 36 , 6 2 9 . 5 4 33 , 8 9 7 . 9 8 31 , 7 9 7 . 4 7 29 . 0 6 4 . 5 5 78 2 . 0 1 8 . 3 0 69 2 . 2 0 4 . 6 7 53 8 , 0 1 9 . 2 0 68 7 . 7 0 0 . 1 5 41 4 , 0 1 9 . 1 3 39 , 7 2 2 . 4 4 36 , 6 2 9 . 5 4 33 . 8 9 7 . 9 8 31 . 7 9 7 . 4 7 29 . 0 6 4 . 5 5 65 5 , 5 7 5 . 1 3 '- - 5 õ , 1 i i : 2 . 74 2 , 2 9 5 . 8 6 65 5 . 9 0 2 . 6 8 38 4 , 9 5 4 . 5 8 8, 7 9 1 . 0 9 0 . 2 4 8, 1 3 5 . 5 1 5 . 1 1 7,6 3 1 , 3 9 3 . 8 9 6, 9 7 5 , 4 9 1 . 2 1 6. 5 9 0 . 5 3 6 . 6 3 Au a u s t Se p t e m b e r No v e m b e r De c e m b e r Oc t o b e r M Ja n u a i Fe b r u a 6.5 9 0 . 5 3 6 . 6 3 T ' " 5 9 7 ' 5 . 2 9 1 9 3 1 5 , 3 8 5 , 3 1 1 . 4 Ma r c h 0. 0 0 0. 0 0 0.0 0 0. 0 0 0.0 0 0. 0 0 6, 5 9 0 . 5 3 6 . 6 3 5,9 7 5 , 2 9 1 . 9 3 5.0 % 5. 0 % 27 , 4 6 0 . 5 7 24 , 8 9 7 . 0 5 64 2 , 7 0 5 . 2 7 61 4 . 8 7 7 3 4 27 , 4 6 0 . 5 7 24 . 8 9 7 . 0 5 61 5 2 4 4 7 0 - - - S 8 g ; 9 8 õ . 2 9 5. 9 7 5 , 2 9 1 . 9 3 5.3 8 5 , 3 1 1 . 6 4 Ja n u a r y Fe b r u a r y N 0.0 0 0.0 0 0.0 0 5, 3 8 5 . 3 1 1 . 6 4 22 , 4 3 8 . 8 0 54 5 , 2 6 3 . 8 5 o~ "( 7 . - 9 4 1 ! i q ~ ~ ) j t T ) 1 42 . 1 1 5 . 2 7 9 . 6 3 (2 " 7 . 0 2 5 , 0 1 2 . 4 9 ) 1 0.0 0 7. 1 4 9 , 1 7 3 . 2 6 5.0 % 61 9 , 8 7 5 . 1 2 2. 9 0 6 , 5 6 1 . 7 9 22 , 4 3 8 . 8 0 ., I ' . 52 2 . 8 2 5 . 0 5 2 , 2 8 6 . 6 8 6 . 6 7 4.8 6 2 , 4 8 6 . 5 9 Ma r c h 4, 8 6 2 , 4 8 6 . 5 9 To t a l s (1 , 1 " 1 7 J S : 3 0 . ì 9 ) í4 £ 1 1 , ' ¡ ' 1 4 . 8 5 í . 9 5 , 0 0 1 . 5 2 ' 1. 5 7 3 J : i 4 4 . 1 2 ! (1 , 7 2 4 . : : ) 1 7 , ; . i O j ('1 , 6 1 2 , 1 2 6 , 5 Ö ) r '- 1 . 7 9 6 . 5 1 L ? 4 ' 0. 0 0 (: i 2 5 , Ø H S . 5 1 . ) (1 3 : . 1 1 , 4 2 2 - 7 9 ) 0. 0 0 '2 5 5 , 1 7 9 , 6 1 ) (1 7 , 7 6 5 . 7 9 ) (3 ; 3 . 3 4 2 9 9 ) 1 (4 . 6 8 , 3 1 7 . 4 5 ) 1, 4 2 1 J ì 6 . 5 ; j j (6 0 3 . 5 5 0 . 1 9 ) 30 . 1 8 0 . 6 4 (1 , 0 0 0 , 1 4 6 . 1 0 , 10 4 . 5 0 6 . 4 3 12 9 , 2 5 6 . 5 9 12 9 . ~ ~ _ 11 9 , 4 2 5 . 8 3 95 . 7 9 0 . 9 7 10 3 . 1 1 2 . 9 8 13 6 , 7 4 3 . 2 6 33 5 , 6 4 7 . 2 1 I 0. 0 0 0. 0 0 0. 0 0 0. 0 0 1. 7 2 4 , ~ ~ 1 " 1 . ; . \ 0 ) (1 , 6 1 2 , 8 2 6 , 5 0 ) ('1 , 7 Ø 6 , 5 1 1 2 ' l ( 2 , 1 4 5 , 4 ü 2 . 8 t i l P2 5 . 9 8 5 . S 8 ) (8 3 ' 1 . 4 2 2 . 7 9 ) (6 6 4 , 4 9 H . 8 9 ) (6 6 4 , 4 9 H . 8 ~ (1 , 5 7 : ~ , r ¡ 4 4 . 1 2 J (2 . 1 4 5 . 4 0 2 , 8 6 ) - - - - - - (1 3 , 5 5 4 . 0 5 ) 4, 8 3 2 . 4 0 4 . 7 4 7 . 4 0 (2 , 1 5 4 , ! 2 4 . 5 1 ) ( 2 , 3 8 1 , 3 B 7 . 5 3 1 (2 , ' i 4 ~ l A 0 2 J I 6 ) 1 U5 9 . 3 8 ' (2 , 3 7 ' ¡ , 3 0 2 . 4 3 1 PC A BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION CASE NO. IPC-E-08-07 IDAHO POWER COMPANY EXHIBIT NO.4 CELESTE SCHWENDIMAN Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 55-1 SCHEDULE 55 POWER COST ADJUSTMENT APPLICABILITY This schedule is applicable to the electric energy delivered to all Idaho retail Customers served under the Company's schedules and Special Contracts. These loads are referred to as "firm" load for purposes of this schedule. BASE POWER COST The Base Power Cost of the Company's rates is computed by dividing the Company's power cost components by firm kWh load. The power cost components are the sum of fuel expense and purchased power expense (including purchases from cogeneration and small power producers), less the sum of off-system surplus sales revenue. The Base Power Cost is 0.8955 cents per kWh. PROJECTED POWER COST The Projected Power Cost is the Company estimate, expressed in cents per kWh, of the power cost components for the forecasted time period beginning April 1 each year and ending the following March 31. The Projected Power Cost is 0.7641 cents per kWh. TRUE-UP AND TRUE-UP OF THE TRUE-UP The True-up is based upon the difference between the previous Projected Power Cost and the power costs actually incurred. The True-up of the True-up is the difference between the previous years approved True-Up revenues and actual revenues collected. The total True-up is 1.0205 cents per kWh. POWER COST ADJUSTMENT The Power Cost Adjustment is 90 percent of the difference between the Projected Power Cost and the Base Power Cost plus the True-ups. The monthly Power Cost Adjustment applied to the Energy rate of all metered schedules and Special Contracts is 0.9022 cents per kWh. The monthly Power Cost Adjustment applied to the per unit charges of the nonmetered schedules is the monthly estimated usage times 0.9022 cents per kWh. EXPIRATION The Power Cost Adjustment included on this schedule will expire May 31, 2009. Exhibit NO.4 Case No. IPC-E-08-07 C. Schwendiman, ¡PC Page 1 of2 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 55-1 SCHEDULE 55 POWER COST ADJUSTMENT APPLICABILITY This schedule is applicable to the electric energy delivered to all Idaho retail Customers served under the Company's schedules and Special Contracts. These loads are referred to as "firm" load for purposes of this schedule. BASE POWER COST The Base Power Cost of the Company's rates is computed by dividing the Company's power cost components by firm kWh load. The power cost components are the sum of fuel expense and purchased power expense (including purchases from cogeneration and small power producers), less the sum of off-system surplus sales revenue. The Base Power Cost is 0.74770.8955 cents per kWh. PROJECTED POWER COST The Projected Power Cost is the Company estimate, expressed in cents per kWh, of the power cost components for the forecasted time period beginning April 1 each year and ending the following March 31. The Projected Power Cost is 0.95750.7641 cents per kWh. TRUE-UP AND TRUE-UP OF THE TRUE-UP The True-up is based upon the difference between the previous Projected Power Cost and the power costs actually incurred. The True-up of the True-up is the difference between the previous years approved True-Up revenues and actual revenues collected. The total True-up is 0.05311.0205 cents per kWh. POWER COST ADJUSTMENT The Power Cost Adjustment is 90 percent of the difference between the Projected Power Cost and the Base Power Cost plus the True-ups. The monthly Power Cost Adjustment applied to the Energy rate of all metered schedules and Special Contracts is 0.24190.9022 cents per kWh. The monthly Power Cost Adjustment applied to the per unit charges of the nonmetered schedules is the monthly estimated usage times 0.24190.9022 cents per kWh. EXPIRATION The Power Cost Adjustment included on this schedule will expire May 31, 200g~. Exhibit NO.4 Case No. IPC-E-08-07 C. Schwendiman, ¡PC Page 2 of2 BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION CASE NO. IPC-E-08-07 IDAHO POWER COMPANY EXHIBIT NO.5 CELESTE SCHWENDIMAN Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 55-1 SCHEDULE 55 POWER COST ADJUSTMENT APPLICABILITY This schedule is applicable to the electric energy delivered to all Idaho retail Customers served under the Company's schedules and Special Contracts. These loads are referred to as "firm" load for purposes of this schedule. BASE POWER COST The Base Power Cost of the Company's rates is computed by dividing the Company's power cost components by firm kWh load. The power cost components are the sum of fuel expense and purchased power expense (including purchases from cogeneration and small power producers), less the sum of off-system surplus sales revenue. The Base Power Cost is 0.8955 cents per kWh. PROJECTED POWER COST The Projected Power Cost is the Company estimate, expressed in cents per kWh, of the power cost components for the forecasted time period beginning April 1 each year and ending the following March 31. The Projected Power Cost is 0.7641 cents per kWh. TRU&UP AND TRU&UP OF THE TRU&UP The True-up is based upon the difference between the previous Projected Power Cost and the power costs actually incurred. The True-up of the True-up is the difference between the previous years approved True-Up revenues and actual revenues collected. The total True-up is 1.0205 cents per kWh. POWER COST ADJUSTMENT The Power Cost Adjustment is 100 percent of the difference between the Projected Power Cost and the Base Power Cost plus the True-ups. The monthly Power Cost Adjustment applied to the Energy rate of all metered schedules and Special Contracts is 0.8891 cents per kWh. The monthly Power Cost Adjustment applied to the per unit charges of the nonmetered schedules is the monthly estimated usage times 0.8891 cents per kWh. EXPIRATION The Power Cost Adjustment included on this schedulewil expire May 31, 2009. Exhibit NO.5 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 1 of2 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, 10 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 55-1 SCHEDULE 55 POWER COST ADJUSTMENT APPLICABILITY This schedule is applicable to the electric energy delivered to all Idaho retail Customers served under the Company's schedules and Special Contracts. These loads are referred to as "firm" load for purposes of this schedule. BASE POWER COST The Base Power Cost of the Company's rates is computed by dividing the Company's power cost components by firm kWh load. The power cost components are the sum of fuel expense and purchased power expense (including purchases from cogeneration and small power producers), less the sum of off-system surplus sales revenue. The Base Power Cost is 0.74770.8955 cents per kWh. PROJECTED POWER COST The Projected Power Cost is the Company estimate, expressed in cents per kWh, of the power cost components for the forecasted time period beginning April 1 each year and ending the following March 31. The Projected Power Cost is 0.95750.7641 cents per kWh. TRUE-UP AND TRUE-UP OF THE TRUE-UP The True-up is based upon the difference between the previous Projected Power Cost and the power costs actually incurred. The True-up of the True-up is the difference between the previous years approved True-Up revenues and actual revenues collected. The total True-up is 0.05311.0205 cents per kWh. POWER COST ADJUSTMENT The Power Cost Adjustment is 00100 percent of the difference between the Projected Power Cost and the Base Power Cost plus the True-ups. The monthly Power Cost Adjustment applied to the Energy rate of all metered schedules and Special Contracts is O~.8891 cents per kWh. The monthly Power Cost Adjustment applied to the per unit charges of the nonmetered schedules is the monthly estimated usage times 0.24190.8891 cents per kWh. EXPIRATION The Power Cost Adjustment included on this schedule will expire May 31, 200g~. Exhibit NO.5 Case No. IPC-E-08-07 C. Schwendiman,lPC Page 2of2 BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION CASE NO. IPC-E-08-07 IDAHO POWER COMPANY EXHIBIT NO.6 CELESTE SCHWENDIMAN Idaho Power Company Second Revised Sheet No. 1-2 Cancels Original Sheet No. 1-2I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 1 RESIDENTIAL SERVICE (Continued) RESIDENTIAL SPACE HEATING All space heating equipment to be served by the Company's system shall be single-phase equipment approved by Underwriters' Laboratories, Inc., and the equipment and its installation shall conform to all National, State and Municipal Codes and to the following: Individual resistance-type units for space heating larger than 1,650 watts shall be designed to operate at 240 or 208 volts, and no single unit shall be larger than 6 kW. Heating units of 2 kW or larger shall be controlled by approved thermostatic devices. When a group of heating units, with a total capacity of more than 6 kW, is to be actuated by a single thermostat, the controlling switch shall be so designed that not more than 6 kW can be switched on or off at anyone time. Supplemental resistance- type heaters, that may be used with a heat exchanger, shall comply with the specifications listed above for such units. SUMMER AND NON-SUMMER SEASONS The summer season begins on June 1 of each year and ends on August 31 of each year. The non-summer season begins on September 1 of each year and ends on May 31 of each year. MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98 (Residential and Small Farm Energy Credit). Summer Non-summer Service Charge, per month $4.00 $4.00 Energy Charge, per kWh First 300 kWh All Additional kWh 5.6973cl 6.4125cl 5.6973cl 5.6973cl PAYMENT The monthly bil rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit No.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 1 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, 10 Idaho Power Company Second Revised Sheet No. 4-3 Cancels Original Sheet No. 4-3I.P.U.C. No. 29. Tariff No. 101 SCHEDULE 4 RESIDENTIAL SERVICE ENERGY WATCH PROGRAM (OPTIONAL) (Continued) MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98 (Residential and Small Farm Energy Credit). Summer Non-summer Service Charge, per month $4.00 $4.00 Energy Charge, per kWh . Energy Watch Event hours All other hours 20.0000i 5.6973i n/a 5.6973i PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman,lPC Page 2 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, 10 Idaho Power Company Second Revised Sheet No. 5-3 Cancels Original Sheet No. 5-3I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 5 RESIDENTIAL SERVICE TIME-OF-DAY PROGRAM (OPTIONAL) (Continued) MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98 (Residential and Small Farm Energy Credit). Energy Charge, per kWh On-Peak Mid-Peak Off-Peak All Non-summer Hours Summer Non-summer $4.00 $4.00 8.7443Ø n/a 6.4125Ø n/a 4.7402Ø n/a n/a 5.6973Ø Service Charge, per month PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 c. Schwendiman, IPC Page 30f50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company Second Revised Sheet No. 7-2 Cancels Original Sheet NO.7 -2I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 7 SMALL GENERAL SERVICE (Continued) MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98 (Residential and Small Farm Energy Credit). Summer Non-summer Service Charge, per month $4.00 $4.00 Energy Charge, per kWh First 300 kWh All Additional kWh 6.92251t 7.79581t 6.92251t 6.92251t PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 4 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company Second Revised Sheet No. 9-2 Cancels Original Sheet No. 9-2I.P.U.C. No. 29. Tariff No. 101 SCHEDULE 9 LARGE GENERAL SERVICE (Continued) FACILITIES BEYOND THE POINT OF DELIVERY At the option of the Company, transformers and other facilities installed beyond the Point of Delivery to provide Primary or Transmission Service may be owned, operated, and maintained by the Company in consideration of the Customer paying a Facilities Charge to the Company. Company-owned Facilities Beyond the Point of Delivery wil be set forth in a Distribution Facilities Investment Report provided to the Customer. As the Company's investment in Facilities Beyond the Point of Delivery changes in order to provide the Customer's service requirements, the Company shall notify the Customer of the additions and/or deletions of facilities by forwarding to the Customer a revised Distribution Facilties Investment Report. In the event the Customer requests the Company to remove or reinstall or change Company- owned Facilities Beyond the Point of Delivery, the Customer shall pay to the Company the "non- salvable cost" of such removal, reinstallation or change. Non-salvable cost as used herein is comprised of the total original costs of materials, labor and overheads of the facilities, less the difference between the salvable cost of material removed and removal labor cost including appropriate overhead costs. POWER FACTOR Where the Customer's Power Factor is less than 90 percent, as determined by measurement under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand by multiplying the measured kW by 90 percent and dividing by the actual Power Factor. SUMMER AND NON-SUMMER SEASONS The summer season beings on June 1 of each year and ends on August 31 of each year. The non-summer season begins on September 1 of each year and ends on May 31 of each year. MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98 (Residential and Small Farm Energy Credit). Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 5 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 9-3 Cancels Original Sheet No. 9-3 SCHEDULE 9 LARGE GENERAL SERVICE (Continued) MONTHLY CHARGE (Continued) SECONDARY SERVICE Service Charge, per month Basic Charge, per kW of Basic Load Capacity First 20 kW All Additional kW Demand Charge, per kW of Billing Demand First 20 kW All Additional kW Energy Charge, per kWh First 2,000 kWh All Additional kWh Facilities Charge None. PRIMARY SERVICE Service Charge, per month Basic Charge, per kW of Basic Load Capacity Demand Charge, per kW of Billing Demand Energy Charge, per kWh Summer Non-summer $12.50 $12.50 $0.00 $0.00 $0.66 $0.66 $0.00 $0.00 $3.79 $3.14 7.20161t 6.42481t 3.08541t 2.75221t Summer Non-summer $210.00 $210.00 $0.94 $0.94 $3.74 2.80731t $3.13 2.51421t Facilities Charge The Company's investment in Company-owned Facilties Beyond the Point of Delivery times 1.7 percent. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 6 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company Second Revised Sheet No. 9-4 Cancels Original Sheet No. 9-4I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 9 LARGE GENERAL SERVICE (Continued) MONTHL Y CHARGE (Continued) TRANSMISSION SERVICE Summer Non-summer Service Charge, per month $210.00 $210.00 Basic Charge, per kW of Basic Load Capacity $0.49 $0.49 Demand Charge, per kW of Billing Demand $3.67 $3.06 Energy Charge, per kWh 2.7405Ø 2.4673Ø Facilities Charge The Company's investment in Company-owned Facilities Beyond the Point of Delivery times 1.7 percent. PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 7 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company Second Revised Sheet No. 15-2 Cancels Original Sheet No. 15-2I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 15 DUSK TO DAWN CUSTOMER LIGHTING (Continued) NEW FACILITIES Where facilities of the Company are not presently available for a lamp installation which wil provide satisfactory lighting service for the Customer's Premises, the Company may install overhead or underground secondary service facilities, including secondary conductor, poles, anchors, etc., a distance not to exceed 300 feet to supply the desired service, all in accordance with the charges specified below. MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). 1. Monthly Per Unit Charge on existing facilities: AREA LIGHTING High Pressure Average Base Sodium Vapor Lumens Rate 100 Watt 8,550 $ 6.17 200 Watt 19,800 $10.02 400 Watt 45,000 $16.01 FLOOD LIGHTING High Pressure Average Base Sodium Vapor Lumens Rate 200 Watt 19,800 $12.18 400 Watt 45,000 $18.18 Metal Halide 400 Watt 28,800 $20.32 1000 Watt 88,000 $37.05 2. For New Facilities Installed Before June 1, 2004: The Monthly Charge for New Facilties installed prior to June 1, 2004, such as overhead secondary conductor, poles, anchors, etc., shall be 1.75 percent of the estimated installed cost thereof. 3. For New Facilities Installed On or After June 1, 2004: The non-refundable charge for New Facilities to be installed, such as underground service, overhead secondary conductor, poles, anchors, etc., shall be equal to the work order cost. PAYMENT Exhibit NO.6 The monthly bill for service supplied hereunder is payable upon receipt, and becomes ~t'~~~~~~~~6 15 days from the date on which rendered. . Page 8 ~f 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company Second Revised Sheet No. 19-3 Cancels Original Sheet No. 19-3I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 19 LARGE POWER SERVICE (Continued) FACILITIES BEYOND THE POINT OF DELIVERY At the option of the Company, transformers and other facilities installed beyond the Point of Delivery to provide Primary or Transmission Service may be owned, operated, and maintained by the Company in consideration of the Customer paying a Facilities Charge to the Company. Company-owned Facilities Beyond the Point of Delivery will be set forth in a Distribution Facilities Investment Report provided to the Customer. As the Company's investment in Facilities Beyond the Point of Delivery changes in order to provide the Customer's service requirements, the Company shall notify the Customer of the additions and/or deletions of facilities by forwarding to the Customer a revised Distribution Facilities Investment Report. In the event the Customer requests the Company to remove or reinstall or change Company- owned Facilities Beyond the Point of Delivery, the Customer shall pay to the Company the "non- salvable cost" of such removal, reinstallation or change. Non-salvable cost as used herein is comprised of the total original costs of materials, labor and overheads of the facilities, less the difference between the salvable cost of material removed and removal labor cost including appropriate overhead costs. POWER FACTOR ADJUSTMENT Where the Customer's Power Factor is less than 90 percent, as determined by measurement under actual load conditions, the Company may adjust the kW measured to determine the Biling Demand by multiplying the measured kW by 90 percent and dividing by the actual Power Factor. TEMPORARY SUSPENSION When a Customer has properly invoked Rule G, Temporary Suspension of Demand, the Basic Load Capacity, the Billing Demand, and the On-Peak Billing Demand shall be prorated based on the period of such suspension in accordance with Rule G. In the event the Customer's metered demand is less than 1,000 kW during the period of such suspension, the Basic Load Capacity and Billng Demand will be set equal to 1,000 kW for purposes of determining the Customer's Monthly Charge. MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 9 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company Second Revised Sheet No. 19-4 Cancels Original Sheet No. 19-4I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 19 LARGE POWER SERVICE (Continued) MONTHLY CHARGE (Continued) SECONDARY SERVICE Demand Charge, per kW of Billng Demand Summer Non-summer $12.50 $12.50 $0.66 $0.66 $3.36 $3.14 $0.43 n/a 3.3575i n/a 3.1899i 2.8699i 2.9731i 2.7401i Service Charge, per month Basic Charge, per kW of Basic Load Capacity On-Peak Demand Charge, per kW of On-Peak Biling Demand Energy Charge, per kWh On-Peak Mid-Peak Off-Peak Facilities Charge None. PRIMARY SERVICE Summer Non-summer Service Charge, per month Basic Charge, per kW of Basic Load Capacity $210.00 $0.94 $210.00 $0.94 Demand Charge, per kW of Billing Demand $3.31 $3.13 On-Peak Demand Charge, per kW of On-Peak Biling Demand $0.43 n/a Energy Charge, per kWh On-Peak Mid-Peak Off-Peak 2.8708i 2.5915i 2.4153i n/a 2.3445i 2.2368i Facilities Charge The Company's investment in Company-owned Facilities Beyond the Point of Delivery times 1 ~hibi NO.6Percent Case No. IPC-E-08-07. C. Schwendiman, IPC Page 10 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 19-5 Cancels Original Sheet No. 19-5 and 19-6 SCHEDULE 19 LARGE POWER SERVICE (Continued) MONTHL Y CHARGE (Continued) TRANSMISSION SERVICE Summer Non-summer Service Charge, per month $210.00 $210.00 Basic Charge, per kW of Basic Load Capacity $0.49 $0.49 Demand Charge, per kW of Billing Demand $3.24 $3.06 On-Peak Demand Charge, per kW of On-Peak Biling Demand $0.43 n/a Energy Charge, per kWh On-Peak 2.8426st n/a Mid-Peak 2.5655st 2.3164st Off-Peak 2.3913st 2.2100st Facilties Charge The Company's investment in Company-owned Facilities Beyond the Point of Delivery times 1.7 percent. PAYMENT The monthly bill for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 11 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company Second Revised Sheet No. 24-3 Cancels Original Sheet No. 24-3I.P.U.C. No. 29. Tariff No. 101 SCHEDULE 24 AGRICULTURAL IRRIGATION SERVICE (Continued) MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98 (Residential and Small Farm Energy Credit). SECONDARY SERVICE In-Season Out-of-Season Service Charge, per month Demand Charge, per kW of Billing Demand Energy Charge, per kWh $15.00 $ 4.61 3.5894Ø $3.00 $0.00 4.5690Ø Facilities Charge None. TRANSMISSION SERVICE In-Season Out-of-Season Service Charge, per month $210.000 $3.00 Demand Charge, per kW of Biling Demand $ 4.33 3.4144Ø $0.00 4.3463ØEnergy Charge, per kWh Facilities Charge The Company's investment in Company-owned Facilities Beyond the Point of Delivery times 1.7 percent. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 12 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, 10 Idaho Power Company Second Revised Sheet No. 39-1 Cancels Original Sheet No. 39-1I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 39 STREET LIGHTING SERVICE SUPPLEMENTAL SEASONAL OR VARIABLE ENERGY AVAILABILITY Service under this schedule is available throughout the Company's service area within the state of Idaho to Customers who were receiving Customer-owned Non-Metered Service under Schedule 41 prior to June 1, 2004. Eligible Customers may continue to receive supplemental energy service under this schedule unti there is no potential for seasonal or variations in usage from the street lighting service, or street lighting service is converted to Metered Service under Schedule 41, or May 31, 2011, whichever is sooner. This schedule will expire on May 31,2011. APPLICABILITY Service under this schedule is applicable to seasonal or variable energy service utilized by municipalities or agencies of federal, state, or county governments through wired outlets or useable plug-ins on a Customer-owned street lighting fixture. Service under this schedule is apart from and supplemental to the street lighting service received under Schedule 41. SERVICE CONDITIONS Each Customer who takes supplemental service under this schedule must have the Company ascertain the estimated annual number of kWh used as seasonal or variable usage. MONTHLY CHARGE The estimated annual kWh of energy usage is divided by 12 to determine the estimated monthly kWh of energy usage. The Monthly Charge shall be computed at the following rate, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Energy Charge, per estimated monthly kWh 5.6850Ø PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 13 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company Second Revised Sheet No. 40-2 Cancels Original Sheet No. 40-2I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 40 UNMETERED GENERAL SERVICE (Continued) MONTHLY CHARGE The average monthly kWh of energy usage shall be estimated by the Company, based on the Customer's electric equipment and one-twelfth of the annual hours of operation thereof. Since the service provided is unmetered, failure of the Customer's equipment wil not be reason for a reduction in the Monthly Charge. The Monthly Charge shall be computed at the following rate, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Energy Charge, per kWh 5.6850it $1.50Minimum Charge, per month PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit No. 6 Case No. IPC-E-OS-07 C. Schwendiman, IPC Page 14 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company Second Revised Sheet No. 41-2 Cancels Original Sheet No. 41-2I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 41 STREET LIGHTING SERVICE (Continued) ACCELERATED REPLACEMENT OF EXISTING FIXTURES In the event a Customer requests the Company perform an accelerated replacement of existing fixtures with the cut-off fixture, the following charges will apply: 1. The actual labor, time, and mileage costs incurred by the Company for the removal of the existing street lighting fixtures. 2. $65.00 per fixture removed from service. The total charges identified in 1 and 2 above must be paid prior to the beginning of the fixture replacement and are non-refundable. The accelerated replacement will be performed by the Company during the regularly scheduled working hours of the Company and on the Company's schedule. MONTHLY CHARGE The monthly charges are as follows, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Lamp Charges, per lamp High Pressure Sodium Vapor 70 Watt 100 Watt 200 Watt 250 Watt 400 Watt Average Lumens 5,540 8,550 19,800 24,750 45,000 Base Rate $ 7.45 $ 6.72 $ 7.86 $ 8.88 $11.18 Pole Charges For Company-owned poles installed after October 5, 1964 required to be used for street lighting only: Charge Wood pole, per pole Steel pole, per pole $1.81 $7.18 Facilities Charges Customers assessed a monthly facilities charge prior to June 1, 2004 for the installation of underground circuits wil continue to be assessed a monthly facilities charge equal to 1.75 percent of the estimated cost difference between overhead and underground circuits. Exhibit NO.6 Case NO.IPC-E-08-07 C. Schwendiman, IPC Page 15 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, 10 Idaho Power Company Second Revised Sheet No. 41-3 Cancels Original Sheet No. 41-3I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 41 STREET LIGHTING SERVICE (Continued) "B" - CUSTOMER-OWNED SYSTEM The Customer's lighting system, including posts or standards, fixtures, initial installation of lamps and underground cables with suitable terminals for connection to the Company's distribution system, is installed and owned by the Customer. Customer-owned systems installed on or after June 1,2004 which are constructed, operated, or modified in such a way as to allow for the potential or actual variation in energy usage, such as through, but not limited to, the use of wired outlets or useable plug-ins, are required to be metered in order to record actual energy usage. Customer-owned systems installed prior to June 1, 2004 that are constructed, operated, or modified in such a way as to allow for the potential or actual variation in energy usage may have the estimated annual variations in energy usage served under Schedule 39 until its expiration on May 31, 2011, or until the street lighting system is converted to Metered Service, or until the potential for variations in energy usage has been eliminated, whichever is sooner. Effective June 1, 2011 all Customer-owned street lighting systems that have the potential for variations in energy usage must be metered. ENERGY AND MAINTENANCE SERVICE Energy and Maintenance Service includes operation of the system, energy, lamp renewals, cleaning of glassware, and replacement of defective photocells which are standard to the Company- owned street light units. Service does not include the labor or material cost of replacing cables, standards, broken glassware or fixtures, painting, or refinishing of metal poles. Individual lamps will be replaced on burnout as soon as reasonably possible after notification by the Customer and subject to the Company's operating schedules and requirements. ENERGY-ONLY SERVICE Energy-Only Service ìs available only to a metered lighting system. Service includes energy supplied from the Company's overhead or underground circuits and does not include any maintenance to the Customer's facilities. A street lighting system receiving service under the Energy-Only Service offering is not eligible to transfer to any street lighting service option under this schedule that includes maintenance provisions to the Customer's facilities. MONTHLY CHARGE The monthly charges are as follows, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman,lPC Page 16 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, 10 Idaho Power Company Second Revised Sheet No. 41-4 Cancels Original Sheet No. 41-4I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 41 STREET LIGHTING SERVICE (Continued) MONTHLY CHARGE (Continued) Non-Metered Service (With Maintenance), per lamp High Pressure Sodium Vapor 70 Watt 100 Watt 200 Watt 250 Watt 400 Watt Average Lumens 5,450 8,550 19,800 24,750 45,000 Base Rate $3.19 $3.63 $5.03 $6.01 $8.33 Metered Service (With Maintenance), per lamp High Pressure Sodium Vapor 70 Watt 100 Watt 200 Watt 250 Watt 400 Watt $2.06 $1.84 $1.89 $1.84 $1.87 $8.45 4.9139Ø Meter Charge, per meter Energy Charge, per kWh Metered Energy-Only Service (No Maintenance) Meter Charge, per meter $8.45 4.9139ØEnergy Charge, per kWh PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman. IPC Page 17 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, 10 Idaho Power Company Second Revised Sheet No. 41-6 Cancels Original Sheet No. 41-6I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 41 STREET LIGHTING SERVICE (Continued) NO NEW SERVICE "B" - ORNAMENTAL LIGHTING - CUSTOMER-OWNED SYSTEM (Continued) ENERGY AND MAINTENANCE SERVICE Energy and Maintenance Service includes operation of the system, energy, lamp renewals, cleaning of glassware, and replacement of defective photocells which are standard to the Company- owned street light units. Service does not include the labor or material cost of replacing cables, standards, broken glassware or fixtures, or painting or refinishing of metal poles. Individual lamps will be replaced on burnout as soon as reasonably possible after notification by the Customer and subject to the Company's operating schedules and requirements. ENERGY-ONLY SERVICE Energy-Only Service is available only to a metered lighting system. Service includes energy supplied from the Company's overhead or underground circuits and does not include any maintenance to the Customer's facilities. A street lighting system receiving service under the Energy-Only Service offering is not eligible to transfer to any street lighting service option under this schedule that includes maintenance provisions to the Customer's facilities. MONTHLY CHARGE The monthly charges are as follows, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Non-Metered Service (With Maintenance), per lamp Average Lumens Base Rate Mercury Vapor 175 Watt 400 Watt 7,654 19,125 $ 5.50 $ 8.69 Exhibit No.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 18 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company Second Revised Sheet No. 41-7 Cancels Original Sheet No. 41-7I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 41 STREET LIGHTING SERVICE (Continued) NO NEW SERVICE MONTHLY CHARGE (Continued) Metered Service (With Maintenance), per lamp Mercury Vapor 175 Watt 400 Watt $1.90 $1.97 $8.45 4.91391t Meter Charge. per meter Energy Charge, per kWh Metered Energy-Only Service (No Maintenance) Meter Charge. per meter $8.45 4.91391tEnergy Charge, per kWh PAYMENT The monthly bil rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendíman, IPC Page 19 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company Second Revised Sheet No. 42-1 Cancels Original Sheet No. 42-1I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 42 TRAFFIC CONTROL SIGNAL LIGHTING SERVICE APPLICABILITY Service under this schedule is applicable to Electric Service required for the operation of traffic control signal lights within the State of Idaho. Traffic control signal lamps are mounted on posts or standards by means of brackets, mast arms, or cable. CHARACTER OF SERVICE The traffic control signal fixtures, including posts or standards, brackets, mast arm, cable, lamps, control mechanisms, fixtures, service cable, and conduit to the point of, and with suitable terminals for, connection to the Company's underground or overhead distribution system, are installed, owned, maintained and operated by the Customer. Service is limited to the supply of energy only for the operation of traffic control signal lights. The installation of a meter to record actual energy consumption is required for all new traffic control signal lighting systems installed on or after June 1, 2004. For traffc control signal lighting systems installed prior to June 1, 2004 a meter may be installed to record actual usage upon the mutual consent of the Customer and the Company. MONTHLY CHARGE The monthly kWh of energy usage shall be either the amount estimated by the Company based on the number and size of lamps burning simultaneously in each signal and the average number of hours per day the signal is operated, or the actual meter reading as applicable. The Monthly Charge shall be computed at the following rate, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Energy Charge, per kWh 3.6384Ø PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 20 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, 10 Idaho Power Company Second Revised Sheet No. 26-1 Cancels Original Sheet No. 26-1I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 26 IDAHO POWER COMPANY ELECTRIC SERVICE RATE FOR MICRON TECHNOLOGY, INC. BOISE. IDAHO SPECIAL CONTRACT DATED SEPTEMBER 1, 1995 MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Monthly Contract Demand Charge $1.80 per kW of Scheduled Contract Demand Scheduled Monthly Contract Demand The Scheduled Monthly Contract Demand is 0 - 140,000 kW as per the contract with one year written notification. Monthly Biling Demand Charge $7.30 per kW of Billing Demand but not less than Scheduled Minimum Monthly Biling Demand. Minimum Monthly Billng Demand The Minimum Monthly Billing Demand wil be 25,000 kilowatts. Daily Excess Demand Charge $0.223 per each kW over the Contract Demand. The Daily Excess Demand Charge is applicable beginning January 1997 or once the Contract Demand reaches 100,000 kW, which ever comes first. Monthly Energy Charge 1.4872í per kWh Monthly 0 & M Charges Zero percent of total cost of Substation Facilities. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman.IPC Page 21 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company Second Revised Sheet No. 29-1 Cancels Original Sheet No. 29-1I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 29 IDAHO POWER COMPANY ELECTRIC SERVICE RATE FOR J. R. SIMPLOT COMPANY POCATELLO, IDAHO SPECIAL CONTRACT DATED JUNE 29, 2004 MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Contract Demand Charge $1.65 per kW of Contract Demand Demand Charge, $5.64 per kW of Billing Demand but no less than the Contract Demand less 5,000 kW Daily Excess Demand Charge $0.223 per each kW over the Contract Demand Energy Charge 1.4951 ø per kWh Monthly Facilities Charge 1.7% of the Company's investment in Distribution Facilities Exhibit NO.6 Case No. IPC-E-08-07 c. Schwendiman,lPC Page 22 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company Second Revised Sheet No. 30-1 Cancels Original Sheet No. 30-1I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 30 IDAHO POWER COMPANY ELECTRIC SERVICE RATE FOR UNITED STATES DEPARTMENT OF ENERGY IDAHO OPERATIONS OFFICE SPECIAL CONTRACT DATED MAY 16, 2006 CONTRACT NO. GS-OOP-99-BSD-0124 AVAILABILITY This schedule is available for firm retail service of electric power and energy delivered for the operations of the Department of Energy's facilities located at the Idaho National Engineering Laboratory site, as provided in the Contract for Electric Service between the parties. MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). 1.Demand Charge, per kW of Billing Demand $6.10 2.Energy Charge, per kWh 1.60231t SPECIAL CONDITIONS 1. Billing Demand. The Billing Demand shall be the average kW supplied during the 30- minute period of maximum use during the month. 2. Power Factor Adjustment. When the Power Factor is less than 95 percent during the 30-minute period of maximum load for the month, Company may adjust the measured Demand to determine the Billing Demand by multiplying the measured kW of Demand by 0.95 and dividing by the actual Power Factor. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendilnan, IPC Page 23 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company Second Revised Sheet No. 31-1 Cancels Original Sheet No. 31-1I.P.U.C. No. 29, Tariff No. 101 SCHEDULE 31 IDAHO POWER COMPANY AGREEMENT FOR SUPPLY OF STANDBY ELECTRIC SERVICE FOR THE AMALGAMATED SUGAR COMPANY MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Standby Contract Demand Charge, per kW of Standby Contract Demand $0.25 Standby Facilities Contract Demand Charge Per kW of Standby Facilities Contract Demand: Paul Facility: Nampa Facilty: Twin Falls Facility: $0.96 $0.98 $0.60 Standby Billing Demand Charge, per kW of Standby Billing Demand $2.47 Excess Demand Charge $0.50 per day for each kW taken in excess of the Total Contract Demand during the months of September through March $0.75 per day for each kW taken in excess of the Total Contract Demand during the months of April through August $5.00 per kW for the highest Excess Demand recorded during the Billing Period. (This charge will not be prorated.) Energy Charge Energy taken with Standby Demand will be priced at the applicable Schedule 19 Energy Charge. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 24 of 50 IDAHO Issued - April 15, 2008 Effective - June 1, 2008 Issued by IDAHO POWER COMPANY John R. Gale, Vice President, Regulatory Affairs 1221 West Idaho Street, Boise, ID Idaho Power Company l.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 1-2 SCHEDULE 1 RESIDENTIAL SERVICE (Continued) RESIDENTIAL SPACE HEATING All space heating equipment to be served by the Company's system shall be single-phase equipment approved by Underwriters' Laboratories, Inc., and the equipment and its installation shall conform to all National, State and Municipal Codes and to the following: Individual resistance-type units for space heating larger than 1,650 watts shall be designed to operate at 240 or 208 volts, and no single unit shall be larger than 6 kW. Heating units of 2 kW or larger shall be controlled by approved thermostatic devices. When a group of heating units, with a total capacity of more than 6 kW, is to be actuated by a single thermostat, the controlling switch shall be so designed that not more than 6 kW can be switched on or off at anyone time. Supplemental resistance- type heaters, that may be used with a heat exchanger, shall comply with the specifications listed above for such units. SUMMER AND NON.SUMMER SEASONS The summer season begins on June 1 of each year and ends on August 31 of each year. The non-summer season begins on September 1 of each year and ends on May 31 of each year. MONTHLY CHARGE The Monthly Charge is the sum of th.£€f¥k;e Charge, -tfle-rgharge, and the PO'Ner Cos Adjustment at the following-f charges~, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), Schedule 95 (Adjustment for Summer Non-summer Service Charge, per month $4.00 $4.00 Energy Charge, per kWh First 300 kWh All Additional kWh 5.6973Ø 6.4125Ø PowerCeAdjustment*-.~-.------.,24+Ø 5.6973Ø 5.6973Ø O.2419Ø *This Power Cost Adjustment is computed as provided in Schedule 55..-.--..Gf The monthly Minimum Charge shall be the sum of the Service Charge, the Energy Charge, and the PO'Ner Cost i\djustment.PAYMENT Exhibit NO.6 Case No. IPC.E-08.07 C. Schwendiman,lPC The monthly bill rendered for service supplied hereunder is payable upon receipt, and beco~e 25 of 50 past due 15 days from the date on which rendered. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 4-3 SCHEDULE 4 RESIDENTIAL SERVICE ENERGY WATCH PROGRAM (OPTIONAL) (Continued) MONTHLY CHARGES The Monthly Charge is the sum of the Service Charge,rgy-iJ,-a-#e Power Go Adjustment at the following i:charges, and may also include charges as set forth in Schedule 55 (Power Cost Adiustment), Schedule 91 (Energy Efficiency Rider), Schedule 95 (Adìustment for Municipal Franchise Fees). and Schedule 98 (Residential and Small Farm Energy Credit)~ Summer Non-summer Service Charge, per month $4.00 $4.00 Energy Charge, per kWh Energy Watch Event hours All other hours 20.0000a; 5.6973a; 0.2419$ n/a 5.6973a; ü,.24.t9;t.----.-.-PBWGotAdjustment*, per kWh-- PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case NO.IPC-E-08-07 C. Schwendiman,lPC Page 26 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 5-3 SCHEDULE 5 RESIDENTIAL SERVICE TIME-OF-DAY PROGRAM (OPTIONAL) (Continued) MONTHLY CHARGE The Monthly Charge is the sum of the Service Charge, the Energy Charge, and the Power Cost following~ charges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98 (Residential and Small Farm Energy Credit) Summer Non-summer Service Charge, per month $4.00 $4.00 Energy Charge, per kWh On-Peak Mid-Peak Off-Peak All Non-summer Hours 8.7443í 6.4125í 4.7402í n/a n/a n/a n/a 5.6973í *This P(iwer Cost.Ad~ßl:ted as previded În Schedule- The mofty~M~f.g-sfatl-be-um (if tRe-SeGehafge,~ PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 27 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 7-2 SCHEDULE 7 SMALL GENERAL SERVICE (Continued) MONTHLY CHARGE The Monthly Charge is the sum of the Servioe Charge, the Energy Charge, and the Pmver Cost Adjustment at the following ffcharges, and may also include charges as set forth in Schedule 55 (Power Cost Adiustment), Schedule 91 (Energy Effciency Rider), Schedule 95 (Adíustment for Municipal Franchise Fees), and Schedule 98 (Residential and Small Farm Energy Credit). Summer Non-summer Service Charge, per month $4.00 $4.00 Energy Charge, per kWh First 300 kWh All Additional kWh 6.9225Ø 7.7958Ø 6.9225Ø 6.9225Ø PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E.08-07 C. Schwendiman,lPC Page 28 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 9-2 SCHEDULE 9 LARGE GENERAL SERVICE (Continued) FACILITIES BEYOND THE POINT OF DELIVERY At the option of the Company, transformers and other facilities installed beyond the Point of Delivery to provide Primary or Transmission Service may be owned, operated, and maintained by the Company in consideration of the Customer paying a Facilities Charge to the Company. Company-owned Facilities Beyond the Point of Delivery will be set forth in a Distribution Faciliies Investment Report provided to the Customer. As the Company's investment in Facilities Beyond the Point of Delivery changes in order to provide the Customer's service requirements, the Company shall notify the Customer of the additions and/or deletions of facilities by forwarding to the Customer a revised Distribution Facilities Investment Report. In the event the Customer requests the Company to remove or reinstall or change Company- owned Facilities Beyond the Point of Delivery, the Customer shall pay to the Company the "non- salvable cost" of such removal, reinstallation or change. Non-salvable cost as used herein is comprised of the total original costs of materials, labor and overheads of the facilities, less the difference between the salvable cost of material removed and removal labor cost including appropriate overhead costs. POWER FACTOR Where the Customer's Power Factor is less than 90 percent, as determined by measurement under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand by multiplying the measured kW by 90 percent and dividing by the actual Power Factor. SUMMER AND NON-SUMMER SEASONS The summer season beings on June 1 of each year and ends on August 31 of each year. The non-summer season begins on September 1 of each year and ends on May 31 of each year. MONTHLY CHARGE The Monthly Charge is the sum of the Service, the Basic, the Demand, the Energy, the PO'Ner Cost Adjustment, and the Facilities Charges at the following rates: charges, and may also include charges as set forth in Schedule 55 (Power Cost Adíustment), Schedule 91 (Energy Effciency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98 (Residential and Small Farm Energy Credit). Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 29 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 9-3 SCHEDULE 9 LARGE GENERAL SERVICE (Continued) MONTHLY CHARGE (Continued) SECONDARY SERVICE Service Charge, per month Basic Charge, per kW of Basic Load Capacity First 20 kW All Additional kW Demand Charge, per kW of Billing Demand First 20 kW All Additional kW Energy Charge, per kWh First 2,000 kWh All Additional kWh Facilties Charge None. Summer $12.50 $0.00 $0.66 $0.00 $3.79 7.2016í 3.0854í Non-summer $12.50 $0.00 $0.66 $0.00 $3.14 6.4248í 2.7522í Demand Charge;-.tll.EHefI-Gaf§e,and-€-P~st; PRIMARY SERVICE Service Charge, per month Basic Charge, per kW of Basic Load Capacity Demand Charge, per kW of Billing Demand Energy Charge, per kWh Power Cost Adjustmont*, per kWh Summer $210.00 $0.94 $3.74 2.8073í O.2419Ø *This POINor Cest Adjustment is Gomputed as provided in Schedulo 55. Non-summer $210.00 $0.94 $3.13 2.5142í O.2419Ø Exhibit No.6 Case No. IPC.E.08-07 c. Schwendiman, IPC Page 30 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 9-4 SCHEDULE 9 LARGE GENERAL SERVICE (Continued) MONTHLY CHARGE (Continued) Facilities Charge. The Company's investment in Company-owned Facilities Beyond the Point of Delivery times 1.7 percent. TRANSMISSION SERVICE Summer Non-summer Service Charge, per month $210.00 $210.00 Basic Charge, per kW of Basic Load Capacity $0.49 $0.49 Demand Charge, per kW of Billing Demand $3.67 $3.06 Energy Charge, per kWh 2.7405í 2.4673í Power-Gst Adjustment*.__.~-O.2419~ Facilities Charge The Company's investment in Company-owned Facilities Beyond the Point of Delivery times 1.7 percent. The monthly Minimum Charge shall be the sum of the Service Charge, the Basic Charge, the G€ar4.GHge, the Energy Charge, the Power Cest AdftstffAt,aH4~liCharge. PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 31 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 15-2 SCHEDULE 15 DUSK TO DAWN CUSTOMER LIGHTING (Continued) NEW FACILITIES Where facilities of the Company are not presently available for a lamp installation which will provide satisfactory lighting service for the Customer's Premises, the Company may install overhead or underground secondary service facilities, including secondary conductor, poles, anchors, etc., a distance not to exceed 300 feet to supply the desired service, all in accordance with the charges specified below. MONTHLY CHARGE~ 1.Monthly Per Unit Charges on existing facilties: AREA LIGHTING High Pressure Average Base Sodium Vapor Lumens Rate 100 Watt 8,550 $ 6.17 200 Watt 19,800 $10.02 400 Watt 45,000 $16.01 FLOOD LIGHTING High Pressure Average Base Sodium Vapor Lumens Rate 200 Watt 19,800 $12.18 400 Watt 45,000 $18.18 Metal Halide 400 Watt 28,800 $20.32 1000 Watt 88,000 $37.05 $0.331403 POINer Cost Adiustment* $0.164492 $0.33140 ~.331403 $0.827298 *This Power Cost Adjustment is computed as provided in 80hedule 55. 2. For New Facilities Installed Before June 1, 2004: The Monthly Charge for New Facilties installed prior to June 1, 2004, such as overhead secondary conductor, poles, anchors, etc., shall be 1.75 percent of the estimated installed cost thereof. 3. For New Facilities Installed On or After June 1, 2004: The non-refundable charge for New Facilties to be installed, such as underground service, overhead secondary conductO¿åstii;l~g~~~~~ò~anchors, etc., shall be equal to the work order cost. C. Schwendiman, IPC Page 32 of 50 PAYMENT The monthly bill for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 19-3 SCHEDULE 19 LARGE POWER SERVICE (Continued) FACILITIES BEYOND THE POINT OF DELIVERY At the option of the Company, transformers and other facilities installed beyond the Point of Delivery to provide Primary or Transmission Service may be owned, operated, and maintained by the Company in consideration of the Customer paying a Facilities Charge to the Company. Company-owned Facilities Beyond the Point of Delivery will be set forth in a Distribution Facilities Investment Report provided to the Customer. As the Company's investment in Facilities Beyond the Point of Delivery changes in order to provide the Customer's service requirements, the Company shall notify the Customer of the additions and/or deletions of facilties by forwarding to the Customer a revised Distribution Facilities Investment Report. In the event the Customer requests the Company to remove or reinstall or change Company- owned Facilities Beyond the Point of Delivery, the Customer shall pay to the Company the "non- salvable cost" of such removal, reinstallation or change. Non-salvable cost as used herein is comprised of the total original costs of materials, labor and overheads of the facilities, less the difference between the salvable cost of material removed and removal labor cost including appropriate overhead costs. POWER FACTOR ADJUSTMENT Where the Customer's Power Factor is less than 90 percent, as determined by measurement under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand by multiplying the measured kW by 90 percent and dividing by the actual Power Factor. TEMPORARY SUSPENSION When a Customer has properly invoked Rule G, Temporary Suspension of Demand, the Basic Load Capacity, the Biling Demand, and the On-Peak Billing Demand shall be prorated based on the period of such suspension in accordance with Rule G. In the event the Customer's metered demand is less than 1,000 kW during the period of such suspension, the Basic Load Capacity and Billing Demand will be set equal to 1,000 kW for purposes of determining the Customer's mMonthly Mfl:Charge. MONTHLY CHARGE The Monthly Charge is the sum of the Service, the Basic, the Demand, the Energy, the PO'ller Cost Adjustment, and the Facilities Charges at the following facharges, and may also include charges as set forth in Schedule 55 (Power Cost Adíustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 33 of 50 Idaho Power Company I.P.U.C. No. 29. Tariff No. 101 Original Sheet No. 19-4 SCHEDULE 19 LARGE POWER SERVICE (Continued) MONTHL Y CHARGE (Continued) SECONDARY SERVICE Summer Non-summer Service Charge, per month $12.50 $12.50 Basic Charge, per kW of Basic Load Capacity $0.66 $0.66 Demand Charge, per kW of Billing Demand $3.36 $3.14 On-Peak Demand Charge, per kW of On-Peak Billing Demand $0.43 n/a Energy Charge, per kWh On-Peak 3.35751t n/a Mid-Peak 3.18991t 2.86991t Off-Peak 2.97311t 2.7401 It Facilities Charge None. The monthly Minimum Charge shall be the sum of the Service Charge, the Basic Charge, the Demand Charge, the On Peak Demand Charge, the Energy Charge and the Power Cost Adjustment. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 34 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 19-5 SCHEDULE 19 LARGE POWER SERVICE (Continued) MONTHLY CHARGE (Continued) PRIMARY SERVICE Summer Non-summer Service Charge, per month Basic Charge, per kW of Basic Load Capacity $210.00 $0.94 $210.00 $0.94 Demand Charge, per kW of Billing Demand $3.31 $3.13 On-Peak Demand Charge, per kW of On-Peak Billing Demand $0.43 n/a Energy Charge, per kWh On-Peak Mid-Peak Off-Peak 2.8708Ø 2.5915Ø 2.4153Ø n/a 2.3445Ø 2.2368Ø Facilities Charge The Company's investment in Company-owned Facilities Beyond the Point of Delivery times 1.7 percent. Minimym Charge The monthly Minimum Charge shall be tho sum of the Servico Charge, the Basic Charge, the Demand Charge, the On Peak Demand Charge tho Energy Charge, the Power Cest MjHment, and the FaGfli4e-~ Exhibit No.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 35 of 50 Idaho Power Company l.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 19-6 SCHEDULE 19 LARGE POWER SERVICE (Continued) MONTHL Y CHARGE (Continued) TRANSMISSION SERVICE Summer Non-summer Service Charge, per month $210.00 $210.00 Basic Charge. per kW of Basic Load Capacity $0.49 $0.49 Demand Charge. per kW of Billing Demand $3.24 $3.06 On-Peak Demand Charge, per kW of On-Peak Billing Demand $0.43 n/a Energy Charge, per kWh On-Peak 2.84261t n/a Mid-Peak 2.56551t 2.31641t Off-Peak 2.39131t 2.21001t Facilities Charge The Company's investment in Company-owned Facilities Beyond the Point of Delivery times 1.7 percent. Minimum Charge The monthly Minimum Charge shall be the sum of the Service Charge, the Basic Charge, the Demand Charge, the On Peak Demand Charge. the Energy Charge. the Power Cost Adjustment, and tRe Facilities C~ PAYMENT The monthly bil for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC.E.08-07 C. Schwendiman, IPC Page 36 of 50 Idaho Power Gompany I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 24-3 SCHEDULE 24 AGRICULTURAL IRRIGATION SERVICE (Continued) MONTHLY CHARGE The Monthly Charge is the sum of the Service, the Demand, the Energy, the Pewer Cost AGstment,-aG-thB-ilties Glafs-hefollowing facharges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98 (Residential and Small Farm Energy Credit) SECONDARY SERVICE In-Season Out-of-Season Service Charge, per month $15.00 $3.00 Demand Charge. per kW of Billing Demand $ 4.61 $0.00 Energy Charge. per kWh 3.5894í 4.5690í Facilities Charge None. Energy. Chage, and the Powefost Adjustment. TRANSMISSION SERVICE In-Season Out-of-Season Service Charge. per month $210.000 $3.00 Demand Charge, per kW of Billing Demand Energy Charge, per kWh 3.4144í O.24:W $0.00 4.3463í O.2419~ $ 4.33 Power Cost Adjustment*, per kWh *This Power Cost Adjustment is computed as provided in Schedule 55. Facilities Charge Exhibit NO.6 The Company's investment in Company-owned Facilties Beyond the Point of Delivery t~§;Jst7~~~t~¿percent. . Page 37 ~f 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 39-1 SCHEDULE 39 STREET LIGHTING SERVICE SUPPLEMENTAL SEASONAL OR VARIABLE ENERGY AVAILABILITY Service under this schedule is available throughout the Company's service area within the state of Idaho to Customers who were receiving Customer-owned Non-Metered Service under Schedule 41 prior to June 1, 2004. Eligible Customers may continue to receive supplemental energy service under this schedule until there is no potential for seasonal or variations in usage from the street lighting service, or street lighting service is converted to Metered Service under Schedule 41, or May 31, 2011, whichever is sooner. This schedule will expire on May 31,2011. APPLICABILITY Service under this schedule is applicable to seasonal or variable energy service utilized by municipalities or agencies of federal, state, or county governments through wired outlets or useable plug-ins on a Customer-owned street lighting fixture. Service under this schedule is apart from and supplemental to the street lighting service received under Schedule 41. SERVICE CONDITIONS Each Customer who takes supplemental service under this schedule must have the Company ascertain the estimated annual number of kWh used as seasonal or variable usage. MONTHLY CHARGE The estimated annual kWh of energy usage is divided by 12 to determine the estimated monthly kWh of energy usage. The Monthly Charge shall be computed at the following rates;, and may also Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Energy Charge, per estimated monthly kWh 5.6850Ø .Q.2419ØPO'ver Cost-A~~estimated monthly kWh *This Pmver Cost Adjustment is computed as provided in Schedule 55. PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC.E-08-07 C. Schwendiman,lPC Page 38 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 40-2 SCHEDULE 40 UNMETERED GENERAL SERVICE (Continued) MONTHLY CHARGE The average monthly kWh of energy usage shall be estimated by the Company, based on the Customer's electric equipment and one-twelfth of the annual hours of operation thereof. Since the service provided is unmetered, failure of the Customer's equipment will not be reason for a reduction in the Monthly Charge. The Monthly Charge shall be computed at the following rate.;, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Energy Charge, per kWh 5.6850Ø Minimum Charge, per month. The monthly Minimum CJar.g-&be the sm-of-thB Energy Charge and the Pmver Cost ,Adjustment, but not less than $1.50. PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman.IPC Page 39 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 41-2 SCHEDULE 41 STREET LIGHTING SERVICE (Continued) ACCELERATED REPLACEMENT OF EXISTING FIXTURES In the event a Customer requests the Company perform an accelerated replacement of existing fixtures with the cut-off fixture, the following charges will apply: 1. The actual labor, time, and mileage costs incurred by the Company for the removal of the existing street lighting fixtures. 2. $65.00 per fixture removed from service. The total charges identified in 1 and 2 above must be paid prior to the beginning of the fixture replacement and are non-refundable. The accelerated replacement will be performed by the Company during the regularly scheduled working hours of the Company and on the Company's schedule. MONTHLY CHARGE~ High Pressure Average Base Sodium Vapor Lumens Rate 70 Watt 5,540 $ 7.45 -------OJJ-r 100 Watt 8,550 $ 6.72 $0.099179 200 Watt 19,800 $ 7.86 250 Watt 24,750 $ 8.88 $002545+ê 400 Watt 45,000 $11.18 $0.401554 *This Povver Cost Adjustment is computed as provided in Schedule 55. ADDITIONAL MONTHLY RATEPo!e Charges For Company-owned poles installed after October 5, 1964 required to be used for street lighting only: Charge Wood pole, per pole Steel pole, per pole $1.81 $7.18 Facilities Charges Customers assessed a monthly facilities charge prior to June 1, 2004 for the installation f)ibit NO.6 underground circuits wil continue to be assessed a monthly facilities charge equaPc~c:ttJ2~~~~i6 percent of the estimated cost difference between overhead and underground circuits. Page 40 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 41-3 SCHEDULE 41 STREET LIGHTING SERVICE (Continued) "B" - CUSTOMER-OWNED SYSTEM The Customer's lighting system, including posts or standards, fixtures, initial installation of lamps and underground cables with suitable terminals for connection to the Company's distribution system, is installed and owned by the Customer. Customer-owned systems installed on or after June 1,2004 which are constructed, operated, or modified in such a way as to allow for the potential or actual variation in energy usage, such as through, but not limited to, the use of wired outlets or useable plug-ins, are required to be metered in order to record actual energy usage. Customer-owned systems installed prior to June 1, 2004 that are constructed, operated, or modified in such a way as to allow for the potential or actual variation in energy usage may have the estimated annual variations in energy usage served under Schedule 39 until its expiration on May 31, 2011, or until the street lighting system is converted to Metered Service, or until the potential for variations in energy usage has been eliminated, whichever is sooner. Effective June 1, 2011 all Customer-owned street lighting systems that have the potential for variations in energy usage must be metered. ENERGY AND MAINTENANCE SERVICE Energy and Maintenance Service includes operation of the system, energy, lamp renewals, cleaning of glassware, and replacement of defective photocells which are standard to the Company- owned street light units. Service does not include the labor or material cost of replacing cables, standards, broken glassware or fixtures, painting, or refinishing of metal poles. Individual lamps will be replaced on burnout as soon as reasonably possible after notification by the Customer and subject to the Company's operating schedules and requirements. ENERGY-ONLY SERVICE Energy-Only Service is available only to a metered lighting system. Service includes energy supplied from the Company's overhead or underground circuits and does not include any maintenance to the Customer's facilities. A street lighting system receiving service under the Energy-Only Service offering is not eligible to transfer to any street lighting service option under this schedule that includes maintenance provisions to the Customer's facilities. MONTHLY CHARGE& The monthly charges are as follows, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Non-Metered Service (With Maintenance), per lamp High Pressure Sodium Vapor 70 Watt 100 Watt 200 Watt 250 Watt Average Lumens 5,450 8,550 19,800 24,750 Base Rate $3.19 $3.63 $5.03 $6.01 Power Cost Adjustment* $0.070151 $0.099179 $0.193520 $0.251576 Exhibit NO.6 Case No. IPC-E-QS-07 C. Schwendiman, IPC Page 41 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 400 Watt Original Sheet No. 41-345,000 $8.33 $0.401554 Exhibit NO.6 Case No. IPC-E-QS-07 C. Schwendiman. IPC Page 42 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 41-4 SCHEDULE 41 STREET LIGHTING SERVICE (Continued) MONTHLY CHARGE~ (Continued) Metered Service (With Maintenance), per lamp High Pressure Sodium Vapor 70 Watt 100 Watt 200 Watt 250 Watt 400 Watt $2.06 $1.84 $1.89 $1.84 $1.87 $8.45 4.9139Ø Meter Charge, per meter Energy Charge, per kWh Metered Energy-Only Service (No Maintenance) Meter Charge, per meter $8.45 4.9139ØEnergy Charge, per kWh PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, LPC Page 43 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 41-6 SCHEDULE 41 STREET LIGHTING SERVICE (Continued) NO NEW SERVICE "B" - ORNAMENTAL LIGHTING - CUSTOMER-OWNED SYSTEM (Continued) ENERGY AND MAINTENANCE SERVICE Energy and Maintenance Service includes operation of the system, energy, lamp renewals, cleaning of glassware, and replacement of defective photocells which are standard to the Company- owned street light units. Service does not include the labor or material cost of replacing cables, standards, broken glassware or fixtures, or painting or refinishing of metal poles. Individual lamps wil be replaced on burnout as soon as reasonably possible after notification by the Customer and subject to the Company's operating schedules and requirements. ENERGY-ONLY SERVICE Energy-Only Service is available only to a metered lighting system. Service includes energy supplied from the Company's overhead or underground circuits and does not include any maintenance to the Customer's facilties. A street lighting system receiving service under the Energy-Only Service offering is not eligible to transfer to any street lighting service option under this schedule that includes maintenance provisions to the Customer's facilities. MONTHLY CHARGES Non-Metered Service (With mMaintenance), per lamp Average BaseLumens Rate Mercury Vapor 175 Watt 400 Watt Power Cost Ad í ustrne¡ 7,654 19,125 $ 5.50 $ 8.69 $0.169330 $0.394297 Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 44 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 41-7 SCHEDULE 41 STREET LIGHTING SERVICE (Continued) NO NEW SERVICE MONTHLY CHARGES (Continued) Metered Service (With Maintenance), per lamp Mercury Vapor 175 Watt 400 Watt $1.90 $1.97 $8.45 4.9139Ø Meter Charge, per meter Energy Charge, per kWh --ler Cost Adjustment*,tJer kWh ~ Metered Energy-Only Service (No Maintenance) Meter Charge, per meter $8.45 4.9139ØEnergy Charge, per kWh PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 45 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 42-1 SCHEDULE 42 TRAFFIC CONTROL SIGNAL LIGHTING SERVICE APPLICABILITY Service under this schedule is applicable to Electric Service required for the operation of traffic control signal lights within the State of Idaho. Traffc control signal lamps are mounted on posts or standards by means of brackets, mast arms, or cable. CHARACTER OF SERVICE The traffc control signal fixtures, including posts or standards, brackets, mast arm, cable, lamps, control mechanisms, fixtures, service cable, and conduit to the point of, and with suitable terminals for, connection to the Company's underground or overhead distribution system, are installed, owned, maintained and operated by the Customer. Service is limited to the supply of energy only for the operation of traffic control signal lights. The installation of a meter to record actual energy consumption is required for all new traffc control signal lighting systems installed on or after June 1, 2004. For traffic control signal lighting systems installed prior to June 1, 2004 a meter may be installed to record actual usage upon the mutual consent of the Customer and the Company. MONTHLY CHARGE& The monthly kWh of energy usage shall be either the amount estimated by the Company based on the number and size of lamps burning simultaneously in each signal and the average number of hours per day the signal is operated, or the actual meter reading as applicable. The Monthly Charge Energy Charge, per kWh 3.6384st O.24191tPO'Ner Cost Adjustment", per kVVh "This Pei"Jer Cost Adjustment is computed as provided in Schedule 55. PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 46 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 26-1 SCHEDULE 26 IDAHO POWER COMPANY ELECTRIC SERVICE RATE FOR MICRON TECHNOLOGY, INC. BOISE. IDAHO SPECIAL CONTRACT DATED SEPTEMBER 1, 1995 The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Effciency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). MONTHL~f"""l-rv\'v! Ut:!VIl'd'IU'v1 Monthly Contract Demand Charge $1.80 per kW of Scheduled Contract Demand ~DULED MONTHLY GQNTRACT DEM/\NDScheduled Monthly Contract Demand -._- The Scheduled Monthly Contract Demand is 0 - 140,000 kW as per the contract with one year written notification. MGN.:i¥..bfNG DEMAN~Monthly Billing Demand Charge $7.30 per kW of Billing Demand but not less than Scheduled Minimum Monthly Billing Demand. MINiMUM-MQ¥-~lllNG DéMANDMinimum Monthly Biling Demand The Minimum Monthly Biling Demand will be 25,000 kilowatts. QA¥.EXG~S..QEMAQ.CHARGEDaily Excess Demand Charge $0.223 per each kW over the Contract Demand. The Daily Excess Demand Charge is applicable beginning January 1997 or once the Contract Demand reaches 100,000 kW, which ever comes first. MONTHL¥ ENERGY CHARGE Monthly Energy Charge 1.4872il per kWh *This Power Cest Adjustmont is computed as provided in Schedule 55. MONTHLY 0 &. M CHti,RGESMonthly 0 & M Charges Zero percent of total cost of Substation Facilties. Exhibit NO.6 Case No. IPC..E-08-07 C. Schwendiman,lPC Page 47 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 29-1 SCHEDULE 29 IDAHO POWER COMPANY ELECTRIC SERVICE RATE FOR J. R. SIMPLOT COMPANY POCATELLO, IDAHO SPECIAL CONTRACT DATED JUNE 29, 2004 MONTHLY CHARGES Contract Demand Charge $1.65 per kW of Contract Demand Demand Charge, $5.64 per kW of Billing Demand but no less than the Contract Demand less 5,000 kW Daily Excess Demand Charge $0.223 per each kW over the Contract Demand Energy Charge 1.4951Ø per kWh _....-~4+9f3ef-*W1l Monthly Facilities Charge 1.7% of the Company's investment in Distribution Facilities Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 48 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 30-1 SCHEDULE 30 IDAHO POWER COMPANY ELECTRIC SERVICE RATE FOR UNITED STATES DEPARTMENT OF ENERGY IDAHO OPERATIONS OFFICE SPECIAL CONTRACT DATED MAY 16, 2006 CONTRACT NO. GS-OOP-99-BSD-0124 AVAILABILITY This schedule is available for firm retail service of electric power and energy delivered for the operations of the Department of Energy's facilities located at the Idaho National Engineering Laboratory site, as provided in the Contract for Electric Service between the parties. MONTHLY CHARGE 1.Demand Charge, per kW of Billing Demand $6.10 2.Energy Charge, per kWh 1.6023\C ---.-*-TI=-eer Cost Mjment is-Bomputed as provd-f.-Seewe- SPECIAL CONDITIONS 1. Billing Demand. The Billing Demand shall be the average kW supplied during the 30- minute period of maximum use during the month. 2. Power Factor Adjustment. When the Power Factor is less than 95 percent during the 30-minute period of maximum load for the month, Company may adjust the measured Demand to determine the Billng Demand by multiplying the measured kW of Demand by 0.95 and dividing by the actual Power Factor. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 49 of 50 Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 31-1 SCHEDULE 31 IDAHO POWER COMPANY AGREEMENT FOR SUPPLY OF STANDBY ELECTRIC SERVICE FOR THE AMALGAMATED SUGAR COMPANY MONTHLY CHARGES forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energv Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Standby Contract Demand Charge, per kW of Standby Contract Demand $0.25 Standby Faciliies Contract Demand Charge Per kW of Standby Facilities Contract Demand: Paul Facility: Nampa Facility: Twin Falls Facility: $0.96 $0.98 $0.60 Standby Billing Demand Charge, per kW of Standby Billing Demand $2.47 Excess Demand Charge $0.50 per day for each kW taken in excess of the Total Contract Demand during the months of September through March $0.75 per day for each kW taken in excess of the Total Contract Demand during the months of April through August $5.00 per kW for the highest Excess Demand recorded during the Billing Period. (This charge will not be prorated.) Energy Charge Energy taken with Standby Demand wil be priced at the applicable Schedule 19 Energy Charge. Exhibit NO.6 Case No. IPC-E-08-07 C. Schwendiman, IPC Page 50 of 50