Module 1 WESM Trading and Operations Final PDF ok

Philippine Electricity Market Corporation (PEMC)Copyright © 2012 by Philippine Electricity Market Corporation

Module 1:MARKET OPERATIONS AND

TRADINGScheduling, Pricing and Dispatch


Presentation Outline Hour-ahead Real-time Dispatch (RTD)

Effect of Transmission Loss Factor (TLF) on Dispatch and Usage on Scheduling

Determination of Ex-ante Price (EAP), RTD Schedule and Ex-ante Quantity (EAQ) for Generator and Load Customer

Real-time Expost Dispatch(RTX)

Determination of Ex-post Price (EPP) for Generator and Load Customer

Examples2


HOUR-AHEAD REAL TIME DISPATCH (RTD)

“Ex-Ante”

3



•It is the Hour-Ahead Dispatch Schedulewhich determines the target loading, inMW, of facilities at the end of the tradinginterval.

•The RTD calculates the Ex-ante NodalPrices.

4



H+1(End of Trading Interval)

H (Start of Trading Interval)

80

20

120

100

60

40

0

MW

Time

Initial MW (EAIQ) for H(Optimized by MMS)

Hour - Ahead Dispatch ScheduleRTD/Target MW (EATQ) for H+1

5


RTD Market Trading Mechanism

System Conditions:•System Snapshot •Outage Schedules•Security Limits•Contingency Lists•Transmission limits•Reserve Requirement

MarketManagement

System

Market Input Data:• Energy offers(Price, Quantity, Ramp Rate)

Trading Participant Market Operator System Operator

System DemandForecast

Market Dispatch Optimization Model

(MDOM)

•Pricing and Scheduling

6


Table 1.1 - Generator Offers (Trading Participants)

Region Participant Pmin(MW)

Quantity (MW)

Price (Php/MWh)

Ramp-rates (MW/min)

Luzon 3,025.00 6,312.20 RRUP RRDNLhydro_G01 70.00 684.60 1,000.00 30 30Lgeo_G01 110.00 369.00 270.69 3 3Lcoal_G01 1,080.00 2,400.60 2,168.32 4 4Ldiesel_G01 0 143.00 7,469.00 4 4Lnat_G01 1,765.00 2,715.00 -1.00 6 6

Visayas 465.00 1,485.80Vgeo_G01 216.00 616.50 0.00 3 3Vcoal_G01 249.00 622.00 1,981.70 4 4Vdiesel_G01 0 247.30 18,500.19 2 2

Total 3,490.00 7,798.00

Note: Price-Qty Offer must be up to 10 energy blocks.

7


Table 1.2 - System Demand Forecast (Market Operator)

Region System Demand* Forecast (MW)Luzon 5,348Visayas 932.1Total 6,280.1

Note: * - System Demand = Demand + Losses

8


General Constraint

Generation = Losses + Demand

9


Effect of Transmission Loss Factors on Dispatch

•The incremental transmission lossesbased on the location of the resourcewith respect to the reference bus andflow of power on the grid•This factor is called the TransmissionLoss Factor, or Penalty Factor

∂∂

−

=

igen

Loss

i

PP

TLF1

1 Change in System Losses

Change in Unit’s MW Output

10


Usage of Transmission Loss Factors on Scheduling

•The amount of power (MW) that needsto be generated/consumed at theresource bus in order toconsume/supply 1MW at the referencebus (Richview).•The factor that is multiplied to the offerand bids to come up with a value ofthose offers and bids relative to thereference bus.

11


•An increment in generation results inan increase in system losses,

• The price offer is adjusted higher

10 <∂∂

<igen

Loss

PP 1

1

1>

∂∂

−

=

igen

Loss

i

PP

TLF


12


•An increase in generation results in adecrease in system losses then:

• The price offer is adjusted lower

10 −>∂∂

>igen

Loss

PP 1

1

1<

∂∂

−

=

igen

Loss

i

PP

TLF


13


•The generator offer price will beadjusted as:

Adjusted Offer Price = Offer x TLF


14


Table 1.3 - Adjusted Generator Price Offers

Region Participant Offer Price (Php/MWh) TLF

Adjusted Offer Price (Php/MWh)

LuzonLhydro_G01 1,000.00 1.0000 1,000.00Lgeo_G01 270.69 0.9937 268.98Lcoal_G01 2,168.32 1.0013 2,171.14

Ldiesel_G01 7,469.00 0.9705 7,248.66Lnat_G01 -1.00 1.0483 -1.05

VisayasVgeo_G01 0.00 1.0243 0.0000Vcoal_G01 1,981.70 0.9978 1,977.34

Vdiesel_G01 18,500.19 0.9974 18,452.09

15


G5G4

Determination of Generator Dispatch Schedules and System Marginal Price

Price(P/MWh)

System Demand Forecast

Adjusted Price Offers

Quantity (MW)

System Marginal Price, λ

λ = (Price Offer x TLF)Marginal Plant

G1G2

G3G5

Schedule

Non-contestableQty

Non-contestable Qty.: Pmin, Must-run Unit (MRU), New and Renewable Energy and/or Non-scheduled Generator

16


Determination of Generator Dispatch Schedules and System Marginal Price

Price(P/MWh)

Quantity (MW)

Over-all System Demand Forecast

6,280.1 MW

System Marginal Price, λ= Php 2,171.1/MWhMarginal Plant: Lcoal_G01

Lnat_G01Adj. P = -1.05Q = 950

Lhydro_G01Adj. P= 1,000Q = 614.6

Lcoal_G01Adj. P= 2171.1Q= 193

Lgeo_G01Adj. P = 268.98Q = 259

Vcoal_G01Adj. P= 2002.51Q = 373

Luzon System Demand Forecast

5,348 MW

V isayas System Demand Forecast

932.1 MW

Ldiesel_G01Adj. P = 7248.66Q = 143

Vdiesel_G01Adj. P= 18452.09Q = 247.3

Vgeo_G01Adj. P= 0 Qty = 400.5

ΣPmin = 3,490 MW

ΣGen Offer = 7,798 MW

17


RTD HVDC Flow

Luz Vis

HVDC Flow = 306.40 MW

Gen Sched = 5,041.60 MWSystem Demand = 5,348 MW

Gen Sched = 1,238.5 MWSystem Demand = 932.1 MW

18


Table 1.4 - Generator Dispatch Schedules

Participants Offered Qty. (MW) RTD* (MW)

Lnat_G01 2,715.00 2,715.00

Vgeo_G01 616.5 616.5

Lgeo_G01 369 369

Lhydro_G01 684.6 684.6

Vcoal_G01 622 622

Lcoal_G01 2,400.60 1,273.00

Ldiesel_G01 143 Not Cleared

Vdiesel_G01 247.3 Not Cleared

Total 7,798.00 6,280.10

19


MW

→ LD Node 1

LD Node 2

LD Node 3

System Demand Forecast per

Region

System Snapshot

Node 1Node 2Node 3

Nodal Demand Schedules per

Region

MW

→

Determination of Load Nodal Schedules

Nodal Load Pattern

∑ ± HVDCGenregion

20


Table 1.5 - Determination of Load Nodal Schedules

System Demand Forecast:

RegionLoad Demand

(MW)Losses(MW)

System Demand (MW)

Luzon 5260.6 87.4 5,348

Visayas 915.3 16.8 932.1

Load MTN:Participants RTD (MW)

Luzon 5,260.60

LC01_L01 1,308.26

LC02_L01 2,403.48

LC03_L01 1,548.86

Visayas 915.30

VC01_L01 101.00

VC02_L01 548.67

VC03_L01 151.27

VC04_L01 29.95

VC05_L01 84.40

Total 6,175.90

21


Table 1.6 - Generator and Load Nodal Schedules

Load MTN:Participants RTD (MW)

Luzon 5,260.60 LC01_L01 1,308.26 LC02_L01 2,403.48 LC03_L01 1,548.86

Visayas 915.30 VC01_L01 101.00 VC02_L01 548.67 VC03_L01 151.27 VC04_L01 29.95 VC05_L01 84.40

Total 6,175.90

Generator MTN:Participants RTD (MW)

Lnat_G01 2,715.00

Vgeo_G01 616.50

Lgeo_G01 369.00Lhydro_G01 684.60

Vcoal_G01 622.00

Lcoal_G01 1,273.00

Ldiesel_G01 0.00

Vdiesel_G01 0.00

Total 6,280.10

22


Determination of Scheduled Nodal Energy Generation/Consumption

H+1(End of Trading Interval)

H (Start of Trading Interval)

80

20

120

100

60

40

0

MW

Time

EAQ= ½(EAIQ+ EATQ)

EAQ – Ex-ante Qty

EAIQ – Ex-ante Initial Qty.

EATQ – Ex-ante Target Qty.

Scheduled Nodal Energy Generation / Consumption

Initial MW (EAIQ) for H

Hour - Ahead Dispatch ScheduleRTD/Target MW (EATQ) for H+1

23


Table 1.7 - Forecasted/Scheduled Nodal Energy Generation/Consumption

Ex-ante Quantity (EAQ)

Generator MTN:

Resources EAIQ (MW)

EATQ (MW)

EAQ (MWh)

Lcoal_G01 1,084.95 1,273.00 1,178.97 Lgeo_G01 239.05 369.00 304.02 Lhydro_G01 794.48 684.60 739.54 Lnat_G01 2,369.89 2,715.00 2,542.44 Vcoal_G01 349.35 622.00 485.67 Vgeo_G01 467.60 616.50 542.05 Ldiesel_G01 0 0 0Vdiesel_G01 0 0 0

Total 5,305.31 6,280.10 5,792.70

Load MTN:Resources EAIQ (MW) EATQ (MW) EAQ (MWh) LC01_L01 1,165.40 1,308.26 1,236.83 LC02_L01 1,862.80 2,403.48 2,133.14 LC03_L01 1,490.30 1,548.86 1,519.58 VC01_L01 82.80 101.00 91.90 VC02_L01 392.20 548.67 470.43 VC03_L01 120.80 151.27 136.04 VC04_L01 26.30 29.95 28.13 VC05_L01 70.90 84.40 77.65

Total 5,211.50 6,175.90 5,693.70

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Nodal Prices/Locational Marginal Prices (LMP)

LMPGeneration

Price(SMP)

= Cost ofLosses+

TransmissionCongestion

Cost+

Marginal cost of supplying the next increment of electricenergy at a specific location while considering thegeneration marginal cost and the physical aspects of thetransmission system.

LMPi = λ + λ1

TLF i1 * + Σ µj aij

25


Nodal Prices/Locational Marginal Prices (LMP)

LMPi =λ

TLF i

If no congestion occurs,

Generator:

∂∂

−

==

igen

L

ii

PP

TLFPF1

1Load:

∂∂

+

==

iload

L

ii

PP

TLFPF1

1

26


Table 1.8 - Ex-ante Price (EAP)Nodal Price / Locational Marginal Price (LMP)

Generator MTN:

Resources TLF EAP (Php/MWh)

Lnat_G01 1.0483 2,071.10 Vgeo_G01 1.0243 2,119.63 Lgeo_G01 0.9937 2,184.90

Lhydro_G01 1.0000 2,171.10 Vcoal_G01 1.0105 2,148.58 Lcoal_G01 1.0013 2,168.32

Ldiesel_G01 0.9705 2,237.13 Vdiesel_G01 0.9974 2,176.80

Load MTN:

Resources TLF EAP (Php/MWh)

LC01_L01 0.9704 2,237.36 LC02_L01 0.9752 2,226.35 LC03_L01 1.0046 2,161.20 VC01_L01 0.9919 2,188.87 VC02_L01 1.0096 2,150.49 VC03_L01 0.9714 2,235.06 VC04_L01 0.9611 2,259.01 VC05_L01 0.8503 2,553.38

λ= Php 2,171.1/MWh

27


REAL TIME EX-POST DISPATCH (RTX)

“Ex-post”

28


REAL TIME EX-POST DISPATCH (RTX)

•It is a real time dispatch scheduleprocess performed at the end of atrading interval utilizing actualoperations data.

•The RTX calculates the Ex-postNodal Prices.

29


RTX Market Trading Mechanism

System Condition:•System Demand

(System Snapshot )•Outage Schedules•Security Limits•Contingency Lists•Transmission limits

MarketManagement

System

Market Input Data:• Energy offers (Price, Qty, and Ramp Rate

Trading Participant Market Operator System Operator

Market Dispatch Optimization Model

(MDOM)

•Pricing and Scheduling

32


Table 1.9 - Generator Offers*(Trading Participants)

Note: Same as Ex-ante

Region Participant Pmin(MW)

Quantity (MW)

Price (Php/MWh)

Ramp-rates (MW/min)

Luzon 3,025.00 6,312.20 RRUP RRDNLhydro_G01 70.00 684.60 1,000.00 30 30Lgeo_G01 110.00 369.00 270.69 3 3Lcoal_G01 1,080.00 2,400.60 2,168.32 4 4Ldiesel_G01 0 143.00 7,469.00 4 4Lnat_G01 1,765.00 2,715.00 -1.00 6 6

Visayas 465.00 1,485.80Vgeo_G01 216.00 616.50 0.00 3 3Vcoal_G01 249.00 622.00 1,981.70 4 4Vdiesel_G01 0 247.30 18,500.19 2 2

Total 3,490.00 7,798.00

33


Table 1.10 - RTX System Demand (System Operator)

Region System Demand* (MW)Luzon 5,357.7Visayas 963.4Total 6,321.1

Note: * - System Demand = Genregion ± HVDC (Import/Export of power)- Based on the system snapshot at the end of the trading interval from SO

34


Table 1.11 - Adjusted Generator Price Offers

Region Resources Offer Price (Php/MWh) TLF

Adjusted Offer Price (Php/MWh)

LuzonLhydro_G01 1,000.00 1.0000 1.0000Lgeo_G01 270.69 0.9956 269.50Lcoal_G01 2,168.32 1.0004 2,169.19

Ldiesel_G01 7,469.00 0.9778 7,303.19Lnat_G01 -1.00 1.0442 -1.04

VisayasVgeo_G01 0.00 1.0067 0.0000Vcoal_G01 1,981.70 0.9961 1,973.97

Vdiesel_G01 18,500.19 0.9947 18,402.14

35


Determination of System Marginal Price

Price(P/MWh)

Quantity (MW)

Over-all System Demand6,321.1 MW

System Marginal Price, λ= Php 2,169.19/MWhMarginal Plant: Lcoal_G01

Lnat_G01Adj. P = -1.04Q = 950

Lhydro_G01Adj. P= 1,000Q = 614.6

Lcoal_G01Adj. P= 2169.19Q= 234

Lgeo_G01Adj. P = 269.50Q = 259

Vcoal_G01Adj. P= 1973.97Q = 373

Luzon System Demand Forecast

5,357.7 MW

V isayas System Demand Forecast

963.4 MW

Ldiesel_G01Adj. P = 7303.19Q = 143

Vdiesel_G01Adj. P= 18402.14Q = 247.3

Vgeo_G01Adj. P= 0 Qty = 400.5

ΣPmin = 3,490 MW

ΣGen Offer = 7,798 MW

36


RTX HVDC Flow

Luz Vis

HVDC Flow = 275.10 MW

Gen Sched = 5,082.60 MWSystem Demand = 5,357.70 MW

Gen Sched = 1,238.5 MWSystem Demand = 963.4 MW

37


Table 1.12 - Ex-post Price (EPP)Nodal Price / Locational Marginal Price (LMP)

Generator MTN:

Resources TLF EPP (Php/MWh)

Lnat_G01 1.0442 2,077.37

Vgeo_G01 1.0067 2,154.75

Lgeo_G01 0.9956 2,178.77

Lhydro_G01 1.0000 2,169.19

Vcoal_G01 0.9961 2,177.68

Lcoal_G01 1.0004 2,168.32

Ldiesel_G01 0.9778 2,218.44

Vdiesel_G01 0.9947 2,180.75

Load MTN:

Resources TLF EPP (Php/MWh)

LC01_L01 0.9782 2,217.53

LC02_L01 0.9826 2,207.60

LC03_L01 1.0074 2,153.25

VC01_L01 0.9753 2,224.12

VC02_L01 1.0005 2,168.10

VC03_L01 0.9837 2,205.13

VC04_L01 0.9569 2,266.89

VC05_L01 0.8753 2,478.22

λ= Php 2,169.19/MWhMarginal Plant:Lcoal_G01

38


Table 1.13 - Ex-ante and Ex-post Prices and Schedules

(Generator MTN)Generator MTN:

Resources EAIQ (MW) EATQ (MW) EAQ (MWh) EAP (Php/MWh) EPP (Php/MWh) Lcoal_G01 1,084.95 1,273.00 1,178.97 2,168.32 2,168.32 Lgeo_G01 239.05 369.00 304.02 2,184.90 2,178.77 Lhydro_G01 794.48 684.60 739.54 2,171.10 2,169.19Lnat_G01 2,369.89 2,715.00 2,542.44 2,071.10 2,077.37 Vcoal_G01 349.35 622.00 485.67 2,175.93 2,177.68 Vgeo_G01 467.60 616.50 542.05 2,119.63 2,154.75 Ldiesel_G01 0 0 0 2,237.13 2,218.44 Vdiesel_G01 0 0 0 2,176.80 2,180.75

39


Table 1.14 - Ex-ante and Ex-post Prices and Schedules

(Load MTN)Load MTN:

Resources EAIQ (MW) EATQ (MW) EAQ (MWh) EAP (Php/MWh) EPP (Php/MWh) LC01_L01 1,165.40 1,308.26 1,236.83 2,237.36 2,217.53 LC02_L01 1,862.80 2,403.48 2,133.14 2,226.35 2,207.60 LC03_L01 1,490.30 1,548.86 1,519.58 2,161.20 2,153.25 VC01_L01 82.80 101.00 91.90 2,188.87 2,224.12 VC02_L01 392.20 548.67 470.43 2,150.49 2,168.10 VC03_L01 120.80 151.27 136.04 2,235.06 2,205.13 VC04_L01 26.30 29.95 28.13 2,259.01 2,266.89 VC05_L01 70.90 84.40 77.65 2,553.38 2,478.22

40


End of Presentation

41

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Module 1 WESM Trading and Operations Final PDF ok

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