syngas production from petroleum coke gasification
DESCRIPTION
Team Hotel: Russel Cabral, Tomi Damo , Ryan Kosak, Vijeta Patel, Lipi Vahanwala Advisors: Bill Keesom – Jacobs Consultancy Jeffery Perl, PhD – UIC Dept. Of Chemical Engineering March 8, 2011. Syngas Production from Petroleum Coke Gasification. Project Purpose. What we are doing - PowerPoint PPT PresentationTRANSCRIPT
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Syngas Production from Petroleum Coke Gasification
Team Hotel:Russel Cabral, Tomi Damo, Ryan Kosak, Vijeta Patel, Lipi Vahanwala
Advisors:Bill Keesom – Jacobs Consultancy Jeffery Perl, PhD – UIC Dept. Of Chemical Engineering
March 8, 2011 13/8/2011
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Project Purpose
What we are doing Producing syngas from petcoke Using entrained flow gasifier Implementing a rigorous syngas
cleaning Why we are doing this
Making syngas for acetic acid production
Chemical production team specs▪ CO to H2 molar ratio of 0.409▪ CO2 and N2 mixed in
2
http://coalgasificationnews.com/tag/petcoke-gasification/
3/8/2011
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Review from Presentation 2
Discussed the Shell™ membrane gasifier
Discussed our syngas cleaning processes Sulfur Removal Claus Process Water Gas Shift
Flow Sheets Early Material and Energy Balances
33/8/2011
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Questions Brought Up Last Time
What was the heat rate brought up in the gasifier comparisons?
Why use N2 as a transport gas and not CO2?
How are we absorbing CO2? What is a better definition of the
quench?
43/8/2011
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5
Agenda
Recent changes Using Selexol instead of MDEA Using the Superclaus
Aspen Simulation Heat Load Identification Economics
Aspen Price Evaluator (ICARUS) Equipment Sizing Energy Balance Location Update
3/8/2011
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Flow Sheeting
3/8/2011
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Flow Sheeting
3/8/2011
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Flow Sheeting
3/8/2011
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Flow Sheeting
3/8/2011
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Flow Sheeting
3/8/2011
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Flow Sheeting
3/8/2011
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Heat Load Identification
Sulfur Cleanup Table showing stripper, flash , cooler &
heat load Claus Process
Table showing furnace, flash, cat. reactor, cooler & heat load
Gasifier Section Table showing gasifier and syngas
cooling
3/8/2011
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Heat Sink Optimization
Stream Pre-heating Lower Heater / Cooler Duties Higher Duty vs. Heat Ex. Cost
Furnace Cooler
HX
Acid Gas Cold
Acid Gas Hot
To Claus Catalyst
s Hot Furnace
Gas
Cold Furnace
Gas
3/8/2011
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Heat Loads
Gasifier Equipment Heat Load (MMBtu/hr)
Gasifier -34.7
HP Steam Heat Exchanger 139.0
MP Steam Heat Exchanger 281
Cooler -106.8
Flash 2.99
Sulfur Clean Up Equipment Heat Load (MMBtu/hr)
Sulfur Stripper Reboiler 57.o
Sulfur Stripper Cooler -200.0
Selexol Cooler -40.7
Rich / Lean Heat Exchanger 274.9 3/8/2011
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Heat Loads (Heat Duties)
Claus Process Equipment Heat Load (MMBtu/hr)
Claus Furnace -3.26
Condenser (Modeled Cooler and Flash) 1
-31.3
Condenser 2 -11.2
Condenser 3 -5.97
Condenser 4 -3.92
Re-heater 1 9.72
Re-heater 2 5.29
Re-heater 3 3.46
Catalytic Reactor 1 3.03
Catalytic Reactor 2 1.72
Catalytic Reactor 3 -5.73 3/8/2011
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Energy Balance
Energy Balance
3/8/2011
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Gasification Process
Solid Removal
Claus Process
CO2 Absorption
Water-gas Shift
Final syngasproduct
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Gasification
SIZE INDIRECT COST
DIRECT COST
Air SeparationUnit
N/A N/A $100,000,000
Petroleum Coke Crusher $ 5,401,890.00
$ 7,022,455.00
Gasifier N/AN/A
$66,000,000
Heat Exchanger $305,741.91
$ 642,058.00
Total
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Gasification Process
Solid Removal
Claus Process
CO2 Absorption
Water-gas Shift
Final syngasproduct
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Solids Removal
SIZE EQUIP COST TOTAL COST
Candle Filter $ 364,770.77 $ 510,679.07
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Gasification Process
Solid Removal
Claus Process
Water-Gas Shift
CO2 Absorption
Final syngasproduct
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Claus Process (Sulfur Removal)
SIZE EQUIP COST TOTAL COST
Reactor $ 103,115.04
$ 164,984.06
Absorber 1 10737 cub. ft $ 1,500,000.00
Absorber 2 10737 cub. ft $ 1,500,000.00
Stripper 6636 cub. ft $ 102,585.15
$ 178,400.00
Heat Exchanger
1200 sq ft (trs area)
$ 121,978.84
$ 256,155.55
Cooler 1
6739 sq ft
$ 168,800.00
$ 320,600.00
Cooler 2
440 sq ft
$ 16,700.00
$ 79,200.00
Cooler 3
258 sq ft
$ 13,600.00
$ 73,600.00
Cooler 4
163 sq ft
$ 11,800.00
$ 69,800.00
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Gasification Process
Solid Removal
Claus Process
Water-Gas Shift
CO2 Absorption
Final syngasproduct
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Water-Gas Shift (WGS)
Equipment Cost Direct Cost Size
WGS reactor $224,140.08 $358,624.13 144 ft3
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Gasification Process
Solid Removal
Claus Process
Water-Gas Shift
CO2 Absorption
Final syngasproduct
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CO2 Absorption
Equipment Cost Direct Cost Size
CO2 absorber
CO2 Stripper 2020 ft3
CO2 capture n/a $ 55,477,294.50
n/a
Compressor $272,889.23 $ 409,333.84
Total
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Gasification Process
Solid Removal
Claus Process
Water-Gas Shift
CO2 Absorption
Final syngasproduct
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Summary of Equipment Cost
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Other Fixed Cost
Other Fixed Cost
License Fees and Royalties
2% of Capital Cost
$ 4.7 million
Maintenance
5% of Capital
Cost
$ 12 million
Laboratory Cost
30% Labor Cost
$ 5.4 million
Insurance 1% Capital Cost
$ 2.4 million
Capital Cost as of now= $ 237,000,000
Labor Cost as of now = $ 18,000,000
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Expected Revenue
Product and Side Products
Unit Price (per ton)
Unit Price (per year)
Syngas $150.00 $ 86.60 million
CO2 $40.00 $ 7.00 million
Sulfur $10.00 $ 0.30 million
Slag TBD TBD
Total $200.00 ~ $ 94 million
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Location
Victoria, Texas Between Houston
and Corpus Christi 200 acres Kansas City
Southern, Union Pacific, and Burlington Northern Santa Fe railways
Gulf Intracoastal Waterway
3/8/2011
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Report Outline
Final Report: Executive Summary IP Discussion IP Recommendations IP
Appendices Design Basis: Done Block Flow Diagram: Done Process Flow Showing Major Equip.: IP
323/8/2011
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Report Outline
Appendices (Continued) Material and Energy Balances: IP Calculations: IP Annotated Equip. List: IP Econ. Eval. Factored from Equip. Costs:
IP Utilities: IP Conceptual Control Scheme: N/A Major Equipment Layout: IP
333/8/2011
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Report Outline
Appendices (Continued) Distribution and End-use Issues:
N/A Constraints Review: IP Applicable Standards: N/A Project Communications File: IP Information Sources and References:
IP
343/8/2011
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References
http://fossil.energy.gov/images/programs/sequestration/what_sequestration_lg.jpg
http://coalgasificationnews.com/tag/petcoke-gasification/
353/8/2011
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CO2 Sequestration
CO2 in our syngas is absorbed on Selexol to be selectively removed
Delete only one CO2 slide.
3/8/2011
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http://fossil.energy.gov/images/programs/sequestration/what_sequestration_lg.jpg3/8/2011