market performance and planning forum · 2018-02-10 · • 2011 resource adequacy assessment –...
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Market Performance and PlanningForum
October 26, 2011
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Objective: Enable dialogue on implementation planning and market performance issues
• Review key market performance topics• Share updates to 2011-2012 release plans, resulting
from stakeholders inputs• Provide information on specific initiatives
– to support Market Participants in budget and resource planning
• Focus on implementation planning; not on policy• Clarify implementation timelines• Discuss external impacts of implementation plans• Launch joint implementation planning process
Slide 2
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Agenda
Slide 3
TIME TOPIC LEAD9:00 – 9:10 Introduction, Agenda Mercy Parker Helget
9:10 – 10:10 Market Analysis Mark Rothleder
10:10 – 10:40 Policy Update Eric Little
10:40 – 11:10 Distributed Energy Resources Visibility and Control Study Update
Heather Sanders
11:10 – 12:15 Technical Updates Khaled Abdul-Rahman & Li Zhou
12:15 – 1:00 LUNCH
1:00 – 1:30 RUG / TUG Updates Janet Morris, Kevin Colmer
1:30 – 2:00 OMS Phase 3 Requirements Gathering
Jami Herguth & Team
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Market Performance and Quality Update
Mark Rothleder, Executive DirectorMarket Analysis & Development
Slide 4
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Slide 5
1. Market Metrics
• Price volatility and market convergence
• RT energy imbalance offset
• Convergence bidding
• Exceptional Dispatch trends
• Bid cost recovery
2. Recent Market Events
3. Updates of Market Enhancements
4. Update of Renewable Integration Studies and Initiatives
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$0
$10
$20
$30
$40
$50
$60
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep
2010 2011
IFM HASP RTD
PG&E DLAP LMP Monthly Average (DA/HASP/RTD)
Page 6
Trend of improved price convergence continued in September
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PG&E DLAP LMP Monthly Average (On Peak)
Page 7
$0
$10
$20
$30
$40
$50
$60
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep
2010 2011
IFM HASP RTD
Good On-Peak Convergence
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PG&E DLAP LMP Monthly Average (Off Peak)
Page 8
$0
$5
$10
$15
$20
$25
$30
$35
$40
$45
$50
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep
2010 2011
IFM HASP RTD
Good Off-Peak ConvergenceObserved in September
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Monthly Price Distributions: Observed reduced negative and positive price volatility in Aug and Sept.
Page 9
-10.0%
-8.0%
-6.0%
-4.0%
-2.0%
0.0%
2.0%
4.0%
JAN
FEB
MAR AP
R
MAY JUN
JUL
AUG
SEP
OCT
NOV
DEC
JAN
FEB
MAR AP
R
MAY JUN
JUL
AUG
SEP
2010 2011
Perc
ent o
f Rea
l Tim
e In
terv
als
-$30 to -$5 -$100 to -$30 -$300 to -$100 < -300
$250 to < $500 $500 to < $750 $750 to $1000 > $1000
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Monthly Average of RTD Intervals with Insufficient Up Ramping Capacity
Page 10
Steady in September
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Monthly Average of RTD Intervals with Insufficient Down Ramping Capacity
Page 11
Uptick in September
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HASP/RTD Price Differential: 30 day average price difference near $0.
Page 12
0
0.5
1
1.5
2
2.5
3
3.5
-10
-8
-6
-4
-2
0
2
4
6
8
10
3/2/2011 4/2/2011 5/2/2011 6/2/2011 7/2/2011 8/2/2011 9/2/2011 10/2/2011
Aver
age
Num
ber o
f Spi
ke/D
ay
Aver
ge H
ASP-
RT P
rice
Diffe
renc
e ($
/Mw
h)
30-Day Rolling Average
Average Difference in SMEC (RT-HASP) Average number of price spikes >$500
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Daily Total Real-Time Imbalance Energy Offset (RTIEO) Continued to Stabilize in September (Based on LMP)
Page 13
-$5,000,000
$0
$5,000,000
$10,000,000
$15,000,000
$20,000,000
$25,000,000
$30,000,000
3/2/2011 4/2/2011 5/2/2011 6/2/2011 7/2/2011 8/2/2011 9/2/2011
30-Day Rolling Cumulative Total Real Time Energy Offset
Virtual Contribution to RT Energy Offset Total Real-time Energy Offset
Balanced Convergence bids1/3 of RTIEO
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Balanced convergence bidding volumes MW
Page 14
0200,000400,000600,000800,000
1,000,0001,200,0001,400,0001,600,0001,800,0002,000,000
3/2/
2011
3/16
/201
1
3/30
/201
1
4/13
/201
1
4/27
/201
1
5/11
/201
1
5/25
/201
1
6/8/
2011
6/22
/201
1
7/6/
2011
7/20
/201
1
8/3/
2011
8/17
/201
1
8/31
/201
1
9/14
/201
1
9/28
/201
1
10/1
2/20
11Volu
me
of B
alan
ced
Virt
ual (
MW
)
Date
30-Day Rolling Cumulative(Volume of balanced offsetting virtual intertie supply
and virtual internal demand)
SC Balanced Virtual Residual Balanced Virtual across SCs
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Convergence bidding dual constraint impacts:Day-Ahead Intertie Overpayment and Shortages Due to Dual Intertie Constraint
Page 15
-$400,000
-$200,000
$0
$200,000
$400,000
$600,000
$800,000
$1,000,000
$1,200,000
$1,400,000
$1,600,000
Feb Mar Apr May Jun Jul Aug Sep
Over Shortage
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Exceptional Dispatches Average Remained low in August and September (in % of Total Dispatches).
Page 16
Elevated amount of EDs on 8th and 9th due to San Diego outage
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Daily Exceptional Dispatches in MWh
Page 17
Elevated amount of EDs on 8th and 9th due to San Diego outage
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Daily Exceptional Dispatches in MWh – by Reason
Page 18
Elevated amount of EDs on 8th and 9th due to San Diego outage
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Bid Cost Recovery Costs Resumed Downward Trend in September.
Page 19
$0$2,000,000$4,000,000$6,000,000$8,000,000
$10,000,000$12,000,000$14,000,000$16,000,000$18,000,000$20,000,000
Jan
Feb
Mar
Apr
May Jun Jul
Aug
Sep
Oct
Nov
Dec
Jan
Feb
Mar
Apr
May Jun Jul
Aug
Sep
2010 2011
Total Bid Cost Recovery ($)
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MIP Gap performance improved September.
Page 20
-$10,000
$0
$10,000
$20,000
$30,000
$40,000
$50,0008/
15/2
009
9/4/
2009
9/24
/200
910
/14/
2009
11/3
/200
911
/23/
2009
12/1
3/20
091/
2/20
101/
22/2
010
2/11
/201
03/
3/20
103/
23/2
010
4/12
/201
05/
2/20
105/
22/2
010
6/11
/201
07/
1/20
107/
21/2
010
8/10
/201
08/
30/2
010
9/19
/201
010
/9/2
010
10/2
9/20
1011
/18/
2010
12/8
/201
012
/28/
2010
1/17
/201
12/
6/20
112/
26/2
011
3/18
/201
14/
7/20
114/
27/2
011
5/17
/201
16/
6/20
116/
26/2
011
7/16
/201
18/
5/20
118/
25/2
011
9/14
/201
110
/4/2
011
10/2
4/20
1111
/13/
2011
MIP
Gap
($)
Day
MIP Gap ($ difference)
Series1 30 per. Mov. Avg. (Series1)
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Slide 21
1. October 13 price corrections: Outage incorrectly modeled in real-time. Two/Three transformer banks were modeled as out when only
one of the four transformer banks was actually out. Invalid congestion occurred at a number of locations. Total of 92 RTD and HASP interval prices were corrected. Working to improve process/software to avoid similar
modeling errors.2. October 14 price corrections:
CAS sent incorrect import/export schedules in real-time created false large supply/demand imbalance.
Total of 9 RTD interval prices were corrected, 15 RTD intervals filled.
Recent Market Events
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Slide 22
3. San Diego Gas Pipeline Outages Outages are going well. No reliability issue encountered. Convergence bidding suspended on the weekends during the gas
pipeline outages. May finish one week ahead of schedule.
4. September 19 and 21 Day-Ahead Market Congestion Congestion in DA on a closed interface in a small area. Low ratio of local load relative to the total DLAP level load. Large DLAP load change to effect a small local area load change. Constraint relaxation may result in pricing run vs. scheduling run
differences Leads to high MCC and potential DLAP convergence bids
awarded off bid curve.
Recent Market Events (cont.)
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Slide 23
• Flexi-ramp nomogram – expected implementation in December.
• Group constraint implemented in October.
• Reduces exceptional dispatch related to pump operations
• More planned in 2012.
• Dynamic Transfer approved by FERC -
• Effective Date: November 1, 2011
• Intra-hour scheduling pilot started in October ~ 25MW
Updates and upcoming enhancements
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Slide 24
1. 33% Renewable Integration studies
• Scope next step of analysis – October 7 meeting• Incorporate LCR/OTC in studies – January 2012- March 2012
2. Annual resource adequacy evaluation
• 2011 resource adequacy assessment – November 20113. Frequency/Inertia Study
• Evaluate frequency response high renewable / low inertia • Complete, Report finalized by GE, publish end of September
4. Distributed Energy Resources
• Evaluate the visibility / controllability cost and benefits• Scheduled completion: December 31, 2011
Renewable integration related studies in progress at
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Policy Updates
Eric Little, ManagerMarket Design & Regulatory Policy
Page 25
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Market initiatives going to the Board for approval in 2011
Page 26
Initiative Board PresentationMulti-Stage Generating unit modeling enhancements
October 2011
Renewable Integration Market &Product Review Phase 2 – Vision and Roadmap
October 2011 (briefing only)
Renewable Integration Market & Product Review Phase 1
December 2011
Review and update of the Operations & Maintenance cost adder
December 2011
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Overview of current market design initiatives
• Multi Stage Generator Unit Modeling Enhancements – Increase number of configurations for MSG in RT– Required to bid from Minimum Operating Capacity to
RA capacity or Highest bid-in capacity• If not bid, ISO will insert cost-based bids
– Increase in the number of ramp rates per configuration
– Ability to schedule and MSG unit in RT into a configuration different that that scheduled DA
– Changes to BCR when transitioning between configurations
Page 27
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Overview of current market design initiatives(continued)
• RIMPR Phase 2– Elements split into:
• Short-term (now – 2013)– Regulation Energy Management, Flexible Ramping Constraint, Bid
Cost Recovery, 72-Hour RUC, Start-up and Shut-down profiles, Dynamic Transfers, Energy bid floor, PIRP Modifications, VER Forecasting, Enhanced Operating Reserves Management
• Mid (2013 – 2015)– Flexi-Ramp Product, Intertie Pricing and Settlement, Flexible Capacity
Forward Procurement, PIRP Resource Decremental Bidding, Pay for Performance Regulation
• Long-term (2015 – 2020)– Frequency/Inertia Response, Real-time Settlement (15 minute market),
Evaluate need for RTIS
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Overview of current market design initiatives(continued)
• RIMPR Phase 1: 5th revised straw proposal:– Lower the energy bid floor– Make changes to PIRP cost allocation– Remove DA, RT netting, add performance metric
• Review and update of default O&M cost adders– Update of costs– More granularity added
• Moved from 2 to 10 resource types
Page 29
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Market design initiatives coming soon
• Market design catalog update• Standard Capacity Product Phase III
– FERC order to apply SCP to all RA resources• Phase III will evaluate SCP for DR
• Marginal Loss Surplus Allocation– Targeted to start in the 4th quarter of 2011
• Post-emergency BCR filing review– Targeted to start in October, 2011
Page 30
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Distributed Energy Resources Visibility and Control Study Update
Heather Sanders, DirectorSmart Grid Technologies and Strategy
Page 31
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Briefing Overview
• Project Overview• Approach• Expected Deliverables• High-Level Timeline• Summary
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Background
• Increased adoption of Distributed Energy Resources will have impacts and benefits on the ISO and IOUs
• ISO/IOUs have limited ability to monitor, exchange information with, and control Distributed Energy Resources – this has an impact on their reliability functions
• A review of current interconnection requirements and configurations is needed to assess adequacy of reliability monitoring, functions, processes and control systems
• A cost / benefit comparison of additional visibility and control options is needed
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Project Overview
Develop Forecasts and Impacts…Identify baseline and penetration forecasts of Distributed Energy Resources on the ISO’s system by 2020, including:• Solar Photovoltaics• Energy Storage• Dispatchable Demand and Price Response• Combined Heat and Power (CHP)• Plug-in Electric Vehicles (PEV)
Create a Framework to Assess…• ISO current visibility of these Distributed Energy Resources• ISO current control of these Distributed Energy Resources• Future resource and technology developments
Implications…• Assess reliability and market cost impacts, given Distributed
Energy Resource forecasts• Identify potential enabling technology improvements to current
visibility and control requirements
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Objectives
• Do the current levels of visibility and control allow the ISO to manage the forecasted growth?
• How would additional visibility enhance the ISO’s ability to forecast and manage the system and markets?
• What are the costs and expected benefits to increased visibility and control?
• What are the technical requirements for monitoring and control to achieve market and operational benefits?
Overall project objective – To quantify operational, market, and implementation impacts of Distributed Energy Resource integration by answering these questions:
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Approach
Benefit / Cost
Analysis
Phase 1 Model
Phase 2 Simulate
Phase 3 Tech
Road Map
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Deliverables
Phase 1 -Model
• Monitoring and control technologies
• Current visibility and control requirements
• Baselines penetration forecasts
• Variability data• Impact of improved
visibility on forecasting error
• Technical feasibility and impact of variability management schemes
Phase 2 -Simulate
• Simulation results for base cases and additional scenarios
• Market impact analysis for baseline penetration and additional selected scenarios with varying visibility and control
Phase 3 –Technology Road Map
• Technology road map –identify most cost effective technologies for each visibility and control scenario
• Benefit/Cost Analysis
All deliverables pertain to Distributed Energy Resources
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High-level Timeline
Phase 1 - Model
• Penetration scenarios• Late October
2011
• Variability characteristics for penetration scenarios• Late October
2011
Phase 2 -Simulate
• Simulation results for selected scenarios• Mid to late
November 2011
Phase 3 –Technology Road Map
• Technology road maps for studied scenarios• Mid to late
December 2011
• Benefit/Cost Analysis• Late December
2011, Early January 2012
• Final Report• January/February
2012
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Summary
• This study should give the ISO and stakeholders an increased understanding of Distributed Energy Resources impacts and benefits
• The cost / benefit comparison of additional visibility and control options will inform ongoing ISO and other stakeholder policy activities
Page 39
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Technical Updates
Khaled Abdul-Rahman, DirectorLi Zhou, Senior AdvisorPower Systems Technology Development
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Technical Updates
Flexible RampingMarket Systems, CMRI and SaMC: All in testCMRI/OASIS/SaMC: External specifications published
NRS-RAA gap has been identified in testing for case when there is a self schedule not meeting the RA. It should use the “generated bid” to fill in the gap between the self schedule and RA capacity. But current rule does not do that. New SIBR rule set will be published this week. No impact to Market Participants.
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Technical Updates
MSG Enhancements (Phase 1)IFM/RTM in test
Changes in DAM and RTM for:• Terminal condition logic for MSG configurations• Ramp-rate segment limit for MSG configurations• Ability to self-schedule into Real-Time for different
configurations that have Day-Ahead energy or Ancillary Service awards
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Technical Updates
Example with MSG Terminal Condition
A MSG resource has the ability to transition between Configuration1 (C1) and Configuration2 (C2).Assume that C1 (minimum up time = 6) can transition to C2 (Minimum down time is 4 hours). In DA we commit them in C2 in HE 7. The terminal condition is to say that, in RTPD,
assuming we put this unit in C2 (HE 1), we cannot Transition to C1 within HE2 to HE6 (because we would have to maintain that Minimum up time and in this example would not make it to C2 by HE 7).
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Technical Updates
NGR/REMMarket Participants: Continue to sign up for participation in market simulation scheduled for Spring 2012. Six physical
resources. Nine pseudo resources.
Market Participant Inputs: We have made some adjustments based on MP’s inputs.
New Functional Updates: SLIC will allow for the de-rate of minimum charging andmaximum charging limits;
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Technical UpdatesNew Functional Updates: State of Charge will be calculated based on prior day’s IFM results, not submitted by MPs;Energy Curtailment Limit will be enforced in IFM as well as in RTM for demand response resources;Direct Telemetry and Metering requirement will be enforced for both LESR and DDR.Update of external BRS will follow.
CAISO Status: The main challenge and focus is the logic to recognize the continuous energy limit in both market applications and settlement.
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Technical Updates
LMPM Enhancements
OASIS Publication for market transparency (IFM/HASP)1. Interval based competitive and non competitive LMPs
including components with associated reference bus;2. AC run binding constraints with their shadow prices;3. Competitive and non competitive path designations.
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Release Plan Update
Janet Morris, DirectorProgram Office
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Release Plan - 2011• Fall 2011 release – http://www.caiso.com/informed/Pages/ReleasePlanning/Default.aspx
– RDRP (DRS deployment on 11/1)– FERC Order 741 Credit Reform / Settlements Timeline Improvements - deployed– Convergence Bidding limit changes - deployed– Dynamic Transfer – interim solution (deployed; to be activated 11/1/11)– Grouping Constraints - deployed– SIBR Interface Specification for Bidding Services - deployed
• October monthly release – OMS Phase 2 - deployed
• Seasonal rating change- 11/1/11• Daylight Savings Time Change – 11/06/11• Removal of Convergence Bidding on the Interties – 11/29• December monthly release – 12/13/11
– Generation of bids for NRS-RA– GMC rate structure change– Flexible Ramping– MSG Enhancements Phase 1– Contingency Flag enhancement (OASIS 6.0.4)
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Release Plan - 2012
• February 2012 monthly release– Enhanced Operating Reserve Management
• Spring 2012 release– Non-Generator Resources / Regulation Energy Management - Phase 1– LMPM Enhancements – MSG Enhancements Phase 2– Revisions to Default O&M Adder Values
• Fall 2012 Release– Non-Generator Resources / Regulation Energy Management - Phase 2– Data Release Phase 3– Enterprise Model Management (tentative)– Outage Management System (tentative)
Note: 72 Hour RUC schedule to be determined
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Fall 2011 Release - Reliability Demand Response Product (RDRP) FERC Order
• FERC opened a comment period for the ISO’s response to the Commission’s deficiency filing (Docket # ER11-3616-001)
• No Demand Response Agreements (and thus RDRR registrations) may be accepted by the ISO until FERC approval is received
• The ISO expects a FERC order on or about November 20th
• It is possible the FERC order could require software revisions, which may in turn impact the schedule up to an including the April 1, 2012 implementation
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Fall 2011 Release - Reliability Demand Response Product (RDRP) Release MilestonesMilestone DatePublish business requirementshttp://www.caiso.com/2b51/2b519218728d0.pdf
March 29
Publish draft BPM June 30Technical specificationshttp://www.caiso.com/27ab/27ab6e875c2e0.html
June 30
Implementation Planhttp://www.caiso.com/Documents/ReliabilityDemandResponseProductImplementationPlan.pdf
July 22
Market Simulation Plan http://www.caiso.com/Documents/Fall2011Release_OctoberMonthlyReleaseMarketSimulationPlan.pdf
July 29
Market Simulation(Registration & Settlement simulation delayed & expanded due to environment issues. Additional details in Market Sim meeting)
Aug 23 – Sept 9 (Bidding)Oct 17-21 (Settlement) Rescheduled
Production Deployment October 10 (Bidding)November 1 (DRS)
Production Activation April 1, 2012 On TrackPage 52
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December Monthly Release - Generation of Bids for NRS-RA
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Milestone Date StatusFrequently Asked Questions http://www.caiso.com/informed/Pages/StakeholderProcesses/GeneratedBidsOutageReporting-ResourceSpecificRAResources.aspx
Oct 13, 2011
RA Template Availabilityhttp://www.caiso.com/Documents/December%202011%20release%7CPlan%20templates/ProposedISOSupplyPlanTemplate.xls
http://www.caiso.com/Documents/December%202011%20release%7CPlan%20templates/ProposedISOResourceAdequacyPlanTemplate.xls
Sep 9, 2011
Technical specificationsSIBR Ruleshttp://www.caiso.com/Documents/December%202011%20release/ReleaseNotes-SchedulingInfrastructureBusinessRulesBusinessRulesforBidding-Version4.7.2_DecemberRelease.pdfMaster Filehttp://www.caiso.com/Documents/December%202011%20release/TechnicalInterfaceSpecificationforMasterFileDataExchangeServices.pdf
SIBR Rules – Aug 25, 2011
Master File – Aug 19, 2011
BPM change management submittal dates:Reliability Requirements: PR0487Settlements: PR0484Market Instruments: PR0486
Reliability Requirements - Sep 26 2011Settlements – Sep 12, 2011Market Instruments - Sept 21, 2011
IRR User GuideConfiguration guides Oct 27, 2011 On Track
Market Participant - NRS-RA Web Training Conference Oct 27, 2011 On Track
Market simulation Nov 8 - 14 On Track
Production deployment
IRR UI avail Nov 21, 2011 to load Jan 2012 monthly RA data Full deployment on Dec 13, 2011 Effective date is Jan 1, 2012
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December Monthly Release - GMC Rate Structure
Milestone Date
Application Software Changes • Congestion Revenue Rights (CRR)• Settlements
BPM Changes • Congestion Revenue Rights (CRR)• Settlements & Billing• Definitions & Acronyms
Board Approval May 2011
Configuration Guides September 26
FERC ruling September 30
Training Session - WebEx October 19 On Track
Statement Publication(3 daily statements +1 monthly statement +1 invoice)
Nov 8 – Nov 14 On Track
Production Activation January 1, 2012 On Track
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December Monthly Release – Flexible Ramping
Milestone Date
Application Software Changes • DAM/RTM• CMRI• OASIS• Settlements
BPM Changes • Settlements & Billing• Market Operations, Market Instruments
Business Process Changes • Manage Billing & Settlements• Manage Real Time Market
Board Approval August 2011
Configuration Guides September 26, 2011
Technical Specifications September 26, 2011
Market Simulation Nov 8, 2011 – Nov 18, 2011 On Track
Production Activation December 13, 2011 On Track
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December Monthly Release – MSG Enhancements (Phase 1)
Milestone DateApplication Software Changes Master File
Changes in DAM and RTM for:• Terminal condition logic for MSG configurations• Ramp-rate segment limit for MSG configurations• Ability to self-schedule into Real-Time for different configurations that have Day-Ahead energy or Ancillary Service awards
BPM Changes • Market OperationsBusiness Process Changes • TBD
Board Approval October 2011
Configuration Guides N/A
Technical Specifications N/A
Market Simulation Nov 8, 2011 – Nov 23, 2011
Production Deployment December 13, 2011
Production Activation Upon FERC order
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December Monthly Release – OASIS Contingency Flag
Milestone Date
Application Software Changes • DAM/RTM• CMRI• OASIS• Settlements
BPM Changes •Market Instruments
Technical Specifications http://www.caiso.com/Documents/InterfaceSpecification_OASIS
3-08_Clean.pdf
October 7, 2011
Release Notes http://www.caiso.com/Documents/OASIS6-0-4ReleaseNotes.pdf
October 7, 2011
Market Simulation Nov 8, 2011 – Nov 18, 2011 On Track
Production Activation December 13, 2011 On Track
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Milestone DateApplication Software Changes Phase I & II Phase III
DAM/HASP RTMMaster File (MF) CMRIOASIS OASIS
BPM Changes Market OperationsMarket InstrumentsSettlements & BillingDefinitions & Acronyms
Board Approval July 14, 2011
Tariff Filing October 2011
External Business Requirements Specifications November 15, 2011
BPM PRR December 5, 2011
Technical Specifications December 19, 2011
Market Simulation Starts February 6, 2012
Production Activation Phase I, April 10, 2012 Phase II, May 2012Phase III, Q4 2012
Spring 2012 Release – LMPM Enhancements
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Milestone DateApplication Software Changes SIBR
DAM/RTM SettlementsMaster File (MF) RIMSOASIS SLIC
BPM Changes
PRR submittal
Manage Full Network ModelMarket OperationsMarket InstrumentsOutage ManagementReliability RequirementsSettlements & BillingCompliance Monitoring December 5, 2011
External Business Requirements Specifications& FAQ
Posted; to be revised October 26, 2011
Tariff Filing August 22, 2011
Technical Specifications December 19, 2011
Market Simulation February 2012
Production Activation Spring 2012 (Phase 1)Fall 2012 (Phase 2)
Spring 2012 Release – NGR/REM
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Technical Users Group Update
Kevin Colmer, ManagerIT Architecture
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Technical Users GroupTopics Discussed since last update
• Web Service Versioning– Proposed methodology and policy tabled for review
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Future topics
• Endpoint consolidation
• ECN Strategy
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Outage Management System Phase 3
Jami Herguth, DirectorBusiness Solutions and Quality
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Outage Management System Phase 3 - Requirements
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Milestone Date
External User Checkpoint 1 September 14 Completed
External User Checkpoint 2 November 15 On Track
Requirements Walkthrough December 13 On Track
Use Cases Walkthrough January 18 On Track
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Stakeholder Participation
Posted Market Notice October 19 Notifying users that we have posted market participant scope requests and are
soliciting comments. Scope Requests are posted to
http://www.caiso.com/informed/Pages/StakeholderProcesses/OutageManagementSystemProject.aspx
Comments are due October 31. Participants can submit comments to [email protected]
ISO Executive sign-off on Phase 3 scope by early November
Planning an external Business Requirements Specification walk-through in mid-December
Subsequent reviews of user interface prototypes, sequence diagrams for B2B integration and use cases
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