Annual Electric Balancing Authority Area and Planning Area Report
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1 Part I - Schedule 1. Identification and Certification Form Approved OMB Numbers: (Expires 05/31/2016) 1. Respondent Identification: Code: Name: 3. Respondent Mailing Address: Chris Robinson P.O. Box 7 Tacoma, WA Respondent Type: (Please check appropriate box and fill in name) [ X ] Part I: Balancing Authority Area (Complete Parts I, II, and IV) [ ] Balancing Authority Area Name: Tacoma Power [ X ] Part II: Planning Area (Complete Parts I, III, and IV) Planning Area Name: Tacoma Power Unit dispatch is not based on the economic dispatch of thermal units (i.e., a system lambda is not calculated) 4 Contact Person: Name: Rhea Payne Title: Marketing Coordinator address: rpayne@ci.tacoma.wa.us Telephone #: Ext: 5. Certifying Official: Name: Chris Robinson /// Signed /// Title: Power Manager : 05/30/2013 This report is an X Original Revised Filing Page 1
2 Part II - Schedule 1. Generating Plants Included in Reporting Balancing Authority Area Under the name of its operating electric utility, list all generating plants (1) within the respondent's balancing authority area which are controlled, metered or for which the required information is otherwise available to balancing authority area operators and (2) dynamically scheduled plants or units outside the balancing authority area. Specifically identify dynamically scheduled plants. Report only plant totals with generators in an operating or standby status. Provide totals for columns and as a last line. The total in column should equal the value in column on Schedule 2 for the month of the annual peak demand. The total in column should equal the value in column on Schedule 3 for the month of the annual peak demand. Any differences must be explained in a footnote. Refer to the Form 714 instructions for specific guidelines. Line No Tacoma Power Electric Utility Name " " Alder La Grande " " Cushman #1 " " Cushman #2 " " Mayfield " " Mossyrock " " Wynoochee Grant County PUD Priest Rapids - Dynamic Schedule Plant Name TOTAL Plant Available Capacity at the Hour of the Annual Peak Demand on Net Energy for Load Integrated Net Load on the Plant at the Hour of the Annual Peak Demand Based on Net Energy for Load Page 2
3 Part II - Schedule 2. Balancing Authority Area Monthly Capabilities at of Monthly Peak Demand The peak demand and other terms used in this schedule are defined in the Form 714 instructions. Please first read the instructions, then complete this Schedule. The value in column for the month of the annual peak demand should equal the total in column in Schedule 1. Any difference must be explained in a footnote. Net Capability at the of the Monthly Peak Demand, Based on Balancing Authority Area Area Net Energy For Load (NEL) Net Capability from Plants Reported on Schedule II Unavailable Capability Due to: External to the Balancing Authority Area Net Unit or Firm Capability Line No Month Available Capability Planned Outage and Derating Unplanned Outage and Derating Other Outage and Derating* Total (c + d + e + f) Available Not Available Total Capability (g + h + i) 1 Jan ,361 2 Feb ,336 3 Mar , 4 Apr ,394 5 May , 6 Jun ,462 7 Jul ,457 8 Aug ,444 9 Sep 822 1,206 1, Oct , Nov , Dec ,353 Page 3
4 Part II - Schedule 3. Balancing Authority Area Net Energy for Load and Peak Demand Sources by Month Enter the monthly "Net Energy for Load" which is the amount of energy that the balancing authority area requires internally including balancing authority area losses. The total in column should equal the difference in the totals for columns minus on Schedule 5. The value in column for the month of the annual peak demand should equal the total in column in Schedule 1. Any differences must be explained in a footnote. Refer to the Form 714 instructions for specific guidelines. Balancing Authority Area Area Load Sources at of Balancing Authority Area Area Monthly Peak Demand, Based on Net Energy For Load (NEL) Line No Month Balancing Authority Area Net Generation (MWh) Net Actual Interchange (MWh) Net Energy for Load (MWh) (c + d) Output of Generating Plants Unit or Firm Purchases Unit or Firm Sales Net Non-Firm & Inadvertent Monthly Peak Demand (f+g-h+i) Monthly Minimum Demand 1 January 291, ,870, February 278, , , March 304, ,, April 331,997 62, 394, May 374, , June 352, -3, , July 287, 64, , August 198, , , September 203, , 334, October 208, ,, November 351,421 88, , December 431,036 73,938, Total 3,611, 1,358,609 4,970,078 Page 4
5 Annual Electric Balancing Authority Area and Planning PART IV: FOOTNOTE DATA Schedule Page: 4 Line No.: 6 Column: d For the month of June we had more exports than imports, thus making our net actual interchange negative. Footnotes.1
6 Part II - Schedule 4. Adjacent Balancing Authority Area Interconnections Identify on this schedule: each adjacent balancing authority area with which the respondent balancing authority area is interconnected in column, all the interconnection line or bus names with the adjacent balancing authority area in column, and the line or bus voltage in column. Refer to the Form 714 instructions for specific guidelines. Line No Name of Adjacent Balancing Authority Area Balancing Authority Area Interconnection Line or Bus Names Line or Bus Voltage (kv) Bonneville Power Administration " " " " " " " " " " " " " " " " " " " " " " " " " " " " " " Puget Sound Energy " " " Avista Corporation " " Pacificorp Chelan County PUD Seattle City Light Portland General Electric Grant County PUD Mayfield Switchyard Mossyrock Switchyard Northeast Substation Cowlitz Substation South Tacoma Canyon Scootney Substation Glade Substation Ringold Substation Wynoochee Substation Midway Pierce County Mutuals Midway Starwood Substation Midway Stratford Substation Midway " " " " Page 5
7 Part II - Schedule 5. Balancing Authority Area Scheduled and Actual Interchange Identify on this schedule: each balancing authority area with which the respondent balancing authority area has actual or scheduled interchange of energy, in column ; the total annual megawatthours (MWh) of the scheduled interchange that were received by the respondent balancing authority area through all interconnection points with each balancing authority area, in column ; the MWh of scheduled interchange delivered to each balancing authority area, in column ; the MWh of total annual actual interchange received and delivered within each adjacent balancing authority area, in columns and. Provide totals for columns,, and. The difference in the totals for columns minus should equal the total in column on Schedule 3. Any difference must be explained in a footnote. Refer to the Form 714 instructions for specific guidelines. Line No Name of Balancing Authority Area Scheduled Interchange Between Balancing Authority Area Areas (MWh) Received Delivered Actual Interchange Between Adjacent Balancing Authority Area Areas (MWh) Received Delivered Bonneville Power Administration Puget Sound Energy Avista Corporation Chelan County PUD Grant County PUD Pacificorp, West Portland General Electric Los Angeles Dept. of Water and Power Idaho Power Balancing Authority of Northern California California ISO British Columbia Hydroelectric Authority North Western Energy Turlock Irrigation District Imperial Irrigation District Nevada Power Company Salt River Project Tucson Electric Power Company Western Area Power Administration Arizona Public Service Company Pacificorp, East Sierra Pacific Power Company TOTAL 3,634, 10,254 2, , ,595 6,696 3,662,902, ,263 18, ,434 99,721 34,365 94, 8, 156, 441,882 25,404 45, 22, 329 1,755 1,064 1,044 1, 800 4,143 2,306,862 6,,797 3, 3, 6,605,917 4,,423, ,186 37, 5,247,308 Page 6
8 Part II - Schedule 6. Balancing Authority Area System Lambda Data For balancing authority areas where demand following is primarily performed by thermal generating units, the system lambda is derived from the economic dispatch function associated with automatic generation control performed at the controlling utility or pool control center. Excluding transmission losses, the fuel cost ($/hr) for a set of on-line and loaded thermal generating units (steam and gas turbines) is minimum 1/ when each unit is loaded and operating at the same incremental fuel cost ($/MWh) 2/ with the sum of the unit loadings equal to the system demand plus the net of interchange with other Balancing Authority Areas. This single incremental cost of energy is the system lambda. System lambdas are likely recalculated many times in one clock hour. However, the indicated system lambda occurring on each clock hour would be sufficient for reporting purposes. Respondents must provide the following data: the system lambda, in dollars, for each hour of the year starting with 1 a.m. January 1 as more fully described in the Form 714 instructions. In column indicate the time zone and the days for which daylight savings time was observed. This schedule will have 365 rows for the report year (366 rows for a leap year). Provide, as a footnote, an explanation describing the reason for the unavailability of system lambda information. The Commission expects that all Energy Management Systems, with proper instructions, can record the system lambda being used for economic dispatch of the balancing authority area's thermal units. Respondents should be able to report system lambda, along with the other information reported on a Balancing Authority Area basis, that describe the operation of such areas from information that should be readily available. The Commission is not requesting Respondents to develop incremental or marginal cost (either short or long term) according to any formula. Nor is the Commission requesting "avoided cost rates" that electric utilities file with state commissions or otherwise make available for prospective qualified facilities /01/ /02/ /03/ /04/ /05/ /06/ /07/ /08/ /09/ /10/ /11/ /12/ /13/ /14/ /15/ /16/ /17/ /18/ /19/ /20/ /21/ /22/ /23/ /24/ /25/2012 Page 7a
9 Part II - Schedule 6. Balancing Authority Area System Lambda Data (continued) /26/ /27/ /28/ /29/ /30/ /31/ /01/ /02/ /03/ /04/ /05/ /06/ /07/ /08/ /09/ /10/ /11/ /12/ /13/ /14/ /15/ /16/ /17/ /18/ /19/ /20/ /21/ /22/ /23/ /24/ /25/ /26/ /27/ /28/ /29/ /01/2012 Page 7a.1
10 Part II - Schedule 6. Balancing Authority Area System Lambda Data (continued) /02/ /03/ /04/ /05/ /06/ /07/ /08/ /09/ /10/ /11/ /12/ /13/ /14/ /15/ /16/ /17/ /18/ /19/ /20/ /21/ /22/ /23/ /24/ /25/ /26/ /27/ /28/ /29/ /30/ /31/ /01/ /02/ /03/ /04/ /05/ /06/2012 Page 7a.2
11 Part II - Schedule 6. Balancing Authority Area System Lambda Data (continued) /07/ /08/ /09/ /10/ /11/ /12/ /13/ /14/ /15/ /16/ /17/ /18/ /19/ /20/ /21/ /22/ /23/ /24/ /25/ /26/ /27/ /28/ /29/ /30/ /01/ /02/ /03/ /04/ /05/ /06/ /07/ /08/ /09/ /10/ /11/ /12/2012 Page 7a.3
12 Part II - Schedule 6. Balancing Authority Area System Lambda Data (continued) /13/ /14/ /15/ /16/ /17/ /18/ /19/ /20/ /21/ /22/ /23/ /24/ /25/ /26/ /27/ /28/ /29/ /30/ /31/ /01/ /02/ /03/ /04/ /05/ /06/ /07/ /08/ /09/ /10/ /11/ /12/ /13/ /14/ /15/ /16/ /17/2012 Page 7a.4
13 Part II - Schedule 6. Balancing Authority Area System Lambda Data (continued) /18/ /19/ /20/ /21/ /22/ /23/ /24/ /25/ /26/ /27/ /28/ /29/ /30/ /01/ /02/ /03/ /04/ /05/ /06/ /07/ /08/ /09/ /10/ /11/ /12/ /13/ /14/ /15/ /16/ /17/ /18/ /19/ /20/ /21/ /22/ /23/2012 Page 7a.5
14 Part II - Schedule 6. Balancing Authority Area System Lambda Data (continued) /24/ /25/ /26/ /27/ /28/ /29/ /30/ /31/ /01/ /02/ /03/ /04/ /05/ /06/ /07/ /08/ /09/ /10/ /11/ /12/ /13/ /14/ /15/ /16/ /17/ /18/ /19/ /20/ /21/ /22/ /23/ /24/ /25/ /26/ /27/ /28/2012 Page 7a.6
15 Part II - Schedule 6. Balancing Authority Area System Lambda Data (continued) /29/ /30/ /31/ /01/ /02/ /03/ /04/ /05/ /06/ /07/ /08/ /09/ /10/ /11/ /12/ /13/ /14/ /15/ /16/ /17/ /18/ /19/ /20/ /21/ /22/ /23/ /24/ /25/ /26/ /27/ /28/ /29/ /30/ /01/ /02/ /03/2012 Page 7a.7
16 Part II - Schedule 6. Balancing Authority Area System Lambda Data (continued) /04/ /05/ /06/ /07/ /08/ /09/ /10/ /11/ /12/ /13/ /14/ /15/ /16/ /17/ /18/ /19/ /20/ /21/ /22/ /23/ /24/ /25/ /26/ /27/ /28/ /29/ /30/ /31/ /01/ /02/ /03/ /04/ /05/ /06/ /07/ /08/2012 Page 7a.8
17 Part II - Schedule 6. Balancing Authority Area System Lambda Data (continued) /09/ /10/ /11/ /12/ /13/ /14/ /15/ /16/ /17/ /18/ /19/ /20/ /21/ /22/ /23/ /24/ /25/ /26/ /27/ /28/ /29/ /30/ /01/ /02/ /03/ /04/ /05/ /06/ /07/ /08/ /09/ /10/ /11/ /12/ /13/ /14/2012 Page 7a.9
18 Part II - Schedule 6. Balancing Authority Area System Lambda Data (continued) /15/ /16/ /17/ /18/ /19/ /20/ /21/ /22/ /23/ /24/ /25/ /26/ /27/ /28/ /29/ /30/ /31/2012 Page 7a.10
19 Annual Electric Balancing Authority Area and Planning PART IV: FOOTNOTE DATA Schedule Page: 7a Line No.: 01/01/2012 Column: b See Part II Schedule 6 Description of Economic Dispatch (7b). Footnotes.1
20 Annual Electric Balancing Authority Area and Planning Part II - Schedule 6. Description of Economic Dispatch Provide in writing a detailed description of how Respondent calculates system lambda. For those systems that do not use an economic dispatch algorithm and do not have a system lambda, provide in writing a detailed description of how Balancing Authority Area resources are efficiently dispatched. Description of Economic Dispatch: Balancing Authority load is followed by hydro generating units January though December. Real- Energy Traders manage the operation of the bulk power supply system. The energy traders optimize the resource portfolio by directing, in real time, the operation of Tacoma s owned generation, adjusting power supply contracts and conducting wholesale power transactions to ensure the power supply obligations of Tacoma s customers are met in the most economical and cost-efficient manner. 7b.1
21 Part III - Schedule 1. Electric Utilities That Compose the Planning Area Enter the name of each entity, including the respondent, that forms the planning area for which this report is being prepared and their coincident summer and winter peak demands in megawatts. Refer to the Form 714 instructions for specific guidelines. Line No Electric Utility Name Summer Electric Utility Coincident Peak Demand Winter Tacoma Power Page 8
22 Part III - Schedule 2. Planning Area Hourly Demand Respondents must provide the following data: the planning area's actual hourly demand, in megawatts, for each hour of the year starting with 1 a.m. January 1 as more fully described in the Form 714 instructions. In column indicate the time zone and the days for which daylight savings time was observed. This schedule will have 365 rows for the report year (366 rows for a leap year). For hours when this information is not available, enter "" and provide, as a footnote to those hours, an explanation describing the reason for the unavailability of the data. 01/01/ /02/ /03/ /04/ /05/ /06/ /07/ /08/ /09/ /10/ /11/ /12/ /13/ /14/ /15/ /16/ /17/ /18/ /19/ /20/ /21/ /22/ /23/ /24/ /25/ /26/ /27/ /28/ /29/ PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST PST Page 9a
23 Part III - Schedule 2. Planning Area Hourly Demand (continued) PST /30/ PST /31/ PST /01/ PST /02/2012 PST /03/ PST /04/ PST /05/2012 PST /06/ PST /07/2012 PST /08/2012 PST /09/ PST /10/2012 PST /11/ PST /12/ PST /13/ PST /14/ PST /15/ PST /16/ PST /17/ PST /18/ PST /19/ PST /20/ PST /21/2012 PST /22/ PST /23/ PST /24/ PST /25/ PST /26/ PST /27/ PST /28/ PST /29/ PST /01/2012 PST /02/2012 PST /03/ PST /04/ PST /05/2012 Page 9a.1
24 Part III - Schedule 2. Planning Area Hourly Demand (continued) PST /06/ PST /07/ PST /08/2012 PST /09/ PST /10/ PDT /11/ PDT /12/ PDT /13/ PDT /14/ PDT /15/ PDT /16/ PDT /17/ PDT /18/ PDT /19/ PDT /20/ PDT /21/ PDT /22/2012 PDT /23/2012 PDT /24/ PDT /25/2012 PDT /26/2012 PDT /27/2012 PDT /28/ PDT /29/ PDT /30/ PDT /31/ PDT /01/2012 PDT /02/ PDT /03/2012 PDT /04/ PDT /05/2012 PDT /06/2012 PDT /07/2012 PDT /08/2012 PDT /09/2012 PDT /10/2012 Page 9a.2
25 Part III - Schedule 2. Planning Area Hourly Demand (continued) PDT /11/2012 PDT /12/2012 PDT /13/2012 PDT /14/2012 PDT /15/ PDT /16/2012 PDT /17/2012 PDT /18/2012 PDT /19/2012 PDT /20/2012 PDT /21/2012 PDT /22/2012 PDT /23/2012 PDT /24/2012 PDT /25/2012 PDT /26/2012 PDT /27/2012 PDT /28/2012 PDT /29/2012 PDT /30/2012 PDT /01/2012 PDT /02/2012 PDT /03/2012 PDT /04/2012 PDT 05/05/2012 PDT /06/2012 PDT /07/2012 PDT /08/2012 PDT /09/2012 PDT /10/2012 PDT /11/2012 PDT /12/2012 PDT /13/2012 PDT /14/2012 PDT /15/2012 PDT /16/2012 Page 9a.3
26 Part III - Schedule 2. Planning Area Hourly Demand (continued) 0 1 PDT /17/2012 PDT /18/2012 PDT /19/2012 PDT /20/2012 PDT /21/2012 PDT /22/2012 PDT /23/2012 PDT /24/2012 PDT /25/2012 PDT /26/ PDT /27/2012 PDT /28/2012 PDT /29/2012 PDT /30/2012 PDT /31/2012 PDT /01/2012 PDT /02/2012 PDT /03/2012 PDT /04/2012 PDT /05/2012 PDT /06/2012 PDT /07/2012 PDT /08/2012 PDT /09/2012 PDT /10/2012 PDT /11/2012 PDT /12/2012 PDT /13/2012 PDT /14/2012 PDT /15/2012 PDT /16/2012 PDT /17/2012 PDT /18/2012 PDT /19/2012 PDT /20/2012 PDT /21/2012 Page 9a.4
27 Part III - Schedule 2. Planning Area Hourly Demand (continued) 0 1 PDT /22/2012 PDT /23/2012 PDT /24/2012 PDT /25/2012 PDT /26/2012 PDT /27/2012 PDT /28/2012 PDT /29/ PDT /30/2012 PDT /01/2012 PDT /02/2012 PDT /03/ PDT /04/2012 PDT /05/2012 PDT /06/2012 PDT /07/2012 PDT /08/2012 PDT /09/2012 PDT /10/2012 PDT /11/2012 PDT /12/2012 PDT /13/2012 PDT /14/2012 PDT /15/ PDT /16/2012 PDT /17/2012 PDT /18/2012 PDT /19/2012 PDT /20/ PDT /21/2012 PDT /22/2012 PDT /23/2012 PDT /24/2012 PDT /25/2012 PDT /26/2012 PDT /27/2012 Page 9a.5
28 Part III - Schedule 2. Planning Area Hourly Demand (continued) 0 1 PDT /28/2012 PDT /29/2012 PDT /30/2012 PDT /31/2012 PDT /01/2012 PDT /02/2012 PDT /03/2012 PDT /04/2012 PDT /05/2012 PDT /06/2012 PDT /07/2012 PDT /08/2012 PDT /09/2012 PDT /10/2012 PDT /11/2012 PDT /12/2012 PDT /13/ PDT /14/ PDT /15/2012 PDT /16/ PDT /17/2012 PDT /18/2012 PDT /19/2012 PDT /20/2012 PDT /21/2012 PDT /22/2012 PDT /23/2012 PDT /24/2012 PDT /25/2012 PDT /26/2012 PDT /27/2012 PDT /28/2012 PDT /29/2012 PDT /30/2012 PDT /31/ PDT /01/2012 Page 9a.6
29 Part III - Schedule 2. Planning Area Hourly Demand (continued) PDT /02/2012 PDT /03/2012 PDT /04/2012 PDT /05/2012 PDT /06/2012 PDT /07/2012 PDT /08/ PDT /09/2012 PDT /10/2012 PDT /11/2012 PDT /12/2012 PDT /13/2012 PDT /14/2012 PDT /15/2012 PDT /16/2012 PDT /17/2012 PDT /18/2012 PDT /19/2012 PDT /20/2012 PDT /21/ PDT /22/2012 PDT /23/2012 PDT /24/2012 PDT /25/2012 PDT /26/2012 PDT /27/2012 PDT /28/ PDT /29/2012 PDT /30/2012 PDT /01/2012 PDT /02/2012 PDT /03/2012 PDT /04/2012 PDT /05/2012 PDT /06/2012 PDT /07/2012 Page 9a.7
30 Part III - Schedule 2. Planning Area Hourly Demand (continued) 0 1 PDT /08/2012 PDT /09/ PDT /10/2012 PDT /11/2012 PDT /12/2012 PDT /13/2012 PDT /14/2012 PDT /15/2012 PDT /16/2012 PDT /17/2012 PDT /18/2012 PDT /19/2012 PDT /20/2012 PDT /21/ PDT /22/ PDT /23/ PDT /24/ PDT /25/ PDT /26/2012 PDT /27/2012 PDT /28/ PDT /29/ PDT /30/2012 PDT /31/2012 PDT /01/ PDT /02/2012 PDT /03/2012 PST /04/ PST /05/ PST /06/ PST /07/ PST /08/ PST /09/ PST /10/ PST /11/ PST /12/2012 Page 9a.8
31 Part III - Schedule 2. Planning Area Hourly Demand (continued) PST /13/ PST /14/ PST /15/2012 PST /16/ PST /17/ PST /18/ PST /19/ PST /20/2012 PST /21/ PST /22/2012 PST /23/2012 PST /24/ PST /25/ PST /26/ PST /27/ PST /28/ PST /29/ PST /30/2012 PST /01/ PST /02/ PST /03/ PST /04/ PST /05/ PST /06/ PST /07/ PST /08/ PST /09/ PST /10/ PST /11/ PST /12/ PST /13/ PST /14/ PST /15/ PST /16/ PST /17/ PST /18/2012 Page 9a.9
32 Part III - Schedule 2. Planning Area Hourly Demand (continued) 12/19/ /20/ /21/ /22/ /23/ /24/ /25/ /26/ /27/ /28/ /29/ /30/ /31/ PST PST PST PST PST PST PST PST PST PST PST PST PST Page 9a.10
33 Part III - Schedule 2. Forecast Summer and Winter Peak Demand and Annual Net Energy for Load Provide the planning area's forecast summer and winter peak demand, in megawatts, and annual net energy for load, in megawatthours, for the next ten years. Line No Year Summer Forecast Winter Forecast Forecast of Annual Net Energy for Load (MWh) ,996, ,050, ,131, ,214, ,000 5,239, ,005 5,274, ,009 5,305, ,013 5,358, ,019 5,, ,026 5,438,208 Page 9b
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