C1_CCPP

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1. Introduction to Combined 1. Introduction to Combined Cycle Cycle Power Plants Power Plants

Combined Cycle Power Plants 1. Combined Cycle Power Plants 1 / 109

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Introduction to Combined Cycle Power Plants 21

Electricity Demand and Supply 222

Cost of Electricity 443

Electricity Demand and Supply 222

Characteristics of Combined Cycle Power Plants 534

Wide Use of Gas Turbine 1025



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Gas Turbine In a gas turbine, the working fluid for transforming thermal energy into rotating mechanical energy is the hot

combustion gas, hence the term “gas turbine.”

The first power generation gas turbine was introduced by ABB in 1937 it was a standby unit with a thermal The first power generation gas turbine was introduced by ABB in 1937. it was a standby unit with a thermal efficiency of 17%.

The gas turbine technology has many applications. The original jet engine technology was first made into a h d t li ti f h i l d iheavy duty application for mechanical drive purposes.

Pipeline pumping stations, gas compressor plants, and various modes of transportation have successfully used gas turbines.

While the mechanical drive applications continue to have widespread use, the technology has advanced into larger gas turbine designs that are coupled to electric generators for power generation applications.

Gas turbine generators are self-contained packaged power plants.

Air compression, fuel delivery, combustion, expansion of combustion gas through a turbine, and electricity generation are all accomplished in a compact combination of equipment usually provided by a singlegeneration are all accomplished in a compact combination of equipment usually provided by a single supplier under a single contract.

The advantages of the heavy-duty gas turbines are their long life, high availability, and slightly higher overall


efficiencies. The noise level from the heavy-duty gas turbines is considerably less than gas turbines for aviation.

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Power Generation Requirement

CoalGas

Variety of Fuels Competitive Machine

GasOilWaterNuclearWind ci

ency

ilabi

lity

erat

ing

xibi

lity

Em

issioC

osts

WindSolarGeothermalBiomass

Effi

cAv

aO

peFl

ex

ns


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Type of Plant

Base Load Intermediate Load Peak Load

OperatingOperating Hours [hr/a] 5000 2000 to 5000 2000

• Nuclear plant • Gas turbine

Generating Units

• High-performance steam turbine plant

• High efficient combined cycle

• Simple steam turbine plant

• Old base-load plant

• Combined gas and steam

• Diesel engine

• Pumping-up power plantg yplant

• Hydropower plant

• Combined gas and steam plant • Old simple steam turbine

plant

Characteri-

• Operated at full load as long as possible during the year

• High efficiency and lowest cost

• Operated on weekdays andshutdown at night and on the weekend

• Low capital investment, buthighest operating costs

Characteri-stics

• High efficiency and lowest cost

• Poor load change capability (take more time to respond load demand)

• The efficiency is higher than that of peak-load plants, but lower than that of base-load plants

• Ease in startup

• Used as standby or emergency also


) plants

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Combined Cycle Power Plants

In simple cycle mode, the gas turbine is operated alone, without the benefit of recovering any of energy in the hot exhaust gases. The exhaust gases are sent directly to the atmosphere.Fuel

In combined cycle mode, the gas turbine exhaust gases are sent into HRSG. The HRSG generates steam that is normally used to power a steam turbine.

Combustor

Turbine G

Compressor

Inlet Air

Steam GHP LP

Exhaust GasAir Turbine G

Condenser

HP Drum

LP Drum

HRSGCondenser

DeaeratorHP Superheater

HP EvaporatorHP Economizer

LP Superheater

Condensate

LP Boiler Feed Pump

pLP Evaporator

LP Economizer


PumpHP Boiler Feed Pump

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Simple Cycle

Simple cycle gas turbines for electricity generation are typically used for standby or peaking capacity and are generally operated for a limited number of hours per year. Peaking operation is often defined as fewer than 2,000 hours of operation per year., p p y

In mechanical drive applications, and for some industrial power generation, simple cycle gas turbines are base load and operate more than 5 000 hours of operation per yearbase-load and operate more than 5,000 hours of operation per year.

Some plants are initially installed as simple cycle plants with provisions for future conversion to combined cycle.

Gas turbines typically have their own cooling, lubricating, and other service systems needed for simple yp y g g y pcycle operation. This can eliminate the need to tie service systems into the combined cycle addition and will allow continued operation of the gas turbine during the conversion process and, with proper provisions, during periods when the combined cycle equipment is out of service.

If future simple cycle is desired, a bypass stack may be included with the connection of the HRSG. A typical method for providing this connection is to procure a divert damper box at the outlet of the gas turbine.


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Schematic of a CCPP


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3 P R h C l (F Cl G T bi )

Cycle Diagram3 Pressure Reheat Cycle (F-Class Gas Turbine)

Fuel

GHeat Recovery

Steam Generator

Air

Gas Turbine

IP Steam LP SteamCold ReheatHot Reheat Main

G

SteamCold Reheat Steam

Hot Reheat Steam

Main Steam

St

Condenser

G

Steam Turbine

Condensate Pump

SteamWaterFuelAir


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T-s Diagram for a Typical CCPP

T

Topping Cyclepp g y(Brayton Cycle)

Bottoming Cycle(Rankine Cycle)

s


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CHP; Combined Heat and Power

In the simplest arrangements, the gas turbine waste heat is used directly in an industrial process, such as for drying in a paper mill,such as for drying in a paper mill, or cement works.

Adding an HRSG converting t h t i t t iwaste heat into steam, gives

greater flexibilities in the process for chemical industries, or district heating


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Thermodynamic Consideration

THH

W

QH

Gas

TH

WTurbine

W

QH

에너지

HRSG

Q

W에너지변환

Q

WSteamTurbine

TL

QL

TL

QL

[ F il / N l ] [ C bi d C l ]


[ Fossil / Nuclear ] [ Combined Cycle]

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Gas Turbine Combined Cycle

구분 Topping Cycle Bottoming Cycle

Main Components GT ST/HRSG

Working Fluid Air Water/Steam

Temperature High Medium/Low

Thermodynamic Cycle Brayton Rankine

Coupling Two Cycles Heat Exchanger

Topping Cycle Bottoming Cycle


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Combined cycle means the combination of two thermal cycles in one plant.

When two cycles are combined, the efficiency increases higher than that of one cycle alone.y y g y

Thermal cycles with the same or with different working fluid can be combined.

In general a combination of cycles with different working fluid has good characteristics because their In general, a combination of cycles with different working fluid has good characteristics because their advantages can complement one another.

Normally, when two cycles are combined, the cycle operating at the higher temperature level is called as t i l Th t h t i d f d th t i t d t th l t t l ltopping cycle. The waste heat is used for second process that is operated at the lower temperature level, and is called as bottoming cycle.

The combination used today for commercial power generation is that of a gas topping cycle with a water/steam bottoming cycle. In this case heat can be introduced at higher temperature and exhausted at very low temperature.

Temperature of the air used as a working fluid of gas turbines can be increased very high under lower Temperature of the air used as a working fluid of gas turbines can be increased very high under lower pressure. Water/steam used as a working fluid can contain very high level of energy at lower temperature because it has very high specific heat.

N ll th t i d b tt i l l d i h t h


Normally the topping and bottoming cycles are coupled in a heat exchanger.

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Air is used as a working fluid in gas turbines having high turbine inlet temperatures because it is easy to get and has good properties for topping cycle.

Steam/water is an ideal material for bottoming cycle because it is inexpensive, easy to get, non-hazardous, and suitable for medium and low temperature ranges.

The initial breakthrough of gas-steam cycle onto the commercial power plant market was possible due to the development of the gas turbine.

In the late 1970s, EGT reached sufficiently high level that can be used for high efficiency combined cycles.

The breakthrough was made easier because gas turbines have been used for power generation as a simple cycle and steam turbines have been used widely.

For this reason, the combined cycle, which has high efficiency, low installation cost, fast delivery time, had been developed easily.


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CCPP System Options

Items Options Remarks

• Single pressure / Two pressure /Three pressure *Steam Cycle • Reheat

• Non-reheatDependent on EGT

• Natural gas */ Distillate oil / Ash bearing oilFuel • Low BTU coal and oil-derived gas

• Multiple fuel systems

• Water injection / Steam injectionNOx Control • SCR (NOx and/or CO)

• Dry Low NOx combustion *

Condenser• Water cooled (once-through system) *

Condenser• Water cooled (cooling tower) /Air-cooled condenser

Deaeration• Deaerating condenser *• Deaerator/evaporator integral with HRSGg

HRSG Design

• Natural circulation evaporators *• Forced circulation evaporators• Unfired *


• Supplementary fired

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Base Configurations for CCPP

Unfired, 3-pressure steam cycle• Non-reheat for rated EGT less than 1000°F/538°C• Reheat for rated EGT higher than 1050°F/566°C and fuel heating• Heat recovery feedwater heating• Feedwater dearation on condenser• Feedwater dearation on condenser• Natural circulation HRSG evaporators

GT with DLN combustors

Once-through condenser cooling water system

Multi-shaft systems

Single-shaft systems• Integrated equipment and control system


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GT vs. ST

Gas Turbine Steam Turbine

Combustion Internal External

Thermodynamic cycle Brayton Rankine

Cycle type Open Closed

Working fluid Air Water/Steam

Max. pressure, bar 23 (40 for Aviation) 350 (5050 psig)

Max. temperature, C(F) 1350 (2462) 630 (1166)a te pe atu e, C( ) 350 ( 6 ) 630 ( 66)

Blade cooling Yes No

Shaft cooling No Yes (USC only)

Max. cycle efficiency, % 40 49 (USC only)

Max. number of reheat 1 2

Power density High Lowy g

Steam conditions of the steam turbines for combined cycle applications are lower than those for USC steam turbines.


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CCPP

Major equipment of combined cycle power plant• Gas turbine, steam turbine, generator, HRSG

Main advantages of the combined cycle power plant• Higher thermal efficiency than the others (up to 60%)

- SC steam plants: 35~40%, USC steam plants: 49%p , p• Shorter construction period• Lower initial construction cost

- Capital costs of gas fired combined cycle are about 40% of coal fired steam plants• Lower emission (low NOx burners, SCR, CO catalysts are available)

Current situationC t ti f CCPP h i d d ti ll i 1970• Construction of CCPP has increased dramatically since 1970s

• Market is governed by GE and SIEMENS• It is hard to develop a new competitive model because it requires both advanced technologies and

high costhigh cost


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CCPP Concept

Electricity Demand Process-energy (steam/water) demand Operating Philosophy Financing

Customer Requirements

(steam/water) demand

Site Related FactorsSite conditions / Ambient conditions50 or 60Hz Site conditions / Ambient conditions

Legislation / Emission requirements

Resources

50 or 60Hz

Fuel Water Space

Plant Concept SolutionpCapital cost

US$/kWType / Number of GTs

Single shaft Multiple shaft

Cycle selection with parameter optimization

Final optimization Plant /Cycle


Plant /Cycle

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A Typical HRSG

StackHPSection

IPSection

LPSection

TransitionDuct

starting

DuctBurner

Air Inlet

Duct

AddtionalAir supply

startingMoter

GeneratorGasTurbine

GasTurbine

FlowCorrectionDevice

HRSG

Inlet duct

A-A section


Exhaust duct

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Introduction to Combined Cycle Power Plants1

Electricity Demand and Supply2



Characteristics of Combined Cycle Power Plants4




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Demand and Supply

Electricity must be produced when the consumers need it because it cannot be stored in a practical manner on a large scale.

Electricity can be stored indirectly through water, but it is not economical.

Actually only storage of water pumped into lakes during off-peak time to be used during peak hours has been used practically.

Large fluctuation in demand during the day requires quick response from power plants to meet the balance between demand and supply.

Gas turbine combined cycle power plants have good characteristics in terms of fast start-up and shut-down.

In addition, they have low investment costs, short construction times compared to large coal-fired power stations and nuclear plants.

The other advantages of combined cycles are high efficiency and low emission.


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Power Demand during a Day

Excellent start-up and shut down capabilities are essential for thisare essential for this


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발전전력량 분석


출처: 전력시장분석보고서, 전력거래소 (2012)

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연도별 전력수급 실적 및 전망



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발전연료별 설비용량 추이



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발전원별 연평균 가동시간 비율



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발전원별 발전기 이용률



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발전연료별 열량 단가



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향후 발전연료별 구성 전망



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주요 발전회사별 전력거래량 점유율



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국내 복합발전 설치 현황 - 민자

회사 위치 제작사 GT 대수 GT용량 ST용량 총용량 비고

GS EPS 당진 SiemensV84.3

SGT6-8000H41

710.0274 0

378.0136 0 2013/8 완공SGT6 8000H 1 274.0 136.0 2013/8 완공

GS 파워부천 WH 501D5 3 315.6 100.0 CHP안양 ABB GT11N 4 317.6 100.0 CHP

SK E&S광양 GE 7FA+e 4 686.8 340.0 K-Power평택 3 515 1 285 0 833 3 on 1 Conf평택 3 515.1 285.0 833 3-on-1 Conf.

POSCO광양 GE 7FA+ 2 337.6 165.0포항 GE 7FA+ 2 337.6 165.0

POSCO에너지 인천 WHW501D5 12 1,200.0 600.0

POSCO에너지 인천 WHV84.3A 4 812.0 440.0

MPC순천

Siemens W501F 2 340.0 160.0MHI M501J 2 640.0 280.0 920 2-on-1 Conf.

대산 WH W501D5 4 408.0 100.0 현대중공업 인수

한국지역난방기술 화성 2 340.0한국지역난방공사 7EA인천종합에너지 인천 GE 6F 2 154.0

여천NCC 여수 GE 6B 5 190 0여천NCC 여수 GE 6B 5 190.0포천파워 포천 2 1560S-Power 안산 Siemens SGT6-8000H 2 548.0 272.0 2014/10 완공예정

대륜발전(한진중) 양주 556 2013/12 열병합


소 계

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국내 복합발전 설치 현황 - 한전

발전소 Site 제작사 GT (용량) GT 대수 GT용량 ST용량 총용량 비고

신인천 GE 7FA+e (171.7) 8 1373.6 680.0부산 GE 7FA (170) 8 1360.0 680.0

남부발전 한림 GE 6B (38) 2 76.0 38.0영월 MHI M501F 3 550.0 310.5안동 Siemens SGT6-8000H 1 274.0 136.0 2014년 완공

보령 ABB GT24 (150) 6 900 0 450 0

중부발전

보령 ABB GT24 (150) 6 900.0 450.0

인천Siemens V84.3A

?22

320.0360.0

160180.0

세종 515.0 2013/11월 열병합

서부발전

서인천 GE 7FA+e (171.7) 8 1373.6 680.0

평택GE 7EA (87.9) 4 351.6 160.0MHI M501J 2 640.0 280.0

군산 MHI M501G 2 508.0 210.0군산 MHI M501G 2 508.0 210.0동두천 MHI M501J 4 1280.0 560.0

남동발전 분당 ABB GT11N (79.4) 8 635.2 300.0일산 WH 501D5 (105.2) 6 631.2 300.0

동서발전 울산

WH 501D5 (105.2) 2 210.4 100.0WH 501F (150) 4 600.0 300.0MHI M501J 2 640.0 280.0

춘천 500MW 열병합 340 0 160 0 2014 완공(열병합)


춘천 500MW 열병합 340.0 160.0 2014 완공(열병합)

소 계

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신인천/서인천복합발전단지

복합화력 4,300 MW (7FA+e x 16 Units)


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국내 복합화력발전소

부산복합 (2,000 MW) 분당복합 (960 MW) 일산복합 (900 MW)

보령복합 (1,800 MW) POSCO 광양복합 (500 MW) POSCO 포항복합 (500 MW)

POSCO파워 (3 000 MW) GS EPS (1 000 MW) 현대중 대산 (500 MW) 메이야율촌 (500 MW) K P (1 074 MW)POSCO파워 (3,000 MW) GS EPS (1,000 MW) 현대중 대산 (500 MW) 메이야율촌 (500 MW) K-Power(1,074 MW)

울산 (1,200 MW)

담수설비

GS 파워 (1,000 MW)


담수설비

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국내 복합화력발전소

메이야율촌복합 (550 MW) 군산복합 (700 MW) 영월복합 (900 MW)( ) ( ) ( )

현대 대산복합 (507 MW)분당복합 (960 MW) GS EPS 부곡복합 (1020 MW)


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Gas Turbine Production by SectorS D i F F I i l

18

Source: Davis Franus, Forecast International

7)

15Commercial Aviation

lars

(200

7

12

Electrical Generation

ons

of D

ol

6

9Electrical Generation

Billi

o

3

6Military Aviation

Mechanical Drive

2004 2006 2008 2010

Marine Propulsion


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세계 에너지원별 소비

구분 석유 천연가스 석탄 원자력 신재생 합계

(단위: QBtu, %)

구분 석유 천연가 석탄 원자력 신재생 합계

소비량 162.1 99.1 100.4 26.5 32.7 420.8

소비비중 38.5 23.6 23.9 6.2 7.8 100

기준년도: 2003년

원자력 ( )

신재생 (7.8%)

자료) 미국에너지정보국, International Energy Outlook, 2006

1 QBtu = 25.2Mtoe

1 QBtu 1 Qu d illi Btu {Qu d illi 1015

석유 (38.5%)석탄(23.9%)

원자력 (6.2%)

1 QBtu = 1 Quadrillion Btu {Quadrillion = 1015

(미국) or 1024 (유럽)}

toe = Tonnage of Oil Equivalent (1석유환산톤 = 석유 1톤을 연소시킬 때 발생되는 에너지)

천연가스 (23.6%)


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World Primary Energy


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S IEO (2008)

World Power Generation by Fuel Type

Billion MW-h40

Source: IEO (2008)

40

30

Renewables

Nuclear

20

Renewables

Nat. Gas

10Coal

02005 2010 2015 2020 2025 2030

Hydro


2005 2010 2015 2020 2025 2030

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B d C li d G i

World Power Generation by Fuel TypeBased on Centralized Generation


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Market Share and Product


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국내 발전원가 비교

2007년 기준

단위: 원/kWh 677 4단위: 원/kWh 677.4

117.0128.3

107.3

39.4 40.9

원자력

• 석탄의 경우 탄소배출권 비용을 감안하면 발전원가 27.2원 상승

원자력의 경우 핵폐기물 처리비용 미반영

원자력 석탄 중유 LNG 풍력 태양광


• 원자력의 경우 핵폐기물 처리비용 미반영

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S P Pl E i i (Bl k & V h)

발전원가 비교Source: Power Plant Engineering (Black & Veatch)


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발전원가 비교

400

300W

-yea

r

Coal-Steam

Gas Turbine

200

l Cos

t, $/

kW

100

Ann

ua Combined Cycle

0 1,500 5,000 8,760

Operation Hours/year

0

Comparisons will depend on fuel costs, capital costs, and maintenance costs.


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발전원가 비교

In contrast to steam turbine-generators, the manufacturers of gas turbines have a defined product line, allowing for substantial standardization and assembly line manufacturing.

The modular concept of the package power plants made gas turbines relatively quick and easy to install.

Standardization and modularization combine to provide the product benefits of relatively low capital cost and fast installation.

The benefits of low capital cost and fast installation were initially offset by higher operating costs when compared to other installed capacity. Therefore, early utility applications of gas turbine generator were strictly for peak load operation for a few hundred hours per year.

Improvements in efficiency and reliability and the application of combined cycles have added to the economic benefits of the technology and now give gas turbine based power plants a wider range of application on electric systems.


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Cost of Electricity

< Inputs for the evaluation of the cost of electricity >

Type of Plant Output, MW

Description

Investment cost, US$/kW

Average efficiency (LHV), %

Fuel price, US$/MBTu

(LHV)감가상각

Combined Cycle Power Plant 800

2 x GT1 x ST

750 56.5 8.0 25

Gas Turbine Plant (gas) 250 1 x GT 413 37.5 8.0 25Plant (gas)

Steam Power Plant (coal) 800 1 x ST 1716 44.0 3.5 25

Nuclear Power 1250 1 x ST 3500 34 5 0 5 40Plant 1250 1 x ST 3500 34.5 0.5 40

No cost for CO2 emissions were included.


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Cost of Electricity

100Capital

I t di t L dB L d

MW

h) 80

O&MFuel

Intermediate LoadBase Load

ricity

(US

$/M

60

ost o

f Ele

ctr

20

40

Co 20

800 MW CCPP (gas)

800 MW Steam (coal)

250 MW GT PP (gas)

1250 MW Nuclear PP

800 MW CCPP (gas)

800 MW Steam (coal)

250 MW GT PP (gas)

1250 MW Nuclear PP


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복합화력발전 가격

GE S109H: Dry Low NOxCombustors(H System™): Combined cycle: 14 Can-annular lean pre-mix DLN-2.5combustors : Output 480 MW (Gas turbine power 300 MW): Heat rate 6000 kJ/kWh: $153,500,000 ($320/kW) F15-K : $1억


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Turbine Blade Prices (1998년 기준)NOZZLE BUCKET

제작사 MODEL 출력(MW) TIT (C) 단

개수 가격($)/Set MATERIAL 개수 가격($)/Set MATERIAL1 48 1,180,000 FSX410 92 2,200,000 GTD1112 48 1,180,000 GTD222 92 1,500,000 GTD1117FA 175 1,2603 60 1 190 000 GTD222 92 1 450 000 GTD1113 60 1,190,000 GTD222 92 1,450,000 GTD1111 32 680,000 FSX414 92 670,000 GTD1112 48 690,000 FSX414 92 680,000 IN7387EA 88 1,1043 48 740,000 FSX414 92 600,000 U5001 36 390,000 FSX414 92 430,000 GTD111

GE

2 48 450,000 GTD222 92 330,000 IN7386B 39 1,1043 64 420,000 GTD222 92 310,000 U5001 42 240,000 IN738 115 400,000 IN738LC2 66 210,000 IN939 115 400,000 IN738LC3 84 280 000 IN730 97 210 000 IN738LCGT11N 80 1 027 3 84 280,000 IN730 97 210,000 IN738LC4 90 210,000 X45 105 390,000 IN738LC

GT11N 80 1,027

5 40 390,000 20/25/2 59 500,000 ST 16/25MD1 100 1,170,000 MAR M247LC 197 800,000 DS CM247LC2 44 656,000 MAR M247LC 88 950,000 DS CM247LC

ABB

3 80 948,000 MAR M247LC 86 1,170,000 DS CM247LC4 78 1,170,000 IN738LC 84 950,000 MAR M247LC

GT24 150 1,255

5 76 800,000 IN738LC 82 1,240,000 MAR M247LC1 48 810,000 ECY-768 81 340,000 U5202 48 700 000 X45 73 300 000 U5202 48 700,000 X45 73 300,000 U5203 56 720,000 ECY-768 55 340,000 U520

501D2 105 1,198

4 56 770,000 X45 51 340,000 IN GC-7501 32 560,000 ECY-768 72 1,400,000 IN7382 24 410,000 X45 66 1,000,000 IN738

WH

501F 150 1 293


3 16 380,000 ECY-768 112 1,400,000 IN738501F 150 1,293

4 14 430,000 X45 100 1,100,000 U520

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System Features of CCPP

Advantages Disadvantages

ff1. High thermal efficiency

2. Low initial investment

3. Short construction time

4. Fuel flexibility Wide range of gas and liquid fuels

5. High reliability and availability1. Higher fuel costs

g y y

6. Low operation and maintenance cost

7. High efficiency in small capacity increments Various gas turbine models

2. Uncertain long-term fuel supply

3. Output more dependent on ambient temperatures

Various gas turbine models

8. Operating flexibility Base, intermediate, peak load

9 E i t l f i dli9. Environmental friendliness

10. Reduced plant space


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1. High Thermal Efficiency [1/6]

The value of efficiency is very high because fuel spend may be about 70 percent of the total cost.

All major OEMs have developed air-cooled gas turbines for combined cycles with efficiencies around 61 percent.percent.

Siemens proved performance of 60.75% at the Irsching site outside Berlin.

The old paradigm that high performance meant advanced steam cooled gas turbines and slow started The old paradigm that high performance meant advanced steam cooled gas turbines and slow started bottoming cycles has definitely proven false.

Both GE and Siemens are able to do a hot-start within 30 minutes to full load.

Steam cooling will most likely only be used for 1,600C firing level since there will be an air shortage for both dry low emission and turbine cooling.

The key for 61% efficiency is high performance gas turbines having higher pressure ratio and firing The key for 61% efficiency is high performance gas turbines having higher pressure ratio and firing temperature.

In addition, the exhaust gas temperature has to be at a level for maximum bottoming cycle performance.

Currently, most OEMs have capability of steam turbine throttle temperature of 600C(1112F) and the optimum exhaust gas temperature should therefore be on the order of 25-30C higher.

B th GE d Si h t d d d th ttl diti f th i b tt i l 165


Both GE and Siemens have presented advanced throttle conditions for their bottoming cycles, 165 bar/600C and 170 bar/600C, respectively.

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Fuel EnergyThree Pressure

Combined cycle power plants have a higher thermal efficiency because of the application of two complementary thermodynamic cycles

Fuel Energy

100%

GT 37 6%L i HRSG

Three PressureReheat Cycle T

Topping CycleGT 37.6%Loss in HRSG0.3%

Loss

0 5%

pp g y(Brayton Cycle)

ST 21.7%

ense

r

0.5%

Loss

Con

deStack8.6%Loss

0.3% Bottoming Cycle(Rankine Cycle)

31.0%s

[ Heat balance in a typical combined cycle plant ]


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C i f Th l Effi i


발전 유형별 성능 비교

Comparison of Thermal Efficiency

60

5049 48

60발전 유형별 성능 비교

, %

50

4035

38 40

열효

율

30

35

10

20

원자력 IGCC가스터빈(SIMPLE)

화력(SC)

화력(USC)

가스터빈(복합)


(SIMPLE)(SC) (USC) (복합)

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E l i f H D G T bi D i F


1967 1972 1979 1990 2000 2008 2012

Evolution of Heavy Duty Gas Turbine Design Features

TIT, C (F) 900 (1650) 1010 (1850) 1120 (2050) 1260 (2300) 1426 (2600)

1426 (2600) 1500

Press. Ratio 10.5 11 14 14.5 19-23 20-23 20-23

EGT, C (F) 427 (800) 482 (900) 530 (986) 582 (1080) 593 (1100) 623

Cooling 1 vane1&2 vane1 blade

1&2 vane1&2 blade

1,2,3 vane1,2,3 blade

1,2,3 vane1,2,3 bladeblade

SC Power, MW 50-60 60-80 70-105 165-240 165-280 400-480 (CC)

SC Heat RateSC Heat Rate, Btu/kWh 11,600 11,180 10,250 9,500 8,850

CC Heat Rate, Btu/kWh 8,000 7,350 7,000 6,400 5,880 5,690

SC Effi., % 29.4 30.5 33.3 35.9 38.6 40

CC Effi., % 42.7 46.4 48.7 53.3 58.0 60 61


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P L d Effi i


100 The gas turbine equipped with

Part Load Efficiency

95

90

The gas turbine equipped with VIGV or several rows of variable stator vanes keeps the efficiency of the combined cycle plant almost constant down to

85

80

almost constant down to approximately 80 to 85% load.

This is because a high exhaust

75

70

ggas temperature can be maintained as the air mass flow is reduced.

30 40 50 60 70 80 90 100

65

60

Below that level, the turbine inlet temperature must be reduced, leading to an increasingly fast

d i f ffi i iLoad, %

30 40 50 60 70 80 90 100reduction of efficiencies.

The steam turbine is operated with sliding pressure mode down to 50% load. Below that point, the live-steam pressure is held constant resulting in throttling losses


steam pressure is held constant, resulting in throttling losses.

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P L d Effi i


110

Part Load Efficiency

95

1004GTs3GTs2GTs1GT

85

90

75

80

Down to 75% parallel reduction in load on all 4 GTs

65

70

Down to 75%, parallel reduction in load on all 4 GTs.At 75%, one GT is shut down.Down to 50%, parallel reduction in load on 3 remaining GTs.At 50%, a second GT is shut down.

Combined Cycle Load, %30 40 50 60 70 80 90 100

6020


4 GTs + 1 ST Arrangement

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C i f I i i l C i C

2. Low Initial Construction Cost [1/4]

Capital costs of gas-fired combined cycle are about 45% of coal-fired steam plants

Comparison of Initial Construction Cost

Type of Plant Output (MW) Specific Price (US$/kW)

Combined Cycle Power Plant 800 550 650Combined Cycle Power Plant 800 550 - 650

Combined Cycle Power Plant 60 700 - 800

Gas Turbine Plant 250 300 - 400

Gas Turbine Plant 60 500 - 600

Steam Power Plant (coal) 800 1,200 – 1,400

Steam Power Plant (coal) 60 1,000 – 1,200

Nuclear Power Plant 1,250 2,000 – 3,000

Bi P Pl t 30 2 000 2 500Biomass Power Plant 30 2,000 – 2,500

These prices are valid for 2007.Interest during construction is not included.


g

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C i f G T bi P i


550

Source: Gas Turbine World (1999 Jan/Feb)

Comparison of Gas Turbine Price

500

550

1xV84.2

1xGT13D1x401

1x501D5A

1x701D

G.E.

SIEMENS

ABB

se)

450

500

W

1x7FA

1xV94.21xV84.3A

1xGT11N2 1xGT24

1x701DW.H.

urnk

ey B

as

400

450

US

Dpe

rkW

1x7EA

1 9FA

1xGT11N2 1xGT24

r CC

PP

(Tu

350

400U 1x9FA

1xV94.2A

1x501F

e Le

vel f

or

100 200 300 400300

350

1xV94.3A1xGT26

1x701F

Pric

e


100 200 300 400ISO Net Combined Cycle Plant Output (MW)

300

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C B kd f CCPP


Items Portion % CCPP

Cost Breakdown for CCPP

Integrated Services 15%

4 Project management / Subcontracting

2 Plant and project engineering / Software

8 Plant erection / Commissions / TrainingServices 8 Plant erection / Commissions / Training

1 Transport / Insurance

15 Civil works

Lots 85%

32 Gas turbine / Steam turbine / Generator set

16 Balance of plants

7 Electrical systems7 Electrical systems

4 Instrumental and control

11 HRSG island

Basis: 350~700MW CC plant with a V94.3A Gas Turbine

As a rule of thumb, a 1% increase in the efficiency could mean that 3.3% more capital can be invested.


, y p

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C B kd f 400 MW CCPP


Site

Cost Breakdown for a 400 MW CCPP

Steam Turbine Set

Power Island Mechanical System

9%Civil, Arrangement, Building Facilities

18%

Site Infrastructure

3%

8%Heat Recovery

Steam Generator 10%

Mechanical Systems Outside

18%

Control 3%

yPower Island

8%

Electrical (without high

Control 3%

Gas Turbine Set 32%

Electrical (without high voltage switchyard)

9%


32%

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C i f C i Ti

3. Short Construction Time [1/2]

T pe of Plant Time [Months] Combined cycle plants are relatively quick

to design and erect because all major

Comparison of Construction Time

Type of Plant Time [Months]

Combined Cycle Power Plant 20 - 30

Gas Turbine Plant 12 - 24

to design and erect because all major equipment is shipped to the field as assembled and tested components.

The gas turbine is assembled at theSteam Power Plant (coal) 40 - 50

Nuclear Power Plant 60 - 80

The gas turbine is assembled at the factory and mounted on a structural base plate or skid, minimizing the need for field assembly of the turbine.

Biomass Power Plant 22 - 26 Other components and support systems such as cooling water and lubricating oil are modules that are easily erected and connected to the gas turbine skid

The gas turbine usually can be operated in simple cycle mode while the steam portion of the combined cycle is erected.

connected to the gas turbine skid.

The gas turbine from the 1960s to the late 1980s was used only as peaking power in the countries where the large steam turbines were used as base load power plants.

However gas turbine was used as base load mainly in the developing countries where the need of power


However, gas turbine was used as base load mainly in the developing countries where the need of power was increasing rapidly because the waiting period of three to six years for a steam plant was unacceptable.

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3. Short Construction Time [2/2]

Design Philosophy for Combined Cycle Plants

주문 / 제작 모델 / 표준화

Customizationstart from outside to inside

Standardizationstart from inside to outside

주문 / 제작 모델 / 표준화

1980’s 2000’s

Pre-engineered solution has the following benefits:• Time (shorter delivery time)• Quality (robust design)• Risk (exchangeable components in case of troubles)• Cost


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4. Fuel Flexibility

Most gas turbine applications rely on natural gas or No. 2 distillate oil.

Because of the availability and economics of natural gas, the [Table] GE heavy-duty GT shipped for fuels (by 1983)y g ,

majority of new power plants prefer natural gas as a fuel.

Fuel affects CC performance in a variety of ways.Fuel Units

Natural Gas 1408

shipped for fuels (by 1983)

Natural gas containing high hydrogen content has a higher heat content and therefore output and efficiency increase when the natural gas is used as a fuel.

Process GasDual GasDistillateNaphtha

1360

78314

Plant output and efficiency can be reduced when the ash bearing fuels (crude oil, residual oil, blends, or heavy distillate) are used because of fouling occurred in gas turbine and HRSG.

KeroseneDistillate or GasDistillate and GasCrudeCrude and Distillate

30964

825932

Plant output and efficiency can be reduced when the fuels containing higher sulfur content are used. This is because higher stack gas temperature is required to prevent condensation of corrosive sulfuric acid

Crude and DistillateResidualResidual or GasResidual/Distillate/Gas

32120

41

corrosive sulfuric acid.

Heavy fuels normally cannot be ignited for gas turbine startup; therefore a startup and shutdown fuel, usually light distillate, is needed with its own storage forwarding system and fuel

Total 3570


needed with its own storage, forwarding system, and fuel changeover equipment.

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D fi i i f R li bili d A il bili

5. High Reliability and Availability [1/4]

Reliability = Availability =P F P S F

Definition of Reliability and Availability

P = period hours (normally one year, 8,760h)F = total forced outage hours for unplanned outages and repairs

Reliability = Availability =P P

No of Successful Starts

S = scheduled maintenance hours

The probability that a unit, which is classified as available, and in ready service, can be started, and be brought to synchronization within a specific period time is defined as above An inability to start

Starting Reliability =No. of Successful StartsNo. of Attempted Starts

be brought to synchronization within a specific period time is defined as above. An inability to start within the specified period and synchronize is considered a failure to start. However, repeated attempts to start without attempting corrective action are not considered additional failures to start.

MTBF =Fired Hours

Trips from a state of operation


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C i f R li bili d A il bili


Source A Source B

Comparison of Reliability and Availability

Type of Plant Availability (%)

Reliability (%)

Availability (%)

Reliability (%)

Combined Cycle Power Plant 90 - 94 95 - 98 86 - 93 95 - 98y

Advanced GT CCPP 84 - 90 94 - 96

Gas Turbine Plant (gas fired) 90 - 95 97 - 99 88 - 95 97 - 99

Steam Power Plant (coal fired) 88 - 92 94 - 98 82 - 89 94 - 97

Nuclear Power Plant 88 - 92 94 - 98 80 - 89 92 - 98

• SGT6-5000F (W501F): Reliability: 99%, Availability: 95%, Starting reliability: 93% (2010)

Many analyses show that a 1% drop in the availability needs about 2~3% increase in the efficiency to Many analyses show that a 1% drop in the availability needs about 2 3% increase in the efficiency to offset that loss.

The larger gas turbines, just due to their size, take more time to undergo any of the regular inspections, such as combustor, hot gas path, and major overall inspections, thus reducing the availability of these turbines


availability of these turbines.

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A il bili R d i i C l Fi d P Pl


Source: EPRI CS-3344 pp.1-3

Stack S.H.R.H.

Availability Reduction in Coal-Fired Power Plant

Stack

HP Turbine IP Turbine

Econ

Gas

Water

LP Turbines

I.D. fan

Generator

Gas clean up

Condenser

AshAsh

Air heater

Coal

HP heater

LP heater

Water treatment

Fans (0 6%) Boiler tubes (4 2%) Fouling/slagging (2 8%) Pulverizers (0 6%) Bearings (2 0%)

Pulverizer

Coal prep Coal

F.D. fan


Fans (0.6%) Boiler tubes (4.2%) Fouling/slagging (2.8%) Pulverizers (0.6%) Bearings (2.0%) Pumps (1.7%) Condenser (3.8%) Turbine blades (2.7%) Generator (3.8%)

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Reliability is the percentage of the time between planned overhauls where the plant is generating or is ready to generate electricity, whereas the availability is the percentage of the total time where power could be producedbe produced.

Availability and reliability are very important in terms of plant economy because the power station’s fixed costs are constant whether the plant is running or not.costs are constant whether the plant is running or not.

A high availability has a positive impact on the cost of electricity.

The major factors affecting plant availability and reliability are:

• Design of the major components

• Engineering of the plant as whole, especially of the interfaces between the systems

• Mode of operation (whether base, intermediate, or peak-load duty)

• Type of fuel• Type of fuel

• Qualifications and skill of the operating and maintenance staff

• Adherence to manufacturer’s operating and maintenance instructions (preventive maintenance)


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C i f O i d M i C

6. Low O&M Cost [1/4]

Type of Plant Output (MW) Fixed (Million US$/ )

Variable(US$/MWh)

Comparison of Operating and Maintenance Cost

yp p ( ) US$/year) (US$/MWh)

Combined Cycle Power Plant 800 6~8 2~3

Combined Cycle Power Plant 60 3~4 3~4y

Gas Turbine Plant 250 2~2.5 3~4

Gas Turbine Plant 60 1~1.5 4~5

Steam Power Plant (coal) 800 12~15 2.5~3.5

Nuclear Power Plant 1250 40~60 2.0

Biomass Power Plant 30 3~4 5~8

Fixed O&M: personnel and insurance costs. Variable O&M: cost depending upon the operation regime of the plant. Included items are:Variable O&M: cost depending upon the operation regime of the plant. Included items are: • Inspection and overhauls, including labor, parts, and rentals• Water treatment expenses• Catalyst replacement• Major overhaul expences


Major overhaul expences• Air filter replacements

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C i f O i d M i C


Source: GE (1991)

Comparison of Operating and Maintenance Cost

Items Simple cycle

Combined cycle Steam coal IGCC

Fuel type NG NG Coal Coal

Fuel cost ($/MBtu) 2.65 2.65 1.5 1.5

Fixed O&M cost ($/kW/year) 0.7 3.7 28.1 38.8

Variable O&M cost ($/MWh) 7.3 3.3 2.7 3.7

Normalized plant cost 1.14 1 4.40 6.07

Some estimate that burning residual or crude oil will increase maintenance costs by a factor of 3, (summing a base of 1 for natural gas, and by a factor of 1.5 for distillate) and that those costs will ( g g , y )be three times higher for the same number of fired hours if the unit is started every fired hour, instead of once every 1000 fired hours.


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O&M costs include operating labor, materials, and tools for plant maintenance on both a routine and emergency basis.

These expenses are neither a function of plant capital cost nor plant generating capacity.p p p p g g p y

They vary from year to year and generally become higher as the plant becomes older.

These costs also vary according to the size of plant type of fuel used loading schedule and operating These costs also vary according to the size of plant, type of fuel used, loading schedule, and operating characteristics (peaking or base load).

In general, O&M costs are approximately equal to one-fourth of the fuel costs.

A good rule of thumb is that the maintenance cost is twice the initial cost during the plant life (normally, 25 years).

The running profile has a profound impact on the O&M cost The running profile has a profound impact on the O&M cost.

Usually, the first maintenance is scheduled for either 24,000 hours or 1,200 starts (whichever occurs first).

Nowadays it is common to have a maintenance agreement at some level for risk mitigation Nowadays, it is common to have a maintenance agreement at some level for risk mitigation.

There are different levels of contractual services ranging from part agreement to full coverage LTSA services.


One can choose to use either the OEM or another third party service provider.

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In many cases, financing organs or insurer requires and LTSA (or better) for risk mitigation to level the insurance cost at a reasonable level.

There are ways of potentially reducing the maintenance cost and one should always lumped methods with equivalent hours.

The word lumped is used in a sense that the two different ageing mechanisms, such as creep, oxidation, regular wear and tear and stresses related to thermal gradients during start and stop, are evaluated as equivalent time by e.g. assuming that a start consumes time rather being a low cycle.

The total number of gas turbine operated in the world is about 47,000 units and the total value of the gas turbine after market was 19.3 billion USD in 2009.

The after market is valuable greatly to the manufacturers since all 47,000 units requires maintenance on a regular basis.

Certain in-house produced parts may be offered with several hundred percent margin. In contrast, the margin of a complete new turn-key power plant is about 10 percent.


The reward for the user, by having a LTSA, is discounted parts and prioritized treatment by the supplier.

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7. Operating Flexibility [1/11]

Mode Baseload Plant (1990s) SCC5-4000F cycling plant (Siemens)

Hot start (8 h) 90 min 45-55 min

Warm start (64 h) 200 min 120 min

C ld t t ( 120 h) 250 i 150 iCold start (>120 h) 250 min 150 min

Operational flexibility is essential in combined cycle power plants for frequency control.

Most OEMs are capable of 30 min hot-start and steep (35-50 MW/minute) ramp-rates.

The steam cooled gas turbine gas a longer start-up time. Thus, is has less flexibility in terms of DSS.


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Gas turbines as well as combined cycle power plants have the unique potential to react quickly and with flexibility to changes in grid, because they have the following characteristics:

• Short startup time• High-loading gradients• Possibilities for frequency support

Operational flexibility becomes a major topic in modern power

k t• Good part load behavior• Additional system for power augmentation

B ilt f b th b l d d k l d ti

markets

Built for both base-load and peak-load operation

High efficiency to maximize generation opportunities

Lower start-up emissions

Lower demineralized water consumption

• Once-through HRSG


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[ Start-up procedure ]


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Hot start (start after an 8-hour shutdown) of a 400 MW CCPP with optimized steam turbine start-up technology (Siemens)


HIPT


5 additional

30 min. to baseload

30 MW/min 5 additional minutes to 150 MW

5 minutes to accelerate

13.5 minutes to accelerate

Improved

accelerate to accelerate

Improvement of SGT6-5000F (W501F) Starting Capability


Improvement of SGT6-5000F (W501F) Starting Capability

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Gas turbines are capable of relatively quick starts.

Heavy duty gas turbines can achieve starting times as low as 10 minutes but usually no higher than 30 minutes from cold start to 100% load.

Aeroderivative gas turbines can achieve 100% load in 3 minutes or less.

If equipped with bypass systems, the startup of the steam cycle portion of the combined cycle can be t d f th t biseparated from the gas turbine.

The gas turbine can be operated at full load while the steam turbine is warming up.

The HRSG can be warmed up nearly as quickly as the gas turbine with excess steam produced being The HRSG can be warmed up nearly as quickly as the gas turbine, with excess steam produced being bypassed to the condenser.

The startup time of the gas turbine and the combined cycle plant is significantly less than the time required for a comparably sized coal-fired power plantfor a comparably sized coal-fired power plant.

Supercritical plants require feedwater purity so that tube side deposition will not cause overheating damage.

Condensate polishing with oxygenated water treatment is required to achieve excellent water purity.p g yg q p y

Even many natural circulation (drum type) units now use oxygenated water treatment.

The deposition has been greatly reduced so that the requirement for frequent chemical cleaning is almost


eliminated.

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For rapid changes in gas temperature, the edges of the bucket or nozzle respond more quickly than the thicker bulk section.

These gradients, in turn, produce thermal stress that, when cycled, can eventually lead cracking.

Turbine start/stop cycle – firing temperature changes Transient temperature distribution (1st stage bucket)


HIPT

B k L C l F i (LCF) T S i Hi


Key Parameters

Bucket Low Cycle Fatigue (LCF) – Temperature Strain History

FSNL

Fired Shutdown

Tens

ile (+

)Key Parameters• Total strain range• Max metal temperature

Tm

FSNL

rain

T

Metal Temperaturem

% S

tr

max Base Load

ress

ive

()

Light Off & Warm-up

Acceleration

Com

pr


HIPT


Currently, short start-up and shutdown times are emphasized by customers because of high fuel price.

Especially, fast start-up is important for intermediate load application.

The important parameters should be considered for fast start-up are as follows:

• HRSG ramp capability• Steam turbine ramp capabilityp p y• Piping warm up times• Steam chemistry• Steam turbine back-pressure limitations


HIPT

HRSG


HRSG

There has also been a debate over the years whether the once-through HRSG technology should be better off than drum boilers in terms of cyclingthan drum boilers in terms of cycling.

• Detailed transient analysis showed that the majority of fatigue life consumption occurs at the hottest high pressure superheater and reheater during fast gas turbine loading

GE

the hottest high pressure superheater and reheater during fast gas turbine loading, regardless of whether the HRSG uses high pressure drum or once through technology.

• The HRSG stack is equipped with an automatic damper that closes upon plant shutdown to reduce HRSG heat loss and the time required for next plant start-up as well as reduce thereduce HRSG heat loss and the time required for next plant start up, as well as reduce the cyclic stress of the start.

• Once through HRSG eliminates the thick wall HP drum and allows an unrestricted gas

Siemens

• Once-through HRSG eliminates the thick wall HP drum and allows an unrestricted gas turbine start-up.a. gas turbine start-up produces rapid boiling in the evaporatorb. if water level in the drum rises to the separators, water carry over into the superheaterp , y p

may occurc. the typical response to this is to either trip or slow gas turbine load ramp


It is hard to conclude that which one is better in terms of operating flexibility.

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8. Lower Emissions [1/6]

Pollutants characteristics

Smoke • Smoke is usually formed in small fuel rich regions especially during start-up.

Unburned hydrocarbons • The unburned hydrocarbons and CO are formed incomplete combustion and CO typically at idling conditions.

• CO2 production is a direct function of the CHx fuels burned it produces 3.14 times the fuel burned

CO2

times the fuel burned.

• The only way to reduce the production of CO2 is to use less fuel for the power produced.

• NOx have been major pollutant in modern gas turbines.

• New units under development have goals which would reduce NOx levels below 9 ppmNOx below 9 ppm.

• SCRs have also been used in conjunction with DLN combustors.

• New research of catalytic combustors will give 2 ppm in the future.


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E i i [N 2 Oil]


Emission [No. 2 Oil]

4000 300

High SmokeEmissions

High CO Emissions

3000F e, p

pmv

and

3000

me

Tem

p.,

200

NO

x R

ate

cond

ition

Opt

imum

B

2000Fla

100

chio

met

ric

O

1000

Sto

i


0.5 1.51.0Equivalence Ratio

Fuel richFuel lean

HIPT

W /S I j i


Most gas turbines control NOx emission with diluent injection into the combustor until 1990.

The injected diluent used as a heat sink that lowers the combustion zone temperature which is the primary

Water/Steam Injection

The injected diluent used as a heat sink that lowers the combustion zone temperature, which is the primary parameter affecting NOx formation.

As the combustion zone temperature decreases, NOx production decreases exponentially.

In order to increase thermal efficiency, gas turbines having higher firing temperature has being developed by manufacturers.

H hi h fi i t t hi h b ti t t hi h d NO However, higher firing temperature mean higher combustion temperatures, which produce more NOx, resulting in more diluent injection to achieve the same emission levels of NOx.

The increased diluent injection lowers the thermal efficiency because some of the energy of combustion i d t h t th t tgases is used to heat the water or steam.

Furthermore, as injection increases, dynamic pressure oscillation activity (i.e., noise) in the combustor also increases, resulting in increased wear of internal parts.

Carbon monoxide, representing the measure of the inefficiency of the combustion process, also increases as the diluent injection increases.


The lowest practical NOx levels achieved with diluent injection are generally 25 ppm and 42 ppm when firing natural gas and distillate oil, respectively.

HIPT

L NO E i i


CCPP includes gas turbines with DLN combustors that can operate with stack gas NOx emission concentration as low as 9 ppmvd at 15% oxygen without steam or water injection, when the natural gas is

f

Lower NOx Emissions

used as a fuel.

Water or steam injection may be required to meet NOx emission requirements, when distillate is used as a fuel.

Water or steam injection can be used in the gas turbines with diffusion flame combustors to meet NOxemission limits.

NOx can be reduced to less than 9 ppmvd by the installation of SCR in the HRSG.

Lower CO Emissions

Carbon monoxide (CO) emissions are low at gas turbine loads above 50%, typically less than 5~25 ppmvd(9~43 g/GJ).

Low CO emissions are the result of highly-efficient combustion.

Catalytic CO emission abatement systems are also available, if required.


The CO catalyst is installed in the exhaust gas path, typically upstream of the HRSG superheater.

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L CO E i i


The role of gas turbine has changed from either a special application or stand-by mode to combined cycle plants in either intermediate or base load.

Lower CO2 Emissions

The high efficiency combined with natural gas high hydrogen content result in relatively low levels of specific CO2 emission.

Unfortunately, however, the relative lower CO2 content in the flue gas makes the separation process more difficult, and may render in high separation tower heights to provide for sufficient residence time.

Another issue is the flue gas flow which is on the order of 1.5 kg/MW, compared to 0.95 kg/MW for than advanced steam plants.

The cross section of the separation tower should provide for a velocity around 5 m/s Therefore a combined The cross section of the separation tower should provide for a velocity around 5 m/s. Therefore, a combined cycle plant requires a higher and wider tower for CO2 capture plant compared to a coal fired plant.

No commercial full-scale technology for CO2 capture exists today and the road-maps towards feasible solution are still not clear.

It has been expected that the efficiency of combined cycle power plant with CO2 capture plant will drop 8 percent for a GE 9FB.03 with a 3-pressure HRSG. This is because a lot of LP steam is required for solvent


percent for a GE 9FB.03 with a 3 pressure HRSG. This is because a lot of LP steam is required for solvent regeneration.

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CO E i i f Diff P Pl


Lignite: 980~1,230

CO2 Emissions from Different Power Plants

Hard coal: 790~1,080

Oil: 890

NG: 640

NG Comb. cycle 410~430

Unit: g CO2/kWh

Solar 80~160

Nuclear: 16~23

Wind: 8~16

Hydro power: 4~13

Electricity generation with CCS

The CO2 emissions of the plant are having a more direct impact on the economics of a plant due to the effort to globally limitation.

The combined cycle plant emits about 40% of the CO of a coal fired plant This is driven by the higher


The combined cycle plant emits about 40% of the CO2 of a coal-fired plant. This is driven by the higher efficiency and the higher hydrogen content in natural gas.

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9. Options for Power Enhancements

O ti f P E h tTypical Performance Impact

Output = m h•

Options for Power Enhancements Output Heat Rate

Base configuration Base Base

Evaporative cooling GT inlet air (85% effective cooler) +5.2 % -

Chill GT inlet air to 45F +10.7 % +1.6 %

GT k l d i 2 % 1 0 %GT peak load operation +5.2 % 1.0 %

GT steam injection (5% of GT airflow) +3.4 % +4.2 %

GT water injection (2 9% of GT airflow) +5 9 % +4 8 %GT water injection (2.9% of GT airflow) +5.9 % +4.8 %

HRSG supplementary firing +28 % +9 %

Note: 1. Site conditions = 90F, 30% RH(Relative Humidity)2. Fuel = NG3. 3-pressure, reheat steam cycle


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C i i h C l Fi d P Pl

10. Compactness [1/8]

BoilerFeedwater

Steam Turbine

Comparison with Coal-Fired Power Plants

FeedwaterPump

Turbine

10 Meters


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A f Si l Sh f [GE]


Arrangement of Single-Shaft [GE]

[ Single-Shaft CCPP (107FA) ]


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A f M l i Sh f [207FA GE]


Arrangement of Multi-Shaft [207FA – GE]


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Single Shaft (1-on-1 configuration) Multiple Shaft (2-on-1 configuration)

ComponentsLess generator required One large ST instead of 2 smaller STs

ComponentsOne compact lube oil system Less auxiliaries (pumps etc) required

Civil Smaller plant area Higher flexibility in plant layout

L i l f l bCosts

Lower capital cost of plant because one generator and one step-up transformer is eliminated

St t bi h hi h ffi i bPerformance Same level in larger plants Steam turbine has higher efficiency because of larger steam volume flow

Operating Fl ibilit

Suitable for daily start and stop (DSS) ti Suitable for base load operationFlexibility operation p

Availability Higher (less complexity)

Operation limit

Operation is limited to concurrent operation of the gas turbine and steam turbine, unless the steam turbine can be decoupled from the generator through a clutch

The gas turbine can be decoupled from the operation of the steam turbine, allowing for steam turbine shutdown with continued gas turbine operation


generator through a clutch turbine operation

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A f Si l Sh f [Si ]


Arrangement of Single-Shaft [Siemens]


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Si l Sh f


Single-shaft with generator between gas turbine and steam turbine enables installation of a clutch between steam turbine and generator.

Single-Shaft

One problem of a Jaw clutch, which was used previously, is that it can only be engaged when the gas turbine is at rest. This means that in the event of a failed gas turbine start, the operator must wait until the gas turbine is stationary before engaging the jaw clutch to re-start.

Currently, SSS(Synchronous Self-Shifting) clutch has been employed popularly. The SSS clutch engages in that moment when the steam turbine speed tries to overrun the rigidly coupled gas turbine generator and disengages if the torque transmitted from the steam turbine to the generator becomes zero.

The clutch allows startup and operation of gas turbine without driving the steam turbine.

This results in a lower starting power and eliminates certain safety measures for the steam turbine, such as g ycooling steam or sealing steam.

The clutch also provides design opportunities for accommodating axial thermal expansion.

However, the clutch is an additional component with a potential impact on availability. Additionally, the generator located at the end of the line of shafting has advantages during generator overhaul.

Single-shaft units without a clutch definitely need auxiliary steam supply to cool the steam turbine during


Single shaft units without a clutch definitely need auxiliary steam supply to cool the steam turbine during startup. This is not necessary in units with a clutch.

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A f Si l Sh f [GE 6FA]


Arrangement of Single-Shaft [GE, 6FA]

A b i i li ti hA gearbox is necessary in applications where the manufacturer offers the package for both 60 and 50 cycle applications. The gearbox will use roughly 2 percent of the power produced b th t biby the turbine.


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T i l Pl A [GE S207EA]


Typical Plant Arrangement [GE, S207EA]


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C i [1/2]

Wide Use of Gas Turbine

Cogeneration means the simultaneous production of electricity and thermal energy in the same plants.

Cogeneration [1/2]

The thermal energy is usually steam or hot water.

The types of cogeneration plants:

① Industrial power stations supplying heat to an industrial process

② District heating power plants

③ Power plants coupled to seawater desalination plants

The supplementary firing in the HRSG gives greater design and operating flexibility, but the cycle efficiency is normally lower if supplementary firing is used.y pp y g

Thermal energy in the form of steam can be extracted from HRSG, or from an extraction in the steam turbine.

The power coefficient (also called the alpha-value) is defined as the ratio between the electrical and the thermal output.

Fuel utilization is a measure of how much of the fuel supplied is usefully used in the plant It is equal to the


Fuel utilization is a measure of how much of the fuel supplied is usefully used in the plant. It is equal to the sum of electrical output and thermal output divided by the fuel input.

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C i [2/2]

Wide Use of Gas TurbineCogeneration [2/2]

Single PressureSupplementary FiringB k T bi

Heat Balance

Backpressure Turbine


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S D li i Pl

Wide Use of Gas TurbineSeawater Desalination Plant


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P ll l P i

Wide Use of Gas TurbineParallel Powering


Parallel powering: Gas turbine exhausts are used in the existing steam cycle.

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IGCC

Wide Use of Gas TurbineIGCC


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Load Control & Frequency Response

Combined cycle plants are very well suited to rapid load changes because gas turbine react extremely quickly to frequency variations.

As soon as fuel valve opens more added power becomes available on the shaft and gas turbine load jumps As soon as fuel valve opens, more added power becomes available on the shaft and gas turbine load jumps of up to 35% are possible, but this is detrimental to the life expectancy of the turbine blades.

To perform a plant load jump while the frequency is falling, it is essential that gas turbine is operating below the maximum output levelthe maximum output level.

For frequency support gas turbines are typically operated between 50 and 95% load.

The electrical output of the combined cycle power plants is controlled by means of gas turbine only This is The electrical output of the combined cycle power plants is controlled by means of gas turbine only. This is because the gas turbine generates two-thirds of the total power output, a solution without control for the steam turbine power output is generally preferred.

The gas turbine output is controlled by a combination of VIGV and TIT control The gas turbine output is controlled by a combination of VIGV and TIT control.

The TIT is controlled by a combination of the fuel flow into the combustor and VIGV setting.

VIGV ll hi h t bi h t t t d t i t l 40% GT l d B l thi l l VIGVs allows a high gas turbine exhaust temperature down to approximately 40% GT load. Below this level, TIT is further reduced because the airflow cannot be further reduced.

The steam turbine will always follow the gas turbine by generating power with whatever steam is available.


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질의 및 응답질의 및 응답

작성자: 이 병 은 (공학박사)작성일: 2014 03 03 (Ver 3)


작성일: 2014. 03. 03 (Ver.3)연락처: ebyeong @ naver.com

Mobile: 010-3122-2262저서: 실무 발전설비 열역학/증기터빈 열유체기술

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