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TRANSCRIPT
Evaluation of Gas Separation Processes
Novel Method for Gas Separation
By: Chris Wilson
For: Senior Capstone 2008
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Overview
Current process
New process
Economic comparison
Natural Gas ProcessingThe Way it is Done
Current process
Remove excess water
Remove acid gas
Dehydrate
Remove mercury
Remove nitrogen
Separate NGL (ethane, and heavier hydrocarbons)
Natural Gas Processing Everything Together
Water removal
Removes free liquid water and condensate gas
Sends the gas to a refinery
The water goes to waste
Natural Gas Processing Everything Together
Natural Gas ProcessingAcid Gas Removal
Hydrogen sulfide
Mercaptans
Carbon dioxide
Acid gas removal processes
Amine treating
Benfield process
Sulfinol process
others
Natural Gas ProcessingAmine Treatment
Most common used amines
Monoethanolamine
Diethanolamine
Diisopropylyamine
Methylethanolamine
Hydrogen sulfide goes through a Claus process
64,000,000 metric tons of sulfur are produced from this process
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Natural Gas ProcessingAmine Treating
Natural Gas ProcessingSulfinol Process
Used to reduce H2S, CO2, and mercaptans from gases
Great for treating large quantities of gas
Solvent absorbs the sour gas
Sulfolane is used
Sulfolane, a clear colerless liquid, developed by shell in the 1960s
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Natural Gas ProcessingSulfinol Process
Natural Gas Processing Everything Together
Natural Gas ProcessingGlycol Dehydration
Method for removing the water vapor from the gas
Usable glycols
Triethylene glycol
most commonly used
Diethylene glycol
Ethylene glycol
Tetraethylene glycol
Works by having the glycol adsorb the water
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Natural Gas ProcessingGlycol Dehydration
Wet gas enters a contacting tower at the bottom. Dry glycol flows down the tower from the top, from tray to tray, or through packing material. A bubble cap configuration maximizes gas/glycol contact, removing water to levels below 5 lbs/MMscf. Systems can be designed to achieve levels down to 1lb/MMscf.The dehydrated gas leaves the tower at the top and returns to the pipeline or goes to other processing units. The water rich glycol leaves the tower at the bottom, and goes to the reconcentration system. In the reconcentration system, the wet glycol is filtered of impurities and heated to 400F. Water escapes as steam, and the purified glycol returns to the tower where it contacts wet gas again.
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Pressure Swing Adsorption
Adsorbent material is used
Gas and material go under high pressure
Material adsorbs the gas ( H2S, mercaptans, CO2)
Disadvantages
Requires high pressures
Slow cycle times
Natural Gas Processing
Mercury removal
Current Processes
Activated carbon through chemisorption. Activated has extremely high surface area
Mercury can damages aluminum heat exchangers
Those used in cryogenic processing plants
Those use in liquefaction plants
Natural Gas Processing
Nitrogen Rejection
Processes that can reject nitrogen
Cryogenic process
Absorption process (using lean oil or solvent)
Membrane separation
Adsorption process (activated carbon)
Natural Gas ProcessingCryogenic Process
Common refrigerants used
Most common method for removal of impurities such as nitrogen
Disadvantages
Must reach extremely low temperatures
Only useful for large scale production
Natural Gas ProcessingLean Oil Removal
Lean oil is fed countercurrent with the wet gas
Temperature and pressure are set to allow for the greatest absorption of unwanted gases
In the ambient lean oil absorption process the natural gas is contacted with the lean oil (molecular weight of about 150) in an absorber column at the ambient temperature of about 100F. The rich oil exiting the bottom of the absorber flows into a rich oil depropanizer (ROD) which separates the propane and lighter components and returns them to the gas stream. The rich oil is then fractionated in a still, where the NGL's (C4+) are recovered as an overhead product and the lean oil is recycled to the absorber column. Typically, 75 percent of butanes and 85-90 percent of pentanes and heavier components are recovered. In the refrigerated lean oil absorption process, the lean oil is chilled against propane refrigerant to improve the recovery of propane to the 90 percent level, and depending upon the gas composition, up to 40 percent of ethane may be recovered (Elliot, 1997). Since reducing the molecular weight of lean oil enhances the lighter component absorption and an external refrigerant is used to chill the lean oil, 100 to 110 molecular weight lean oils are generally used in this process.
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Natural Gas Processing Membranes
Driving force
Partial pressure
Type of material determine permeability
D = diffusion coefficient (cm2/s)
k = Henrys law sorption coefficient (cm3/cm3cmHg)
P1 = Permeability of component 1
P2 = Permeability of component 2
Natural Gas ProcessingEconomics
Demethanizer
Demethanizer
The next step is to recover the NGLs
Process
Cryogenics using a turbo-expander can be used
This is the most common
Lean oil adsorption can be used here
Natural Gas ProcessingCryogenic Process
NGL recovery
NGL recovery
Now the rest of the liquid is fed to three units
Deethanizer
Debutanizer
Depropanizer
Process
Each sent to a distillation column
Sweetening NGLs
Merox Processes
Mercaptan oxidation
Removes mercaptans from
Propane
Butane
Larger hydrocarbons
Natural Gas Processing Another Process
Novel Method
Technical information momentarily not available due to IP issues
However economics will be compared
If you want the access to this, then talk to OTD
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Novel Method
Advantage
More cost effective than any previous methods
Less environmental impacts than previous methods
Separates all contaminants
Separates each component
Everything is done using one process
If you want the access to this, then talk to OTD
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Novel Method
Current Method
Economics - Amine Treating
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Amine Treating - Simulation
Economics - Demethanizer
Demthanizer - Simulation
Economics - Dethanizer
Deethanizer - Simulation
Economics
Built in Error
k
D
P
=
2
1
P
P
=
a
Equipment Description Price ($)
Column - 1 4.88 meters tall, 2,02 meters in diameter $23,000
Column - 2 6.71 meters tall, 3.60 meters in diamter $58,000
Heat exchanger - 1 530 square meters $59,000
Heat exchanger - 2 615 square meters $69,000
Pump 38,000 gallon flow, 235 psi rise $68,000
Total $277,000
Cost of Equipment
Utilities Price ($/hr)
Cooling Water 19,800 gallons/hr ($0.08/1000kg) $5.98
column reboiler 139 million BTU/hr ($6 per million BTU) $834
Pump 97.53 Kw ($0.06/Kw) $5.85
Total $845.83
Operating Costs
Utility Price ($/hr)
Cooling water using $0.08 per 1000 kg of cooling water $1.17
Electricity Two compressors and an expander $116.25
Total $117.42
Operating Costs
Equipment Description Price
Column Diamter of 1.53 meters, Height of 8.54 meters $25,000
Heat exchanger 1 Area of 1055 square meters $118,287
Heat exchanger 2 Area of 15.6square meters $1,874
Heat exchanger 3 Area of 113.12 square meters $12,796
Heat exchanger 4 Area of 25.2 square meters $2,953
Heat exchanger 5 Area of 261.7 square meters $29,440
Heat exchanger 6 Area of 6.8 square meters $890
Heat exchanger 7 Area of 11.5 square meters $1,417
Refrigerant For a 10 year period $880,000
Expander 1200 KW output $370,000
Compressor Compresseing to pressure of inlet for deethanization $50,000
Compressor 2 $190,000
Compressor 3 Bringing methane back to pipeline pressure $640,000
Pump $3,000
Total $2,325,657
Cost of Equipment
Equipment Price
Column8.7 meters tall, 1.86 meters in diameter $32,000
Cost of Equipment
Utility Price
Reboiler(8 million Btu's needed, 6 dollars/million BTU) $48
Operating Costs
Current $4,111.45 $6.74$7.49
A $8,239.58 $1.24$2.74
B-best $7,194.03 $0.98$2.29
C-worst $16,697.63 $2.75$5.80
Current $3,697.91 $6.74$7.41
A $7,459.32 $1.24$2.60
B-best $6,523.00 $0.98$2.17
C-worst $14,372.45 $2.75$5.37
100%
70%
Fixed Capital Investment
(per 1000 cubic feet)
Operating Costs (per
1000 cubic feet/day)
Annulized Cost
(perday)
Equipment Costs $16,800,000
Operating Costs $435/hr
Novel Method - Error for the Worse
Equipment Costs$3,441,657
Operating Costs$1,011/hr
Current Process
Equipment Costs $6,600,000
Operating Costs $155/hr
Novel Method - Error for the Better