Market Performance and Planning Forum January 18, 2017 Objective: - - PowerPoint PPT Presentation

Market Performance and Planning Forum

January 18, 2017

Objective: Enable dialogue on implementation planning and market performance issues

• Review key market performance topics
• Share updates to 2016 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

Page 2 Last updated: January 17, 2017

Market Performance and Planning Forum

Agenda – January 18, 2017

Time: Topic: Presenter: 10:00 – 10:05 Introduction, Agenda Kristina Osborne 10:05 – 10:20 Capacity Procurement Market Update Dede Subakti 10:20 – 11:30 Market Performance and Quality Update Amber Motley Guillermo Bautista Alderete 11:30 – 12:00 Flexible Ramping Sufficiency Test Keith Collins 12:00 – 1:00 Lunch 1:00 – 1:30 Policy Update Brad Cooper 1:30 – 1:45 Sub-LAP Area Definition Updates Jim Price Jim McClain 1:45 – 2:00 Model Enhancement for DERs *w/update on Sub-Lap revision implementation for PDR/RDRR Jill Powers 2:00 – 3:00 Release Update Janet Morris

Capacity Procurement Market Update

Dede Subakti Director, Operations Engineering Services

Slide 4

CPM and CSP update

• New CPM and CSP process went live on Nov 1, 2016
• On Nov 8, CAISO issued ED to Mandalay due to transmission
• utage in Santa Clara sub-area. Unit CPM’d
• On Nov 9, CAISO issued EDs to 8 resources needed to mitigate the

emergency event caused by a market disruption. Emergency event involved area control error and low system frequency. The market tool did not work, so ED done manually. Units were CPM’d.

• On Dec 14, CAISO issued EDs to 2 resources in Bay Area due to

transmission outage. Units were CPM’d.

• On Dec 18, CAISO issued ED to Moss Landing Due to the cold

temperatures, potential gas supply issues, and potential loss of imports into the California ISO Balancing Authority. The market tool did not work, so ED done manually. Unit was CPM’d

• On Dec 19, CAISO issued ED to Mountain View due to outages in

West of Devers sub-area. Unit was CPM’d.

Observations

• After the fact analysis (following Nov 8 event), showed

that some SCs did not provide CSP offer because the SC operators were not aware that CSP went live on Nov 1, 2016

Page 6

Other Observation (optional slide)

• If SC does not submit CSP offer, then the SC may reject the CPM

designation following an ED. Under Tariff, SC must do this within the 24 hour window. If ED is done over the weekend, CAISO reminds all SCs to watch for this notification (CAISO notes that in

• rder for an SC for a resource to know that they have received a

CPM designation, they must subscribe to the email notification. Not everyone is doing this.)

• We observe that some resources offer Flex RA > Generic RA.

Sometimes, there is 0 MW for generic RA, but non-zero for Flex RA . Under tariff, the ISO cannot grant an intra-monthly CPM to capacity that is Committed RA Capacity on the day the CPM designation would begin. Take for example a resource with 0 MW of generic RA capacity and Flex RA capacity greater than zero. The resource is not eligible to receive an intra-monthly CPM designation for the MW of capacity that is Flex RA.

Page 7

Market Performance and Quality Update

Amber Motley Manager, Short Term Forecasting Guillermo Bautista Alderete, Ph.D. Director, Market Quality and Forecasting

Slide 8

Flexible Ramp Update

Page 9 Last updated: January 17, 2017

Flexible Ramp Product

• Flexible Ramp product went live on November 1, 2016
• There is both upward and downward definitions for the

product.

• Each EIM area has its own requirement, and there is

also a system-wide area enforced in the real-time market.

• Flexible ramp sufficiency test done prior to the real-time

market.

• Requirements are based on historical data and

calculated in the Balancing Area Ramp Requirement (BARR) application.

Page 10 Last updated: January 17, 2017

What is driving the flexible ramp requirement profile?

• The requirement for RTPD is based off the difference

between the RTD net load and the RTPD net load.

• The FRU requirement is typically lower for ramp up

periods because the RTD net load forecast is more accurate than the RTPD net load.

Page 11 Last updated: January 17, 2017

Why is the individual EIM areas FRP procurement volatile?

• Raw FRP requirements are adjusted first for Net

Import/Export Capability (NIC/NEC) or diversity credit.

• Generally, the NIC/NEC will largely offset the raw

requirement and thus the individual requirement constraints will often not bind

• The system-wide EIM area constraint still has to be in

place and will usually bind.

• Individual EIM areas may procure FRP towards the EIM

area based on economics, and influenced by – Energy bid ranges among areas, and – transfers

Page 12 Last updated: January 17, 2017

Individual versus EIM area procurement

Page 13 Last updated: January 17, 2017

Flexible Ramp requirements and prices

Page 14 Last updated: January 17, 2017

$0 $50 $100 $150 $200

• 1,500
• 1,000
• 500

500 1,000 1,500 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Average Hourly Flex Ramp Price ($/MW) Average Hourly Flex Ramp Requirement (MW) Flex Ramp Down Average Requirement Flex Ramp Up Average Requirement Flex Ramp Down Average Price Flex Ramp Up Average Price

Why there is procurement in excess of the requirement?

• The procurement of the flex Ramp is actually driven by

the requirements of the system-wide EIM area.

• The capacity is not unlimited, and individual areas meet

the procurement of the overall EIM area

• There may be capacity in excess but it will be at $0

price

• Usually changes in commitment or deviations may make

more capacity available at $0 price.

Page 15 Last updated: January 17, 2017

Regulation Update

Page 16 Last updated: January 17, 2017

Examples: December Regulation Required

Solid – Sunny Weather Conditions Dotted – Partly Cloudy/Cloudy weather conditions

Page 17 Last updated: January 17, 2017

December Regulation Cost Comparison March 2016 vs December 2016

Page 18 Last updated: January 17, 2017

Market Update

Page 19 Last updated: January 17, 2017

Page 20

Good price convergence in December.

Page 21

RT prices higher than DA prices for NP15 in November but lower than DA prices for both NP15 and SP15 in December.

Page 22

Insufficient upward ramping capacity in ISO dropped in December.

Page 23

Insufficient downward ramping capacity stayed low in 2016.

Page 24

Congestion revenue rights market revenue inadequacy without including auction revenues.

Page 25

Congestion revenue rights market revenue sufficiency including auction revenues.

Page 26

Exceptional dispatch volume in the ISO area remained low in November and December.

Page 27

Daily exceptional dispatches by reason

Page 28

Real-time Bid cost recovery increased since September

Page 29

Bid cost recovery (BCR) by Local Capacity Requirement area

Page 30

Minimum online commitment (MOC)

Page 31

Pmax of MOC Cleared Units

Page 32

Enforcement of minimum online commitments in November and December

MOC Name Number (frequency) of hours in November and December Humboldt 7110 1459 MOC East Nicolaus 1374 MOC Moorpark 101 MOC Palermo Hi Volt 4462683 80 MOC Moss 3919104 78 Orange County 7630 68 MOC SAN ONOFRE BUS 57 SCIT MOC 27 MOC PLACER 4371261 25 HNTBH 7820 7 SDGE 7820 2

Page 33

IFM under-scheduling of solar generation

Page 34

IFM under-scheduling of wind generation declined in November and December

Page 35

Renewable (VERS) schedules including net virtual supply and aligns with VER forecast in November and December

http://www.caiso.com/Pages/documentsbygroup.aspx?GroupID=EFF75C 2E-F28E-4087-B88B-8DFFAED828F8

Page 36

RTD renewable (VERS) curtailment trended upward since August

Page 37

Hourly distribution of maximum RTD renewable (VERS) curtailment in December

Page 38

Wind, solar and hydro production

Monthly wind (VERS) downward flexibility in FMM

Page 39

Monthly solar (VERS) downward flexibility in FMM

Page 40

Monthly solar (VERS) downward flexibility in FMM from 11 AM to 5 PM

Page 41

Page 42

ISO area RTCO and RTIEO remains at low levels in November and December.

2015 2016 RTCO $55,376,805 $50,506,525 RTIEO $13,648,680

• $691,475

Total Offset $69,025,485 $49,815,050

Page 43

CAISO Price correction events increased in November but decreased in December

1 2 3 4 5 6 7 8 9 10 Jan-15 Feb-15 Mar-15 Apr-15 May-15 Jun-15 Jul-15 Aug-15 Sep-15 Oct-15 Nov-15 Dec-15 Jan-16 Feb-16 Mar-16 Apr-16 May-16 Jun-16 Jul-16 Aug-16 Sep-16 Oct-16 Nov-16 Dec-16 Count of Events Process Events Software Events Data Error Events Tariff Inconsistency

Page 44

EIM-Related Price correction events increased in November and December

2 4 6 8 10 12 14 16 18 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2015 2016

Count of Events

Process Events Software Events Data Error Events Tariff Inconsistency

EIM Price trends

Page 45

EIM transfers

Page 46

Page 47

EIM BCR in November and December

Page 48

EIM Manual Dispatch in November and December

Day-ahead load forecast

0.0% 0.5% 1.0% 1.5% 2.0% 2.5% 3.0% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 2015 2016

MAPE

Day-ahead peak to peak forecast accuracy

0.0% 0.5% 1.0% 1.5% 2.0% 2.5% 3.0% 3.5% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 2015 2016

MAPE

Day-ahead wind forecast

0.0% 1.0% 2.0% 3.0% 4.0% 5.0% 6.0% 7.0% 8.0% 9.0% 10.0% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 2015 2016

MAE

Day-ahead solar forecast

0.0% 2.0% 4.0% 6.0% 8.0% 10.0% 12.0% 14.0% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 2015 2016

MAE

Real-time wind forecast

0.0% 0.5% 1.0% 1.5% 2.0% 2.5% 3.0% 3.5% 4.0% 4.5% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 2015 2016

MAE

Real-time solar forecast

0% 1% 2% 3% 4% 5% 6% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 2015 2016

MAE

Flexible ramping sufficiency test

Keith Collins Manager, Monitoring and Reporting Department of Market Monitoring

Page 55

Flexible ramping sufficiency test

• Ensures that each EIM balancing authority area

has sufficient upward and downward ramping capability over an hour to meet expected ramp as well as uncertainty

• If a balancing area does not have sufficient

ramping capacity, then:

– It cannot increase EIM transfers into its area to meet upward ramping limitations – It cannot decrease EIM transfers from its area to meet downward ramping limitations

Page 56

Flexible ramping sufficiency test

• In order to pass the hourly flexible ramping sufficiency test in a given

direction (upward or downward), an EIM entity needs to show sufficient ramping capability from the start of the hour to each of the four 15-minute intervals in the hour.

• An EIM entity must pass all four 15-minute interval tests in order to

pass the hourly flexible ramping sufficiency test for upward and downward ramping.

𝐺𝑚𝑓𝑦 𝑆𝑏𝑛𝑞 𝑉𝑞 𝑆𝑓𝑟𝑣𝑗𝑠𝑓𝑛𝑓𝑜𝑢 = ∆𝑀𝑝𝑏𝑒 + 𝐺𝑚𝑓𝑦 𝑉𝑞 𝑉𝑜𝑑𝑓𝑠𝑢𝑏𝑗𝑜𝑢𝑧 + max −𝑂𝑓𝑢 𝐽𝑛𝑞𝑝𝑠𝑢 𝐷𝑏𝑞𝑏𝑐𝑗𝑚𝑗𝑢𝑧, −𝐸𝑗𝑤𝑓𝑠𝑡𝑗𝑢𝑧 𝐶𝑓𝑜𝑓𝑔𝑗𝑢 − 𝐺𝑚𝑓𝑦 𝑆𝑏𝑛𝑞 𝑉𝑞 𝐷𝑠𝑓𝑒𝑗𝑢

Page 57

Forecasted component Uncertainty component (Same used in flexible ramping product) Diversity benefit and credit reduction capped at net import capability

Flexible ramping sufficiency test – Modifiers

• Diversity Benefit Factor – A fraction that represents a

balancing authority area’s share of the net load forecast error for the combined EIM area. It is equal to the EIM area uncertainty requirement divided by the sum of the individual balancing authority area uncertainty requirements. It represents the smoothing effect that happens when combining net load forecast errors across a larger footprint.

• Flexible ramping credit – The ability to reduce exports to

increase upward ramping capability or reduce imports to increase downward ramping capability.

Page 58

Flexible ramping sufficiency test – Modifiers

• Net import capability – The amount of import capacity a

balancing authority area has in each interval. The reduction in the upward sufficiency test requirement because of any diversity benefit or flexible ramping up credit may not be greater than the available net import capability.

• Net export capability – The amount of export capacity a

balancing authority area has in each interval. The reduction in the downward sufficiency test requirement because of any diversity benefit or flexible ramping down credit may not be greater than the available net export capability.

Page 59

Sufficiency test example – diversity benefit

• PacifiCorp West upward sufficiency test on December 2, hour 17
• Diversity benefit factor = 514

1,210 = 42%

• PACW diversity benefit reduction = 97 − 97 ∗ 42% = 56 MW

Page 60

200 400 600 800 1,000 1,200 1,400

MW

CAISO PACE PACW PSEI NEVP AZPS EIM area Pro rata diversity benefit reduction = 56 MW BAA uncertainties EIM area uncertainty PACW uncertainty PACW uncertainty * diversity benefit factor Sum of BAA uncertainties = 1,210 MW EIM area uncertainty = 514 MW PACW uncertainty = 97 MW

Sufficiency test example – net transfer capability and credits

• Upward sufficiency test on December 2, hour 17
• PacifiCorp West flexible ramping up credit = 158 MW
• PacifiCorp West net import capability = 1,064 MW

Page 61

• 400
• 200

200 400 600 800 1,000 PACW HMWY import limit MALIN import limit BPAT import limit With PACE on HMWY With PSEI on BPAT With CAISO on MALIN Total import limit Net transfer Flex ramp up credit = net EIM export = 158 MW (zero down credit) Net import capability = 1,064 MW Total import limit = 906 MW Exports Imports

Sufficiency test example – PacifiCorp West Hour 17

𝐺𝑚𝑓𝑦 𝑆𝑏𝑛𝑞 𝑉𝑞 𝑆𝑓𝑟𝑣𝑗𝑠𝑓𝑛𝑓𝑜𝑢 = ∆𝑀𝑝𝑏𝑒 + 𝐺𝑚𝑓𝑦 𝑉𝑞 𝑉𝑜𝑑𝑓𝑠𝑢𝑏𝑗𝑜𝑢𝑧 + max −𝑂𝑓𝑢 𝐽𝑛𝑞𝑝𝑠𝑢 𝐷𝑏𝑞𝑏𝑐𝑗𝑚𝑗𝑢𝑧, −𝐸𝑗𝑤𝑓𝑠𝑡𝑗𝑢𝑧 𝐶𝑓𝑜𝑓𝑔𝑗𝑢 − 𝐺𝑚𝑓𝑦 𝑆𝑏𝑛𝑞 𝑉𝑞 𝐷𝑠𝑓𝑒𝑗𝑢

• 𝐺𝑚𝑓𝑦 𝑆𝑏𝑛𝑞 𝑉𝑞 𝑆𝑓𝑟𝑣𝑗𝑠𝑓𝑛𝑓𝑜𝑢 = 197 + 97 + max

−1,064, −56 − 158 = 80

• 𝑉𝑞𝑥𝑏𝑠𝑒 𝑠𝑏𝑛𝑞𝑗𝑜𝑕 𝑑𝑏𝑞𝑏𝑑𝑗𝑢𝑧 𝑏𝑤𝑏𝑗𝑏𝑐𝑚𝑓 = 218
• PacifiCorp West passes the test for the fourth 15-minute

interval of the hour

Page 62

• PacifiCorp West failed sufficiency test in hour ending 9.

Flexible ramping sufficiency test example – PacifiCorp West

Page 63

• 600
• 400
• 200

200 400 600 800

123412341234123412341234123412341234123412341234123412341234123412341234123412341234123412341234 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

MW Hour and test # Import capability reduction Diversity benefit reduction Flex ramp credit reduction Forecasted component Uncertainty component Net requirement Upward ramping capacity

• There was a significant uptick in sufficiency failures after launch of the

flexible ramping product on November 1. Many were due to issues in counting available supply to meet the requirement.

Flexible ramping sufficiency test – Upward ramping sufficiency failures

Page 64

5 10 15 20 25 30

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 October November December

Number of hours where the sufficiency test failed PACE PACW NEVP PSEI AZPS

Flexible ramping sufficiency test – Downward ramping sufficiency failures

Page 65

• The downward sufficiency test was added on November 1.
• There have been a significant set of failures in the APS area since launch.

2 4 6 8 10 12 14 16 18

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 November December

Number of hours where the sufficiency test failed PACE PACW NEVP PSEI AZPS

Policy Update

Brad Cooper Manager, Market Design and Regulatory Policy

Page 66

Ongoing policy stakeholder initiatives

• Stakeholder Initiatives Catalog

– Feb EIM Governing Body and ISO Board Meetings

• Energy Storage and Distributed Energy Resources

(ESDER) - Phase 2 – Schedule TBD

• Bid Cost Recovery Enhancements

– Revised straw proposal in Jan – Remaining schedule TBD

• Contingency Modeling Enhancements

– Technical analysis results and stakeholder call targeted for Jan-Feb – May ISO Board Meeting

Page 67

Ongoing policy stakeholder initiatives (continued)

• Stepped Constraint Parameters

– Incorporating parameter changes needed for FERC Order 831 compliance – Straw proposal targeted for Feb – May EIM Governing Body and ISO Board Meetings

• Generator Contingency and Remedial Action Scheme

Modeling – Revised straw proposal targeted for Jan – July EIM Governing Body and ISO Board Meetings

Page 68

• Commitment Costs and Default Energy Bid Enhancements

– Straw proposal targeted for February 2017 – July EIM Governing Board and ISO Board Meetings

– Will address bid cost verification for FERC Order 831 compliance

• Frequency Response – Phase 2

– Working groups meetings in Feb, March – Straw proposal targeted for April – Sept ISO Board Meeting

• Flexible Resource Adequacy Criteria and Must-Offer

Obligation – Phase 2 – Revised straw proposal targeted for Feb 2017 – Board Meeting TBD

Page 69

Ongoing policy stakeholder initiatives (continued)

Ongoing policy stakeholder initiatives (continued)

• Regional Integration and EIM Greenhouse Gas Compliance

– ARB 15-Day Notice comments due Jan 20 – Draft final proposal TBD – EIM Governing Body and ISO Board Meeting TBD

• Transmission Access Charge Options, Regional Resource

Adequacy – Frameworks published Dec 2016 – ISO response to comments targeted Jan-Feb – Further policy development on hold pending regional governance structure development

Page 70

Policy stakeholder initiatives coming soon

• Planned to start in Q1 2017

– Resource Adequacy Enhancements – Economic and Maintenance Outages – CRR Auction Efficiency Analysis Working – Blackstart and System Restoration

Page 71

Sub-LAP Areas Update

Jim Price Senior Advisor, Market Development & Analysis

Slide 72

Recap: Sub-LAPs within default load aggregation points (DLAPs) have been implemented as of 1/1/2017

• Other than publication of locational marginal prices (LMPs),

Sub-LAPs have two purposes:

– Aggregations of demand response and distributed resources – More precise congestion costs than default LAPs and award of additional CRRs when congestion limits DLAPs.

• Existing Sub-LAPs were identified when current market

design was implemented in MRTU, and were outdated

• Basing Sub-LAP boundaries on RA local capacity areas will

allow demand response to qualify as local RA resources.

• Several Sub-LAP boundaries have shifted slightly to reflect

RA areas, and some could be merged.

• Updates do not change Custom LAPs of Participating Loads.
• If RA local capacity areas change, Sub-LAPs will follow.

Page 73

Most Sub-LAPs retain same name. Name changes indicate splitting or merging areas.

Current Sub- LAP New Sub-LAP Current Sub- LAP New Sub- LAP

SLAP_PGCC SLAP_PGCC SLAP_SCEC SLAP_SCEC SLAP_PGEB SLAP_PGEB SLAP_SCEN SLAP_SCEN SLAP_PGF1 SLAP_PGF1 SLAP_SCEW SLAP_SCEW SLAP_PGFG SLAP_PGFG SLAP_SCHD SLAP_SCHD SLAP_PGHB SLAP_PGHB SLAP_SCLD SLAP_SCLD SLAP_PGLP SLAP_PGZP SLAP_SCNW SLAP_SCNW SLAP_PGKN (New LCA) SLAP_SDG1 SLAP_SDG1 SLAP_PGNB SLAP_PGNB Not defined SLAP_VEA SLAP_PGNC SLAP_PGNC SLAP_PGNV SLAP_PGNP SLAP_PGP2 SLAP_PGP2 SLAP_PGSA SLAP_PGSI SLAP_PGSB SLAP_PGSB SLAP_PGSF SLAP_PGSF SLAP_PGSI SLAP_PGSI SLAP_PGSN SLAP_PGNP SLAP_PGST SLAP_PGST

Page 74

CRR Modeling of change to Sub-LAPs

• Sub-LAP Changes

– Changes to Sub-LAP definitions were initially intended for implementation on 1/1/2017 – A few days before the 2017 annual auction was to

• pen the ISO received notice of a concern with the

implementation of this change – After review it was determined that there was a possible exposure to the market and that the best solution was to update the model to be used for the annual auction ahead of schedule

CRR Modeling of change to SLAPs

• Sub-LAP Changes created multiple revisions to CRR FNM

– Since the process for developing the new Sub-LAPs was

• utside of the normal process for developing this data

there were multiple revisions made to the CRR FNM – These revisions created additional workload for our participants as well as the ISO – The CAISO recognizes the additional effort this required for our participants – Going forward we are not expecting the significant changes that were seen this time and the updates will flow through our normal change process and not be implemented as they were this time

 with update on Sub-Lap revision implementation for PDR/RDRR Jill Powers Smart Grid Solutions Manager, Smart Grid Technologies and Strategy

Slide 77

Model Enhancement for Distributed Energy Resources

UPDATE: SubLap Redefinition Implementation Completed for PDR/RDRR

ISO and Demand Response Providers coordinated PDR/RDRR registration activities to successfully transition to new Sub-Laps

Page 78

• Effective 1/1/2017 Locations and Registrations reflect new

Sub-Lap areas

• Pre-defined Resources were made available for revised

Sub-Laps prior to 1/1/2017 to meet Resource Adequacy (RA) processing timelines

• Activities were completed prior to the Demand Response

Registration System (DRRS) Phase 2 Enhancements November 30, 2016 deployment.

1/1/2017 Effective SubLap Selections Available in DRRS

Slide 79

• Master file

effective dated SubLaps

• Choices in

SUBLAP field are determined by Start Date/End Date of location

• Any Location

created with Start Date on or after 1/1/2017 can only choose new SUBLAPs

ISO Established Pre-Defined Resource ID Modeling Based On 1/1/2017 Effective Sub-LAP Boundaries

80

2017 Sub-Lap Pre-Defined Modeling Impact PGCC, PGEB, PGF1, PGFG, PGHB, PGNC, PGP2, PGSB, PGSF, SCEW, SCHD, SCNW, SDG1 No Change PGNB, PGSI, PGST Distribution Factor Changes Only SCEC, SCEN, SCLD Distribution Factor Change with added or removed substation(s) PGKN, PGNP, PGZP, VEA New

• The ISO has posted a spreadsheet titled 2017 Sub-Load Aggregation

Point to California ISO Bus Mapping to its load participation and demand response webpage

http://www.caiso.com/Documents/2017Sub-LoadAggregationPointToCaliforniaISOBusMapping.xls

• A spreadsheet for 2017 Pre-Defined Resources Sub-LAP to Bus (Pnode)

to Distribution Factor association will be posted

Model Enhancement Provides Ease of Resource ID Implementation for all DERs

81

• Resource will be created on demand in the Masterfile when

requested through the GRDT process

– Significantly reduces processing timelines and management of requests for a new Resource ID for DERAs – Maintains Pre-Defined resource ID option for PDR/RDRRs – Customizing DER resources no longer requires a Full Network Model (FNM) update More information on model change requirements are in the Energy Storage and Distributed Energy Resource (ESDER) BRS:

http://www.caiso.com/Documents/BusinessRequirementsSpecification-v10-EnergyStorageandDistributedEnergyResources.pdf

Deployed New Modeling Capability Before 1/1/2017

Release Plan Update Janet Morris Director, Program Office

Page 82

The ISO offers comprehensive training programs

83

Training calendar - http://www.caiso.com/participate/Pages/Training/default.aspx Contact us - markettraining@caiso.com Date Training February 7 Settlements 101 (Folsom) February 8 Settlements 201 (Folsom)

Release Plan 2017

Page 84

Independent 2017

• Settlements Release - January 2017
• MRI-S ACL Groups + CPG Enhancements (formerly OMAR Replacement)
• Reactive Power Requirements and Financial Compensation – no system changes
• Administrative Pricing Policy Update
• RIMS Functional Enhancements

Spring 2017

• Acceptable Use Policy – CMRI
• RTD Local Market Power Mitigation (LMPM) Enhancements
• CRR Clawback Modifications
• PIRP System Decommissioning
• Metering Rules Enhancement

Fall 2017

• Bidding Rules Enhancements – Part B
• Reliability Services Initiative Phase 1B
• Reliability Services Initiative Phase 2
• Commitment Cost Enhancement Phase 3
• RTM & EIM 2017 Enhancements
• EIM Portland General Electric (PGE)

Release Plan – 2018 and subject to further planning

Page 85

Spring 2018

• EIM 2018 Idaho Power Company

Fall 2018 – tentative, subject to impact assessment

• Bid Cost Recovery Enhancements
• Generation Contingency and Remedial Action Scheme
• Flexible Resource Adequacy Criteria and Must-offer Obligation Phase 2
• Frequency Response Phase 2
• Contingency Modeling Enhancements
• Commitment Costs and Default Energy Bid Enhancements
• ADS User Interface Replacement

Subject to further release planning:

• ESDER Phase 2
• Stepped Transmission Constraints
• Regional Resource Adequacy
• Regional Integration and EIM Greenhouse Gas Compliance
• Transmission Access Charge Options

Page 86

Settlements Release – January 2017

ISSUE SUMMARY BPM IMPACTED

Update BPM for charge code 6478 real-time system imbalance energy offset and CC 6985 real-time marginal losses offset to align the documentation with the current active settlement configuration PRR 946: ( CC 6478 and CC 6985) Documentation Only Updated BPM for metered energy adjustment factor pre-calculation to clarify conversion of ramp rate in minutes to MWh PRR 947: (PC Metered Energy Adjustment Factor) Updated capacity procurement mechanism (CPM) related configuration guides to re-formulate the eligible CPM capacity designation quantity and pass through bill functionality PRR 948: (PC Metered Demand over TAC Area, CC 7891, and CC 7896 ) Update BPM configuration guide for spin non-spin no pay pre-calculation to retroactively adjust calculation impacting resources without regulation schedules PRR 949: (PC Spin Non-Spin No-Pay) Update BPMs for start-up and minimum load cost and integrated forward market net amount pre-calculation to implement bidding rules enhancement Pmin rerate Pmax derate settlements PRR 955: ( PC Start-up Metered Energy Adjustment Factor v.5.14, and PC IFM Net Amount) Update configuration guides in accordance with administrative pricing initiative to settle congestion revenue rights at the average hourly fifteen minute market price when specific conditions are triggered PRR 956: (CC 6700) Update existing BPM for real-time net amount pre-calculation to exclude hourly block bid opted intertie resources flex ramp product settlement amounts in bid cost recovery PRR 957: (PC RTM Net Amount) Update real time market net amount pre-calculation for regulation up and regulation down bid cost recovery costs PRR# 958 (PC RTM Net Amount) Updated calculation of day ahead and real time self-scheduled bids for resource adequacy availability incentive mechanism PRR# 959 (PC RA Availability Incentive Mechanism) Updated calculations and business rules for RA Availability Incentive Mechanism settlement PRR# 960 (PC RA Availability Incentive Mechanism, CC 8830, and CC 8831)

Page 87

Settlements Release – January 2017

Milestone Date

Status

Configuration Guides Posted December 13, 2016 First DRAFT Configuration Output File Posted December 15, 2016 Second DRAFT Configuration Output File Posted January 13, 2017 Pre-Production DRAFT Configuration Output File Posted January 17, 2017 Production Deployment January 24, 2017 FINAL Configuration Output File Posted January 24, 2017

2017 - MRI-S ACL Groups+ CPG Enhancements

Project Info Details/Date Application Software Changes

The MRI-S metering (MRI-S) application cannot currently support ACL (Access Control List) groups functionality for defining a subset of resources belonging to an SCID. Enhancements to the Application Identity Management (AIM) application will enable the use of ACL groups for SCID-level read-only access for MRI-S.

BPM Changes

None

Business Process Changes

Potential Level-II business process changes under –

• Manage Market & Reliability Data & Modeling
• Manage Operations Support & Settlements

Page 88

Milestone Type Milestone Name Dates Status

Board Approval Board Approval N/A BPMs Metering BPM Changes N/A External BRS Post External BRS Nov 14, 2016



Tariff Pre-Tariff Filing QRB N/A Config Guides Configuration Guide N/A Tech Spec Publish Tech Specs Nov 02, 2016



Market Simulation Phase 2 - MRI-S Metering Enhancements Feb 01, 2017 - Feb 28, 2017 Production Activation Phase 1 - ACL Groups Feb 01, 2017 Phase 2 - MRI-S Metering Enhancements Mar 08, 2017

MRI-S ACL Groups + CPG Enhancements

Page 89

* ACL group creation to filter for a read only role at the resource level is not currently available

# System Summary Status Estimated Fix Date 1 MRI-S CIDI 183777, 183993 - MRI-S for Metering Limitation of 100,000 records. Under review See previous slide 2 MRI-S Option to choose UOM is missing on the UI 3 MRI-S CIDI 184018 - Time zone is missing on the UI 4 MRI-S CIDI 183777, 183993 - Modification to AUP policy on data retrieval to include querying by last updated time 5 MRI-S Option to request for data in various time interval in UI 6 MRI-S Ability to view log files within the same organization 7 MRI-S Ability to provide SC ID in the data retrieve request MRI-S *ACL Group – filter read-only at the resource level In process See previous slide

MRI-S ACL Groups + CPG Enhancements

Page 90

Per last fall’s Customer Partnership Group discussions, the ISO will be not be performing any user access migration, including the current third party access in OMAR to AIM because:

• The platform and business logic for third party access are completely different

between OMAR and AIM, so no automation is possible

• Any effort by the ISO would be manual, and would require heavy market

participant involvement due to data integrity questions around security and third-party access concerns

• The data in OMAR is historical (aged) and therefore must be vetted by the

Scheduling Coordinators to ensure its validity

2017 – Reactive Power Requirements and Financial Compensation

Project Info

Details/Date

Application Software Changes None BPM Changes None Business Process Changes Develop Infrastructure (DI) (80001)

• Level II - Manage Generator Interconnection Process (GIP) (Logical Group):

Page 91

Milestone Type Milestone Name Dates Status

Board Approval BOG Approval N/A BPMs Post Draft BPM changes N/A External BRS Post External BRS N/A Tariff File Tariff FERC Approval Dec 6 Feb 6



Config Guides Prepare Draft Configuration Guides N/A Tech Spec Publish Tech Specs N/A Market Sim Market Sim Window N/A Production Activation Reactive Power Requirements and Financial Compensation March 6, 2017

2017 – Administrative Pricing Policy Updates

Page 92

Project Info Details/Date Application Software Changes

• MQS:
• Part 1 (used under normal market conditions): If there are less than 12 RTDs and 4

RTPDs missing – leverage existing process (last price used)

• Part 2 (used under normal market conditions): If RTD prices are available copy over

to RTPD; RTPD prices available copy over RTD. If neither RTPD or RTD prices are available use DA prices

• Part 3 (used Market Suspension conditions): Use DA prices. If we don’t have DA

prices, revert to prior DA prices (awards and prices)

Business Process Change

• Manage Markets and Grid

BPMs

Market Instruments, Market Operations Milestone Type Milestone Name Dates Status

Board Approval BOG Approval Dec 10, 2014



BPMs Post Draft BPM changes Jan 6, 2017 External BRS Post External BRS Mar 20, 2015



Tariff File Tariff Nov 23, 2016



Config Guides Prepare Draft Configuration Guides Dec 2, 2016



Tech Spec Publish Tech Specs N/A Market Sim Market Sim Window N/A Production Activation Bidding Rules Part B Feb 01, 2017

2017 – RIMS Functional Enhancements

Project Info Details/Date Status

Application Software Changes Functional enhancements resulting from the Customer Partnership Group CPG. More details to be provided in the future. BPM Changes Generator Interconnection and Deliverability Allocation Procedures Generator Interconnection Procedures Managing Full Network Model Metering Generator Management Transmission Planning Process Customer Partnership Group 10/16/15 Application and Study Webinar 3/31/16

Page 93

Milestone Type Milestone Name Dates Status

Board Approval Board approval not required N/A BPMs Generator Interconnection and Delivery Allocation Apr 29, 2016



External BRS External BRS not Required N/A Tariff No Tariff Required N/A Tech Spec No Tech Specifications Required N/A Production Activation Ph1 RIMS5 App & Study Mar 21, 2016



Production Activation Ph2 RIMS5 Queue Management, Transmission and Generation TBD

Spring 2017 – Acceptable Use Policy – CMRI

Project Info Details/Date Application Software Changes Scope includes enforcement of Acceptable Use Policy for CMRI services to support the full implementation of 1 call per service per identity (as designated by certificate) every 5 seconds. An error code of 429 will be returned for any violation instance of the use policy.

Page 94

Milestone Type Milestone Name Dates Status

Board Approval Board Approval N/A BPMs BPMs N/A External BRS External BRS N/A Tariff Tariff N/A Config Guides Config Guide N/A Tech Spec Tech Spec N/A Market Sim Market Sim Window Aug 23, 2016 - Sep 23, 2016



Production Activation Acceptable Use Policy - CMRI Apr 1, 2017

Spring 2017 - Real Time Dispatch Local Market Power Mitigation

Project Info

Details/Date

Application Software Changes

• CMRI – Display mitigated bids from RTD process
• OASIS (Open Access Sametime Information System): Display RTD

reports for Market Clearing, the Pnode clearing, similar to current RTPD reports

• RTM (Real Time Market)
• RTPD: Perform the LMPM run as an integral part of the binding

interval RTPD run

• RTD: Proposed mitigation in RTD run would work the same way

as the current RTPD run BPM Changes

• Energy Imbalance Market (EIM): under the proposed RTD method,

bids are not necessarily mitigated for the whole hour

• RTD MPM will work the same way as the current RTPD MPM

Business Process Changes

• Manage Markets & Grid
• ATF – System Operations: Add MPM Application to Real Time and

annotate inputs and outputs

• ATF – System Operations, Real Time: Add MPM to diagram with inputs

and outputs

• Level II – Manage Real Time Operations – maintain balancing area

Page 95

Spring 2017 - Real Time Dispatch Local Market Power Mitigation

Page 96 Project CMRI OASIS ADS RTD LMPM Update (add RTD results): MPMResults v3 Update (add RTD results)-

• PRC_MPM_RTM_LMP
• PRC_MPM_RTM_NOMOGRAM
• PRC_MPM_RTM_NOMOGRAM_CMP
• PRC_MPM_RTM_FLOWGATE
• PRC_MPM_CNSTR_CMP
• PRC_MPM_RTM_REF_BUS
• ENE_MPM

N/A

Milestone Type Milestone Name Dates Status

Board Approval Board of Governors (BOG) approval Mar 24, 2016



BPMs Posted Market Operations BPM PRR 945 Nov 04, 2016



External BRS Post External BRS Apr 05, 2016



Tariff Received FERC approval Nov 08, 2016



Tech Spec Publish Technical Specification - OASIS Apr 08, 2016



Publish Technical Specification - CMRI Apr 14, 2016



Market Sim Market Sim Window Jan 31, 2017 - Feb 16, 2017 Production Activation RTD - Local Market Power Mitigation Enhancement Apr 01, 2017

Spring 2017 – Congestion Revenue Rights (CRR) Clawback

Project Info

Details/Date

Application Software Changes MQS/CRR Clawback: If import bid <= day-ahead price, then the import is not considered a virtual award. If export bid >= day-ahead price, then the export is not considered a virtual award. If an import/export bid/self-schedule in real-time market is less than the day-ahead schedule, then the difference shall be still subject to CRR Clawback rule. CRR Clawback rule should include convergence bids cleared on trading hubs and load aggregation points in the flow impact used to determine if the 10% threshold is reached. Inform Market Participants of CRR annual allocation/auction for 2017. BPM Changes Market Operations Appendix F Business Process Changes TBD

Page 97

Milestone Type Milestone Name Dates Status

Board Approval Board of Governors Approval Jun 28, 2016



BPMs Publish Final Business Practice Manuals Jan 30, 2017 External BRS Post External BRS Nov 29, 2016



Tariff File Tariff Jan 20, 2017 Receive FERC order Mar 21, 2017 Production Activation CRR Clawback Modification Apr 01, 2017

Spring 2017 – PIRP Decommissioning

Project Info

Details/Date

Application Software Changes: PIRP/CMRI

• Forecast Data Reporting (resource-level) that was performed in PIRP will be done in
• CMRI. Rolling Hour Ahead, Locked Hour Ahead, and Rolling Day-Ahead forecasts.
• PIRP Decommissioning to occur in 2017
• CMRI to receive the Electricity Price Index for each resource and publish it to the

Market Participants.

• 60 Day PIRP / CMRI parallel production to start when AIM/ACL becomes available.

BPM Changes CMRI Technical Specification; New APIs will be described. Data Transparency

• Independent changes, won’t

impact existing services

• Will be made available in

Production and cutover schedule is discretionary Atlas Reference:

• 1. Price Correction Messages (ATL_PRC_CORR_MSG)
• 2. Scheduling Point Definition (ATL_SP)
• 3. BAA and Tie Definition (ATL_BAA_TIE)
• 4. Scheduling Point and Tie Definition (ATL_SP_TIE)
• 5. Intertie Constraint and Scheduling Point Mapping (ATL_ITC_SP)
• 6. Intertie Scheduling Limit and Tie Mapping (ATL_ISL_TIE)

Energy

• EIM Transfer Limits By Tie (ENE_EIM_TRANSFER_LIMITS_TIE)
• Wind and Solar Summary (ENE_WIND_SOLAR_SUMMARY)

Prices

• MPM Default Competitive Path Assessment List (PRC_MPM_DEFAULT_CMP)

Business Process Changes MPs will receive the VER reports from CMRI rather than PIRP.

Page 98

Spring 2017 – PIRP Decommissioning

Page 99

Milestone Type Milestone Name Dates Status

Board Approval Board Approval N/A BPMs Publish Draft Business Practice Manuals (Market Instruments; PRR 936) Sep 06, 2016



External BRS External Business Requirements Jun 29, 2015



Tariff Tariff Filing Activities N/A Config Guides Settlements Configuration N/A Tech Spec Publish Technical Specifications (CMRI; Wind and Solar) Apr 15, 2016



Publish Technical Specifications (CMRI: PIRP Decommissioning) Feb 05, 2016



Market Sim CMRI Reports; VER Forecast & EPI (Fall 2016 Release) Aug 23, 2016 - Sep 23, 2016



New Renewables CMRI reports and APIs Mar 02, 2017 - Mar 20, 2017 Production Activation CMRI Reports; VER Forecast & EPI (Fall 2016 Release) Oct 01, 2016



OASIS API Enhancements; 9 Reports Dec 20, 2016



New Renewables CMRI reports and APIs April 1, 2017

Spring 2017 – Metering Rules Enhancements

Project Info Details/Date Application Software Changes N/A BPM Changes Metering

• Metering BPM will be updated to reflect the ISO ME vs SC ME role
• ptions, changes to the metering entity election process, and impacts

for metering data access via the metering data submission portal.

• EIM BPM will be updated to explain Metering data reporting access

based on transitions from ISOME to SCME (shall transition to submission of SQMD meter data to Metering Data submission portal) or SCME to ISOME (shall be able to review historical meter data in MRI-S when resource was SCME). Definitions & Acronyms BPM Changes

• New Tariff and Business Process/System acronyms.

Business Process Changes

• Manage Transmission & Resource Implementation
• Manage Market & Reliability Data & Modeling (MMR) (80004)
• ISO Meter Certification (MMR LII)
• Metering Systems Access (Production) (MMR LII)
• Metering System Configuration for Market Resources (MMR

LII)

• Station Power Implementation (MMR LIII)
• Application Flow - Billing & Settlements
• Analyze Missing Measurement Report (MOS LIII)
• Manage Market Billing & Settlements (MOS LII)
• Manage Market Quality System (MOS LII)
• Manage Rules of Conduct (MOS LII)
• Meter Data Acquisition & Processing (MOS LII)
• SCME Self Audit (MOS LII)

Page 100

Spring 2017 – Metering Rules Enhancements

Page 101

Milestone Type Milestone Name Dates Status

Board Approval Board of Governors (BOG) approval Dec 14, 2016



BPMs Market Operations BPM Feb 02, 2017 Energy Imbalance Market BPM Feb 02, 2017 External BRS External Business Requirements N/A Tariff Tariff Filing at FERC Feb 01, 2017 Config Guides Config Guides N/A Tech Spec Tech Spec N/A Market Sim Market Sim Window N/A Production Activation Metering Rules Enhancements Apr 01, 2017

Fall 2017 - Bidding Rules Enhancements – Part B

Page 102

Project Info Details/Date Application Software Changes

• MasterFile:
• Provide ability to submit requests for new fuel regions (Policy Section 8.1.1.3)
• Include resource-specific start-up electricity costs in proxy costs based on wholesale

projected electricity price, unless resource verifies costs incurred are retail rates (RDT change)

• Allow ability to submit a weighting when using a more than one fuel region.
• Automation of the Aliso Canyon process for creating NEW Fuel Regions
• OASIS:
• Publish fuel regions (public information)

Business Process Change

• Manage Transmission & Resource Implementation
• Manage Entity & Resource Maintenance Updates
• Manage Full Network Model Maintenance
• Manage Market Quality System (MQS)

BPMs

Market Instruments, Market Operations, Reliability Requirements Milestone Type Milestone Name Dates Status

Board Approval BOG Approval Mar 25, 2016



BPMs Post Draft BPM changes Jun 15, 2017 External BRS Post External BRS Jan 13, 2017 Tariff File Tariff Jun 01, 2017 Config Guides Prepare Draft Configuration Guides Apr 03, 2017 Tech Spec Publish Tech Specs Apr 03, 2017 Market Sim Market Sim Window Aug 08, 2017 – Sept 08, 2017 Production Activation Bidding Rules Part B Nov 01, 2017

Fall 2017 - Reliability Services Initiative Phase 1B

Project Info Details/Date Status

Application Software Changes

Developments under consideration include: Scope:

• Default flexible qualifying capacity provisions for phase 2 consideration (we might need data collection

performed in order to support RSI Phase 2

• Redesign of Replacement Rule for System RA and Monthly RA Process
• RA Process and Outage Rules for implementation for 2017 RA year
• Scope not delivered in RSI Phase 1A (Grandfathered Contracts, RAAM Decommissioning – SCP & CPM

screens from RAAM to CIRA, Acquired Contracts, OASIS reporting, web services related to APIs for CSP

• ffers, APIs for Generic/Flex Substitutions, and Release of Generic/Flex Subs – UI & API)

Impacted Systems:

• CIRA
• OASIS
• Integration (B2B)
• Settlements
• Decommission RAAM

Business Process Changes

Manage Market & Reliability Data & Modeling Page 103

Milestone Type Milestone Name Dates Status

Board Approval Board Approval May 12, 2015



BPMs Post Draft BPM changes Jun 15, 2017 External BRS Post External BRS Dec 23, 2016



Tariff File Tariff Jun 01, 2017 Config Guides Config Guide Apr 03, 2017 Tech Spec Publish Technical Specifications Apr 03, 2017 Market Sim Market Sim Window Aug 08, 2017 – Sept 08, 2017 Production Activation Reliability Services Initiative Phase 1B Nov 01, 2017

Fall 2017 – Reliability Services Initiative Phase 2

Project Info

Details/Date

Application Software Changes CIRA –

• Modifications to the RA and Supply Plan to show breakdown of local and
• system. Validation rules need to be updated.
• Update planned/forced outage substitution rules
• Allow market participants to select how much system/local MWs to

substitute.

• Modification of UI screens to accommodate system/local MW split.
• Enhance system to handle EFC monthly updates similar to NQC

(workflow change)

• Enhance system to allow exemption from submission of RA Plans for

LSE that have a RA obligation < 1 MW for a given capacity product. Settlements –

• Splitting local from system in upstream RA system could potentially

impact the RAAIM calculation. BPM Changes

• Reliability Requirements: Changes to the monthly RA process
• Settlements and Billing

Business Process Changes Manage Market & Reliability Data & Modeling

• Manage Monthly & Intra-Monthly Reliability Requirements
• Manage Yearly Reliability Requirements

Page 104

Fall 2017 – Reliability Services Initiative Phase 2

Page 105

Milestone Type Milestone Name Dates Status

Board Approval Board of Governor's Approval Oct 27, 2016



BPMs Post Draft BPM changes Jun 15, 2017 External BRS Post External BRS Jan 31, 2017 Tariff File Tariff Jun 01, 2017 Config Guides Config Guide Apr 03, 2017 Tech Spec Publish Technical Specifications Apr 03, 2017 Market Sim Market Sim Window Aug 08, 2017 – Sept 08, 2017 Production Activation Reliability Services Initiative Phase 2 Nov 01, 2017

Project Info Details/Date

Application Software Changes Scope: 1. Clarify use-limited registration process and documentation to determine opportunity costs 2. Each submission evaluated on a case-by-case basis to determine if the ISO can calculate opportunity costs

• ISO calculated; Modeled limitation
• Market Participant calculated; Negotiated limitation

3. Enhanced definition of “use-limited” in response to FERC’s rejection of the proposed definition in Cost Commitment Enhancements Phase 2 4. Change Nature of Work attributes (Outage cards)

• 1. Modify use-limited reached for RAAIM Treatment
• 2. Add new demand response nature of work attribute for RDRR and PDR

5. Market Characteristics

• 1. Maximum Daily Starts
• 2. Maximum MSG transitions
• 3. Ramp rates

Impacted Systems:

• 1. CIRA
• 2. CMRI
• 3. IFM/RTN
• 4. SIBR
• 5. MasterFile
• 6. OASIS
• 7. OMS
• 8. Settlements

BPM Changes Market Instruments, Outage Management, Reliability Requirement, Market Operations, Settlements & Billing Business Process Changes Level II – Manage Reliability Requirements Level II – Manage Day Ahead Market

Page 106

Fall 2017 - Commitment Cost Enhancements Phase 3

Page 107

Fall 2017 - Commitment Cost Enhancements Phase 3 (cont.)

Milestone Type Milestone Name Dates Status

Board Approval Board of Governors (BOG) Approval Mar 25, 2016



BPMs Post Draft BPM changes Jun 15, 2016 Publish Final Business Practice Manuals TBD External BRS Post External BRS Jan 06, 2016 Tariff File Tariff TBD Receive FERC order TBD Config Guides Config Guide Apr 03, 2017 Tech Spec Create ISO Interface Spec (Tech spec) Apr 03, 2017 Market Sim Market Sim Window Aug 08, 2017 – Sept 08, 2017 Production Activation Commitment Costs Phase 3 Nov 01, 2017

Fall 2017 – RTM & EIM Enhancements 2017

Project Info

Details/Date

Application Software Changes ​Address enhancements identified by policy, operations, technology, business and market participants. Requirements are being evaluated for the following:

• EIM Entity access reports
• BAAOP provisioning in AIM
• EIM data report enhancements to support market participant and EIM

entity shadow settlements

• Joint Owned Units modeling
• Allow MSG resource to send actual configuration in telemetry for RTM
• Comprehensive model for startup and transition energy in DAM, RTM,

RTBS, MQS

• Combine the import/export under/over-scheduling histograms to a

single net interchange under/over-scheduling histogram BPM Changes TBD Business Process Changes TBD

Page 108

Page 109

Fall 2017 – RTM & EIM Enhancements 2017 (cont.)

Milestone Type Milestone Name Dates Status

BPMs Draft BPM changes TBD Post Draft BPM changes TBD Publish Final Business Practice Manuals TBD External BRS Post External BRS Jan 20, 2017 Tariff File Tariff TBD Receive FERC order TBD Config Guides Design review - BPM and Tariff SMEs TBD Tech Spec Fall 2017 - Technical Specifications due to external clients Apr 03, 2017 Market Sim Market Sim Window Aug 08, 2017 – Sept 08, 2017 Production Activation EIM Enhancements 2017 Nov 01, 2017

Fall 2017 – EIM Portland General Electric

Project Info Details/Date Application Software Changes Implementation of Portland General Electric as an EIM Entity. BPM Changes EIM BPM will be updated to reflect new modeling scenarios identified during PGE implementation and feedback from PGE. Market Simulation ISO promoted market network model including PGE area to non- production system and allow PGE exchange data in advance of Market Simulation. Parallel Operations August 1 – September 30, 2017

Page 110

Milestone Type Milestone Name Dates Status

Board Approval Board of Governors (BOG) approval N/A BPMs BPMs N/A External BRS External Business Requirements N/A Tariff File EIM Readiness Certification Aug 31, 2017 Tech Spec Tech Spec N/A Market Sim Market Sim Window Jun 6, 2017 – Jul 6, 2017 Production Activation EIM – Portland General Electric Oct 01, 2017

Spring 2018 – EIM Idaho Power Company

Project Info Details/Date Application Software Changes Implementation of Idaho Power Company as an EIM Entity. BPM Changes EIM BPM will be updated if needed to reflect new modeling scenarios identified during Idaho Power implementation and feedback from Idaho Power. Market Simulation December 1, 2017 – January 31, 2018 ISO and Idaho Power continue progress to integrate the Idaho Power network model with the ISO model in a non-production environment to allow Idaho Power to exchange data in advance of Market Simulation. Initial integration testing is expected to begin in August 2017. Parallel Operations February 1, 2018 – March 31, 2018

Page 111

Milestone Type Milestone Name Dates Status

Board Approval Board Approval N/A BPMs BPMs N/A External BRS External BRS N/A Tariff File Tariff Changes with FERC N/A Receive Final FERC Order Tariff Changes N/A Config Guides Config Guide N/A Tech Spec Tech Specs N/A Production Activation EIM - Idaho Power Apr 04, 2018

Short-Term Plan OASIS

The updated OASIS Technical Specifications v4.3.3 include changes noted below:

Page 112

API Report Name Existing Version(XML & CSV) Proposed New Version(XML & CSV) PRC_INTVL_LMP- Changes apply to Group Zip Only One file with all price components within the same zip file- LMP, Congestion , Energy, Loss and GHG Separate file for each price component within the same zip file - LMP, Congestion , Energy, Loss and GHG PRC_RTPD_LMP - Changes apply to Group Zip Only One file with all price components within the same zip file- LMP, Congestion , Energy, Loss and GHG Separate file for each price component within the same zip file - LMP, Congestion , Energy, Loss and GHG PRC_HASP_LMP - Changes apply to Group Zip Only One file with all price components within the same zip file- LMP, Congestion , Energy and Loss Separate file for each price component within the same zip file - LMP, Congestion , Energy and Loss PRC_SPTIE_LMP(RTD,RTPD)- Changes apply to Group Zip only One file with all price components within the same zip file- LMP, Congestion , Energy, Loss and GHG Separate file for each price component within the same zip file - LMP, Congestion , Energy, Loss and GHG TRNS_CURR_USAGE Request allows for past , current and future trade dates No change to current and future trade dates . System will throw - "Invalid Request Error" for requests with past trade dates. TRNS_CURR_USAGE & TRNS_USAGE No restriction on number of transmission id's requested in single zip. System will throw error 1017 which is “Please select a maximum of 10 nodes or use the ALL option.” when you are requesting data for more than 10 transmission id's for single zip.

Short-Term Plan OASIS

OASIS API changes based on query type:

XML Report Name Market Run ID Version Query Type Response file PRC_INTVL_LMP RTM 3 Single node One file with all price components within the same zip file- LMP, Congestion , Energy, Loss and GHG PRC_INTVL_LMP RTM 3 ALL_APNODES One file with all price components within the same zip file- LMP, Congestion , Energy, Loss and GHG PRC_INTVL_LMP RTM 3 ALL Separate file for each price component within the same zip file - LMP, Congestion , Energy, Loss and GHG PRC_HASP_LMP HASP 3 Single node One file with all price components within the same zip file- LMP, Congestion , Energy, Loss and GHG PRC_HASP_LMP HASP 3 ALL_APNODES One file with all price components within the same zip file- LMP, Congestion , Energy, Loss and GHG PRC_HASP_LMP HASP 3 ALL Separate file for each price component within the same zip file - LMP, Congestion , Energy, Loss and GHG PRC_RTPD_LMP RTPD 3 Single node One file with all price components within the same zip file- LMP, Congestion , Energy, Loss and GHG PRC_RTPD_LMP RTPD 3 ALL_APNODES One file with all price components within the same zip file- LMP, Congestion , Energy, Loss and GHG PRC_RTPD_LMP RTPD 3 ALL Separate file for each price component within the same zip file - LMP, Congestion , Energy, Loss and GHG PRC_SPTIE_LMP RTD,RTPD 5 Single node One file with all price components within the same zip file- LMP, Congestion , Energy, Loss and GHG PRC_SPTIE_LMP RTD,RTPD 5 ALL_APNODES One file with all price components within the same zip file- LMP, Congestion , Energy, Loss and GHG PRC_SPTIE_LMP RTD,RTPD 5 ALL Separate file for each price component within the same zip file - LMP, Congestion , Energy, Loss and GHG

Page 113

Short-Term Plan OASIS

OASIS API New Versions - Transition Schedule :

Market Simulation Testing Period : 1/3/2017 - 1/22/2017 Production Transition Period : 1/23/2017 – 2/19/2017

Page 114

XML Report Name Market Run ID Group Name Version Transition Period in Production (01/23/2017-2/19/2017) After Transition Period(2/20/2017

• nwards)

PRC_INTVL_LMP RTM RTM_LMP_GRP 1 Supported Not Supported/ Invalid Request PRC_INTVL_LMP RTM RTM_LMP_GRP 2 Supported Not Supported/ Invalid Request PRC_INTVL_LMP RTM RTM_LMP_GRP 3 Supported Supported PRC_HASP_LMP HASP HASP_LMP_GRP 1 Supported Not Supported/ Invalid Request PRC_HASP_LMP HASP HASP_LMP_GRP 2 Supported Not Supported/ Invalid Request PRC_HASP_LMP HASP HASP_LMP_GRP 3 Supported Supported PRC_RTPD_LMP RTPD RTPD_LMP_GRP 1 Supported Not Supported/ Invalid Request PRC_RTPD_LMP RTPD RTPD_LMP_GRP 2 Supported Not Supported/ Invalid Request PRC_RTPD_LMP RTPD RTPD_LMP_GRP 3 Supported Supported PRC_SPTIE_LMP RTD,RTPD RTD_SPTIE_LMP_GRP, RTPD_SPTIE_LMP_GRP 3 Supported Not Supported/ Invalid Request PRC_SPTIE_LMP RTD,RTPD RTD_SPTIE_LMP_GRP, RTPD_SPTIE_LMP_GRP 4 Supported Not Supported/ Invalid Request PRC_SPTIE_LMP RTD,RTPD RTD_SPTIE_LMP_GRP, RTPD_SPTIE_LMP_GRP 5 Supported Supported

CAISO Web Layer Maintenance

• CAISO is in the process of upgrading UI, web services, and ads web

layer technology to newer versions – Maintain vendor recommended and supported software versions

• Linux Operating System, Apache, Actional Intermediary

– Add support for newer security protocols

• TLS 1.1 and TLS 1.2

– Improve supportability – Add additional logging forensics and diagnostics to help address Production issues

Page 115

CAISO Web Layer Maintenance

• URL’s which will be affected by this upgrade:

– Note: MAPStage has already been upgraded!

Page 116

MAPStage Production

https://portalmap.caiso.com https://portal.caiso.com https://portaleimmap.caiso.com https://portaleim.caiso.com https://wsmap.caiso.com https://ws.caiso.com https://wsstas.caiso.com:4445 https://idpmap.caiso.com https://idp.caiso.com https://reportingmap.caiso.com https://reporting.caiso.com https://adsmap.caiso.com:447 https://adssta.caiso.com:447 https://ads.caiso.com:447

CAISO Web Layer Maintenance

• Changes participants should expect:

– Brief system failovers (will communicate and keep to a minimum) – HTTP error page look/feel will be standardized – B2B WSDL’s generated by the new software @ CAISO may have slight formatting differences or namespace declarations. – RESOLVED: SOAPAction HTTP header is now required to be set for web service transactions

• Note: This item was required as a vendor product default setting; we have disabled.

Sorry for the confusion

• What will not be changing:

–

• asis.caiso.com and www.caiso.com sites will not be upgraded as part of this effort

– AUP (Acceptable Use Policy)

• Additional enforcement is not scheduled to be implemented alongside this work; but will

be communicated via a separate market notices. May go in around the same time.

• AUP violation HTTP return code will remain using HTTP code 429

– URL’s, naming conventions. We will keep all the same current domain names, and URI’ as provided in the System Access Information document – IP Addresses including ECN traffic, routing, and AT&T NAT addressing will not change

Page 117

CAISO Web Layer Maintenance

• What we would like from you now:

– Please test your critical web service calls in MAPStage – We would like help testing MNS messages as before

• Other upcoming web layer changes scheduled or proposed for 2017:

– The Legacy webservices URL https://wsstas.caiso.com:4445 will be scheduled for decommission soon. These URL’s will all work when pointed to https://ws.caiso.com

• Exact date/process will be scheduled and communicated.

– The Production alias https://adssta.caiso.com:447 will be retired in 2017. We would like to ensure all clients are using https://ads.caiso.com:447. This may require an ADS client upgrade.

• Exact date/process will be scheduled and communicated.

– Support for TLS 1.0 will be removed in 2017.

• Exact date/process will be scheduled and communicated.

Page 118

CAISO Web Layer Maintenance

• Questions???

– Please create CIDI tickets for tracking purposes – You may call the CAISO Help Desk @ 916-351-2309 – You may reach John Huetter, Systems Integration @ 916-608-5839

For all support tickets, please provide (the more information, the quicker we can resolve):

– CAISO URL you attempted – Error Message, Error Code, Screenshot – Time of transaction, please include seconds if possible – Certificate Used – Source IP (If available)

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ISO Daily Briefing

• A digest version of ISO market notices
• Distributed Mon-Fri around 1:30 p.m. (Pacific) daily
• To subscribe:
• Go to www.caiso.com
• Under “Stay Informed” tab
• Select “Notifications”
• Click Subscribe here under Market notices heading

Note: If you currently receive ISO market notices and you re-subscribe, the system will override your previous category selections. You’ll need to reselect categories

• f interest.

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Market Performance and Planning Forum 2017 Schedule

• March 14
• May 16
• July 18
• September 19
• November 14

Questions or meeting topic suggestions: Submit through CIDI - select the “Market Performance and Planning Forum” category

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