market performance and planning forum - california · pdf file• discuss external impacts...
TRANSCRIPT
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 ForumAgenda – 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
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
outage 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
order 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 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
Flexible Ramp requirements and prices
Page 14
Last updated: January 17, 2017
$0
$50
$100
$150
$200
-1,500
-1,000
-500
0
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
Ave
rage
Ho
url
y Fl
ex R
amp
Pri
ce (
$/M
W)
Ave
rage
Ho
url
y Fl
ex R
amp
Req
uir
emen
t (M
W)
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
Examples: December Regulation RequiredSolid – 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
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 32
Enforcement of minimum online commitments in
November and December
MOC NameNumber (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 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 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
0
1
2
3
4
5
6
7
8
9
10
Jan
-15
Feb
-15
Mar
-15
Ap
r-1
5
May
-15
Jun
-15
Jul-
15
Au
g-1
5
Sep
-15
Oct
-15
No
v-1
5
De
c-1
5
Jan
-16
Feb
-16
Mar
-16
Ap
r-1
6
May
-16
Jun
-16
Jul-
16
Au
g-1
6
Sep
-16
Oct
-16
No
v-1
6
De
c-1
6
Co
un
t o
f Ev
ents
Process Events Software Events Data Error Events Tariff Inconsistency
Page 44
EIM-Related Price correction events increased in November
and December
0
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
Co
un
t o
f Ev
ents
Process Events Software Events Data Error Events Tariff Inconsistency
Day-ahead load forecast
0.0%
0.5%
1.0%
1.5%
2.0%
2.5%
3.0%Jan
Feb
Ma
r
Ap
r
Ma
y
Jun
Jul
Au
g
Se
p
Oct
No
v
De
c
2014 2015 2016
MA
PE
Day-ahead peak to peak forecast accuracy
0.0%
0.5%
1.0%
1.5%
2.0%
2.5%
3.0%
3.5%Jan
Fe
b
Ma
r
Ap
r
Ma
y
Jun
Jul
Au
g
Se
p
Oct
No
v
De
c
2014 2015 2016
MA
PE
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
Fe
b
Ma
r
Ap
r
Ma
y
Jun
Jul
Au
g
Se
p
Oct
No
v
De
c
2014 2015 2016
MA
E
Day-ahead solar forecast
0.0%
2.0%
4.0%
6.0%
8.0%
10.0%
12.0%
14.0%Jan
Fe
b
Ma
r
Ap
r
Ma
y
Jun
Jul
Au
g
Se
p
Oct
No
v
De
c
2014 2015 2016
MA
E
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
Fe
b
Ma
r
Ap
r
Ma
y
Jun
Jul
Au
g
Se
p
Oct
No
v
De
c
2014 2015 2016
MA
E
Real-time solar forecast
0%
1%
2%
3%
4%
5%
6%Jan
Fe
b
Ma
r
Ap
r
Ma
y
Jun
Jul
Au
g
Se
p
Oct
No
v
De
c
2014 2015 2016
MA
E
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.
𝐹𝑙𝑒𝑥 𝑅𝑎𝑚𝑝 𝑈𝑝 𝑅𝑒𝑞𝑢𝑖𝑟𝑒𝑚𝑒𝑛𝑡
= ∆𝐿𝑜𝑎𝑑 + 𝐹𝑙𝑒𝑥 𝑈𝑝 𝑈𝑛𝑐𝑒𝑟𝑡𝑎𝑖𝑛𝑡𝑦 + max−𝑁𝑒𝑡 𝐼𝑚𝑝𝑜𝑟𝑡 𝐶𝑎𝑝𝑎𝑏𝑖𝑙𝑖𝑡𝑦,
−𝐷𝑖𝑣𝑒𝑟𝑠𝑖𝑡𝑦 𝐵𝑒𝑛𝑒𝑓𝑖𝑡 − 𝐹𝑙𝑒𝑥 𝑅𝑎𝑚𝑝 𝑈𝑝 𝐶𝑟𝑒𝑑𝑖𝑡
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
0
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
0
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
Ex
po
rts
Imp
ort
s
Sufficiency test example –
PacifiCorp West Hour 17
𝐹𝑙𝑒𝑥 𝑅𝑎𝑚𝑝 𝑈𝑝 𝑅𝑒𝑞𝑢𝑖𝑟𝑒𝑚𝑒𝑛𝑡
= ∆𝐿𝑜𝑎𝑑 + 𝐹𝑙𝑒𝑥 𝑈𝑝 𝑈𝑛𝑐𝑒𝑟𝑡𝑎𝑖𝑛𝑡𝑦 + max−𝑁𝑒𝑡 𝐼𝑚𝑝𝑜𝑟𝑡 𝐶𝑎𝑝𝑎𝑏𝑖𝑙𝑖𝑡𝑦,
−𝐷𝑖𝑣𝑒𝑟𝑠𝑖𝑡𝑦 𝐵𝑒𝑛𝑒𝑓𝑖𝑡 − 𝐹𝑙𝑒𝑥 𝑅𝑎𝑚𝑝 𝑈𝑝 𝐶𝑟𝑒𝑑𝑖𝑡
• 𝐹𝑙𝑒𝑥 𝑅𝑎𝑚𝑝 𝑈𝑝 𝑅𝑒𝑞𝑢𝑖𝑟𝑒𝑚𝑒𝑛𝑡 = 197 + 97 +max−1,064,−56 − 158
= 80
• 𝑈𝑝𝑤𝑎𝑟𝑑 𝑟𝑎𝑚𝑝𝑖𝑛𝑔 𝑐𝑎𝑝𝑎𝑐𝑖𝑡𝑦 𝑎𝑣𝑎𝑖𝑎𝑏𝑙𝑒 = 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
0
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
0
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October November December
Nu
mb
er
of
ho
urs
wh
ere
th
e
su
ffic
ien
cy t
es
t fa
ile
d
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.
0
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November December
Nu
mb
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urs
wh
ere
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e s
uff
icie
nc
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tes
t fa
ile
d
PACE PACW NEVP PSEI AZPS
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
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-
LAPNew 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_PGLPSLAP_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
open 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
outside 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
The ISO offers comprehensive training programs
83
Training calendar - http://www.caiso.com/participate/Pages/Training/default.aspx
Contact us - [email protected]
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 ChangesPotential 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
TariffFile 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 ChangesFunctional 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
ProjectCMRI 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 DecommissioningProject 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
BPMsPublish 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
options, 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
offers, 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 ChangesMarket Instruments, Outage Management, Reliability Requirement, Market Operations,
Settlements & Billing
Business Process ChangesLevel 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 ChangesEIM 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
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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
onwards)
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
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CAISO Web Layer Maintenance
• URL’s which will be affected by this upgrade:– Note: MAPStage has already been upgraded!
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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:
– oasis.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
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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.
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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)
Page 119
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
of interest.
Page 120