Market Performance and Planning
Forum
December 19, 2012
Objective: Enable dialogue on implementation
planning and market performance issues
• Review key market performance topics
• Share updates to 2012-2014 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
Proposed Meeting Schedule for 2013
•
•
•
•
•
•
February 13
April 10
June 5
July 31
Sept 25
Nov 20
Page 3
Agenda
Agenda
10:00- 10:05
Introduction, Agenda
Mercy P. Helget
10:05 – 11:20
Market Analysis
Mark Rothleder, Nan Liu,
11:20 – 11:40
Outage Management System
Guillermo Bautista-Alderete
Jami Herguth
11:40 – 12:20
Release Updates
Janet Morris
12:20 – 1:00
Lunch
1:00 – 2:00
Technical Updates -
Li Zhou, George
FERC Order 755
Angelidis
2:00 – 2:20
Policy Updates
Delphine Hou
2:20 – 2:50
Valley Electric Association Modeling
Justin Wong
Note: Agenda is subject to change.
Slide 4
Market Performance and Quality Update
Market Quality and Renewable Integration
Mark Rothleder
Nan Liu
Guillermo Bautista-Alderete
Slide 5
1. Operation Highlights
2. Market Metrics
•
Price volatility and market convergence
•
RT energy/congestion imbalance offset
•
Convergence bidding
•
Exceptional dispatch
•
Bid cost recovery
•
MIP gap
•
Flex-ramp cost
3. Price Corrections
4. Events and developments
Slide 6
Operation highlights:
•
Improvements across most market metrics: price convergence,
exceptional dispatch, BCR, real-time congestion offset.
•
Real-time congestion offset cost peaked in August, trended
lower in the following months but remained at elevated levels.
•
Lower seasonal load, winter “needle” evening peak and
transmission outages present operational challenges in
December.
•
More outages and more constraints modeled in the market
continue to challenge operations and market solutions.
Slide 7
Nov-12
30
20
Nov-12
Sep-12
Jul-12
May-12
Mar-12
Jan-12
PG&E
Nov-11
Sep-11
Jul-11
May-11
RTD
Sep-12
20
$/MWh
HASP
Mar-11
Jan-11
Nov-12
Sep-12
Jul-12
May-12
Mar-12
Jan-12
Nov-11
Sep-11
30
Jul-12
0
Jul-11
IFM
May-12
0
May-11
50
Mar-12
10
Mar-11
40
Jan-12
Nov-11
Sep-11
Jul-11
May-11
Mar-11
Jan-11
$/MWh
10
Jan-11
$/MWh
DLAP LMP Monthly Average:
Price convergence improved in November
50
SCE
40
IFM
30
HASP
20
RTD
60
SDG&E
50
40
IFM
HASP
10
RTD
0
Page 8
90
80
70
60
50
40
30
20
10
0
Nov-12
Sep-12
Jul-12
May-12
Mar-12
PG&E
Jan-12
0
Nov-11
0
Sep-11
10
Jul-11
10
Nov-12
RTD
May-11
50
Sep-12
50
Mar-11
60
Jul-12
Jan-11
60
May-12
HASP
$/MWh
IFM
Mar-12
20
Jan-12
30
Nov-11
Nov-12
Sep-12
Jul-12
May-12
Mar-12
Jan-12
40
Sep-11
Jul-11
May-11
Mar-11
Jan-11
$/MWh
Nov-11
Sep-11
Jul-11
May-11
Mar-11
Jan-11
$/MWh
DLAP LMP Monthly Average (On Peak)
SCE
40
30
IFM
20
HASP
RTD
SDG&E
IFM
HASP
RTD
Page 9
20
10
Nov-12
Sep-12
Jul-12
May-12
Mar-12
PG&E
Jan-12
Nov-11
0
Sep-11
0
Jul-11
10
Nov-12
10
May-11
40
Sep-12
40
Mar-11
50
Jul-12
Jan-11
50
May-12
RTD
Mar-12
HASP
$/MWh
IFM
Jan-12
20
Nov-11
Nov-12
Sep-12
Jul-12
May-12
Mar-12
Jan-12
30
Sep-11
Jul-11
May-11
Mar-11
Jan-11
$/MWh
Nov-11
Sep-11
Jul-11
May-11
Mar-11
Jan-11
$/MWh
DLAP LMP Monthly Average (Off Peak)
SCE
30
IFM
20
HASP
RTD
40
SDG&E
30
IFM
HASP
RTD
0
Page 10
DLAP LMP Hourly Average in November
PG&E
SCE
IFM
40
HASP
30
$/MWh
50
RTD
20
10
0
1 2 3 4 5 6 7 8 9 101112131415161718192021222324
80
70
60
50
40
30
20
10
0
IFM
HASP
RTD
1 2 3 4 5 6 7 8 9 101112131415161718192021222324
Hour
SDG&E
120
100
$/MWh
$/MWh
60
80
IFM
60
HASP
40
RTD
20
0
1 2 3 4 5 6 7 8 9 101112131415161718192021222324
Page 11
Monthly price distributions: price volatility continued to
decrease in November.
4.0%
Percent of Real Time Intervals
2.0%
0.0%
Jan-11
Mar-11
May-11
Jul-11
Sep-11
Nov-11
Jan-12
Mar-12
May-12
Jul-12
Sep-12
Nov-12
-2.0%
-4.0%
-6.0%
-8.0%
-10.0%
-$30 to -$5
-$100 to -$30
-$300 to -$100
<-$300
$250 to $500
$500 to $750
$750 to $1000
>$1000
Page 12
Monthly average of RTD intervals with insufficient up
ramping capacity declined in November.
180
2.00%
160
1.80%
1.20%
100
1.00%
80
0.80%
60
0.60%
40
0.40%
Nov-12
Oct-12
Sep-12
Aug-12
Jul-12
Jun-12
May-12
Apr-12
Mar-12
Feb-12
Jan-12
Dec-11
Nov-11
Oct-11
Sep-11
Aug-11
Jul-11
Jun-11
May-11
0.00%
Apr-11
0
Mar-11
0.20%
Feb-11
20
Jan-11
Count of Intervals
1.40%
120
Percent of Intervals
1.60%
140
5-minute intervals with insufficient upward ramping capability
percent of intervals with insufficient upward ramping capability
Page 13
Monthly average of RTD Intervals with insufficient
down ramping capacity remained at low level.
5.00%
500
4.50%
4.00%
3.50%
3.00%
300
2.50%
2.00%
200
1.50%
1.00%
100
0.50%
Nov-12
Oct-12
Sep-12
Aug-12
Jul-12
Jun-12
May-12
Apr-12
Mar-12
Feb-12
Jan-12
Dec-11
Nov-11
Oct-11
Sep-11
Aug-11
Jul-11
Jun-11
May-11
Apr-11
Mar-11
0.00%
Feb-11
0
Jan-11
Number of Intervals
400
5-minute intervals with insufficient downward ramping capability
percent of intervals with insufficient downward ramping capability
Page 14
Real-time energy offset costs increased in November
but remained at relatively low level.
Page 15
-10
Apr-09
May-09
Jun-09
Jul-09
Aug-09
Sep-09
Oct-09
Nov-09
Dec-09
Jan-10
Feb-10
Mar-10
Apr-10
May-10
Jun-10
Jul-10
Aug-10
Sep-10
Oct-10
Nov-10
Dec-10
Jan-11
Feb-11
Mar-11
Apr-11
May-11
Jun-11
Jul-11
Aug-11
Sep-11
Oct-11
Nov-11
Dec-11
Jan-12
Feb-12
Mar-12
Apr-12
May-12
Jun-12
Jul-12
Aug-12
Sep-12
Oct-12
Nov-12
$Millions
Real-Time congestion offset costs trended lower in recent
months with November concentration of congestion in the
San Diego area.
60
50
40
30
20
10
0
Congestion Imbalance Offset
Energy Imbalance Offset
Slide 16
Exceptional dispatch volume decreased in November,
less than one half percent of total dispatch.
Total Exceptional Dispatch as Percent of Load
2.50%
2.00%
% of Total Load
1.50%
1.00%
0.50%
0.00%
Jan
Feb
Mar
Apr
May
Jun
Jul
Aug
2009
2010
2011
2012
Sep
Oct
Nov
Dec
Page 17
Daily exceptional dispatches in MWh – by reason
40
30
Exceptional dispatch to prepare for
post-contingency reduction of SOL
per operating procedures.
25
20
15
10
5
0
1-Oct
3-Oct
5-Oct
7-Oct
9-Oct
11-Oct
13-Oct
15-Oct
17-Oct
19-Oct
21-Oct
23-Oct
25-Oct
27-Oct
29-Oct
31-Oct
2-Nov
4-Nov
6-Nov
8-Nov
10-Nov
12-Nov
14-Nov
16-Nov
18-Nov
20-Nov
22-Nov
24-Nov
26-Nov
28-Nov
30-Nov
Thousands MWh Per Day
35
Transmission Outage
T Procedure
System Energy
Other
Software Limitation
Conditions beyond control of the CAISO BA
Ramp Rate
Page 18
$Millions
20
18
16
14
12
10
8
6
4
2
0
Jan-10
Feb-10
Mar-10
Apr-10
May-10
Jun-10
Jul-10
Aug-10
Sep-10
Oct-10
Nov-10
Dec-10
Jan-11
Feb-11
Mar-11
Apr-11
May-11
Jun-11
Jul-11
Aug-11
Sep-11
Oct-11
Nov-11
Dec-11
Jan-12
Feb-12
Mar-12
Apr-12
May-12
Jun-12
Jul-12
Aug-12
Sep-12
Oct-12
Nov-12
Bid cost recovery (BCR) costs decreased in November
and RUC uplifts were still high.
IFM
RT
RUC
Page 19
Good MIP gap performance in November.
100,000
October 1 and 2 low quality
solution due to timeout of
solution
90,000
80,000
60,000
50,000
40,000
30,000
20,000
Daily Dollar
11/1/12
10/1/12
9/1/12
8/1/12
7/1/12
6/1/12
5/1/12
4/1/12
3/1/12
2/1/12
1/1/12
12/1/11
11/1/11
10/1/11
9/1/11
8/1/11
7/1/11
6/1/11
5/1/11
4/1/11
3/1/11
0
2/1/11
10,000
1/1/11
Mip Gap ($)
70,000
30 Day Moving Average
Page 20
Price corrections reduced in November.
1.2%
Percentage of Nodes Corrected
1.0%
Incorrect distribution factors in two
weeks of July caused 70% of
corrections in July
Market Software
timed out while
searching for the
solution
0.8%
0.6%
0.4%
0.2%
0.0%
Jan
Feb Mar Apr May Jun
Jul
Aug Sep
Oct Nov Dec
Jan
Feb Mar Apr May Jun
2011
Data Input
Jul
Aug Sep
Oct Nov
2012
Software
Tariff
Process
Page 21
Price corrections reduced in November.
1.2%
Percentage of Nodes Corrected
1.0%
Incorrect distribution factors in two
weeks of July caused 70% of
corrections in July
Market Software
timed out while
searching for the
solution
0.8%
0.6%
0.4%
0.2%
0.0%
Jan
Feb Mar Apr May Jun
Jul
Aug Sep Oct Nov Dec Jan
Feb Mar Apr May Jun
2011
Jul
Aug Sep Oct Nov
2012
RTD
HASP
DA
Page 22
Flexi-ramp constraint costs continued the downward trend
in November.
Monthly Flexi-Ramp Cost
4.5
4
$Millions
3.5
3
2.5
2
1.5
1
0.5
0
Dec-11
Jan-12
Feb-12 Mar-12
Apr-12 May-12 Jun-12
Jul-12
Aug-12 Sep-12
Oct-12
Nov-12
Slide 23
Events and Developments:
•
CAISO Board approved the proposal to modify the real-time
scheduling run transmission constraint relaxation parameter from
$5000 to $1500. Significant increase of transmission constraint
relaxation in real-time this year over 2011.
•
Implemented software feature to avoid infeasible manual adjustments
in the real-time market.
•
Based on stakeholder feedback of interest, reversed the plan to stop
publishing the monthly market catalog report due to low interests.
•
Will reduce the redundancy/duplication of exceptional dispatch
reports.
Slide 24
Release Updates
Jami Herguth
Director, Business Solutions
Slide 25
Outage Management System (OMS) Update
• Changes in the landscape
• ISO is not staffed to delivery OMS with number of
policy changes impacting this area
• Turnover in staffing earlier this year led us to reevaluate vendors
• Several vendors now have model-aware OMS
solutions
• Finished Build versus Buy decision pending final vendor
negotiation
Slide 26
Outage Management System (OMS) Update
• Vendor selected for final negotiation is Ventyx/ABB
• Two-month vendor engagement on requirements
beginning in January
•
Stakeholder input on generation module received earlier this year
•
What was communicated as in-scope remains part of the negotiation
• Objective is to align ISO processes to out-of-the-box
Ventyx/ABB solution as much as possible while meeting
tariff and efficiency requirements
• This activity will conclude negotiations and runs through
the end of March
Slide 27
Release Updates
Janet Morris
Director, Program Office
Slide 28
The ISO offers comprehensive training programs
Date
Training
December 20
Welcome to the ISO (webinar)
January 8
Introduction to ISO Markets (on-site)
January 9, 10
Market Transactions (on-site)
January 15
Settlements 101 (on-site)
January 16
Settlements 201 (on-site)
January 24
Welcome to the ISO (webinar)
January 31
Introduction to ISO Markets (Houston)
February 1
Settlements 101 (Houston)
Training calendar - http://www.caiso.com/participate/Pages/Training/default.aspx
Contact us - markettraining@caiso.com
Page 29
Release Plan – 2012
•
Fall 2012 – deployed and activated
• Non-Generator Resources / Regulation Energy Management - Phase 2
• Data Release Phase 3
• 72 Hour RUC
• Transmission Reliability Margin
• Contingency Dispatch Enhancements (RTDD enhancements not activated)
• Regulatory Must Take Generation
• Group Constraint enhancement
• BAPI, OASIS – UI upgrade (does not impact API)
• Replacement Requirement for Scheduled Generation Outages
•
Year End 2012
• Settlements 9.07 (12/18/12)
• DB62 (12/19/12)
• Commitment Costs Refinements - Greenhouse Gas Regulation (1/1/13)
• City of Colton activation (1/1/13)
• Valley Electric Association activation (1/3/13)
Page 30
Release Plan – 2013
•
Spring 2013
• MSG Phase 3 deployment
• FERC Order 755 – Pay for Performance
• LMPM Enhancements Phase 2
• Exceptional Dispatch Mitigation in Real Time
• Post Emergency Filing BCR changes / Mandatory MSG
• Flexible Capacity and Local Reliability Resource Retention
• Price Inconsistency Market Enhancements (not including bid floor cap)
• DRS API deployment
• Master File Enhancements Phase 2 (tentative)
• FERC Order 745: Changes to the DR Compensation for PDR
• Access and Identity Management
• CMRI UI upgrade (does not impact API)
•
Fall 2013
•
RIMPR-Phase 1 / BCR Mitigation Measures / Bid Floor Cap
•
Circular Scheduling
•
Commitment Cost Refinements (remaining scope)
•
Ancillary Services Buy-Back
Page 31
Release Plan – 2014 (proposed)
•
Spring 2014
• FERC Order 764 Compliance / 15 Minute Market
• Dynamic Transfers
•
Fall 2014
•
Flexible Ramping Product
•
iDAM (simultaneous IFM and RUC)
•
Subject to further release planning:
• Outage Management System (Scoping phase to start January 22, 2013))
• Enterprise Model Management System
• Subset of Hours
• Flexible Resource Adequacy Criteria and Must Offer Obligation
Page 32
2012 Release Plan
http://www.caiso.com/Documents/2012ReleasePlan.pdf
2013 Release Plan
http://www.caiso.com/Documents/2013ReleasePlan.pdf
Page 34
BPM Change Management Enhancement Replacement
Milestone
Date
Application Software Changes
BPM: The purpose of this project is to replace the existing Business Practice
Manual (BPM) Change Management system to improve usability, increase
stakeholder participation, redesign the system architecture and enhance
functionality by leveraging existing SharePoint functionality
BPM Changes
None
Business Process Changes
Not Applicable
Board Approval
Not Applicable
External Training
December 12, 2012
Tariff
Not Applicable
Production Activation
January 7, 2013
Page 35
Fall 2012 Release Deployment Dates
The new deployment and activation dates are as follows:
Drop
DEPLOYMENT
ACTIVATION
Revised
Revised
Settlements fall release for November
MRI Settlements Application deployment
Congestive Revenue Rights (CRR)
RRSGO - IRR
11-01-2012
11-05-2012
11-12-2012
11-12-2012
RRSGO - RAAM
11-27-2012
11-27-2012
1
Master File (MF) and Application Integration Layer
11-20-2012
11-20-2012
2
Application Upgrade Deployment – part 1

FERC 745
Application Upgrade Deployment – part 2

CDE RTCD

Group Constraints
12-03-2012
12-03-2012
12-03-2012
12-04-2012
Application Upgrade Deployment – part 3
• Open Access Same-Time Information System (OASIS) –
MRI
• Market Participant Portal (MPP)
12-13-2012
See project slides
3
Description
http://www.caiso.com/Documents/Fall%202012%20release%20-%20plans
Page 36
Fall 2012 Release – SIBR Business Rules Revision Summary
Milestone
Associated project(s)
Date
SIBR BR v5.0
NGR rules
Posted
SIBR BR v5.1
RMT on/off peak self-schedule quantity
Posted
SIBR BR v5.2
MSG Enhancements modifications
Posted
SIBR BR v5.3*
72h RUC modifications
Posted
SIBR BR v5.4*
Green house gas and MSG group constraints
Posted
* Note: SIBR BR sets 5.3 and 5.4 may be revised beyond June 29, pending review with
software vendor and stakeholders
Page 37
Fall 2012 Release – RDT and API Versioning
RDT/API
Versioning
Generator
GRDT 6.5 (and 6.5 in second row of RDT XLS file)
Intertie
IRDT 4 (and 4.1 in second row of RDT XLS file)
SLIC
SLIC API 4.4.1
Detailed in Technical Specifications to be posted July 23, 2012
Page 38
•
Fall
2012 Release – Web Service Changes
ADS
•
•
•
OASIS
•
•
•
•
•
•
•
New API version 3.10.1 available, URL is not changing.
(Data Release Phase 3) Update to OASISReport / API Web Service to accommodate query
of “Wind and Solar Forecasting Data” data
(Data Release Phase 3) New OASISCRRPublicBid / API Web Service to accommodate query
of “CRR Public Bid Data” data
(Data Release Phase 3) Update to OASIS OASISReport / API Web Service to accommodate query
of “Aggregated Generation Outage” data
(Greenhouse Gas) Update to OASIS OASISReport / API Web Service to accommodate query
of “GHG Allowance Index Price” data
(TRM) Update to OASIS OASISReport / API Web Service to accommodate query
of the Transmission-related reports (Current Transmission Usage, Transmission Interface Usage, ATC)
SLIC
•
•
•
•
New API version 5.1 available; version 3.1 will be deprecated.
(Contingency Dispatch) Update to ADS APIWebService Web Service / API to accommodate new data elements
(contingencyType & pathExclusion)
New API version ID 4.4.1available
API versions 4.0, 3.0 and 2.0 also supported
(NGR-REM) Update to SLIC API External Web Services to accommodate updates/queries
of “NGR-REM” data
MFRD
•
•
•
•
(RMTG) Update to MFRD GeneratorRDT Web Service / API to accommodate updates/queries
of “Regulatory must take maximum (RMTMax)” data -- GeneratorRDT_v20121001
(MLCA) Update to MFRD IntertieRDT Web Service / API to accommodate updates/queries
of “Marginal Loss Cost Adjustment” data -- IntertieRDT_v20121001
(GHG) Update to MFRD GeneratorRDT Web Service / API to accommodate updates/queries
of “Green House Gas” data -- GeneratorRDT_v20121001
(NGR-REM) Update to MFRD GeneratorRDT Web Service / API to accommodate updates/queries
of “NGR-REM” data -- GeneratorRDT_v20121001
Page 39
Fall 2012 Release – NGR Phase II: Non-Rem
Milestone
Date
SIBR: NGR as a generation resource
Application Software Changes
DAM/RTM: Model NGR with an negative to positive power injection Settlements
- Settle the NGR energy and AS similar as generator; Master File: Define NGR
resource characteristics and REM flag SLIC: Support NGR register outage or
de-rate ramp rates OASIS: Include NGR for publishing T+90 bids,
EMS: Model NGR with supply range of negative to positive
BPM Changes
Manage Full Network Model
Market Instruments
Settlements & Billing
Market Operations
Outage Management
Compliance Monitoring
Business Process Changes
May 31, 2012 - Expected Energy Calculations –PRR 563
External Business Requirements Update
June 8, 2012
Technical specifications
July 19, 2012
Market Simulation registration conference call
July 23, 2012
Configuration Guides
Aug 1, 2012
ISO delivery of Market Simulation RDT 6.5 to Market Participant
Aug 17, 2012
Market Simulation RDT
August 27th, 2012- Please submit to MarketSim@caiso.com
NGR-REM workshop
Aug 30, 2012, 10-4pm
Updated BPM
Sep 2012
Market Simulation
Sep 11 – 28, 2012
Production Activation
Dec 1, 2012
Page 40
Fall 2012 – Data Release (Phase 3)
Milestone
Date
Application Software Changes
MPP: Load Distribution Factors (DA), Shift Factors (DA, HASP,
RTD), Transmission Limits (DA, HASP, RTD)
OASIS: Aggregated Generation Outages, Wind and Solar Forecasts,
CRR Public Bids
BPM Changes
Market Instruments
Business Process Changes
None
Board Approval
May 17, 2011
External Business Requirements
March 19, 2012
NDAs/AARFs
NDA posted October 25, 2012
NDAs/AARFs must be returned by December 3, 2012
OASIS/ CMRI Technical Specifications
July 19, 2012
Updated BPMs
Posted on October 11, 2012; Publish by November 30, 2012
Market Simulation
Sept 24 – Oct 5, 2012 (OASIS), Oct 1 – Oct 5, 2012 (MPP)
Tariff
Tariff filed October 5, 2012
Approval received December 10, 2012
Production Activation
Trade Date 12/11/12; consistent with our tariff, provision of 30
days to post this data, data will be posted back to 12/11/12
upon deployment
Page 41
Fall 2012 – 72 Hour RUC
Milestone
Date
Application Software Changes
CMRI : Existing reports will publish extra long start unit
binding startup instructions / initial condition
BPM Changes
Market Operations
Market Instruments
Business Process Changes
Not Applicable
External Business Requirements
September 23, 2010 and September 1, 2011
(BPM synch revision)
Technical Specifications
Not Applicable
Updated BPMs
October 28, 2011
Market Simulation scenarios
July 30, 2012
Market Simulation
September 18-21
Production Activation
Trade Date TBD
Page 42
Fall 2012 – Transmission Reliability Margin
Milestone
Date
Application Software Changes
OASIS –Three TRM component line items added.
BPM Changes
Market Instruments, Market Operations, Full Network Model, Reliability
Requirements, Congestion Revenue Rights, Acronyms and Definitions
Business Process Changes
Manage Real-Time Interchange Scheduling
Board Approval
March 22, 2012
External Business Requirements
April 9, 2012
Technical Specifications
July 19, 2012
Updated BPMs
July 31, 2012
Market Simulation
September 24-28, 2012
Tariff
Filed
April 2012
Approved June 2012
Production Activation
12-17-2012
Page 43
Fall 2012 – Commitment Cost Refinements - GHG
Milestone
Date
Application Software Changes
Master File: Two new modifiable fields in the Generator RDT.
• A yes / no flag to indicate whether a resource has a Greenhouse gas (GHG)
compliance obligation
• GHG emission rate / factor for resources that have a GHG compliance obligation
SIBR: (CAISO internal) Changes to calculation of Generated Bids, Startup (SU) and
Minimum Load (ML) Costs for resources that have a GHG compliance obligation.
OASIS: A new report to show the GHG Allowance index price used in the calculation
of proxy SU and ML costs as well in the default energy bids and generated bids.
BPM Changes
Market Instruments – 11/9/12
Business Process Changes
Manage Reliability Requirements
Board Approval
May, 2012
External Business
Requirements
June 29, 2012
Market Simulation RDT
August 27th, 2012- Please submit to MarketSim@caiso.com
Market Simulation
September 24–October 12, 2012
Technical Specifications
July 23, 2012
(Master File Generator Data API, OASIS Report GHG Allowance Price)
Tariff
Filing – 10/29/12
RDT Submission
The RDT contains the GHG_COMPLIANCE_OBLIG flag and the EMISSION_RATE field. MPs will
update the flag to Y and provide an emission rate for their covered resources and submit the RDT
RDTs must be submitted by Dec 21 to have their updates in for 1/1. Anything after 12/21 will be
accepted just not available on 1/1.
If the GHG_COMPLIANCE_OBLIG flag is set and the EMISSION_RATE is not submitted the RDT
will be rejected.
Production Activation
Trade Date January 1, 2013
Page 44
Fall 2012 Release – DR Net Benefits Test
FERC Order 745 Compliance – DR compensation in organized wholesale
Markets
Milestone
Date
Application Software Changes
Demand Response System (DRS): 6/26 - No longer impacted.
Settlements
• Automation of the calculation of the Monthly Demand Response DR
Net Benefits test (NBT) Threshold Prices.
• Change Settlement Charge Codes (RT Energy Pre-Calc, CC6806,
CC6475, CC6477) to comply with guidance issued in FERC order
745
BPM Changes
Market Operations, Settlement Configuration Guides, Definitions and
Acronyms
External Business Requirement Specification
May 2, 2012
Configuration Guides
Aug 27, 2012 – CC6806, CC6475, CC6477, RT Energy Pre-Calculation
[Please attend SaMC User Group meeting for more information
regarding charge code changes.]
Market Simulation
September 27, 2012
Production Deployment
Spring release 2013
Production Activation
May 1, 2013
Retroactive settlement dating back to effective trade date Dec 15, 2011
Page 45
Fall 2012 – Contingency Dispatch Enhancements
Milestone
Date
Application Software Changes
RTM: Prioritize Operating reserves dispatch over energy-only during
Disturbance Control Standard (DCS) event
ADS:
• Always broadcast the Dispatch when it is coming from Real-Time
Contingency Dispatch (RTCD).
• Two new fields to indicate
 RTCD was a Disturbance Dispatch (Prioritized Operating
Reserves over energy-only bids)
 Incrementing the Northern Ties was skipped
 Incrementing Southern Ties was skipped
BPM Changes
Market Operations
Business Process Changes
Manage Real-Time Contingency Dispatch
Board Approval
May 16, 2012
External Business Requirements
May 8, 2012
Updated BPMs
RTCD-6/15/12 (Complete), RTDD-8/17/12 (Complete)
Tariff
Filed October 10, 2012
Requesting FERC approval by Dec 2012
Technical Specifications
July 20, 2012 (ADS.caiso.com API)
Note: Will include ADS screen-shots
Market Simulation
September 20, 2012 – October 5, 2012
Production Activation
RTCD-12/04/12
RTDD- subject to FERC response
Page 46
Fall 2012 – Regulatory Must Take Generation
Milestone
Description/Date
Application Software Changes
Master File: Allow SCs of Combined Heat and Power (CHP) resources to view
On-peak and off-peak regulatory must take maximum (RMTmax) values along
with their expiration dates via generator Resource data template (GRDT). For
CHP resources, RMTMax values must be within Pmin and Pmax and must be
renewed at least once every 12 months.
SIBR: Change validation rules to only allow self-scheduling priority up to the
resource’s RMTMax value for on-peak and off-peak hours. Current validation is
to allow self-schedule priority up to Pmax.
BPM Changes
Market Operations and Market Instruments to be posted on 9/27/12
Business Process Changes
Potential new business process to
• Manage contracts and approval of a CHP resource for RMT
External Business Requirements
April 30, 2012 (updated June 26, 2012)
Market Simulation RDT
August 27th, 2012- Please submit to MarketSim@caiso.com
Board Approval
May 16, 2012
Technical Specifications
July 23, 2012 (Master File Generator Data API)
Tariff
Re-Post Final Draft
FERC Filing
Market Simulation
September 18-28, 2012
RMTG Value Letter and Registration
Process
October 23, 2012
Production Activation
September 10, 2012
September 17, 2012
Trade Date 12/11/12
Page 47
Fall 2012 – Group Constraints - (Recognition of Order of
Startups between Grouped Resources Enhancement)
Milestone
Date
Application Software Changes
Database Model: In order to distinguish the resources with different priority levels
within the same group, a new column will be introduced into
EMM_SCUC_IMM_GROUP_MEMBERS. New rows will be added to existing tables
EMM_SCUC_IMM_GROUP_CONSTRAINTS and potentially
EMM_SCUC_INPUT_GR_CNSTR_STATUS.
Master File: Population from Masterfile will be modified to account for two new
constraint types populated to EMM_SCUC_IMM_GROUP_CONSTRAINTS
Technical Bulletin
May 2012
Business Process Changes
N/A
Production Activation
12/04/2012
Page 48
Fall 2012 – Replacement Requirements for Scheduled Generation Outages
Milestone
Date
Application Software Changes
IRR and RAAM
BPM Changes
BPM Posting October 2012: Outage Management & Reliability Requirements
Settlements BPM Posting November 2012: Not applicable due to FERC Ruling
Settlements (2 new charge codes): Not applicable due to FERC Ruling
Manage Generation Outages:
Business Process Changes
• RA Outage Management Process (new)
Manage Reliability Requirements:
• Annual Monthly RA Process (new)
Settlements
NA
Board Approval
July 12, 2012
External Business Requirements
July 16, 2012
Templates
September 20, 2012 New template posted
September 24, 2012 Call about use of new template
Training
October 19, 2012
December 14, 2012
Market Simulation
November 5, 2012
Tariff
September 20, 2012 Tariff Filed; order received
Compliance Filing December 19, 2012
Production Activation
November 12, 2012 Open for submittals
November 21, 2012 (T-41 Deadline for January 2013 submittals)
RAAM is deployed on November 27, 2012
February 2013 T-45 RA Plans and Supply Plans due Dec 18, 2012
RA Resubmittals of Cures Required December 20, 2012
Page 49
2012 Year End Activation
City of Colton
Milestone
Date
Application Software Changes
N/A
BPM Changes
N/A
Board Approval
September 11, 2012
Market Simulation
N/A
Production Activation
January 1, 2013
Valley Electric
Association Milestone
Date
Application Software Changes
N/A
BPM Changes
N/A
Board Approval
September 11, 2012
Market Simulation
December 10 - 14, 2012
Production Activation
January 3, 2013
Page 50
Spring 2013 Release – RDT and API Versioning Alert
RDT
Generator V7.0
IRDT
Versioning
The ISO will deprecate the current production version of the GRDT
with the 2013 Spring Release and will only support a single
version which includes CERT_REG_DOWN and CERT_REG_UP,
no longer supporting CERT_REG. The ISO will only be supporting
v7.0 (previously v6.5) of the GRDT UI and V1 (previously
v20121001) of the GRDT API.
The ISO will continue to support 2 versions of the IRDT which is
not being affected by the Spring Release.
Page 51
Spring 2013 - Flexible Capacity and Local Reliability Resource Retention
Milestone
Date
Application Software Changes
The Flexible Capacity and Local Reliability Resource Retention (FLRR) will
allow the ISO to pursue tariff changes that will ensure the ISO has sufficient
backstop procurement authority to address capacity at risk of retirement that
the ISO identifies as needed up to five years in the future to maintain system
flexibility or local reliability.
MasterFile: Designate FLRR resources and input/store the going-forward
costs; Define FLRR cost allocation Areas.
Settlements: New Charge Codes for FLRR payments and allocations.
POTOMAC/RLC: Energy: LMP – Default Energy Bid, Start up and Minimum
Load Costs, Ancillary Services Costs
BPM Changes
Reliability Requirements, Settlements & Billing
Business Process Changes
Manage Entity & Resource Maintenance Updates (MMR LII), Manage Long
Term Transmission Planning (DI LII), Manage Market Billing & Settlements
(MOS LII)
Board Approval
September 2012
External Business Requirements
January 2013
Updated BPMs
January 2013
Market Simulation
February 2013
Tariff
Filing December 12, 2012
Production Activation
FLRR Designation – April 1, 2013
Settlements, Master File, RLC – April 1, 2013
Page 52
Spring 2013 – MSG Enhancements (Phase 3)
Milestone
Date
Application Software Changes
Master File: System must be extended to allow the registration of minimum
up time (MUT) or minimum down time (MDT) on a group of MSG
configurations. Registrations would be submitted to the ISO via a separate
registration form.
DAM/RTM: System must be able to recognize the MUT and MDT constraints
on a group of configurations (as registered in the Master File) during the
optimization.
BPM Changes
Market Instruments, Market Operations
Business Process Changes
Not Applicable
Board Approval
Not Applicable
External Business Requirements
June 15, 2012 (updates made to document)
Registration Form
Draft Available 7/13/12 (subject to change before Market Simulation)
Market Simulation
February 11-15, 2013
Tariff
Not Applicable
Production Activation
May 1, 2013
Page 53
Spring 2013 – FERC Order 755 pay for performance
Milestone
Description/Date
Application Software Changes
SLIC – Provide a regulation outage flag CMRI : provide DA and RT regulation
up/down mileage price and awards DAM/RTM: include mileage bids and
requirements into the optimization and generate mileage price and awards
Master File: regulation certification based on 10 min ramping capability
OASIS: provide DA regulation up/down mileage price, system mileage
multipliers, system mileage requirement, actual system mileage, historical
mileage bids, historical resource mileage multipliers Settlements : calculate
mileage payment, mileage cost allocation and GMC for mileage bids SIBR:
receive and validate regulation up/down mileage bid
BPM Changes
Market Operations
Settlements & Billing
Business Process Changes
Maintain Master File, Day Ahead Process, Manage Billing and Settlements,
Manage Analysis Dispute and Resolution, Market Performance (MAD),Market
Performance (DMM), Manage AS Certification and Testing
Board Approval
March 23, 2012
External Business Requirements
June 7, 2012
December 10, 2012 (update)
Technical Specifications
Nov 16, 2012- MasterFile technical specifications, SIBR rules, charge code list
Dec 21, 2012 – OASIS, CMRI and SLIC, technical Specifications
Jan 8, 2013 – Settlements configuration guides
External Training
Jan 23, 2013
Market Simulation
Feb 5, 2013 registration deadline Dec 19, 2012
Product Activation
May 1, 2013 (Extension approved by FERC 12/3/2012)
Market Instruments
Definitions & Acronyms
Page 54
Spring 2013 – LMPM Enhancements (Phase 2)
Milestone
Date
Application Software Changes
Real-Time Market: MPM for 15 min. DCPA for HASP and 15 min.
OASIS: Display LMPM-related components for nomogram & intertie
shadow prices, and competitive paths for real-time
CMRI : Display real-time mitigated bid curve
[Note: Mitigation for Exceptional Dispatch in Real Time will be added]
BPM Changes
Market Operations
Market Instruments
Business Process Changes
Real Time Market & Grid
Manage Real Time Market- After Close of Market
Manage Real Time Operations- Generation Dispatch
Board Approval
July 14, 2011
External Business Requirements
November 1, 2012
OASIS/ CMRI Technical Specifications
December 21, 2012
Updated BPMs
March 2013
Market Simulation
February 2013
Tariff
Post Draft Tariff December 18, 2012
Stakeholder Comments and Call January 2013
FERC filing targeted for February 2013
Production Activation
Spring Release 2013 (May 1, 2013)
Page 55
Spring 2013 – Mitigation for Exceptional Dispatch in Real
Time (Combined with LMPM P2)
Milestone
Application Software Changes
Date
IFM/RTM:
• A default competitive constraint list will be calculated based on the most
recent 60 days in the RTUC run where DCPA is calculated and deemed
competitive 75% or more of the instances where the constraint was binding;
unless they meet the competitive criteria with exception to path 15 and path
26. The frequency of update will be based on ISO specified parameter.
• Will use the default competitive constraint list as “back-up” in the event
that DCPA within the real time market fails to produce valid set of path
designations.
• Will compare the constraint received for the exceptional dispatch with the
default competitive constraint list to determine the type to mitigate pricing.
BPM Changes
Market Operations
Business Process Changes
Manage MQS
Board Approval
December 14 , 2012
External Business Requirements
TBD
Updated BPMs
March 2013
Market Simulation
February 2013
Tariff
Post Draft Tariff December 18, 2012
Stakeholder Comments and Call January 2013
FERC filing targeted for February 2013
Production Activation
Spring Release 2013 (May 1, 2013)
Page 56
Spring 2013 - Post Emergency BCR Filing / Mandatory MSG
Milestone
Application Software Changes
BPM Changes
Date
Master File: Additional MSG Configuration registrations need to completed
by Spring Release 2013.
Reporting: Monthly Market Reports incorporating greater granularity in
reporting BCR components have been made available.
SAMC: Requires a tune-up on formulas to determine the ON criteria for
resources, and the eligibility for Bid Cost Recovery.
Market Instruments; Settlements & Billing
Business Process Changes
N/A
Board Approval
Feb 16, 2012
External Business Requirements
Dec 19, 2012
Updated BPMs
TBD
Market Simulation
TBD
Tariff
TBD
Production Activation
Spring 2013
Page 57
Spring 2013 – Price Inconsistency Market Enhancements
Milestone
Date
IFM/RTM:
Application Software Changes
-
Use both MW awards and clearing prices from the pricing run
Use ANode prices for settlements of bids at default load aggregate
points and trading hubs, contingent upon the ISO ability to generate an
Anode for the real-time markets.
BPM Changes
Market Instruments; Market Operations
Business Process Changes
N/A
Board Approval
November 1, 2012
External Business Requirements
December 2013
Updated BPMs
March 2013
Market Simulation
February 2013
Tariff
TBD
Production Activation
Spring 2013 Release
Page 58
Spring 2013 – Access and Identity Management (AIM)
Milestone
Date
Application Software Changes
The goal of the AIM project is to improve upon the existing approach for
establishing, updating and terminating access to applications as well as
providing visibility (transparency), ease of use and self-service where
appropriate to POCs (Points of Contact), internal ISO users, business units
and IT to manage this process from end to end.
AIM: New system with UI and workflow
BPM Changes
Congestion Revenue Rights; SC Certification and Termination; Candidate
CRR Holder; Definitions and Acronyms
Business Process Changes
IT Access Mgmt. - Certificate based application access; Metering systems
access
Board Approval
N/A
External Business Requirements
December 2012
Updated BPMs
TBD
Market Simulation
TBD
Tariff
N/A
Production Activation
Spring 2013 Release (Tentative)
Page 59
Fall 2013 – RIMPR Phase 1 / BCR Mitigation / Bid Floor
Milestone
Date
Application Software Changes
IFM/RTM: Energy Bid Floor to -$150/MWh
MQS:
• Modify MLC calculation and cost allocation rules.
• Change DA MLC determination
• Program PUIE calculation (may need to change MQS energy algorithm)
• Split netting between DA and RT markets.
Settlements:
• Modify and build up to 12 charge codes to implement new BCR netting
rules and MLC.
• Program PUIE (persistent UIE) calculation.
• Program new RT PM (performance metric) calculation.
• Offset DA MLC by MLE revenues.
SIBR:
• SIBR rule changes will be needed to change the bid floor from -$30 (soft)
to -$150 (hard).
BPM Changes
Settlements & Billing, Market Operation
Business Process Changes
Manage Billing and Settlements, Market Performance
Board Approval
Bid Floor and BCR netting: December 15-16, 2011
BCR Mitigation Measures: December, 2012
External Business Requirements
TBD
Updated BPMs
TBD
Market Simulation
TBD
Tariff
TBD
Production Activation
Fall 2013
Page 60
Fall 2013 – Circular Scheduling
Milestone
Date
Application Software Changes
CAS: Identify the circular schedules MW, import/export resource IDs for the
single e-tag, with source/sink at the same BAA; the BAA could be CAISO or
other BAA; Exclude dynamic, DC segment, open intertie, Wheeling through for
load.
CRR Claw Back/MQS: Identify the SC’s affiliation for single SC and circular
schedule MW. Build new rule of calculate value the claw-back CRR in dollars.
Settlement: Identify the SC’s affiliation for single SC. Identify the circular
schedule Import applicable IFM and HASP scheduled MW. Build Settlement
rule the settle the import schedule at lower LMP of Import/export. Circular
schedule is not eligible for BCR for the interval.
BPM Changes
Market Operations, Market Instruments, Settlements & Billing
Business Process Changes
Manage Interchange Scheduling, Manage MQS, Manage Billing and
Settlements
Board Approval
March 22, 2012
External Business Requirements
TBD
Updated BPMs
TBD
Market Simulation
TBD
Tariff
TBD
Production Activation
Fall 2013
Page 61
Fall 2013 – Commitment Cost Refinement
Milestone
Date
Application Software Changes
Masterfile: Creation of new field to capture resource specific characteristics.
Settlements: Operational Flow Orders, NOx, and Sox penalties must be
submitted ex post under circumstances attributable to exceptional dispatch
and real-time commitments. These costs will be included in a re-evaluation
of the real-time BCR calculation for that day with the Operational Flow
Orders (OFO) costs added into the calculation of the generator’s net shortfall
or surplus over that day. Must establish an interface in which Market
Participants can enter data to flow directly to Settlements.
BPM Changes
Market Instruments
Billing & Settlements
Business Process Changes
Manage Reliability Requirements
Board Approval
May 2012
External Business Requirements
TBD
Updated BPMs
TBD
Market Simulation
TBD
Tariff
TBD
Production Activation
Fall 2013 Release
Page 62
Fall 2013 – AS Buy Back
Milestone
Description/Date
Application Software Changes
SLIC: Operators have the ability to manually force a buy back due
to resource or transmission constraints. These manually forced buy
backs will be compiled in a new SLIC log which shall include the
modified AS quantity, interval that the buy back is applied and
reason for manual buy back. .
Settlements: Settlement will need to map to the new SLIC
payload. Impacted 14 Charge Codes related ancillary services.
BPM Changes
Settlements & Billing;
Business Process Changes
Manage Billing and Settlements
Board Approval
July 13, 2012
External Business Requirements
TBD
Technical Specifications
TBD
Market Simulation
Fall 2013
Production Activation
Fall 2013 Release
Page 63
Spring 2014 – Dynamic Transfers
Milestone
Description/Date
Application Software Changes
SIBR: Pass the 5-min-2-hour rolling forward forecast to Real-Time Market,
including bidding capability and relevant validation rules for the TRC.
ALFS : Create the ISO forecast for the intermittent DT
CAS: e-tag DS/PTG that mapped to multi-ITGs
CMRI : Report Transmission Reservation (TRC)
DAM/RTM: Include TRC, incorporate forecast value, model multi-tie services,
model primary/alternative tie under open tie
Master File: Define TRC, multi-tie group
OASIS: Show aggregated TRC
Settlements: Settle TRC as shadow price of Intertie constraint in market,
exclude congestion cost in RTD for the resources that have TRC.
BPM Changes
Market Operations; Market Instruments;
Settlements & Billing; Definitions & Acronyms
Business Process Changes
Maintain Master File, Day Ahead Process, Real Time Process,
Manage Billing and Settlements, Manage Interchange Scheduling
Board Approval
May 19, 2011
External Business Requirements
June 8, 2012
Technical Specifications
TBD
Market Simulation
Spring 2014
Production Activation
Spring 2014 Release
Page 64
Spring 2014 – FERC Order 764 / 15 Minute Market
Milestone
Description/Date
Application Software Changes
TBD
BPM Changes
TBD
Business Process Changes
TBD
External Business Requirements
TBD
Technical Specifications
TBD
Board Approval
May 2013
Market Simulation
TBD
Production Activation
Spring 2014 Release
Page 65
Fall 2014 – Flexible Ramping Product
Milestone
Description/Date
Application Software Changes
ADS: Send Flexible Ramping Up/Down Awards to Market Participants.
CMRI : Report Flex Ramp Up/Down Awards to Market Participants.
DAM/RTM: Co-optimize Energy Ancillary Services and Flexible Ramping
up/down. This optimization is subject to Flexible Ramping requirements and
existing constraints.
OASIS: Show aggregated Flexible Ramping capacity awards, requirements and
marginal prices.
Settlements: Settle Flexible Ramping payment at marginal price in Day Ahead
and Real Time markets Add no pay and cost allocation for Flexible Ramping.
SIBR: Include Flexible Ramping bidding capability and relevant validation rules
of bid cap, self provision.
BPM Changes
Market Operations; Market Instruments; Settlements & Billing; Definitions &
Acronyms.
Business Process Changes
Maintain Day Ahead Process, Real Time Process, Manage Billing and
Settlements
External Business Requirements
TBD
Technical Specifications
TBD
Board Approval
Fall 2013
Market Simulation
TBD
Production Activation
Fall 2014 Release
Page 66
Fall 2014 – iDAM (simultaneous IFM and RUC)
Milestone
Description/Date
Application Software Changes
TBD
BPM Changes
TBD
Business Process Changes
TBD
External Business Requirements
TBD
Technical Specifications
TBD
Board Approval
TBD
Market Simulation
TBD
Production Activation
Fall 2014 Release
Page 67
Technical Updates
Li Zhou, Senior Advisor
George Angelidis, Principal
Power Systems Technology Development
Page 68
Mandatory MSG Transition
• To facilitate a smooth transition from non MSG to MSG,
CAISO proposes,
– When applicable, use a Spring outage maintenance
period and convert in the middle of period.
Page 69
Questions/Answers
• CAISO has presented NGR market simulation results
and FERC order 755 examples in last MPPF meeting
– Questions/Answers
• Questions/Answers for Fall 2012 and Spring 2013
projects
Page 70
Policy Update
Delphine Hou
Market Design and Regulatory Policy
Slide 71
Market initiatives going to the Board for approval
Initiative
Board Presentation
FERC Order 1000 (Inter-regional)
March
Administrative Pricing Rules
May
FERC Order 764 Market Changes
May
Page 72
Market design initiatives coming soon (slide 1 of 2)
• Flexible RA Resource Criteria and Must Offer
Requirements
– Phase I starting tomorrow
– Phase II targeted to start Q2 2013
• Marginal Loss Surplus Allocation
– Targeted to start Q1 2013
• Expanding Metering and Telemetry Options
– Targeted to start Q1 2013
• Multi-Stage Generator Bid Cost Recovery
– Targeted to start Q1 2013
Page 73
Market design initiatives coming soon (slide 2 of 2)
• Generator Interconnection Procedures (GIP 3)
− Targeted to start Q1 2013
• Load Granularity Refinements
− Targeted to start Q2 2013
Page 74
Additional initiatives being considered:
• Priorities from Stakeholder Initiatives Catalog process:
− Address transient price spikes, real-time imbalance
energy offset / real-time congestion offset
− Additional constraints, processes or products to
address exceptional dispatch (30 minute reserve
capacity)
− Multi-year forward reliability capacity pricing
mechanism
− Use-limited must offer requirements and standard
capacity product enhancements
− Extended pricing mechanism
Page 75
Valley Electric Association Modeling Information
Justin Wong
Market Settlement Design Analyst, Market Settlement
Design and Configuration
Valley Electric Association Transition
• VEA system integrated into CAISO BAA
– January 3rd, 2013
• Four new lines of interconnection
– Amargosa – Sandy
– Jackass Flats – Lathrop
– Northwest – Dessert View
– Mead – Pahrump
• Two new scheduling points
– AMARGO
– NWEST
VEA Market Constraints
New Constraints
1) AMARGO_MSL:
•
+/-25 MW limit for AMARGOSA-SANDY.
4) VEA_MSL:
•
Limits schedules to not exceed the
entitlement transmission capacity of the
Mead-Pahrump line.
•
The limit shall be dynamic depending on
VEA’s hourly load forecast.
•
Operating limits:
2) NWEST_MSL:
•
+/-315 MW limit for JACKASS FLATSLATHROP and NORTHWEST-DESERT VIEW
aggregate scheduling point.
3) MEADVEA_BG:
•
+/- 159 MW limit for MEAD-PAHRUMP.
Import: 159 MW + VEA load forecast.
Export: 159 MW – VEA load forecast.
VEA Market Constraints
Modified Constraints
MEAD_MSL
ADLANTOVICTVL-SP_MSL.
Currently the MEAD_MSL consists of four lines with
limits as follows:
•
Camino-Mead 1&2 230 kV +/- 320
•
Eldorado-Mead 1&2 230 kV +/- 1,140
New WALC intertie:
•
New Mead-Pahrump 230 kV +/- 159
Currently the ADLANTOVICTVL-SP_MSL is made up
of the following lines
•
Sylmar-AC 230 kV
+/- 1600
•
Victorville-Lugo 500 kV
+ 2,400/-900
•
Camino-Mead 1&2 230 kV +/- 320
•
Eldorado-Mead 1&2 kV
+/-1,140
New WALC intertie:
•
New Mead-Pahrump 230 kV +/- 159
New MEAD_MSL (sum of 5 lines)
Limit
+/-1619
New ADLANTOVICTVL-SP_MSL
Limit +5,219/-3,719
VEA Diagram Legend
Substation
Voltage level
(TNAME)
Substation
Voltage level
CAISO Boundary
MSL – Market
Scheduling Limit
Connection of
Substations
BG – Branch Group
VEA Market Model Diagram
NV Energy Balancing Authority
WALC Balancing Authority
AMARGO_MSL
-25/+25
NWEST_MSL
-315/+315
NWEST
230 kV
(NWEST)
VEA_MSL
Import = 159 + VEA Load Forecast
Export = 159 – VEA Load Forecast
Jackass F
138 kV
(NWEST)
Amargosa
138 kV
(AMARGO)
Mead S
230 kV
(MEAD230)
MEAD_MSL
-1,619/+1,619
ADLANTOVCTVL-SP_MSL
-5,219/+3,719
MEADVEA_BG
-159 / +159
Mead
230 kV
Psuedo Bus
CAISO Balancing Authority
MEADELDORD_BG
-1,140 / +1,140
VEA
Pahrump
230 kV
Camino
230kv
Camino
230kv
New Scheduling Points
Special tagging for scheduling purposes only.
Schedule’s (import/export) at a VEA scheduling point (NWEST or
AMARGO), shall tag their energy schedule through MEAD.
• Import path:
NEVP(NWEST/AMARGO) - SP15 - MEAD(WALC) – SP15
• Export path:
SP15 – MEAD(WALC) – SP15 – NEVP(NWEST/AMARGO)
http://www.caiso.com/Documents/CaliforniaISOTaggingTemplates.xls