ASM Phase II Real Time Dispatch and Reserve Constraint Penalty Factors rev3.0 NEPOOL Markets...
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Transcript of ASM Phase II Real Time Dispatch and Reserve Constraint Penalty Factors rev3.0 NEPOOL Markets...
ASM Phase IIReal Time Dispatch and Reserve Constraint Penalty Factors rev3.0
NEPOOL Markets CommitteeJuly 12-13, 2005Jim MilliganISO-NE Markets Development
Presentation Title
© 2005 ISO New England Inc. 2
Outline
• Overview of real time dispatch
– TMSR Re-dispatch
– TMSR Shortage
• Proposed Reserve Constraint Penalty Factors
• Use of RCPFs
– Dispatch Solutions
• Reserve Shortages
Presentation Title
© 2005 ISO New England Inc. 3
Real Time Dispatch
• Objective of real time dispatch algorithm is to determine the least costly means of serving the next increment of load and reserves at each node in the system from available resources given all identified constraints
• Identified constraints include;– Active transmission constraints– Resource operating constraints including ramp rates and limits– System reserve requirements (new with ASM)– Locational reserve requirements (new with ASM)– Real time energy (load) requirements– Regulation requirements
Presentation Title
© 2005 ISO New England Inc. 4
Real Time Dispatch (cont)
• Available Resources– On-line dispatchable Resources (Generators and Asset Related
Demand)– On-line non-dispatchable Generators and scheduled External
transactions (energy requirements)– Off-line Fast Start Generators
Presentation Title
© 2005 ISO New England Inc. 5
Real Time Dispatch (cont)
• Real time ex-ante dispatch outputs– Desired Dispatch Points (MW) and reserve designations for all
dispatchable resources to meet the energy, reserve and transmission constraints
– Ex-ante dispatch rates (energy LMP) for all pricing nodes and reserve clearing prices for each reserve product for system and reserve zones
• Real time ex-post LMP Calculator determines energy LMPs and final reserve allocations based on performance
Presentation Title
© 2005 ISO New England Inc. 6
Real Time Dispatch (cont)
• Non-normal dispatch conditions– Re-dispatch to meet system TMSR reserve requirements
• When re-dispatch is required to maintain the system TMSR reserve requirement, the resource(s) re-dispatched will incur an opportunity cost to provide the reserves
• When this condition occurs, the real time TMSR Reserve Clearing Price will be the highest opportunity cost of the resource dispatched to provide the reserves
• The energy LMP will be the sum of the marginal energy resource plus the opportunity cost of meeting the reserve constraint
• All resources that are designated as providing TMSR will be eligible to receive the TMSR Clearing Price for the MWs of reserve provided
Presentation Title
© 2005 ISO New England Inc. 7
Real Time Dispatch (cont)
• Non-normal dispatch conditions– System Capacity Deficiency (OP#4)
• If there is insufficient capacity in real time to meet the energy and reserve requirements, the energy needs of the system will be met and the reserve requirements will not be met
• Under these conditions, one or more reserve constraint violation(s) will occur and non-zero real time reserve clearing price(s) will be produced by the Reserve Constraint Penalty Factor(s)(RCPF)
• The energy LMP will be the sum of the marginal energy resource plus the sum of the RCPF(s)
• The RCPFs have been developed to recognize the value of the reserve shortage and reduced reliability state of the power system
Presentation Title
© 2005 ISO New England Inc. 8
Derivation of RCPFs
• RCPFs have been established to be consistent with operational requirements and practices of power system.
• RCPFs reflect the costs the ISO would be willing to incur to procure reserves given the $1000/MW Energy Cap.
• RCPFs will replace the existing Reserve Shortage Condition Pricing Rule as defined in Market Rule 1.
• RCPFs will provide mechanism to reflect reserve shortages in stages for system and locational requirements.
Presentation Title
© 2005 ISO New England Inc. 9
Proposed Reserve Constraint Penalty Factors
Location
Product RoS Reserve Zones
TMSRS $50 n/a
TMNSRS $850 n/a
TMORS $100 n/a
TMORL n/a $50
Presentation Title
© 2005 ISO New England Inc. 10
Dispatch Rules
• Additional Dispatch Rules:
– Unused MWs of higher quality reserves will be available to meet lower quality reserve requirements
– Lower quality Reserve Clearing Prices will cascade upward to higher quality Reserve Clearing Prices
• Reserve capability of on-line Resources will be computed based on either 10*MRR or 30*MRR from DDP constrained by EcoMax using MRR at DDP.
• Reserve capability of off-line Resources will be computed based on CLAIM10/30 Offer data constrained by EcoMax.
Presentation Title
© 2005 ISO New England Inc. 11
Real Time Re-dispatch For TMSR
• Example:– First example is a re-dispatch to meet TMSR requirements that
result in opportunity costs setting the TMSR Clearing Price– Second example is an application of TMSR RCPF setting the
TMSR Clearing Price in Reserve Shortage Condition
Presentation Title
© 2005 ISO New England Inc. 12
Unit Supply Offer Data
Unit A Unit B Unit C Unit D
EcoMax 175 185 150 100
EcoMin 100 (SS) 150 75 50
MRR 2 1 3 2
Initial MW
155 150 75 30
Initial TMSR
20 10 30 0
Energy Offers
Unit A Unit B Unit C Unit D
Block 4 175 $35 185 $50 150 $48 100 $70
Block 3 150 $30 165 $40 140 $42 85 $30
Block 2 125 $25 125 $25 125 $38 70 $25
Block 1 100 $20 100 $25 75 $20 50 $15
Presentation Title
© 2005 ISO New England Inc. 13
Dispatch at t=0
• System is being economically dispatched– Unit A is the marginal resource and setting LMP at $35– TMSR is assigned based on response rates and available
capacity
• Unit D is in a startup ramp and not dispatchable
Presentation Title
© 2005 ISO New England Inc. 14
Initial Conditions (Dispatch at t=0)
35
__150__
30
__125__
25
__100__
20
50
__165__
40
__125__
25
__100__
25
48
__140__
42
__125__
38
_75__
20
70
__85__
30
__70__
25
__50__
15
Unit A Unit B Unit C Unit D
DDP155 DDP
150
DDP75
DDP30
175 185 150 100
Load = 410 MW Spin Reserve Req’t = 60 MW
LMP = $35 TMSR CP = $0
Unit D in S/U
Presentation Title
© 2005 ISO New England Inc. 15
Dispatch at t=1
• Load has increased to 435MW• Unit A must be constrained to meet reserve requirements
and incurs an opportunity cost• Unit C becomes marginal and sets LMP at $38• Unit D is still not dispatchable
Presentation Title
© 2005 ISO New England Inc. 16
Dispatch at t=1
35
__150__
30
__125__
25
__100__
20
50
__165__
40
__125__
25
__100__
25
48
__140__
42
__125__
38
_75__
20
70
__85__
30
__70__
25
__50__
15
Unit A Unit B Unit C Unit D
DDP155 DDP
150
DDP85
DDP45
175 185 150 100
Load = 435 MW Spin Reserve Req’t = 60 MW
LMP = $38 TMSR CP = $3 (OC Unit A)
Unit D in S/U
Presentation Title
© 2005 ISO New England Inc. 17
Dispatch at t=2
• Load has increased to 451MW• Unit D is now dispatchable and eligible to participate in
energy and reserve dispatch• Unit C is marginal and sets energy LMP at $38• TMSR is satisfied without re-dispatch
Presentation Title
© 2005 ISO New England Inc. 18
Dispatch at t=2
35
__150__
30
__125__
25
__100__
20
50
__165__
40
__125__
25
__100__
25
48
__140__
42
__125__
38
_75__
20
70
__85__
30
__70__
25
__50__
15
Unit A Unit B Unit C Unit D
DDP175
DDP150
DDP76
DDP50
175 185 150 100
Load = 451 MW Spin Reserve Req’t = 60 MW
LMP = $38 TMSR CP = $0
Unit D is dispatchable
Presentation Title
© 2005 ISO New England Inc. 19
Dispatch at t=X-1
• Load has increased to 550MW• System is exactly meeting energy and reserve
requirements• Unit B is the marginal energy resource and sets LMP at
$50• Units A and C are constrained to meet reserve
requirements• Unit A has the highest opportunity cost and sets TMSR
CP at $15
Presentation Title
© 2005 ISO New England Inc. 20
Dispatch at t=X-1
35
__150__
30
__125__
25
__100__
20
50
__165__
40
__125__
25
__100__
25
48
__140__
42
__125__
38
_75__
20
70
__85__
30
__70__
25
__50__
15
Unit A Unit B Unit C Unit D
DDP170 DDP
175
DDP120
DDP85
175 185 150 100
Load = 550 MW Spin Reserve Req’t = 60 MW
LMP = $50 TMSR CP = $15
Presentation Title
© 2005 ISO New England Inc. 21
Dispatch at t=X
• Load has increased to 551MW• System energy requirements are being met, however,
insufficient capacity exists to meet the reserve requirements
• TMSR CP is set by TMSR RCPF=$50• Unit A becomes the marginal energy resource and
energy LMP is $85 (Unit A energy offer plus TMSR RCPF)
Presentation Title
© 2005 ISO New England Inc. 22
Dispatch at t=X (TMSR Shortage)
35
__150__
30
__125__
25
__100__
20
50
__165__
40
__125__
25
__100__
25
48
__140__
42
__125__
38
_75__
20
70
__85__
30
__70__
25
__50__
15
Unit A Unit B Unit C Unit D
DDP171 DDP
175
DDP120
DDP85
175 185 150 100
Load = 551 MW Spin Reserve Req’t = 60 MW
Spin Actual = 59
LMP = $85 TMSR CP = $50
Presentation Title
© 2005 ISO New England Inc. 23
Real Time Dispatch (cont)
• Non-normal dispatch conditions– Re-dispatch to meet local reserve requirements
• See example
Presentation Title
© 2005 ISO New England Inc. 24
Locational Example of RCPFs
• Initial conditions:Actual EcoMin EcoMax Energy MRR
Reserve
– GenA 25 25 100 $70 1 30– GenB 80 50 100 $50 5 20– GenC 0 5 25 $150 C10=25 25– GenD 0 5 25 $200 C30=25 25
GenA and GenB committed, Local Reserve Req’t = 100 MW
Interface Limit =200MW, Interface Flow=150MW
Local Load = 255
System LMP = $50, Reserve Prices = $0
Presentation Title
© 2005 ISO New England Inc. 25
Conditions at t=0
Local Load = 255
GenA 25 R=30
GenB 80 R=20
GenC 0 R=25
GenD 0 R=25
Load 255
L Res = 150
Local LMP $50
L RCP = $0
Limit = 200
Actual = 150
System LMP = $50
System RCPs = $0
System
Reserve Zone
Presentation Title
© 2005 ISO New England Inc. 26
Conditions at t=1
Local Load = 300
GenA 25 R=30
GenB 100 R=0
GenC 0 R=25
GenD 0 R=25
Load = 300
L Res = 105
Local LMP = $55
L RCP = $0
Limit = 200
Actual = 175
System LMP = $55
System RCPs = $0
System
Reserve Zone
Energy Balance is satisfied
Local Reserve Req’t is satisfied
Presentation Title
© 2005 ISO New England Inc. 27
Conditions at t=2
Local Load = 310
GenA 30 R=30
GenB 100 R=0
GenC 0 R=25
GenD 0 R=25
Load = 310
L Res = 100
Local LMP = $70
L RCP = $15
Limit = 200
Actual = 180
System LMP = $55
System RCPs = $0
System
Energy Balance is satisfied
Local Reserve Req’t is satisfied
Re-dispatch of Interface – similar to Gen opportunity cost
Reserve Zone
Presentation Title
© 2005 ISO New England Inc. 28
Conditions at t=3
Local Load = 351
GenA 70 R=30
GenB 100 R=0
GenC 0 R=25
GenD 0 R=25
Load = 351
L Res = 99
Local LMP = $105
L RCP = $50
Limit = 200
Actual = 181
System LMP = $55
System RCPs = $0
System
Energy Balance is satisfied
Local Reserve Req’t is violated
Reserve Zone
Presentation Title
© 2005 ISO New England Inc. 29
Conditions at t=4
Local Load = 371
GenA 71 R=29
GenB 100 R=0
GenC 0 R=25
GenD 0 R=25
Load = 371
L Res = 79
Local LMP = $120
L RCP = $50
Limit = 200
Actual = 200
System LMP = $55
System RCPs = $0
System
Energy Balance is satisfied
Local Reserve Req’t is violated
Reserve Zone
Presentation Title
© 2005 ISO New England Inc. 30
Reserve Shortages
• Previous example shows local reserve shortage and use of local RCPF
• Similar concept employed for system reserve shortages• Typical condition would begin with a shortage of TMOR
followed by shortage of TMNSR, and in extreme cases, a shortage of TMSR.
• Under this scenario, system TMOR RCPF would be violated first followed by system TMNSR RCPF and finally system TMSR RCPF
Presentation Title
© 2005 ISO New England Inc. 31
Reserve Shortages (cont)
• Frequency of System Reserve Shortages– Reference: Analysis of Historical Reserve Shortages White
Paper
• Historical analysis indicates that the Control Area has experienced a deficiency in Operating Reserves (TMOR) in real time approximately 0.26% of time.
• Of the total Number of deficient conditions (24), five resulted in a deficiency of TMNSR, and of the five, three may have resulted in a deficiency of TMSR.
Presentation Title
© 2005 ISO New England Inc. 32
Reserve Shortages (cont)
• Historical information does not exist to perform similar analysis of locational reserve shortage conditions. The ISO is continuing to investigate the feasibility of producing such an analysis.
Presentation Title
© 2005 ISO New England Inc. 33
Discussion and Questions