WP2: REVIEW OF THE IGCC CCS PLANT DESIGN AND PROCESS...
Transcript of WP2: REVIEW OF THE IGCC CCS PLANT DESIGN AND PROCESS...
WP2: REVIEW OF THE IGCC–CCS
PLANT DESIGN AND PROCESS
OPERATIONS
Vaclav Novotny, FME CTU in Prague
Norway Grants CZ08 Workshop
5. 11. 2015 Prague
PLANT PROCESS OPERATIONS
Oxygen
Production
Fuel Preparation
Gasification Fly Ash
Removal
Water Gas
Shift Desulphurisation
CO2 Separation
Combined Cycle Power Plant
H2-O2 Cycle
Absorption
Technology
Cryogenic
Separation
CO2 Transport
H2
CO2
Membrane
Separation (addit.
activity)
Fuel Cell Hybrid Plant
FUEL
Parameter Unit Fuel – raw Fuel – input to
the gasification
Qir MJ/kg 16,50 21,99
Qsr MJ/kg 18,07 23,31
Wtr % hm. 31,00 11,00
Ad % hm. 13,00 13,00
Ar % hm. 8,97 11,57
Volatile matter
Cdaf % hm. 70,4 70,4
Hdaf % hm. 6,1 6,1
Ndaf % hm. 1,0 1,0
Odaf % hm. 20,89 20,89
Sdaf % hm. 1,61 1,61
Parameter Name Unit Value
DT Deformation point °C 1 325
ST Softening point °C 1 425
HT Hemisphere temperature °C 1 525
FT Flow temperature °C 1 550
FUEL PREPARATION
• Fuel preparation systems
with direct dosing (typical for standard power plants)
with a prepared fuel container
• Chosen technology: WTA drying system • Drying medium: LP-steam
• Fluidized-bed drying
• 2 milling stages
• before drying
• before final use
• Advantages • Low energy consumption
• Separate system - flexible
Source: RWE, The WTA technology, An advanced method of
processing and drying lignite, 2008
OXYGEN PRODUCTION
• Available technologies
Cryogenic separation – verified method, only one possibility for a large
performance
Adsorption separation – for a small performance
Membrane separation – pilot plants, potential for the future
• Chosen technology:
Cryogenic separation • Separation in
rectification column
• O2 purity 95%
(3% Ar, 2% N2)
• High power input for
compressor stage
Source: R. J. Allam, Improved oxygen production technologies, Energia Procedia, 2009.
• Proven technology for conversion of solid feedstock (coal) to gaseous
(syngas) for further processing
• Technologies
Fluidized bed, fixed bed, entrained flow
• Choice of entrained flow
Dry fed
Slurry fed
• Options for Quench and particulate removal
• We selected entrained flow technologies, why?
Low concentration of methane
High conversion of carbon
Better possible acceptance of changed fuel parameters
Company Shell and Texaco
More details and realization have technologies from Shell company
GASIFICATION
• Basic scheme
GASIFICATION
GAS PROCESSING
- ASH REMOVAL
• Gas needs to be cooled down with respect to filter limitations, ash solidification
• Nearly impossible to determine ratio of slag : fly ash
• Available several options:
Ceramic filter • Higer temperatures (400°C), high cost
Metal filter • Maximum temperature (900°C), very high cost
Bag filters + cyclone • Proven economical solution, required at most around 250°C
Chosen cyclone followed by bag filters • Gas needs to be rather cold for WGS
• Simple and proven
• Filters cleaned by shock by clean syngas
Conversion CO+H2O -> CO2 + H2 on catalytic bed
• Proven technology from rafining industry
• Requires steam if water content in gas low
• Typically catalyst intollerant to sour gas
• Sour shift – novel catalyst type can be placed before
desulphurisation, higher cost, but energy and complexity advantage
• Temperature dependence of reaction
• High temperature – faster kinetics of reaction
• Low temperature – higher conversion to CO2 and H2
2 stage conversion
GAS PROCESSING
- WATER GAS SHIFT
DESULPHURISATION
- H2S ABSORPTION
• S in form of H2S (very small amount as COS)
• From range of separation methods for pre-combustion considered
physical absorption (Rectisol, Selexol, Purisol, Fluor Solvent),
chemical (MDEA), eventually hybrid (MDEA+sulfolane), most often
considered Rectisol and Selexol
• Literature often prefers Selexol for slightly lower power
consumption (with relatively little system optimization). Thanks to
direct experience with Vřesová IGCC plant chosen Rectisol
• Principle based on absorption column and desorption by flash
drums and distillation columns
CO2 SEPARATION
- ABSORPTION
• High CO2 content – preferred physical absorption
• In basic principle same process as desulphurisation (simlilar range of
suitable processes)
Best to use same same solvent as for H2S determines use of Rectisol
Lower solubility of CO2 - its capture is placed downstream
• In optimization can be connected with desulhurisation as single
interconnected process (with CO2 separation possible as PSA only)
RECTISOL PROCESS
- H2S and CO2 separation
• MeOH at below zero temperatures
• Necessary MeOH – H2O regeneration, scrubbing of MeOH in produced gases
• With H2S scrubbed also part of CO2 – potential issue for captured amount
Simplified Rectisol scheme from Vřesová plant for only H2S scrubbing
Typical Lurgi and Line scheme of Rectisol process for both H2S and CO2 capture (Gatti, Manuele, et al. 2014)
CO2 SEPARATION
- CRYOGENIC METHOD
• Technology options
• Liquid-gas separation
• Distillation
• Simple separation
• Solid-gas separation
• Chosen technology: Simple Liquid-gas separation
Compression of syngas (if needed)
Cooling of syngas to around -55°C
Phase separation in two stages (High pressure low pressure)
Advantages: Simple process, well-known components, efficient
• Work on-goin for identifying
• Cost-optimal CO2 capture-%
• Energy-optimal CO2 capture-%
More in separate presentation by
David Shifted
syngas
Regenerative
adsorption
dehydration
Compression
Hydrogen fuel
CO2/H2 recycle
CO2 to
transport
LT CO2 pumpHT CO2 pump
R290
utility
R170
utility
Hydrogen expanders
HX1
HX2a
HX2b
M
G
HX3HX4
HX5
M
35 bar30°C
115.5 bar
25 bar
150 bar 90 bar
54 bar
26 bar
CO2 SEPARATION
- MEMBRANES
Membranes are perspective mean of gas separation for future
More in separate presentation from Rahul
POWER ISLAND
- COMBINED CYCLE PLANT
• Basic “market ready“ case
• Turbines selection, off the shelf turbine, choice of SGT-2000E (172 MWe)
• Fuel requirement analysis
Hydrogen fuel requires dilution (N2 / H2O)
Fuel temperature
Limitations of imputities and contaminants (H2S, ash & particulates, others)
• Base case with dual pressure steam cycle
• De-NOx probably required as a result of H2 combustion
• Possibilities for optimization
Triple pressure steam cycle
Process heat recovery (steam
cycle / separate units)
Different quenching and heat
recovery
Simplified scheme of considered combined cycle
POWER ISLAND
- POLYGENERATION
- FUEL CELL HYBRID PLANT
FUEL CELLS HYBRID SYSTEMS
• Theoretically high potential and efficiency for FC
• Many theoretical configurations of hybrid cycles
• Fuel quality limitations
• Scale up issues (largest MCFC unit 2 MWe, SOFC 100s kWe)
Polygeneration out of the main scope of the study, FC considered as
inapplicable for near term deployment
POLYGENERATION
• Hydrogen can operate as a feedstock for chemical production
• Theoretically methanol production for peak-load power island operation with
constant gasification island operation, scaling up issue
Gas specie PEMFC AFC PAFC MCFC SOFC
H2 Fuel Fuel Fuel Fuel Fuel
CO Poison (> 10 ppm) Poison Poison (>0.5%) Fuel Fuel
CH4 Diluent Diluent Diluent Fuel (IR) Fuel (IR)
CO2 Diluent Poison Diluent Required Diluent
S (H2S and COS) Poison Unknown Poison (>50 ppm) Poison (<0.5 ppm) Poison (>1 ppm)
POWER ISLAND
- H2 – O2 CYCLE
• Combustion of H2 with O2 yields water
• Theoretically explored option for novel concept of power Island
• Potential for very high efficiency, condensig gas turbine
• Alreday explored in few modifications, proposed new one
O2 obtained from already
present ASU (only higher
capacity)
Fits CCS-IGCC with
relatively high NCG content
in flue gas (1 bar venting)
Minimization of
nontraditional high
pressure vessels from
other concepts
Purity of water in system
might limit cycle
parameters Suggested basic scheme of novel H2-O2 cycle
RESULTING PLANT DIAGRAM
CONCLUSION OF WP2
• Reviewed potential technologies for pre-cobustion IGCC CCS plant
• Analysed potetially feasible cases
• Selected appropriate technologies for further system modelling
– Of the shelf, market ready option
– Theoretical options for near term development research
• WP2 report in progress