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Home My WebLink AboutOrdinance 2365 ORDINANCE NO. 2365 AN ORDINANCE APPROVING RATE SCHEDULES FOR TEXAS UTILITIES ELECTRIC COMPANY, PROVIDING AN EFFECTIVE DATE THEREFORE, PROVIDING CONDITIONS UNDER WHICH SUCH RATE SCHEDULES MAY BE CHANGED, MODIFIED, AMENDED OR WITHDRAWN, FINDING AND DETERMINING THAT THE MEETING AT WHICH THIS ORDINANCE IS PASSED IS OPEN TO THE PUBLIC AS REQUIRED BY LAW. BE IT ORDAINED BY THE CITY COUNCIL OF THE CITY OF NORTH RICHLAND HILLS, TEXAS: SECTION 1. On January 15, 1999, Texas Utilities Electric Company (hereinafter referred to as ATU Electric@) filed with the Governing Body of this municipality a Statement of Intent and Application to implement within the corporate limits of this municipality proposed new rate schedules that provide additional rate options for its customers, which options are entirely voluntary on the part of the customer, namely its proposed Rate GTU-M - General Service Time-of Use-Municipality, proposed Rate RTU1- M - Residential Time-of-Use Service-Municipality, and proposed Rate GTUC-M - General Service Time-of-Use Voluntary Curtailable-Municipality (said three proposed new rate schedules hereinafter collectively referred to as the ATime-of-Use Rate Schedules@). SECTION 2. The Time-of-Use Rate Schedules are hereby approved, and TU Electric is authorized to render service and to collect charges as specified in the Time-of- Use Rate Schedules from its customers electing to receive electric service under said Time-of-Use Rate Schedules within the corporate limits of this municipality until such time as said rate schedules may be changed, modified, amended or withdrawn with the approval of the Governing Body of this municipality. SECTION 3. The Time-of-Use Rate Schedules herein approved shall be effective from and after the final passage and approval of this Ordinance. SECTION 4. The filing of said Time-of-Use Rate Schedules shall constitute notice to the consumers of electricity within this municipality of the availability and application of such Time-of-Use Rate Schedules. SECTION 5. Nothing in this Ordinance contained shall be construed now or hereafter as limiting or modifying in any manner the right and power of the Governing Body of this municipality under the law to regulate the rates, operations, and services of TU Electric. SECTION 6. It is hereby officially found and determined that the meeting at which this Ordinance is passed is open to the public and as required by law and that public notice of the time, place, and purpose of said meeting was given as required. PASSED AND APPROVED at a Regular Meeting of the City Council of the City of North Richland Hills, Texas, this rP day of ,F-éÞr¿¡6f rl ' 1999. \ \ \ '_ \, \ " ; \ ~ i it: l : í ¡ /1 _\\\'. (")\r-,L.H Jj ~ 1///_ ~\.. í,,'Ví~ï/¡i';'/, ,.' . S'T:'·,,'/./",..'·· , .. . ~"- ~ ,- t:5~:'" ' . .".f:;::.\ ,~r ., :~,', _:~-:.:::~ c" . d4r '(J,-" C ,~_ ' 6(¿f¿.?" "/ '.., .... ç.,-:~ '-ej,!y ·Se,pe1âry..~,·"':' I/,III/l!:! r ¡: \ \ \ \ \\ \\\\ APPROV~9/A' TO FORM AND LEG~~~~~ /,.~ I", fí....· ,.". '----"'" /' '" ~',. , /1: ¿ /'é>'t'/ RLMc~re,!>1 orney;tjlt /' ,/ APPROVED: o Uf þ-&11tk Mayor TU Electric TIME-OF-USE RATE SUMMARY CITY OF NORTH RICHlAND HillS, TEXAS (January, 1999) This document outlines the voluntary time-of-use rate options proposed for approval in North Richland Hills. The idea for these rates came from TU Electric customers. We worked with several of our customers in designing these rates, which will allow customers who have the ability to shift some of their electric usage away from our peak periods to save money on their electric bills. TU Electric has already requested approval of these rates at the Public Utility Commission and they are in effect on an interim basis in the areas in which the Commission exercises original jurisdiction. We're expecting the Commission's final approval of these rates in the next couple of months. We'd like to also begin offering our customers in North Richland Hills the benefits of these time-of-use rate options. Since these rates are purely optional on the part of the customer, only those customers who would expect to be able to save money on their electric bills will likely take advantage of these options. Why would TU offer ways for a customer to pay less for electricity? Simply, if customers take advantage of these rates (and save money on their bills) those customers will place less demand on our system during our peak hours. This, in turn, means that TU won't have to buy as much power to serve peak load requirements, which allows us to save money overall. Those savings not only benefit TU Electric, but also benefit all of our customers. TU Electric Time-of-Use Rate Summary Page 2 of6 These time-of-use rates price electricity according to the hour of the day and the month of the year. There are four different pricing periods (Chart1), with the lowest price being during the periods when demand for electricity is the lowest, and, consequently, the cost to produce electricity is also the lowest. As you'd expect, the highest price is applicable during those afternoon and early evening hours of our hot summer weekdays, when TU's cost of electricity is at its highest. Those customers who can shift significant portions of their electric usage away from those higher- priced periods can save money. These time-of-use rates allow customers flexibility in controlling their energy costs. The three time-of-use rates being proposed are: 1. Rate GTU-M (General Service Time-ot-Use - Municipality), which is applicable to customers that are otherwise eligible for service under the Company's existing general service rates (i.e., GS, GP and HV); 2. Rate RTU1-M (Residential Time-of-Use Service Municipality), which is applicable to residential customers who are otherwise eligible for service under existing Rate R or Rate RTU; and 3. Rate GTUC-M (General Service Time-ot-Use Voluntary Curtailable - Municipality), which is applicable to those general service customers eligible for Rate GTU-M that are willing to voluntarily curtail their loads when the peak demand on the system is 95% or more of the estimated peak demand and during times of short supply conditions. TU Electric Time-of-Use Rate Summary Page 3 of6 The time-of-use options are a "win-win" for all of our customers and for all of our communities that rely on businesses for jobs and investment (Chart 2). By having this opportunity to experience cost savings and operating efficiencies through better management of their power needs, businesses will be able to remain more competitive. This in turn results in the potential for greater economic development opportunities for our communities and more value for the customers' energy dollar. TU would like to begin achieving peak load savings for this coming summer. But to do so, we need your approval of these additional rate options, so we can begin contacting our customers and exploring with them how they can take steps to shift electric loads away from our peak periods and, thereby, save money on their electric bills. ~;;: s 0 s..". ~ ~ ~ ;:: V VJ ~ ..- :J :J :J v~ 0 ~ 0 0 -:;¡ !' .c .c .c "C :J p::: 0 c ... 0 ... ... v () .c () () '" 'C C) .c .c .c ;:J () (,) õ õ - en < 0 <..,!., Q. ~ 0 < < < I .... V - .§ r-< E u - (/ oð '5 J!J "t:I 0. C 0 E u c () ~ ~ ...... N v ~ I 0. ...... - ~ () () z z c¡J .c, U () E I C> ~ 0 ~ 0. E E ï:: N (1 0. 32 ~ 0 0 E CO) ...... ...... - ("II oð oð tn (/ c oð "C :>. 8 E E E E CI) (1 0 "t:I C 0. ~ 0. 0. (1 ..... 'C ~ N 0 N 0 0 N - as () z ...... .c () ...... ...... I ...... ...... I () ,Q> 0:: Q. ~ I I E I I E E E E E c (1 0. 32 (1 0. 0 0. (1 0 E CI) co co ...... 00 00 ...... tn tn ::J "'C - - (/ E u J!J "t:I 0. 0 () c 0 tn C () ~ ~ ~ ...... .- ~ .... L. - () () z z -0 CI) :E u () E c.. I co ~ 0. ~ ::) N t ..- CI) .... , co C) CD .c E C) - () "C CO) -.- C c (/ E oð l- .- ra "C :>. 0. E E (1 00 (.) :E 0 "t:I ~ ~ 0. 0. 'C ~ N 0 .- I () Z Z ...... L. () E I "'C ..- () I c.. ::) Q. ~ 0. E CI) .... N (1 E tn 0 0. 0:: ...... 00 0 c. - (/ e J!J "t:I C C () ~ ~ ~ ~ c.. () ~ u () z z z () ("II ~ ~ CO) ..- - "lilt (/ E :>. 0. "C (1 ~ ~ ~ 00 0 "t:I ~ 'C () z z z E () () ~ 0. D.. N I ... m ... I ... () .c () () .CI .CI ... .CI E ... E oð () oð ¡¡; C .c .CI E () 0 () e 0 ~ - () :J U 'I:: - :>. 0. c C> :E () (1 0. U 0 (1 () :J :J 0 :2 « 0 z :2 C/J """) « ,,'0 ~..... 8 0 8-.:1" ;j Q) VJ~ fn Q)p., ~ fn (1) Q) -- en +' +' ~ c.!. fn -- 0 (1) e I 0 ... Q) ,5 0 C) ::J ca f-< ca E - (.) - 'E ~ fn fn 0 (.) en E Q) ¡:¡J C) e :) C ~ I- ... 0 0 - (1) -- ~ 0 ~ LL e +' C) C) W C. ... ... ... W 0 (1) 0 (1) C) e .... e Z e C) W w e - W -- 0 - -- .... .. - (.) 0 0 ~ m 0 -- I- - ... ... +' (1) N +' a.. e W ~ e +' E (1) e CO 0 (1) E (1) ::J en J: 0 0 ... E fn ::) - 0 (1) e e :E C) c. 0 -- ca 0 U. ~ fn e - 0 0 +' ... ca (1) ... -- (1) > - :E 0 -- E (1) .c .... W -- 0 fn C (1) >< :æ (1) +' (1) (.) ::J fn C) - - -- - LL ::J ~ E ca I- 0 > ... ::J 0 (1) fn 0 e (1) +' ... ca Cl) (.) 0 0 (1) > e (.) :E ... -- W C) C) W . . . . . -- -- -- .. . TUElectric K Lone Star Gas V Texas Utilities Companies Linda K. Allen Customer Service District Manager Fort Worth District January 15, 1999 To the Honorable Mayor and Members of the City Council City of North Richland Hills Enclosed for filing please find a Statement of Intent and Application of Texas Utilities Electric Company. This filing requests approval of three time-of-use rate options that would be available to residential, commercial and industrial customers within the city limits. These rates are strictly voluntary at the customer's choice, Materially identical time-of-use rates are pending approval at the Public Utility Commission of Texas in that Commission's Docket No. 17942. The proposed rates themselves, as well as supporting data underlying the proposed rates, are set forth in the direct testimony of Stephen 1. Houle, attached to the Statement of Intent and Application as Exhibit A. Should you have any questions concerning this filing, please give me a call. Very truly yours, /' r / } ).., Y../ . ^ ...1/ í /,~ ~ ^~r;-'--f\., á~ Linda K. Allen Receipt Acknowledg~ By: Name: ~ ' 0'"' /J.I ¿' ..'/ /? ' 0 Title: ~.;f i //Æ /Æ". I -7 oj ,/ /, :.'/ Date: 1'// /.>--//:f';? P,O, Box 970 Fan Wonh. Texas 76101·0970 January 15, 1999 TU ELECTRIC PROPOSES NEW TIME.QF·USE RATES TU Electric requested today that all cities exercising original jurisdiction over its rates approve three optional time-of-use rates for residential and business customers within their city limits. Last year the Public Utility Commission gave interim approval to the rates, which lower prices for electricity during periods of low demand. Since the PUC put them into effect in 197 cities governed by the PUC and in unincorporated areas, about 200 customers have signed up. These time-of-use rates, which are purely voluntary on the part of the individual customer, appeal to a diverse group of customers. About 20 percent of the customers now on the rates are churches and school districts. The remainder range from pipeline companies and heavy manufacturers to a tanning parlor and video rental chain. The rate has four pricing periods that depend on the month and time of day. Customers who are able to shift their on-peak energy use to pre-determined off-peak times within those pricing periods are charged less. Under the time-of-use rates, prices for residential and business customers receiving electricity at secondary distribution voltages vary from 1.09 cents per kilowatt-hour every day in April, October, and November, when demand is low, to 13.42 cents per kilowatt-hour for electricity used from 2 p.m. to 8 p.m. weekdays during the months of June, July, and August. Businesses are also eligible for a voluntary curtailable rate and an aggregate billing option. TU Electric developed these time-of-use rates after many hours of consultations with customers who were looking for ways to better manage their electric usage. The time-of- use rates are a "win-win situation" in that they allow customers who can shift significant portions of their electric loads away from the company's peak periods to save money on their electric bills -- and by dOing so allow TU Electric to incur less costs in buying power to meet its customers' peak demands, which saves money for all customers. The company hopes cities will approve the rates in time for customers to sign up and make the necessary changes in their processes and operations in time to achieve peak load reductions this coming summer peak season. BEFORE THE GOVERNING BODY OF THE CITY OF NORTH RICH LAND HILLS, TEXAS APPLICATION FOR APPROVAL OF § TIME-OF-USE RATE OPTIONS FOR § TEXAS UTILITIES ELECTRIC COMPANY § DOCKET NO. STATEMENT OF INTFNT AND APPLICATION TO THE HONORABLE SAID GOVERNING BODY: COMES NOW Texas Utilities Electric Company ("TU Electric") and files this its Statement of Intent and Application to implement proposed Rate GTU-M - General Service' Time-of-Use-Municipality, Rate RTU1-M - Residential Tirne-of-Use-Municipality, and Rate GTUC-M - General Service Time-of-Use Voluntary Curtailable-Municipality, respectfully showing the following: I. In an effort to provide additional rate options that will not only benefit participating customers but will also benefit non-participating customers, TU Electric has held discussions with several of its customers and has developed optional time-of-use rates that would be available to TU Electric's residential, commercial, and industrial customers on a voluntary basis at the customer's choice. These time-of-use rate options will allow participating customers to plan and manage their electrical energy usage to shift their loads from TU Electric's peak periods to TU Electric's off-peak periods, thereby saving on their electric bills and, at the same time, allowing TU Electric to acquire less resources to meet the peak loads of all of its customers, which will benefit both participating customers and non-participating customers as well. The optional time-of-use rates for which approval is sought are: (a) Rate GTU-M - General Service Time-of-Use-Municipality, which would be available to any TU Electric customer, regardless of the voltage at which the individual customer takes electric service, and which would typically include all customers receiving firm electric service under one of TU Electric's existing general service rates, Rate GS - General Service Secondary, Rate GP - General Service Primary, and Rate HV - High Voltage Service; (b) Rate RTU1-M - Residential Time-of-Use Service-Municipality, which would -1- be available to any TU Electric residential customer who would otherwise take electric service under one of TU Electric's residential rates, including Rate R - Residential Service and Rate RTU - Residential Time-of-Use Service; and (c) Rate GTUC-M - General Service Time-of-Use Voluntary Curtailable- Municipality, which would be available to any TU Electric customer, regardless of the voltage at which the individual customer takes electric service. and which would typically include customers that could interrupt or significantly reduce their usage during peak periods similar to customers receiving interruptible electric service under TU Electric's Rider I - Interruptible Service. Materially identical time-of-use rates are pending approval at the Public Utility Commission of Texas in that Commission's Docket No. 17942. These proposed time-of-use rate options each provide for four different pricing levels with eight distinct time-of-use periods. The proposed rates themselves, as well as supporting data underlying the proposed rates, are set forth in the direct testimony of Stephen J. Houle, attached hereto as Exhibit A and made a part hereof for all purposes. Proposed Rate GTU-M - General Service Time-of- Use-Municipality is attached to Mr. Houle's said testimony as Exhibit SJH-1; proposed Rate RTU1-M - Residential Time-of-Use Service-Municipality is attached to that testimony as Exhibit SJH-2; and proposed Rate GTUC-M - General Service Voluntary Curtailable- Municipality is attached to that testimony as Exhibit SJH-3. II. TU Electric's authorized representatives are: Stephen J. Houle Rates Manager Texas Utilities Electric Company Energy Plaza 1601 Bryan Street, Suite 32-002 Dallas, Texas 75201 Telephone:-(214) 812-4821 and J. Dan Bohannan Worsham, Forsythe & Wooldridge, L.L.P. -2- 1601 Bryan Street, 30th Floor Dallas, Texas 75201 Telephone: (214) 979-3000 General inquiries concerning this Statement of Intent and Application should be directed to Mr. Houle at the above-stated address and telephone number. All pleadings, motions, orders, and other documents filed in this proceeding should be served upon Mr. Bohannan at the above-stated address. III. This City has jurisdiction over TU Electric and the subject matter hereof by virtue of Sections 33.001,36.001,36.003, and 36.101-36.111 ofthe Texas Utilities Code ("PURA"). IV. TU Electric's business address and telephone number are: Texas Utilities Electric Company Energy Plaza 1601 Bryan Street Dallas, Dallas County, Texas 75201 Telephone: (214) 812-4600 V. In accordance with the provisions of PURA § 36.102, TU Electric proposes that these proposed rates be implemented effective on February 19, 1999 (which is 35 days after the filing hereof), the proposed effective date, or as soon thereafter as permitted by law. VI. While each of the proposed time-of-use rate options is wholly optional at the customer's choice, these rates are, considered together, available to all of TU Electric's retail customers. Thus, all of TU Electric's retail customers and classes of retail customers within the corporate limits of this City will be affected if this Application is granted. VII. Notice of the filing of this Application is being published in newspapers of general circulation in each county in which the proposed optional time-of-use rates are proposed to be implemented and is being delivered to all affected customers, all in accordance with PURA § 36.103. WHEREFORE, PREMISES CONSIDERED, TU Electric respectfully prays that this -3- Application be in all things granted, that the proposed Rate GTU-M - General Service Time-of-Use-Municipality, Rate RTU1-M - Residential Time-of-Use Service-Municipality, and Rate GTUC-M - General Service Time-of-Use Voluntary Curtailable-Municipality be approved as filed, and that it be granted such other and additional relief to which it is justly entitled. Respectfully submitted, WORSHAM, FORSYTHE & WOOLDRIDGE, L.L.P. J. Dan Bohannan State Bar No. 02563000 1601 Bryan Street. 30th Floor Dallas, Texas 75201 Telephone: (21. ) 979-3000 Fax: (214) 880- 011 ,~M~ ~J¡Ëts FOR TEXAS UTILltlES ËLECTRIC COMPANY By: -4- EXHIBIT A DIRECT TESTIMONY OF STEPHEN J. HOULE FOR TEXAS UTILITIES ELECTRIC COMPANY JANUARY 1999 DIRECT TESTIMONY OF STEPHEN J. HOULE WITNESS FOR TEXAS UTILITIES ELECTRIC COMPANY TABLE OF CONTENTS I. POSITION AND QUALIFICATIONS ................................. 2 II. PURPOSE OF TESTIMONY ....................................... 2 III. GENERAL DESCRIPTION OF PROPOSED RATES .................... 3 IV. DEVELOPMENT OF TIME-OF-USE PRICING PERIODS. . . . . . . . . . . . . . . .. 5 V. COST BASES & RATE DESIGN. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. 9 VI. SPECIAL PROVISIONS OF PROPOSED RATES............. ........ 13 Exhibits Exhibit SJH-1 - Proposed Rate GTU-M - General Service Time-ot-Use - Municipality Exhibit SJH-2 - Proposed Rate RTU1-M - Residential Time-ot-Use Service - Municipality Exhibit SJH-3 - Proposed Rate GTUC-M - General Service Time-ot-Use Voluntary Curtailable - Municipality Exhibit SJH-4 - Proposed Time-ot-Use Rates Pricing Periods Exhibit SJH-S . TU Electric System Load Exhibit SJH·6 . System Monthly Peak Demands Exhibit SJH·7 . Rates RTU1·M, GTU-M, and GTUC·M . Calculation ot Facilities Charges Exhibit SJH·8.. Rates RTU1-M, GTU·M, and GTUC·M - Price Determination tor Pricing Periods 1-4 ·1· Houle - Direct 10 11 12 14 15 16 17 18 19 20 21 22 23 24 25 26 1 2 Q. A. 3 4 5 6 Q. A. Q. 7 8 9 A. "\ Q. A. DIRECT TESTIMONY OF STEPHEN J. HOULE I. POSITION AND QUALIFICATIONS PLEASE STATE YOUR NAME AND BUSINESS ADDRESS. My name is Stephen J. Houle. My busin,ess address is Energy Plaza, 1601 Bryan Street, Dallas. Texas 75201. WHAT IS YOUR POSITION WITH TEXAS UTILITIES ELECTRIC COMPANY? I hold the position of Rates Manager. PLEASE OUTLINE YOUR EDUCATIONAL BACKGROUND AND PROFESSIONAL QUALIFICATIONS. I graduated from the University of Notre Dame in May 1977, with a Bachelor of Science degree in Electrical Engineering. In December 1979, I received the degree of Master of Business Administration from the University of Dallas. I was employed by Dallas Power & Light Company in June 1977. I worked in the Distribution Design Division of the Engineering Department from June 1977 through December 1979, the Regulatory Services Department from January through December 1980, and the Rate Department from January 1981 through December 1983. In January 1984, I was named Supervisor, Rate Design for Texas Utilities Electric Company (TU Electric). In March 1987, I was named Supervisor - Rate and Cost Analysis. In October 1990, I was named to my current position of Rates Manager. II. PURPOSE OF TESTIMONY WHAT IS THE PURPOSE OF YOUR TESTIMONY IN THIS PROCEEDING? The purpose of my testimony in this proceeding is to support three new Time-of-Use rates that TU Electric is proposing in order to provide its customers with additional pricing options. These rates will offer enhanced Time-of-Use pricing to all of TU Electric's Residential and General Service customers, providing these customers increased flexibility to control their operating costs and may encourage innovative Demand Side Management (DSM) activities by these customers. The Company -2- Houle - Direct 1 ¿ 3 4 5 6 a. 7 A. 8 9 10 11 12 13 14 15 17 18 19 20 21 22 a. A. 23 24 25 26 27 28 29 a. has pending before the Public Utility Commission of Texas, as Docket No, 17942, an application for approval of materially identical rates to be applicable in those portions of the Company's service area over which that Commission exercises original jurisdiction. III. GENERAL DESCRIPTION OF PROPOSED RATES PLEASE DESCRIBE THE THREE RATES YOU ARE PROPOSING. Rate GTU-M, General Service Time-of-Use - Municipality, is applicable to customers that are otherwise eligible for service under the Company's general service rates (Le., Rates GS, GP, and HV) and is attached as my Exhibit SJH-1. Rate RTU1-M. Residential Time-of-Use Service - Municipality, is applicable to residential customers who are otherwise eligible for service under Rate R or Rate RTU, and is attached as my Exhibit SJH-2. Rate GTUC-M - General Service Time- of-Use Voluntary Curtailable - Municipality -- is applicable to those general service customers eligible for Rate GTU-M that are willing to voluntarily curtail their loads during times of system peak or short supply conditions. Rate GTUC-M is limited to 1,000 MW of total contracted load for the Company's 1999 peak load season and to 2,000 MW for the 2000 peak load season, on a first-come-first-served basis until the total contracted load (i.e., the total of all Contract kW) reaches these maximums. Rate GTUC-M is attached as my Exhibit SJH-3. Each of the proposed rates is comprised of a customer charge. a facilities charge. a time-dependent energy charge, a fuel charge, and a purchased power charge. WHAT ARE THE OBJECTIVES OF THE THREE PROPOSED RATES? The objectives of the proposed rates are to: (1) provide customers with additional flexibility regarding pricing options; (2) encourage customers to engage in effective demand side management activities; and (3) reflect TU Electric's cost of service. HOW DO THE PROPOSED RATES PROVIDE CUSTOMERS WITH ADDITIONAL PRICING FLEXIBILITY? The proposed rates provide four pricing levels with eight distinct time-of-use periods . that offer an additional pricing option for a wide spectrum of residential, commercial, A. -3· Houle - Direct 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 17 18 19 20 21 22 23 24 25 26 27 28 29 A. .:> Q. A. Q. A. Q. and industrial customers. Customers with minimal on-peak usage and customers with the wherewithal to reduce on-peak load and/or shift load from on-peak to off- peak periods can manage their cost of electric service under these rates. HOW DO THE PROPOSED RATES ENCOURAGE CUSTOMERS TO ENGAGE IN EFFECTIVE DEMAND SIDE MANAGEMENT ACTIVITIES? The proposed rates encourage demand side management (DSM) activities by means of the price signals inherent in the rates. Consumption during the Company's relatively few on-peak hours is discouraged by high energy prices. Conversely, low off-peak pricing gives customers the incentive necessary to engage in load shifting from on-peak to off-peak periods. Customers who can reduce their loads during the on-peak hours specified in these rates and/or who can shift their loads from the on-peak hours to the off-peak hours can achieve considerable savings as a result of their actions. The Company's non-participating customers will also benefit from these DSM measures that reduce the need for additional, and costly, generating resources strictly to serve on-peak loads. HOW DO THE PROPOSED RATES REFLECT TU ELECTRIC'S COST OF SERVICE? The energy pricing provisions of these rates are designed to recover the Company's annual production revenue requirement as set forth in the Company's last general rate case, Docket No. 11735. Similarly, the proposed rates also include cost-based customer charges as well as a facilities charge designed to recover the costs of the Company's transmission and distribution facilities. As a result, these rates ,are designed to be revenue neutral. HOW DO THESE PROPOSED NEW RATES DIFFER FROM THE COMPANY'S EXISTING TIME DIFFERENTIATED RATES? TU Electric's existing time-of-day option contained in Rates GS, GP, and HV, is a demand-based time-of-day option that provides for a reduction in the demand billing for off-peak demand. The proposed time-of-use rates replace the demand charge pricing provisions with an energy-based pricing schedule that is applicable to a set -4- Houle - Direct :2 3 4 5 6 7 8 9 10 11 12 13 14 lb 17 18 19 20 21 22 23 24 25 26 27 28 ....9 Q. A. Q. A. A. Q. of pre-determined pricing periods. This energy-based pricing provides the customer with additional flexibility in pursuing demand side management activities and in controlling costs, For residential customers, Rate RTU1-M offers an expanded menu of time-of-use energy prices in addition to the on-peak/off-peak energy prices offered under existing Residential Time-of-Use, Rate RTU. The proposed rates also include a facilities charge that recovers the system costs associated with transmission and distribution facilities. In the existing rates, these facilities costs are rolled into the energy charges for those customers with non-demand billing and are contained in the demand charge (along with production costs) in rates with demand billing. IV. DEVELOPMENT Of TIME-Of-USE PRICING PERIODS PLEASE DESCRIBE THE TIME-OF-USE PRICING PERIODS INCLUDED IN THE PROPOSED RATES. The proposed tariffs contain an identical table that classifies each weekday and weekend hour into one of four pricing periods, denoted as Pricing Periods 1-4. An enlarged version of this table is included as Exhibit SJH-4. HOW WERE THESE TIME-OF-USE PERIODS DETERMINED? The analyses described below identified four distinctive load groups based on the relationship of both the average hourly load and the maximum hourly load to the annual system peak demand. A summary of the system load data that were used to determine these time-of-use pricing periods are shown in Exhibits SJH-5 and SJH-6. HOW DID YOU DETERMINE WHICH HOURS TO INCLUDE IN EACH PRICING PERIOD? The classification of each hour was based on an assessment of three primary factors: (1) the average load for each hour in a given month as a percentage of the Company's annual system peak; (2) the maximum load for each hour in a given month as a percentage of the Company's system peak demand; and (3) simplifying the application of Rates GTU-M. RTU1-M, and GTUC-M to the maximum extent -5- Houle - Direct 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 _6 17 18 19 20 21 22 23 24 25 26 27 28 29 a. possible, HOW WERE THE AVERAGE HOURLY LOADS USED TO DEVELOP THE PRICING PERIODS IN THE PROPOSED RATES? The Company's average hourly load (as a percentage of the annual peak load) was analyzed for each month in the three-year period ending in December 1996, to determine the hourly variation of the load and the average hourly load compared to the annual peak load. The main conclusions that can be drawn from a review of Exhibit SJH-5 are as follows: (1) The average hourly loads in the months of December - February exhibit both a morning and an afternoon peak, with a maximum average weekday load of about 60% of the Company's peak load. (2) The average hourly loads in the months of March and November exhibit a load pattern with relatively minor morning and evening peaks of about 55% of the annual peak. (3) The average hourly loads in the months of April and October exhibit a load pattern with a fairly constant average weekday load of about 55% of the peak. (4) The average hourly loads in the months of May and September, for both weekdays and weekends, exhibit a load pattern that is very similar to the Company's traditional summer load pattern, but at lower percentages of the Company's peak load (about 70% to 75% of the annual peak). (5) The average hourly loads in the months of June - August exhibit the Company's familiar summer load pattern characterized by a rapid increase in load beginning at 5:00 a.m. to 6:00 a.m., peaking at 5:00 p.m., and gradually decreasing, but remaining at relatively high levels, throughout the remainder of the day. The average peak weekday load during June - August is about 85% to 90% of the annual peak load, and the average peak weekend load is about 75% A. -6- Houle - Direct 1 .2 3 4 5 6 7 8 9 10 11 12 13 14 15 17 18 19 20 21 22 23 24 25 26 27 28 29 a. A a. .5 A to 80% of the annual peak. DOES THE AVERAGE HOURLY LOAD DATA FOR EACH MONTH PROVIDE A SUFFICIENT BASIS FOR DETERMINING WHICH HOURS SHOULD BE INCLUDED IN EACH PRICING PERIOD? No. While the average hourly load in each month provides a reasonable starting point for such a determination, the averaging process often conceals the peak load requirements in a given month. These peak load requirements result from weather- related fluctuations in the Company's load. For example, the highest average hourly load in February (1994-1996) is about 60% of the annual peak demand. However, from February 1 through February 5, 1996, the hourly load exceeded 70% of the annual peak demand in 59 hours and 75% of the annual peak demand in 26 hours. Clearly, the average hourly load does not capture the peak load requirements of the TU Electric system and, as such, are not sufficient to form the sole basis for the assignment of hours into time-of-use pricing periods. HOW WERE THE MAXIMUM HOURLY LOADS USED IN THE DEVELOPMENT OF THE PRICING PERIODS IN THE PROPOSED RATES? The hourly loads for the peak day(s) in each month of 1996 were analyzed to determine how the peak loads in each month relate to one another with respect to the magnitude of the monthly peak demand and the daily load patterns experienced in each month. As a result, common load relationships were noted in four distinct monthly groups: (i) December - March; (ii) April, October, and November; (iii) May and September; and (iv) June - August. The main conclusions that can be drawn from a review of Exhibit SJH-6 are as follows: (1) The maximum hourly loads in the months of December - March exhibit both an morning and an afternoon peak, with the maximum load of about 80% of the Company's peak load. (2) The maximum hourly loads in the months of April, October, and November do not deviate significantly from the average values. (3) The maximum hourly loads in the months of May and September, -7- Houle· Direct 3 4 5 6 7 8 9 10 11 12 13 14 15 17 18 19 20 21 22 23 24 25 26 27 28 29 , A. Q. approach 85% to 95% of the annual peak. (4) The maximum hourly loads in the months of June - August exhibit the same pattern as the average hourly load pattern for these months, but at a higher percentage of the Company's peak load. HOW DID THE NEED FOR SIMPLIFYING THE APPLICATION OF THE PROPOSED RATES AFFECT THE DEVELOPMENT OF THE PRICING PERIODS? Rates with an overly-complex pricing structure typically discourage customer acceptance. One way to simplify these rates is to limit the number of times per year that the pricing period changes. The proposed rates are limited to weekday and weekend pricing periods in four seasonal groups. In addition, the two pricing periods with the highest prices (Pricing Periods 3 and 4) occur only in the five consecutive months of May - September. The simplicity of these rates is also enhanced by having as many pricing periods throughout the year as possible begin or end at certain "key" hours (e.g., as shown in Exhibit SJH-4, many pricing periods begin at 10:00 a.m. or 2:00 p.m. and many pricing periods end at 2:00 p.m. or 10:00 p.m.). The Company has attempted to strike a balance between the multiple pricing periods needed to send proper pricing signals and the need to simplify the application of the rates as much as possible. Also, meter costs and technology must be considered. The proposed rate structure can be administered using existing meter technology. HOW WERE THE HOURS IN A GIVEN MONTH OF THE YEAR ASSIGNED TO THE FOUR PRICING PERIODS? Pricing Period 1 represents the hours for which the Company's average load is less than about 60% of its annual peak demand and for which the maximum load does not consistently exceed about 66% of the annual peak demand. For example, as shown in Exhibit SJH-4, all hours in the months of April, October, and November are in Pricing Period 1. Pricing Period 1 contains 5,880 hours, or about 67.1 % of the hours in a year. Pricing Period 2 includes: (i) the peak load hours during the months of A. Q. -8. Houle - Direct 3 4 5 6 7 8 9 10 11 12 13 14 15 17 18 19 20 21 22 23 24 25 26 27 28 29 1 December - March, (ii) some of the "shoulder" load hours in May - September. and (iii) the weekend peak hours in the months of May and September. Pricing Period 2 represents the hours for which the Company's average load is typically about 60% to 70% of its annual peak demand, although for relatively few hours during the winter months, the hourly load can exceed 80% of the Company's traditional summer peak load. These relatively few high load hours are offset by the number of winter days when the maximum hourly load is less than 60% of the system peak load. The maximum hourly load in this period typically ranges from about 66% to about 80% of the annual peak demand. Pricing Period 2 contains 1,640 hours, or about 18.7% of the hours in a year. Pricing Period 3 includes: (i) the peak load hours during the months May - September, (ii) the weekend peak load hours in the months of June - August, and (iii) some of the "shoulder" load hours on weekdays in June - August. Pricing Period 3 represents the hours for which the Company's average load is between 70% and 80% of the annual peak demand and for which the maximum load is typically about 80% to 92% of the annual peak demand. Pricing Period 3 contains 854 hours, or about 9.7% of the hours in a year. Pricing Period 4 includes the peak load hours (weekdays from 2:00 p.m. to 8:00 p.m.) during the months June, July, and August. Pricing Period 4 represents the hours for which the Company's average load is greater than 80% of the annual peak demand and for which the maximum load is typically more than about 92% of the annual peak demand. During this period, the Company's costs are usually the highest due to the need to use additional peaking capacity for extended periods in order to meet its load. Pricing Period 4 contains 384 hours, or about 4.4% of the hours in a year. Q. V. COST BASES & RATE DESIGN PLEASE EXPLAIN THE BASIS FOR THE MONTHLY CUSTOMER CHARGES IN THE PROPOSED RATES. The customer charges in Rate GTU-M vary according to the type of service required A. ·9· Houle· Direct 3 4 5 6 7 8 9 10 11 12 13 14 15 17 18 19 20 21 22 23 24 25 26 27 28 29 1 ¿ .) A. Q. (i.e., secondary, primary, or transmission) and are the same as those for the Company's General Service time-of-use rates approved in Docket No. 11735. The customer charge proposed for Rate RTU1-M, Residential Time-of-Use Service - Municipality, is $9.00 per month. TU Electric has an existing Residential Time-of- Use Rate (TU Electric's Rate RTU - Residential Time-of-Use Service, a two-step time-of-use rate), which would remain in effect after the approval of the new rate, that has a customer charge of $9.00 per month. The proposed customer charge in Rate RTU1-M would make the two charges the same and would simplify customers' ability to choose between the two rate options. The customer charges in Rate GTUC-M also vary according to the type of service required and are equal to the sum of the Rate GTU-M customer charges plus a $200 charge to recover the cost of additional metering and communications equipment and the administrative costs associated with curtailable service. WHAT IS THE BASIS FOR THE FACILITIES CHARGES IN THE PROPOSED RATES? The Facilities Charges are based on the Company's unbundled transmission and distribution costs, adjusted for losses. These charges are applied to the higher of the customer's maximum annual demand or contract demand. The calculation of the facilities charges for secondary, primary, and transmission voltage customers for Rates RTU1-M, GTU-M, and GTUC-M are as shown in Exhibit SJH-7. WHAT IS THE PURPOSE OF THE $1.00/KW FACILITIES CHARGE FOR DEMAND IN EXCESS OF THE CONTRACT DEMAND? This charge is designed to partially recover the costs associated with possible equipment failures and related engineering studies, and with the administrative work associated with reevaluating and recontracting for higher electric loads, when the customer places a higher demand on the Company's facilities than the customer has contracted for. This charge also acts as an incentive to customers to adjust their contractual arrangements with the Company, so that the types of expenses mentioned above can be avoided. This provision is identical to the $1/kW charge Q. A. -10- Houle - Direct 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 17 18 19 20 21 22 23 24 25 26 27 28 29 A. ) Q, for demand in excess of the contact demand that was approved in Docket No, 11735 for the Company's General Service rates. HOW WERE THE ENERGY CHARGES IN RATE GTU-M DERIVED FOR EACH OF THE FOUR PRICING PERIODS, AS SHOWN IN EXHIBIT SJH-1? The calculations of the energy prices in Rate GTU-M are shown in Exhibit SJH-8. These calculations are based on the Company's demand and energy usage data for the 12 months ending in December 1996. The methodology used to determine these charges can be summarized as follows: , (1) Calculate the average of the maximum demands in each month, for each pricing period, from the data tabulated in Exhibit SJH-8, Sheet 3. For example, the maximum monthly demands during Pricing Period 4 for the three months with Pricing Period 4 hours (June - August) are 19,382 kW, 19,668 kW, and 19,268 kW, respectively. Thus, the average monthly maximum demand for Pricing Period 4 is 19,439 kW (see column [1] of Exhibit SJH-8, Sheet 1). (2) Develop a demand allocation percentage for each of the four Pricing Periods based on the ratio of the average monthly maximum demand for each pricing period to the total of the average monthly maximum demands for Pricing Periods 1-4 (67,640 kW). Thus. the Demand Allocator for Pricing Period 4 is 19,439 kW divided by 67,640 kW, or 28.74% (see column [2] of Exhibit SJH-8, Sheet 1). (3) Determine the number of hours in each pricing period (see column [3] of Exhibit SJH-8, Sheet 1). (4) Allocate the system-wide Annual Production Revenue Requirement (excluding fuel) of $2.743 billion from the Company's latest Public Utility Commission-approved functionalized cost-of-service study (based on the Final Order in Docket No. 11735) to each pricing period, by multiplying the total revenue requirement by the demand allocator for each pricing period. For example, the Revenue -11- Houle - Direct 3 4 5 6 7 8 9 10 11 12 13 14 15 17 18 19 20 21 22 23 24 25 26 27 28 29 1 Q. A. Q. A. Q. A. Requirement applicable to Pricing Period 4 is 28.74% of $2,743 billion, or approximately $788 million (see column [4] in Exhibit SJH-8, Sheet 1). (5) Determine the number of kilowatt-hours consumed during each of the four pricing periods (see column [5] in Exhibit SJH-8. Sheet 1), (6) Calculate the unit charges for each pricing period by dividing the revenue requirement for each pricing period (column [4] in Exhibit SJH-8, Sheet 1) by the number of kilowatt-hours in each pricing period (column [5] in Exhibit SJH-8, Sheet 1). For example, for Pricing Period 4, the energy charge is $788 million divided by 6.362 billion kWh, or 12.39¢/kWh. (7) Adjust the unit charges for each pricing period by the appropriate loss factor to determine the energy charges for service at secondary, primary, and transmission voltages. These loss factors. and the energy charges for each voltage level and pricing period, are shown in Exhibit SJH-8, Sheet 2. HOW WERE THE ENERGY CHARGES IN RATE RTU1-M DERIVED FOR EACH OF THE FOUR PRICING PERIODS, AS SHOWN IN EXHIBIT SJH-2? The energy charges in each pricing period in Rate RTU1-M were determined by the same methodology described above for Rate GTU-M. HOW WERE THE ENERGY CHARGES IN RATE GTUC-M DERIVED FOR EACH OF THE FOUR PRICING PERIODS, AS SHOWN IN EXHIBIT SJH-3? The energy charges in each pricing period in Rate GTUC-M were determined by applying a 45% reduction to the system production cost. Otherwise, the energy charges were determined by the same methodology described above for Rate GTU-M. WHAT IS THE BASIS FOR THIS REDUCED ENERGY CHARGE? The energy charges in Rate GTUC-M were designed to recover the same percentage of the Company's production costs as is recovered from the Company's -12- Houle - Direct 9 10 11 12 13 14 15 17 18 19 20 21 22 23 24 25 26 1 1. 3 4 5 6 A. 7 8 a. A. a. A. a. A. a. Noticed Interruptible Rate,' This is an appropriate basis for the energy charges in Rate GTUC-M because the value of curtailable service to the Company is essentially the same as that of noticed interruptible service. HOW WILL THE COST OF FUEL BE RECOVERED UNDER RATES GTU-M, RTU1-M, AND GTUC-M? As shown in Exhibits SJH-1, SJH-2, and SJH-3, the applicable fuel cost is determined in accordance with the Company's Rider FC, which is applicable to the Company's standard Residential and General Service rates. HOW WILL THE COST OF PURCHASED POWER BE RECOVERED UNDER RATES GTU-M, RTU1-M, AND GTUC-M? As shown in Exhibits SJH-1 SJH-2, and SJH-3. purchased power costs are determined in accordance with the Company's Rider PCR. This is the same cost recovery mechanism that is applicable to the Company's standard Residential and General Service rates. VI. SPECIAL PROVISIONS OF PROPOSED RATES PLEASE EXPLAIN THE AGGREGATE BILLING OPTION PROPOSED IN RATES GTU-M AND GTUC-M. This option allows customers with several points of delivery to receive a single monthly bill, provided the following criteria are met: (i) all points of delivery are billed on the same voltage level service; (ii) all points of delivery are on the same billing cycle; and (iii) all points of delivery are under the same ownership. A one-time charge of $25 for each point of delivery is made under this billing option in order to recover the administrative costs associated with this service. PLEASE DESCRIBE THE BASES FOR THE CURTAILMENT PROVISIONS INCLUDED IN RATE GTUC-M. Rate GTUC-M limits the curtailment of the customer's load to no more than 700 Noticed Interruptible Service (NIS) includes both a demand charge (that is 50% of the demand charge for comparable firm service rate) and an energy charge. with 5% of the demand·related production costs recovered in the energy charge, Hence. the net production cost discount for NIS customers is 45%, -13- Houle - Direct 1 hours in the last 12 months and no more than 12 hours in any 24 hour period. except that the 12 hour limit is not applicable during system emergencies when the Company has made public pleas to restrict electric energy usage to essential needs because of an area or statewide shortage of electric power and/or energy. These provisions are identical to those applicable to noticed interruptible service, as contained in the Company's Rider I. In lieu of interrupting equipment, Rate GTUC- M contains an energy charge applicable during a curtailment period of 70¢ per kilowatt-hour unless the customer actually curtails at least 35% of its total load throughout the curtailment period, in which case, the energy charge is 50¢ per kilowatt-hour. The 35% minimum voluntary curtailment in order to qualify for the 50¢ energy price, rather than the 70¢ energy price, is applicable to the total load at each individual point of delivery if the customer has not selected the Aggregate Billing Option or to the total load of all of a customer's points of delivery under Rate GTUC-M that are aggregated under the Aggregate Billing Option provided for in Rate GTUC-M, with total load being defined as the customer's 15-minute demand recorded immediately prior to the customer's receipt of notice from the Company of the curtailment period. This alternative curtailment period energy price is purposed to provide further encouragement to the customer to curtail load during a curtailment period, without imposing such a high price as to make the marketing of this rate impossible. This provision is designed to replace the active control hardware required for service under Rider I and assures that the Company will be able to recover the costs of capacity and energy used by a Rate GTUC-M customer in the event the customer chooses not to curtail load when requested to do so. This pricing level also represents a price that will exceed the outage costs of most customers and, in so doing, sends the proper price signal to any customer that might otherwise ignore a curtailment request. The Company will request customers served under Rate GTUC-M to curtail their loads within 15 minutes after either of the following occurrences: (i) when the Company is required by the ERCOT Independent System Operator to interrupt 3 4 5 6 7 8 9 10 11 12 13 14 15 17 18 19 20 21 22 23 24 25 26 27 28 29 -14- Houle - Direct 1 3 4 5 6 7 8 9 10 11 12 13 14 15 Q. A. 17 18 19 20 21 22 23 Q. 24 A. (noticed) interruptible loads; or (ii) when the Company's hourly load is at or above 95% of the estimated system peak load for the current calendar year. In the event that the actual system peak load exceeds the estimated system peak load, the actual system peak load automatically becomes the new estimated system peak load on the next day. PLEASE EXPLAIN THE BASES FOR SPECIAL CONDITIONS (c) AND (d) IN RATE GTUC-M. The initial three-year term of service is required to assure some reasonable level of cost recovery for the Company's facilities used to serve the curtailable load. The initial three-year term and the one-year termination notice allow the Company the time to adjust its planning process associated with securing capacity resources. These terms are also needed to prevent customers from attempting to "game the system" by switching back and forth between firm service and curtailable service. Special Condition (c) requires the customer to pay the difference between the billings under Rate GTUC-M and what the billings would have been under the applicable firm service rate (i.e., Rate HV - High Voltage Service. Rate GP - General Service Primary, or Rate GS - General Service Secondary, depending upon the voltage level of the service provided at the point of delivery) for a period not to exceed three years if the customer decides to switch from Rate GTUC-M during the initial term of the Agreement for Electric Service and not to exceed two years if the customer decides to switch from Rate GTUC-M during a subsequent term. Interest would also be payable on such difference at the rate applicable to undercharges. DOES THIS CONCLUDE YOUR DIRECT TESTIMONY? Yes, it does. -15- Houle - Direct STATE OF TEXAS § § COUNTY OF DALLAS § BEFORE ME, the undersigned authority, on this day personally appeared Stephen J. Houle, who, having been placed under oath by me, did depose as follows: My name is Stephen J. Houle. I am of legal age and a resident of the State of Texas. The foregoing direct testimony and the attached exhibits offered by me are true and correct, and the opinions stated therein are, to the best of my knowledge and belief, accurate, true and correct. ~~ 'J ~....l , Stephen ~. ~ ¡IIIL SUBSCRIBED AND SWORN TO BEFORE ME by the said Stephen J. Houle this 1.:::::..- day of -:r~, 1999. rä- - -- y- -- ,-~~,";¡-~-~~- 1 TERI SMAIl' ; .... . Mt·COtNJISK!N'" : ~ November 13. 2000 , , . !2 /'~ ~bliC. Slate of Texas - -------------...--------- ·16· Tariff for Electric Service Texas Utilities Electric Company Exhibit SJH-} Page 1 of 2 Sheet 25 Page I of 2 Revision: Original 3.2 General Service Applicable: Cities Exercising Original Jurisdiction Effective Date: 3.2.25 Rate GTU-M - General Service Time-of-Use Municipality Application Applicable to any customer for all electric service supplied at one point of delivery and measured through one meter. Each point of delivery is metered and billed separately, UlÙess the Aggregate BiUing Option is selected, A time-of-day demand meter or interval recorder is required prior to service being provided under this rate. Not applicable to temporary, shared, or resale service, Type of Service Single or three phase, 60 henz, at the most available secondary, primary, or transmission voltage, Where service of the type desired by Customer is not already available at the point of delivery, additional charges and special contract arrangements between the Company and Customer may be required prior to service being furnished. The Company may, at its option. meter service on the secondary side of Customer's transfonners and adjust for transfonner losses in accordance with Company's Tariff for Electric Service, Monthly Rate Pricing Period 2 Amount Secondary Primary TraDsmission (GTU·M.sEC) (GTU-M-PRI) (GTU·M-TRAN) $24,00 $25.00 $425,00 $3.47 per kW $2.74 per kW $1.08 per kW $1.00 per kW $1.00 per kW $1.00 per kW 13,42 ç per kWh 13.02 ç per kWh 12,78 ç per kWh 6.18 ç per kWh 5.99 ç per kWh 5,88 ç per kWh 3,50 c per kWh 3.39 ç per kWh 3.33 ç per kWh 1.09 ç per kWh 1.06 ç per kWh 1.04 ç per kWh Charge Customer (per point of delivery) Facilities Charge (per point of delivery) Higher of the Contract kW or Annual kW Each current month JeW in excess of the Contract kW Energy Pricing Period 4 Pricing Period 3 Pricing Period 1 Fuel Cost: Plus an amount for fuel cost calculated in accordance with Rider FC, using the General Service-Secondary factor for GTU-M· SEC, the General Service-Primary factor for Gro-M·PR!. and the General Service-Transmission factor for GTU·M-TRAN, Power Cost: Plus an amount for purchased power cost calculated in accordance with Rider PCR, using the General Service Secondary f.1ctor for GTU·M-SEC, the General Service Primary factor for GTU-M-PRI, and the High Voltage Service factor for GTU·M-TRAN. Payment: Bills are due when rendered and become past due if not paid within 16 days thereafter. Bills are increased by 5% if not paid within 20 days after being rendered. Aggregate Billing Option An entity with multiple points of delivery receiving service under Rate GTU-M may elect to receive an aggregate summary bill. Aggregate billing is available to entities that meet all of the following criteria: a) all points of delivery are billed on the same voltage level service, b) all points of delivery are on the same billing cycle, and c) all points of delivery are under the same ownership, A one-time charge of $25 per point of delivery is made when Customer selects the Aggregate Billing option. Defmitions Contract kW is the maximum kW specified in the Agreement for Electric Service. o 1999 Texas Utilities Electric Company Rate Schedules 29.24 Tariff for Electric Service Texas Utilities Electric Company Exhibit SJH-! Page 2 of 2 Sheet 25 Page 2 of 2 Revision: Original 3,2 General SelVice Applicable: Cities Exercising Original Jurisdiction Effective Date: Annual kW is the highest IS-minute kW recorded at the point of delivery during the 12-month period ended with the current month. Current month kW is the highest 1 S-minute kW recorded at the point of delivery during the current month, Pricing Period is the billing period determined in accordance with the following and the specified hours are local Dallas. Texas. time: December - March N/A N/A N/A N/A Pricing Period 2 Pricing Period 1 Weekdays Weekends 6 a m . N/A All Other Hours 12noon 6pm-1Opm N/A N/A All Hours Pricing Period 4 Pricing Period 3 Month Weekdays Weekends Weekdays Weekends April & October - N/A N/A November May & September N/A N/A June - August 2pm-8pm NJA N/A N/A 2pm-8pm NJA lOam-2pm 2pm-1Opm All Other Hours 8pm'10pm lOam-2pm 2pm-lOpm 8am-10am 1 Oam·2pm All Other Hours 8pm-lOpm lOpm-12 1Opm-12 midlÙght midlÙgbt Special Conditions (a) Where customer has another source of power that is connected, either electrically or mechanically, to equipment that may be operated concurrently with selVice provided by Company, Customer must install and maintain, at Customer's expense, such devices as may be necessary to protect Customer's and the Company's equipment and service. (b) Customers may discontinue selVice under Rate Gro·M and change selVice to an otherwise applicable Company rate during the first year without penalty. Agreement An Agreement for Electric Service with a term of not less than three years is required. The maximum e1ectricalload specified in the Agreement for Electric SelVice may not be less than the sum of Customer's nonnalload plus the load that may be carried all or pan of the time by Customer's generator or prime mover or other source of energy. Notice SelVice hereunder is subject to the orders of regulatory bodies having jurisdiction and to the Company's Tarit! for Electric SelVice. c 1999 Texas Utilities Electric Company Rate Schedules 29.2S Tariff for Electric Service Texas Utilities Electric Company Exhibit SJH-2 Page 1 of 2 Sheet: 8 Pa¡:e I or 2 Revision: Ori~inal 3.1 Residential Service Applicable: Cities Exercising Original Jurisdiction Effective Date: 3.1.8 Rate RTUI-M - Residential Time-or-Use Service - Municipality Application Applicable to all customers for aJl of the electric service supplied at one point of delivery and measured through one meter used for residential purposes (which may include small amounts of commercial usage incidental to residential usage) in an individual private dwelling or in an individually metered apartment for which no specific rate is provided, A time-of-day demand meter is required prior to service being provided under this rate, Not applicable to temporary, shared, or resale service, Type of Service Single or three phase, 60 hertz, at standard voltages as described in the Company's Tariff for Electric Service, Where service of the type desired by Customer is not already available at the point of delivery, additional charges and special contract arrangements between the Company and Customer may be required prior to service being furnished, Monthly Rate Charge Amount Customer S9.oo Facilities Charge Higher of the Contract kW or Annual kW S1.92 per kW S1.oo per kW 13.42 c per kWh Each cum:nt month kW in excess of the Contract kW Energy Pricing Period 4 Pricing Period 3 Pricing Period 2 Pricing Period 1 6.18 c per kWh 3.50 c per kWh 1.09 c per kWh Fuel Cost: Plus an amount for fuel cost calculated in accordance with Rider FC, using the Residential Service factor, Power Cost: Plus an amount for purchased power cost calculated in accordance with Rider PCR, using the Residential Service factor, Payment: Bills are due when rendered and become past due if not paid within 16 days thereafter, Definitions Contract kW is the maximum kW specified in the Agreement for Electric Service, Annual kW is the highest IS-minute kW recorded at the point of delivery during the 12-month period ended with the current month, Current month k W is the highest IS·minute kW recorded at the point of delivery during the current month, 01999 Texas Utilities Electric Company Rate Schedules 11.S Tariff for Electric Service Texas Utilities Electric Company Exhibit SJH-2 Page 2 of 2 Sheet: 8 Page 2 of2 Revision: Ori!!inal 3,1 Residential Service Applicable: Cities Exercising Original Jurisdiction Effective Date: Pricing Period is the billing period detennined in accordance with the following and the specified houn are local Dallas, Texas, time: Pricing Period 4 Pricin¡ Period 3 Pricing Period 2 Month Pricing Period I Weekdays Weekends Weekdays Weekends Weekdays Weekends December - March N/A N/A N/A N/A 6 a m - N/A All Other Hours 12noon 6pm-1Opm April & October - N/A N/A N/A N/A N/A N/A All Hours November May & September N/A N/A 2pm-8pm N/A IOam·2pm 2pm-lOpm All Other Hours 8pm-lOpm June· August 2pm-8pm N/A 1 Oam-2pm 2pm-lOpm Sam· 1 Oam lOam-2pm All Other Hours 8pm-lOpm lOpm-12 lOpm-12 midnight midnight Agreement An Agreement for Electric Service with a term of not less than one year is required, If Customer terminates service on this rate, said Customer is ineligible for service under this rate for a period of one year from tcnDination date, If Customer tenninatc5 service before the end of the initial one year tenn of service, the fmal bill will include an adjustment for the amount by which billing on Residential Service Rate R exceeds the billing rendered on this rate, Ifservice is tcnDinated due to the Company's withdrawing this rate, the above adjustment to the fmal bill does not apply, Notice Service hereunder is subject to the orders of regulatory bodies having jurisdiction and to Company's Tarifffor Electric Service, 01999 Texas Utilities Electric Company Rate Schedules 11.6 Tariff for Electric Service Texas Utilities Electric Company Exhibit SJH-3 Page 1 of 3 Sheet 26 Page I of 3 Revision: Original 3,2 General Service Applicable: Cities Exercising Original Jurisdiction Effective Date: 3.2.26 Rate GTUC-M General Service Time-of-Use Voluntary Curtailable - Municipality Application Applicable to any customer for all electric service supplied at one point of delivery and measured through one meter, Each point of delivery is metered and billed separately, unless the Aggregate Billing Option is selected, An interval demand recorder is required prior to service being provided under this rate, The applicability of this rate is limited, on a first-comc-first-served basis, to a maximum total contracted load from all Customers of 1,000 MW (i.e,. a total of all Customers' Contract kW) for the Company's summer peak season of 1999 and 2,000 MW for the Company's peak season of 2000 and thereafter, Not applicable to temporary. shared, or resale service, Type of Service Single or three phase, 60 henz, at the most available secondary, primary, or transmission voltage, Where service of the type desired by Customer is not already available at the point of delivery, additional charges and special contract amngements between the Company and Customer may be required prior to service being furnished, The Company may, at its option, meter service on the secondary side of Customer's transfonners and adjust for transfonner losses in accordance with Company's Tariff for Electric Service, Monthly Rate Pricing Period 3 Amount Secondary Primary Transmission (GTUC·M-SEC) (GTUC-M·PRI) (GTUC·M·TRAN) $224.00 $225.00 $625.00 $3,47 per kW $2.74 per kW $1.08 per kW $1.00 per kW $1.00 per kW $1.00 per kW 7,38 C per kWh 7,16 C per kWh 7,03 C per kWh 3.40 C per kWh 3.29 C per kWh 3,23 C per kWh 1.92 C per kWh 1.86 C per kWh 1.83 C per kWh 0,60 c per kWh 0.58 C per kWh 0.57 c per kWh Charge Customer (per point of delivery) Facilities Charge (per point of delivery) Higher of the Contract kW or Annual kW Each current month kW in excess of the Contract kW Energy Pricing Period 4 Pricing Period 2 Pricing Period 1 Fuel Cost: Plus an amount for fuel cost calculated in accordance with Rider FC, using the General Service-Secondary factor for GTUC-M- SEC, the General Service-Primary factor for GTUC-M·PRI, and the General Service-Transmission factor for GTUC·M-TRAN, Power Cost: Plus an amount for purchased power cost calculated in accordance with Rider PCR, using the General Service Secondary factor for GTUC-M-SEC, the General Service Primary factor for GTUC-M-PRI, and the High Voltage Service factor for G11JC-M·TRAN. Payment: Bills are due when rendered and become past due if not paid within 16 days thereafter. Bills are increased by 5 % if not paid within 20 days after being rendered, Curtailment Provisions Customer's load will be subject to no more than 700 hours of curtailment during the 12 months ending with the current month and no more than 12 hours in any 24 hour period, except when the Company has made public pleas to restrict electric energy usage to essential needs because of an area or statewide shortage of electric power and/or energy, then the 12 hour limit no longer applies, Customer will have IS minutes in which to-voluntarily curtail all of the load at the point of delivery or, if Customer chooses not to curtail all of the load at the point of delivery, all kWh used during the curtailment period will be billed at an energy charge of 70C per kWh, rather than at the energy charge specified above, provided that, in the event the Customer curtails 35 % or more of the total load at a point of delivery not included in the Aggregate Billing Option, or 35 % or more of the total load at all points of delivery to the Customer aggregated under the Aggregate Billing Option, throughout the curtailment period, the energy charge for all kWh used during the curtailment period at such point(s) of delivery will be billed at an energy charge of 50c per kWh, Total load (either at a single point of delivery or aU of Customer's points of delivery under the Aggregate BiUing Option) is defined as the Customer's IS-minute demand recorded immediately prior to Customer's receipt of the notice from Company of the curtailment period, II 1999 Texas Utilities Electric Company Rate Schedules 29,26 Tariff for Electric Service Texas Utilities Electric Company Exhibit SJH-3 Page 2 of 3 Sheet 26 Page 2 of 3 Revision: Original 3,2 General Service Applicable: Cities Exercising Original Jurisdiction Effective Date: Curtailments will occur during the following conditions: (a) when the Company is required by the Electric Reliability Council of Texas (ERCOT) Operating Guides or the ERCOT Independent System Operator (ISO) to interrupt interruptible loads. The curtailment period is the entire period during which ERCOT Operating Guides or the ERCOT ISO requires the Company to interrupt interruptible loads, begiDlÙng 15 minutes after Customer is requested to curtail load, or (b) when the Company's system load is at or above 95% of the higher of (I) the estimated system aMual peak load for the current calendar year or (2) the actual system peak load for the current calendar year, In the event that the actual system peak load in the calendar year exceeds the previously estimated system aMual peak load for that calendar year, such actual system peak load shall become the new estimated system aMual peak load begiDlÙng on the following day, The curtailment period is the entire period during which the Company's system load is at or above 95% of the estimated system aMual peak load for the current year, beginning 15 minutes after Customer is requested to curtail load, Aggregate Billing Option An entity with multiple points of delivery receiving service under Rate GTUC·M may elect to receive an aggregate summary bilI, Aggregate billing is available to entities that meet aU of the following criteria: a) all points of delivery are billed on the same voltage level service, b) all points of delivery are on the same billing cycle, and c) all points of delivery are under the same ownership, A one-time charge of $2S per point of delivery is made when Customer selects the Aggregate Billing option, Defmitions Contract kW is the maximum kW specified in the Agreement for Electric Service. Annual kW is the highest IS-minute kW recorded at the point of delivery during the 12-month period ended with the current month. Current month kW is the highest IS·minute kW recorded at the point of delivery during the current month, Hourly System Load is TU Electric's total system demand excluding non·finn economy energy sales. Pricing Period is the billing period detennined in accordance with the following and the specified hours are local DalIas, Texas, time: Pricing Period 4 Pricing Period 3 Weekdays Weekends Weekdays Weekends Pricing Period 2 Pricing Period I Weekdays Weekends 6 a m . N/A All Other Hours 12noon 6pm-lOpm N/A N/A All Hours Month December - March N/A N/A N/A N/A April & October - N/A N/A November May & September N/A N/A June· August 2pm-Spm N/A N/A N/A 2pm-Spm N/A 10am-2pm 2pm-lOpm All Other Hours Spm-l0pm 10am-2pm 2pm-lOpm Sam-lOam IOam-2pm All Other Hours Spm-IOpm 10pm-12 IOpm-12 midnight midnight Special Conditions a) Where customer has another source of power that is COMected, either electrically or mechanically, to equipment that may be operated concurrently with service provided by Company, Customer must install and maintain, at Customer's expense. such devices as may be necessary to protect Customer's and the Company's equipment and service, b) Customer must pay all costs associated with installing and maintaining any special metering equipment and telephone charges, if required , c) An Agreement for Electric Service is required for an initial tenn of three years when service is first rendered under this rate and for subsequent periods of 2 years thereafter. continuing until canceled by either party by written notice 1 year in advance of the end of the initial period or any subsequent period. Customers that discontinue curtailable service under Rate GTUC-M during the tenn of the o 1999 Texas Utilities Electric Company Rate Schedules 29.27 Tariff for Electric Service Texas Utilities Electric Company Exhibit SJH-3 Page 3 of 3 Sheet 26 Page 3 of 3 Revision: Ori!!inal 3.2 General Service Applic.1ble: Cities Exercising Original Jurisdiction Effective Date: Agreement for Electric Service shall be charged the difference between their billings under Rate GTUC-M and what their billings would have been under an applic.1ble firm service rate (either Rate HV, Rate GP, or Rate GS, depending upon the voltage level of the Customer's service) for the ilÙtial term the Customer received service under Rate GTUC-M, not to exceed three years, and not to exceed two years for subsequent tenns, plus interest thereon at the rate applic.1ble to undercharges established pursuant to the Conunission's Substantive Rule 23.3S(h), d) If it is detennined at any time by Company that the Customer has failed to operate and maintain commulÙc.1tions equipment in such a manner so that there c.1n be compliance with the provisions of this rate. then the Customer will be immediately billed on the rate schedule for firm power for the period since service was first commenced under this rate, or for the one year period just prior to such detennination. whichever period is less, The difference between the actual bills rendered and the amount so c.1lculated shall be adjusted each month to cover the Company's annual cost of c.1pital, compounded monthly from such month to date, as detennined in the Company's most recent rate c.1se by the Public Utility Commission of Texas, Such adjusted difference shall immediately become due by Customer to Company, Agreement An Agreement for Electric Service with a tenn of not less than three years is required, The maximum electric.1lload specified in the Agreement for Electric Service may not be less than the sum of Customer's normal load plus the load that may be c.1rried all or part of the time by Customer's generator or prime mover or other source of energy, Notice Service hereunder is subject to the orders of regulatory bodies having jurisdiction and to the Company's Tariff for Electric Service, œ 1999 Texas Utilities Electric Company Rate Schedules 29.28 II) II) II) ~ .... ~ ~ ::3 ::3 ::3 0 II) 0 0 .!:. ~ .!:. .!:. 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CÞ ... ~ =» ... c .- " c W ('\II ... .. ~ 0 :r Q ... co CD ~ ('\II Exhibit SJH· 7 Sheet 1 of 1 TEXAS UTILITIES ELECTRIC COMPANY Rates RTU1-M, GTU-M, and GTUC-M Calculation of Facilities Charges General Service Transmission Costs Residential Secondary Primary Transmission Annual Transmission Rev, Req.1 $89,491,596 $75,998,555 $14,447.382 $7.705,718 Class NCP (kW) 1 8.254.252 6,409.748 1,232,688 640.728 Avg, Class NCP ( kW ) 2 4.36 22.72 181,44 10.775,90 Avg. of Customer Max. Demand ( kW ) 2 10,63 30,48 210.41 11,507,24 Annual Cost I kW 3 $4.4469 $8.8381 $10.1065 $11.2622 Monthly Cost I kW $0.3706 $0.7365 $0.8422 $0.9385 General Service Distribution Costs Residential Secondary Primary Transmission Annual Distribution Rev, Req.1 $343.948,404 $258,477,275 $30,434,833 $902,854 Class NCP (kW) 1 8.254,252 6,409,748 1,232.688 640,728 Avg. Class NCP (kW) 2 4,36 22.72 181.44 10,775.90 Avg. of Customer Max. Demand ( kW ) 2 10.63 30,48 210.41 11,507.24 Annual Cost I kW 3 $17.0911 $30.0590 $21.2904 $1.3196 Monthly Cost I kW $1 4243 $2.5049 $1.7742 $0.1100 Total Monthly Cost / kW $1.7949 $3.'414 $'.6164 $1.0485 Demand-Related Loss Factor 1.07091 1.07091 1.048861 1.026417 Monthly Facilities Charges ($/kW) $1.92 $3.47 $2.74 $1.08 1 . Source: Functionalized Cost of Service Study based on the Final Order in Docket No, 11735, 2 . Avg, Class NCP and Avg. of Customer Max. Demand are based on the Company's load research data for the 12 months ending in December 1996, 3 . The Annual Cost per kW for each cost component is determined as follows: Cost Component = [ (Revenue Requirement) I (Class NCP) ] . ¡ (Avg, Class NCP) I (Avg, of Customer Maximum Demand) ] "'It > z « a.. :E o o o æ .... o w ~ w UJ w ~ ::¡ ~ :) en ~ w .... ~ ~ en 0" :) .2 .... '- C!)~ "0) c c ca ._ CJ ~.¡: .e. :) '- t;~ .. c :E .2 .- ~ ca :)c .... .- a:: E '- en Q) Q)- - Q) caO a:: cþ CJ .- '- a.. . 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""" TEXAS UTILITIES ELECTRIC COMPANY Monthly Peak Demands By Pricing Period 1996 Maximum Demand (MW) In Pricing Period: Month 1 2 3 4 January 15,160 15.826 February 15.371 15.775 March 13,355 15,162 April 13,746 May 14,531 16.308 17,804 June 13.189 16.133 18.359 19,382 July 13,694 16,856 18,746 19,668 August 13,150 16,4 77 18,013 19,268 September 14,719 15.884 16,601 October 13,328 November 14.316 December 15.605 16.624 Average 14.180 16,116 17,905 19,439 Exhibit SJH-8 Sheet 3 of 3