Upload
duongkien
View
218
Download
2
Embed Size (px)
Citation preview
CCT- an Overview
Presentation titlePage 2
Presentation titlePage 3
Market for New Coal Power Plant Technology
Presentation titlePage 4
The Bigger market
Presentation titlePage 5
Regional power capacity and electricity demand in the BLUE Mapscenario for India, 2050
Presentation titlePage 6
Presentation titlePage 7
Types of Clan Coal Technology In practice
Coal is India’s dominant fuel. The country is in urgent need for CCT todevelop its economy in an environmental benign way. After some years ofstudy and exploration, India has developed its own categories of CCT, whichinclude the following technologies:
· Coal preparation technology;· Coal water mixture technology;· Coal briquetting technology;· Coal gasification technology;· Coal liquefaction technology;· Fuel cell technology;· Pressurized fluidized bed combustion (PFBC);· Atmospheric circulating fluidized bed combustion (ACFBC);· Integrated gasification combined cycles (IGCC);· Coal bed methane (CBM) exploitation and utilization;· Flue gas desulfurization (FGD);· Utilization of fly ash and coal refuse;· Pollution control measures for industrial boilers and kilns.
Presentation titlePage 8
Status of Clean Coal Technology
Presentation titlePage 9
Market for New Coal Power Plant Technology
Hybrid and Advanced Systems
Hybrid combined cycles are also under development. They combine the best features of both
gasification and combustion technologies, using coal in a two-stage process. The first stage gasifies
the majority of the coal and runs a gas turbine, the second stage combusts the residual ‘char’ to
produce steam. Efficiencies greater than 50% are possible (World Coal Institute, 2002: 26).
Presentation titlePage 10
Technology of Future
Presentation titlePage 11
Technology of Future- kalina Cycle
In low gas temperature heat recovery systems such as dieselengine exhaust or fired heater exhaust,the energy recovered fromthe hot gas stream is more significant and Kalina cycle outputincreases by 20-30 %.The main reason for the improvement isthat the boiling of ammonia-water mixture occurs over arange of temperatures,unlike steam and hence the amount ofenergy recovered from the gas stream is much higher. SeeFigure below,where a 550 F gas temperature source is shownwith say a cold end fluid temperature of 100 F. 70 % ammonia-water mixture at 500 psia by virtue of its varying boiling point,isable to "match" or run parallel to the gas temperature line whilerecovering energy and hence the exit gas temperature can be aslow as 200 F.The steam-water mixture at 500 psia,on the otherhand,due to pinch,approach point limitations and a constantboiling point of 467 F,cannot cool the gases below about 500F.Only about 15-20 % of the energy is recovered,compared to100% in Kalina
Presentation titlePage 12
Gasification and Micro turbines- DPS
C:\Documents and Settings\shuvendu.bose\My Documents\energy\CCT\Product_Catalog_ENGLISH_LR[1].pdf
Presentation titlePage 13
Some Weird thoughts
► How good are we in Utilization?► Are we costing our losses to optimize?► Are we responsible and penalized for losses/rewarded for
gains?
Presentation titlePage 14
Is India really looking for CCT? – A critical Question
Presentation titlePage 15
► Part -2
Presentation titlePage 16
Pulverized Coal Technology
Conditions Net Energy Efficiency
Heatrate HHV
Subcritical 2,400 psig 35% 9,751 Btu/kWh
Supercritical 3,500 psig 37% 9,300 Btu/kWh
Advanced Supercritical
->4,710 psig 42% 8,126 Btu/kWh
Ultra-Supercritical
5,500 psig 44% 7,757 Btu/kWh
Source: Supercritical Plant Overview
Presentation titlePage 17
Subcritical vs. Supercritical
Subcritical SupercriticalHeatrate Efficiency 34-37% HHV 36-44% HHVBoiler Capital Cost Base 0-9% Higher
Plant Capital Cost Base 1-6% Higher
Non-Fuel O&M Base 0-2% Higher
Fuel Cost Base LowerControlled Emissions Base Lower- Higher
Efficiency
US Operating Units 1,338 Units 117 Units
Source: Supercritical Plant Overview
Presentation titlePage 18
EFFICIENCY IMPROVEMENT FORECAST
CONVENTIONAL Vs IGCC ( Courtesy BHEL)
60
55
50
45
40
35
301990 1995 2000 2005 2010
Year of commercial use
Net
The
rmal
Effi
cien
cy (%
)
Ceramic gasturbine
566 Co 600 Co 623 Co1300 Co 1500 Co
540 Co650 Co1184 Co
IGCC (15 C Amb)IGCC (Indian Condition)
Super Critical PC Power Plant (15 C Amb.)o
Super Critical PC Power Plant (Indian Condition)o
Sub Critical PC Power Plant (Indian Condition)
Presentation titlePage 19
Features of IGCC Technology
Efficiency:
TechnologyGross
Efficiency,LHV%
Net Efficiency,
LHV%
IGCC
(according to gasification process)
ELCOGAS-Entrained flow, dry-fed 47,1% 42,2%
SHELL (dry feeding) 48,3% 43,1%
TEXACO (no integrated) 51,6% 41,2%
E-GAS TM 44,5% 39,2%
PC, pulverised coal (with FGD, ESP and low NOx burners)
Subcritical (165 bar, 5400C) 37,5% 36,0%
Supercritical (240 bar, 5650C) 41,1% 39,6%
AFBC 37,5% 36,0%
NGCC, gas turbine F technology 57,3% 56,0%
Presentation titlePage 20
Features of IGCC TechnologyEnvironment:
Technology Emissions g/kWh By-products / solid waste
g/kWh(*)SO2 NOX Particles
CO2
IGCC
(according to gasification process / gas turbine)
ELCOGAS/ SIEMENS V94.3
0.07 0.40 0.02 727
Slag: 210 Fly ash: 2.0
Sulphur: 4.0
SHELL / SIEMENS V94.2 0.10 0.05 0.02 712
TEXACO / GE 7F 0.13 0.35 0.02 745
E-GAS TM / GE 7F A 0.14 0.37 0.02 783
PC Subcritical ηnet=36.0%
FGD (90%), LNB (50%),
2.50 2.30 0.30 852 Fly ash: 25.0 Gypsum
(FGD): 19.6
Supercritical ηnet=39.6% FGD (95%), SCR (95%), ESP (99.2%)
2.15 1.10 0.27 774 Fly ash: 25.0 Gypsum
(FGD) : 18.8
AFBC 1.40 0.80 0.10 852 Fly ash –gypsum-
limestone: 52.9
NGCC, ηnet=56.0% 0.007 0.54 0.02 350
Presentation titlePage 21
Features of IGCC TechnologyEnvironment:
1. SOx , NOx and Particles:
SOx , NOx and particulate emissions are comparable to or less
than those obtained in a combined cycle using Natural Gas
(NGCC).
2. Greenhouse effect gas CO2 :
CO2 emission is reduced by 20% in IGCC over conventional
boiler base power plant.
CO in syngas can be converted to CO2 and production of Hydrogen can
be increased. Thus CO2 can be captured directly using regular
commercial process at a higher pressure than extracting it from combustion gases
from conventional PC plant or NGCC plant.
3. Water consumption:
Specific consumption of water for the operation of IGCC plant is approx. half that of
conventional plant using gas cleaning system.
Presentation titlePage 22
Features of IGCC TechnologyEnvironment:
4. Other contaminants : Chlorine , Mercury, Heavy metals:
In IGCC operation,
Chlorine compounds are extracted from Gas by washing with water.
Heavy metals are almost entirely captured in the slag which is a vitrified, non
leachable, inert solid.
Mercury can be removed by absorption on a bed of active carbon for IGCC at a cost
of 1/12 that of PC power plant.
5. Solid by products:Sulphur is recovered in a pure elemental state or as sulphuric acid.
Solid waste (slag) can be disposed as by products for manufacturing of ceramic
material, fiber glass, filling roads, manufacturing of cements, roof tiles or bricks.
Presentation titlePage 23
Features of IGCC TechnologyFuel-multiple choice:
IGCC / POX :
1. Fossil Fuel:-
Natural gas
Petroleum coal
2. Alternative fuels:-
Petroleum coke
Biomass and waste products
The security of supply of fuel, stability in prices of fuel and multiplicity in choice of fuel, IGCC
Technology has clear cut edge over other technology / process for power generation.
Presentation titlePage 24
Features of IGCC Technology
Global Situation:Owner/ Location Commissioning Net output. MW
Other productsFuel Combined
cycleGasification
Cool Water, USA 1984 120 MW Coal GE 107E Texaco
Nuon, Buggenum, Holland
1994 253 MW Coal/ Wastes and biomass
Siemens V94.2
Shell
Wabash River, Indiana, USA
1995 262 MW Coal/ pet-coke
GE 7F E-GasTM
Tempa Electric, Florida, USA
1996 250 MW Coal/ pet-coke
GE 7F Texaco
ELCOGAS, Puertollano, Spain
1997 282.7 MW Coal/ pet-coke
Siemens V94.3
Entrained flow
SUV, Versova Chec Republic
1996 350 MW, vapor Lignite 2 x GE 9E Moving bed, Lurgi
SVZ, Schwarze Pumpe, Germany
1996 40 MW, steam, methanol
Lignite/Wastes
GE 6B Noell
Sulcis, Sardinia, Italy 2006 450 MW Coal SHELL
Texaco El Dorado, Kansas, USA
1996 40 MW, steam Petcoke GE 6B Texaco
Presentation titlePage 25
Features of IGCC Technology
Global Situation:
Owner/ Location Commissioning Net output. MW Other products
Fuel Combined cycle
Gasification
Motiva, Delaware, USA
1996 240 MW, steam Petcoke 2 x GE 6FA Texaco
Shell Pernis, Rotterdam, Holland
1997 127 MW, H2, steam
Visbreaker reesidues
3 x GE 7FA Texaco
ISAB, Priolo, Italia 1999 510 MW Asphalts Siemens 2 x V94.2 K
Texaco
API, Falconara, Italy 2000 260 MW Visbreaker ABB 13E2 Texaco
SARLUX, Sardinia, Italy
2000 550 MW, H2m steam
Visbreaker residues
3 x GE 9E Texaco
Presentation titlePage 26
IGCC Heatrate Penalty vs. Fuel Type
0 0
6
14
22
0
5
10
15
20
25
Petco
ke
Easter
n Bit
Illinoi
s Bas
in
Subbi
tum
inous
Lign
ite
Coal Type
% Heatrate Penalty
Presentation titlePage 27
Features of IGCC Technology
Investment Cost:
500
1997
1,500
0
1000
2000 2010 2015
$/kw
Forecast development evolution IGCC power plants costs ($/kw)
Presentation titlePage 28
Features of IGCC TechnologyCost Comparison among IGCC, PC and NGCC Power plant:
IGCC PC sub critical
NGCC base
NGCC peak 1 NGCC peak 2
Output MW 590 500 506 506 506
Met efficiency, HHV % (LHV%)
41.0 (42.2) 35.0(36.0) 50.5(56.0) 48.7(54.0) 47.3(52.4)
Fuel cost €/kWh 1.31(0.55) 1.31(0.55) 3.56(1.50) 3.56(1.50) 3.56(1.50)
Investment cost €/kWh 1300 1186 496 496 496
Investment cts. €/kWh 2.63 2.40 0.96 1.17 1.91
O&M cts. €/kWh 0,71 0,68 0,32 0,33 0,39
Fuel cts. €/kWh 1.14 1.33 2.57 2.67 2.74
Electricity cost cts. €/kWh 4.48 4.41 3.85 4.17 5.04
Presentation titlePage 29
Features of IGCC TechnologyCost Comparison among IGCC, PC and NGCC Power plant:
1.14 1.33
2.57 2.67 2.740.71 0.68
0.32 0.33 0.392.63 2.4 0.96 1.171.91
0
1
2
3
4
5
6
IGCC PC subcritical
NGCCbase
NGCCpeak 1
NGCCpeak 2
€/kW
h Investment cts. €/kWhO&M cts. €/kWhFuel cts. €/kWh
Coal price = 1.38 €/MMBtu
Gas price = 3.74 €/MMBtu