Power market operation-발표

832019 Power market operation-

httpslidepdfcomreaderfullpower-market-operation- 137

Power PlanningPower Market

Power System

Power Market Operation

Sang-Jin Chung

T ampJ Construction Co Ltd

+82-10-5234-6134

sjchungkpxorkr



Copyright 2011 by KPX co Ltd All rights reserved

IIII

II

IIIIII

Power Business Overview

Electricity Market

Recent Market Results

Market IssuesⅣⅣ

ⅣⅣ





Power System Power Business OverviewII

Electric Power SystemGeneration Sites amp Fuel Mix

Transmission System Network

Peak Demand amp Capacity Margin



Copyright 2011 by KPX co Ltd All rights reserved 2011 IRAN IGMC Power System Operation Training Program

Jeju TP

Yangju

Seo-Incheon

Youngheung TP

Hanrim CC

NamjejuSeogwipo

AndukSin-Jeju

Hanla

Sungsan

Jocheon

Dong-Jeju

Sanji

Seo-Incheon CC

Incheon TP CC

Sin-Incheon

Sin-Sihung

Sin-Bupyung

Sin-Dukheun

ChungbuYoungdeungpo

Youngseo

Seo-seoul

Uijeongbu

Sungdong

HwasungSin-suwonPyungtaek TP CC

Ansan

Sin-DangjinDangjin TP

Taean TP

Sin-onyang

Boryeong TP CCChungyang

Gunsan

Sin-Gimje

Youngwang NP

Sin-Gwangju

Sin-Hwasun

Sin-Gangjin

Haenam CSYeosu NP

Gwangyang

Hadong TP

Sin-Namwon Euiryong

Sancheong PP

Muju PP

Sin-OkcheonSinkaedong

Chungwon

Sin-Jincheon

Sin-Gosung

Samcheonpo TP

In-Masan

Sin-Gimhae

Bukbusan

Pusan CCNam-Pusan

Kori NP

Sin-Onsan

Ulsan TP CC

Wolseong NPSeo-Daegu

Buk-DaeguSunsan

GoryeongDaegu

Sin-Kyeongsan

Ulju

Sin-Ulsan

Sin-Youngju

Sin-Youngil

Cheongsong PP

Uljin NP

Donghae

Yangyang PP

Sin-Jecheon

Sin-Gapyung

Sin-Ansung

Sin-seosan

Sin-Yangje

Sin-Ansan

Sin-Taebaek

Sin-Yangsan

Sin-Youngin

Sin-Sungnam

Dong-Seoul

Migum

Gonjiam

CHARACTERISTICS

Isolated power grid within Korean peninsularHigh growth rates of power consumption

- Annual increase rates

middot lsquo91-rsquo95 109 lsquo96-rsquo00 74 lsquo01-rsquo05 66

lsquo06-rsquo10 56Highly dependent on foreign energy resources- 964 of primary energy imported (232 million

toe lsquo08) Primary energy resources

- Oil 431 Coal 276 LNG 153 Nuclear140

KEY STATISTICS (2010)

People served (million) 50

Generating capacity (MW) 76078

Peak loads (MW) 71308

Total transmission lines (C-Km) 30676

Electricity traded annually (GWh) 406000

Generators (above 20MW) 372 ea

4




Bundang

Seoul

Sanchung

Hapchun

Cheongsong

IncheonPucheon

Pyungtaek

Anyang

Youngkwang

Chungju

Chuam

Yeosu

Honam Kwangyang

Sumjinkang

Yongdam

Muju

SeocheonBoryeong

POSCO

Sin-IncheonPaldnag

Chungpyung

Euiam

ChuncheonHwachun

Hadong

Samrangjin

SamcheonpoBusan

Kori

Andong

Yangyang

Kangreung

Uljin

Imha

Youngnam

Wolseong

Small Hydro (Pocheon etc)

Soyangkang

Ilsan

Youngheung

Taean

LGBugok

Ulsan

Daechung

Dangjin

Seo-Incheon Youngdong

Donghae

Yulchon

Jeju

(Unit 10 MW)

53180

99

120

180

50

48

45 9050

45

180180

180

90

40

33

74

50

40

400300

180

300

400

40

247

140

39

400

115

53

590

278

314590

6

60

10011

12

8

7

20

2

3

2

9

59

60

41

40

6010

70

6

5Chungpyung

As of Dec 31 2010

Capacity by Fuels(Unit MW)

Nuclear

17716(233)

Oil

5805(76)

Hydro5524(73)

Renewable

1762(23)Coal

24800

(326)

LNG

20471

(269)

5




Characteristics

Direct Current Line

- Connect the main land

to Jeju Island

345kV

Main transmission system

Distribution system

- Connected to major areas of consumption

154kV

Second HVDC Line between main landand Jeju island is being built by 2012( 300MW 700MW)rArr

765kVMass transmission system

(Unit C-km Numbers of SS)

154kV 20700 628

345kV 8552 88

765kV 755 6Jeju TP

Yangju

Seo-Incheon

Youngheung TP

Hanrim CC

NamjejuSeogwipo

Anduk Sin-Jeju

Hanla

Sungsan

Jocheon

Dong-Jeju

Sanji

Seo-Incheon CC

Incheon TP CC

Sin-Incheon

Sin-Sihung

Sin-Bupyung

Sin-Dukheun

Chungbu

Youngdeungpo

Youngseo

Seo-seoul

Uijeongbu

Sungdong

Hwasung

Sin-suwonPyungtaek TP CC

Ansan


Taean TP

Sin-onyang


Gunsan

Sin-Gimje

Youngwang NP

Sin-Gwangju

Sin-Hwasun

Sin-Gangjin

Haenam CSYeosu NP

Gwangyang

Hadong TP

Sin-Namwon Euiryong

Sancheong PP

Muju PP

Sin-Okcheon

Sinkaedong

Chungwon

Sin-Jincheon

Sin-Gosung

Samcheonpo TP

In-Masan

Sin-Gimhae

Bukbusan

Pusan CCNam-Pusan

Kori NP

Sin-Onsan

Ulsan TP CC


Buk-Daegu

Sunsan

Goryeong

Daegu

Sin-Kyeongsan

Ulju

Sin-Ulsan

Sin-Youngju

Sin-Youngil

Cheongsong PP

Uljin NP

Donghae

Yangyang PP

Sin-Jecheon

Sin-Gapyung

Sin-Ansung

Sin-seosan

Sin-Yangje

Sin-Ansan

Sin-Taebaek

Gwangyang Steel

Sin-Yangsan

Sin-Youngin

Sin-Sungnam

Dong-Seoul

Migum

Gonjiam

Hadong TP Samcheonpo TPPusan CC

Gwangyang Steel

6




A peak demand of 71GW occurred on Dec 15 2010

bull 68 increase compared to the last yearlsquos peak

bull Higher than expected due to the extended cold waves

The capacity margin was just around 62 (the lowest since 2001)

bull Has gradually decreased due to the delayed construction in facilities

bull May improve from 2012 with the generator additions

45000

50000

70000

(UnitMW)

65000

60000

55000

rsquo04 rsquo05 rsquo06 rsquo07 rsquo08 rsquo10

62790

(08)62290(56)62290(56)

54630(66)54630(66)51260

(82)51260(82)

58990(80)58990(80)

Reserve margin

As of Dec 201071308

(68)

Peak demand

(Growth rate)

122122113113

105105

7272

9191

6262

66800

(64)

7979

rsquo09

7





Power SystemElectricity MarketIIII

Key FeaturesMarket Operations

- Procedures

- Biddings

- Load Forecasting

- Generation Scheduling

- Metering

- Settlement




Mandatory Pool

bull All generators(ge 1 MW) and retailers should trade(buy and sell)electric power through the market All market participants shouldregister as the KPX member

bull The market players are GENCOs(sellers) and KEPCO(the single buyer)

Generator Bidding Pool

bull Only the supply(generation) side bid into the pool with their generator availabilities for each trading day

bull The buyer does not bid and the purchaser KEPCO acts as a price taker in the market KPX forecasts the hourly electricity demand for the tradingday

bull The market clearing is processed hourly base prices and volumes arefixed day-ahead for 24 hours of the following day

9




Cost Based Pool (CBP)

bull The cost (not the price) of each generator is bid into the pool

ndash The generation cost is determined monthly by the Generation Cost EvaluationCommittee(GCEC) based on the fuel prices in the previous month

ndash As mentioned before the generators bid only their availability

bull The System Marginal Price(SMP) is determined in the process of Price SettingScheduling

ndash SMP reflects actual production costs of generators(start-up no-load incremental cost)

bull The Capacity Payment(CP) is paid by for the availability declared(MW)

ndash CP is paid to all generators(the Centrally Dispatching Units(ge 20 MW)) who submitoffer data whether or not dispatched

ndash CP is determined at every year and it is adjusted considering the level of reservemargin which can be the signal of investments

CONCOFF Payment are payed for the differences between the scheduled andthe actual generations

10




Marginal Loss Factor(MLF) for the transmission lossintroduced( rsquo07)

- To minimize the long-term social cost by the incentives to generationinvestment in heavy load center (Generation+Transmission)

- To operate optimally the resources in the short-term by considering the

locational value of generations The transmission losses are considered

- MLFs are applied to generator nodes Application to the load nodes is

not necessary because the KEPCO is the single buyer

- As the stranded costs were incurred a relaxation factor was introduced

to prevent the abrupt change of generator revenues(10 increase in each

year)

Definition of MLF

11

Change of generation at the reference busMLF = -------------------------------------------------------

Change of load at a specific bus

= 1 + Loss Load increment where Loss change of total loss in the network

Load increment incremental load at acertain bus




Types of of Ancillary Services

1) Frequency Control GFAGC2) Generation Reserves Operational reserves provided by fast start

generators

3) Black Starts 1 or 2 Self start-up generators per region

4) Voltage Regulation Service Obligation of reactive power supply

Ancillary Services Payments

bull Compensation for ancillary services is paid according to theircontributions ie GFAGC service performances are assessd by theperformance index

bull Co-optimization between energy and ancillary is possible

bull The economic dispatch principle (merit order) is fully met ie the rolesof each types of the generator is fulfilled according to their functions

ie the Base load(Coal) Max energy outputthe Peaker(LNG) Effective load following by providing AGC service

12




The reference capacity payment(RCP) is adjusted according to theforecasted capacity margin by regions (metropolitanotherJeju island) whenit is beyond a reasonable value ie12

The seasonalhourly coefficients are applied to RCP to ensure the sufficientgeneration capacity in peak times

All the offered capabilities of the centrally dispatched generators(over 20MW) are compensated by hourly based RCP regardless of their actualoperations

13



Copyright 2011 by KPX co Ltd All rights reserved 2011 IRAN IGMC Power System Operation Training Program 14







Daily Bidding

bullContents ndash Hourly availability

ndash Technical characteristics

bull Bidding time

ndash Closing time AM 1000 trading-day ahead(D-1)

ndash Term 34 hours (1900 D-1 ~ 0400 D+1)

Default Data is used if generators donrsquot submit their data due tocommunication failures or human errors

Re-Offers

bull Starting Time 1001 AM before the trading day

bull Closure Time l (one) hour before the trading hourldquo Re-offerrdquo is allowed only when the generator has faults and it

cannot meet the declared availability

16




Real-timeReal-time

DispatchDispatch(D-0)(D-0)

A Day-aheadA Day-ahead MMarketarket

( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm

SystemOperationSchedule

Disclosure

19pm

Bid change Closure

1 hour before trading hour

faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost

Generation Cost [WonkWh] = Heat rate [kcalkWh] times Fuel cost [Wonkcal]

- Gencos submit monthly the fuel cost data to the Committee

- Fuel consumption rates are measured at 25 50 75 100 of the gen

output level during the performance test

Cost curve Determine the efficiency coefficients(abc)

Cost(CCost(Cii) =) = (aP(aP22 + bP + c+ bP + c) x Fuel) x FuelCostCost$hour Gcalhour $Gcal$hour Gcalhour $Gcal




Forecasting tool

bull Load forecasting system (LOFY)

Application

bull For the fairness and transparency of the market pricing the output of LOFYis used without any adjustments or modifications

bull However for the operational generation schedule specific knowledge

experiencesjudgement of the engineer who is in charge is added

Using database

bull Weather forecasting data (Korea Meteorological Administration)

bull Historical load data (using similar day pattern data)

LOFY was developed by the KEPRI(Korea Electric Power Research Institute)and updated their historical data base every year

19




Generation Scheduling Program

Delivered by ALSTOM-ESCA (now ALSTOM-Grid) 1999

bull in 2010 changed into New RSC with MIP(Mixed Integer Program) solution

Major Functions

bull Market-based scheduling and day-ahead dispatch scheduling

bull The price setting is made by the unconstrained schedule and the

generator dispatch planning by the constrained schedule

20

RSC( Resource Scheduling and Commitment) determines the

generator startstop operations and also the generation outputs

which can minimize the total generation cost while balancing

supply and demand




Price Setting Scheduling

bull The cost data bidding data and forecasted load data are input for generationscheduling

bull Least cost generation scheduling reflects only the technical characteristics of generators

bull When the scheduling is finished the hourly SMPrsquos are published at 300 PM

System Operational Scheduling

bull The forecasted load data can be adjusted for the system operational scheduling

bull All the system constraints such as the reserve margin transmission limits fuelrestrictions co-generation for district heat supply are reflected in the scheduling

bull The scheduling result(startsstops dispatch targets) are notified to Gencos

before 600 PM to prepare their operations

21




Price Setting Schedule System Operational Schedule

Features To produce the hourly SMP in themarket

To produce the actual operational schedulein consideration of various constraints of the

power system

Input

Data

bull Hourly forecasted load (34 hrs)

bull Generation cost curve

bull Generator availability

bull Technical characteristics of thegenerating units





bull Transmission constraintsbull Reserve constraints

bull Heat supply and fuel constraints

bull Hydro and pump storage constraints

ObjectiveFunction

Total Generation Cost Minimization

DisclosureTime

bull Published at 1500 (D ndash 1) bull Published at 1800 (D ndash 1)

22



How do we set the market price



p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740

Market price(wonkWh) 7041 3267 13189 14221 14221 1384 14221 11865

24

Power demand

Market price

Available supply capacity




All kinds of constraints should be considered inthe real timebull All the data should be updated based on the initial operational schedule

such as the load forecasts generator availability changes(Re-Offers)heat supply and fuel constraints and hydro and pump storage operationsetc

bull SCADA data is very important at this stages for the system stability

analysisbull Schedule energy (generation and dispatch-able load) regulation and

operating reserves every 5 minutes to -

minimize cost

balance load

meet regulation and reserve requirements

satisfy transmission constraints

satisfy generatorload constraints

25




Optimal dispatch by inter-connection MOS with EMSbull 5-min optimal constrained dispatch using MOS(ABB)

bull Ancillary serve requirements is met by the MOS-EMS coupling

bull AGC base points are given by MOS and economic participation factors aswell

bull Coupled operation between the AGC operation scheme of the existing EMSand the MOS economic dispatch algorithms

Requirements of MOS-EMS Coupling

① Transform the CBP cost data into the MOS bidding data(10 prices andoutputs)

rarr The bidding data transformation server does this

②Accuracies of the Load ForecastState Estimation are possible by the reliableSCADA RTU performance and the network modeling techniques

③ The on-line monitoring of MOS operation is required

26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29




IPPs SMP is paid for trading volumes

bull Giving incentives for independent power producers and inducing the invests for the

base load generations

KEPCO Subsidiary Gencos RRC is applied instead of the full SMP

bull Can not give all the settlement revenues due to KEPCOrsquo revenue shortfalls

bull Financial balancing among six power generation subsidiaries

RRC Regulated revenue coefficients are different according to the generator types

Classification Variable Cost Fixed Cost(WonkW-hour)

IPPS SMP 746

KEPCO Subsidiary(by generator types)

Variable cost+(SMP-VC)timesRRC

30





Power System Recent Market ResultsⅢⅢ

Trends of Electricity Trading

Market Prices amp Retail Tariffs

Summary of the Market Experiences




Trade Volumes(Unit TWh)

Trade Payments(Unit Billion Dollar)

rsquo07 rsquo08 rsquo10rsquo07 rsquo08 rsquo10

18

2328

Number of Members

(Unit No)

rsquo07 rsquo08 rsquo10

As of December 2010

104

302422

374

392441

Number of participants has increased due to the growth of the renewablesespecially the solar power (104 members in lsquo07 422 members in lsquo10)rArr

Despite global economic recession trade volume is increasing steadilybull Trade volume is 441TWh (Average increase rate for the last 4 years 5≒ )

bull Trade payments is $28 Billion (Average increase rate for the last 4 years 14 )

6 Gencos KEPCOrsquos subsidiaries take 917 of the total trade volume in 2010

32




MarketPurchasing Pricesbull Steadily rising since the establishment of the

market

bull The market price jumped in 2008 due to highincrease of fuel prices

bull Market prices were maintained at high levelshowever the average settlement prices keptat a marginally increased level thanks to thenuclear power

Retail prices

bull Stable even with the high fuel prices

bull This is because retail tariffs are regulated by thegovernment and KEPCOrsquos financial status are notgood in recent years due to the high purchasing pric

bull Cross subsidy between the tariffs according to theusages make it difficult to progress the marketevolutions

lt Retail tariffs by the usages gt

lt Market PricePurchasing Price gt($MWh)

33




Electricity market reduces the electricity production cost andmaximizes the resource availability

bull Economic dispatch is possible based on generation cost

bull Increasing the efficiency of OampM works of the generating facility

bull Improving the rate of using low-cost facility(nuclear coal)

(Capacity factor of nuclear and coal power plants are increased after operation of CBP market as 339p and 27p respectively)

Accomplish the efficiency of investment

bull The substitution effect of new generation because the maximum capacity of generators were increased and maintenance schedules were shortened

- About 1000MW substitution effect of new base load generator were occurred after

the market opening

bull OM cost were cut down owing to the competition





Power System

Market IssuesⅣⅣ

Cross Subsidy between Customers

Demand Response

Vesting Contract




Vesting Contract between Gencos and KEPCO has beensuggested for the existing generators which were commissionedbefore the market opening(Because their construction cost hasbeen already recovered and should be paid less compared thenew generations)

Cross subsidized tariffs between the electricity users results ininefficient use of the electricity in the beneficiaries

bull It seems that some users waste the electricity at heatingbecause of low electricity prices compared with other form of energy

Demand response mechanism in the market will contribute tothe optimal use of the electricity in generals

bull By using the market price(if possible the real-time price) asthe economic signal smart grid initiatives will have a brightfuture in the industry

Po er PlanningPower Market



Power Planning

Power System

THANK YOU




IIII

II

IIIIII

Power Business Overview

Electricity Market

Recent Market Results

Market IssuesⅣⅣ

ⅣⅣ












Jeju TP

Yangju

Seo-Incheon

Youngheung TP

Hanrim CC

NamjejuSeogwipo

AndukSin-Jeju

Hanla

Sungsan

Jocheon

Dong-Jeju

Sanji

Seo-Incheon CC

Incheon TP CC

Sin-Incheon

Sin-Sihung

Sin-Bupyung

Sin-Dukheun

ChungbuYoungdeungpo

Youngseo

Seo-seoul

Uijeongbu

Sungdong


Ansan


Taean TP

Sin-onyang


Gunsan

Sin-Gimje

Youngwang NP

Sin-Gwangju

Sin-Hwasun

Sin-Gangjin

Haenam CSYeosu NP

Gwangyang

Hadong TP

Sin-Namwon Euiryong

Sancheong PP

Muju PP


Chungwon

Sin-Jincheon

Sin-Gosung

Samcheonpo TP

In-Masan

Sin-Gimhae

Bukbusan

Pusan CCNam-Pusan

Kori NP

Sin-Onsan

Ulsan TP CC


Buk-DaeguSunsan

GoryeongDaegu

Sin-Kyeongsan

Ulju

Sin-Ulsan

Sin-Youngju

Sin-Youngil

Cheongsong PP

Uljin NP

Donghae

Yangyang PP

Sin-Jecheon

Sin-Gapyung

Sin-Ansung

Sin-seosan

Sin-Yangje

Sin-Ansan

Sin-Taebaek

Sin-Yangsan

Sin-Youngin

Sin-Sungnam

Dong-Seoul

Migum

Gonjiam

CHARACTERISTICS














4




Bundang

Seoul

Sanchung

Hapchun

Cheongsong

IncheonPucheon

Pyungtaek

Anyang

Youngkwang

Chungju

Chuam

Yeosu

Honam Kwangyang

Sumjinkang

Yongdam

Muju

SeocheonBoryeong

POSCO

Sin-IncheonPaldnag

Chungpyung

Euiam

ChuncheonHwachun

Hadong

Samrangjin

SamcheonpoBusan

Kori

Andong

Yangyang

Kangreung

Uljin

Imha

Youngnam

Wolseong


Soyangkang

Ilsan

Youngheung

Taean

LGBugok

Ulsan

Daechung

Dangjin


Donghae

Yulchon

Jeju

(Unit 10 MW)

53180

99

120

180

50

48

45 9050

45

180180

180

90

40

33

74

50

40

400300

180

300

400

40

247

140

39

400

115

53

590

278

314590

6

60

10011

12

8

7

20

2

3

2

9

59

60

41

40

6010

70

6

5Chungpyung

As of Dec 31 2010


Nuclear

17716(233)

Oil

5805(76)

Hydro5524(73)

Renewable

1762(23)Coal

24800

(326)

LNG

20471

(269)

5




Characteristics

Direct Current Line


to Jeju Island

345kV


Distribution system


154kV




154kV 20700 628

345kV 8552 88

765kV 755 6Jeju TP

Yangju

Seo-Incheon

Youngheung TP

Hanrim CC

NamjejuSeogwipo

Anduk Sin-Jeju

Hanla

Sungsan

Jocheon

Dong-Jeju

Sanji

Seo-Incheon CC

Incheon TP CC

Sin-Incheon

Sin-Sihung

Sin-Bupyung

Sin-Dukheun

Chungbu

Youngdeungpo

Youngseo

Seo-seoul

Uijeongbu

Sungdong

Hwasung


Ansan


Taean TP

Sin-onyang


Gunsan

Sin-Gimje

Youngwang NP

Sin-Gwangju

Sin-Hwasun

Sin-Gangjin

Haenam CSYeosu NP

Gwangyang

Hadong TP

Sin-Namwon Euiryong

Sancheong PP

Muju PP

Sin-Okcheon

Sinkaedong

Chungwon

Sin-Jincheon

Sin-Gosung

Samcheonpo TP

In-Masan

Sin-Gimhae

Bukbusan

Pusan CCNam-Pusan

Kori NP

Sin-Onsan

Ulsan TP CC


Buk-Daegu

Sunsan

Goryeong

Daegu

Sin-Kyeongsan

Ulju

Sin-Ulsan

Sin-Youngju

Sin-Youngil

Cheongsong PP

Uljin NP

Donghae

Yangyang PP

Sin-Jecheon

Sin-Gapyung

Sin-Ansung

Sin-seosan

Sin-Yangje

Sin-Ansan

Sin-Taebaek

Gwangyang Steel

Sin-Yangsan

Sin-Youngin

Sin-Sungnam

Dong-Seoul

Migum

Gonjiam


Gwangyang Steel

6










45000

50000

70000

(UnitMW)

65000

60000

55000


62790

(08)62290(56)62290(56)

54630(66)54630(66)51260

(82)51260(82)

58990(80)58990(80)

Reserve margin

As of Dec 201071308

(68)

Peak demand

(Growth rate)

122122113113

105105

7272

9191

6262

66800

(64)

7979

rsquo09

7







- Procedures

- Biddings

- Load Forecasting


- Metering

- Settlement




Mandatory Pool







9














10












year)

Definition of MLF

11










generators








12







13










Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU












Jeju TP

Yangju

Seo-Incheon

Youngheung TP

Hanrim CC

NamjejuSeogwipo

AndukSin-Jeju

Hanla

Sungsan

Jocheon

Dong-Jeju

Sanji

Seo-Incheon CC

Incheon TP CC

Sin-Incheon

Sin-Sihung

Sin-Bupyung

Sin-Dukheun

ChungbuYoungdeungpo

Youngseo

Seo-seoul

Uijeongbu

Sungdong


Ansan


Taean TP

Sin-onyang


Gunsan

Sin-Gimje

Youngwang NP

Sin-Gwangju

Sin-Hwasun

Sin-Gangjin

Haenam CSYeosu NP

Gwangyang

Hadong TP

Sin-Namwon Euiryong

Sancheong PP

Muju PP


Chungwon

Sin-Jincheon

Sin-Gosung

Samcheonpo TP

In-Masan

Sin-Gimhae

Bukbusan

Pusan CCNam-Pusan

Kori NP

Sin-Onsan

Ulsan TP CC


Buk-DaeguSunsan

GoryeongDaegu

Sin-Kyeongsan

Ulju

Sin-Ulsan

Sin-Youngju

Sin-Youngil

Cheongsong PP

Uljin NP

Donghae

Yangyang PP

Sin-Jecheon

Sin-Gapyung

Sin-Ansung

Sin-seosan

Sin-Yangje

Sin-Ansan

Sin-Taebaek

Sin-Yangsan

Sin-Youngin

Sin-Sungnam

Dong-Seoul

Migum

Gonjiam

CHARACTERISTICS














4




Bundang

Seoul

Sanchung

Hapchun

Cheongsong

IncheonPucheon

Pyungtaek

Anyang

Youngkwang

Chungju

Chuam

Yeosu

Honam Kwangyang

Sumjinkang

Yongdam

Muju

SeocheonBoryeong

POSCO

Sin-IncheonPaldnag

Chungpyung

Euiam

ChuncheonHwachun

Hadong

Samrangjin

SamcheonpoBusan

Kori

Andong

Yangyang

Kangreung

Uljin

Imha

Youngnam

Wolseong


Soyangkang

Ilsan

Youngheung

Taean

LGBugok

Ulsan

Daechung

Dangjin


Donghae

Yulchon

Jeju

(Unit 10 MW)

53180

99

120

180

50

48

45 9050

45

180180

180

90

40

33

74

50

40

400300

180

300

400

40

247

140

39

400

115

53

590

278

314590

6

60

10011

12

8

7

20

2

3

2

9

59

60

41

40

6010

70

6

5Chungpyung

As of Dec 31 2010


Nuclear

17716(233)

Oil

5805(76)

Hydro5524(73)

Renewable

1762(23)Coal

24800

(326)

LNG

20471

(269)

5




Characteristics

Direct Current Line


to Jeju Island

345kV


Distribution system


154kV




154kV 20700 628

345kV 8552 88

765kV 755 6Jeju TP

Yangju

Seo-Incheon

Youngheung TP

Hanrim CC

NamjejuSeogwipo

Anduk Sin-Jeju

Hanla

Sungsan

Jocheon

Dong-Jeju

Sanji

Seo-Incheon CC

Incheon TP CC

Sin-Incheon

Sin-Sihung

Sin-Bupyung

Sin-Dukheun

Chungbu

Youngdeungpo

Youngseo

Seo-seoul

Uijeongbu

Sungdong

Hwasung


Ansan


Taean TP

Sin-onyang


Gunsan

Sin-Gimje

Youngwang NP

Sin-Gwangju

Sin-Hwasun

Sin-Gangjin

Haenam CSYeosu NP

Gwangyang

Hadong TP

Sin-Namwon Euiryong

Sancheong PP

Muju PP

Sin-Okcheon

Sinkaedong

Chungwon

Sin-Jincheon

Sin-Gosung

Samcheonpo TP

In-Masan

Sin-Gimhae

Bukbusan

Pusan CCNam-Pusan

Kori NP

Sin-Onsan

Ulsan TP CC


Buk-Daegu

Sunsan

Goryeong

Daegu

Sin-Kyeongsan

Ulju

Sin-Ulsan

Sin-Youngju

Sin-Youngil

Cheongsong PP

Uljin NP

Donghae

Yangyang PP

Sin-Jecheon

Sin-Gapyung

Sin-Ansung

Sin-seosan

Sin-Yangje

Sin-Ansan

Sin-Taebaek

Gwangyang Steel

Sin-Yangsan

Sin-Youngin

Sin-Sungnam

Dong-Seoul

Migum

Gonjiam


Gwangyang Steel

6










45000

50000

70000

(UnitMW)

65000

60000

55000


62790

(08)62290(56)62290(56)

54630(66)54630(66)51260

(82)51260(82)

58990(80)58990(80)

Reserve margin

As of Dec 201071308

(68)

Peak demand

(Growth rate)

122122113113

105105

7272

9191

6262

66800

(64)

7979

rsquo09

7







- Procedures

- Biddings

- Load Forecasting


- Metering

- Settlement




Mandatory Pool







9














10












year)

Definition of MLF

11










generators








12







13










Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU




Jeju TP

Yangju

Seo-Incheon

Youngheung TP

Hanrim CC

NamjejuSeogwipo

AndukSin-Jeju

Hanla

Sungsan

Jocheon

Dong-Jeju

Sanji

Seo-Incheon CC

Incheon TP CC

Sin-Incheon

Sin-Sihung

Sin-Bupyung

Sin-Dukheun

ChungbuYoungdeungpo

Youngseo

Seo-seoul

Uijeongbu

Sungdong


Ansan


Taean TP

Sin-onyang


Gunsan

Sin-Gimje

Youngwang NP

Sin-Gwangju

Sin-Hwasun

Sin-Gangjin

Haenam CSYeosu NP

Gwangyang

Hadong TP

Sin-Namwon Euiryong

Sancheong PP

Muju PP


Chungwon

Sin-Jincheon

Sin-Gosung

Samcheonpo TP

In-Masan

Sin-Gimhae

Bukbusan

Pusan CCNam-Pusan

Kori NP

Sin-Onsan

Ulsan TP CC


Buk-DaeguSunsan

GoryeongDaegu

Sin-Kyeongsan

Ulju

Sin-Ulsan

Sin-Youngju

Sin-Youngil

Cheongsong PP

Uljin NP

Donghae

Yangyang PP

Sin-Jecheon

Sin-Gapyung

Sin-Ansung

Sin-seosan

Sin-Yangje

Sin-Ansan

Sin-Taebaek

Sin-Yangsan

Sin-Youngin

Sin-Sungnam

Dong-Seoul

Migum

Gonjiam

CHARACTERISTICS














4




Bundang

Seoul

Sanchung

Hapchun

Cheongsong

IncheonPucheon

Pyungtaek

Anyang

Youngkwang

Chungju

Chuam

Yeosu

Honam Kwangyang

Sumjinkang

Yongdam

Muju

SeocheonBoryeong

POSCO

Sin-IncheonPaldnag

Chungpyung

Euiam

ChuncheonHwachun

Hadong

Samrangjin

SamcheonpoBusan

Kori

Andong

Yangyang

Kangreung

Uljin

Imha

Youngnam

Wolseong


Soyangkang

Ilsan

Youngheung

Taean

LGBugok

Ulsan

Daechung

Dangjin


Donghae

Yulchon

Jeju

(Unit 10 MW)

53180

99

120

180

50

48

45 9050

45

180180

180

90

40

33

74

50

40

400300

180

300

400

40

247

140

39

400

115

53

590

278

314590

6

60

10011

12

8

7

20

2

3

2

9

59

60

41

40

6010

70

6

5Chungpyung

As of Dec 31 2010


Nuclear

17716(233)

Oil

5805(76)

Hydro5524(73)

Renewable

1762(23)Coal

24800

(326)

LNG

20471

(269)

5




Characteristics

Direct Current Line


to Jeju Island

345kV


Distribution system


154kV




154kV 20700 628

345kV 8552 88

765kV 755 6Jeju TP

Yangju

Seo-Incheon

Youngheung TP

Hanrim CC

NamjejuSeogwipo

Anduk Sin-Jeju

Hanla

Sungsan

Jocheon

Dong-Jeju

Sanji

Seo-Incheon CC

Incheon TP CC

Sin-Incheon

Sin-Sihung

Sin-Bupyung

Sin-Dukheun

Chungbu

Youngdeungpo

Youngseo

Seo-seoul

Uijeongbu

Sungdong

Hwasung


Ansan


Taean TP

Sin-onyang


Gunsan

Sin-Gimje

Youngwang NP

Sin-Gwangju

Sin-Hwasun

Sin-Gangjin

Haenam CSYeosu NP

Gwangyang

Hadong TP

Sin-Namwon Euiryong

Sancheong PP

Muju PP

Sin-Okcheon

Sinkaedong

Chungwon

Sin-Jincheon

Sin-Gosung

Samcheonpo TP

In-Masan

Sin-Gimhae

Bukbusan

Pusan CCNam-Pusan

Kori NP

Sin-Onsan

Ulsan TP CC


Buk-Daegu

Sunsan

Goryeong

Daegu

Sin-Kyeongsan

Ulju

Sin-Ulsan

Sin-Youngju

Sin-Youngil

Cheongsong PP

Uljin NP

Donghae

Yangyang PP

Sin-Jecheon

Sin-Gapyung

Sin-Ansung

Sin-seosan

Sin-Yangje

Sin-Ansan

Sin-Taebaek

Gwangyang Steel

Sin-Yangsan

Sin-Youngin

Sin-Sungnam

Dong-Seoul

Migum

Gonjiam


Gwangyang Steel

6










45000

50000

70000

(UnitMW)

65000

60000

55000


62790

(08)62290(56)62290(56)

54630(66)54630(66)51260

(82)51260(82)

58990(80)58990(80)

Reserve margin

As of Dec 201071308

(68)

Peak demand

(Growth rate)

122122113113

105105

7272

9191

6262

66800

(64)

7979

rsquo09

7







- Procedures

- Biddings

- Load Forecasting


- Metering

- Settlement




Mandatory Pool







9














10












year)

Definition of MLF

11










generators








12







13










Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU




Bundang

Seoul

Sanchung

Hapchun

Cheongsong

IncheonPucheon

Pyungtaek

Anyang

Youngkwang

Chungju

Chuam

Yeosu

Honam Kwangyang

Sumjinkang

Yongdam

Muju

SeocheonBoryeong

POSCO

Sin-IncheonPaldnag

Chungpyung

Euiam

ChuncheonHwachun

Hadong

Samrangjin

SamcheonpoBusan

Kori

Andong

Yangyang

Kangreung

Uljin

Imha

Youngnam

Wolseong


Soyangkang

Ilsan

Youngheung

Taean

LGBugok

Ulsan

Daechung

Dangjin


Donghae

Yulchon

Jeju

(Unit 10 MW)

53180

99

120

180

50

48

45 9050

45

180180

180

90

40

33

74

50

40

400300

180

300

400

40

247

140

39

400

115

53

590

278

314590

6

60

10011

12

8

7

20

2

3

2

9

59

60

41

40

6010

70

6

5Chungpyung

As of Dec 31 2010


Nuclear

17716(233)

Oil

5805(76)

Hydro5524(73)

Renewable

1762(23)Coal

24800

(326)

LNG

20471

(269)

5




Characteristics

Direct Current Line


to Jeju Island

345kV


Distribution system


154kV




154kV 20700 628

345kV 8552 88

765kV 755 6Jeju TP

Yangju

Seo-Incheon

Youngheung TP

Hanrim CC

NamjejuSeogwipo

Anduk Sin-Jeju

Hanla

Sungsan

Jocheon

Dong-Jeju

Sanji

Seo-Incheon CC

Incheon TP CC

Sin-Incheon

Sin-Sihung

Sin-Bupyung

Sin-Dukheun

Chungbu

Youngdeungpo

Youngseo

Seo-seoul

Uijeongbu

Sungdong

Hwasung


Ansan


Taean TP

Sin-onyang


Gunsan

Sin-Gimje

Youngwang NP

Sin-Gwangju

Sin-Hwasun

Sin-Gangjin

Haenam CSYeosu NP

Gwangyang

Hadong TP

Sin-Namwon Euiryong

Sancheong PP

Muju PP

Sin-Okcheon

Sinkaedong

Chungwon

Sin-Jincheon

Sin-Gosung

Samcheonpo TP

In-Masan

Sin-Gimhae

Bukbusan

Pusan CCNam-Pusan

Kori NP

Sin-Onsan

Ulsan TP CC


Buk-Daegu

Sunsan

Goryeong

Daegu

Sin-Kyeongsan

Ulju

Sin-Ulsan

Sin-Youngju

Sin-Youngil

Cheongsong PP

Uljin NP

Donghae

Yangyang PP

Sin-Jecheon

Sin-Gapyung

Sin-Ansung

Sin-seosan

Sin-Yangje

Sin-Ansan

Sin-Taebaek

Gwangyang Steel

Sin-Yangsan

Sin-Youngin

Sin-Sungnam

Dong-Seoul

Migum

Gonjiam


Gwangyang Steel

6










45000

50000

70000

(UnitMW)

65000

60000

55000


62790

(08)62290(56)62290(56)

54630(66)54630(66)51260

(82)51260(82)

58990(80)58990(80)

Reserve margin

As of Dec 201071308

(68)

Peak demand

(Growth rate)

122122113113

105105

7272

9191

6262

66800

(64)

7979

rsquo09

7







- Procedures

- Biddings

- Load Forecasting


- Metering

- Settlement




Mandatory Pool







9














10












year)

Definition of MLF

11










generators








12







13










Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU




Characteristics

Direct Current Line


to Jeju Island

345kV


Distribution system


154kV




154kV 20700 628

345kV 8552 88

765kV 755 6Jeju TP

Yangju

Seo-Incheon

Youngheung TP

Hanrim CC

NamjejuSeogwipo

Anduk Sin-Jeju

Hanla

Sungsan

Jocheon

Dong-Jeju

Sanji

Seo-Incheon CC

Incheon TP CC

Sin-Incheon

Sin-Sihung

Sin-Bupyung

Sin-Dukheun

Chungbu

Youngdeungpo

Youngseo

Seo-seoul

Uijeongbu

Sungdong

Hwasung


Ansan


Taean TP

Sin-onyang


Gunsan

Sin-Gimje

Youngwang NP

Sin-Gwangju

Sin-Hwasun

Sin-Gangjin

Haenam CSYeosu NP

Gwangyang

Hadong TP

Sin-Namwon Euiryong

Sancheong PP

Muju PP

Sin-Okcheon

Sinkaedong

Chungwon

Sin-Jincheon

Sin-Gosung

Samcheonpo TP

In-Masan

Sin-Gimhae

Bukbusan

Pusan CCNam-Pusan

Kori NP

Sin-Onsan

Ulsan TP CC


Buk-Daegu

Sunsan

Goryeong

Daegu

Sin-Kyeongsan

Ulju

Sin-Ulsan

Sin-Youngju

Sin-Youngil

Cheongsong PP

Uljin NP

Donghae

Yangyang PP

Sin-Jecheon

Sin-Gapyung

Sin-Ansung

Sin-seosan

Sin-Yangje

Sin-Ansan

Sin-Taebaek

Gwangyang Steel

Sin-Yangsan

Sin-Youngin

Sin-Sungnam

Dong-Seoul

Migum

Gonjiam


Gwangyang Steel

6










45000

50000

70000

(UnitMW)

65000

60000

55000


62790

(08)62290(56)62290(56)

54630(66)54630(66)51260

(82)51260(82)

58990(80)58990(80)

Reserve margin

As of Dec 201071308

(68)

Peak demand

(Growth rate)

122122113113

105105

7272

9191

6262

66800

(64)

7979

rsquo09

7







- Procedures

- Biddings

- Load Forecasting


- Metering

- Settlement




Mandatory Pool







9














10












year)

Definition of MLF

11










generators








12







13










Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU










45000

50000

70000

(UnitMW)

65000

60000

55000


62790

(08)62290(56)62290(56)

54630(66)54630(66)51260

(82)51260(82)

58990(80)58990(80)

Reserve margin

As of Dec 201071308

(68)

Peak demand

(Growth rate)

122122113113

105105

7272

9191

6262

66800

(64)

7979

rsquo09

7







- Procedures

- Biddings

- Load Forecasting


- Metering

- Settlement




Mandatory Pool







9














10












year)

Definition of MLF

11










generators








12







13










Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU







- Procedures

- Biddings

- Load Forecasting


- Metering

- Settlement




Mandatory Pool







9














10












year)

Definition of MLF

11










generators








12







13










Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU




Mandatory Pool







9














10












year)

Definition of MLF

11










generators








12







13










Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU














10












year)

Definition of MLF

11










generators








12







13










Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU












year)

Definition of MLF

11










generators








12







13










Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU






generators








12







13










Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU







13










Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU










Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU







Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU




Daily Bidding



bull Bidding time




Re-Offers




16




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU




Real-timeReal-time



( D-1 )( D-1 )

Daily bidamp offer

made by standing

bid procedure

5 am 10am

Daily bid

Submission

Gate Closure

16pm

Pumping bid

Gate Closure

15pm

SMPDisclosure

Trading hour

20pm

18pm


Disclosure

19pm

Bid change Closure


faults outages

17




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU




18

P(MW)P(MW)

C C

i i ( $

h o ur )

( $

h o ur )

No-load -

Cost










Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU




Forecasting tool


Application




Using database




19







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU







Major Functions




20




supply and demand













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU













21







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU







power system

Input

Data












ObjectiveFunction


DisclosureTime


22






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU






p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU



p(SMP) (2)

(Time)

(Unit WonkWh

(Unit10MW)

Low

High

0100 0400 0900 1200 1500 1900 2100 2400

Power demand(10MW) 3730 3320 4770 5500 5690 5420 5420 4740


24

Power demand

Market price










minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU









minimize cost

balance load




25













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU













26










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU










Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU







Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU




Day-ahead

Market

Price(SMP)

Schedule

Load Forecast

Cost Based

Bid Curve

Capacity

Bid

Real Time

System Operation

A S Bid

Generation

Capacity Prices

AS Prices

Energy

Scheduled

Metered

Capacity

A S

Settlements

+-

29












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU












IPPS SMP 746



30















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU















18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU







18

2328

Number of Members

(Unit No)


As of December 2010

104

302422

374

392441





32





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU





market



Retail prices






33












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU












the market opening






Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU





Power System

Market IssuesⅣⅣ


Demand Response

Vesting Contract












Power Planning

Power System

THANK YOU












Power Planning

Power System

THANK YOU



Power Planning

Power System

THANK YOU

Documents

Power market operation-발표