Power Plant Base

7/28/2019 Power Plant Base

1/11

Optimisation of integrated energy conversionsystems

Dr. Franois Marechal

Computer aided energy system analysis and synthesis group

Laboratoire dnergtique industrielle (LENI)

Ecole Polytechnique fdrale de Lausannehttp://leniwww.epfl.ch

mailto:[email protected]

Example : Thermo-economic modeling of power plants

Thermodynamic models

mi ,Wi ,Pi ,Ti => Sizei

Costi = f(Sizei ,Pi )

Thermo-economic models

mNG ,mCO2, Wii

"

OC= mNG *CGN + mCO2*TCO2

#Cel * Wii

"

System Performances

IC= Costii

"

System investment

Flowsheets and models


2/11

Superstructures

Equipments optionsLow Nox burner, O2 burning

Equipments selection1 / 2 gas turbines, CO2 separation

Equipments interconnectiondraw-off, heat exchangers

System integrationheat exchange system

Optimisation

Decisionvariables

Continuous Variables

mi ,Ti ,Pi

Integer Variables

Optioni ,equipmenti

Objectivefunctions

Total cost

Investment

Emissions

Efficiency

Op. cost

Solving methods


3/11

Multi-objective optimisation

Decisionvariables

Continuous Variables

mi ,Ti ,Pi

Integer Variables

Optioni ,equipmenti

Objectivefunctions

Total cost

Investment

Emissions

Efficiency

Op. cost

Multi-objective optimisation (MOO)!Evolutionary algorithm!Mixed Integer Non Linear Prog.!Clusters of solutions

Pareto Curves

Emissions(kgCO

2/kWh)

Investment Cost ($/kW)

Infeasible

Min Emissions for a max Investment

Min Investment for a max emission

PerformancesSystem configurationEquipment design specifications

PerformancesSystem configurationEquipment design specifications


4/11

Pareto Curves

Emissions(kgCO2/kWh)


For each configuration

Selected equipments

Operating conditions : T, P, m Interconnections

Sizes

"E

"Inv

Calculations for 1 plant size

Technicallyinaccessible

region

1GT/2P level

1GT/SQ+3P level + reheat

CO2 capture solutions

Typification MapGT & NGCCs based onALSTOM Catalogue1

1Based on public data from ALSTOM Website

1 GT26 420MW2 GT26850MW

1 GT11175 MW

2 GT11350 MW

3 GT11530 MW

1 GT13250 MW

3 GT13770 MW

2 GT13510 MW

50.7%

53%

seq comb. Effelec=59.5%;3p with RH STTfiring = 1425C, PR =31

Effelec=58.7%; 3p with RH STTfiring = 1421C, PR =21

simple combustionEffelec=56.6%; 3p STTfiring = 1367C, PR=18

seq comb. Effelec=58.8%;3p with RH STTfiring = 1387C, PR =24


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Definition of technology port-folio

Competing options

Different markets

Different objectives

Market identification

For a given technology

For a given goal

E.g. CO2 emissions

CDM Potential

Effect of CO2 value

! ! wrt to baselineEmissions(kgCO2

/kWh)



1 GT262 GT26

1 GT112 GT113 GT11

1 GT133 GT13 2 GT13

800

600

400

200

300

500

700

Specific Investment cost including gas supply subsystem (US$/kWh)

Typification Through Thermoeconomic Modellingand Multi-Objective Optimization

Natural Gas Price Sensitivity Analysis(1)Natural gas price: 1 UScents/kwh, Annual operating hours: 7500, Depreciation period: 15 years

OptimalConfiguration57.9 %849 MW

OptimalConfiguration57.16 %419 MW

With 2 GT26

With 1 GT26


6/11


Natural Gas Price Sensitivity Analysis (2)Natural gas price: 2UScents/kwh, Annual operating hours: 7500, Depreciation period: 15 years

58.39 %856 MW

58.08 %426 MW

With 2 GT26

With 1 GT26


Natural Gas Price Sensitivity Analysis (3)Natural gas price: 3 UScents/kwh, Annual operating hours: 7500, Depreciation period: 15 years

58.45 %857 MW

58.14 %426.3 MW

With 2 GT26

With 1 GT26


7/11

Cost of Electricity vs CO2 Emission RateNGCCs based onALSTOM Catalogue

1 GT262 GT26

1 GT112 GT113 GT11

1 GT133 GT131 GT13

800

600

400

200

300

500

700


1 GT262 GT26

1 GT112 GT11

3 GT11

1 GT133 GT13 2 GT13

800

600

400

200

300

500

700

Specific Investment cost including gas supply subsystem (US$/kWh) %CO2abatement

Sensitivity analysis : CO2 impact

CO2 abatment cost [$/tonCO2]

mNG[kg /s]

E[kW]

I[$]mCO2

[kg /s]

mCO2

ref,i" mCO2

mCO2

ref,i

(mNGCiNG +O

i+

1

"iIi)#LEC

ref,i E

mCO2

ref,i# m

CO2

From technology data base

Country i

Country 2

Country 1


8/11

The same system in different context

Configuration with 2 GT 26

Advanced power plants

CO2 Sequestration

Subsystem

GAS TURBINESUBSYSTEMS

GAS SUPPLYSUBSYSTEM

STEAM

CYCLE

SUBSYSTEMS

Transportation and

Storage


9/11

Project : Supply 400 MW to a community

subject to

Average Cost of Electricity COEav[US$/kWh]=

(Annual Capital Cost + Annual O&M Cost + Annual Fuel Cost+ Annual MEA Solvent and CO2 Disposal Cost+ Power ImportationCost)/ Total Annual Power Demand

Average CO2 Emission Rate RCO2av[gCO2/kWh]=

(Annual CO2 Emission from NGCC combustion +Annual CO2 Emission Due to Natural Gas Leakage +Annual CO2 Emission due to PowerImportation)/ Total Annual Power Demand

Min (COEav, RCO2av) =

Pareto Optimization Frontier (POF)Of A 400 MW Power Supply Project in Germany

Natural gas price is of 1 UScents/kWh; Electricity importation price is of 3.8 UScents/kWh

400MW NGCCwith MEA

NGCCwith

CO

2cap

ture

GrowingSize

400MWNGCC

400MWNGCC withCO2capture

All Power Importedfrom the Grid

176MW

CO2emissionlimitation




10/11

Sensitivity Analysis (I)Different CO2 Tax Levels

0 US$/tonCO2Baseline:Full Power Imported from

the Power Grid

B2 176MW

D1400MW

D2

A1400MW

400MW NGCC

400MW NGCC

with CO2 capture

NGCC with CO2 capture

+ Grid Power Importation

C1

30 US$/tonCO2

A1B2

C1

D2


D1

COEav

(UScents/kWh)

RCO2av

(gCO2/kWh)

CO2abatement percentage (AP) [%]

CO2abatement cost (ABC) [US$/tonCO2]

Alternative Presentation: Relative CO2 Abatement Cost

For a given baseline (Reference Case)

(RCO2av RCO2baseline) [gCO2/kWh]

RCO2baseline [gCO2/kWh]AP=

(COEav COEbaseline) [US$/kWh]

(RCO2av RCO2baseline) [tonCO2/kWh]ABC=


11/11

CO2 Abatement Percentage vs CO2 Abatement Cost

BASELINE: Full Electricity Importation from Power Grid

Profitable

Non-Profitable

Further financial aid is needed

Documents

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