Market Performance and Planning Forum November 7, 2012 Objective: - - PowerPoint PPT Presentation

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Market Performance and Planning Forum November 7, 2012 Objective: - - PowerPoint PPT Presentation

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Market Performance and Planning Forum November 7, 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

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SLIDE 1

Market Performance and Planning Forum

November 7, 2012

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SLIDE 2

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

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SLIDE 3

Proposed Meeting Schedule for 2013

  • February 13
  • April 10
  • June 5
  • July 31
  • Sept 25
  • Nov 20

Page 3

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SLIDE 4

Agenda

Slide 4

10:00- 10:05 Introduction, Agenda Mercy Helget 10:05 – 11:20 Market Analysis Mark Rothleder, Nan Liu,

Guillermo Bautista- Alderete

11:20 – 11:40 Four Corners Transition Debi Le Vine 11:40 – 12:00 Policy Update Brad Cooper 12:00 – 1:00 Lunch 1:00 – 2:00 Technical Updates NGR/REM Market Simulation Report Khaled Abdul-Rahman, George Angelidis, Li Zhou, Jeremy Malekos Outage Management System – deferred until 12/19 Jami Herguth 2:00 – 3:00 Release Updates Janet Morris

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SLIDE 5

Market Performance and Quality Update

Market Quality and Renewable Integration

Mark Rothleder Nan Liu Guillermo Bautista-Alderete

Slide 5

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SLIDE 6

Slide 6

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

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SLIDE 7

Slide 7

  • With summer over, lower load and more transmission outages

present a different set of challenges.

  • More outages led to more constraints modeled in the market

contributing to day-ahead solution challenges.

  • Continue to focus on setting up forward markets conditions to

meeting real-time reliability needs.

  • Improved price convergence between DA/HASP/RTD on
  • average. Varies between DLAPs and time of the day.
  • Real-time congestion offset cost peaked in August but remained

at elevated levels in September and October.

Operation highlights:

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SLIDE 8

DLAP LMP Monthly Average: Price convergence improved in August and September

Page 8 10 20 30 40 50 Jan-11 Mar-11 May-11 Jul-11 Sep-11 Nov-11 Jan-12 Mar-12 May-12 Jul-12 Sep-12 $/MWh

IFM HASP RTD

PG&E 10 20 30 40 50 Jan-11 Mar-11 May-11 Jul-11 Sep-11 Nov-11 Jan-12 Mar-12 May-12 Jul-12 Sep-12 $/MWh

IFM HASP RTD

SCE 10 20 30 40 50 60 70 Jan-11 Mar-11 May-11 Jul-11 Sep-11 Nov-11 Jan-12 Mar-12 May-12 Jul-12 Sep-12 $/MWh

IFM HASP RTD

SDG&E

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SLIDE 9

DLAP LMP Monthly Average (On Peak)

Page 9 10 20 30 40 50 60 Jan-11 Mar-11 May-11 Jul-11 Sep-11 Nov-11 Jan-12 Mar-12 May-12 Jul-12 Sep-12 $/MWh

IFM HASP RTD

PG&E 10 20 30 40 50 60 Jan-11 Mar-11 May-11 Jul-11 Sep-11 Nov-11 Jan-12 Mar-12 May-12 Jul-12 Sep-12 $/MWh

IFM HASP RTD

SCE 10 20 30 40 50 60 70 80 90 Jan-11 Mar-11 May-11 Jul-11 Sep-11 Nov-11 Jan-12 Mar-12 May-12 Jul-12 Sep-12 $/MWh

IFM HASP RTD

SDG&E

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SLIDE 10

DLAP LMP Monthly Average (Off Peak)

Page 10 10 20 30 40 50 Jan-11 Mar-11 May-11 Jul-11 Sep-11 Nov-11 Jan-12 Mar-12 May-12 Jul-12 Sep-12 $/MWh

IFM HASP RTD

PG&E 10 20 30 40 50 Jan-11 Mar-11 May-11 Jul-11 Sep-11 Nov-11 Jan-12 Mar-12 May-12 Jul-12 Sep-12 $/MWh

IFM HASP RTD

SCE 10 20 30 40 Jan-11 Mar-11 May-11 Jul-11 Sep-11 Nov-11 Jan-12 Mar-12 May-12 Jul-12 Sep-12 $/MWh

IFM HASP RTD

SDG&E

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SLIDE 11

DLAP LMP Hourly Average in October

Page 11 10 20 30 40 50 60 70

1 2 3 4 5 6 7 8 9 101112131415161718192021222324

$/MWh

IFM HASP RTD

PG&E

Hour

10 20 30 40 50 60 70 80 1 2 3 4 5 6 7 8 9 101112131415161718192021222324 $/MWh

IFM HASP RTD

SCE

50 100 150 200 250 1 2 3 4 5 6 7 8 9 101112131415161718192021222324 $/MWh

IFM HASP RTD

SDG&E

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SLIDE 12

Monthly price distributions: price volatility decreased in September and October.

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  • 10.0%
  • 8.0%
  • 6.0%
  • 4.0%
  • 2.0%

0.0% 2.0% 4.0% Jan-11 Mar-11 May-11 Jul-11 Sep-11 Nov-11 Jan-12 Mar-12 May-12 Jul-12 Sep-12 Percent of Real Time Intervals

  • $30 to -$5
  • $100 to -$30
  • $300 to -$100

<-$300 $250 to $500 $500 to $750 $750 to $1000 >$1000

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SLIDE 13

Monthly average of RTD intervals with insufficient up ramping capacity declined in October.

Page 13 0.00% 0.20% 0.40% 0.60% 0.80% 1.00% 1.20% 1.40% 1.60% 1.80% 2.00% 20 40 60 80 100 120 140 160 180 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 Percent of Intervals Count of Intervals

5-minute intervals with insufficient upward ramping capability percent of intervals with insufficient upward ramping capability

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SLIDE 14

Monthly average of RTD Intervals with insufficient down ramping capacity continued the downward trend in September and October.

Page 14 0.00% 0.50% 1.00% 1.50% 2.00% 2.50% 3.00% 3.50% 4.00% 4.50% 5.00% 100 200 300 400 500 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 Number of Intervals

5-minute intervals with insufficient downward ramping capability percent of intervals with insufficient downward ramping capability

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SLIDE 15

Real-time energy offset costs decreased in September and October.

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SLIDE 16

Slide 16

Real-Time congestion cost dropped remained at relatively high level in October due to congestion related to outage.

Caused by abnormally high congestion and high shadow prices (RT vs. DA) on: Table Mountain transformer, Hoodoo Wash-N Gila line and SCE percent import limits.

  • 10

10 20 30 40 50 60

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

$Millions

Congestion Imbalance Offset Energy Imbalance Offset

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SLIDE 17

Exceptional dispatch volume as percent of load declined in September and rose in October.

Page 17

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SLIDE 18

Daily exceptional dispatches in MWh – by reason

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5 10 15 20 25 30 35 40 1-Sep 3-Sep 5-Sep 7-Sep 9-Sep 11-Sep 13-Sep 15-Sep 17-Sep 19-Sep 21-Sep 23-Sep 25-Sep 27-Sep 29-Sep 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

Thousands MWh Per Day

T Procedure Transmission Outage SP26 Capacity SCE SOB 204 Unit Testing Conditions beyond control of the CAISO BA G Procedure Other

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SLIDE 19

Bid cost recovery (BCR) costs decreased in September and then increased in October due to RUC uplifts.

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2 4 6 8 10 12 14 16 18 20

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 $Millions IFM RT RUC

RUC procurement increased to respond to potential for loss COI transfer capability during

  • utage work.
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SLIDE 20

October encountered challenge to achieve quality solution within specified time thresholds.

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100,000 200,000 300,000 400,000 500,000 600,000 700,000 800,000 900,000

1/1/11 2/1/11 3/1/11 4/1/11 5/1/11 6/1/11 7/1/11 8/1/11 9/1/11 10/1/11 11/1/11 12/1/11 1/1/12 2/1/12 3/1/12 4/1/12 5/1/12 6/1/12 7/1/12 8/1/12 9/1/12 10/1/12

Daily Dollar 30 Day Moving Average

Mip Gap ($)

October 1 and 2 low quality solution due to timeout of solution

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SLIDE 21

0.0% 0.2% 0.4% 0.6% 0.8% 1.0% 1.2% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct 2011 2012 Percentage of Nodes Corrected

Data Input Software Tariff Process

Price corrections reduced in Sep but increased in Oct to address DA timing out issue.

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Incorrect distribution factors in two weeks of July caused 70% of corrections in July Market Software timed out while searching for the solution

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SLIDE 22

Price corrections reduced in Sep but increased in Oct to address DA timing out issue.

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Incorrect distribution factors in two weeks of July caused 70% of corrections in July Market Software timed out while searching for the solution

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SLIDE 23

Enhanced Process for DAM

  • Leverage on the DA+2 run process to identify potential

issues.

  • Increased support for the day-ahead market run.
  • Further validation of the DAM results before publishing.
  • Ongoing Root Cause Analysis effort for price corrections.
  • Development of a market validation tool.

Page 23

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SLIDE 24

Slide 24

Flexi-ramp constraint costs remained relatively low in the past four months.

0.5 1 1.5 2 2.5 3 3.5 4 4.5

Dec-11 Jan-12 Feb-12 Mar-12 Apr-12 May-12 Jun-12 Jul-12 Aug-12 Sep-12 Oct-12 $Millions

Monthly Flexi-Ramp Cost

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SLIDE 25

Slide 25

  • Ancillary Services Requirement Setter (ASRS) was implemented in late

August.

  • Better real-time market flows with Compensating Injection (CI)

enhancement in late September.

  • Experienced DA MIP gap issue on Oct 1 and Oct 2. Measures are in

place in DA run to prevent it from happening in the future.

  • Expediting process to modify the real-time scheduling run transmission

constraint relaxation parameter from $5000 to $2500.

  • Conformed transmission constraint limits in forward market (DA) to be

consistent with real-time market where appropriate.

  • Real-time congestion offset cost peaked in August but remained at

elevated levels in September.

  • Plan to stop publishing the monthly market catalog report due to low

interests.

  • Implemented flexible ramp settlement on November 1, 2012

Events and Developments:

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SLIDE 26

Price correlation between flex ramp constraint and energy

  • Overall, good correlation between RTUC flex ramp price and RTUC

energy price

  • The correlation would extend to negative prices with the downward

flex ramp product

Page 26

RTUC RTUC

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SLIDE 27

Price correlation between flex ramp constraint and energy

  • Overall, good correlation between HASP flex ramp price and HASP

energy price, but prices are lower than RTPD

  • For the same interval, the advisory conditions are different from the

binding conditions, which have impacted the unit commitments

Page 27

HASP HASP

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SLIDE 28

Price correlation between flex ramp constraint and energy

  • No correlation between RTD flex ramp price and RTD energy price

because zero requirement is enforced for the binding RTD interval

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RTD RTD

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SLIDE 29

Price correlation between flex ramp constraint and energy

  • Poor/no correlation between RTUC flex ramp price and RTD energy

price raises the concern of over/under procurement and poor deployment – Over procurement: FRC price high, energy price low – Under procurement: FRC price low, energy price high – Poor deployment: use up capacity unnecessarily, and get short when real need comes

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RTUC RTD

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SLIDE 30

Four Corners Transition

Deb Le Vine Director of Infrastructure Contracts & Management

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SLIDE 31

Updated Information – 11/7/2012

  • The ISO was notified this morning by SCE that the Four

Corners transition will not take place on 12/1/2012, but SCE does not have a new date at this time.

  • The ISO will publish a market notice with the new dates
  • nce they are known.
  • SCs should still register for the new WILLOWBEACH

scheduling point as soon as possible.

Note: This presentation has been adjusted to account for this uncertainty. Any date that is no longer certain is in blue italics and has (TBD) after it.

Page 31

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SLIDE 32

Four Corners Transition – Big Picture

  • Effective 12/1/2012 (TBD), SCE entitlement on

Eldorado-Moenkopi east of the Colorado River and Moenkopi-Four Corners is terminated

– New scheduling point between APS and CAISO is WILLOWBEACH versus MOENKOPI500 or FOURCORNE345

  • APS Balancing Area will include:

– Four Corners – Moenkopi – Moenkopi – Willow Beach

  • CAISO Balancing Area will include:

– Willow Beach – Eldorado 500 kV

  • ISO’s markets will not be updated until 12/21/2012 (TBD)

– 12/19: DB 62 is deployed – 12/21 (TBD): New scheduling point and MSL effective

Page 32

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SLIDE 33

4 Corners 345 kV 4 Corners 500 kV El Dorado 500 kV 24042

McCullough X 500 kV 6047

FCORNER3_MSL FCORNER5_MSL ELDORADO_MSL MCCULLGH_MSL Moenkopi 500 kV 14002 Navajo 500 kV Crystal 500 kV 6123 McCullough 500 kV 26048

Network topology 4/1/2009 – 11/30/2012 (TBD) CAISO Boundary

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SLIDE 34

4 Corners 345 kV 4 Corners 500 kV El Dorado 500 kV 24042

McCullough X 500 kV 6047

ELDORADO_MSL Moenkopi 500 kV 14002 Willow Beach 500 kV Navajo 500 kV Crystal 500 kV 6123 McCullough 500 kV 26048

Network topology changes effective 12/1/2012 (TBD) CAISO Boundary

MCCULLGH_MSL

Import / Exports : FOURCORNE345 =0 FCORNER3_MSL=0 FCORNER5_MSL=0 Active scheduling point is MOENKOPI500

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SLIDE 35

4 Corners 345 kV 4 Corners 500 kV El Dorado 500 kV 24042

McCullough X 500 kV 6047

ELDORADO_MSL Moenkopi 500 kV 14002 Willow Beach 500 kV Navajo 500 kV Crystal 500 kV 6123 McCullough 500 kV 26048

Network topology changes effective 12/21/2012 (TBD) CAISO Boundary

MCCULLGH_MSL

Scheduling points deactivated Active scheduling point is WILLOWBEACH

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SLIDE 36

Tag and Bidding Examples - Today

Transmission Provider Point of Receipt Point of Delivery Scheduling Entity CISO MOENKOPI500 ELDORADO500 AZPS CISO ELDORADO500 SP15 CISO BIDS SC_MOENKOPI500_I_F_xxxx SC_MOENKOPI500_E_F_xxxx TAGS

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SLIDE 37

Tag and Bidding Examples – Trade Date 12/1 to 12/20 (TBD)

Transmission Provider Point of Receipt Point of Delivery Scheduling Entity AZPS MOENKOPI500 WILLOWBEACH AZPS CISO WILLOWBEACH SP15 CISO BIDS SC_MOENKOPI500_I_F_xxxx SC_MOENKOPI500_E_F_xxxx TAGS

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SLIDE 38

Tag and Bidding Examples – Trade Date 12/21/2012 (TBD)

Transmission Provider Point of Receipt Point of Delivery Scheduling Entity AZPS MOENKOPI500 WILLOWBEACH AZPS CISO WILLOWBEACH SP15 CISO BIDS SC_WILLOWBEACH_I_F_xxxx SC_WILLOWBEACH_E_F_xxxx TAGS

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SLIDE 39

Next Steps

  • SCs must register for the new WILLOWBEACH

scheduling point (ITIE and ETIE)

– Registration will open 11/12/2012 – For 12/21/2012 (TBD) effective date

  • registration closes 11/30/2012 (TBD)

– After 11/30/2012 (TBD) effective date will be in accordance with regular MasterFile update timelines and subject to MasterFile data freeze

  • WILLOWBEACH is already registered in TSIN and EIR
  • SC will need to obtain transmission service from APS for

MOENKOPI500 - WILLOWBEACH

Page 39

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SLIDE 40

Policy Update

Brad Cooper Manager, Market Design and Regulatory Policy

Slide 40

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SLIDE 41

Market initiatives going to the Board for approval in Dec 2012

Initiative Board Presentation BCR Mitigation Meas. (RIMPR 1) Dec Exceptional Dispatch Mitigation in Real Time Dec Transition Constraint Relaxation Parameter Change Dec

Page 41

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SLIDE 42

Market design initiatives coming soon (slide 1 of 2)

  • Flexible RA Resource Criteria and Must Offer

Requirements – Targeted to start late Nov or early Dec 2012

  • Marginal Loss Surplus Allocation

– Targeted to start Q4 2012

  • Expanding Metering and Telemetry Options

– Targeted to start Q1 2013

  • Multi-Stage Generator Bid Cost Recovery

– Targeted to start Q1 2013

Page 42

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SLIDE 43

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

  • Additional initiatives based on Stakeholder Initiative

Catalog process

Page 43

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SLIDE 44

Technical Updates

Khaled Abdul-Rahman, Director George Angelidis, Principal Li Zhou, Senior Advisor Fan Zhang, Senior Advisor Power Systems Technology Development Jeremy Malekos, Project Manager

Page 44

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SLIDE 45

Non-generator resource – Regulation energy management

Fall 2012 market simulation September 11 – 27

Li Zhou Jeremy Malekos

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SLIDE 46

NGR/REM Market Simulation goal

  • Provide market participants end-to-end functionality of

the NGR/REM model – Regulation Energy Management

  • Option that allows new storage, demand response

and other technologies to provide regulation over a continued sustained period.

  • AGC manages resource to its mid-point

implementing the “50% rule” (REM only) – Non-REM model storage, demand response and

  • ther technology resources to participate in energy,

regulation, spin and non-spin.

Page 46

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SLIDE 47

NGR/REM Market Simulation Summary

  • Total NGR Resources: 49
  • Total NGR REM resources: 24
  • Total Non-REM resources: 25
  • Demand Response: 10
  • Energy Storage: 39
  • Total Capacity (MW): 415
  • Total Stored Energy (MWh): 249
  • Scheduling Coordinators: 7
  • Market Participants: 18
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SLIDE 48

NGR/REM Market Simulation Links Market simulation scenarios

http://www.caiso.com/Documents/RegulationEnergyManagementPhase2Marke tSimulationScenarios.pdf

Market simulation execution report:

http://www.caiso.com/Documents/RegulationEnergyManagement_NGR- REM_Phase2StructuredScenarioExecutionReport.doc

Market simulation AGC data; week1, week2, week3:

http://www.caiso.com/Documents/Regulation%20energy%20management%20- %20implementation%20phase%202

Historical production ACE data:

http://www.caiso.com/Documents/Area%20control%20error%20data

Historical system frequency data

http://www.caiso.com/Documents/System%20frequency%20data

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SLIDE 49

Scenario #1 Normal system conditions - apply 50% rule to REM only resources Scenario #2 System under Stress – AGC uses available energy left indicated by the

SOC to meet regulation requirement.

– Demonstrate how the ±150MW Area Control Error (ACE) threshold is applied to the 50% rule. – Scenario outcome:

  • REM resources are maintained by AGC at their

mid point.

Page 49

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SLIDE 50

Area Control Error (ACE) TD 9/11, HE 19

Page 50

  • 1000
  • 800
  • 600
  • 400
  • 200

200 400 600 800 ACE

ACE within threshold Scenario#1 ACE outside of Threshold Scenaro#2

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SLIDE 51

Scenario #1

Page 51

  • 2.25
  • 2
  • 1.75
  • 1.5
  • 1.25
  • 1
  • 0.75
  • 0.5
  • 0.25

0.25 0.5 0.75 1 1.25 1.5 1.75 2 2.25 ±2MW SOC

±2MW, 0.5MWH

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SLIDE 52

Scenario #2 HE 19

Page 52

  • 2.25
  • 2
  • 1.75
  • 1.5
  • 1.25
  • 1
  • 0.75
  • 0.5
  • 0.25

0.25 0.5 0.75 1 1.25 1.5 1.75 2 2.25 2.5 ±2MW SOC

Setting up scenario #2

End of scenario#1 scenario#2

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SLIDE 53

Scenario #3 Continuous energy charge Non-REM resource for one hour.

– Non-REM resource 50% rule does not apply. – Scenario outcome:

  • Using energy bid, AGC received a negative DOT

and then sent the resource to charge continuously for several hours.

  • ACE threshold not applicable

Page 53

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SLIDE 54

Scenario #3 DOT (Neg.) AGC (Neg.)

  • 3
  • 2
  • 1

1 2 3 4 5 ±2.2MW SOC

±2.2MW, 13.2MWH ADS DOT

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SLIDE 55

Scenario #6 AGC is in charging while Dispatch is in discharging (Non-REM) Scenario #7 AGC is in discharging while Dispatch is in charging (Non-REM)

– Non-REM resource can be dispatched in one direction but AGC’d in the opposite direction.

Page 55

  • 10
  • 5

5 10 15 20

Scenario#6

DOT AGC SOC

  • 2
  • 1

1 2 3 4 5 6 7 8 9

Scenario#7

DOT AGC SOC

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SLIDE 56

Scenario #9 REM Demand Response regulated in the positive and negative range

without energy limit

– Demand Response REM resource

  • no energy limit / SOC

– Scenario outcome:

  • Modeled just the capacity of a demand response

participating in regulation only.

Page 56

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SLIDE 57

Scenario #9 REM Demand Response regulated in the positive and negative range

without energy limit

±1MW ±2.5MW

  • 1.5
  • 1
  • 0.5

0.5 1 1.5

Demand Response #16

Demand Response #16

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SLIDE 58

Scenario #10 Non-REM Demand Response dispatched and regulated in the negative

range, on a continuous basis

– Non-REM Demand Response

  • no energy limit / SOC
  • Dispatch and AGC in the negative range

Page 58

  • 3.5
  • 3
  • 2.5
  • 2
  • 1.5
  • 1
  • 0.5

MW

Resource 16

DOT AGC

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SLIDE 59

Conclusion / Next steps

– NGR base model builds a solid foundation for participation of non-generator resources such as storage, flywheels, demand response and others – ISO continues working with participants in the upcoming FERC Order 755 pay for performance market simulation to further simulate such resources – ISO will utilize the NGR model in production for resources under agreed pilot programs

Page 59

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SLIDE 60

FERC Order 755 – Pay for Performance

Technical Update

George Angelidis Jeremy Malekos

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SLIDE 61

FERC Order 755 Pay for Performance Bid to Bill Example

Refer to spreadsheet on:

  • CAISO.com > Stay informed > Release Planning >

Spring 2013 release > Pay for performance regulation – implementation >

– http://www.caiso.com/Documents/Pay%20for%20performance%20regul ation%20-%20implementation

Page 61

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SLIDE 62

FERC Order 755 Pay for Performance Bid to Bill Example

Spring Market Simulation

– Goal:

  • End-to-End software functionality
  • Provide a simulation that shows reasonable dispatch of a

resources potential mileage – Feb 2, 2013 – Mar 1, 2013 – Structured week1, unstructured week2, structured week3, unstructured week4 – Incorporate lessons learned from Fall 2012 non-generator resource Market sim

Page 62

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SLIDE 63

Release Plan Updates

Janet Morris, Director Program Office

Page 63

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SLIDE 64

The ISO offers comprehensive training programs

Date Training November 6, 7 SC Certification class (on-site) November 15 Welcome to the ISO (webinar) 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)

Page 64

Training calendar - http://www.caiso.com/participate/Pages/Training/default.aspx Contact us - markettraining@caiso.com

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SLIDE 65

Release Plan – 2012

  • Fall 2012
  • Non-Generator Resources / Regulation Energy Management - Phase 2
  • Data Release Phase 3
  • 72 Hour RUC
  • Transmission Reliability Margin
  • Commitment Costs Refinements - Greenhouse Gas Regulation only (1/1/13)
  • FERC 745 Net Benefits Test
  • Contingency Dispatch Enhancements
  • Regulatory Must Take Generation
  • Group Constraint enhancement
  • BAPI, OASIS – UI upgrade (does not impact API) ; CMRI UI upgrade rescheduled
  • Replacement Requirement for Scheduled Generation Outages
  • Year End 2012
  • Four Corner transition (12/1/12)
  • Settlements 9.07 (12/18/12)
  • DB62 (12/19/12)
  • City of Colton activation (1/1/13)
  • Valley Electric Association activation (1/3/13)

Page 65

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SLIDE 66

Release Plan – 2013

  • Spring 2013
  • MSG Phase 3 deployment (Market Simulation December 10-14, 2012)
  • 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 Procurement – Risk of Retirement
  • Price Inconsistency Market Enhancements
  • DRS API deployment
  • Master File Enhancements Phase 2
  • 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)
  • Dynamic Transfers (rescheduled)
  • Ancillary Services Buy-Back

Page 66

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SLIDE 67

Release Plan – 2014 (proposed)

  • Spring 2014
  • FERC Order 764 Compliance / 15 Minute Market
  • Fall 2014
  • Flexible Ramping Product
  • iDAM (simultaneous IFM and RUC)
  • Subject to further release planning:
  • Outage Management System (External BRS posted)
  • Enterprise Model Management System
  • Subset of Hours
  • Flexible Resource Adequacy Criteria and Must Offer Obligation

Page 67

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SLIDE 68

Fall 2012 Release Deployment Dates

The new deployment and activation dates are as follows:

Page 68

http://www.caiso.com/Documents/Fall%202012%20release%20-%20plans

Drop Description DEPLOYMENT ACTIVATION Published Revised Published Revised Settlements fall release for November MRI Settlements Application deployment Congestive Revenue Rights (CRR) 11-01-2012 11-01-2012 11-05-2012 11-05-2012 RRSGO 11-12-2012 11-12-2012 11-12-2012 11-12-2012 1 Master File (MF) and Application Integration Layer 11-01-2012 11-19-2012 11-01-2012 11-19-2012 2 Application Upgrade Deployment – part 1  FERC 745 11-06-2012 11-26-2012 11-06-2012 11-26-2012 Application Upgrade Deployment – part 2  CDE RTCD  Group Constraints  RTPD Advisory 11-06-2012 11-27-2012 11-06-2012 11-27-2012 3 Open Access Same-Time Information System (OASIS) – MRI Market Participant Portal (MPP) 12-04-2011 12-11-2012 12-11-2012 12-11-2012

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SLIDE 69

2012 Release Plan

http://www.caiso.com/Documents/2012ReleasePlan.pdf

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SLIDE 70

2013 Release Plan

Page 70

http://www.caiso.com/Documents/2013ReleasePlan.pdf

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SLIDE 71

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

Fall 2012 Release – SIBR Business Rules Revision Summary

Page 71

* Note: SIBR BR sets 5.3 and 5.4 may be revised beyond June 29, pending review with software vendor and stakeholders

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SLIDE 72

RDT 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) Detailed in Technical Specifications to be posted July 23, 2012

Fall 2012 Release – RDT and API Versioning

Page 72

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SLIDE 73

Fall 2012 Release – Web Service Changes

Page 73

  • ADS
  • 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)

  • 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
  • f “Wind and Solar Forecasting Data” data
  • (Data Release Phase 3) New OASISCRRPublicBid / API Web Service to accommodate query
  • f “CRR Public Bid Data” data
  • (Data Release Phase 3) Update to OASIS OASISReport / API Web Service to accommodate query
  • f “Aggregated Generation Outage” data
  • (Greenhouse Gas) Update to OASIS OASISReport / API Web Service to accommodate query
  • f “GHG Allowance Index Price” data
  • (TRM) Update to OASIS OASISReport / API Web Service to accommodate query
  • f the Transmission-related reports (Current Transmission Usage, Transmission Interface Usage, ATC)
  • SLIC
  • New API version ID TBD
  • (NGR-REM) Update to SLIC API External Web Services to accommodate updates/queries
  • f “NGR-REM” data
  • MFRD
  • (RMTG) Update to MFRD GeneratorRDT Web Service / API to accommodate updates/queries
  • f “Regulatory must take maximum (RMTMax)” data -- GeneratorRDT_v20121001
  • (MLCA) Update to MFRD IntertieRDT Web Service / API to accommodate updates/queries
  • f “Marginal Loss Cost Adjustment” data -- IntertieRDT_v20121001
  • (GHG) Update to MFRD GeneratorRDT Web Service / API to accommodate updates/queries
  • f “Green House Gas” data -- GeneratorRDT_v20121001
  • (NGR-REM) Update to MFRD GeneratorRDT Web Service / API to accommodate updates/queries
  • f “NGR-REM” data -- GeneratorRDT_v20121001
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SLIDE 74

Milestone Date

Application Software Changes SIBR: NGR as a generation resource 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 Operations Market Instruments Outage Management Settlements & Billing 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

Fall 2012 Release – NGR Phase II: Non-Rem

Page 74

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SLIDE 75

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

NDA posted October 25, 2012 Must be returned by November 16, 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 expected December 2012

Production Activation

Trade Date December 11, 2012

Fall 2012 – Data Release (Phase 3)

Page 75

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SLIDE 76

Ongoing Data Request Process

Please refer to: http://www.caiso.com/Documents/Agenda_Presentation- MarketPerformance_PlanningForumJan26_2012.pdf

Page 76

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SLIDE 77

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 December 11, 2012

Fall 2012 – 72 Hour RUC

Page 77

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SLIDE 78

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

Trade Date December 11, 2012

Fall 2012 – Transmission Reliability Margin

Page 78

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SLIDE 79

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

  • f proxy SU and ML costs as well in the default energy bids and generated bids.

BPM Changes

Market Instruments – 11/2/12

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

Posting for Review – 8/3/2012 Stakeholder Review Due – 8/17/12 Stakeholder Meeting/Call – 8/22/12 Filing – 10/29/12

Production Activation

Trade Date January 1, 2013

Fall 2012 – Commitment Cost Refinements (Greenhouse Gas Emissions Costs)

Page 79

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SLIDE 80

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 80

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SLIDE 81

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-11/27/12 (tentative), RTDD-12/11/12

Fall 2012 – Contingency Dispatch Enhancements

Page 81

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SLIDE 82

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 September 10, 2012 FERC Filing September 17, 2012

Market Simulation

September 18-28, 2012

RMTG Value Letter and Registration Process

October 23, 2012

Production Activation

Calendar date December 11, 2012

Fall 2012 – Regulatory Must Take Generation

Page 82

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SLIDE 83

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

11/27/12

Fall 2012 – Group Constraints - (Recognition of Order of Startups between Grouped Resources Enhancement)

Page 83

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SLIDE 84

Milestone Date

Application Software Changes

IRR: Updated template for RA plan submittal to include non-RA designated resources and replacement prioritization of those resources

BPM Changes

BPM Posting October 2012: Outage Management & Reliability Requirements Settlements BPM Posting November 2012: Settlements (2 new charge codes)

Business Process Changes

Manage Generation Outages:

  • RA Outage Management Process (new)

Manage Reliability Requirements:

  • Annual Monthly RA Process (new)
  • Replacement Requirement Backstop Capacity (new)

Settlements

October 10, 2012 Settlement Technical Document October 20, 2012 Settlement Draft Configuration File

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

Market Simulation

November 5, 2012

Tariff

September 20, 2012 Tariff Filed

Production Activation

November 12, 2012 Open for submittals November 21, 2012 (T-41 Deadline for January 2013 submittals)

Fall 2012 – Replacement Requirements for Scheduled Generation Outages

Page 84

slide-85
SLIDE 85

2012 Year End Activation

Page 85

Valley Electric Association Milestone Date

Application Software Changes

N/A

BPM Changes

N/A

Board Approval

September 11, 2012

Market Simulation

November 26 - 30, 2012

Production Activation

January 3, 2013

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

slide-86
SLIDE 86

Milestone Date

Application Software Changes

This project will allow the ISO to pursue tariff changes that will ensure the ISO has sufficient backstop procurement authority to address capacity at risk

  • f retirement (ROR) that the ISO identifies as needed up to five years in the

future to maintain system flexibility or local reliability. MasterFile: Designate ROR resources and input/store the minimum revenue guarantee (MRG) Settlements: New Charge Code for Risk of Retirement payment DREAMS/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), Perform Market Reporting (MOS LII), Perform Market Validation (MOS LII), Maintain DMM DB & Monitoring Systems (SBS LII)

Board Approval

September 2012

External Business Requirements

November 2012

Updated BPMs

December 2012

Market Simulation

February 2013

Tariff

Filing November 2012 Expected approval February 1, 2013

Production Activation

ROR Designation – April 1, 2013 Settlements, MasterFile, DREAMS – Spring 2013

Flexible Capacity Procurement Phase 1 – Risk of Retirement

Page 86

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SLIDE 87

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

  • n a group of configurations (as registered in the Master File) during the
  • ptimization.

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

December 10–14, 2012

Tariff

Not Applicable

Production Activation

Spring 2013

Spring 2013 – MSG Enhancements (Phase 3)

Page 87

slide-88
SLIDE 88

Milestone Description/Date

Application Software Changes

ADS: provide DA regulation up/down mileage awards 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

  • n 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 Market Instruments Settlements & Billing Definitions & Acronyms

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

Technical Specifications

Nov 16, 2012

Configuration Guides

Jan 8, 2013

Market Simulation

Feb 2, 2013

Compliance Filing

April 2012 - docket no. ER12-1630

Product Activation

Oct 19, 2012 filing 1) Compliance filing, 2) request for rehearing 3) motion for an extension requesting effective date May 1, 2013

Spring 2013 – FERC Order 755 pay for performance

Page 88

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SLIDE 89

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 2012

Updated BPMs

December 2012

Market Simulation

February 2013

Tariff

Filing in November, FERC Approval TBD

Production Activation

Spring Release 2013 (May 1, 2013)

Spring 2013 – LMPM Enhancements (Phase 2)

Page 89

slide-90
SLIDE 90

Milestone Date

Application Software Changes

Master File: Additional MSG Configurations need to completed by Spring Release 2013. Reporting: A Breakdown of BCR Components will be added to the Monthly Market Report. SAMC: Requires a tune-up on formulas to determine the ON criteria for resources, and the eligibility for Bid Cost Recovery.

BPM Changes

Market Instruments; Market Operations; Settlements & Billing

Business Process Changes

N/A

Board Approval

Feb 16, 2012

External Business Requirements

N/A

Updated BPMs

TBD

Market Simulation

TBD

Tariff

TBD

Production Activation

Spring 2013

Spring 2013 - Post Emergency BCR Filing / Mandatory MSG

Page 90

slide-91
SLIDE 91

Milestone Date

Application Software Changes

IFM/RTM:

Depending on defined approach between Siemens and ISO, we anticipate no payload change however IFM/RTM software shall populate APNODE and Anode values accordingly. A similar approach shall be used for the pricing run vs. scheduling run. SIBR (Fall 2013) – Shall be tracked under the BCR initiative.: SIBR rule changes will be needed to change the bid floor from -$30 (soft) to - $150 (hard). The implementation timeline is dependent on the -$150 go-live (renewable initiative – phase 1). The bid floor change will NOT be part of this initiative.

BPM Changes

Market Instruments; Market Operations

Business Process Changes

N/A

Board Approval

November 1, 2012

External Business Requirements

TBD

Updated BPMs

TBD

Market Simulation

TBD

Tariff

TBD

Production Activation

Spring 2013

Spring 2013 – Price Inconsistency Market Enhancements

Page 91

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SLIDE 92

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 CIDI: Provides POC data to AIM

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

November 2012

Updated BPMs

TBD

Market Simulation

TBD

Tariff

N/A

Production Activation

Spring 2013 Release (Tentative)

Spring 2013 – Access and Identity Management (AIM)

Page 92

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SLIDE 93

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.

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

Fall 2013 – RIMPR Phase 1 / BCR Mitigation / Bid Floor

Page 93

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SLIDE 94

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

  • ther 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

Fall 2013 – Circular Scheduling

Page 94

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SLIDE 95

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

  • f 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

  • r 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

Fall 2013 – Commitment Cost Refinement

Page 95

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SLIDE 96

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

Fall 2013

Production Activation

Fall 2013 Release

Fall 2013 – Dynamic Transfers

Page 96

slide-97
SLIDE 97

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

Spring 2014 – FERC Order 764 / 15 Minute Market

Page 97

slide-98
SLIDE 98

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

  • f 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

Fall 2014 – Flexible Ramping Product

Page 98

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SLIDE 99

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

Fall 2014 – iDAM (simultaneous IFM and RUC)

Page 99