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Home My WebLink About20110602Youngblood Di, Exhibits.pdfRECEIVED 2011JUN-l PM ~ BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION IN THE MATTER OF THE APPLICATION OF I DAHO POWER COMPANY FOR AUTHORITY TO INCREASE ITS RATES AND CHARGES FOR ELECTRIC SERVICE TO ITS CUSTOMERS IN THE STATE OF IDAHO. CASE NO. IPC-E-II-08 IDAHO POWER COMPANY DIRECT TESTIMONY OF MICHAEL J. YOUNGBLOOD 1 Q.Please state your name and business address. 2 A.My name is Michael J. Youngblood. My business 3 address is 1221 West Idaho Street, Boise, Idaho. 4 Q.By whom are you employed and in what capacity? 5 A.I am employed by Idaho Power Company (~Idaho 6 Power" or ~Company") as the Manager of Rate Design in the 7 Regulatory Affairs Department. 8 Q .Please describe your educational background. 9 A.In May of 1977, I received a Bachelor of 10 Science Degree in Mathematics and Computer Science from the 11 University of Idaho. From 1994 through 1996, I was a 12 graduate student in the Executive MBA program of Colorado 13 State University. Over the years, I have attended numerous 14 industry conferences and training sessions, including 15 Edison Electric Institute' s ~Electric Rates Advanced 16 Course. " 17 Q.Please describe your work experience with 18 Idaho Power Company. 19 A.I began my employment with Idaho Power in 20 1977. During my career, I have worked in several 21 departments and subsidiaries of the Company, including 22 Systems Development, Demand Planning, Strategic Planning 23 and IDACORP Solutions. Most relevant to this testimony 24 though is my experience within the Regulatory Affairs 25 Department. From 1981 to 1988, I worked as a Rate Analyst YOUNGBLOOD, DI 1 Idaho Power Company 1 in the Rates and Planning Department where I was 2 responsible for the preparation of electric rate design 3 studies and bill frequency analyses. I was also 4 responsible for the validation and analysis of the load 5 research data used for cost of service allocations. 6 From 1988 through 1991, I worked in Demand Planning 7 and was responsible for the load research and load 8 forecasting functions of the Company, including sample 9 design, implementation, data retrieval, analysis, and 10 reporting. I was responsible for the preparation of the 11 five-year and twenty-year load forecasts used in revenue 12 proj ections and resource plans as well as the presentation 13 of these forecasts to the public and regulatory 14 commissions. 15 In 2001, I returned to the Regulatory Affairs 16 Department and have worked on special projects related to 17 deregulation, the Company's Integrated Resource Plan, and 18 filings with both the Idaho Public Utilities Commission 19 (~IPUC" or ~Commission") and the Oregon Public Utility 20 Commission (~OPUC"). 21 In 2008, I was promoted to my current position of 22 Manager of Rate Design for Idaho Power. It is in this 23 position that I am currently responsible for the management 24 of the rate design strategies of the Company as well as the 25 oversight of all tariff administration. YOUNGBLOOD, DI 2 Idaho Power Company 1 Q.What is the purpose of your testimony in this 2 matter? 3 A.In my testimony, I describe the overall 4 obj ecti ves I provided Senior Regulatory Analysts, Ms. 5 Darlene Nemnich and Mr. Scott Sparks, for the development 6 of the Company's proposed rate design strategy for the 7 tariff schedules. With regard to the Company's direction 8 and future development of time variant pricing options for 9 residential customers, I will preview the Company's plans 10 for a new pilot to be proposed as a modification and 11 expansion of the time variant pricing options currently 12 offered to residential customers in the Emmett/Letha area. 13 For the Company's special contract customers, I will 14 address the Company's proposed rates and rate designs for 15 Micron Technology, Inc. (~Micron"), the J. R. Simplot 16 Company (~Simplot"), the United States Department of Energy 17 Idaho Operations Office (~DOE/INL"), and Hoku Materials, 18 Inc. (~Hoku"). 19 Lastly, I will discuss the derivation of the Fixed 20 Cost per Customer (~FCC") and Fixed Cost per Energy (~FCE") 21 rates to be used in determining the annual adjustment under 22 Schedule 54, Fixed Cost Adjustment (~FCA"). The FCA 23 discussion will culminate with the Company's proposal to 24 remove the temporary ~pilot" status of Schedule 54 and 25 convert the FCA to an ongoing, permanent tariff schedule. YOUNGBLOOD, DI 3 Idaho Power Company 1 I . RATE DESIGN OBJECTIVES 2 Q.What are the Company's overall obj ecti ves with 3 regard to its rate design strategy? 4 A.The Company's rate designs are developed to 5 recover the revenue requirement targets provided by Mr. 6 Matthew T. Larkin for each customer class and special 7 contract customer. In doing so however, the Company 8 continues to maintain two primary obj ecti ves with regard to 9 rate design:(1) to establish prices that primarily 10 reflect the costs of the services provided, and (2) to have 11 cost-based rate proposals designed to align with and 12 encourage energy efficiency. 13 Q.Is the Company proposing major rate design 14 modifications with this filing? 15 A.No, the Company is not proposing maj or rate 16 design changes with this filing. In the Company's last 17 filed general rate case, Case No. IPC-E-08-10, the 18 Commission authorized several significant rate design 19 changes, including a three-tiered rate structure for 20 residential customers for the summer and non-summer months, 21 the addition of non-summer tiered rates for small general 22 service customers, time-of-use rates for the large general 23 service class, and the introduction of load factor pricing 24 for the irrigation class.The Company's rate design 25 proposals are based upon these prior changes with only YOUNGBLOOD, DI 4 Idaho Power Company 1 minor modifications. This approach will provide the 2 Company's customers with rate design stability and billing 3 continui ty. 4 Q.Because the Company is not proposing maj or 5 rate design modifications in this filing, does that mean 6 the Company is proposing to modify all billing components 7 by the same percentage increase? 8 A.No. If all billing components were increased 9 by the same uniform percentage without consideration of the 10 cost-of-service unit costs, then some billing units would 11 move further away from their actual unit cost of service, 12 contrary to the Company's obj ecti ve of moving toward cost- 13 based rate designs. 14 Q.What rate design changes is the Company 15 proposing with this filing? 16 A.For most of the Company's tariff schedules, 17 the Company is proposing to leave the current rate design 18 structure in place, while adjusting each of the billing 19 components to move incrementally closer to their cost-of- 20 service and recover the revenue assigned to each class. 21 However, there are a few notable exceptions. 22 For the Schedule 1, Residential Service, the Company 23 is proposing to retain the current three-tiered rate 24 design. However, I have directed Ms. Nemnich to provide a 25 residential rate design proposal that minimizes the impact YOUNGBLOOD, DI 5 Idaho Power Company 1 of any rate change on the third-tier customers in the non- 2 summer months. 3 Q.Why did you direct Ms. Nemnich to minimize the 4 impact of any rate change on third-tier customers during 5 the non-summer months? 6 A.Idaho Power continues to be a summer peaking 7 utili ty wi th its highest system peak occurring during the 8 summer months. It is appropriate to send a higher price 9 signal to encourage customers to use energy more 10 efficiently during the summer peak months. However, I 11 directed Ms. Nemnich to minimize the impact of any rate 12 change to third-tier customers during the non-summer months 13 primarily in response to the lessons learned by both the 14 Commission Staff and the Company following the 15 implementation of the three-tier rate design in 2009. 16 Q.What lessons were learned following the 17 implementation of the non-summer three-tier rate design? 18 A.During the winter of 2009, the Company and the 19 Commission received record numbers of high bill complaints 20 from customers. In response to these record numbers of 21 complaints, both the Company and the Commission Staff 22 independently, and together, began investigating the root 23 causes of the complaints. There were a number of 24 explanations for the high bill complaints, including a 25 YOUNGBLOOD, DI 6 Idaho Power Company 1 number of prior rate increases compounded by a record cold 2 snap in December. 3 The investigation revealed that the high bill 4 complaints were not just from the ~McMansions" or large 5 scale homes in the Treasure Valley, but from customers 6 throughout our service terri tory, regardless of income, 7 customer's age, premise type, employment class, ownership 8 status, or size of household. In fact, the one 9 differentiation that was significant in determining whether 10 or not a customer was more at risk of having a high bill 11 was whether they lived in a suburban city or a rural town. 12 Q.Why does living in a rural town increase a 13 customer's risk of experiencing high electric bills? 14 A.In most rural settings, alternate fuels, 15 primarily natural gas, are not readily available. The 16 Company's all-electric customers were affected the most. 17 Q.Shouldn't all-electric customers who have 18 large monthly loads, receive the higher price signal of a 19 three tier structure in order to provide the customer with 20 an incentive to reduce their consumption? 21 A.Not necessarily. In fact, many all-electric 22 homes who heat with electricity may experience their 23 greatest use during the winter evenings and nights, at a 24 time when the Company's costs to serve that load are lower 25 than during peak hours. Unlike customers who may better be YOUNGBLOOD, DI 7 Idaho Power Company 1 able to manage their electric use during the summer months 2 by reducing their air conditioning load during peak load, 3 high cost times, the non-summer high-use customers may have 4 less discretion to dramatically reduce their usage. 5 Customers who were owners of all-electric homes felt the 6 Company was now penalizing them for their electric use at 7 times when production costs weren't necessarily high. 8 Consequently, I have directed Ms. Nemnich to propose a 9 residential rate design that would continue to send the 10 price signals to use energy efficiently, but to minimize 11 the rate change impact to the third tier during the non- 12 summer months. 13 Q.Have you provided any other guidance for the 14 development of the Company's tariff schedules? 15 A.Yes. In response to customer needs resulting 16 from the availability of new and enhanced street lighting 17 technologies, I directed Mr. Sparks to investigate 18 revamping the Company's lighting schedules. As a result of 19 his investigation, Mr. Sparks will be proposing some 20 additional provisions and options for customers taking 21 service under Schedule 41, Street Lighting Service. In 22 addi tion, as part of the Company's annual review of its 23 facilities charges, I have directed Mr. Sparks to update 24 the Company's facilities charges as appropriate. The 25 YOUNGBLOOD, DI 8 Idaho Power Company 1 impact of these adjustments has been included in the 2 Company's overall revenue determination. 3 And lastly, in preparation for an extended offering 4 of a time variant pricing (~TVP") option, I have directed 5 Ms. Nemnich to update our current time-of-day and critical 6 peak pricing schedules to provide year-round TVP options to 7 be more consistent in design with current industry 8 standards. 9 II. FUTU PLAS FOR TIME VARIENT PRICING OPTIONS 10 Q. What are the Company's plans to expand the 11 time variant pricing alternatives now available to 12 customers in Emmett and Letha? 13 A.Since the Company first offered a TVP option 14 to its customers in the Emmett/Letha area on a pilot basis, 15 the Company has anticipated that the knowledge gained from 16 the initial pilot may one day be expanded and offered to 17 more customers system-wide. However, there are two maj or 18 projects which must be completed before TVP options can be 19 offered across the Company's system. First, implementation 20 of the Company's Advanced Metering Infrastructure (~AMI") 21 smart meters must be installed in order for customers to 22 take advantage of time variant rates.Idaho Power's three 23 year AMI implementation project is on track to finish the 24 meter installations by the end of 2011. Second, all of the 25 back office infrastructure must be updated and implemented, YOUNGBLOOD, DI 9 Idaho Power Company 1 including a new Customer Information System (~CIS") and 2 enterprise data warehouse as described in Mr. Warren 3 Kline's testimony. It is estimated that this work will be 4 completed by early in the year 2013. 5 Q.Does this mean Idaho Power will not be able to 6 expand its TVP offerings until mid 2013? 7 A.No. Idaho Power anticipates offering the TVP 8 options as an expanded pilot to additional customers 9 outside of the Emmett Valley next year. It is indeed in 10 anticipation of such an expanded offering that the Company 11 is making the changes to the current Schedules 4 and 5 with 12 this filing. 13 Q.How does the Company propose to transition the 14 customers who are currently taking service under the 15 Company's Schedule 4, Energy Watch and Schedule 5, Time-of- 16 Day pricing options? 17 A.The Company's proposal is for the customers 18 who are currently taking service under the existing 19 Schedules 4 and 5 be moved to Schedule 1 following the 2011 20 summer season. Schedules 4 and 5 rates and rate structures 21 for the non-summer months are identical to that of Schedule 22 1, therefore the customers' bills would not be adversely 23 affected in any way. Prior to the summer season of 2012, 24 the Emmett customers will have the opportunity to fully 25 evaluate the revised TVP rate structures, and will be able YOUNGBLOOD, DI 10 Idaho Power Company 1 to move back to a time-of-day or critical peak pricing 2 option if they so desire. Company representatives will be 3 available to assist the customers in understanding the new 4 pricing structure and answer any questions they may have. 5 Q.Why is the Company proposing these changes now 6 to the Energy Watch and Time-of-Day pricing options? 7 A.Idaho Power envisions the proposed Schedules 4 8 and 5 to be the foundational time variant pricing options 9 that will be offered to residential customers when an 10 expanded pilot is rolled out. With these changes in place, 11 the Company anticipates offering TVP options to a greater 12 number of participants as an expanded pilot in 2012. The 13 Company anticipates making a separate filing prior to that 14 time explaining the details of the proposed pilot. While 15 the pilot would be expanded from the current geographical 16 limit of the Emmett Valley, it would still be limited in 17 numbers pending the completion of the implementation of the 18 required infrastructure needed to support a larger 19 offering. 20 III. SPECIAL CONTRACT CUSTOMERS 21 Q.What are the Company's rate design proposals 22 for the Special Contract customers? 23 A.The Company is proposing to maintain the 24 current rate structures for the Special Contract customers 25 of Micron, Simplot, and Hoku. Accordingly, the existing YOUNGBLOOD, DIll Idaho Power Company 1 rates for the Special Contract customers Micron and Simplot 2 are simply increased uniformly by 14.85 percent to recover 3 the revenue requirement shown on Mr. Larkin's Exhibit No. 4 38. The Company's proposed rates for each of the Special 5 Contract customers are shown in Exhibit No. 43. 6 For Hoku, consistent with its current contract, the 7 First Block Contract Demand Charge and Energy Charge are 8 fixed and not subj ect to change. The Second Block Charges 9 increase or decrease uniformly with any base rate change 10 authorized by the Commission that is applicable to Idaho 11 Power's Tariff Schedule 19T customers. Consequently, Idaho 12 Power proposes that Hoku's Second Block Demand and Energy 13 Charges be increased by 14.84 percent, consistent with 14 Schedule 19T. 15 The Company and the DOE/INL, at the time of this 16 filing, are negotiating a new special contract. On March 17 9, 2011, the Commission issued Order No. 32199 in Case No. 18 IPC-E-11-02 approving a 120-day extension continuing the 19 existing contract until September 14, 2011. In 20 anticipation that a special contract with DOE/INL will be 21 completed and approved by this Commission by September 14, 22 2011, the Company has developed rates for the DOE to 23 recover $8,799,100, as shown on Mr. Larkin's Exhibit No. 24 38. This represents a 14.85 percent increase over current 25 rates. However, contract negotiations are still ongoing, YOUNGBLOOD, DI 12 Idaho Power Company 1 and Idaho Power has not yet finalized a specific rate 2 design for DOE/INL. Regardless of the final rate design, 3 the amount of revenue required from DOE/INL will not be 4 different from that proposed in this case. Once a new rate 5 design is finalized for the DOE/INL contract, the parties 6 will submit the new design as the final rate design in this 7 case. 8 iv. FIXED COST ADJUSTMNT 9 Q.Please describe the Fixed Cost Adj ustment 10 (~FCA") mechanism. 11 A.The FCA is a rate mechanism that is designed 12 to remove the financial disincentive to utility acquisition 13 of demand-side management resources. The mechanism 14 accomplishes this goal by severing the link between energy 15 sales and the recovery of fixed costs. Currently, the FCA 16 applies only to Residential Service (Schedules 1, 3, 4, and 17 5) and Small General Service (Schedule 7). The annual FCA 18 amount is determined according to the following formula: 19 FCA = (CUST X FCC) - (NORM X FCE) 20 Where: 21 FCA = Fixed Cost Adj ustment; 22 CUST = Actual number of customers, by class; 23 FCC = Fixed Cost per Customer, by class; 24 NORM = Weather-normalized energy, by class; 25 FCE = Fixed Cost per Energy, by class. YOUNGBLOOD, DI 13 Idaho Power Company 1 Q.What values are required to calculate the FCA 2 amount annually? 3 A.As outlined in the above formula, for each 4 class (Residential Service and Small General Service), the 5 actual number of customers (~CUST"), the fixed cost per 6 customer (~FCC"), weather-normalized energy (~NORM"), and 7 the Fixed Cost per Energy (~FCE") are required to determine 8 the FCA amount. Two of these variables (CUST and NORM) are 9 determined at the end of each year based upon the Company's 10 actual billing records. The other two variables (FCC and 11 FCE) are updated each time the Company files a general rate 12 case and are based on the results of the class cost-of- 13 service study. 14 Q.Have you updated the FCC and FCE rates as part 15 of this general rate case proceeding? 16 A.Yes. Pursuant to Order No. 30267, I have 17 updated the FCC and the FCE rates using the functionalized 18 and classified revenue requirement data provided by Mr. 19 Larkin. The updated FCC and FCE rates have been included 20 on the revised Schedule 54, Fixed Cost Adjustment. 21 Q.Please describe the process used to determine 22 the FCC and FCErates for the FCA mechanism, which have 23 been submitted as part of this general rate case 24 proceeding. 25 YOUNGBLOOD, DI 14 Idaho Power Company 1 A.The FCC and FCE rates submitted as part of 2 this general rate case proceeding are based upon the 2011 3 test year. These rates most accurately represent the 4 Company's current fixed 'costs. Exhibit No. 44, Tables I, 5 II, and III detail the computational process that was used 6 to determine these class-specific fixed-cost amounts. 7 The first step in this process is a determination of 8 the 2011 test year fixed cost recovery embedded in the 9 energy charges for Residential Service and Small General 10 Service customers. As can be seen on Exhibit No. 44, Table 11 III, column J, for Residential Service, $269,822,080 of 12 fixed costs is to be recovered from the residential 13 customers through energy charges. For Small General 14 Service, $11,206,634 of fixed costs is to be recovered from 15 the energy charges. 16 Q.Do these fixed cost amounts for the 17 Residential and Small General Service customer classes 18 include more than their actual class cost of service? 19 A.Yes.There is a difference between the class 20 cost of service numbers and the amount of requested revenue 21 requirement. This difference is a result of the cross- 22 class subsidies that are currently present in the Company's 23 rate structure. The total cross-class subsidies as well as 24 the fixed cost portion of those subsidies are identified on 25 Exhibit No. 44, Table II. YOUNGBLOOD, DI 15 Idaho Power Company 1 Q.Why is it important to include these fixed 2 cost subsidies for the Residential and Small General 3 Service classes? 4 A.When fixed costs are recovered through a 5 'volumetric rate, the effects of any conservation program 6 that reduces energy consumption results in a loss in the 7 recovery of those fixed costs. In the case of both the 8 Residential and Small General Service customer classes, the 9 reduction of energy consumption through conservation 10 measures not only prevents the Company from recovering the 11 fixed costs associated with those classes, but in addition, 12 prevents the fixed cost recovery of the subsidies which are 13 incorporated in their energy rates. 14 Q.How are the class-specific fixed cost amounts 15 established in the initial step used to derive the updated 16 FCC rates? 17 A.The determination of the FCC rate utilizes the 18 annual average number of customers for the Residential 19 customer class and Small General Service customer class. 20 As can be seen on Exhibit No. 44, Table III, column A, the 21 2011 average number customers is 397,403 for the 22 Residential customer class and 28,351 for the Small General 23 Service customer class. 24 Wi th these two principal base level values, the FCC 25 rate can be determined. The annual fixed costs recovered YOUNGBLOOD, DI 16 Idaho Power Company 1 through the energy charges divided by the 2011 average 2 number of customers results in an annual fixed cost 3 recovery per customer, or the FCC rate, shown on Exhibit 4 No. 44, Table III, column K. For the Residential class, 5 the annual fixed cost recovery per customer is $ 67 8.96 6 ($269,822,080 / 397,403). For the Small General Service 7 class, the annual fixed cost recovery per customer is 8 $395.28 ($11,206,634 / 28,351). 9 Q.How are the class-specific fixed cost amounts 10 established in the initial step used to derive the updated 11 FCE values? 12 A.The determination of the FCE rate utilizes the 13 Residential and Small General Service weather-normalized 14 energy consumption for the 2011 test year. As can be seen 15 on Exhibit No. 44, Table III, column B, the 2011 weather- 16 normalized annual energy consumption for the Residential 17 customer class is 5,010,676,610 kilowatt-hours (~kWh") and 18 annual energy consumption for the Small General Service 19 class is 148,946,670 kWh. 20 With these additional principal base level values, 21 the FCE rate can be determined. The annual fixed cost 22 recovered through the energy charges divided by the 23 normalized energy results in an annual fixed cost recovery 24 per kWh, or the FCE rate, shown on Exhibit No. 44, Table 25 III, column L. For the Residential class, the fixed cost YOUNGBLOOD, DI 17 Idaho Power Company 1 recovery per kWh is $0.053849 ($269,822,080 / 2 5,010,676,610). For the Small General Service class, the 3 annual fixed cost recovery per kWh is $0.075239($11,206,634 4 / 148,946,670). 5 Q.Is the methodology used to establish the FCC 6 and FCE rates in this general rate case proceeding the same 7 as that used previously to establish the FCC and FCE rates 8 in Case Nos. IPC-E-07-08 and IPC-E-08-10? 9 A.Yes it is. 10 Q.How do the FCC and FCE computed in this filing 11 compare to the FCC and FCE established in the Company's 12 last general rate case, IPC-E-08-10, Case No. 30754. 13 A.Both the FCC and FCC rates are greater than 14 those currently in effect, which were established using the 15 functionalized classified revenue requirement data in the 16 Company's last filed general rate case, IPC-E-08-10, Case 17 No. 30754. The Company has made significant investments in 18 its infrastructure since that time, and the newly 19 calculated FCC and FCE rates reflect those fixed costs that 20 are being recovered through the Residential and Small 21 General Service energy charges. The magnitude of the 22 amount of fixed costs being recovered through a volumetric 23 rate emphasizes the Company's need to have an FCA true-up 24 mechanism in place. Mr. Larkin describes the determination 25 YOUNGBLOOD, DI 18 Idaho Power Company 1 of the functionalized classified revenue requirement that 2 has been used for the determination of the FCC and FCE. 3 Q.Are there any other changes being proposed by 4 the Company with regard to the FCA? 5 A.Yes. The Company is proposing to remove the 6 temporary ~pilot" status of Schedule 54 - Fixed Cost 7 Adj ustment - and convert it to an ongoing, permanent tariff 8 schedule. The current FCA pilot is set to expire on 9 December 31, 2011. Mr. Cavanagh of the National Resources 10 Defense Council has filed testimony in this case in support 11 of the Company's proposal. 12 Q.Why is the Company proposing to make Schedule 13 54 - Fixed Cost Adj ustment - an ongoing, permanent tariff 14 schedule? 15 A.The purpose of the pilot was to test a fixed 16 cost adjustment mechanism designed ~to true-up the 17 collection of fixed costs per customer to recover the 18 difference between the fixed costs actually recovered 19 through rates and the fixed costs authorized for recovery 20 in the Company's most recent rate case". Order No. 30267. 21 Results from the first three years of the pilot, and now 22 the last year and a half of the extended pilot, indicate 23 that the true-up mechanism is working as intended and 24 operating to mitigate adverse financial effects for the 25 Company of Demand Side Management (~DSM") by ensuring that YOUNGBLOOD, DI 19 Idaho Power Company 1 the fixed costs authorized for recovery are being trued-up 2 via the FCA mechanism. The mechanism has proven to be fair 3 to both the customer and the Company, providing both a 4 refund and a surcharge throughout the pilot years. The 5 mechanism has also been proven to be reasonable as the 6 individual customer bill impacts, both up and down, have 7 been relatively small. 8 Q.During the first three years of the pilot, the 9 annual FCA balances for the Residential and Small General 10 Service customer classes were combined to create an equal 11 adj ustment for both classes, or spread uniformly to both 12 customer classes on an equal percentage basis. In Staff's 13 comments in IPC-E-11-03, dated March 12, 2011, the Staff's 14 recommendation was to again distribute the surcharge on an 15 equal percentage basis. Is this how the Company originally 16 intended the FCA balances to be distributed under the pilot 17 FCA? 18 A.No. The annual FCA deferral balance for the 19 residential customer class was originally intended to be an 20 adj ustment for the Residential class only. Likewise, and 21 separately, the annual FCA deferral balance for the Small 22 General Service customer class was intended to be an 23 adj ustment for the Small General Service class only. 24 Q.Why were the annual FCA balances for the 25 Residential and Small General Service customer classes YOUNGBLOOD, DI 20 Idaho Power Company 1 combined to create one adjustment for both customer 2 classes? 3 A.Originally, in the first year of the FCA, the 4 Commission's Staff recommended, and the Commission 5 ultimately approved, a combined adjustment for the 6 Residential and Small General Service customer classes to 7 help offset a FCA rate increase to Small General Service 8 customers. By combining the FCA balances for both customer 9 classes, the Commission was able to balance a rate increase 10 to Small General Service customers with a refund to 11 Residential customers. The result was rate reduction to 12 both customer classes. 13 During the next three years of the FCA pilot, the 14 FCA balance for both the Residential and Small General 15 Service customer classes were posi ti ve amounts. Consistent 16 with the distribution methodology utilized in the first 17 year of the FCA pilot, the Company recommended a combined 18 annual adjustment to help mitigate the individual rate 19 increase to the Small General Service customer class. In 20 turn, the Commission approved a combined rate increase for 21 the Residential and Small General Service customer classes. 22 Q.How does the Company propose to distribute the 23 annual Residential and Small General Service FCA balances 24 if Schedule 54 is changed to a permanent tariff? 25 YOUNGBLOOD, DI 21 Idaho Power Company 1 A.For the first four years of the FCA pilot, 2 ei ther the Commission ordered or the Company proposed to 3 recover or refund the FCA deferral balance equally to both 4 classes. Under the proposed permanent tariff, the Company 5 proposes to true-up the Residential and Small General 6 Service FCA by combining the deferral balances of each 7 class and implement rates for each class that represent a 8 uniform percent change. This method of recovery or refund 9 is consistent with the first four years of the FCA Pilot. 10 In addition, by combining the Residential and Small General 11 Service FCA balances and determining the rate adders based 12 on an equal FCA rate adj ustment for each class, the overall 13 rate impact to customers in these classes is a more 14 representati ve total amount of the required fixed cost 15 recovery for each class. 16 Q.Upon conversion to a permanent FCA, are you 17 proposing any other changes to the pilot FCA provisions set 18 forth in Order No. 30267? 19 A.Yes. Under the pilot, the Company was 20 required to document each year specific ways it had 21 increased its investment in energy efficiency and DSM as a 22 resul t of the FCA mechanism. The Company believes that 23 this increased commitment to invest in energy efficiency is 24 now evident and a separate annual reporting requirement is 25 no longer needed with the permanent Tariff Schedule 54. If YOUNGBLOOD, DI 22 Idaho Power Company 1 questions arise as to the Company's commitment toward the 2 acquisition of all cost effective DSM, one can simply 3 review the Company's DSM Annual Report which is filed with 4 the Commission in March of each year. The Company will 5 continue reporting the monthly FCA balance as it now does 6 and will continue to file annual applications seeking 7 approval of the FCA true-up balances. All other provisions 8 will remain the same. 9 Q.What effective date is the Company proposing 10 for converting Schedule 54 from a pilot schedule to a 11 permanent schedule? 12 A.The Company is proposing to make Schedule 54 13 an ongoing, permanent schedule immediately following the 14 completion of the extended pilot which ends December 31, 15 2011. Therefore, the Company proposes that Schedule 54 16 become a permanent tariff schedule, effective January 1, 17 2012. 18 Q.Does this conclude your direct testimony in 19 this case? 20 A.Yes, it does. 21 22 23 24 25 YOUNGBLOOD, DI 23 Idaho Power Company BEFORE THE REceiVED 20 \\ JUN - I PM 2: 4 1 IDAHO PUBLIC UTiliTIES COMMISSldÑL CASE NO. IPC-E-11-08 \tl IDAHO POWER COMPANY YOUNGBLOOD, DI TESTIMONY EXHIBIT NO. 43 _ CDU CII =i=- a. CC E ::II - II ..a.Gl Gl..E :: 0 II 0OC.cIiNo ~ ~ O..~o.Gl-GlGlGl~'õli C~'õ.s~";a.CJ!l!'Co .S! II Gl .!~.: ¡ü: :: ~ Cl ii ::o 0N c.N C Gl0-o. ::u 'C.- Gl:E .cuII is ë ~Q) c:~ II Q) ..a. 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(j . . 600 Id a h o P o w e r C o m p a n y Ca l c u l a t i o n o f R e v e n u e I m p a c t St a t e o f I d a h o 20 1 1 G e n e r a l R a t e C a s e F u n d i n g Fi l e d J u n e 1 , 2 0 1 1 J R S i m p l o t C o m p a n y Sc h e d u l e 2 9 (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) Cu r r e n t Cu r r e n t Pr o p o s e d Pr o p o s e d Li n e Ba s e Ba s e Ba s e Ba s e Re v e n u e Pe r c e n t No De s c r i p t i o n ~ Ra t e Re v e n u e Ra t e Re v e n u e Di f f e r e n c e Ch a n g e Co n t r a c t k W 30 0 , 0 0 0 $2 . 0 4 $6 1 2 , 0 0 0 $2 . 3 4 $7 0 2 , 0 0 0 $9 0 , 0 0 0 14 . 7 1 % 2 Da i l y E x c e s s D e m a n d k W 0 0. 2 7 6 $0 0. 3 2 0 $0 $0 0. 0 0 % 3 De m a n d ( k W ) 27 8 , 3 1 8 6. 9 7 $1 , 9 3 9 , 8 7 6 8. 0 1 $2 , 2 2 9 , 3 2 7 $2 8 9 , 4 5 1 14 . 9 2 % 4 En e r g y ( k W h ) 18 0 , 7 5 8 , 7 9 7 0. 0 1 8 4 8 0 $3 , 3 4 0 , 4 2 3 0. 0 2 1 2 2 1 $3 , 8 3 5 , 8 8 2 $4 9 5 , 4 5 9 14 . 8 3 % 5 To t a l R e v e n u e $5 , 8 9 2 , 2 9 9 $6 , 7 6 7 , 2 0 9 $8 7 4 , 9 1 0 14 . 8 5 % 6 En e r g y E f f i c i e n c y R i d e r 4. 7 5 % $2 7 9 , 8 8 4 4. 7 5 % $3 2 1 , 4 4 2 $4 1 , 5 5 8 14 . 8 5 % 7 FC A R e v e n u e 0. 0 0 0 0 0 0 $0 0. 0 0 0 0 0 0 $0 $0 0. 0 0 % 8 PC A R e v e n u e (0 . 0 0 0 2 3 4 ) ($ 4 2 , 2 9 8 ) (0 . 0 0 0 2 3 4 ) ($ 4 2 , 2 9 8 ) $0 0. 0 0 % 9 To t a l B i l e d R e v e n u e $6 , 1 2 9 , 8 8 5 $7 , 0 4 6 , 3 5 3 $9 1 6 , 4 6 8 14 . 9 5 % "' s : ( j m Il . I I X (0 . . e n : : CD ò ' C D B ' w c : z : : o : i 0 Z :; c g : . ! = õ" ' , ¡ 8. 0 w . m - , "' . . (j i " o00 Id a h o P o w e r C o m p a n y Ca l c u l a t i o n o f R e v e n u e I m p a c t St a t e o f I d a h o 20 1 1 G e n e r a l R a t e C a s e F u n d i n g Fi l e d J u n e 1 , 2 0 1 1 De p a r t m e n t o f E n e r g y Sc h e d u l e 3 0 (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) Cu r r e n t Cu r r e n t Pr o p o s e d Pr o p o s e d Li n e Ba s e Ba s e Ba s e Ba s e Re v e n u e Pe r c e n t No De s c r i p t i o n Us e Ra t e Re v e n u e Ra t e Re v e n u e Di f f e r e n c e Ch a n g e De m a n d 39 8 , 6 0 4 $7 . 5 5 $3 , 0 0 9 , 4 6 0 $8 . 6 7 $3 , 4 5 5 , 8 9 7 $4 4 6 , 4 3 7 14 . 8 3 % 2 To t a l E n e r g y 23 5 , 1 0 0 , 0 0 0 0. 0 1 9 7 8 7 $4 , 6 5 1 , 9 2 4 0. 0 2 2 7 2 7 $5 , 3 4 3 , 1 1 8 $6 9 1 , 1 9 4 14 . 8 6 % 3 To t a l R e v e n u e $7 , 6 6 1 , 3 8 4 $8 , 7 9 9 , 0 1 5 $1 , 1 3 7 , 6 3 1 14 . 8 5 % 4 En e r g y E f f c i e n c y R i d e r 4. 7 5 % $3 6 3 , 9 1 6 4. 7 5 % $4 1 7 , 9 5 3 $5 4 , 0 3 7 14 . 8 5 % 5 FC A R e v e n u e 0. 0 0 0 0 0 0 $0 0. 0 0 0 0 0 0 $0 $0 0. 0 0 % 6 PC A R e v e n u e (0 . 0 0 0 2 3 8 ) ($ 5 5 , 9 5 4 ) (0 . 0 0 0 2 3 8 ) ($ 5 5 , 9 5 4 ) $0 0. 0 0 % 7 To t a l B i l e d R e v e n u e $7 , 9 6 9 , 3 4 6 $9 , 1 6 1 , 0 1 4 $1 , 1 9 1 , 6 6 8 14 . 9 5 % "' s : ( j m Il . I I X lC . . c n : : CD 0 ' C D e ' .¡ c : z : : o : i 0 Z _l C . 0 .¡ 0 ' - . Õ " ' . ¡ 8. n w - m - , "' . . (j T õ' Li n e No De s c r i o t i o n 1 Fi r s t B l o c k C o n t r a c t D e m a n d 2 Fi r s t B l o c k E n e r g y 3 Se c o n d B l o c k C o n t r a c t D e m a n d 4 Se c o n d B l o c k E n e r g y 5 Ad d i t i o n a l M i n . E n e r g y R e v e n u e 6 Ex c e s s D e m a n d C h a r g e s 7 Da i l y E x c e s s D e m a n d 8 Mo n t h l y ex c e s s D e m a n d 9 Ex c e s s E n e r g y C h a r g e . 10 To t a l R e v e n u e - B l o c k 1 11 To t a l R e v e n u e - B l o c k 2 12 To t a l R e v e n u e 13 En e r g y E f f c i e n c y R i d e r - B l o c k 1 14 En e r g y E f f c i e n c y R i d e r - B l o c k 2 15 FC A R e v e n u e 16 PC A R e v e n u e 17 To t a l R e v e n u e - B l o c k 1 18 To t a l R e v e n u e - B l o c k 2 19 To t a l B i l e d R e v e n u e Id a h o P o w e r C o m p a n y Ca l c u l a t i o n o f R e v e n u e I m p a c t St a t e o f I d a h o 20 1 1 G e n e r a l R a t e C a s e F u n d i n g Fi l e d J u n e 1 , 2 0 1 1 Ho k u Sc h e d u l e 3 2 (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) Cu r r e n t Cu r r e n t Pr o p o s e d Pr o p o s e d Ba s e Ba s e Ba s e Ba s e Re v e n u e Pe r c e n t Us e Ra t e Re v e n u e Ra t e Re v e n u e Di f f e r e n c e Ch a n g e 59 1 , 3 8 7 $2 . 3 5 $1 , 3 8 9 , 7 6 0 $2 . 3 5 $1 , 3 8 9 , 7 6 0 $0 0. 0 0 % 37 0 , 0 0 6 , 2 1 9 0. 0 6 1 6 6 0 $2 2 , 8 1 4 , 5 8 3 0. 0 6 1 6 6 0 $2 2 , 8 1 4 , 5 8 3 $0 0. 0 0 % 30 0 , 0 0 0 $4 . 6 3 $1 , 3 8 9 , 0 0 0 $5 . 3 2 $1 , 5 9 6 , 0 0 0 $2 0 7 , 0 0 0 14 . 9 0 % 19 7 , 1 0 0 , 0 0 0 0. 0 2 8 8 9 4 $5 , 6 9 5 , 0 0 7 0. 0 3 3 1 7 7 $6 , 5 3 9 , 1 8 7 $8 4 4 , 1 8 0 14 . 8 2 % 0 $0 $0 $0 0. 0 0 % 0 $0 . 5 7 $0 $0 . 6 5 $0 $0 0. 0 0 % 0 $5 . 7 1 $0 $6 . 5 6 $0 $0 0. 0 0 % 0 0. 0 8 8 6 4 7 $0 0. 1 0 1 8 0 2 $0 $0 0. 0 0 % $2 4 , 2 0 4 , 3 4 3 $2 4 , 2 0 4 , 3 4 3 $0 0. 0 0 % $7 , 0 8 4 , 0 0 7 $8 , 1 3 5 , 1 8 7 $1 , 0 5 1 , 1 8 0 14 . 8 4 % $3 1 , 2 8 8 , 3 5 0 $3 2 , 3 3 9 , 5 3 0 $1 , 0 5 1 , 1 8 0 3. 3 6 % 4. 7 5 % $1 , 1 4 9 , 7 0 6 4. 7 5 % $1 , 1 4 9 , 7 0 6 $0 0. 0 0 % 4. 7 5 % $3 3 6 , 4 9 0 4. 7 5 % $3 8 6 , 4 2 1 $4 9 , 9 3 1 14 . 8 4 % 0. 0 0 0 0 0 0 $0 0. 0 0 0 0 0 0 $0 $0 0. 0 0 % 0. 0 0 1 1 9 5 $2 3 5 , 5 3 5 0. 0 0 1 1 9 5 $2 3 5 , 5 3 5 $0 0. 0 0 % $2 5 , 3 5 4 , 0 4 9 $2 5 , 3 5 4 , 0 4 9 $0 0. 0 0 % $7 , 6 5 6 , 0 3 2 $8 , 7 5 7 , 1 4 3 $1 , 1 0 1 , 1 1 1 14 . 3 8 % $3 3 , 0 1 0 , 0 8 1 $3 4 , 1 1 1 , 1 9 2 $1 , 1 0 1 , 1 1 1 3. 3 4 % BEFORE THE RECEIVED 2011 JUN -I PH 2: 41 t ¡-i!.lfÇ~f~t¡qIDAHO PUBLIC UTILITIES COMMissiON CASE NO. IPC-E-11-08 IDAHO POWER COMPANY YOUNGBLOOD, DI TESTIMONY EXHIBIT NO. 44 "' s : ( j m Il , I I X lO C O - ( g ¡ = . o 0 ' .. C Z ; : o : i 0 Z _1 O . 0 W 0 ' - . Õ " ' . ¡ 8. 0 . ¡ - m - , "' . . (j i " g ID A H O P O W E R C O M P A N Y De v e l o p m e n t o f F i x e d C o s t A d j u s t m e n t R a t e 20 1 1 T e s t Y e a r Ta b l e I Cl a s s C o s t o f S e r v i c e F u n c t i o n a l i z e d C o s t s A B C D E F Ra t e CO S Di s t r i b u t i o n a n d Li n e Sc h e d u l e Re v e n u e Ge n e r a t i o n Tr a n s m i s s i o n Cu s t o m e r To t a l Fi x e d C o s t No . Un i f o r m T a r i f f S c h e d u l e s No . Re q u i r e m e n t · Fi x e d C o s t s b Fi x e d C o s t s C Fi x e d C o s t s d Fix e d C o s t s % o f T o t a l C o s t B+ C + D E+ A Re s i d e n t i a l S e r v i c e 1, 3 , 4 & 5 40 2 , 2 3 5 , 5 9 0 95 , 1 0 5 , 0 1 7 42 , 4 2 7 , 8 7 5 15 0 , 5 2 3 , 7 5 8 28 8 , 0 5 6 , 6 5 0 71 . 6 % 2 Sm a l l G e n e r a l S e r v i c e 7 16 , 1 9 6 , 2 1 1 2, 2 2 2 , 5 9 2 1, 0 5 0 , 8 7 2 9, 4 7 8 , 5 5 6 12 , 7 5 2 , 0 2 0 78 . 7 % 3 La r g e G e n e r a l S e r v i c e 9 19 8 , 5 6 5 , 3 9 1 53 , 2 7 2 , 7 0 9 24 , 1 0 6 , 2 8 3 42 , 4 5 1 , 9 6 5 11 9 , 8 3 0 , 9 5 7 60 . 3 % 4 Du s k / D a w n L i g h t i n g 15 52 3 , 6 9 1 15 , 7 8 0 (8 3 ) 40 1 , 4 2 4 41 7 , 1 2 1 79 . 7 % 5 La r g e P o w e r S e r v i c e 19 92 , 1 9 7 , 2 2 8 25 , 6 4 1 , 9 5 2 12 , 1 3 4 , 6 2 3 9, 0 4 0 , 2 0 2 46 , 8 1 6 , 7 7 7 50 . 8 % 6 Ir r i g a t i o n S e r v i c e 24 12 7 , 6 1 9 , 8 2 7 33 , 8 1 2 , 7 7 6 12 , 8 3 2 , 7 9 2 41 , 6 3 6 , 0 6 0 88 , 2 8 1 , 6 2 8 69 . 2 % 7 Un m e t e r e d S e r v i c e 40 1, 1 4 1 , 8 0 4 18 5 , 4 9 4 87 , 1 5 9 50 6 , 2 7 8 77 8 , 9 3 1 68 . 2 % 8 Mu n i c i p a l S t r e e t L i g h t i n g 41 2, 1 0 7 , 4 7 7 73 , 2 4 3 26 , 0 6 2 1, 5 5 8 , 3 3 8 1, 6 5 7 , 6 4 2 78 . 7 % 9 Tr a f f c C o n t r o l L i g h t i n g 42 27 8 , 7 3 3 46 , 2 6 7 26 , 5 0 9 11 8 , 4 3 4 19 1 , 2 1 1 68 . 6 % 10 Sp e c i a l C o n t r a c t s 26 , 2 9 , 3 0 & 3 2 76 , 7 4 3 , 0 6 6 17 , 4 7 7 , 7 3 4 9, 8 0 9 , 9 4 6 2, 2 4 8 , 9 0 2 29 , 5 3 6 , 5 8 2 38 . 5 % 11 To t a l U n i f o r m T a r i f f S c h e d u l e s 91 7 , 6 0 9 , 0 1 9 58 8 , 3 1 9 , 5 2 0 No t e s : (a ) V a l u e s f o r e a c h c u s t o m e r c l a s s c a n b e f o u n d o n E x h i b i t N o . 3 5 R e v e n u e R e q u i r e m e n t S u m m a r y , l i n e 4 5 . (b ) V a l u e s f o r e a c h c u s t o m e r c l a s s a r e f r o m E x h i b i t N o . 3 6 , C l a s s C o s t o f S e r v i c e U n i t C o s t s . C o l u m n D , s e c t i o n " P r o d u c t i o n - D e m a n d " (c ) V a l u e s f o r e a c h c u s t o m e r c l a s s a r e f r o m E x h i b i t N o . 3 6 , C l a s s C o s t o f S e r v i c e U n i t C o s t s , C o l u m n D , s e c t i o n " T r a n s m i s s i o n - D e m a n d " (d ) V a l u e s f o r e a c h c u s t o m e r c l a s s a r e f r o m E x h i b i t N o . 3 6 , C l a s s C o s t o f S e r v i c e U n i t C o s t s , C o l u m n D , s e c t i o n s " D i s t r i b u t i o n " , "C u s t o m e r A c c o u n t i n g , " C o n s u m e r I n f o r m a t i o n " & " M i s c e l l a n e o u s " ( e x c l u d i n g " E n e r g y " ) "' s : ( j m Il . I I X 1O . J e n : : CD 0 ' C D e ' ", c : z : : 9, ! È 9 ~ W 0 ' - . Õ " ' . ¡ 8. n . ¡ . m - , "' . . (j i " g ID A H O P O W E R C O M P A N Y De v e l o p m e n t o f F i x e d C o s t A d j u s t m e n t R a t e 20 1 1 T e s t Y e a r Ta b l e I I Id e n t i f i c a t i o n o f I n t e r c l a s s R e v e n u e S u b s i d y Li n e No . U n i f o r m T a r i f f S c h e d u l e s A B C D E F G Pr o p o s e d CO S Re v e n u e Fi x e d C o s t Fi x e d C o s t Ba s e R a t e Re v e n u e Sh o r t - F a l l Re v e n u e %o f Po r t i o n o f R e v . Re v e n u e ( a ) Re q u i r e m e n t Di f f e r e n c e Id e n t i f i e r Sh o r t - F a l l To t a l C o s t Sh o r t - F a l l Ta b l e I , C o l . A A. B Ta b l e i , C o l . F Ex F Sc h e d u l e No . Re s i d e n t i a l S e r v i c e 1 , 3 , 4 & 5 4 1 2 , 9 3 9 , 4 8 0 4 0 2 , 2 3 5 , 5 9 0 1 0 , 7 0 3 , 8 9 0 2 S m a l l Ge n e r a l Se r v i c e 7 1 6 , 4 9 3 , 3 8 1 1 6 , 1 9 6 , 2 1 1 2 9 7 , 1 7 0 3 L a r g e G e n e r a l S e r v i c e 9 2 0 2 , 8 6 4 , 0 7 4 1 9 8 , 5 6 5 , 3 9 1 4 , 2 9 8 , 6 8 3 4 D u s k / D a w n L i g h t i n g 1 5 1 , 1 2 8 , 7 4 4 5 2 3 , 6 9 1 6 0 5 , 0 5 3 5 L a r g e P o w e r S e r v i c e 1 9 9 5 , 1 7 0 , 3 8 7 9 2 , 1 9 7 , 2 2 8 2 , 9 7 3 , 1 5 9 6 I r r i g a t i o n S e r v i c e 2 4 1 1 8 , 3 7 1 , 7 6 9 1 2 7 , 6 1 9 , 8 2 7 ( 9 , 2 4 8 , 0 5 8 ) X ( 9 , 2 4 8 , 0 5 8 ) 6 9 . 2 % ( 6 , 3 9 7 , 3 8 9 ) 7 U n m e t e r e d S e r v i c e 4 0 1 , 1 7 4 , 2 8 2 1 , 1 4 1 , 8 0 4 3 2 , 4 7 8 8 M u n i c i p a l S t r e e t L i g h t i n g 4 1 2 , 7 8 6 , 7 2 7 2 , 1 0 7 , 4 7 7 6 7 9 , 2 5 0 9 T r a f f i c C o n t r o l L i g h t i n g 4 2 1 8 3 , 9 7 4 2 7 8 , 7 3 3 ( 9 4 , 7 5 9 ) X ( 9 4 , 7 5 9 ) 6 8 . 6 % ( 6 5 , 0 0 5 ) 10 S p e c i a l C o n t r a c t s 2 6 , 2 9 , 3 0 & 3 2 6 6 , 4 9 5 , 5 7 6 7 6 , 7 4 3 , 0 6 6 ( 1 0 , 2 4 7 , 4 9 0 ) X ( 1 0 , 2 4 7 , 4 9 0 ) 3 8 . 5 % ( 3 , 9 4 4 , 0 1 5 ) 11 T o t a l U n i f o r m T a r i f f S c h e d u l e s 9 1 7 , 6 0 8 , 3 9 4 9 1 7 , 6 0 9 , 0 1 9 6 2 5 ( 1 9 , 5 9 0 , 3 0 7 ) ( 1 0 , 4 0 6 , 4 0 9 ) We i g h t e d A v e r a g e Fi x e d C o s t % of S h o r t - F a l l b 53 . 1 % No t e s : (a ) V a l u e s f o r e a c h c u s t o m e r c l a s s c a n b e f o u n d o n A t t a c h m e n t N O . 3 t o t h e A p p l i c a t i o n , S u m m a r y o f R e v e n u e I m p a c t , c o l u m n " P r o p o s e d B a s e R e v e n u e " (b ) T h e " W e i g h t e d A v e r a g e F i x e d C o s t % o f S h o r t - F a l l " i s c a l c u l a t e d b y d i v i d i n g t h e t o t a l " F i x e d C o s t P o r t i o n o f R e v . S h o r t - F a l l " ( C o L . G ) by t h e t o t a l " R e v e n u e S h o r t - F a l l " ( C o L . H ) "' s : ( j m Il , I I X 1O . . U l : : CD 0 ' C D õ ' w c : z : : g, ~ ! = ~ W 0 ' - . Õ " ' , ¡ 8. n , ¡ - m - , "' . . (j i ' o00 ID A H O P O W E R C O M P A N Y De v e l o p m e n t o f F i x e d C o s t A d j u s t m e n t R a t e 20 1 1 T e s t Y e a r Ta b l e I I De r i v a t i o n o f F i x e d C o s t p e r C u s t o m e r a n d F i x e d C o s t p e r E n e r g y R a t e s A B C 0 E F 20 1 1 20 1 1 S a l e s Sh a r e o f To t a l Li n e Sc h e d u l e Av g . N u m b e r o f No r m a l i z e d CO S CO S Re v e n u e Ba s e R a t e No . Un i f o r m T a r i f f S c h e d u l e s No . Cu s t o m e r s " (k W h ) " Fi x e d C o s t Va r i a b l e C o s t Sh o r t - F a l l / S u b s i d y Re v e n u e Ta b l e I , C o l . E Ta b l e I , C o l . A - C o l . C Ta b l e I I , C o l . C C+ D + E Re s i d e n t i a l S e r v i c e 1, 3 , 4 & 5 39 7 , 4 0 3 5, 0 1 0 , 6 7 6 , 6 1 0 28 8 , 0 5 6 , 6 5 0 11 4 , 1 7 8 , 9 4 0 10 , 7 0 3 , 8 9 0 41 2 , 9 3 9 , 4 8 0 2 Sm a l l G e n e r a l S e r v i c e 7 28 , 3 5 1 14 8 , 9 4 6 , 6 7 0 12 , 7 5 2 , 0 2 0 3, 4 4 4 , 1 9 2 29 7 , 1 7 0 16 , 4 9 3 , 3 8 1 3 La r g e G e n e r a l S e r v i c e 9 30 , 5 6 2 3, 4 9 2 , 1 4 0 , 6 5 1 11 9 , 8 3 0 , 9 5 7 78 , 7 3 4 , 4 3 4 4, 2 9 8 , 6 8 3 20 2 , 8 6 4 , 0 7 4 4 La r g e P o w e r S e r v i c e 19 11 4 2, 0 4 0 , 6 8 1 , 7 9 6 46 , 8 1 6 , 7 7 7 45 , 3 8 0 , 4 5 1 2, 9 7 3 , 1 5 9 95 , 1 7 0 , 3 8 7 5 Ir r i g a t i o n S e r v i c e 24 16 , 6 0 7 1, 6 7 9 , 7 7 6 , 7 3 4 88 , 2 8 1 , 6 2 8 39 , 3 3 8 , 1 9 9 (9 , 2 4 8 , 0 5 8 ) 11 8 , 3 7 1 , 7 6 9 Li n e No . G CO S F i x e d C o s t Re v e n u e f r o m Fi x e d C h a r g e s b H I J CO S F i x e d C o s t F i x e d C o s t T o t a l F i x e d C o s t Re v e n u e f r o m S h a r e o f R e v e n u e R e v e n u e f r o m En e r g y C h a r g e s S h o r t - F a l l / S u b s i d y E n e r g y C h a r g e s Co G E x 5 3 . 1 H + I L Ca l c u l a t i o n o f FC E ($ / k W h ) J + B K Ca l c u l a t i o n o f FC C ($ / C u s t . / Y r . ) J + A Sc h e d u l e Un i f o r m T a r i f f S c h e d u l e s N o . 1 ( C a n t . R e s i d e n t i a l S e r v i c e 2 ( C o n t . ) S m a l l G e n e r a l S e r v i c e 3 ( C a n t . ) L a r g e G e n e r a l S e r v i c e 4 ( C a n t . ) L a r g e P o w e r S e r v i c e 5 ( C a n t . ) I r r i g a t i o n S e r v i c e 1, 3 , 4 & 5 7 9 19 24 5, 6 8 5 , 9 2 7 26 9 , 8 2 2 , 0 8 0 15 7 , 8 5 7 11 , 2 0 6 , 6 3 4 2, 2 8 3 , 4 6 9 76 , 2 7 4 , 4 8 5 $ 2, 4 9 5 . 7 3 $ 0. 0 2 1 8 4 2 1, 5 7 9 , 3 4 8 19 , 7 0 6 , 0 7 9 $ 17 2 , 8 6 0 . 3 5 $ 0. 0 0 9 6 5 7 (4 , 9 1 2 , 5 8 6 ) 54 , 6 9 9 , 6 9 8 $ 3, 2 9 3 . 7 7 $ 0. 0 3 2 5 6 4 23 , 9 2 0 , 4 9 7 1, 7 0 3 , 2 4 3 45 , 8 3 9 , 9 4 1 28 , 6 9 0 , 0 4 5 28 , 6 6 9 , 3 4 4 26 4 , 1 3 6 , 1 5 3 11 , 0 4 8 , 7 7 7 73 , 9 9 1 , 0 1 6 18 , 1 2 6 , 7 3 2 59 , 6 1 2 , 2 8 4 No t e s :