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California ISO – Internal Use Only

2014 Spring Release - Settlements

Cynthia Hinman

California ISO

The information contained in these materials is provided for general information only and does not constitute legal or regulatory advice. The ultimate

responsibility for complying with the ISO FERC Tariff and other applicable laws, rules or regulations lies with you. In no event shall the ISO or its employees

be liable to you or anyone else for any decision made or action taken in reliance on the information in these materials.


What is in the Spring 2014 release for settlements?

FERC Order 764 and RI-MPR Phase 1

Establishment of the Fifteen Minute Market

(FMM)

BCR Netting & Mitigation

Lower Energy Bid Floor


FERC Order 764 - Introduction

Background, Definitions


FERC Order 764 - overview

• “To remove barriers to the integration of variable energy

resources:

1. Offer an option to schedule energy with 15-minute

granularity; and,

2. Require variable energy resources to provide

meteorological and forced outage data for the

purpose of power production forecasting.”

ISO PUBLIC – © 2014 CAISO

FERC Order 764 compliance

• FERC 764 provided ISO with an opportunity to enhance

its markets

– Introduction of a full 15 minute energy market for

intertie and generation

– Resolve existing real-time imbalance energy offset

issues resulting from HASP and RTD optimizations

– Address convergence bidding issues on the interties.

– Meet the needs of VERs to self-schedule its’ forecasts

closer to financially binding interval


Time interval definitions changes

• Daily, hourly or monthly charge codes, where applicable, will utilize same

input bill determinant

• Variable description in BPM will only maintain those attributes definition

which add value to the description

• Attribute definitions will be maintained in the SaMC Design Standard and

Convention document

Current Term Current Definition Revised Term Revised Definition

Ancillary Service Interval

The 15 min interval for

HASP or RT for Trading

Hour. FMM Interval

The 15-min time period associated with

the relevant Bill Determinant or

Settlement Amount

Dispatch Interval

The time interval at

which ISO Dispatch

instructions are issued

corresponding to a

particular Settlement

Interval and Trading Hour

Settlement Interval

The five-minute time period over which

the ISO settles cost compensation

amounts or deviations in Generation and Demand in RTM.

Settlement Interval

The 10-min time period

associated with the

relevant Bill Determinant or Settlement Amount

Ten Minute Interval

The 10-min time period associated with

the relevant Bill Determinant or Settlement Amount.


“Settlement Interval” redefinition

• This means:

– Meter values are required at 5-minute granularity

– Real-time based charge codes will settle at the new

settlement interval definition

– Real-time allocation charge codes will be converted to

reflect new settlement interval definition

– Time interval definitions have also been redefined.

“The five-minute time period over which the ISO settles

cost compensation amounts or deviations in Generation

and Demand in RTM” (RTM = FMM and RTD)


FERC Order 764

Timelines and processes


Hourly Real-Time Processes

Market 1 Market 2 Market 3 Market 4

T-75: Real-Time Bid Submission Deadline

T-45: Results from Hourly Process to Accept Block Schedules Published

T-20: Intertie Hourly Transmission Profile and

Energy Schedule for Market 1 E-Tag Deadline

T

T = Start of the Hour

T-37.5: Start of Market 1 Optimization


15-minute market (FMM) process

• ISO will leverage the existing real-time unit commitment

process (fifteen-minute market) to co-optimize energy

schedules and ancillary service awards

– Financially binding 15-minute energy schedule for

imports, exports, and generation

– Financially binding ancillary service awards for

specific imports and generation

– FMM will be cleared against ISO real-time demand

forecast.


15-Minute real-time process

Financially Binding

Market 2

T-5: Market 2 Energy Schedule E-Tag Deadline

T-22.5: Self Schedule Changes for Market 2

T-7.5: Market 2 Energy Schedule Awards

T

T-22.5: Market 2 Optimization Starts

37.5 Minutes

20 Minutes



FMM energy settlement – charge code 6460

• Incremental/decremental to day-ahead schedule

• Comprised of FMM Optimal Energy, FMM Minimum Load Energy,

FMM Rerate Energy, FMM Pumping Energy, and FMM Exceptional

Dispatch Energy

• FMM Exceptional Dispatch Energy Uplift will be settled in charge

codes 3303, 6460, 6482, and 6488 dependent upon Exceptional

Dispatch Type

• FMM Optimal Energy and FMM Minimum Load Energy will be

eligible for bid cost recovery (like existing RTD)

• Financially binding settlement


5-Minute real-time dispatch

• No changes to 5-minute real-time dispatch timelines.

Financially

Binding

Market 1 Market 2

T+15RTD 4RTD 2 RTD 6

T+7.5: RTD 4 Optimization Starts

T+12.5: RTD 4 Dispatch, RTD 5 Optimization Begins

T+15

RTD 3 RTD 5



5-minute real-time dispatch settlement

• Key change - Incremental/decremental to FMM schedules for

Imports, Exports, and Generation

• Comprised of RTD Optimal Energy, RTD Minimum Load

Energy, RTD Rerate Energy, RTD Pumping Energy, Standard

Ramping Energy, Ramping Energy Deviation, Residual

Energy, MSS Energy, Regulation Energy, Operational

Adjustment, and RTD Exceptional Dispatch Energy

• Will settle at the applicable settlement interval (5-Minute) RTD

Price

• Will settle in Charge Code 6470 – IIE Settlement

• RTD Optimal Energy, RTD Minimum Load Energy will be

eligible for bid cost recovery


FERC Order 764

Settlement changes and examples


FMM ancillary service settlement – Charge codes

6170, 6270, 6570, 6670

• 15-minute ancillary service awards are incremental to

day-ahead market

• Settle at the real-time ancillary service marginal price

(ASMP)

• HASP ancillary service calculations and charge codes

will be terminated

• Dynamic transfer will introduce a resource specific

ancillary service marginal constraint price for settlement

of AS congestion


UIE and Operational Adjustments

• Uninstructed imbalance energy for generating and

dynamic resources will be calculated as a single tier

quantity (instead of two tiers) and settled at the

applicable RTD price

• Uninstructed imbalance energy for non-participating load

will be calculated as a single tier quantity and settled at

weighted average hourly real-time market price • The weighted average price will be based upon the four FMM prices,

the twelve RTD prices, the deviations between DAM load to FMM

forecast, and the deviation between FMM forecast and RTD forecast.

• Operational Adjustment will be settled at RTD Price


Uninstructed imbalance energy – charge code

6475

• Calculated as the difference between the meter read and

the Total Expected Energy

– payment for positive UIE – surplus energy

– charge for negative UIE – replacement energy


Charge Code 6475 – Uninstructed Imbalance Energy

– OLD PROCESS

Slide 19

Dispatch Instruction - OE

DAM Schedule – DASSE

Meter Read

5 10

120

0

MW

100

80

UIE

Total

Total uninstructed imbalance energy

Min

20 MWh in Tier 1, RT

20 MWh in Tier 2, DA


Charge code 6475 – Uninstructed Imbalance Energy

Slide 20

Dispatch Instruction - OE

DAM Schedule – DASSE

Meter Read

5 10

120

0

MW

100

80

UIE

Total

Total uninstructed imbalance energy

Min

40 MWh in RT


Charge code 6470 - Operational adjustment example

21

DA schedule

Tag amount or

meter

DAM LMP = $55.00

RT Price = $65.00

If tagged MW is below DA schedule instruction

OA will be assessed the RT LMP in CC 6470

100

90

CC 6011 = (-1) * MW * $ = payment

CC 6470 = (-1) * MW * $ = charge

*Simplified example of CC 6470

OA = Tag/meter – DA

schedule

OA = 90MW – 100MW

OA = -10MW

MW

100 55.00 ($5,500.00)

-10 65.00 $650.00


Intertie schedules decline charges – CC 6455

• Will apply to intertie schedules not delivered or variable

energy resources (VER) forecasts that are overstated

• Calculated on a monthly basis

• This proposed intertie schedule decline charge will apply

to the different hourly block scheduling options:

• Hourly block

• Hourly block with schedule change

• Variable energy resource using is own forecast


Intertie decline charge example

• Please turn to the “Spring 2014 Release Charge Code

6455 – Intertie Schedules Decline Charges Example”

document


Other changes to settlements

• HASP inter-SC trades, energy, and ancillary service

settlement are to be terminated

• FMM inter-SC trades will settle at the FMM IST Price –

CC 6371

• Convergence bidding for internal nodes and intertie

scheduling points will settle at FMM Prices – CC 6473


Previous convergence bidding real-time settlement led

to market uplifts

Virtual supply

sold

Virtual demand

bought Day-

ahead

5-min

RTD

Hourly

HASP

Virtual supply

bought

Virtual

demand sold

• Cost to market = virtual

demand sold at RTD price –

virtual supply bought at

HASP price

• Convergence bid cost paid

by uplift charge to load

• Uplift charge to load also

produced by HASP/RTD

dispatch and price

differences

Interties Internal

nodes


Proposed design clears all convergence bids at 15-

minute price

Virtual supply

sold

Virtual demand

bought Day-

ahead

5-min

RTD

15-min

Market

Virtual supply

bought Virtual

demand sold

• No convergence bids

between 15-min market

and RTD

• Increased consistency

between 15-min and day-

ahead will reduce other

uplift charges to load

• Position limits will phase in

intertie convergence

bidding

Interties Internal

nodes


Transition plan to phase in convergence bidding

functionality on the interties.

Convergence bidding position limits on the interties enables ISO to address

any unanticipated market issues prior to adding complexity of convergence

bidding:

– Significant real-time market changes to scheduling and pricing of intertie

transactions.

– Energy Imbalance Market in Fall 2014 will expand real-time market to

include other balancing authorities.

Position Limit Duration

0% of intertie capacity Implementation to 12 months

5% of intertie capacity 12 to 20 months



No Limit 28 months


Convergence bidding – virtual supply awards

• The ISO will charge each SC with virtual supply awards

at an eligible PNode or eligible aggregated Pnode:

– an amount equal to the simple average of the four

FMM LMPs for the applicable trading hour at the

eligible PNode or eligible aggregated PNode

multiplied by the MWhs of virtual supply awards


Convergence bidding – virtual demand awards

• The ISO will pay each SC with virtual demand awards at

an eligible PNode or eligible aggregated Pnode:

– an amount equal to the simple average of the four

FMM LMPs for the applicable trading hour at the

eligible PNode or eligible aggregated PNode

multiplied by the IFM MWhs of virtual demand awards


RI-MPR Phase 1

BCR netting, BCR mitigation measures, & mandatory MSG


RI-MPR Changes

• Lower the energy bid floor

– Currently -$30/MWh

– Spring release -$150/MWh

– Manage over-generation more efficiently


RI-MPR Changes

• Bid cost recovery (BCR)

– Currently BCR netted over the entire day, all

markets

– Spring release - day-ahead BCR amounts

netted separately from RUC/real-time BCR

amounts

– Spring release - new mitigation measures to

address potential adverse behavior due to

new netting methodology

CMRI - 5 new or enhanced reports related to RI-MPR

changes


Quick recap of BCR

• Financial mechanism to ensure market participants are

able to recover eligible bid costs

• Three part energy bid:

– start-up cost (fixed cost)

– minimum load costs (fixed cost)

– transition costs (fixed cost)

– energy

• BCR uplift when eligible bid costs exceed eligible revenues


BCR changes due to RI-MPR

• IFM BCR no longer netted with RUC/RTM BCR

– Separate BCR uplift settlement for IFM (CC 6630) and combined

RUC/RTM (CC 6620)

• RT BCR payments no longer reduced by IFM revenues

above bid costs

– Incentive for economic bids into RTM

– Netting separation may cause potential adverse market behavior

• BCR Mitigation Measures

– Address IFM/RTM-RUC market separation, and current adverse

market behavior

• RTM energy for BCR includes both FMM &RTD energy

as part of FERC Order 764 enhancement


BCR mitigation measures – netting methodology

Bid costs - Market revenues

•Start-up

•Minimum load

•Transition

•Energy bid: awarded energy

* energy bid price

•Ancillary Services: awarded

AS * AS bid price

•Minimum load: minimum load

energy * LMP

•Energy: awarded energy * LMP

•Ancillary Services: awarded AS *

ASMP

BCR uplift will occur when eligible bid costs exceed eligible revenues

Bid costs - Market revenues = Net market amount


BCR uplift amount for the trading day =

IFM Net Amount

Plus

RUC Net Amount

Plus

RTM Net Amount

If shortfall exists, eligible for BCR

Bid cost recovery settlement methodology


BCR uplift amount for the trading day =

IFM Net Amount

Plus

RUC Net Amount

Plus

RTM Net Amount


Bid cost recovery settlement methodology



Stays the same What’s new

Determining eligibility Modified day-ahead MEAF

calculation

Evaluate performance Performance metric in real-time

Net bid costs and market revenues

per market

RUC calculated in real-time

Persistent deviation metric

BCR mitigation measures – no netting methodology


BCR persistent deviation metric – highlights

• Used to mitigate energy cost basis in BCR as a

consequence of persistent deviation

• Targets deviations that can be used to inflate BCR

without changing the existing bid cost recovery design

when dispatch is not followed


• Modified DA Metered Energy Adjustment Factor

(DA MEAF)

• Real-time Performance Metric (RT PM)

• Persistent Deviation Metric (PDM)

• BCR qualification for start-up, shutdown and

MSG transition

BCR mitigation measures


Modified day-ahead MEAF


Modified day-ahead MEAF

• DA MEAF = min 1,Meter−DA MLE −Reg

min{TEE,DASE}−DA MLE

Apply if |Meter – Reg – min(DASE, TEE)|<= PM tol band

• PM tol band =

max5MWh

12,

0.03∗Pmax

12+ Ramping Tolerance


Ramping tolerance


Real-time performance metric


Real-time performance metric

• Performance Metric (PM) =

min 1,Meter−DA Energy−Regulation

TEE−DA Energy

– Apply PM to BCR Cost and Revenue if | Meter − Reg − TEE | <= PM tol band

• Replaces current real-time MEAF


Application of DA MEAF & RT PM

• DA MEAF

– DA Energy above Pmin

• RT PM

– RUC / RTM ML cost and revenue

– Optimal energy

– DA ML cost and revenue applied in lieu of DA MEAF

• for non-MSG, ISO-committed in DA, de-committed

in RTM

• for MSG, ISO-committed in DA at higher, in RTM at

lower configuration


Application of DA MEAF & RT PM, cont.

• In short, apply to positive costs and negative revenues

– DA MEAF or RT PM should not increase costs or decrease

revenues (i.e., there is no increase in BCR uplift amount)

Costs Revenues Apply DA MEAF or PM to…

+ + costs

+ – costs & revenues

– + n/a

– – revenues


Persistent deviation (PDM)

Meter i − 1 − Meter i

Meter i − 1 − TEE i − Regulation i

• Test PDM per each 5-min from 3-hour perspective for

Trading Hour

– Flag as pass or fail, per 5-min, and count number of fails

– Split 3-hour period as:

• Window 1: Prior and Current Trading Hours

• Window 2: Current and Next Trading Hours

– If fail count > 6 for either window, then

• Mitigate RT OE and RIE bid prices for Current Trading Hour

– Min(Final Bid Price, DEB Price, RT LMP) for “inc” energy

– Max(Final Bid Price, DEB Price, RT LMP) for “dec” energy


PDM threshold test cases


BCR for start-up costs (SUC)

• To receive BCR on start-up costs, resource must be OFF

before becoming ON.

• Short-start resource committed by ISO in IFM but re-

committed in RTM, creating overlaps, RTM SUC costs

are allocated as:

– IFM costs over the IFM commitment period, for 1st RTM start-up;

– RTM costs over the RTM commitment period, for subsequent

RTM start-ups over the same IFM commitment period


BCR minimum load, shutdown

• Disqualify MLC when ISO is not be able to issue binding

shutdown following shutdown advisory

– due to resource’s persistent deviation

– State Variable stores cumulative deviation


BCR MSG transition

• Transition cost paid if based on metered energy,

resource is:

– in its FROM configuration prior to transition period

– and then in its TO configuration


“Mandatory MSG” implementation

• Incorporates enhancement to multi-stage generator

(MSG) modeling

– Replaces current interim MSG model

• Uses RT performance metric to determine eligible MSG

configuration MLC BCR

– Pro-rates cost and revenue based on metered

energy relative to expected energy

– Replaces MLC payment based on metered

configuration


Charge Code Impact

• One (1) new CC under Cost Recovery Parent Group

• CC 6630 – IFM Bid Cost Recovery Settlement

• Configuration Updates to Nine (9) CCs

• CC 6620 – RUC and RTM Bid Cost Recovery Settlement

• CC 6460 – FMM Instructed Imbalance Energy Settlement

• CC 6470 – RT Instructed Imbalance Energy Settlement

• PC BCR Sequential Netting

• PC SUC and MLC

• PC MEAF

• PC IFM Net Amount

• PC RUC Net Amount

• PC RTM Net Amount


Charge Code Impact, cont.

CC 6630 (IFM BCR Settlement) , per resource per TD

• uplift amount from total negative daily IFM net amounts

• net amounts = Bid Cost –Market Revenue per 5-minutes

CC 6620 (RUC and RTM BCR Settlement), per resource

per TD

• uplift amount from total negative daily RUC plus RTM net

amounts

• net amounts = Bid Cost – Market Revenue per 5-minutes


Charge Code Impact, cont.

BCR Sequential Netting (ISO-level) – As before, uplift only positive values, scaled by positive uplift ratio;

but separate IFM uplift ratio from RUC and RTM uplift ratio

• Per 5-min,

– For IFM uplift, net only IFM shortfalls with IFM surpluses

– For RUC and RTM uplifts

1. Identify if RUC shortfall or RUC surplus

2. Identify if RTM shortfall or RTM surplus

3. If RUC shortfall in step 1, Net RUC shortfall with any

RTM surplus

4. If RTM shortfall in step 2, Net RTM shortfall with any

RUC surplus

• Uplift ratio = Total relevant market uplift per TD / Total relevant

market positive uplift per TD


Bid cost recovery examples

• Please turn to

– “Spring 2014 Release – Non MSG Resource with

BCR Settlement Example”; and

– “Spring 2014 Release - Non-Overlapping MSG

Resource with BCR Settlements Example”


IFM BCR change summary

• IFM Net Amount computed as IFM Bid Cost minus IFM

Market Revenue

• IFM Energy Bid Cost and Market Revenue

– Subject to DA MEAF

• IFM MLC and MLE qualifiers;

a. No RTM De-commitment , use Meter >= PMIN – Tolband.

b. If RTM De-commitment, use RT PM with IFM MLC and MLE

• New CC 6630 IFM BCR Settlement


RTM BCR change summary

• RTM Net Amount computed as RT Bid Cost minus RT Market

Revenue

• RT Energy Bid Cost and Market Revenue

– RT PM applied to

• RUC MLC and RTM MLC, Energy Bid Cost, MLE

– MLC payment calculation for MSG simplified

• No more intermediate MSG Configuration cost payment for ISO-

committed MSG Configuration transitions

• Negative RTM MLC – When IFM committed configuration is higher

than RTM Committed configuration.

• RUC Net Amount still computed as RUC Bid Cost minus RUC Market

Revenue

• CC 6620 for RUC/RTM BCR Settlement


Charge Code Impact by Category

• FMM Market

• RIMPR

• 5-Minute Settlements

• Dynamic Transfers


FMM Market

Charge Code # `

4512 GMC Inter-SC Trade Transaction Fee

4560 GMC Market Services Charge

4561 GMC System Operations Charge

6194 Spinning Reserve Obligation Charge

6294 Non Spinning Reserve Obligation Charge

6371 FMM Inter-SC Trades Settlement

6455 Declined Hourly Pre-Dispatch Penalty

6457 Declined Hourly Pre-Dispatch Penalty Allocation

6460 FMM Instructed Imbalance Energy Settlement

6470 Real-time Instructed Imbalance Energy Settlement


FMM Market, cont.

Charge Code # Title

6473 Real-time Convergence Energy Settlement

6475 Real-time Uninstructed Imbalance Energy Settlement

6774 Real-time Congestion Offset

6788 Real-time Market Congestion Credit Settlement

6482 Real-time Excess Cost for Instructed Energy Settlement

6488 Exceptional Dispatch Uplift Settlement

6984 RTM Net Marginal Loss Assessment per CAISO Agreement

701 Forecasting Service Fee

Pre-calc Ancillary Services

Pre-calc Real-time Energy Quantity

Pre-calc Real-time Price


RIMPR

Charge Code # Title

6470 Real Time Instructed Imbalance Energy Settlement

6620 RUC and RTM Bid Cost Recovery Settlement

6630 IFM Bid Cost Recovery Settlement

Pre-calc IFM Net Amount

Pre-calc Metered Energy Adjustment Factor

Pre-calc RTM Net Amount

Pre-calc RUC Net Amount

Pre-calc Bid Cost Recovery Sequential Netting

Pre-calc Start Up and Minimum Load Cost


5-Minute Settlements

Charge Code # Title

6474 Real-time Unaccounted for Energy Settlement

6477 Real-time Imbalance Energy Offset

6678 Real-time Bid Cost Recovery Allocation

7056 Flexible Ramp Cost Allocation

6486 Real-time Excess Cost for Instructed Energy Allocation

6489 Exceptional Dispatch Uplift Allocation

6806 Day Ahead Residual Unit Commitment Tier 1 Allocation

6824 No Pay Residual Unit Commitment Settlement

1303 Supplemental Reactive Energy Allocation


5-Minute Settlements, cont.

Charge Code # Title

1407 MSS Positive Deviation Penalty

2407 MSS Negative Deviation Penalty

3303 Supplemental Reactive Energy Settlement

4563 GMC Transmission Ownership Rights Charge

4989 Daily Rounding Adjustment Allocation

6124 No Pay Spinning Reserve Settlement

6224 No Pay Non-spinning Reserve Settlement

6480 Excess Cost Neutrality Allocation

6490 NERC WECC Charge

6976 Transmission Loss Obligation Charge for Real-time

Schedules Under Control Agreement



Charge Code # Title

6977 Allocation of Transmission Loss Obligation Charge

7024 Flexible Ramp Up No Pay Capacity Charge

Pre-calc Measured Demand over Control Area

Pre-calc ETC TOR CVR Quantity

Pre-calc Standard Capacity Product

Pre-calc System Resource Deemed Delivered Energy

Pre-calc HVAC Metered Load

Pre-calc RUC No Pay Quantity

Pre-calc Wheel Export Quantity

Pre-calc Allocation of Transmission Losses Under Control

Agreements

Pre-calc Measured Demand Over Control Area Excl MSS Energy



Charge Code # Title

Pre-calc Measured Demand Over Control Area Excl Transmission

Loss Adjustment

Pre-calc MSS Deviation Penalty Quantity

Pre-calc MSS Netting

Pre-calc Spin Non-spin No Pay Quantity


Dynamic Transfers

Charge Code # Title

6755 Real-time Congestion – Regulation Up Import Settlement

6760 Day-ahead Congestion – Regulation Down Import

Settlement

6765 Real-time Congestion – Regulation Down Import Settlement

Pre-calc Ancillary Services


Questions?


References


Reference materials

• Renewable Integration – Market & Product Review Draft Final

Proposal – http://www.caiso.com/Documents/DraftFinalProposal-RenewableIntegrationMarket-

ProductReviewPhase1.pdf

• Bid Cost Recovery Mitigation Measures – 3rd Revised Draft Final

Proposal – http://www.caiso.com/Documents/ThirdRevisedDraftFinalProposal_BidCostRecoveryMitigati

onMeasuresNov26_2012.pdf

• FERC Order 764 Compliance – 15-Minute Scheduling and

Settlement – Addendum to Draft Final Proposal – http://www.caiso.com/Documents/Addendum-DraftFinalProposal-

FERC_Order764MarketChanges.pdf

• FERC Order 764 Market Changes – Intermittent Resource

Protective Measures – http://www.caiso.com/Documents/DraftFinalProposal-FERCOrder764MarketChanges-

IntermittentResourceProtectiveMeasures.pdf

http://www.caiso.com/Documents/DraftFinalProposal-RenewableIntegrationMarket-ProductReviewPhase1.pdf






http://www.caiso.com/Documents/ThirdRevisedDraftFinalProposal_BidCostRecoveryMitigationMeasuresNov26_2012.pdf




http://www.caiso.com/Documents/Addendum-DraftFinalProposal-FERC_Order764MarketChanges.pdf






http://www.caiso.com/Documents/DraftFinalProposal-FERCOrder764MarketChanges-IntermittentResourceProtectiveMeasures.pdf









Reference materials, cont.

• Draft Tariff Language – RI-MPR – http://www.caiso.com/informed/Pages/StakeholderProcesses/RenewableIntegrationMarketPr

oductReviewPhase1.aspx (please see under Tariff development)

• Draft Tariff Language – Order 764 Compliance – http://www.caiso.com/Documents/RevisedDraftTariffLanguage-

FERCOrder764MarketChanges.doc

• Draft Configuration Guides – http://www.caiso.com/informed/Pages/ReleasePlanning/Default.aspx

– Under Spring 2014 release>Draft settlements technical documentation

• SaMC Design Bill Determinant Standard and Convention – http://www.caiso.com/informed/Pages/ReleasePlanning/Default.aspx


http://www.caiso.com/informed/Pages/StakeholderProcesses/RenewableIntegrationMarketProductReviewPhase1.aspx

http://www.caiso.com/informed/Pages/StakeholderProcesses/RenewableIntegrationMarketProductReviewPhase1.aspx

http://www.caiso.com/Documents/RevisedDraftTariffLanguage-FERCOrder764MarketChanges.doc




http://www.caiso.com/informed/Pages/ReleasePlanning/Default.aspx




• Second Draft SaMC Bill Determinant Matrix File – http://www.caiso.com/informed/Pages/ReleasePlanning/Default.aspx


• List of Documentation Only and Retiring Configuration Guides – http://www.caiso.com/informed/Pages/ReleasePlanning/Default.aspx


• List of Documentation Only and Retiring Configuration Guides – http://www.caiso.com/informed/Pages/ReleasePlanning/Default.aspx


• California Independent System Operator Corporation – Fifth

Replacement FERC Electric Tariff – CAISO Settlements And Billing

(Section 11) – http://www.caiso.com/rules/Pages/Regulatory/Default.aspx

– Under Tariffs>Conformed tariff by section and appendix>Tariff sections




http://www.caiso.com/rules/Pages/Regulatory/Default.aspx

http://www.caiso.com/rules/Pages/Regulatory/Default.aspx



• External Business Requirement Specification – FERC Order 764 – http://www.caiso.com/informed/Pages/ReleasePlanning/Default.aspx

– Under Spring 2014 release>FERC Order No 764 market changes - implementation

• External Business Requirement Specification – Renewable

Integration Market and Product Review and BCR Mitigation – http://www.caiso.com/informed/Pages/ReleasePlanning/Default.aspx

– Under Spring 2014 release>Renewable integration market and product review phase 1 -

implementation




Acronyms


Common acronyms

Acronym Stands for

ADS Automated Dispatch System

AGC Automatic Generation Control

APN Aggregate Price Node SC Trade

A/S or AS Ancillary Services

ASMP Ancillary Services Marginal Price

BA Balancing Authority

BAA Balancing Authority Area

BAID Business Associate Identification

BCR Bid Cost Recovery

BOG Board of Governors

Slide 78


Common acronyms

Acronym Stands for

BPM Business Practice Manual

BRS Business Requirements Specification

CARB California Air Resource Board

CAS

CAISO California Independent System Operator

DA Day-ahead

DAM Day-ahead Market

DASE Day-ahead Scheduled Energy

DASSE Day-ahead Self-scheduled Energy

DEB Default Energy Bid

Slide 79


Common acronyms

Acronym Stands for

DOP Dispatch Operating Point

DOT Dispatch Operating Target

DSSE Day-Ahead Self-Scheduled Energy

EIM Energy Imbalance Market

EIR Eligible Intermittent Resource

ESQMD Estimated Settlement Quality Meter Data

FERC Federal Energy Regulatory Commission

FMM Fifteen Minute Market

GMC Grid Management Charge

GRDT Generator Resource Data Template

Slide 80


Common acronyms

Acronym Stands for

HAP Hour Ahead Process

HASP Hour Ahead Scheduling Process

IIE Instructed Imbalance Energy

IFM Integrated Forward Market

IRDT Intertie Resource Data Template

ISO Independent System Operator

IST Inter-SC Trade

LAP Load Aggregation Point

LSE Load Serving Entity

LMP Locational Marginal Price

Slide 81


Common acronyms

Acronym Stands for

LMPM Local Market Power Mitigation

MCC Marginal Cost of Congestion

MCL Marginal Cost of Losses

MEAF Metered Energy Adjustment Factor

ML Minimum Load

MLC Minimum Load Cost

MLE Minimum Load Energy

MO Market Operator

MPM Market Power Mitigation

MRI Market Results Interface

Slide 82


Common acronyms

Acronym Stands for

PPT Pacific Prevailing Time

PIR Participating Intermittent Resource

PIRP Participating Intermittent Resource Program

RED Ramping Energy Deviation

REM Regulation Energy Management

RI-MPR Renewable Integration – Market & Product Review

RMR Reliability Must Run

RMT Regulatory Must Take

RT Real-time

RT PM Real-time Performance Metric

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Common acronyms

Acronym Stands for

MW Megawatt

MWh Megawatt Hour

NERC North American Electric Reliability Corporation

OA Operational Adjustment

OASIS Open Access Same Time Information System

OE Optimal Energy

OMAR Operational Meter Analysis & Reporting

PC Pre-calculation

PDM Persistent Deviation Metric

PM Performance Metric

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Common acronyms

Acronym Stands for

RTD Real-time Dispatch

RTED Real-time Economic Dispatch

RTM Real-time Market

RTPD Real-time Pre-Dispatch

SaMC Settlements and Market Clearing

SC Scheduling Coordinator

SCED Security Constrained Economic Dispatch

SCID Scheduling Coordinator ID

SIBR Scheduling Infrastructure Business Rules (application)

SMEC System Marginal Cost of Energy

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Common acronyms

Acronym Stands for

SQMD Settlement Quality Meter Data

SRE Standard Ramping Energy

STUC Short-Term Unit Commitment

TD Trade Day

TEE Total Expected Energy

TG Tie Generator

TOR Transmission Ownership Right

UIE Uninstructed Imbalance Energy

VER Variable Energy Resource

WECC Western Electricity Coordinating Council

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