planningpresentation
DESCRIPTION
TRANSCRIPT
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UtilityForecasting & Planning
MADRI Meeting
March 7, 2006
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Purpose
This presentation is intended to be a general outline of utility forecasting and planning techniques not specific to any one company.
It is, however, intended to represent a utility that is a PJM member, and is following a process that works with the PJM planning regime.
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Planning Criteria
A utility’s planning criteria are intended to be a guide to provide for the safe, reliable and low cost development of the utility’s electrical system as loads increase and reinforcements and/or new facilities are required.
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Basic Principles
With all facilities in service: Load must be within normal equipment
ratings Must provide acceptable voltages
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Basic Principles
With the outage of any single piece of equipment (N-1 Criteria Violation): Affected load must be within the emergency
rating of the remaining facilities System must provide minimum emergency
voltages
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Basic Principles
N-1 criteria are applied in a similar fashion to: Substations Distribution Facilities Subtransmission Facilities Transmission Facilities
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Basic Principles Transmission Planning Criteria
Goes beyond N-1 N-2 (After the N-1 outage and re-
adjustment, loss of an additional element.) Towerline outages Stuck breakers
Transmission planning criteria are more restrictive than operating criteria to account for potential new generation, and network facilities’ forecasted and unplanned outages.
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Distribution Planning Load Forecasting
Substation Feeder
Distribution Circuit Reinforcement Ratings N-1 Criteria
New Business Connected vs. Estimated Loads Load Build-up Schedules Load Shifting
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Substation Forecast/Planning Process Diagram for a Typical Utility
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Substation Forecast/Planning ProcessData Collection
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Substation Forecast/Planning Process Data Collection
CMMS Peak Load Data MV-90 Remote
Metering Substation Data
Concentrators Inspection Data Data “Scrubbing”
Adjustments Voltage Reduction,
Cogen, etc. Reference Data
Station Type, Reactive, Power Factors, Feeder Info, etc.
Load Transfers Historical Trends Peak Adjustments
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Substation Forecast/Planning ProcessWeather Normalization
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Substation Forecast/Planning ProcessWeather Normalization
Weighted Temperature-Humidity Index (WTHI) 3-Day Heat Build-Up 10-5-2 Weighting
Factors
Normalization Standard 50/50 Historical
Probability 84 Degrees WTHI
Normalized Peak Selection Load vs. WTHI
Correlation Exclusion of Data
Points Below 73 Degrees WTHI
Exclusion of Non-Trend Data Points
Current Year Weather Sensitivity
5-Year Weather Sensitivity
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Substation Forecast/Planning ProcessSubstation & Area Forecasts
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Substation Forecast/Planning ProcessSubstation & Area Forecasts
Growth Factors General Growth – Load growth
of existing and small additional customers is generally consistent with historical trending
Specific Growth – Load growth attributable to major new business projects greater than 300 kW
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Diversified Specific Growth
Adjusted for:Over-estimation of LoadsLoad ProfilesDelayed Project CompletionsCustomer to Feeder CoincidenceFeeder to Substation Coincidence
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Coincidence Factor
Substations feed a number of different types of load
Not all of the load will peak at the same time (diversity)
Expect any implementation of time-of-use or RTP tariffs to cause interval customers to change/modify load patterns
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Substation Forecast/Planning ProcessSubstation & Area Forecasts
Forecast Worksheet Historical Trending Feeder Peak
Synthesis Forecast Performance
Short Range Forecast 4-Year Forecast
Long Term Forecast 9 Scenarios
High Tension Service Customer Forecasts Developed by utility
Area (Switching Station) Forecasts Coincidized
Substation Roll-Up System Forecast
Roll-Up Coincidized HV
Substation & Area Forecast Roll-Up
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Substation Forecast/Planning ProcessSubstation & Area Planning
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Substation Forecast/Planning ProcessSubstation & Area Planning Substation & Area
Capacity Firm N-1 Criteria Includes Automatic ICT
Transfers Capacity Processing
Load vs. Capacity Analysis
Load Relief Modeling Power Factor
Correction Load Transfers Dispersed Generation
System Reinforcement Modeling Interstation
Capacity Ties Station
Reinforcement New Station Generation (As
Permitted)
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Feeder Forecast ProcessData Acquisition
Substation Operators collect data during station inspections via a Mobile Data Terminal (MDT)
Data is electronically uploaded into CMMS Data is extracted into spreadsheet Data is scrubbed – no data, broken meter, tie
recloser operations, etc. Summer peak load is selected and utilized to
develop the individual feeder forecasts
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Feeder Forecasting ProcessLoad vs. Capacity Analysis
Peak data is used for Station Feeder Forecasts (Feeder Utilization)
Data is processed to evaluate overloaded circuits
Forecast sheets are used when a New Business Plan of Supply is submitted Is capacity available? If not, how can circuit be relieved?
Reinforcement jobs and New Business jobs are tracked on the Station Feeder Forecast sheets
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How Do Projects Emerge?
Individual substation overloads are not as critical if sufficient ties exist
Greatest concern - area overloads consisting of two (2) or more substations
Could cause cascading overloads and area outages
Time to reinforce when area overloads are present or could reasonably be expected to occur in the near future
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New Business
Division Planners are typically concerned with new business projects 300-kVA and greater
Voltage / Service characteristics can range from secondary to sub-transmission (277/480 volts up to 69-kV)
Types of New Business can vary from Network Service to Substation / High Tension service
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Transmission Planning
Entity Load Forecast Regional Transmission Expansion Planning (RTEP) Process
Lead by PJM and coordinated with Transmission Owners Incorporation of utility’s T&D Planning results into PJM’s
RTEP Process, PJM will begin zonal forecasting utility loads this year
Baseline Reinforcements Merchant Generation/Transmission Interconnections &
Reinforcements Analyses & Tools
Short Circuit Load Flow System Stability LOLP (Loss of Load Probability)
Operations Support
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Entity Load Forecast
The Entity Load Forecast is an independent forecast of summer peak, performed by PJM
Used to set Zonal Scaling Factors in eCapacity and sets capacity obligations for all LSE’s
Relates growth in the PJM normalized peak to the U.S. economy (Gross Domestic Product)
This load is allocated to specific nodes using the various utility’s Distribution Substation Forecasts
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Any Questions?