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TRANSCRIPT
Market Performance and Planning Forum
January 20, 2015 (revised)
Objective: Enable dialogue on implementation planning and market performance issues
• Review key market performance topics • Share updates to 2015 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
Agenda
Slide 3
10:00- 10:05 Introduction and Agenda Kristina Osborne
10:05 – 11:30 Market Performance and Quality Update
Guillermo Bautista
Nan Liu
11:30 – 12:00 Department of Market Monitoring – Energy Imbalance Market Update
Keith Collins
12:00 – 1:00 Lunch
1:00 – 1:30 Policy Update Brad Cooper
1:30 – 2:30 Release Update Janet Morris
Agenda
Note: Agenda is subject to change.
Market Performance and Quality Update
Guillermo Bautista Alderete, Ph.D. Manager, Market Validation and Quality Analysis Nan Liu Manager, Market Development and Analysis
Slide 4
Energy imbalance market update
• Three-month period of tariff waiver to use last economical signal.
• ISO filed a second waiver to cover the period of November 1 through 13.
• ISO filed a tariff amendment for a 12-month transition period for new EIM entities.
• PacifiCorp (PAC) and ISO continue to improve procedures and software functioning.
• PAC and ISO submitting monthly reports to FERC on EIM performance.
Page 5
EIM transfer in fifteen-minute market between PAC and California
Page 6
EIM transfer in FMM for PAC East
Page 7
EIM transfer in FMM between PAC and ISO
Page 8
EIM transfer in FMM for PAC East
Page 9
Balancing test failures observing a downward trend
Page 10
0%
5%
10%
15%
20%
25%
30%
35%
40%
45%1-
Nov
4-N
ov
7-N
ov
10-N
ov
13-N
ov
16-N
ov
19-N
ov
22-N
ov
25-N
ov
28-N
ov
1-D
ec
4-D
ec
7-D
ec
10-D
ec
13-D
ec
16-D
ec
19-D
ec
22-D
ec
25-D
ec
28-D
ec
Dai
ly F
requ
ency
PAC East PAC West Trend for PAC East Trend for PAC West
Flexible ramp sufficiency test failures have reduced
Page 11
0%
10%
20%
30%
40%
50%
60%2-
Nov
5-N
ov
8-N
ov
11-N
ov
14-N
ov
17-N
ov
20-N
ov
23-N
ov
26-N
ov
29-N
ov
2-D
ec
5-D
ec
8-D
ec
11-D
ec
14-D
ec
17-D
ec
20-D
ec
23-D
ec
26-D
ec
29-D
ec
Dai
ly F
requ
ency
PAC East PAC West
Flexible ramp requirement infeasibility has decreased
Page 12
0%
5%
10%
15%
20%
25%
30%
35%
40%1-
Nov
4-N
ov
7-N
ov
10-N
ov
13-N
ov
17-N
ov
21-N
ov
25-N
ov
28-N
ov
1-D
ec
4-D
ec
7-D
ec
12-D
ec
15-D
ec
25-D
ec
28-D
ec
Freq
uenc
y
PAC East PAC West
Price frequency in PAC West (ELAP in FMM)
Page 13
Price frequency in PAC East (ELAP in FMM)
Page 14
Prices are stable on average at $25 with tariff waiver
Page 15
$0
$50
$100
$150
$200
$250
1-N
ov
4-N
ov
7-N
ov
10-N
ov
13-N
ov
16-N
ov
19-N
ov
22-N
ov
25-N
ov
28-N
ov
1-D
ec
4-D
ec
7-D
ec
10-D
ec
13-D
ec
16-D
ec
19-D
ec
22-D
ec
25-D
ec
28-D
ec
31-D
ec
Dai
ly A
vera
ge P
rice
($/M
Wh)
Prices with adjustment per waiver Counterfactual prices Current Prices
$0
$50
$100
$150
$200
$250
1-N
ov
4-N
ov
7-N
ov
10-N
ov
13-N
ov
16-N
ov
19-N
ov
22-N
ov
25-N
ov
28-N
ov
1-D
ec
4-D
ec
7-D
ec
10-D
ec
13-D
ec
16-D
ec
19-D
ec
22-D
ec
25-D
ec
28-D
ec
31-D
ec
Dai
ly A
vera
ge P
rice
($/M
Wh)
Prices with adjustment per waiver Counterfactual prices Current Prices
PAC West less volatile
PAC East
Prices are stable on average at $25 with tariff waiver
Page 16
RTD Market PAC West
RTD Market PAC East
$0
$50
$100
$150
$200
$250
$300
1-No
v
4-No
v
7-No
v
10-N
ov
13-N
ov
16-N
ov
19-N
ov
22-N
ov
25-N
ov
28-N
ov
1-De
c
4-De
c
7-De
c
10-D
ec
13-D
ec
16-D
ec
19-D
ec
22-D
ec
25-D
ec
28-D
ec
31-D
ec
Daily
Ave
rage
Pric
e ($
/MW
h)
Prices with adjustment per waiver Counterfactual prices Current Prices
$0
$50
$100
$150
$200
$250
$300
1-N
ov
4-N
ov
7-N
ov
10-N
ov
13-N
ov
16-N
ov
19-N
ov
22-N
ov
25-N
ov
28-N
ov
1-D
ec
4-D
ec
7-D
ec
10-D
ec
13-D
ec
16-D
ec
19-D
ec
22-D
ec
25-D
ec
28-D
ec
31-D
ecDai
ly A
vera
ge P
rice
($/M
Wh)
Prices with adjustment per waiver Counterfactual prices Current Prices
Frequency of undersupply infeasibilities
Page 17
0%
5%
10%
15%
20%
1-N
ov
4-N
ov
7-N
ov
10-N
ov
13-N
ov
16-N
ov
19-N
ov
22-N
ov
25-N
ov
28-N
ov
1-D
ec
4-D
ec
7-D
ec
10-D
ec
13-D
ec
16-D
ec
19-D
ec
22-D
ec
25-D
ec
28-D
ec
31-D
ec
Freq
uenc
y of
Inte
rval
s
Tariff waiver Last economical signal Penalty-based prices Flex-ramp sufficiency test
0%
2%
4%
6%
8%
10%
12%
14%
16%1-
Nov
4-N
ov
7-N
ov
10-N
ov
13-N
ov
16-N
ov
19-N
ov
22-N
ov
25-N
ov
28-N
ov
1-D
ec
4-D
ec
7-D
ec
10-D
ec
13-D
ec
16-D
ec
19-D
ec
22-D
ec
25-D
ec
28-D
ec
31-D
ec
Freq
uenc
y of
Inte
rval
s
Tariff waiver Last economical signal Penalty-based prices Flex-ramp sufficiency test
FMM Market PAC West
RTD Market PAC West
Drivers of undersupply infeasibilities
Page 18
FMM Market PAC West
FMM Market PAC East
0%
5%
10%
15%
20%
25%
30%
35%
40%
45%2-
Nov
5-N
ov
8-N
ov
11-N
ov
14-N
ov
17-N
ov
20-N
ov
23-N
ov
26-N
ov
29-N
ov
2-D
ec
5-D
ec
8-D
ec
11-D
ec
14-D
ec
17-D
ec
20-D
ec
23-D
ec
26-D
ec
29-D
ec
Freq
uenc
y of
Inte
rval
s
Tariff waiver Last economical signal Penalty-based prices Flex-ramp sufficiency test
0%
5%
10%
15%
20%
25%
30%
1-No
v
4-No
v
7-No
v
10-N
ov
13-N
ov
16-N
ov
19-N
ov
22-N
ov
25-N
ov
28-N
ov
1-De
c
4-De
c
7-De
c
10-D
ec
13-D
ec
16-D
ec
19-D
ec
22-D
ec
25-D
ec
28-D
ec
31-D
ec
Freq
uenc
y of I
nter
vals
Tariff waiver Last economical signal Penalty-based prices Flex-ramp sufficiency test
Drivers of undersupply infeasibilities
Page 19
0%
5%
10%
15%
20%
25%
30%1-
Dec
4-D
ec
7-D
ec
10-D
ec
13-D
ec
16-D
ec
19-D
ec
22-D
ec
25-D
ec
28-D
ec
31-D
ec
Freq
uenc
y
Renewable deviation Load changes Import/Export changesResource Outage Manual Dispatches Resource data alignment
0%
5%
10%
15%
20%
25%
30%
1-D
ec
4-D
ec
7-D
ec
10-D
ec
13-D
ec
16-D
ec
19-D
ec
22-D
ec
25-D
ec
28-D
ec
31-D
ec
Freq
uenc
y
Renewable deviation Load changes Import/Export changesResource Outage Manual Dispatches Resource data alignmentTransfer/Congestion constraints
FMM Market
RTD Market
Daily average of total available EIM resource capacity in FMM (including economic bids and self schedules)
Page 20
Price convergence between FMM and real time dispatch improved in December on average
Slide 21
Real-time prices lower than day-ahead prices in December
Page 22
FMM prices RTD prices
Insufficient upward ramping capacity stayed low in November and December
Page 23
Insufficient downward ramping capacity edged up in December
Page 24
Congestion revenue rights market - Revenue inadequacy continued to improve in November and December
Page 25 CRR revenue adequacy does not include monthly and annual auction avenues.
Exceptional dispatch volume dropped in December
Page 26
Lower than 0.5%
Daily exceptional dispatches by reason
Page 27
Bid cost recovery (BCR) rose slightly in December
Page 28
BCR by local capacity requirement area
Page 29
BCR by utility distribution company
Page 30
IFM under-scheduling of wind generation continued in November and December.
Page 31
Slide 32
Solar scheduled outputs continued to fall in November and December
Integrated forward market (IFM) renewable schedules and forecast in October - December
Page 33
Intertie economic bids in hour ahead scheduling process (HASP)
Page 34
BPA implemented 15 minute scheduling on Oct 21.
Minimum online commitment (MOC)
Page 35
Binding MOC in November and December
MOC Name Number (frequency) of enforced hours in
November and December
Humboldt60 7110 971
SCIT MOC 380
MOC PEASE 2521847 245
SDGE 7820 94
MOC COLEMAN-COTTONWOOD 2435414 61
MOC CENTER 2549952 27
Orange County 7630 16
MOC KRAMER 2544343 14
MOC PALERMO-NICOLAUS 2435410 8
Page 36
Price correction events increased October - December
Page 37
0
2
4
6
8
10
12
Jan Feb Mar April May June July Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
2013 2014
Coun
t of E
vent
s
Process Events Software Events Data Error Events Tariff Inconsistency
0.00%
0.50%
1.00%
1.50%
2.00%
2.50%
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
2014 day-ahead load forecast
MA
PE
0%
2%
4%
6%
8%
10%
12%
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
2014 day-ahead wind forecast M
AE
0%
2%
4%
6%
8%
10%
12%
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
2014 day-ahead solar forecast M
AE
Department of Market Monitoring – Energy Imbalance Market Update Keith Collins Manager, Monitoring and Reporting
Slide 41
Frequent constraint relaxation continues PacifiCorp East – 15 minute market
Special price discovery feature keeping prices in line with bilateral market prices
PacifiCorp East – 15-minute market
Constraint relaxation is much lower and trending downward
PacifiCorp West (15-minute market)
Impact of price discovery feature PacifiCorp West (15-minute market)
Impact of price mitigation feature PacifiCorp East (5-minute market)
Impact of price mitigation measures PacifiCorp West (5-minute market)
Participating capacity in PACE has increased, but curtailments have sometimes been significant. PacifiCorp East (Gas and coal)
Participating capacity in PACW has increased due to the addition of large coal resources. PacifiCorp West (Gas and coal)
About all participating capacity is being offered PacifiCorp East – December 2014 (Gas and coal only)
About all participating capacity is being offered PacifiCorp West – December 2014 (Gas and coal only)
Offer prices have been very competitive
Policy Update
Brad Cooper Manager, Market Design & Regulatory Policy
Slide 53
Ongoing policy stakeholder initiatives
• Reliability services – Draft final proposal on Jan 22 – March board meeting
• Capacity procurement mechanism replacement – Draft tariff posted on Jan 9 – February board meeting
• Contingency modeling enhancements – Resuming analysis – Revised straw proposal early March – Fall 2015 implementation
Ongoing policy stakeholder initiatives (continued)
• Flexible ramping product – Upcoming call to discuss requirement, market
formulation, and next steps – Revised draft final proposal – May board meeting
• Load granularity refinements – Preliminary pricing results presented at MSC meeting
in December – Pricing study results and implementation costs and
benefits paper posted on January 14 – Stakeholder call on January 21
– May board meeting
Ongoing policy stakeholder initiatives (continued)
• EIM enhancements – Comments due on Jan 22 – Technical workshop on Jan 30 – Draft final proposal posted on Feb 11 – March board meeting
• Commitment cost enhancements – Phase 2 – Technical workshop end of Jan on opportunity cost – Draft final proposal on Feb 3 – March board meeting
Page 56
Ongoing policy stakeholder initiatives (continued)
• Bidding rules – Consider design changes that can be implemented
before winter 2015-2016
• Stakeholder initiative catalog process – Draft final proposal posted Jan 23 – Present roadmap at February board meeting
Page 57
Policy stakeholder initiatives coming soon
• Upcoming February board presentation
Stakeholder initiatives going to the Board for approval
Initiative Board Presentation CPM replacement Feb
Reliability services March
Commitment cost enhancements – Phase 2
March
Flexible ramping product May
Load granularity refinements May
Page 59
Release Plan Updates
Janet Morris Director, Program Management Office
Page 60
Early 2015 deployments
• Recently implemented • Commitment Costs Enhancements • OASIS version 6.6.1 release – new reports
• February 3, 2015
• Outage Management System Replacement (OMS) – Tariff section 9 changes effective
• Many to Many: SCP Availability Calculations
• Independent efforts • Enabling Demand Response • Pay for Performance Year 1 design changes
Page 61
Release plan – 2015 • Spring 2015 – Maintenance Release
• No major functional changes • Enhancements or other changes required for summer operations • Minor design changes resulting from the Fall 2014 release • Other system maintenance as needed • Many to Many Substitution/App Consolidation • Convergence Bidding at the Interties • Transaction IDs
• Fall 2015 (tentative) • Energy Imbalance Market (EIM) 2015 / EIM Year 1 Enhancements • Contingency Modeling Enhancements • RIMS functional enhancements • OMAR replacement project • ADS User Interface Replacement and Web Service Standardization • Capacity Procurement Mechanism Replacement • Reliability Services Initiative - tentative based on policy phase • Commitment Cost Enhancements Phase 2 – tentative based on policy phase • Flexible Ramping Product – tentative based on policy phase • Bidding Rules – tentative based on policy phase
• Subject to further release planning: • Expanding Metering and Telemetry Options Phase 2 • BAL-003 Compliance (Frequency Response) – moved to Fall 2016 • Load Granularity Refinements • Pricing enhancements • Subset of Hours (to follow Reliability Service Initiative) • Acceptable Use Policy - Analyzing to identify next services to enforce • IE 11 migration
Page 62
The ISO offers comprehensive training programs
Date Training February 10 Introduction to ISO Markets (in person) February 11, 12 ISO Market Transactions (in person) March 17 Settlements 101 (in person) March 18 Settlements 201 (in person)
Page 63
Training calendar - http://www.caiso.com/participate/Pages/Training/default.aspx Contact us - [email protected]
2015 release schedule
http://www.caiso.com/Documents/ReleaseSchedule.pdf Page 64
Market simulation plans
ISO is hosting twice weekly Market Simulation calls, presentations can be found here - http://www.caiso.com/Pages/documentsbygroup.aspx?GroupID=D0DE8446-C30C-46CE-80B9-6413B6381B64
Commitment costs enhancements Milestone Details/Date Status
Application Software Changes
SIBR: Modification to SIBR rules to accommodate the change of increasing the Proxy Price cap from 100% to 125%. Master File: Modification to restrict Non Use-Limited resources to be on Proxy Cost only, as they shall no longer be allowed to be on Registered Cost. Use-limited resources may use either Registered or Proxy Cost option.
BPM Changes Market Instruments: Updates to section C-3 to help manage gas price spikes (in the event that the more current GPI is greater than 125% of previous day’s GPI in anyone of the ISO’s six gas regions). A process needs to be in place to allow for revising the gas prices used in the commitment cost calculation and bid generation in the Day Ahead market.
Business Process Changes Implement a desktop procedure for the gas price spike
Board Approval Sep 18, 2014 External Business Requirements Oct 15, 2014
Updated BPMs Jan 31, 2014
Technical Specifications N/A
Draft Configuration Guides N/A
Market Simulation N/A
Tariff FERC Order received 12/30/2014; wen into effect 12/31/2014
Production Activation 125% Cap and Manual Process became effective on 12/31/2014; Switching non-use-limited resources from registered to proxy will require 3 business days for the changes, and went into effect on 1/6/2015.
Page 66
January OASIS release
• OASIS Technical documentation - http://www.caiso.com/Pages/documentsbygroup.aspx?GroupID=A177DAEA-91F8-41ED-A85F-B49BE3392393
Page 67
Market GUI Report Name API Single Zip Query API Group Zip Query
Major Version=3 Minor Version=v20150101
Day-Ahead Scheduling Point/Tie Combination Locational Marginal Prices PRC_SPTIE_LMP DAM_SPTIE_LMP_GRP
Fifteen-Minute (RTPD/15-minute)
FMM Scheduling Point/Tie Combination Locational Marginal Prices PRC_SPTIE_LMP RTPD_SPTIE_LMP_GRP
Real-Time Dispatch (RTD/5-minute)
Interval Scheduling Point/Tie Combination Locational Marginal Prices PRC_SPTIE_LMP RTD_SPTIE_LMP_GRP
Real-Time Contingency Dispatch
Contingency Dispatch Scheduling Point/Tie Combination Locational Marginal Prices PRC_CD_SPTIE_LMP n/a
The scheduling point/tie combination LMPs are related to the fall release 2014 Full Network Model expansion initiative.
Outage management system (OMS) Milestone Details/Date Status
Application Software Changes
OMS: New OMS replaces SLLIC and current OMS (transmission) with a single outage management system. Application Programming Interfaces (APIs) will be modified to support new data structures and functionality, and a new user interface will be provided.
BPM Changes
Managing Full Network Model Market Instruments Outage Management Market Operations
Draft Final Proposal Posted December 3, 2013
Conduct Stakeholder Call December 17, 2013 (pushed from December 10)
Stakeholder Comments due December 23, 2013 (pushed from December 17)
Present to Board of Governors February 6, 2014
External Business Requirements - Draft Posted June 28, 2013
External Business Rules Posted February 26, 2014 Reposted Redlined Version December 26, 2015
External Business Requirements - Final http://www.caiso.com/Documents/ExternalBusinessRequirementsSpecification-OutageManagementSystem-Replacement.pdf
Page 68
Milestone Details/Date Status
Technical Specifications
Generation - January 8, 2014
Transmission - January 27, 2014
Other - February 10, 2014 Publish updates - April 9, 2014 Master File (Gen RDT) - May 24, 2014 Publish final updates for Sandbox API testing – May 30, 2014 Publish alternative Doc Attach WSDLs – August 5, 2014 Updates per Market simulation feedback – September 5, 2014
Developer Customer Partnership Group (CPG) Generation: January 21, 2014 Transmission: February 19, 2014
Business CPG Generation : March 11, 2014 Transmission : March 12, 2014 Joint : March 26, 2014
Cutover CPG August 14, 2014 October 9, 2014
Business Process Changes Manage Generation Outages; Manage Transmission Outages
Updated BPMs September 2014 - PRR Process Ongoing
Sandbox Available for B2B service connectivity testing July 7, 2014
Market Simulation API - July 28, 2014; UI - August 5, 2014 Full System – August 5, 2014 – January 30, 2015
Tariff File Tariff: July 7, 2014 Tariff Approval: September 5, 2014 Tariff Effective Date Confirmed for February 3 – February 28, 2015
Production Activation October 1, 2014 for EIM Parallel Production November 1, 2014 for EIM Tariff and EIM entities February 3, 2015
Outage management system (OMS)
Page 69
Many to Many: Standard capacity product (SCP) availability calculations
Milestone Details/Date Status
Application Software Changes
CIRA: • Enhance SCP Availability Calculations Settlements: • Impacts based on resource availability calculation in CIRA. Current system uses point and actual values in RAAM, with
OMS there are only point values because of which the data settlements receive will be different than today.
Board Approval N/A
BPM Changes
September 16, 2014 - Reliability Requirements, PRR 776 July 29, 2014 – Settlements and Billing (related to OMS), PRR 752 (eff. 10/11/14) November 5, 2014 – Reliability Requirements, PRR 802 (eff. 12/08/14) for 1 2 substitution for RAAM
External Business Requirements
Many to Many: January 23, 2014 (original) March 13, 2014 (revised) May 16, 2014 (revised) June 19, 2014 (revised, shows phased approach)
Application Consolidation: March 12, 2014 (original) June 19, 2014 (revised, shows phased approach)
Market Simulation
October 20 – October 31, 2014 Structured: Scenarios posted w/timeline Unstructured:
December 3 – December 4, 2014 (Updated) • Structured: Rerun of Scenarios due to CIDI tickets, posted statements 12/9
File Tariff N/A -
Training August 19, 2014 – SCs for Resources, Settlements (posted RAAM User Guide on 8/5)
Production Activation February 3, 2014 Page 70
Enabling demand response Milestone Details/Date Status
Application Software Changes A new application for DRPs to manage locations via user interface and application programming interface (API). Application will verify UDC account number uniqueness.
BPM Changes Under review.
Business Process Changes Under review.
Board Approval N/A
External Business Requirements Sep 12th, 2014
Updated BPMs Yes, publication date being assessed.
Technical Specifications
Sep 19th, 2014– Use cases Sep 19th 2014– Web Service Data Requirements Oct 15th 2014 –Technical specifications with XSDs Nov 14th 2014 – Full Technical Specifications (including wsdl’s)
Draft Configuration Guides N/A
Market Simulation February 10-20 (Registration) February 23-27 (RDRR Structured Scenario Reruns)
Tariff N/A
Production Activation February 24, 2015
Page 71
Pay for performance year 1 design changes Milestone Details/Date Status
Application Software Changes
MQS: • The monthly performance accuracy calculation will be changed from the simple
average to the weighted average with 15-minute interval instructed regulation mileage as the weighting factor
• The minimum performance threshold will be reduced from the current 50% to 25%.
BPM Changes Yes: Market Instruments
Business Process Changes No
Board Approval 11/13/14
External Business Requirements Yes
Updated BPMs TBD
Technical Specifications N/A
Draft Configuration Guides N/A
Market Simulation N/A
Tariff Posted December 2, 2014 http://www.caiso.com/Documents/Dec2_2014_TariffAmendment_PFP_YearOneChanges_ER15-554-000.pdf Anticipate FERC order in early February 2015
Production Effective Date (pending FERC approval)
Effective date is January 1, 2015 Production changes to be deployed by January 23, 2015
Page 72
Spring 2015 – Many to many substitution/app consolidation Milestone Details/Date Status
Application Software Changes
CIRA: • Add new functionality to process many to many substitution requests • Enhance SCP Availability Calculations (in Fall 2014 Release) • Provide single platform for management of resource adequacy and replacements /substitutions for
associated outages Settlements: • Impacts based on resource availability calculation in CIRA. Current system uses point and actual
values in RAAM, with OMS there are only point values because of which the data settlements receive will be different than today.
Board Approval N/A
BPM Changes N/A (to be confirmed based on feedback provided)
External Business Requirements
Many to Many: January 23, 2014 (original) March 13, 2014 (revised) May 16, 2014 (revised) June 19, 2014 (revised, shows phased approach)
Application Consolidation: March 12, 2014 (original) June 19, 2014 (revised, shows phased approach)
Technical Specifications N/A
Draft Configuration Guides N/A
Market Simulation Yes - TBD
File Tariff January 2015 (tentative)
Production Activation April 1, 2015
Page 73
Spring 2015 – Convergence bidding on the interties Milestone Details/Date Status
Application Software Changes
This is an existing market functionality that is currently disabled. Will be reinstated in DAM in 2015 Spring release. Impacted systems: SIBR, IFM, Settlements, OASIS, and CTS. SIBR: • Allow SC to submit virtual bids on the intertie with an intertie ID • The position limit validation rule will be extended to support both scheduling constraints:
scheduling limit constraint for each intertie and ITC constraint for a set of scheduling points
IFM: • Model virtual bid on the intertie in the same manner as physical import/export bids RUC: • Exclude virtual import/export • Reschedule IFM physical import/export schedules economically based on IFM bids Settlements: • Virtual Import awards on the intertie shall be paid the day-ahead LMP and charged the
simple average of four 15-minute market LMP of the trading hour. • Virtual Export awards on the intertie shall be charged the day-ahead LMP and be paid
the simple average of four 15-minute market LMP of the trading hour. where LMP above is the virtual resource’s Scheduling Point – Intertie combination LMP. OASIS: • Add new field intertie ID in the Convergence Bidding Public Bids report CMRI: • No XSD change. • DAM Virtual Resource Award report will populate the field of intertie ID CTS: • Support Convergence Bidding on the intertie
BPM Changes Market Operations, Market Instruments, Settlements and Billing
Business Process Changes N/A
Page 74
Spring 2015 – Convergence Bidding on the Interties– cont’d Milestone Details/Date Status
Board Approval February 5, 2014
External Business Requirements
January 23, 2015 - tentative
Updated BPMs Market Instruments
Technical Specifications OASIS Convergence Bidding Public Data Report will be modified to add a new field of intertie ID OASIS Reference Price report will be modified to show the Scheduling Point – Intertie combination reference price
Draft Configuration Guides N/A
Market Simulation TBD
Tariff FERC Order – March 20, 2014
Production Activation May 1, 2015
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Spring 2015 – Transaction IDs Milestone Details/Date Status
Application Software Changes
This is an existing market functionality Master File: Retire Import/export resource ID, except some specific resources related RA, AS, contract SIBR: Submit and create transaction ID for the SC Bids on Scheduling Points dynamically; SIBR will not accept bids from retired Resource ID DAM/RTM/ITS/CMRI/ADS/OASIS/Settlement: Receive and process the dynamically formed transaction ID.
BPM Changes No changes expected Market Operations, Market Instruments, Managing FNM
Board Approval February 6, 2014
External Business Requirements
7/29/2014 http://www.caiso.com/Documents/BusinessRequirementsSpecification-FullNetworkModelExpansion.pdf
Updated BPMs N/A
Technical Specifications N/A
Market Simulation N/A
Tariff FERC Approval on July 31, 2014
Production Activation April 1, 2015
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Spring 2015 – Transaction IDs: Market notice dated 7/2/14
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• The ISO postponed the mandatory cutoff date from October 1, 2014 to April 1, 2015 for existing intertie resource IDs to use the transaction IDs to bid or schedule interties.
• The intent of this postponement is to give market participants more time to make necessary system and business process changes prior to requiring the use of the transaction IDs.
• After the mandatory cut-off date, all intertie resource IDs except the ones indicated below will be end dated and thus cannot be used for inter-tie bidding and scheduling purposes.
• This postponement is only applicable to existing defined ITIE/ETIE resource IDs that have been defined in the Master File. The ISO will not "end date" those resource IDs until April 4, 2015. However, the ISO will not accept any new ITIE/ETIE resource ID registration for an effective date after October 1, 2014 unless the resources are not required to convert to transaction IDs. For example, the resources associated with ancillary services import, existing transmission contracts and transmission ownership rights (ETC/TOR) contract, or resource adequacy capacity.
Fall 2015 – NV Energy EIM 2015 Milestone Details/Date Status
Application Software Changes Implementation of NV Energy as an EIM Entity DAM/RTM- model the multiple dynamic schedules on jointly-owned resource Establishment of EIM transfer Limits Using ATC
BPM Changes No changes expected
Business Process Changes No changes expected
Board Approval N/A
External Business Requirements 3/27/15 (Coordinate with EIM Year 1 Enhancement)
Updated BPMs No changes expected
Technical Specifications No changes expected
Draft Configuration Guides No changes expected
Market Simulation
ISO to promote market network model including NVE area to non-production system and allow NVE to connect and exchange data in advance of Market Simulation by 5/15/15. Market Simulation planned 8/3/15 through 9/15/15.
Tariff No changes expected
Production Activation Modeling NVE into the CAISO FNM through the EMS on 4/23/15. Production activation on 10/1/15 (parallel production is being considered).
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Fall 2015 – EIM year 1 enhancements Milestone Details/Date Status
Application Software Changes
• Settlement of Non-Participating Resources IIE and UIE (Settlement) • Administrative pricing rules (MF, MQS) • GHG flag and cost based bid adder (MF, SIBR, RTM) • Resource sufficiency evaluation applied to ISO BAA (MF, BSAP, RTM) • Establishment of EIM transfer Limits Using ATC (MF, RTM) • Modification EIM Transfer Limit Constraints (MF, RTM)
• 15 minute Bidding on external EIM interties (MF,RTM) • Additional Transition Period Measures (MF, MQS) • EIM Administrative Charge Redesign (Settlement)
BPM Changes Market Operations, Settlements and Billing
Business Process Changes Yes
Board Approval Seeking BOG decision on March 26-27, 2015
External Business Requirements March 30, 2015
Technical Specifications TBD
Draft Configuration Guides TBD
Market Simulation Yes
Tariff Yes
Production Activation Fall 2015
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Fall 2015 - Contingency modeling enhancements Milestone Details/Date Status
Application Software Changes
IFM/RTN: Adds a preventive-corrective constraint to the market co-optimization OASIS/CMRI: Publish preventive-corrective capacity awards with associated LMPC Settlements: Payment and charges for corrective capacity awards, allocation of cost of the corrective capacity constraint, no-pay provisions, bid cost recovery
BPM Changes Manage Full Network Model, Market Operations, Market Instruments, Settlement and Billing, Definitions and Acronyms
Study Results In Person Call: March 20, 2014 Resuming analysis as of January 2015 Revised straw proposal to be posted in early March 2015
Board Approval Spring 2015
External Business Requirements TBD
Technical Specifications TBD
Draft Configuration Guides TBD
Market Simulation TBD
File Tariff TBD
Production Activation October 1, 2015 (Fall 2015 Release)
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Fall 2015 – RIMS function enhancements
Milestone Details/Date Status
Application Software Changes Functional enhancements resulting from the Customer Partnership Group CPG). More details to be provided in the future.
BPM Changes TBD
Business Process Changes TBD
Board Approval N/A
External Business Requirements TBD
Updated BPMs TBD
Technical Specifications TBD
Draft Configuration Guides N/A
Market Simulation TBD
Tariff N/A
Production Activation Fall 2015
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Fall 2015 – OMAR replacement project Milestone Details/Date Status
Application Software Changes
Current metering space at the ISO consists of three major software systems – 1. A product that processes Revenue Quality Meter Data (RQMD) in to Settlement
Quality Meter Data (SQMD) 2. A data repository of all SQMD used in Settlements 3. An external facing web application to enable market participant access to
SQMD. The scope of the project is to replace/consolidate all the three above systems with the ISO Settlements solution. A new user interface and B2B services are in scope. B2B services will be modified to align with CIM standard and to convert to GMT, and the existing FTP solution will be replaced. The new solution will also remove the custom OMAR certificates by leveraging the CAISO Multiple Application (CMA) certificates.
BPM Changes Metering and Definitions & Acronyms (references to systems may need to change)
Business Process Changes Potential Level-II business process changes under – • Manage Market & Reliability Data & Modeling • Manage Operations Support & Settlements
Board Approval Potentially needed – Dates TBD
External Business Requirements N/A
Technical Specifications TBD
Draft Configuration Guides N/A
Market Simulation TBD
Tariff N/A
Production Activation Fall 2015 Page 82
Fall 2015 – ADS user interface replacement and web service standardization
Milestone Details/Date Status
Application Software Changes • Port client from Delphi to new common user interface (ADS Query Tool and
Real Time Functionality) • Conform APIs to current ISO standards – will be deferred beyond Fall 2015
BPM Changes N/A
Business Process Changes N/A
Board Approval N/A
External Business Requirements N/A
Updated BPMs N/A
Technical Specifications TBD
Draft Configuration Guides N/A
Market Simulation TBD
Tariff N/A
Production Activation Fall 2015
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Fall 2015 – Capacity procurement mechanism replacement Milestone Details/Date Status
Application Software Changes
- SCs will need the mechanism to submit bids via template (ISO will name application as requirements are developed) - Business and validation rules need to be developed for bid submission - Settlements will need new CPM formulas that will result in configuration changes
BPM Changes Reliability Requirements; Market Operations; Market Instruments; Billing & Settlements
Business Process Changes
- Solicitation for soft offer cap (will be meeting with Heather's team to nail down what level 2 process this belongs to). Timeline for submittal needs to be defined. - Submittal process for annual/monthly CPM bid submittal - New business process for amount of capacity being relied on (non-RA from partial RA) - New process for Competitive Solicitation Process (annual/month annual and risk)
Board Approval February 2015
External Business Requirements TBD
Updated BPMs TBD
Technical Specifications TBD
Draft Configuration Guides TBD
Market Simulation Yes
Tariff Yes
Production Activation TBD
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Fall 2015 – Reliability services initiative Milestone Details/Date Status
Application Software Changes
The following systems could be impacted based on the below scope: CIRA, Settlements, SIBR, Exceptional Dispatch Tool (internal ISO Operations tool), and Master File. • Updates to the eligibility criteria for demand response to qualify as a Resource Adequacy (RA) resources • Language on the eligibility criteria and must-offer requirement for storage to qualify as a RA resource • Replacement and substitution rules for flexible RA resources • New price and rules for the SCP for all RA resources including flexible resources • New CPM price
BPM Changes Reliability Requirements; Market Operations; Market Instruments; Billing & Settlements
Business Process Changes TBD
Board Approval March 2015
External Business Requirements TBD
Updated BPMs TBD
Technical Specifications TBD
Draft Configuration Guides TBD
Market Simulation Yes
Tariff Yes
Production Activation TBD
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Fall 2015 – Flexible ramping product Milestone Details/Date Status
Application Software Changes
ADS: Send Flexible Ramping Up/Down Awards to Market Participants in DAM for CAISO and FMM for CAISO and EIM. CMRI : Report Flex Ramp Up/Down Awards to Market Participants. DAM/RTM: Co-optimize Energy Ancillary Services and Flexible Ramping up/down. 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
Board Approval
February 2015 Restart Stakeholder Process in May, 2014 http://www.caiso.com/informed/Pages/StakeholderProcesses/FlexibleRampingProduct.aspx
External Business Requirements TBD
Technical Specifications TBD; 4/14/2014: Change the FRC penalty price from $247 to $60 in FMM
Draft Configuration Guides TBD
Market Simulation TBD
Tariff
Yes; The language proposes to change the flexible ramping constraint penalty price from $247 to $60. The draft tariff language is available on the ISO website at http://www.caiso.com/Documents/DraftTariffLanguage_FlexibleRampingProduct.doc
Production Activation Fall 2015
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TBD – Expanding Metering and Telemetry Options Phase 2 Milestone Details/Date Status
Application Software Changes
No ISO Application Software Changes. POC’s to test that current systems support the proposals. Proposal 1 - Use of Internet for Telemetry and ISOME Meter Data bridging to the CAISO Energy Communication Network (ECN); Proposal 2 - Use of Internet for Telemetry (with SSL) and Meter Data (w/o SSL) transport directly to the CAISO; Proposal 3 - Expand the use of Inter-Control Center Communications Protocol (ICCP) as an allowable option for RIG Aggregators (telemetry only); Proposal 4 - Expand the ability for resources to submit Settlement Quality Meter Data; Proposal 5 - Remove RIG Aggregator resource ownership and location limitations.
BPM Changes Metering, Direct Telemetry
Post comments and updated draft proposal February 20, 2015
Final draft proposal Stakeholder conference call Week of March 16, 2015
Board Approval May 14 – 15, 2015
External Business Requirements TBD
Updated BPMs TBD
Technical Specifications TBD
Draft Configuration Guides N/A
Tariff filing September 1, 2015
Production Activation TBD
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TBD – Load granularity refinements Milestone Details/Date Status
Application Software Changes
Alternatives: • Existing DLAPs; • Full Nodal; • Slight Disaggregation- Assuming 6 LAPs; • 23 Existing SLAPs; • Custom LSE-Specific LAPs
BPM Changes TBD
Business Process Changes TBD
Board Approval Paper posted on January 14, 2015; stakeholder call on January 21. May 2015
External Business Requirements TBD
Updated BPMs TBD
Technical Specifications TBD
Draft Configuration Guides TBD
Market Simulation TBD
Tariff TBD
Production Activation TBD
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Fall 2016 – BAL-003 compliance
Milestone Details/Date Status
Application Software Changes
On January 16, 2014, FERC approved BAL-003-1 “Frequency Response and Frequency Bias Setting,” with different implementation dates for different requirements. R1 goes into effect the first calendar day of the first calendar quarter 24 months after regulatory approval. http://www.gpo.gov/fdsys/pkg/FR-2014-01-23/pdf/2014-01218.pdf 4/1/16: RI effective date 12/1/16: 2017 BA FRO in place (start data collection) 4/1/18: Compliance effective date (supply data to NERC) (UPDATED)
BPM Changes TBD
Business Process Changes TBD
Board Approval TBD
External Business Requirements TBD
Technical Specifications TBD
Draft Configuration Guides TBD
Market Simulation TBD
Tariff TBD
Production Activation Fall 2016 (UPDATED)
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2015 Schedule – Market Performance and Planning Forum
• March 18 • May 20 • July 21 • September 23 • November 18
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