Market Performance and Planning Forum March 14, 2017 Last updated: - - PowerPoint PPT Presentation

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Market Performance and Planning Forum March 14, 2017 Last updated: - - PowerPoint PPT Presentation

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Market Performance and Planning Forum March 14, 2017 Last updated: March 15, 2017 Objective: Enable dialogue on implementation planning and market performance issues Review key market performance topics Share updates to 2017 release

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Market Performance and Planning Forum

March 14, 2017

Last updated: March 15, 2017

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Objective: Enable dialogue on implementation planning and market performance issues

  • Review key market performance topics
  • Share updates to 2017 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

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Market Performance and Planning Forum

Agenda – March 14, 2017

Time: Topic: Presenter: 10:00 – 10:05 Introduction, Agenda Kristina Osborne 10:05 – 10:20

  • SDG&E Crosstrip Nomogram
  • Peak RC Process Update

Dede Subakti 10:20 – 11:30 Market Performance and Quality Update Guillermo Bautista Alderete Nancy Traweek Amber Motley 11:30 – 12:00 Policy Update Brad Cooper 12:00 – 1:00 Lunch 1:00 – 1:30 Renewable generation market impacts Gabe Murtaugh 1:30 – 2:30 Release Update Adrienne Chiosea Janet Morris

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Dede Subakti Director, Operations Engineering Services

SDG&E Crosstrip Nomogram

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Background

  • High East-West flow on 500 kV lines into Southern California system
  • Contingency of TL50001 could cause overload in the underlying

parallel 230kV lines that would cause RAS to cross trip and open up another 230kV line

  • Objective of the mitigation is to avoid overload in the underlying

parallel 230kV lines and avoid cross tripping.

  • Mitigation: nomogram 7820_TL23040_IV_SPS_NG

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Nomogram definition

  • Nomogram definition is posted in CMRI
  • The nomogram definition takes into account expected

RAS actions

– Note: Specific RAS information cannot be made public due to the nature of the data classification

  • Objective of the nomogram is to avoid overload in the

underlying parallel 230kV lines and avoid cross tripping

  • Limit may be conformed up and down based on the real

time limit based on the real time condition and availability

  • f RAS

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Slide 7

Peak RC Process Update

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Two New Processes Effective April 1, 2017

  • New RC wide outage coordination process to meet the

new NERC IRO-017 Reliability Standard

  • New RC System Operating Limit (SOL) methodology to

meet the spirit of the new NERC TOP/IRO Reliability Standard

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Impact of IRO-017

  • CAISO has filed modification to Section 9 of its Tariff and

the BPM for Outage Management is updated

  • Every BES equipment outage requires RC’s

approval/confirmation – webOMS is updated accordingly to show the RC’s approval/confirmation

Page 9

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Impact of New SOL Methodology

  • It impacts how CAISO calculate System Operating Limit
  • Excerpt from the new methodology

WECC Paths do not have single uniquely monitored SOLs unless the WECC Path is associated with an established transient or voltage stability limit; however, WECC Paths that are associated with scheduling will continue to have TTCs ... This SOL Methodology does not recognize WECC Path Ratings as SOLs. WECC Path Ratings are determined in the planning horizon per the voluntary WECC three-phase rating process. As stated earlier, this SOL Methodology recognizes SOLs to be the Facility Ratings, System Voltage Limits and stability limitations used in operations. If a WECC Path Rating is determined to be “stability limited” per the WECC three-phase rating process, this information can be used by TOPs and the RC to perform further analysis to determine if a stability limit should be established for use in the Operations Horizon; however, the “stability limited” WECC Path Rating itself is not automatically considered as a stability limit (SOL) for use in the Operations Horizon

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Impact of New SOL Methodology

  • Excerpt from the new methodology

While Peak will continue to monitor WECC Path flow relative to WECC Path TTC values for situational awareness purposes, Peak does not acknowledge the TTC as a SOL and does not require operation within TTC values or WECC Path

  • Ratings. Peak monitors the entire BES for SOL exceedance (as described in the

SOL Methodology) and implements Operating Plans as required to address instances of SOL exceedances as determined by RTAs Nomograms may be used to provide System Operators with helpful guidance as part of an Operating Plan; however, they are not considered to be SOLs unless the nomogram represents a region of stability (i.e., the nomogram defines a stability limit).

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Impact of New SOL Methodology

  • Nomogram naming convention are going to changed
  • Since they are not considered SOL, the name SOL will

be taken out of nomogram that are non-stability related

  • The new naming convention will utilize the term “Control

Point” (CP)

  • Procedure:

– Control Point (CP): ####_CP#_NG – Stability Limitation: ####_SOL#_NG

  • Outage:

– OMS_#######_CP#_NG – OMS_#######_SOL#_NG

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Market Performance and Quality Update

Guillermo Bautista Alderete, Ph.D. Director, Market Analysis and Forecasting Nancy Traweek Executive Director, System Operations Amber Motley Manager, Short Term Forecasting

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Over-Supply Update

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Page 15

ISO total monthly VERS schedules and forecasts

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IFM under-scheduling of solar generation

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IFM under-scheduling of wind generation

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Monthly wind (VERS) downward flexibility in FMM

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

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Hydro production already higher than recent historical production

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RTD renewable (VERS) curtailment trended upward since last August

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How are curtailments determined?

  • Priority on real-time schedule types are managed based
  • n synchronized relaxation parameters that are listed in

BPM

  • If economic bids are exhausted self-schedules may be

curtailed pursuant to priority

  • Any self-schedule curtailment based relaxation

parameter is communicated through ADS

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TOR/ETC IFM self schedule RMT Price taker PBC violation Economical bids

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Frequency of negative system prices has steadily increased year over year

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0% 2% 4% 6% 8% 10% 12% 14% 16% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Frequency 2014 2015 2016 2017

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Distribution of negative prices have shifted from early morning hours to midday hours*

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0% 5% 10% 15% 20% 25% 30% 35% 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Frequency 2014 2015 2016 2017

* Metric of 2017 may be over-estimated since it includes only January and February.

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Hydro production is trending higher for Spring

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Self schedules in the real-time market remain high

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Transfer from the ISO to other EIM areas has increased

Page 27 Last updated: March 15, 2017

50 100 150 200 250 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Average Transfer (MW) 2016 2017

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The gross volume of transfers out of the ISO BAA

  • ccurs during midday hours

Page 28 Last updated: March 15, 2017

50 100 150 200 250 300 350 400 450 500 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Transfer (MW) 2016 2017

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The maximum transfer from the ISO to other BAAs in in 2017 have been the highest

Page 29 Last updated: March 15, 2017

500 1000 1500 2000 2500 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Maximum Transfer (MW) 2016 2017

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Load profile in Spring sets conditions for oversupply

Page 30 Last updated: March 15, 2017

15,000 20,000 25,000 30,000 35,000 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)

March 2016

Net Gross 15,000 20,000 25,000 30,000 35,000 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)

April 2016

Net Gross 15,000 20,000 25,000 30,000 35,000 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)

May 2016

Net Gross 15,000 20,000 25,000 30,000 35,000 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)

June 2016

Net Gross

Gross versus Net Load in Spring 2016

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Generation oversupply leading to potential curtailments expected this Spring

  • Real Time Operations is expecting significant oversupply
  • f generation this spring due to load system demand,

exceptional hydro condition, increases solar and wind production.

  • Generation that is not scheduled in the Day Ahead

Market will impact Real Time operations leading to potential self scheduled generation curtailments

  • Identifying oversupply indicators in the D+2 and D+1

timeframe to provide MPs advanced notice of low demand and oversupply conditions

  • Operators will manage real time conditions in

accordance with Overgeneration procedure 2390

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Very short term forecast of potential oversupply

Page 32 Last updated: March 15, 2017

Oversupply Risk Net Load < 20,000 MW VER Forecast > 5,000 MW Cloud Cover Forecast Wind Speed Forecast Load Forecast < 25,000 MW Temperature Forecast Hydro Self Schedule > 3,500MW

Current solar capacity is capable of increasing the risk of oversupply without factoring in wind or hydro schedule Using daily average numbers

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Very short term forecast of potential oversupply

Page 33 Last updated: March 15, 2017

Oversupply Risk Net Load < 16,000 MW VER Forecast > 5,500 MW Cloud Cover Forecast Wind Speed Forecast Load Forecast < 21,500 MW Temperature Forecast Hydro Self Schedule > 4,000 MW

Current solar capacity is capable of increasing the risk of

  • versupply without factoring in wind or hydro schedule

Using daily average numbers

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Aliso Canyon Nomogram

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SoCalGas issued natural gas curtailment watches this winter.

  • SoCalGas issued curtailment watches from January 23

through January 26 arising from cold temperatures and forecasted high gas demand

  • The CAISO implemented gas burn constraints in the

day-ahead and real-time markets to limit the gas burn by electric generation in SCE and SDG&E areas

  • SoCalGas withdrew gas from Aliso Canyon on January

24-25 to maintain gas pressures in its system

  • No gas curtailments to date necessary

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Additional safety measures for natural gas storage will further constrain SoCalGas operations.

  • Constraints at Aliso Canyon for withdraws or injections

this summer will likely continue

  • On February 23, 2017 SoCalGas posted a notice
  • utlining a Storage Safety Enhancement Plan
  • Beginning March 1, SoCalGas will implement storage

enhanced safety measures at La Goleta, Playa del Rey and Honor Rancho

  • SoCalGas forecasts reductions in the maximum

withdrawal capabilities at these gas storage facilities

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Gas conditions in the market were managed using gas nomograms

  • The ISO enforced two gas nomograms during the

curtailment watches. MAXBURN_ALISO_SDGE and MAXBURN_ALISO_TOTAL

  • Shadow prices posted on OASIS
  • Pricing locations do not reflect the shadow prices of the

gas nomograms

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Shadow Prices of MAXBURN_ALISO_SDGE Nomogram show instances where the nomogram had to be relaxed

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Shadow Prices of MAXBURN_ALISO_TOTAL show constraint relaxation in some instances

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Compare RTD, IFM and RUC Gas Burn for all gas resources (fuel provided by SoCalGas)

Date RTD (Mmcfd) IFM (Mmcfd) RUC (Mmcfd) 1/23/2017 410 427 501 1/24/2017 441 448 507 1/25/2017 446 455 484 1/26/2017 458 428 486

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Comparison among IFM, RUC and RTD gas burns

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Flexible Ramp Update

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Flexible Ramp Product Up Requirement

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Flexible Ramp Product Down Requirement

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Flexible Ramp Product Up Awards

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Flexible Ramp Product Down Awards

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Most of the time the EIM area is binding.

Average Flexible Ramp Up Price ($/MWh)

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Average Flexible Ramp Down Price ($/MWh)

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Settlement of Flexible Ramp Product

  • FMM Forecasted Movement Settlement = -1*FMM

forecasted movement quantity * (FMM FRU Price – FMM FRD Price)

  • RTD Forecasted Movement Settlement = -1*(RTD

forecasted movement quantity – FMM forecasted movement quantity) * (RTD FRU Price – RTD FRD Price)

  • Allocation – Scheduling Coordinators with metered

demand (pro-rata share).

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Forecasted Movement

Binding Advisory

…

Forecasted Ramp A A Binding Advisory A RTD Upward example

9:15 9:20 9:25 9:30

Run time 9:07.5 for 9:15

90 MW 100 MW 110 MW

…

Forecasted Movement = 100 – 90 = 10 MW (upward) Settlement = -1*10 MW * ($20 (FRU) - $10 (FRD)) = -$100 (Payment) Binding Advisory A RTD downward example

9:15 9:20 9:25 9:30

Run time 9:07.5 for 9:15

90 MW 85 MW 75 MW

…

Forecasted Movement = 90 – 85 = 5 MW (downward) Settlement = -1*5 MW * ($10(FRU) - $15 (FRD)) = $25 (Charge)

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Forecasted Movement Settlement ISO – From November 1 to February 28, 2017

Scheduled Settlement Correction

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Uncertainty Movement – Example

Binding Advisory B A

…

A RTD Run 1 RTD Run 2

9:15 9:20 9:25 9:30

Run time 9:07.5 for 9:15 Run time 9:12.5 for 9:20

90 MW 100 MW 110 MW 107 MW 113 MW

…

Uncertainty movement = 107 – 100 MW = 7 MW (upward)

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Uncertainty Up Settlement has increased in recent months

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Once normalized for capacity procured, FRP settlements in the same range as in prior months

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FRP Up Uncertainty Payment Amount – Nov 1, 2016 to February 2017

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FRP Down Uncertainty Payment Amount – Nov 1, 2016 to February 28, 2017

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Flex Ramp Up Payment following hourly ramp profile

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Flex Ramp Down Payment – Hourly Distribution

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Market Update

Page 59 Last updated: March 15, 2017

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Good price convergence between FMM and RTD in February.

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RT prices lower than DA prices for both NP15 and SP 15 in January and February.

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Insufficient upward ramping capacity in ISO stayed at low levels since last November.

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Insufficient downward ramping capacity increased in January and February.

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Congestion revenue rights market revenue inadequacy without auction revenues.

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Congestion revenue rights market revenue sufficiency including auction revenues.

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Exceptional dispatch volume in the ISO area remained low in January and February.

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Daily exceptional dispatches by reason

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Real-time Bid cost recovery increased slightly in January and February

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Bid cost recovery (BCR) by Local Capacity Requirement area

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Minimum online commitment (MOC)

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Pmax of MOC Cleared Units

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Enforcement of minimum online commitments in November and December

MOC Name Number (frequency) of hours in January and February Humboldt 7110 1397 MOC East Nicolaus 1128 Orange County 7630 383 DEVERS SOUTH MOC 68 MOC Devers South 35 MOC Drum 30 MOC SAN ONOFRE BUS 25 MOC Wise 4611490 15 MOC Pease 10 MOC Moss 4513897 10 SCIT MOC 9 SDGE 7820 All In Service 4

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Renewable (VERS) schedules including net virtual supply and aligns with VER forecast in January and February

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

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

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ISO area RTIEO increased in January and February.

2016 2017 (YTD) RTCO $50,468,470 $3,434,789 RTIEO

  • $3,797,744

$9,402,400 Total Offset $46,670,726 $12,837,189

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CAISO Price correction events increased in February

1 2 3 4 5 6 7 8 9 10 Jan-16 Feb-16 Mar-16 Apr-16 May-16 Jun-16 Jul-16 Aug-16 Sep-16 Oct-16 Nov-16 Dec-16 Jan-17 Feb-17 Count of Events Process Events Software Events Data Error Events Tariff Inconsistency

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EIM-Related Price correction events increased in February

2 4 6 8 10 12 14 16 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb 2016 2017 Count of Events Process Events Software Events Data Error Events Tariff Inconsistency

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EIM Interruption in NV Energy balancing area

  • 3/6/17 17:35 to 3/10/17 18:00 EIM Interruption in NVE

BAA declared due to planned transmission outage resulting in split of NVE system

  • Interruption declared to mitigate potential abnormal

conditions resulting from split of imbalance conditions

  • During interruption EIM transfer to/from NVE were

limited while NVE maintained balance

  • Posted prices are being reviewed and subject to

administrative pricing or price corrections.

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EIM Price trends

Page 79

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EIM transfers between BAAs*

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PAC W

PAC E

NEV P

AZP S

PSE I

(304MW, 1230MW) (123MW, 917MW) (88MW, 300MW) (244MW, 963MW) (93MW, 766MW) (0MW, 0MW) *Notation: (average, maximum)

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EIM BCR declined in February

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EIM Manual Dispatch increased in February

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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 2015 2016 2017

MAPE

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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 2015 2016 2017

MAPE

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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 2015 2016 2017

MAE

**In 2015-2016, Economic dispatches are not added back in to the generation data. **The 2017 generation data used for accuracy calculation contains the economically dispatched MW.

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Day-ahead solar 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 2015 2016 2017

MAE

**In 2015-2016, Economic dispatches are not added back in to the generation data. **The 2017 generation data used for accuracy calculation contains the economically dispatched MW.

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Real-time wind forecast

0.0% 0.5% 1.0% 1.5% 2.0% 2.5% 3.0% 3.5% 4.0% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2015 2016 2017

MAE

**2015-2016 represent the accuracy of the forecast made each hour at xx:55 for the following hour, i.e. the 5-65 minute ahead forecast. Economic dispatches are not added back in to the generation data. **2017 has been changed to track the RTD accuracy, i.e. the forecast made 7.5 minutes before the binding

  • interval. The 2017 generation data used for accuracy calculation contains the economically dispatched MW.

**This forecast accuracy is pulled directly from the CAISO Forecasting System.

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Real-time solar forecast

0% 1% 2% 3% 4% 5% 6% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2015 2016 2017

MAE

**2015-2016 represent the accuracy of the forecast made each hour at xx:55 for the following hour, i.e. the 5-65 minute ahead forecast. Economic dispatches are not added back in to the generation data. **2017 has been changed to track the RTD accuracy, i.e. the forecast made 7.5 minutes before the binding

  • interval. The 2017 generation data used for accuracy calculation contains the economically dispatched MW.

**This forecast accuracy is pulled directly from the CAISO Forecasting System.

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Policy Update

Brad Cooper Manager, Market Design and Regulatory Policy

Page 89

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Ongoing policy stakeholder initiatives

  • Bid cost recovery enhancements

– Suspended due to FERC uplift allocation NOPR

  • Stepped constraint parameters

– Closed initiative – Will address changes to penalty prices appropriate for for increased bid cap under FERC Order 831 separately

  • Contingency modeling enhancements
  • Fourth revised straw proposal including prototype results in late

March to early April

  • July CAISO Board Meeting

Page 90

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  • Generator contingency and remedial action scheme

modeling

– Revised straw proposal posted March 15 – July EIM Governing Body and CAISO Board Meeting

  • Energy storage and distributed energy resources (ESDER)

Phase 2

– Publish third revised straw proposal in April – July CAISO Board meeting – Publish ESDER Phase 3 issue paper in September

Page 91

Ongoing policy stakeholder initiatives (continued)

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Ongoing policy stakeholder initiatives (continued)

  • Commitment Costs and Default Energy Bid Enhancements

– Stakeholder workshops in late March and April – Straw proposal in May – September 2017 EIM Governing Board and CAISO Board Meetings

  • EIM Greenhouse Gas Enhancements

– Coordinating with ARB – Developing approach to evaluate two-step model prior to finalizing design – Late 2017/early 2018 EIM Governing Board and CAISO Board Meetings

Page 92

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Ongoing policy stakeholder initiatives (continued)

  • Flexible resource adequacy criteria and must-offer
  • bligation – phase 2

– Q1 2018 CAISO Board Meeting – Q2 2018 FERC Filing

  • Frequency response – phase 2

– Late March workshop – 2018 CAISO Board Meeting

  • Review Transmission Access Charge Structure

– Background white paper published in late March – Publish issue paper first week of July

  • Blackstart and system restoration phase 2

– Final draft proposal and stakeholder call in March – May CAISO Board meeting with associated Tariff changes

Page 93

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Policy stakeholder initiatives coming soon

  • Planned to start in Q2 2017

– Resource adequacy enhancements

  • Stakeholder engagement estimated in Q3

– Economic and maintenance outages

  • Publish Issue paper in in April

– CRR auction efficiency

  • Stakeholder working group on analysis in late March – early

April

– Management of EIM Imbalance Settlement for Bilateral Schedule Changes

  • Schedule TBD

– Risk-of-Retirement Process Enhancements

  • Schedule TBD

Page 94

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Renewable generation market impacts

Gabe Murtaugh Senior Analyst, Monitoring and Reporting Department of Market Monitoring

Page 95

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Solar generation increased by almost 33 percent in 2016.

Page 96

5,000 10,000 15,000 20,000 25,000 Solar Wind Geothermal Biogas/Biomass Generatioin (GWh) 2013 2014 2015 2016

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Prices mirrored net load patterns in 2016.

Page 97

5,000 10,000 15,000 20,000 25,000 30,000 35,000 $0 $10 $20 $30 $40 $50 $60 $70 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Average net system load (MW) Price ($/MWh) Day-ahead 15-minute Average net load

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As the ISO integrated more renewables, prices have been negative more frequently.

Page 98

0% 1% 2% 3% 4% 5% 6% 2012 2013 2014 2015 2016 Percent of 5-minute intervals Below -$145

  • $145 to -$50
  • $50 to $0
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As more solar has been added, negative price patterns have shifted.

Page 99

0% 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 Percent of negative 5-minute intervals 2012 2014 2016

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Participants typically bid solar into the market between -$25/MWh and $0/MWh.

Page 100

  • 1,500
  • 1,000
  • 500

500 1,000 1,500 2,000 2,500 3,000 below -$50

  • $50 to -$25
  • $25 to $0

$0 to $25 $25 to $50 above $50 Average hourly MW Natural Gas Hydro Geothermal Wind Solar Other

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Despite more frequent negative prices, curtailments decreased in 2016.

Page 101

500 1,000 1,500 2,000 2,500 3,000 3,500 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 Self schedule curtailment MWh Solar Wind Water Natural Gas Other Geothermal Nuclear

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California exported energy to neighboring EIM areas during midday hours in 2016.

Page 102

  • 200
  • 150
  • 100
  • 50

50 100 150 200 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Imports into NV Energy (MW) California ISO to NV Energy

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Release Plan Update Janet Morris Director, Program Office

Page 103

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Release Plan 2017

Page 104

Independent 2017

  • Settlements Release - Spring 2017
  • MRI-S ACL Groups + CPG Enhancements (formerly OMAR Replacement)
  • Reactive Power Requirements and Financial Compensation
  • Administrative Pricing Policy Update
  • RIMS Functional Enhancements

Spring 2017 (4/1/17)

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

Fall 2017 (11/1/17)

  • EIM Portland General Electric (PGE) – 10/1/17
  • Bidding Rules Enhancements – Part B
  • Reliability Services Initiative Phase 1B
  • Reliability Services Initiative Phase 2
  • Commitment Cost Enhancement Phase 3
  • RM & EIM 2017 Enhancements
  • Gas Burn Report
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SLIDE 105

Release Plan – 2018 and subject to further planning

Page 105

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

Spring 2019

  • EIM 2019 Seattle City Light
  • EIM 2019 Balancing Authority of Northern California (BANC)

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
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Page 106

Settlements Release – Spring 2017

ISSUE SUMMARY BPM IMPACTED

Update configuration guide to compare the Balancing Authority Area Meter Load Quantity to the Balancing Authority Area Base Load Schedule instead of comparing Balancing Authority Area Meter Demand Quantity to Balancing Authority Area Base Load Scheduling when assessing Over and Under Scheduling EIM Settlement. PRR 969: (CC 6045) Update Pre-calculation RTM Net Amount to resolve two issues that relate to (1) the application of the Persistent Deviation Metric (PDM) and (2) the determination of BCR bid cost for a net-settled MSS. PRR 970: (RTM Net Amount PC) Settlement BPM and Charge Code updates for T+33M Settlement Statement implementation (Documentation Only) PRR TBD: (CC 7989, CC 7999, Settlement Main Body BPM) RAAIM - Flex Categories 2 and 3 Assessment Hour Updates (Documentation Only) PRR 968: (RA Availability Incentive Mechanism PC)

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SLIDE 107

Page 107

Settlements Release – Spring 2017

Milestone Date

Status

Configuration Guides Posted February 10, 2017 DRAFT Configuration Output File Posted March 10, 2017 SAMPLE statement for trade date 3/8/2017 Published March 14, 2017 Pre-Production DRAFT Configuration Output File Posted March 20, 2017 Production Deployment March 27, 2017 FINAL Configuration Output File Posted March 27, 2017

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SLIDE 108

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. There will be no market simulation of AIM ACL groups but this functionality will be live in production to support the MRI-S Metering CPG enhancements market simulation. A customer partnership group will be scheduled to address the upcoming market sim.

BPM Changes

None

Business Process Changes

Potential Level-II business process changes under –

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

Page 108

Milestone Type Milestone Name Dates Status

Board Approval Board Approval N/A BPMs Business Practice Manuals 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 MRI-S Metering Enhancements Mar 13, 2017 - Apr 07, 2017 Production Activation Phase 1 – ACL Groups Mar 10, 2017

Phase 2 - MRI-S Metering Enhancements Apr 05, 2017 OMAR Decommissioning OMAR System Decommissioning (+4 month transition) July 14

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SLIDE 109

MRI-S ACL Groups + CPG Enhancements

Page 109

* 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. In process 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

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

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SLIDE 110

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):

Requirement for non-synchronous resources providing dynamic reactive power pursuant to FERC Order No. 827 to employ an automatic voltage regulator system.

Page 110

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 Dec 6, 2016

FERC Approval March 2, 2017

Configuration 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 Mar 06, 2017 FERC approved filing subject to refund and further FERC order

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SLIDE 111

2017 – Administrative Pricing Policy Updates

Page 111

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 Mar 13, 2017 External BRS Post External BRS Mar 20, 2015

Tariff Tariff Approval Jan 30, 2017

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 Administrative Pricing Policy Updates Apr 18, 2017 – no later than 5/16

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SLIDE 112

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 112

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 Dec 14, 2017

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SLIDE 113

Spring 2017 Release – Overview

Page 113

Board Approval BPMs External BRS Tariff Config Guide Tech Spec Market Sim Production Activation Spring 2017 Release Acceptable Use Policy - CMRI

N/A N/A N/A N/A N/A N/A 8/23/16 - 9/23/16 4/1/17

RTD LMPM Enhancements

3/24/16 11/4/16 4/5/16 FERC approved effective date of 4/1/17 N/A 4/14/16 2/7/17 - 2/24/17 Target 4/18, no later than 5/16

CRR Clawback Modifications

6/28/16 2/10/17 11/29/16 FERC approved effective date of 4/1/17 N/A N/A N/A

Forecasting and Data Transparency Improvements (PIRP Decommissioning)

N/A 9/6/16 6/29/15 N/A N/A 4/15/16 3/21/17 - 4/4/17 4/5/17

Metering Rules Enhancement

12/14/16 2/2/17 N/A Filed with FERC

  • n 2/8/17

N/A N/A N/A 4/10/17

COMPLETE N/A

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SLIDE 114

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 114

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 01, 2017

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SLIDE 115

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 115

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SLIDE 116

Spring 2017 - Real Time Dispatch Local Market Power Mitigation

Page 116

Updated OASIS technical specifications 4.3.5

  • http://www.caiso.com/Documents/OASIS-

InterfaceSpecification_v4_3_5Clean_Spring2017Release.pdf

  • Updated the following MPM Services ( Spring 2017)
  • Updated PRC_MPM_RTM_REF_BUS to add support for RTD LMPM.
  • Updated PRC_MPM_RTM_NOMOGRAM_CMP to add support for RTD LMPM.
  • Updated PRC_MPM_CNSTR_CMP to add support for RTD LMPM.

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

Received FERC approval for 4/1 Jan 27, 2017

File updated APR 1 deployment date Jan 13, 2017

Tech Spec Publish Technical Specification - OASIS Apr 08, 2016

Publish Technical Specification - CMRI Apr 14, 2016

Market Sim Market Sim Window Feb 06, 2017 - Feb 24, 2017

Production Activation RTD - Local Market Power Mitigation Enhancement Apr 18, 2017 – no later than 5/16

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SLIDE 117

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 117

Milestone Type Milestone Name Dates Status

Board Approval Board of Governors Approval Jun 28, 2016

BPMs Posted Market Operations BPM PRR 972 Feb 10, 2017

External BRS Post External BRS Nov 29, 2016

Tariff File Tariff Jan 25, 2017

Tariff Receive FERC order Mar 7, 2017

Production Activation CRR Clawback Modification Apr 18, 2017 – no later than 5/16

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SLIDE 118

Spring 2017 – Forecasting and Data Transparency Improvements (PIRP System 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 118

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SLIDE 119

Spring 2017 – Forecasting and Data Transparency Improvements (PIRP System Decommissioning)

Project Info

Details/Date

User-Provisioning process for CMRI in preparation of Market Simulation and subsequently for production

  • Client Services will reach out to the User Access Administrator (UAA)
  • Updated AIM User Guide, detailing how to create new ACL groups, was posted on

February 21, 2017 - The market notice was posted on February 23, 2017

  • If a user is at the SC level, there is no need to provision ACL access
  • Exceptions - (Non-SC Level Users) – provisioning via AIM will be required
  • Provisioning will be required to be done prior to Market Simulation
  • Provisioning for PIRP via AARF will discontinue on Feb 16, 2017 for Map Stage and

Mar 20, 2017 for Production.

  • Participants should begin to download their PIRP data (all reports) as soon as possible

as the data will not be available after June 1, 2017

  • PIRP application including all the UI and API reports will be decommissioned June 6,

2017

  • If you have any questions please contact your client services representative

Page 119

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SLIDE 120

Spring 2017 – Forecasting and Data Transparency Improvements (PIRP System Decommissioning)

Page 120

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 Market Simulation Mar 21, 2017 - Apr 04, 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 Production Deployment Apr 05, 2017 PIRP Decommission PIRP System Decommissioning Jun 06, 2017

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SLIDE 121

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 121

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SLIDE 122

Spring 2017 – Metering Rules Enhancements

Page 122

Milestone Type Milestone Name Dates Status

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

BPMs Metering BPM Feb 02, 2017

Energy Imbalance Market BPM Feb 02, 2017

External BRS External Business Requirements N/A Tariff Tariff Filing at FERC Feb 08, 2017

Config Guides N/A N/A Tech Spec N/A N/A Production Activation Metering Rules Enhancements Apr 10, 2017 upon FERC approval

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SLIDE 123

Fall 2017 Release – Overview

Page 123 Board Approval BPMs External BRS Tariff Config Guide Tech Spec Market Sim Production Activation

Fall 2017 Release

EIM Portland General Electric N/A N/A N/A 8/31/17 N/A N/A 6/6/17 - 7/6/17 10/1/17 Bidding Rules Enhancements - Part B 3/25/16 6/15/17 1/13/17 6/1/17 6/27/17 4/3/17 8/8/17 - 9/8/17 11/1/17 Reliability Services Initiative Phase 1B 5/12/15 12/23/16 Reliability Services Initiative Phase 2 10/27/16 1/31/17 Commitment Cost Enhancement Phase 3 3/25/16 1/6/17 TBD RM & EIM 2017 Enhancements TBD TBD 2/17/17 (Updates) 7/31/17 Gas Burn Reports N/A N/A 7/29/16 N/A N/A N/A COMPLETE N/A

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SLIDE 124

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 124

Milestone Type Milestone Name Dates Status

Tariff File Readiness Certification Aug 31, 2017 Market Sim Market Sim Window Jun 6, 2017 – Jul 6, 2017 Parallel Operations Parallel Operations Window Aug 1, 2017 – Sep 30, 2017 Production Activation EIM - Portland General Electric Oct 01, 2017

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SLIDE 125

Fall 2017 - Bidding Rules Enhancements – Part B

Page 125

Project Info Details/Date Application Software Changes

  • MasterFile:
  • Electric Region added to GRDT as non-modifiable
  • OASIS:
  • Publish fuel regions (public information)

Business Process Change

  • Manage Transmission & Resource Implementation
  • Manage Entity & Resource Maintenance Updates
  • Manage Full Network Model Maintenance

BPMs

Market Instruments, 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 June 27, 2017 Tech Spec Publish CMRI Tech Specs Apr 03, 2017 Market Sim Market Sim Window Aug 08, 2017 - Sep 08, 2017 Production Activation Bidding Rules Part B Nov 01, 2017

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SLIDE 126

Fall 2017 - Reliability Services Initiative Phase 1B

Project Info Details/Date Status

Application Software Changes

Developments under consideration include: Scope:

  • 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 (OASIS reporting),

Impacted Systems:

  • CIRA
  • OASIS
  • Settlements

Business Process Changes

Manage Market & Reliability Data & Modeling

Page 126

Milestone Type Milestone Name Dates Status

Board Approval Board Approval May 12, 2015

BPMs Post Draft BPM changes Jun 15, 2017 External BRS Post Updated External BRS v1.3 Mar 03, 2017

Tariff File Tariff Jun 01, 2017 Config Guides Config Guide June 27, 2017 Tech Spec Publish Technical Specifications Apr 03, 2017 Market Sim Market Sim Window Aug 08, 2017 - Sep 08, 2017 Production Activation Reliability Services Initiative Phase 1B Nov 01, 2017

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SLIDE 127

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 allow exemption from submission of RA Plans for LSE that have a RA
  • bligation < 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 127

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SLIDE 128

Fall 2017 – Reliability Services Initiative Phase 2

Page 128

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 June 27, 2017 Tech Spec Publish Technical Specifications Apr 03, 2017 Market Sim Market Sim Window Aug 08, 2017 - Sep 08, 2017 Production Activation Reliability Services Initiative Phase 2 Nov 01, 2017

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SLIDE 129

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 129

Fall 2017 - Commitment Cost Enhancements Phase 3

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SLIDE 130

Page 130

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, 2017 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 June 27, 2017 Tech Spec Create ISO Interface Spec (Tech spec) Apr 03, 2017 Market Sim Market Sim Window Aug 08, 2017 – Sep 8, 2017 Production Activation Commitment Costs Phase 3 Nov 01, 2017

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SLIDE 131

Fall 2017 – RM & EIM Enhancements 2017

Project Info

Details/Date

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

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

entity shadow settlements

  • Shared BAA Resource Modeling
  • Change to ETSR formulation to separate base energy transfer to

distinct non-optimizable ETSRs. BPM Changes TBD Business Process Changes TBD

Page 131

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SLIDE 132

Page 132

Fall 2017 – RM & 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 Updated External BRS to public site Feb 17, 2017

Tariff File Tariff Jul 31, 2017 Receive FERC order Nov 01, 2017 Config Guides Design review - BPM and Tariff SMEs TBD Configuration Guides due June 27, 2017 Tech Spec Technical Specifications due Apr 03, 2017 Market Sim Market Sim Window Aug 08, 2017 - Sep 08, 2017 Production Activation EIM Enhancements 2017 Nov 01, 2017

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SLIDE 133

Fall 2017 – Gas Burn Reports

Page 133

Project Info Details/Date Application Software Changes

CMRI - implement ISO Market software functionality to calculate and present gas burn estimates to gas companies serving electric generation located within the CAISO BAA

Business Process Change

  • Develop Infrastructure
  • Manage Market & Reliability Data & Modeling

Milestone Type Milestone Name Dates Status

Board Approval BOG Approval N/A BPMs Post Draft BPM changes N/A External BRS External Business Requirements Jul 29, 2016

Tariff Receive FERC order N/A Config Guides Prepare Draft Config Guide N/A Tech Spec Publish Technical Specifications - CMRI Apr 03, 2017 Market Sim Market Sim Window N/A Production Activation GenDB MF Consol and Gas Burn Report Nov 01, 2017

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SLIDE 134

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 The ISO approved the Idaho Power network model and continues to make progress integrating the Idaho model into the ISO non-production environment in preparation for integration testing. Parallel Operations February 1, 2018 – March 30, 2018

Page 134

Milestone Type Milestone Name Dates Status Tariff File Readiness Certification Feb 28, 2018 Market Sim Market Sim Window Dec 01, 2017 - Jan 31, 2018 Parallel Operations Parallel Operations Window Feb 01, 2018 - Mar 30, 2018 Production Activation EIM - Idaho Power Apr 04, 2018

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SLIDE 135

Short-Term Plan OASIS

OASIS API New Versions - Transition Schedule :

Market Simulation Testing : Available from 1/3/2017 Production Deployment – 2/2/2017 Production Transition Period : 2/02/2017 – 3/31/2017

Page 135

XML Report Name Market Run ID Group Name Version Transition Period in Production After Transition Period(4/1/2017

  • 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 DAM,RTD,RTPD DAM_SPTIE_LMP_GRP, RTD_SPTIE_LMP_GRP, RTPD_SPTIE_LMP_GRP 3 Supported Not Supported/ Invalid Request PRC_SPTIE_LMP DAM,RTD,RTPD DAM_SPTIE_LMP_GRP, RTD_SPTIE_LMP_GRP, RTPD_SPTIE_LMP_GRP 4 Supported Not Supported/ Invalid Request PRC_SPTIE_LMP DAM,RTD,RTPD DAM_SPTIE_LMP_GRP, RTD_SPTIE_LMP_GRP, RTPD_SPTIE_LMP_GRP 5 Supported Supported

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SLIDE 136

Short-Term Plan OASIS

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

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API Report Name Existing Proposed Changes

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 New Version -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 New Version -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 New Version -Separate file for each price component within the same zip file - LMP, Congestion , Energy and Loss PRC_SPTIE_LMP(DAM,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 New Version - 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 Existing Version - 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. Existing Version - 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.

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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 DAM,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 DAM,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 DAM,RTD,RTPD 5 ALL Separate file for each price component within the same zip file - LMP, Congestion , Energy, Loss and GHG

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ISO Daily Briefing

  • A digest version of ISO market notices
  • Distributed daily, Mon-Fri around 1:30 p.m. (PST)
  • NEW: Upcoming Events - Every Thursday the briefing

will include stakeholder activities for the following week

  • To subscribe to the Daily Briefing:
  • Go to www.caiso.com
  • Under “Stay Informed” tab
  • Select “Notifications”
  • Click under Market notices heading
  • Select Daily Briefing from the list of categories

Note: If you currently receive ISO market notices and you re-subscribe, the system will override your previous category selections. If you still want to receive market notices in other categories, you’ll need to reselect those categories of interest.

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Market Performance and Planning Forum 2017 Schedule

  • 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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