Commercial Operations Subcommittee
(COPS)
Update to RMS
9/1/2015
COPS VOTING Items
•
LPGRR055, Extend Load Profile Model Calendar
Inputs to 2030
COPS voted to approve LPGRR055 as amended by the
8/5/2015 PWG Comments
•
PRS Assignment: NPRR702, Flexible Accounts,
Payment of Invoices, and Disposition of Interest
on Cash Collateral
o
ERCOT provides Flexible (Pre-pay) Accounts today, but there is no
language in the Protocols
o
IA includes $150k-$200k for automation with a 6 to 9 month project
duration
o
Items discussed: Submitting an SCR separate of the NPRR, Funding
deadlines, Adding wiring fee savings to IA, Overpayment language
COPS voted to endorse NPRR702 as submitted. There was
one abstention from the IOU Segment.
2
COPS VOTING Items
• LPGRR055, Extend Load Profile Model
Calendar Inputs to 2030
LPGRR055 extends the Load Profile Model
calendar-related inputs in Appendix E, Profile
Model Spreadsheets, from 2020 to 2030.
o ERCOT has completed modification to the
Load Profile Model Calendar Inputs
o The PWG has requested an implementation
date of October 1, 2015.
o COPS requests that the TAC table LPGRR055
for one month, to avoid unnecessarily greyboxing language
3
Valley Load Forecasting Options
Preliminary overview of options to address
ERCOT’s Rio Grande Valley (Valley) area load
forecasting and operational requirements
• Stakeholders will have the opportunity to
discuss and provide input
• ERCOT staff plans to present options to ROS
and RMS
Reference: Load Profiling Guide Section 13,
Changes to Weather Zone Definitions
•
Weather Zone Boundaries, Modeling Regions,
Weather Stations, Weighting of Weather stations
4
Valley Load Forecasting Options
ERCOT staff determined a need for independent
modeling of the Valley to facilitate more accurate load
forecasting and address operational needs.
A supplemental Valley load forecast was created to
meet immediate operational needs, e.g. Outage
analysis.
For transparency, ERCOT staff is looking at providing
the supplemental Valley load forecast data to Market
Participants. The initial thought was to add a new
Valley Weather Zone, because load forecasts are
created by Weather Zone, however there is an
alternative.
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Valley Load Forecasting Options
Option1: Create new Valley Weather Zone
Impacts:
o Processes and System modifications
• ERCOT, TDSPs, and CRs
o ERCOT Systems: LFC, STNET, CIM Importer, State
Estimator, Short Term Load Forecast, MTLF
o Retail Operations
o Settlements
o Workforce Management
• 814 Transactions to update customer information
o Depending on volume, will need to be in phases
6
Valley Load Forecasting Options
Option1: Create new Valley Weather Zone
Estimated ESID count by TDSP and Type
for the four targeted counties
TDSP_Name
AEP TEXAS CENTRAL COMPANY
AEP TEXAS CENTRAL COMPANY
AEP TEXAS CENTRAL COMPANY
ENTERGY GULF STATES INC
NUECES ELECTRIC COOP INC
SHARYLAND UTILITIES LP MCALLEN
SHARYLAND UTILITIES LP MCALLEN
SHARYLAND UTILITIES LP MCALLEN
ESIID_Type
Residential
Small Non-Residential
Large Non-Residential
Residential
Residential
Residential
Small Non-Residential
Large Non-Residential
Total
Count
273,396
47,791
85
5
1
2,665
315
2
324,260
Valley Weather Zone Counties: Cameron, Hidalgo, Starr, and Zapata
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Valley Load Forecasting Options
Option 2: Carve out Valley area for modeling
and load forecasting purposes only (Virtual
Weather Zone)
o Solution will work for future areas as well
2A. If no interest by MPs, ERCOT will not provide Valley
load forecast data in a report
o Impacts: None
2B. Develop a mechanism to provide the load forecast
data to the Market in a report/extract
o Impacts ERCOT and CRs, but to a much lesser
degree
o An NPRR may not be required
8
Market Participant Training
Bill Kettlewell provided his Market Participant
Training presentation to COPS
Feedback provided by COPS included:
• Agreed with Credit Management Training being a high
priority
• Suggested the development of a Verifiable Cost Class
• Suggested that Settlements training not be provided the
first week of the month
• Suggested standard cycle training programs and
locations for core classes
• Requested an annual Settlements Workshop
• Incremental to Settlements 301, Covering recent changes
• COPS will work with Mark Ruane on content
9
Non-Registered DG Installed Capacity
Randy Roberts provided the Second Quarter 2015
Non-Registered DG Installed Capacity Report
Load_Zone
LZ_AEN
LZ_CPS
LZ_HOUSTON
LZ_NORTH
LZ_SOUTH
LZ_WEST
Quantity
Aggregate_MW
35
5.29
2
0.226
17
3.55205
38
5.335247
19
3.13438
8
0.99568
kWh_Exported_Prior_12_Months
1,221,036
9,814
596,037
1,382,886
1,033,799
675,930
• COPS requested that all Load Zones be included in the
report
• Aggregate MW reductions from the previous quarter are the
result of a scrubbing effort performed by ERCOT and TDSP
staff (LZ_North was previously at 6.8555 MW)
– Cleaned up duplications, Load profiling issues, Data
variations, etc.
10
Profiling Working Group (PWG)
• Annual Load Profiling Validation process is
progressing on schedule
• UFE Allocation Factors
o PWG will be reviewing the need for the current UFE
allocation factors for NIDR, IDR-Distribution, and IDRTransmission
• Effort to review and update Protocol Section
18, Load Profiling, is progressing on schedule
11
Market Information System User Group (MISUG)
 External Web Services (EWS) Modifications
Workshop III
o September 29, 2015
o 1:00 pm to 4:00 PM
o ERCOT Met Center and WebEx
 Load Forecast Distribution Factor Report Changes
o
o
o
o
o
o
o
o
Report currently publishes data on an hourly basis
Report is 1M lines of data
Some MPs only downloading the file once a day
Data only changes seasonally
Weekly if corrections are made
MISUG recommending daily publication at 5:00 AM
MISUG members to solicit feedback from their shops
Final recommendation to be made at the August 26th MISUG
meeting
12
Market Information System User Group (MISUG)
 Reports to be Automated
o Progress continues in review of requirements to automate
16 manual reports
 Review of Open Items List
o MISUG maintained an “Open Items” list prior to transitioning
from ERCOT leadership to Market leadership
o The open items list was reviewed and several items have
been identified as potential new reports:
• List of Marginal Units
• Historical DC Tie Schedules
• Historical Information for AS Capacity Monitor
o The remaining items had either already been addressed or
were no longer relevant
13
The next COPS meeting is scheduled for
September 9, 2015.
Questions?
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