market performance and planning forum · 2018-02-10 · ferc order 755 li zhou, george angelidis...

Market Performance and Planning

Forum

December 19, 2012

Objective: Enable dialogue on implementation

planning and market performance issues

• Review key market performance topics

• Share updates to 2012-2014 release plans, resulting

from stakeholders inputs

• Provide information on specific initiatives

– to support Market Participants in budget and resource

planning

• Focus on implementation planning; not on policy

• Clarify implementation timelines

• Discuss external impacts of implementation plans

• Launch joint implementation planning process

Slide 2

Proposed Meeting Schedule for 2013

• February 13

• April 10

• June 5

• July 31

• Sept 25

• Nov 20

Agenda

Slide 4

10:00- 10:05 Introduction, Agenda Mercy P. Helget

10:05 – 11:20 Market Analysis Mark Rothleder, Nan Liu,

Guillermo Bautista-Alderete 11:20 – 11:40 Outage Management System Jami Herguth

11:40 – 12:20 Release Updates Janet Morris

12:20 – 1:00 Lunch

1:00 – 2:00 Technical Updates -

FERC Order 755

Li Zhou, George

Angelidis

2:00 – 2:20 Policy Updates Delphine Hou

2:20 – 2:50 Valley Electric Association Modeling Justin Wong

Agenda Agenda Agenda Agenda

Note: Agenda is subject to change.

Market Performance and Quality Update

Market Quality and Renewable Integration

Mark Rothleder

Nan Liu

Guillermo Bautista-Alderete

Slide 5

1. Operation Highlights

2. Market Metrics

• Price volatility and market convergence

• RT energy/congestion imbalance offset

• Convergence bidding

• Exceptional dispatch

• Bid cost recovery

• MIP gap

• Flex-ramp cost

3. Price Corrections

4. Events and developments

• Improvements across most market metrics: price convergence,

exceptional dispatch, BCR, real-time congestion offset.

• Real-time congestion offset cost peaked in August, trended

lower in the following months but remained at elevated levels.

• Lower seasonal load, winter “needle” evening peak and

transmission outages present operational challenges in

December.

• More outages and more constraints modeled in the market

continue to challenge operations and market solutions.

Operation highlights:

DLAP LMP Monthly Average:

Price convergence improved in November

0

10

20

30

40

50

Jan-1

1

Ma

r-1

1

Ma

y-1

1

Jul-1

1

Sep-1

1

No

v-1

1

Jan-1

2

Ma

r-1

2

Ma

y-1

2

Jul-1

2

Sep-1

2

No

v-1

2

$/M

Wh

IFM

HASP

RTD

PG&E

0

10

20

30

40

50

Jan-1

1

Ma

r-1

1

Ma

y-1

1

Jul-1

1

Se

p-1

1

No

v-1

1

Jan-1

2

Ma

r-1

2

Ma

y-1

2

Jul-1

2

Sep-1

2

No

v-1

2

$/M

Wh IFM

HASP

RTD

SCE

0

10

20

30

40

50

60

Jan-1

1

Ma

r-1

1

Ma

y-1

1

Jul-1

1

Sep-1

1

No

v-1

1

Jan-1

2

Ma

r-1

2

Ma

y-1

2

Jul-1

2

Sep-1

2

No

v-1

2

$/M

Wh

IFM

HASP

RTD

SDG&E

DLAP LMP Monthly Average (On Peak)

0

10

20

30

40

50

60

Jan-1

1

Ma

r-1

1

Ma

y-1

1

Jul-1

1

Sep-1

1

No

v-1

1

Jan-1

2

Ma

r-1

2

Ma

y-1

2

Jul-1

2

Sep-1

2

No

v-1

2

$/M

Wh

IFM

HASP

RTD

PG&E

0

10

20

30

40

50

60

Jan-1

1

Ma

r-1

1

Ma

y-1

1

Jul-1

1

Sep-1

1

No

v-1

1

Jan-1

2

Ma

r-1

2

Ma

y-1

2

Jul-1

2

Sep-1

2

No

v-1

2

$/M

Wh

IFM

HASP

RTD

SCE

0102030405060708090

Jan-1

1

Ma

r-1

1

Ma

y-1

1

Jul-1

1

Sep-1

1

No

v-1

1

Jan-1

2

Ma

r-1

2

Ma

y-1

2

Jul-1

2

Sep-1

2

No

v-1

2

$/M

Wh

IFM

HASP

RTD

SDG&E

DLAP LMP Monthly Average (Off Peak)

0

10

20

30

40

50

Jan-1

1

Ma

r-1

1

Ma

y-1

1

Jul-

11

Sep-1

1

No

v-1

1

Jan-1

2

Ma

r-1

2

Ma

y-1

2

Jul-

12

Sep-1

2

No

v-1

2

$/M

Wh

IFM

HASP

RTD

PG&E

0

10

20

30

40

50

Jan-1

1

Ma

r-1

1

Ma

y-1

1

Jul-

11

Sep-1

1

No

v-1

1

Jan-1

2

Ma

r-1

2

Ma

y-1

2

Jul-

12

Sep-1

2

No

v-1

2

$/M

Wh

IFM

HASP

RTD

SCE

0

10

20

30

40

Jan-1

1

Ma

r-1

1

Ma

y-1

1

Jul-1

1

Sep-1

1

No

v-1

1

Jan-1

2

Ma

r-1

2

Ma

y-1

2

Jul-1

2

Sep-1

2

No

v-1

2

$/M

Wh

IFM

HASP

RTD

SDG&E

DLAP LMP Hourly Average in November

0

10

20

30

40

50

60

1 2 3 4 5 6 7 8 9 101112131415161718192021222324

$/M

Wh

IFM

HASP

RTD

PG&E

Hour

0

10

20

30

40

50

60

70

80

1 2 3 4 5 6 7 8 9 101112131415161718192021222324

$/M

Wh

IFM

HASP

RTD

SCE

0

20

40

60

80

100

120

1 2 3 4 5 6 7 8 9 101112131415161718192021222324

$/M

Wh

IFM

HASP

RTD

SDG&E

Monthly price distributions: price volatility continued to

decrease in November.

-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 Nov-12

Pe

rce

nt

of

Re

al T

ime

In

terv

als

-$30 to -$5 -$100 to -$30 -$300 to -$100 <-$300 $250 to $500 $500 to $750 $750 to $1000 >$1000

Monthly average of RTD intervals with insufficient up

ramping capacity declined in November.

0.00%

0.20%

0.40%

0.60%

0.80%

1.00%

1.20%

1.40%

1.60%

1.80%

2.00%

0

20

40

60

80

100

120

140

160

180

Jan

-11

Feb

-11

Mar

-11

Ap

r-1

1

May

-11

Jun

-11

Jul-

11

Au

g-1

1

Sep

-11

Oct

-11

No

v-1

1

De

c-1

1

Jan

-12

Feb

-12

Mar

-12

Ap

r-1

2

May

-12

Jun

-12

Jul-

12

Au

g-1

2

Sep

-12

Oct

-12

No

v-1

2

Pe

rce

nt

of

Inte

rval

s

Co

un

t o

f In

terv

als

5-minute intervals with insufficient upward ramping capability

percent of intervals with insufficient upward ramping capability

Monthly average of RTD Intervals with insufficient

down ramping capacity remained at low level.

0.00%

0.50%

1.00%

1.50%

2.00%

2.50%

3.00%

3.50%

4.00%

4.50%

5.00%

0

100

200

300

400

500

Jan

-11

Feb

-11

Mar

-11

Ap

r-1

1

May

-11

Jun

-11

Jul-

11

Au

g-1

1

Sep

-11

Oct

-11

No

v-1

1

De

c-1

1

Jan

-12

Feb

-12

Mar

-12

Ap

r-1

2

May

-12

Jun

-12

Jul-

12

Au

g-1

2

Sep

-12

Oct

-12

No

v-1

2

Nu

mb

er

of

Inte

rval

s

5-minute intervals with insufficient downward ramping capability

percent of intervals with insufficient downward ramping capability

Real-time energy offset costs increased in November

but remained at relatively low level.

Real-Time congestion offset costs trended lower in recent

months with November concentration of congestion in the

San Diego area.

-10

0

10

20

30

40

50

60

Apr-

09

Ma

y-0

9

Jun-0

9

Jul-0

9

Aug-0

9

Sep-0

9

Oct-

09

No

v-0

9

De

c-0

9

Jan-1

0

Feb

-10

Ma

r-1

0

Apr-

10

Ma

y-1

0

Jun-1

0

Jul-1

0

Aug-1

0

Sep-1

0

Oct-

10

No

v-1

0

De

c-1

0

Jan-1

1

Feb

-11

Ma

r-1

1

Apr-

11

Ma

y-1

1

Jun-1

1

Jul-1

1

Aug-1

1

Sep-1

1

Oct-

11

No

v-1

1

De

c-1

1

Jan-1

2

Feb

-12

Ma

r-1

2

Apr-

12

Ma

y-1

2

Jun-1

2

Jul-1

2

Aug-1

2

Sep-1

2

Oct-

12

No

v-1

2

$M

illio

ns

Congestion Imbalance Offset Energy Imbalance Offset

Exceptional dispatch volume decreased in November,

less than one half percent of total dispatch.

0.00%

0.50%

1.00%

1.50%

2.00%

2.50%

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

2009 2010 2011 2012

Total Exceptional Dispatch as Percent of Load

% o

f To

tal L

oad

Daily exceptional dispatches in MWh – by reason

0

5

10

15

20

25

30

35

401-O

ct

3-O

ct

5-O

ct

7-O

ct

9-O

ct

11

-Oct

13-O

ct

15-O

ct

17-O

ct

19-O

ct

21-O

ct

23-O

ct

25-O

ct

27-O

ct

29-O

ct

31-O

ct

2-N

ov

4-N

ov

6-N

ov

8-N

ov

10-N

ov

12-N

ov

14-N

ov

16-N

ov

18-N

ov

20-N

ov

22

-No

v

24-N

ov

26-N

ov

28-N

ov

30

-No

v

Th

ou

sa

nd

s M

Wh

Pe

r D

ay

Transmission Outage Software Limitation

T Procedure Conditions beyond control of the CAISO BA

System Energy Ramp Rate

Other

Exceptional dispatch to prepare for

post-contingency reduction of SOL

per operating procedures.

Bid cost recovery (BCR) costs decreased in November

and RUC uplifts were still high.

0

2

4

6

8

10

12

14

16

18

20Ja

n-1

0

Fe

b-1

0

Ma

r-1

0

Ap

r-1

0

Ma

y-1

0

Ju

n-1

0

Jul-10

Au

g-1

0

Se

p-1

0

Oct-

10

No

v-1

0

De

c-1

0

Ja

n-1

1

Fe

b-1

1

Ma

r-1

1

Ap

r-1

1

Ma

y-1

1

Ju

n-1

1

Ju

l-1

1

Au

g-1

1

Sep-1

1

Oct-

11

No

v-1

1

De

c-1

1

Ja

n-1

2

Fe

b-1

2

Ma

r-1

2

Ap

r-1

2

Ma

y-1

2

Ju

n-1

2

Ju

l-1

2

Au

g-1

2

Se

p-1

2

Oct-

12

No

v-1

2

$M

illio

ns

IFM RT RUC

Good MIP gap performance in November.

October 1 and 2 low quality

solution due to timeout of

solution

0

10,000

20,000

30,000

40,000

50,000

60,000

70,000

80,000

90,000

100,000

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

/1/1

1

11

/1/1

1

12

/1/1

1

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

/1/1

2

11

/1/1

2

Daily Dollar 30 Day Moving Average

Mip

Ga

p (

$)

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 Nov

2011 2012

Pe

rce

nta

ge o

f N

od

es

Co

rre

cte

d

Data Input Software Tariff Process

Price corrections reduced in November.

Incorrect distribution factors in two

weeks of July caused 70% of

corrections in July Market Software

timed out while

searching for the

solution

Price corrections reduced in November.

Incorrect distribution factors in two

weeks of July caused 70% of

corrections in July Market Software

timed out while

searching for the

solution

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 Nov

2011 2012

Pe

rcen

tage

of

No

de

s C

orr

ect

ed

RTD HASP DA

Flexi-ramp constraint costs continued the downward trend

in November.

0

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 Nov-12

$M

illi

on

s

Monthly Flexi-Ramp Cost

• CAISO Board approved the proposal to modify the real-time

scheduling run transmission constraint relaxation parameter from

$5000 to $1500. Significant increase of transmission constraint

relaxation in real-time this year over 2011.

• Implemented software feature to avoid infeasible manual adjustments

in the real-time market.

• Based on stakeholder feedback of interest, reversed the plan to stop

publishing the monthly market catalog report due to low interests.

• Will reduce the redundancy/duplication of exceptional dispatch

reports.

Events and Developments:

Release Updates

Jami Herguth

Director, Business Solutions

Slide 25

• Changes in the landscape

• ISO is not staffed to delivery OMS with number of

policy changes impacting this area

• Turnover in staffing earlier this year led us to re-

evaluate vendors

• Several vendors now have model-aware OMS

solutions

• Finished Build versus Buy decision pending final vendor

negotiation

Outage Management System (OMS) Update

• Vendor selected for final negotiation is Ventyx/ABB

• Two-month vendor engagement on requirements

beginning in January

• Stakeholder input on generation module received earlier this year

• What was communicated as in-scope remains part of the negotiation

• Objective is to align ISO processes to out-of-the-box

Ventyx/ABB solution as much as possible while meeting

tariff and efficiency requirements

• This activity will conclude negotiations and runs through

the end of March

Outage Management System (OMS) Update

Release Updates

Janet Morris

Director, Program Office

Slide 28

The ISO offers comprehensive training programs

Date Training

December 20 Welcome to the ISO (webinar)

January 8 Introduction to ISO Markets (on-site)

January 9, 10 Market Transactions (on-site)

January 15 Settlements 101 (on-site)

January 16 Settlements 201 (on-site)

January 24 Welcome to the ISO (webinar)

January 31 Introduction to ISO Markets (Houston)

February 1 Settlements 101 (Houston)

Training calendar - http://www.caiso.com/participate/Pages/Training/default.aspx

Contact us - [email protected]

http://www.caiso.com/participate/Pages/Training/default.aspx

mailto:[email protected]

Release Plan – 2012

• Fall 2012 – deployed and activated

• Non-Generator Resources / Regulation Energy Management - Phase 2

• Data Release Phase 3

• 72 Hour RUC

• Transmission Reliability Margin

• Contingency Dispatch Enhancements (RTDD enhancements not activated)

• Regulatory Must Take Generation

• Group Constraint enhancement

• BAPI, OASIS – UI upgrade (does not impact API)

• Replacement Requirement for Scheduled Generation Outages

• Year End 2012

• Settlements 9.07 (12/18/12)

• DB62 (12/19/12)

• Commitment Costs Refinements - Greenhouse Gas Regulation (1/1/13)

• City of Colton activation (1/1/13)

• Valley Electric Association activation (1/3/13)

Release Plan – 2013

• Spring 2013

• MSG Phase 3 deployment

• FERC Order 755 – Pay for Performance

• LMPM Enhancements Phase 2

• Exceptional Dispatch Mitigation in Real Time

• Post Emergency Filing BCR changes / Mandatory MSG

• Flexible Capacity and Local Reliability Resource Retention

• Price Inconsistency Market Enhancements (not including bid floor cap)

• DRS API deployment

• Master File Enhancements Phase 2 (tentative)

• FERC Order 745: Changes to the DR Compensation for PDR

• Access and Identity Management

• CMRI UI upgrade (does not impact API)

• Fall 2013

• RIMPR-Phase 1 / BCR Mitigation Measures / Bid Floor Cap

• Circular Scheduling

• Commitment Cost Refinements (remaining scope)

• Ancillary Services Buy-Back

Release Plan – 2014 (proposed)

• Spring 2014

• FERC Order 764 Compliance / 15 Minute Market

• Dynamic Transfers

• Fall 2014

• Flexible Ramping Product

• iDAM (simultaneous IFM and RUC)

• Subject to further release planning:

• Outage Management System (Scoping phase to start January 22, 2013))

• Enterprise Model Management System

• Subset of Hours

• Flexible Resource Adequacy Criteria and Must Offer Obligation

2012 Release Plan

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


2013 Release Plan



Milestone Date

Application Software Changes

BPM: The purpose of this project is to replace the existing Business Practice

Manual (BPM) Change Management system to improve usability, increase

stakeholder participation, redesign the system architecture and enhance

functionality by leveraging existing SharePoint functionality

BPM Changes None

Business Process Changes Not Applicable

Board Approval Not Applicable

External Training December 12, 2012

Tariff Not Applicable

Production Activation January 7, 2013

BPM Change Management Enhancement Replacement

Fall 2012 Release Deployment Dates

The new deployment and activation dates are as follows:

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

Drop Description DEPLOYMENT ACTIVATION

Revised Revised

Settlements fall release for November

MRI Settlements Application deployment Congestive Revenue Rights (CRR)

11-01-2012 11-05-2012

RRSGO - IRR 11-12-2012 11-12-2012

RRSGO - RAAM 11-27-2012 11-27-2012

1 Master File (MF) and Application Integration Layer 11-20-2012 11-20-2012

2 Application Upgrade Deployment – part 1 FERC 745

12-03-2012 12-03-2012

Application Upgrade Deployment – part 2

CDE RTCD

Group Constraints

12-03-2012 12-04-2012

3 Application Upgrade Deployment – part 3

• Open Access Same-Time Information System (OASIS) –

MRI • Market Participant Portal (MPP)

12-13-2012 See project slides

http://www.caiso.com/Documents/Fall 2012 release - plans



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

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

software vendor and stakeholders

RDT/API Versioning

Generator GRDT 6.5 (and 6.5 in second row of RDT XLS file)

Intertie IRDT 4 (and 4.1 in second row of RDT XLS file)

SLIC SLIC API 4.4.1

Detailed in Technical Specifications to be posted July 23, 2012

Fall 2012 Release – RDT and API Versioning

Fall 2012 Release – Web Service Changes

• 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

of “Wind and Solar Forecasting Data” data

• (Data Release Phase 3) New OASISCRRPublicBid / API Web Service to accommodate query

of “CRR Public Bid Data” data

• (Data Release Phase 3) Update to OASIS OASISReport / API Web Service to accommodate query

of “Aggregated Generation Outage” data

• (Greenhouse Gas) Update to OASIS OASISReport / API Web Service to accommodate query

of “GHG Allowance Index Price” data

• (TRM) Update to OASIS OASISReport / API Web Service to accommodate query

of the Transmission-related reports (Current Transmission Usage, Transmission Interface Usage, ATC)

• SLIC

• New API version ID 4.4.1available

• API versions 4.0, 3.0 and 2.0 also supported

• (NGR-REM) Update to SLIC API External Web Services to accommodate updates/queries

of “NGR-REM” data

• MFRD

• (RMTG) Update to MFRD GeneratorRDT Web Service / API to accommodate updates/queries

of “Regulatory must take maximum (RMTMax)” data -- GeneratorRDT_v20121001

• (MLCA) Update to MFRD IntertieRDT Web Service / API to accommodate updates/queries

of “Marginal Loss Cost Adjustment” data -- IntertieRDT_v20121001

• (GHG) Update to MFRD GeneratorRDT Web Service / API to accommodate updates/queries

of “Green House Gas” data -- GeneratorRDT_v20121001

• (NGR-REM) Update to MFRD GeneratorRDT Web Service / API to accommodate updates/queries

of “NGR-REM” data -- GeneratorRDT_v20121001

Milestone Date


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 [email protected]

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

Milestone Date


MPP: Load Distribution Factors (DA), Shift Factors (DA, HASP,

RTD), Transmission Limits (DA, HASP, RTD)

OASIS: Aggregated Generation Outages, Wind and Solar Forecasts,

CRR Public Bids

BPM Changes Market Instruments

Business Process Changes None

Board Approval May 17, 2011

External Business Requirements March 19, 2012

NDAs/AARFs NDA posted October 25, 2012

NDAs/AARFs must be returned by December 3, 2012

OASIS/ CMRI Technical Specifications July 19, 2012

Updated BPMs Posted on October 11, 2012; Publish by November 30, 2012

Market Simulation Sept 24 – Oct 5, 2012 (OASIS), Oct 1 – Oct 5, 2012 (MPP)

Tariff Tariff filed October 5, 2012

Approval received December 10, 2012

Production Activation Trade Date 12/11/12; consistent with our tariff, provision of 30

days to post this data, data will be posted back to 12/11/12

upon deployment

Fall 2012 – Data Release (Phase 3)

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


External Business Requirements September 23, 2010 and September 1, 2011

(BPM synch revision)

Technical Specifications Not Applicable

Updated BPMs October 28, 2011

Market Simulation scenarios July 30, 2012

Market Simulation September 18-21

Production Activation Trade Date TBD

Fall 2012 – 72 Hour RUC

Milestone Date

Application Software Changes OASIS –Three TRM component line items added.

BPM Changes Market Instruments, Market Operations, Full Network Model, Reliability

Requirements, Congestion Revenue Rights, Acronyms and Definitions

Business Process Changes Manage Real-Time Interchange Scheduling

Board Approval March 22, 2012

External Business Requirements April 9, 2012

Technical Specifications July 19, 2012

Updated BPMs July 31, 2012

Market Simulation September 24-28, 2012

Tariff Filed April 2012

Approved June 2012

Production Activation 12-17-2012

Fall 2012 – Transmission Reliability Margin

Milestone Date


Master File: Two new modifiable fields in the Generator RDT.

• A yes / no flag to indicate whether a resource has a Greenhouse gas (GHG)

compliance obligation

• GHG emission rate / factor for resources that have a GHG compliance obligation

SIBR: (CAISO internal) Changes to calculation of Generated Bids, Startup (SU) and

Minimum Load (ML) Costs for resources that have a GHG compliance obligation.

OASIS: A new report to show the GHG Allowance index price used in the calculation

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

BPM Changes Market Instruments – 11/9/12

Business Process Changes Manage Reliability Requirements

Board Approval May, 2012

External Business

Requirements June 29, 2012


Market Simulation September 24–October 12, 2012

Technical Specifications July 23, 2012

(Master File Generator Data API, OASIS Report GHG Allowance Price)

Tariff Filing – 10/29/12

RDT Submission

The RDT contains the GHG_COMPLIANCE_OBLIG flag and the EMISSION_RATE field. MPs will

update the flag to Y and provide an emission rate for their covered resources and submit the RDT

RDTs must be submitted by Dec 21 to have their updates in for 1/1. Anything after 12/21 will be

accepted just not available on 1/1.

If the GHG_COMPLIANCE_OBLIG flag is set and the EMISSION_RATE is not submitted the RDT

will be rejected.

Production Activation Trade Date January 1, 2013

Fall 2012 – Commitment Cost Refinements - GHG

Fall 2012 Release – DR Net Benefits Test FERC Order 745 Compliance – DR compensation in organized wholesale

Markets

Milestone Date


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

Milestone Date


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


Business Process Changes Manage Real-Time Contingency Dispatch


External Business Requirements May 8, 2012

Updated BPMs RTCD-6/15/12 (Complete), RTDD-8/17/12 (Complete)

Tariff Filed October 10, 2012

Requesting FERC approval by Dec 2012

Technical Specifications July 20, 2012 (ADS.caiso.com API)

Note: Will include ADS screen-shots

Market Simulation September 20, 2012 – October 5, 2012

Production Activation RTCD-12/04/12 RTDD- subject to FERC response

Fall 2012 – Contingency Dispatch Enhancements

Milestone Description/Date


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)



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 Trade Date 12/11/12

Fall 2012 – Regulatory Must Take Generation

Milestone Date


Database Model: In order to distinguish the resources with different priority levels

within the same group, a new column will be introduced into

EMM_SCUC_IMM_GROUP_MEMBERS. New rows will be added to existing tables

EMM_SCUC_IMM_GROUP_CONSTRAINTS and potentially

EMM_SCUC_INPUT_GR_CNSTR_STATUS.

Master File: Population from Masterfile will be modified to account for two new

constraint types populated to EMM_SCUC_IMM_GROUP_CONSTRAINTS

Technical Bulletin May 2012

Business Process Changes N/A

Production Activation 12/04/2012

Fall 2012 – Group Constraints - (Recognition of Order of

Startups between Grouped Resources Enhancement)

Milestone Date

Application Software Changes IRR and RAAM

BPM Changes BPM Posting October 2012: Outage Management & Reliability Requirements

Settlements BPM Posting November 2012: Not applicable due to FERC Ruling

Settlements (2 new charge codes): Not applicable due to FERC Ruling

Business Process Changes

Manage Generation Outages: • RA Outage Management Process (new)

Manage Reliability Requirements: • Annual Monthly RA Process (new)

Settlements NA

Board Approval July 12, 2012

External Business Requirements July 16, 2012

Templates September 20, 2012 New template posted

September 24, 2012 Call about use of new template

Training October 19, 2012

December 14, 2012

Market Simulation November 5, 2012

Tariff September 20, 2012 Tariff Filed; order received

Compliance Filing December 19, 2012

Production Activation

November 12, 2012 Open for submittals

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

RAAM is deployed on November 27, 2012

February 2013 T-45 RA Plans and Supply Plans due Dec 18, 2012

RA Resubmittals of Cures Required December 20, 2012

Fall 2012 – Replacement Requirements for Scheduled Generation Outages

2012 Year End Activation

Valley Electric

Association Milestone

Date

Application Software Changes N/A

BPM Changes N/A

Board Approval September 11, 2012

Market Simulation December 10 - 14, 2012


City of Colton

Milestone

Date

Application Software Changes N/A

BPM Changes N/A

Board Approval September 11, 2012

Market Simulation N/A


RDT Versioning

Generator V7.0

The ISO will deprecate the current production version of the GRDT

with the 2013 Spring Release and will only support a single

version which includes CERT_REG_DOWN and CERT_REG_UP,

no longer supporting CERT_REG. The ISO will only be supporting

v7.0 (previously v6.5) of the GRDT UI and V1 (previously

v20121001) of the GRDT API.

IRDT

The ISO will continue to support 2 versions of the IRDT which is

not being affected by the Spring Release.

Spring 2013 Release – RDT and API Versioning Alert

Milestone Date


The Flexible Capacity and Local Reliability Resource Retention (FLRR) will

allow the ISO to pursue tariff changes that will ensure the ISO has sufficient

backstop procurement authority to address capacity at risk of retirement that

the ISO identifies as needed up to five years in the future to maintain system

flexibility or local reliability.

MasterFile: Designate FLRR resources and input/store the going-forward

costs; Define FLRR cost allocation Areas.

Settlements: New Charge Codes for FLRR payments and allocations.

POTOMAC/RLC: Energy: LMP – Default Energy Bid, Start up and Minimum

Load Costs, Ancillary Services Costs

BPM Changes Reliability Requirements, Settlements & Billing

Business Process Changes Manage Entity & Resource Maintenance Updates (MMR LII), Manage Long

Term Transmission Planning (DI LII), Manage Market Billing & Settlements

(MOS LII)

Board Approval September 2012

External Business Requirements January 2013

Updated BPMs January 2013

Market Simulation February 2013

Tariff Filing December 12, 2012

Production Activation FLRR Designation – April 1, 2013

Settlements, Master File, RLC – April 1, 2013

Spring 2013 - Flexible Capacity and Local Reliability Resource Retention

Milestone Date


Master File: System must be extended to allow the registration of minimum

up time (MUT) or minimum down time (MDT) on a group of MSG

configurations. Registrations would be submitted to the ISO via a separate

registration form.

DAM/RTM: System must be able to recognize the MUT and MDT constraints

on a group of configurations (as registered in the Master File) during the

optimization.

BPM Changes Market Instruments, Market Operations


Board Approval Not Applicable

External Business Requirements June 15, 2012 (updates made to document)

Registration Form Draft Available 7/13/12 (subject to change before Market Simulation)

Market Simulation February 11-15, 2013

Tariff Not Applicable

Production Activation May 1, 2013

Spring 2013 – MSG Enhancements (Phase 3)



SLIC – Provide a regulation outage flag CMRI : provide DA and RT regulation

up/down mileage price and awards DAM/RTM: include mileage bids and

requirements into the optimization and generate mileage price and awards

Master File: regulation certification based on 10 min ramping capability

OASIS: provide DA regulation up/down mileage price, system mileage

multipliers, system mileage requirement, actual system mileage, historical

mileage bids, historical resource mileage multipliers Settlements : calculate

mileage payment, mileage cost allocation and GMC for mileage bids SIBR:

receive and validate regulation up/down mileage bid

BPM Changes Market Operations 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


External Business Requirements June 7, 2012

December 10, 2012 (update)

Technical Specifications Nov 16, 2012- MasterFile technical specifications, SIBR rules, charge code list

Dec 21, 2012 – OASIS, CMRI and SLIC, technical Specifications

Jan 8, 2013 – Settlements configuration guides

External Training Jan 23, 2013

Market Simulation Feb 5, 2013 registration deadline Dec 19, 2012

Product Activation May 1, 2013 (Extension approved by FERC 12/3/2012)

Spring 2013 – FERC Order 755 pay for performance

Milestone Date


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]


Market Instruments

Business Process Changes Real Time Market & Grid

Manage Real Time Market- After Close of Market

Manage Real Time Operations- Generation Dispatch


External Business Requirements November 1, 2012

OASIS/ CMRI Technical Specifications December 21, 2012

Updated BPMs March 2013


Tariff Post Draft Tariff December 18, 2012

Stakeholder Comments and Call January 2013

FERC filing targeted for February 2013

Production Activation Spring Release 2013 (May 1, 2013)

Spring 2013 – LMPM Enhancements (Phase 2)

Milestone Date


IFM/RTM:

• A default competitive constraint list will be calculated based on the most

recent 60 days in the RTUC run where DCPA is calculated and deemed

competitive 75% or more of the instances where the constraint was binding;

unless they meet the competitive criteria with exception to path 15 and path

26. The frequency of update will be based on ISO specified parameter.

• Will use the default competitive constraint list as “back-up” in the event

that DCPA within the real time market fails to produce valid set of path

designations.

• Will compare the constraint received for the exceptional dispatch with the

default competitive constraint list to determine the type to mitigate pricing.


Business Process Changes Manage MQS

Board Approval December 14 , 2012

External Business Requirements TBD



Tariff Post Draft Tariff December 18, 2012

Stakeholder Comments and Call January 2013

FERC filing targeted for February 2013

Production Activation Spring Release 2013 (May 1, 2013)

Spring 2013 – Mitigation for Exceptional Dispatch in Real

Time (Combined with LMPM P2)

Milestone Date


Master File: Additional MSG Configuration registrations need to completed

by Spring Release 2013.

Reporting: Monthly Market Reports incorporating greater granularity in

reporting BCR components have been made available.

SAMC: Requires a tune-up on formulas to determine the ON criteria for

resources, and the eligibility for Bid Cost Recovery.

BPM Changes Market Instruments; Settlements & Billing


Board Approval Feb 16, 2012

External Business Requirements Dec 19, 2012

Updated BPMs TBD

Market Simulation TBD

Tariff TBD

Production Activation Spring 2013

Spring 2013 - Post Emergency BCR Filing / Mandatory MSG

Milestone Date


IFM/RTM: - Use both MW awards and clearing prices from the pricing run - Use ANode prices for settlements of bids at default load aggregate

points and trading hubs, contingent upon the ISO ability to generate an Anode for the real-time markets.

BPM Changes Market Instruments; Market Operations


Board Approval November 1, 2012

External Business Requirements December 2013



Tariff TBD

Production Activation Spring 2013 Release

Spring 2013 – Price Inconsistency Market Enhancements

Milestone Date


The goal of the AIM project is to improve upon the existing approach for

establishing, updating and terminating access to applications as well as

providing visibility (transparency), ease of use and self-service where

appropriate to POCs (Points of Contact), internal ISO users, business units

and IT to manage this process from end to end.

AIM: New system with UI and workflow

BPM Changes Congestion Revenue Rights; SC Certification and Termination; Candidate

CRR Holder; Definitions and Acronyms

Business Process Changes IT Access Mgmt. - Certificate based application access; Metering systems

access

Board Approval N/A

External Business Requirements December 2012

Updated BPMs TBD


Tariff N/A

Production Activation Spring 2013 Release (Tentative)

Spring 2013 – Access and Identity Management (AIM)

Milestone Date


IFM/RTM: Energy Bid Floor to -$150/MWh

MQS:

• Modify MLC calculation and cost allocation rules.

• Change DA MLC determination

• Program PUIE calculation (may need to change MQS energy algorithm)

• Split netting between DA and RT markets.

Settlements:

• Modify and build up to 12 charge codes to implement new BCR netting

rules and MLC.

• Program PUIE (persistent UIE) calculation.

• Program new RT PM (performance metric) calculation.

• Offset DA MLC by MLE revenues.

SIBR:

• SIBR rule changes will be needed to change the bid floor from -$30 (soft)

to -$150 (hard).

BPM Changes Settlements & Billing, Market Operation

Business Process Changes Manage Billing and Settlements, Market Performance

Board Approval Bid Floor and BCR netting: December 15-16, 2011

BCR Mitigation Measures: December, 2012


Updated BPMs TBD


Tariff TBD

Production Activation Fall 2013

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

Milestone Date


CAS: Identify the circular schedules MW, import/export resource IDs for the

single e-tag, with source/sink at the same BAA; the BAA could be CAISO or

other BAA; Exclude dynamic, DC segment, open intertie, Wheeling through for

load.

CRR Claw Back/MQS: Identify the SC’s affiliation for single SC and circular

schedule MW. Build new rule of calculate value the claw-back CRR in dollars.

Settlement: Identify the SC’s affiliation for single SC. Identify the circular

schedule Import applicable IFM and HASP scheduled MW. Build Settlement

rule the settle the import schedule at lower LMP of Import/export. Circular

schedule is not eligible for BCR for the interval.

BPM Changes Market Operations, Market Instruments, Settlements & Billing

Business Process Changes Manage Interchange Scheduling, Manage MQS, Manage Billing and

Settlements



Updated BPMs TBD


Tariff TBD

Production Activation Fall 2013

Fall 2013 – Circular Scheduling

Milestone Date


Masterfile: Creation of new field to capture resource specific characteristics.

Settlements: Operational Flow Orders, NOx, and Sox penalties must be

submitted ex post under circumstances attributable to exceptional dispatch

and real-time commitments. These costs will be included in a re-evaluation

of the real-time BCR calculation for that day with the Operational Flow

Orders (OFO) costs added into the calculation of the generator’s net shortfall

or surplus over that day. Must establish an interface in which Market

Participants can enter data to flow directly to Settlements.

BPM Changes Market Instruments

Billing & Settlements

Business Process Changes Manage Reliability Requirements

Board Approval May 2012


Updated BPMs TBD


Tariff TBD

Production Activation Fall 2013 Release

Fall 2013 – Commitment Cost Refinement



SLIC: Operators have the ability to manually force a buy back due

to resource or transmission constraints. These manually forced buy

backs will be compiled in a new SLIC log which shall include the

modified AS quantity, interval that the buy back is applied and

reason for manual buy back. .

Settlements: Settlement will need to map to the new SLIC

payload. Impacted 14 Charge Codes related ancillary services.

BPM Changes

Settlements & Billing;

Business Process Changes Manage Billing and Settlements



Technical Specifications TBD

Market Simulation Fall 2013


Fall 2013 – AS Buy Back



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


External Business Requirements June 8, 2012


Market Simulation Spring 2014


Spring 2014 – Dynamic Transfers


Application Software Changes TBD

BPM Changes TBD

Business Process Changes TBD



Board Approval May 2013



Spring 2014 – FERC Order 764 / 15 Minute Market



ADS: Send Flexible Ramping Up/Down Awards to Market Participants.

CMRI : Report Flex Ramp Up/Down Awards to Market Participants.

DAM/RTM: Co-optimize Energy Ancillary Services and Flexible Ramping

up/down. This optimization is subject to Flexible Ramping requirements and

existing constraints.

OASIS: Show aggregated Flexible Ramping capacity awards, requirements and

marginal prices.

Settlements: Settle Flexible Ramping payment at marginal price in Day Ahead

and Real Time markets Add no pay and cost allocation for Flexible Ramping.

SIBR: Include Flexible Ramping bidding capability and relevant validation rules

of bid cap, self provision.

BPM Changes Market Operations; Market Instruments; Settlements & Billing; Definitions &

Acronyms.

Business Process Changes Maintain Day Ahead Process, Real Time Process, Manage Billing and

Settlements



Board Approval Fall 2013



Fall 2014 – Flexible Ramping Product


Application Software Changes TBD

BPM Changes TBD

Business Process Changes TBD



Board Approval TBD



Fall 2014 – iDAM (simultaneous IFM and RUC)

Technical Updates

Li Zhou, Senior Advisor

George Angelidis, Principal

Power Systems Technology Development

Mandatory MSG Transition

• To facilitate a smooth transition from non MSG to MSG,

CAISO proposes,

– When applicable, use a Spring outage maintenance

period and convert in the middle of period.

Questions/Answers

• CAISO has presented NGR market simulation results

and FERC order 755 examples in last MPPF meeting

– Questions/Answers

• Questions/Answers for Fall 2012 and Spring 2013

projects

Policy Update

Delphine Hou

Market Design and Regulatory Policy

Slide 71

Market initiatives going to the Board for approval

Initiative Board Presentation

FERC Order 1000 (Inter-regional) March

Administrative Pricing Rules May

FERC Order 764 Market Changes May

Market design initiatives coming soon (slide 1 of 2)

• Flexible RA Resource Criteria and Must Offer

Requirements

– Phase I starting tomorrow

– Phase II targeted to start Q2 2013

• Marginal Loss Surplus Allocation

– Targeted to start Q1 2013

• Expanding Metering and Telemetry Options


• Multi-Stage Generator Bid Cost Recovery


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 being considered:

• Priorities from Stakeholder Initiatives Catalog process:

− Address transient price spikes, real-time imbalance

energy offset / real-time congestion offset

− Additional constraints, processes or products to

address exceptional dispatch (30 minute reserve

capacity)

− Multi-year forward reliability capacity pricing

mechanism

− Use-limited must offer requirements and standard

capacity product enhancements

− Extended pricing mechanism

Valley Electric Association Modeling Information

Justin Wong

Market Settlement Design Analyst, Market Settlement

Design and Configuration

Valley Electric Association Transition

• VEA system integrated into CAISO BAA

– January 3rd, 2013

• Four new lines of interconnection

– Amargosa – Sandy

– Jackass Flats – Lathrop

– Northwest – Dessert View

– Mead – Pahrump

• Two new scheduling points

– AMARGO

– NWEST

VEA Market Constraints New Constraints

1) AMARGO_MSL: • +/-25 MW limit for AMARGOSA-SANDY.

2) NWEST_MSL: • +/-315 MW limit for JACKASS FLATS-

LATHROP and NORTHWEST-DESERT VIEW

aggregate scheduling point.

3) MEADVEA_BG: • +/- 159 MW limit for MEAD-PAHRUMP.

4) VEA_MSL: • Limits schedules to not exceed the

entitlement transmission capacity of the

Mead-Pahrump line.

• The limit shall be dynamic depending on

VEA’s hourly load forecast.

• Operating limits:

Import: 159 MW + VEA load forecast.

Export: 159 MW – VEA load forecast.

VEA Market Constraints

Modified Constraints

MEAD_MSL

Currently the MEAD_MSL consists of four lines with

limits as follows:

• Camino-Mead 1&2 230 kV +/- 320

• Eldorado-Mead 1&2 230 kV +/- 1,140

New WALC intertie:

• New Mead-Pahrump 230 kV +/- 159

New MEAD_MSL (sum of 5 lines)

Limit +/-1619

ADLANTOVICTVL-SP_MSL.

Currently the ADLANTOVICTVL-SP_MSL is made up

of the following lines

• Sylmar-AC 230 kV +/- 1600

• Victorville-Lugo 500 kV + 2,400/-900

• Camino-Mead 1&2 230 kV +/- 320

• Eldorado-Mead 1&2 kV +/-1,140

New WALC intertie:

• New Mead-Pahrump 230 kV +/- 159

New ADLANTOVICTVL-SP_MSL

Limit +5,219/-3,719

VEA Diagram Legend

Substation Voltage level

(TNAME)

Substation Voltage level

MSL – Market

Scheduling Limit

Connection of

Substations

CAISO Boundary

BG – Branch Group

VEA Market Model Diagram

NV Energy Balancing Authority

WALC Balancing Authority

CAISO Balancing Authority

Mead S 230 kV

(MEAD230)

Amargosa 138 kV

(AMARGO)

NWEST 230 kV

(NWEST)

Jackass F 138 kV

(NWEST)

Camino 230kv

Pahrump 230 kV

Mead 230 kV

Psuedo Bus

Camino 230kv

VEA

VEA_MSL

Import = 159 + VEA Load Forecast

Export = 159 – VEA Load Forecast

NWEST_MSL

-315/+315

AMARGO_MSL

-25/+25

MEAD_MSL

-1,619/+1,619

ADLANTOVCTVL-SP_MSL

-5,219/+3,719

MEADVEA_BG

-159 / +159

MEADELDORD_BG

-1,140 / +1,140

New Scheduling Points

Special tagging for scheduling purposes only.

Schedule’s (import/export) at a VEA scheduling point (NWEST or

AMARGO), shall tag their energy schedule through MEAD.

• Import path:

NEVP(NWEST/AMARGO) - SP15 - MEAD(WALC) – SP15

• Export path:

SP15 – MEAD(WALC) – SP15 – NEVP(NWEST/AMARGO)

http://www.caiso.com/Documents/CaliforniaISOTaggingTemplates.xls

http://www.elabs7.com/c.html?ufl=9&rtr=on&s=lgl3,z9ls,7k2,j9lh,fb1e,e08x,ebl1

http://www.elabs7.com/c.html?ufl=9&rtr=on&s=lgl3,z9ls,7k2,j9lh,fb1e,e08x,ebl1