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Ancillary Services Market, Day-Ahead Load Response and Special Case Nodal Pricing
Implementation
Vamsi ChadalavadaFERC Technical Conference
March 4, 2005
2
Primary considerations in delivering market enhancements
– To implement identified market enhancements as
early as possible
– To balance the urgent and competing stakeholder
priorities
– To minimize overall implementation costs
– To maximize the compelling synergies across multiple
market enhancements
3
Primary considerations in delivering market enhancements
– To minimize further delays downstream in various
other important initiatives identified by the ISO and
stakeholders
– This presentation focuses on Ancillary Services
Market, Day-Ahead Load Response and Special Case
Nodal Pricing
4
Ancillary Services Market high level scope
– Regulation market redesign
– External transactions setting price
– Day-ahead re-offer period changes
– Reserve markets
• Forward reserve market
• Real-time joint optimization of energy and reserves
– Direct demand participation in reserve and real-time
energy markets
5
Day-ahead Load Response high level scope
– Designed for demand resources that can offer load
reductions concurrent with the day-ahead wholesale
electricity market
– The Day-Ahead Load Response Program contributes
to greater market efficiency by allowing the demand
resource to specify the wholesale electricity price at
which it is willing to curtail load
– The demand resource has greater control over its
load reduction because it knows a day in advance
when and for how long its load reduction will be
scheduled
6
Special Case Nodal Pricing high level scope
– Permit qualifying customers to settle at nodal prices
– Allows for either a dispatchable or non-dispatchable
option
– Special Case Nodal Pricing will better integrate
demand response directly into wholesale markets
7
Original planned implementation sequence
– ISO proposed Day-Ahead Load Response (‘sequential’
methodology) scheduled for implementation in June 2005
– Ancillary Services Market scheduled for implementation in
October 2005
– Special Case Nodal Pricing scheduled for implementation
in October 2005
8
Rationale for original planned implementation sequence
– Implement market enhancements as early as
possible
– Comply with commission directives
– Leverage the significant synergies across multiple
elements such as the Reserve market design, direct
demand participation in the reserve and real-time
energy markets, dispatchable special case nodal
pricing
– Address the dependencies for certain market
enhancements
– Recognize the benefits of a ‘system release’
methodology
9
Identified synergies that result in efficiency gains
– Many of the elements of the proposed enhancements
primarily involve modifications in exactly the same
software systems and business processes
• Scheduling, Pricing and Dispatch Functions
• Unit Dispatch System
• Settlements and Financial Systems
• Security Constrained Reliability Assessment
• Electronic Dispatch
• Data Modeling
• User Interface and Web Publishing Systems
• Archiving, Performance Monitoring and Analysis
Systems
10
Infrastructure dependency
– A fundamental improvement is the introduction of a generic
asset class called ‘asset related demand (ARD)’ that is
integrated in a similar manner as supply across all
• Software systems
• Databases
• Markets and
• Business processes
– Field improvements required in the area of modeling and
metering
11
Requirement for certain market enhancements
– Asset Related Demand is needed for the implementation of
• Direct demand participation in reserves and real-time
energy market
• Dispatchable Special Case Nodal Pricing
• ‘Integrated’ Day-Ahead Load Response
– This infrastructure improvement is part of the Ancillary
Services Market project
– Therefore, it is not feasible to implement these market
enhancements until the infrastructure improvement is in
place
12
Benefits of a software system release methodology
– Package functionality into a single software system
release
• Significant efficiency gains in terms of software
development, testing and training
• Significant savings in development costs
– Multiple releases (or a ‘release for each market
enhancement’) create the need for additional system
infrastructure and human resources thereby driving
costs and more importantly, delaying the delivery of
market enhancements
13
An illustration of the benefits of ‘release methodology’
Ancillary Services
Market* as one release
Ancillary Services
Market* as three releases
Schedule Fall 2005 Fall 2007
Budget $15M $27-$31M
* Identical Functionality
14
Why do most market enhancements take so long?
Large Projects Medium Projects
Stakeholder process and
Regulatory approval12-15 months 5-9 months
Project Implementation 15-18 months 9 months
Total Duration 27-33 months 14-18 months
• Examples of large projects include Ancillary Services Market,
Hourly bidding; Examples of medium projects include
Regulation market design; Pricing for external nodes
15
Why is the project Implementation phase so long?
Large Projects Medium Projects
Functional Design 10 weeks 6 weeks
Development 24 weeks 10 weeks
Internal Controls, Audits 8 weeks 4 weeks
Testing* 16 weeks 10 weeks
Training** 10 weeks 6 weeks
Total 68 weeks 36 weeks
* unit test, integration test and business end-user test
** 6 shifts of control operators, forecast office and market
administration, business owners and support personnel;
assumes 6 weeks of overlap with testing
16
Stakeholder Feedback
– Stakeholder feedback regarding original proposal and
schedule
• Correlation between Ancillary Services Market and
LICAP; Complexity of the Ancillary Services
Market design
• Heavy demand on time due to LICAP and RTO
• Detailed market impact analysis
• High pace of market design enhancements
17
Stakeholder Process Improvements
– Based on stakeholder feedback, the ISO will
• Work with NEPOOL in implementing a ‘design
sheet’ (decision tree) approach
• Publish a series of white papers and examples
during the conceptual design
• Provide a market impact analysis as part of the
market design proposal
• Vote on the conceptual design, prior to voting on
the detailed design
18
Stakeholder Process Improvements
– The ISO and NEPOOL have adopted this revised
format for further discussion on the Ancillary Services
Market
– The ISO believes that this revised format has resulted
in significant progress being made
– The ISO believes that this experience will help build a
strong foundation for discussions on future market
enhancements
19
Revised Implementation Sequence
– The ISO evaluated and presented alternate proposals
for the implementation of Ancillary Services Market,
Special Case Nodal Pricing and Day-ahead Load
Response
20
Revised Implementation Sequence
– Approved by ~96% at the February NEPOOL Participants
committee
• Implement Ancillary Services Market as two phases
• Phase 1 scheduled for implementation in October 2005 (filing
by March 2005 and approval by May 2005) will include
Regulation market redesign, Day-ahead re-offer period
changes and External transactions setting price
• Phase 2 scheduled for implementation no earlier than June
2006 (filing by Sept. 2005 and approval by Nov. 2005) will
include the Reserve market design, Direct demand
participation in reserve and real-time energy markets and
Special Case Nodal Pricing
21
Revised Implementation Sequence
– Approved by ~77% at the February NEPOOL
Participants committee
• Implement the ISO proposed ‘Sequential’ Day-
Ahead Load response program for June 1 2005
and replace it with the ‘Integrated’ Day-Ahead load
Response program following the implementation of
Ancillary Services Market
22
Revised implementation sequence considerations
• FERC decisions on market design proposals and revised
implementation sequence
• Outcome of the LICAP hearings
23
Conclusion
• The ISO is striving to achieve the optimal balance between
responsiveness and efficiency (human resource
allocations and monetary expenditures)
• It is the ISO’s twin mission to ensure reliability and fair and
efficient wholesale markets
• The ISO looks forward to working with its stakeholders in
implementing these identified market enhancements