Release User Group Agenda - California ISO User Group Agenda March 3rd, 2015 10:00 a.m.–11:00 a.m....
Transcript of Release User Group Agenda - California ISO User Group Agenda March 3rd, 2015 10:00 a.m.–11:00 a.m....
Release User Group Agenda March 3rd , 2015 10:00 a.m.–11:00 a.m. (Pacific Time)
Web Conference Information Conference Call Information
URL: https://www.connectmeeting.att.com
Meeting Number: 8665282256
Access Code: 5251941
Domestic Call In: (866) 528-2256
International Call In: (216) 706-7052
Access Code: 5251941
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Release User Group Agenda March 3rd , 2015 10:00 a.m. – 11:00 a.m. (Pacific Time)
Time Topic Facilitator
10:00 – 10:05 Agenda & ISO Roll call Janet Morris
10:05 – 11:00 Release Plan Adrian Chiosea
Jeremy Malekos
John Huetter
Prince Phillip
Roxann Hall
Kelly Alga
John Williams
Christopher McIntosh
Eureka Cullado
Indu Nambiar
LuAnn Rivera
Yinka Ajede
Elli Johnston
Raja Iyengar
Early 2015 deployments
• Independent efforts
• Enabling Demand Response
• February 26, 2015
• Outage Management System Replacement (OMS)
– Tariff section 9 changes effective
• Many to Many: SCP Availability Calculations
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Release plan – 2015 - 2016 Settlement Q1 2015 Quarterly Release
May 1, 2015
• Convergence Bidding at the Interties (5/1/15)
• Transaction IDs (5/1/15)
Fall 2015
• Energy Imbalance Market (EIM) 2015 / EIM Year 1 Enhancements
• Pricing Enhancements
• Flexible Ramping Product
• Bidding Rules – tentative based on policy phase
Early 2016
• Capacity Procurement Mechanism Replacement
• Reliability Services Initiative - tentative based on policy phase
Fall 2016
• BAL-003 Compliance
• OMAR Replacement
• RIMS Functional Enhancements
Subject to further release planning:
• Contingency Modeling Enhancements
• Expanding Metering and Telemetry Options Phase 2
• Load Granularity Refinements
• Acceptable Use Policy - Analyzing to identify next services to enforce
• IE 11 migration
• ADS User Interface Replacement
• Commitment Cost Enhancements Phase 2
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The ISO offers comprehensive training programs
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Training calendar - http://www.caiso.com/participate/Pages/Training/default.aspx
Contact us - [email protected]
Date Training
March 17 Settlements 101 (in person)
March 18 Settlements 201 (in person)
April 16 Welcome to the ISO (webinar)
May 12 Introduction of ISO Markets (in person - Alhambra)
May 13 – 14 ISO Market Transactions (in person - Alhambra)
2015 Release Schedule
http://www.caiso.com/Documents/ReleaseSchedule.pdf
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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
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 Metering BPM
Business Process Changes No
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)
Jan 7th, 2015 – Technical Specifications & Use Case updates
Jan 27th, 2015 – Technical Specifications Updates
CoB Feb 3, 2015 – User Guide
Feb 12, 2015 – Use Case clarifications
Draft Configuration Guides N/A
Market Simulation Feb 11, 2015 – Mar 6, 2015
RDRR Scenario reruns Mar 2 - Mar 20
Tariff N/A
Production Activation 3/10/2015
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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/ExternalBusinessRequire
mentsSpecification-OutageManagementSystem-
Replacement.pdf
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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
Market Simulation API - July 28, 2014; UI - August 5, 2014
Full System – August 5, 2014 – February 26, 2015
Tariff
File Tariff: July 7, 2014
Tariff Approval: September 5, 2014
Tariff Effective Date Confirmed for February 28, 2015
Production Activation
October 1, 2014 for EIM Parallel Production
November 1, 2014 for EIM Tariff and EIM entities
February 26, 2015
Outage Management System (OMS)
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Many to Many: 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
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 26, 2015
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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:
• XSD modification.
• 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, Credit Management and Market Clearing
Business Process Changes N/A
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Convergence Bidding on the Interties– cont’d
Milestone Details/Date Status
Board Approval February 5, 2014
External Business
Requirements
February 2, 2015
Updated BPMs Market Instruments, Market Operations
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
Feb 18, 2015 – Tech Spec, including XSDs/wsdls for SIBR, CMRI
Draft Configuration Guides N/A
Market Simulation March 31 – April 17, 2015
Tariff FERC Order – March 20, 2014
Production Activation May 1, 2015
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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 May 1, 2015
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Transaction IDs
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Transaction ID Transition Milestones
• February 6th, 2015 – ISO to send list of exempt resources to each SC via client representative
• February, 20th, 2015 – SC’s to identify any additional resources that need exemption and a
justification to their client representatives
• March 31st, 2015 – ISO will setup MAP Stage to match to be, registered resource ID’s in
Production
• May 1s, 2015 – non registered intertie resources must use Transaction ID
List of resources types exempt from Transaction ID –
– Intertie RA
– ETC/TOR Contracts
– Provide AS
– Pseudo-Tie or dynamic scheduling agreements with the ISO or an EIM Entity SC,
– IBAA agreements for transmission loss adjustment Trans bay cable res ID
– Emergency Assistance
– Resource Recirculating Res ID
– Losses
– MSS Load Following
– Inadvertent Payback
ISO will use this process prior to Spring Maintenance release’s going forward, ISO
will give SC’s a minimum of 60 days notice prior to mandatory transition.
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 7/23/15.
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 March 26-27, 2015
External Business Requirements March 30, 2015
Technical Specifications SIBR Greenhouse Gas Charge biddable component options and,
impacted CMRI report changes.
Apr 1, 2015 – Tech Spec, including xsds/wsdls for SIBR, CMRI
Draft Configuration Guides June 30, 2015
Market Simulation Aug 3, 2015 – Sep 15, 2015
Tariff Yes
Production Activation Fall 2015
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Fall 2015 – Pricing Enhancements
Milestone Details/Date Status
Application Software Changes
IFM/RTM:
Compounding Pricing Methodology in the Event of Multiple Contingencies:
Compounding effect on pricing for a constraint concurrently binding for multiple
contingencies when constraints need to be relaxed. Currently, when such cases
arise, LMPs reflect a compounded congestion cost component that is proportional
to the number of contingencies that the constraint is binding for. The ISO aims to
change the model of how you price the slack variable. Prior, it was associated
only with contingency constraints. The slack variable will be associated with the
nomogram flowgates.
Multiplicity of Prices Under “Degenerate” Conditions:
The ISO aims to address multiplicity of prices that may arise in the market under
certain scenarios. Historically, multiplicity of prices are observed on intertie
constraints. The optimization shall change so that a unique pricing outcome is
achieved. This functionality is already developed, however, testing is needed.
Tariff approval is still needed on this piece.
SIBR/Settlements:
Scheduling Priority for Existing Transmission Rights Schedules:
SIRB rules needed to deny or reject bids on ETC/TOR that have self-schedule
entitlement are not activated. These rules have already been developed but could
require Market Simulation.
• Contract self-schedules for netting purposes must be provided to Settlements.
Settlements must map these data points as part of their normal business
process. (optional scope)
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Fall 2015 – Pricing Enhancements (cont.)
Milestone Details/Date Status
BPM Changes Market Instruments; Market Operations
Business Process Changes
Manage Markets & Grid: Administrative Pricing Rule:
For when DA market is not available, our real time market system must use the
prior day-ahead solution for bids/prices/awards. Potential level 3 process
diagrams to document how prices are corrected.
Board Approval December 2014
External Business Requirements March 13, 2015
Technical Specifications TBD
Draft Configuration Guides TBD
Market Simulation Yes - Scheduling Priority for Existing Transmission Rights Schedules.
None of the other policy items require Market Simulation.
Tariff Yes
Production Activation Fall 2015
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Fall 2015 – Flexible Ramping Product (Phase 1)
Milestone Details/Date Status
Application Software Changes
DAM/RTM: Perform the flex ramp down sufficiency test. Enforce the flex ramp down requirements
constraint in RTM.
CMRI : Report RTM Flex Ramp Down Awards to Market Participants.
OASIS: Report RTM Flexible Ramping Down requirements and marginal prices.
Settlements: Settle Flexible Ramping Up and Down payment at the shadow price of the flex ramp
up and down requirement constraints, respectively.
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
May 2015
Stakeholder Process:
http://www.caiso.com/informed/Pages/StakeholderProcesses/FlexibleRampingProduc
t.aspx
External Business Requirements TBD
Technical Specifications TBD
Draft Configuration Guides TBD
Market Simulation TBD
Tariff Yes
Production Activation Fall 2015
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Fall 2015 – Bidding Rules
Milestone Details/Date Status
Application Software Changes
Through this initiative the ISO will evaluate the following: 1) unrestricted flexibility of resources to
change energy bid prices between the day-ahead and real-time markets, and across real-time
hours; 2) restrictions on commitment cost changes between and within the day-ahead and real-time
markets; and 3) verification of generator resource characteristics.
BPM Changes TBD
Business Process Changes TBD
Board Approval July 2015
External Business Requirements TBD
Technical Specifications TBD
Draft Configuration Guides TBD
Market Simulation TBD
Tariff TBD
Production Activation TBD – determine what is possible to be implemented prior to the winter of 2015-2016
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Early 2016 – Capacity Procurement Mechanism Replacement (CPM)
Milestone Details/Date Status
Application Software Changes
Bid Submittal System:
- SCs will need the mechanism to submit capacity bids (not an existing bid type) via
template (ISO will name application as requirements are developed)
- Business and validation rules need to be developed for capacity bids (not an
existing bid type) bid submission.
- Bid submittal shall be on a yearly, monthly, and daily level.
RA System:
- LSE deficiency calculation needed for competitive solicitation process.
- Existing CPM calculation should be deprecated for trade dates after the effective
date of implementation. CPM calculation must be trade date effective. The trade
date must be configurable.
- RA Tool must have the ability to receive the ED/CPM data.
- Manage import allocation
- Manage and process Use Plan information
Settlements:
Settlements will need new CPM formulas that will result in the following charge
code impacts:
- Approx. 1 Pre-calc charge code
- Approx. 10 allocation charge codes
- Approx. 10 payment charge codes
- Approx. 5 incentive charge codes (for RA-AIM)
- Approx. 8 supplemental revenue (part of real-time energy pre-calc) charge codes
Reporting:
If an annual or monthly CPM occurs greater than two times (over a rolling 24 month
period) or more than 50% of the LSE’s RA requirement is CPMed, a report must be
given to Market Participants.
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Early 2016 – Capacity Procurement Mechanism Replacement (cont.)
Milestone Details/Date Status
BPM Changes Reliability Requirements; Market Instruments; Billing & Settlements
Business Process Changes
- Solicitation for soft offer cap. 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/intra-monthly)
Board Approval February 5, 2015
External Business
Requirements March 13, 2015
Updated BPMs TBD
Technical Specifications TBD
Draft Configuration Guides TBD
Market Simulation Yes – November 2015
Tariff Yes
Production Activation 1/10/2016 (effective date of 3/1/16)
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Early 2016 – Reliability Services Initiative (RSI) Milestone Details/Date Status
Application Software Changes
RA System:
- Manage new resource types (new NQC/EFC process request). This will impact both
internal users and Market Participants
- Creation of substitution rules for flexible resource adequacy resources
- Modify existing DA/RT generic substitution rules
- DA substitution timeframe shall change from 6 AM to 8 AM
- Use result of Pre-qualification analysis (the pre-qualification analysis is a manual
process) for real time substitution validation
- Enable the release of substitute capacity for generic and flexible resources
- Allow imports to substitute for other imports and CAISO system resources. The RA
obligation will be at a daily level)
- Manage Import Allocation (CPM Replacement initiative is covering this scope but is
needed for this initiative)
- Modification of Use Plan with new validation rules
- Manage RA obligation (taking into consideration substitution capacity and replacement
capacity as RA capacity) will impact RA, Settlements, market, and outage. The output of
CSP will be needed
OMS:
- Outage Processing (removing SCP exemptions for outages submitted between T-7 to T-
45)
- The following nature of work codes shall be excluded from the availability incentives:
Unit testing, Unit cycling, Unit supporting startup, Transitional limitation, Ambient not due to
temperature, RTU/RIG, ICCP, AVR/Exciter, Transmission induced outage, and Use-limit
reached
- Creation of an additional category that would also be exempt: Non-environmental use-
limit reached
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Early 2016 – Reliability Services Initiative (cont.) Milestone Details/Date Status
Application Software Changes
Settlements:
The following charge code changes are needed for implementation of the RA
Availability Incentive Mechanism (RAAIM)
- Approx. 1 Pre-calc charge code
- Approx. 2 penalty charge codes
- Approx. 3 allocation charge codes
- Approx. 6 Effective dating of SCP charge codes
CMRI:
- Display Comparative snapshot of DA/RT obligation (outages, energy bids, RA
obligation). Display input of RAAIM calculations.
Reporting:
- Report on the effectiveness of the RAAIM results (1 year after implementation)
Other:
- LSE cost allocation methodology needs to automated.
- Comparative snapshot of DA/RT obligation (outages, energy bids, RA obligation).
- These inputs must be saved separately for RA Availability Incentive Mechanism
(RAAIM) calculations.
- Perform RAAIM calculations
- Publish list of all available prequalification combinations
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Early 2016 – Reliability Services Initiative (cont.)
Milestone Details/Date Status
BPM Changes Reliability Requirements; Outage Management; Billing & Settlements
Business Process Changes
- Process to assign NQC values to NGR/PDR/DG resources
- Process for PDR/NGR/DG testing
- Process for RA Availability Incentive Mechanism (RAAIM). Must retire SCP
business process flows.
- Modify DA/Real Time Substitution Process
- Process for allocating year end unallocated RA Availability Incentive Mechanism
(RAAIM) funds
Board Approval March 26 - 27, 2015
External Business Requirements March 13, 2015
Updated BPMs TBD
Technical Specifications TBD
Draft Configuration Guides TBD
Market Simulation Yes – November 2015
Tariff Yes
Production Activation 1/10/2016 (effective date of 3/1/16) – assuming dependency with CPM
Replacement
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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 (ISO to supply data)
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
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Fall 2016 – RIMS Functional 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
Generator Interconnection and Deliverability Allocation Procedures
Generator Interconnection Procedures
Managing Full Network Model
Metering
Generator Management
Transmission Planning Process
Business Process Changes N/A
Board Approval N/A
External Business Requirements N/A
Updated BPMs N/A
Technical Specifications N/A
Draft Configuration Guides N/A
Market Simulation Tentative Spring/Summer 2016
Tariff N/A
Production Activation Fall 2016
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Fall 2016 – OMAR Replacement
Milestone Details/Date Status
Application Software Changes
Current metering space at the California 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.
• Customer Partnership Group will be formed to ensure capture of external requirements.
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 Date TBD
Draft Configuration Guides N/A
Market Simulation Date TBD
Tariff N/A
Production Activation Fall 2016
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Fall 2016 - 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
Distribute Results: TBD
Comments Due: TBD
Board Approval TBD
External Business Requirements TBD
Technical Specifications TBD
Draft Configuration Guides TBD
Market Simulation TBD
File Tariff TBD
Production Activation Fall 2016
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TBD – Expanding Metering and Telemetry Options Phase 2
Milestone Details/Date Status
Application Software Changes
Distributed Energy Resource Provider Agreement:
1. Meet minimum capacity requirements,
• allow aggregate distributed energy resources into a single resource
2. Specify data concentrator functionality for real time monitoring, control and after the fact
metering data
• to disaggregate ISO signals to sub-resources to obtain a resource response and
• to aggregate sub-resource operational and settlement meter data to submit to the
ISO
3. Define the provision of technical and operational information to the ISO,
• metering and communications requirements,
• submission of economic bids and self-schedules and
• provision of ancillary services
4. Identify responsibility for fulfilling the terms of the agreement
• penalties and sanctions, cost responsibility, dispute resolution, representations and
warranties, liability, uncontrollable forces and other miscellaneous terms
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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TBD – ADS UI Replacement
Milestone Details/Date Status
Application Software Changes Port client from Delphi to new common user interface (ADS Query Tool and Real
Time Functionality)
BPM Changes N/A
Business Process Changes N/A
Board Approval N/A
External Business Requirements N/A
Updated BPMs N/A
Technical Specifications N/A
Draft Configuration Guides N/A
Market Simulation TBD
Tariff N/A
Production Activation TBD
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