CAISO 15-Min Liquidity
Transcript of CAISO 15-Min Liquidity
CAISO 15-Min LiquidityCAISO Stakeholder Meeting
October 6, 2015
Alex SpainTrading Floor ManagerPower ServicesBPA
Dave DernovsekDay Ahead TraderPower ServicesBPA
Presentation Objectives
Federal Columbia River Power System (FCRPS) • Facts and Myths
CAISO HASP/FMM Liquidity Impediments• Operational Considerations
• Transmission Utilization
• Market Issues
CAISO HASP/FMM Liquidity Solutions
2
FCRPS: Facts
3
FCRPS is a partnership– US Army Corps of Engineers
(Corps)
– US Bureau of Reclamation
(Reclamation)
– Bonneville Power Administration
(BPA)
FCRPS 31 hydro plants– 21 Corps (14,651 MWs)
– 10 Reclamation (7,807 MWs)
– 209 Generating Units ranging from 1 MW (Boise Diversion) to 805 MW (Grand Coulee)
Canada has 15% basin area, but provides 30% of ave annual flow at The Dalles
FCRPS: Facts
Multiple FCRPS Objectives
4
– Flood Control
– Irrigation
– Navigation
– Recreation
– Fish Operations (BiOps)
– Control Area Services
– Power
FCRPS Myth #1
5
FCRPS has lots of flexibility
– Average January - July runoff is 106 million acre feet
(ranges from 50 – 150 MAF)
– Federal storage about 30 MAF: Storage Limited System
– When the FCRPS is empty, we can store 25 % of the
annual runoff.
– The Colorado or Missouri systems can store two to three times the annual
runoff.
– 12 Hydro Projects provide 94% of gen capacity
– Generation is driven by need to move water.
– ~1000 MWs of INC/DEC Capacity is allocated to Gen/Load Imbalance
– FCRPS persistently faced Spring Oversupply due to lack of flexibility
FCRPS Myth #2
6
FCRPS is always Surplus
– White Book (WBK 2014)
– 1958 (Ave Water Year) and 1937 (Critical Low Water Year)
– Graph shows % of FCRPS capacity and energy allocated to LT
Obligations
Balanced Water Year Driven Oversupply Risk
FCRPS Myth #3
7
Trading Floor controls majority of FCRPS Capacity
– ~ 90% of BPA Power Services revenues and FCRPS Flexibility is
committed prior to Trading Floor transactions
BPA Trading Floor
O N D J F M A M J J A S
0
50,000
100,000
150,000
200,000
250,000
300,000
350,000
400,000
450,000
500,000
Typical Annual Operations Cycle
Natural Flow TDA Flow
Market Transactions support BPA needs to reshape natural flows to
meet operational requirements prior to Real Time
BPA Trading Floor
Goal is to achieve load service and operational requirements
prior to real time (Hourly)
BPA Trading Floor
CA/CAISO volume is capped by intertie transmission capacity
143 MAF
129 MAF
98 MAF
108 MAF
85 MAF
NOB/Sylmar (FMM – HASP) Spread
Recurrent periods of volatile FMM/HASP spread
CAISO DA bids hedge recurring HASP/FMM price volatility
FMM-HASP Spread Frequency and Bias
HASP < FMMHASP < FMM HASP > FMM HASP > FMM
Heavy tail on Sylmar where HASP price is more than $100 below
eventual FMM
NOB/Sylmar: Implications of FMM-HASP Spread Bias
Risk of ineffective economic hourly bid strategy incentivizes
resources to self-schedule as a price taker or in the DAM
Sylmar hourly block bidding - inc Unit opportunity cost: -$
5/1/14 - 8/31/15 Transmission cost: 2.00$
bid price MWh HASP $/MWh FMM $/MWh revenue p/l
price taker 11,875 23.00$ 33.38$ 396,363$ 372,613$
-$ 10,924 32.60$ 35.11$ 383,572$ 361,724$
5.00$ 10,660 33.36$ 35.19$ 375,168$ 353,848$
10.00$ 10,454 33.85$ 35.45$ 370,596$ 349,688$
15.00$ 10,175 34.43$ 35.74$ 363,700$ 343,350$
20.00$ 9,594 35.42$ 36.54$ 350,591$ 331,403$
25.00$ 8,054 37.78$ 38.83$ 312,766$ 296,658$
30.00$ 5,819 41.78$ 42.95$ 249,916$ 238,278$
35.00$ 3,809 46.65$ 48.01$ 182,857$ 175,239$
40.00$ 2,083 54.34$ 55.98$ 116,607$ 112,441$
NOB/Sylmar: FMM-HASP Spread Bias Costs
FMM – HASP Spread risk increases when CAISO sends a HASP
signal to incentivize Exports.
NOB/Sylmar: Cost Implications of FMM/HASP Bias
Sylmar FMM dec prices 5/1/14 - 8/31/15 # intervals avg HASP avg FMM FMM - HASP
All instances when avg FMM < 0 610 (29.24)$ (38.20)$ (8.96)$
instances where HASP > 0 and FMM < 0 354 25.98$ (27.94)$ (53.92)$
Positive HASP signal does not protect against negative binding
FMM price in almost 3% of hours
COB/Malin: FMM Price Protection with Stranded Costs
12/1/2014 - 8/31/2015
COB+NOB COB only
DAM 99.47% 99.05%
Hourly Block 98.97% 98.58%
FMM 75.67%
CAISO Market Transactions - ratio of flow to
awarded MWh
Stranded firm intertie and FCRPS generation capacity more
prevalent in FMM compared to DAM or Hourly Block
COB/Malin: FMM Price Protection with Stranded Costs
Decreasing FMM interval volatility
In absence of alternative compensation, FMM volatility alone may be insufficient to recover the costs associated with providing CAISO 15-min dispatch option
HASP Liquidity impediments for BPA
• FCRPS operational requirements generally met in preschedule
• There are structural challenges to participating in CAISO economic
hourly block markets, specifically persistent FMM/HASP spread bias
– Main cause of FMM/HASP divergence traced to HASP clearing near or
below price floor of -$150
– High tail of positive FMM/HASP divergence affects overall strategy when
attempting to utilize CAISO economic real-time markets
– Economic bidding at low opportunity costs in Hourly Block becomes
suboptimal compared to self-scheduling as a price taker
– There will be no liquidity in dec market if market participants cannot rely on
HASP to send a realistic price signal
FMM Liquidity impediments for BPA
• FMM Market provides no Operational Benefits
– Real-Time markets small portion of overall transaction portfolio
– FCRPS operational requirements generally met on an hourly basis
• BPA has limited incentive to expand FMM participation
– Need economic incentive to lose a quarter of transmission while giving
free option to CAISO
– Interval FMM volatility may not always be sufficient to compensate intertie
and flexible generator owners for the option value
HASP and FMM Potential Liquidity Solutions
• Greater FMM/HASP price convergence at nodes where FMM is not
available
– Create greater liquidity in both import and export economic bids
– Potential to reallocate transactions from DA to RT
• Compensate for reduced flow and resource utilization in FMM
– Capacity/FlexiRamp/Mileage charge
– Interval FMM volatility sufficient to incentivize FMM over Hourly Block
– Introduce 15-minute scheduling on the DC
• More detailed discussion of contributing factors to market price signals
– Inelastic supply stack (marginal MW that binds the tie is a self-schedule)
– Disparity of 15-minute scheduling ability across TSPs
– Seams issues: scheduling practices, intertie TTC assumptions
– Load/generation variability and changes in modeling assumptions
(Transmission Reliability Margin, Operator adjustments)