proposed approaches for biogas treatment system · proposed approaches for biogas treatment system...

®

Proposed Approaches

for Biogas Treatment System

Francis Y. Huang, Ph.D.

Principal Scientist

Chemical Engineering Department

Chemistry and Chemical Engineering Division

R&D Capability: Biogas as Renewal Energy Sources

All types of biogas – digester, landfill,

agricultural, food process organic waste

• Power generation equipment protection and

service life extension

• Biogas recovery

• Efficiency Improvement for cost reduction

• Biogas for syngas production

• Biogas for hydrogen production – water gas shift

with novel ceramic CO2 membrane

R&D Capability: Biogas Power Generation Process Protection and Enhancement

Biogas contaminants elimination process:

• Preliminary particulate removal

Siloxanes removal

• Halogenated and sulfur-containing compounds removal

• Acid gas removal

Power engine off gas reprocessing

• CO2 reforming to methane

• NOx reduction

Pipeline biomethane processes

Proposed SwRI Biogas Treatment Approaches

(Purifcation)

A Module-based Integrated Biogas Purification (Cleaning) System

Offering:

Low energy consumption

Low pressure

Easy retrofit to the existing operations

•Flexibility in accommodating the treatment gas flow (volume)

• Modular adaption for site-specific chemistry

Central control and monitoring capability

No hazardous wastes or emission

Low capital and operating cost

Company Proprietary information

Proposed SwRI Biogas Treatment Approaches

(Upgrading)

An Efficient Pressure Swing Adsorption (PSA) for Expelling

Carbon Dioxide, Nitrogen and Oxygen (Upgrading) System

Offering:

Effective adsorbents for CO2, N2 and O2 rejection

Compact adsorbents (mixed beds) for simple upgrading

Automatic non-thermal swing pressure adsorption and

desorption cycles for low energy consumption

Flexibility in accommodating the treatment gas flow (volume)

• Modular adaption for site-specific chemistry



SwRI Purification System Aiming at Treating

Biogas Containing Typical Harmful Compounds:

Concentration Range in Biogas (mg/m3)

Facility Type Europe US

Organo-silicon *WWTPs 20 - 400 0.5 - 32

Landfills 5 - 36 4.5 - 161

Sulfur (as H2S)WWTPs 710 - 4300 280 - 1100

Landfills 28 - 860 < 1 - 17,000 #

Halogens (as Cl)WWTPs 0.1 - 5 < 0.1

Landfills 20-200 60 - 491

* Siloxanes: L2-L5, and D3-D6, with predominantly D4 and D5 (up to 60%) and trimethylsilanol (MOH)

# including construction and demolition (C&D) landfills.


SwRI Purification System Removes

Contaminants Meeting or Exceeding Power

Engine Specs:

Power Engines Jenbacher Caterpillar Fuel Cell (SOFC)

Heat ValueMax Variation:

< 0.5 % CH4

15.7 - 23.6 MJm-3

(398-598 Btuft-3)-

Total Silicon ,

mg/m3 CH4

Not Detected < 21 < 0.01

Sulfur, mg/m3 CH4 <1150 < 2140 < 1.3

Halogens (as Cl),

mg/m3 CH4

Not Detected < 713 < 7.2

Ammonia, mg/m3 CH4 < 55 < 105 -

Particles, mg/m3 CH4

< 50

size < 3 um

< 30

size < 1 um-


SwRI Purification System Differs from the Current

Commercial Siloxane Removal Technologies

Technology Examples

Adsorption – fixed bed

Chilling and adsorption

Regenerable adsorbent (active soil, activated charcoal)

Temperature Swing Adsorption

Adsorbent by iron hydroxide

Adsorption-fluidized bed Fluidized bed followed by activated charcoal

Gas chilling

Gas cooling condensate followed by iron peroxide destruction

Cold water adsorption

Condensation at – 25 oC


SWRI - Total destruction of siloxanes to immobilized

silicates - no solvent or emission

Current Commercial Technologies:

All the above commercial technologies require solvents or have emission

Technology Examples

Liquid Scavenger Amine-based liquid and liquid oxidization of H2S to Sulfate

Solid ScavengerIron sponge- hydrated iron oxide (Fe2O3) impregnated redwood

chips. And solid sorbent for H2S.

Iron-Redox H2S converted to elemental sulfur

Liquid Scrubbing Converting H2S into elemental sulfur and removed by biosolids.

Bioscruber for H2SAlkaline absorption of H2S followed by biological oxidation to S0

at pH = 8-9

Chemical and Biological H2S

RemovalIron sponge with thiobacteria



Commercial Sulfur Removal Technologies

SwRI: Catalytically converts halogen - , nitrogen- , and sulfur-

containing compounds to inorganic acid gases and captured

by alkaline impregnated carbon. Self-regenerated and no

solvent/emission

Current Commercial Technologies:

No commercial technologies for halogen and nitrogen containing compound removal

SwRI: Integrated complete contaminants removal –

no solvent, no hazardous emission or discharge

Technology Examples

Fixed Bed and Catalytic AdsorptionDehumidification, desulfurization, decarbonization and

siloxane only removal

Pressure Swing Adsorption (PSA) Removes water, CO2, and H2S at high pressure (5-7 atm)

Physical SolventsPG (dimethyl ether of polyethylene glycol), Dialkyl

polyethyene glycol, Methanol, NMP (N-methyl-2-

pyrrolidone), and PC (propylene carbonate)



Commercial Combined Technologies

Commercial biogas contaminants removal systems – very few and

only for partial removal

Solvent-based technologies are costly and difficult to operate

Chemical Compounds in Landfill Gas by GC/MS Analyses

Mescia et al. 2011

SwRI Landfill Gas Purification System

for On-site Electricity generation

SwRI Biogas Purification Approaches


Optional

SwRI LFG Purification System


Conceptual Site Application for LFG Electricity Generation System


Objectives

• An integrated multi-

contaminant removal

process

• Except for removals of

biogas condensate and

particulate, no pretreatment

is required.

• Flexibility in levels of

contaminants removal for

meeting application criteria

• Economical – low

equipment and maintenance

costs

• Module design with

flexibility for scaling and

adaption

• Flexible heat sources -

engine exhaust gas or direct

flareCompany Proprietary information

Unique Approaches in SwRI Biogas

Purification System

Module 1. Siloxanes Removal – Active for converting and

fixing siloxane to inorganic silicate . Economic,

high capacity, and no emission or hazardous

products

0

10

20

30

40

50

60

70

80

90

100

0 5 10 15 20 25 30 35 40

Destruction D4

Destruction L2

%

Destr

ucti

on

Time,

Total organic

silicone converted:

D4: 4.84 g

L2: 9.68 g

Test Conditions:

Flow LFG Flow Rate: 18.5 L/ min

(54% CH4, 35% CO2, 0.89 %

Oxygen, 11 % N2)

D4: 100 ppmv ( 623 mg/m3 Si)

L2: 200 ppmv (1250 mg/m3 Si)

Alumina : 250 g

Siloxanes destruction on activated alumina surface (at 300 oC)


0

10

20

30

40

50

60

70

80

90

100

0 10 20 30 40

Hydrogen Sulfide( H2S)

Pinene (C10H16)

Tetrachloroethylene (C2Cl4)

Limonene (C10H16)

Toluene (C7H8)

Trimethylbenzene (C9H12)

%

Time, hrs.


Purification System


Minor hydrocarbons and partial H2S are also removed

during siloxane destruction by activated alumina

Module 2. Sulfur and Halogen- containing Compounds Removal -

Effective conversions by catalytic oxidation. Self-

regenerated single column with vanadium based

catalysts.

Model CompoundsConcentratio

ns (ppmv)

LFG Gas

Flow Rate

(L/min)

Air Flow Rate

(mL/min)

Destruction

Rates (%)

Tetrachloroethylene 219 1 10 93.2

CFC-113 183 0.5 10 78

Toluene 351 1 10 99.8

H2S 107 1 10 100

Model compound destruction rates on V2O5/TiO2 catalyst.

Test Conditions: LFG : 54% CH4, 35% CO2, 0.89 % Oxygen, 11 % N2



Purification System

0

2

4

6

8

10

12

14

0 100 200 300 400 500 600

After 1st Regeneration

Afetr 2nd Regeneration

After 3rd Regeneration

After 4th Regeneration

pH

Time, min.

0

10

20

30

40

50

60

300 800 1300 1800 2300 2800

Na

Cl C

on

ten

t

Water Steam Used, g

Module 3. Acid Gas Removal - Effective absorption by alkaline

oxides impregnated carbon at ambient temperature.

High capacity dual columns regenerated with external

stream. Nonhazardous inorganic salts are the only

products.

Acid Gas Breakthrough Curve at P = 1 atm.

T = 28oC and HCl at 223,000 ppm.

Water Demand during Steam Regeneration

(activated carbon : 100 grams)

Lee et al. 2003



Purification System

Concentration Profiles for Competitive Adsorption of NO2-SO2 on KOH Impregnated

Activated Carbons (K-IAC)(1000 ppm, 130oC, linear velocity: 30 cm/s)

0

100

200

300

400

500

600

700

800

900

0 50 100 150 200 250 300

NO2

SO2

Reaction Time (min)

Co

nc

en

tra

tio

n

(pp

m)

Lee, 2002

Break Through Curve of SO2 on AC (a) and K-IAC (b)

Lee, 2002

X-ray Diffraction Pattern of K-IAC: (a) non-

adsorbed, (b) 1007 ppm NO2, (c) 1004 ppm

SO2, and (d) mixture of NO2 and SO2

Alkaline Impregnated Activated Carbon Acid Gas Adsorption Mechanisms (1)


Alkaline Impregnated Activated Carbon Acid Gas Adsorption Mechanisms (2)


Engineering of SwRI LFG Purification System

Field Full Scale Unit Components

Identification

(for 500 - 2500 scfm biogas flow rate):

• Module reactor dimension:

• 4 -12 “ dia x 24 – 44’ ( based on

space velocity of 20,000 hr-1 )

• Reactor volume: 42 - 200 L

• Gas-to-oil heat exchanger: gas

intake flow arte: 3,000 CFM. Oil

temperature: 300o C at 720

ft/min flow rate.

• Central electronic control




Conceptual Site Application for LFG Electricity Generation System

SwRI Farm Waste Digester Gas

Purification System

SwRI Animal (Farm) Biogas Purification System

Aiming at Treating Typical Harmful Compounds:

Typical Concentration Range in Anaerobic

Digester Biogas

Methane (CH4) 50 - 80 %

Carbon Dioxide (CO2) 20 - 50 %

Water Vapor (H2O) 2 - 5 % (mass)

Nitrogen (N2) * 1- 4 %

Oxygen (O2) * < 1 %

Hydrogen Sulfide (H2S) 50 – 5000 ppm

Ammonia (NH3) 0 – 300 ppm

Trace gases Low Concentration

Non-Gaseous Particulates and oil in low concentration

* Only present if air is injected into the digester for H2S reduction


Trace Compounds identified in Biogas

Rasi, 2007

SwRI Animal Waste Biogas Purification System ( With Oil Heater)


SwRI Animal Waste Biogas Purification System ( with Gas-Oil Heat Exchanger)


SwRI Animal Waste Digester Gas Purification System


• Two modules:

A. Sulfur- and halogen-

containing compounds

removal

B. Acid gas removal

• Optional heat supplies :

gas heating and electrical oil

heating

• Simple operation

• No emissions

• Low Cost

SwRI Digester Biogas Purification System


Conceptual Site Application

Engineering of SwRI Waste Digester Biogas Purification System

Field Full Scale Unit Components

Identification

(for 100 - 500 scfm digester biogas flow

rate):

• Module reactor dimension:

• 4 “ dia x 3.5 – 17’ ( based on space

velocity of 20,000 hr-1 )

• Reactor volume: 8 - 42 L

• Gas-to-oil heat exchanger: gas

intake flow arte: 3,000 CFM. Oil

temperature: 300o C at 720

ft/min flow rate.

• Central electronic control


Summary - SwRI System Advantages

• Untreated biogas limits engine life and increases maintenance

frequency; jeopardizes upgrading to biomethane

• SwRI has developed a concept supported by laboratory data that

provides cleaner biogas than competing systems:

Comprehensive contaminants removal

Low energy consumption

Low pressure

Modular configuration

Flexible design for various biogas types and flows (treatment volume)


No hazardous wastes

Low capital and installation cost


SwRI Biogas Purification (Cleaning) System Economic

Analyses

A capital cost comparison with other commercial LFG cleanup systems

(excluding compressors)

Economic Analysis I

Protection of CAT

3520 Engines

Solid H2S

Scavengers

Iron-Redox

Regenerable

SwRI Proposed

Approach

System

Description

SulfrStrip® for H2S,

SWOP for siloxane

Sulfur Rite® for H2S

onlyLO CAT® Multi-contaminants

Removals

Capacity

Continuous, 2000

CFM, Caterpillar

specs.

Down to 75-100

ppmv

Down to 75-100

ppmv

Continuous, 2500

CFM, Caterpillar

specs.

Capital

Equipment

Estimates

$ 3,890, 000 $41,000$ 1,000,000 –

$ 2,000,000$ 530,000

Data Source

Cornerstone

Environmental

Group

Merichem Merichem

SwRI VMGSim™ and

CapCost simulation

(excluding site

preparation)


Continuous, 500 to

2500 scfm, meeting

Cat. 3520 specs.

500 scfm - $ 700,000,

2500 scfm - $ 800,000

SwRI VMGsim and

CapCost

Simulations

Summary of Cost Analysis of SwRI LFG Purification System

(500 and 2500 scfm Capacity)


Economic Analysis II

Complete Installation and Operating Cost Evaluation ( excluding compressor)

Treatment

Capacity (SCFM)

System Material

and Assembly

Cost, $

(Note 1)

Installation

Factor

Estimated Capital

Costs, $

Estimated

Annual

Operating

Costs, $

(Note 2)

Annual 5-yr

Straight Line

Depreciation, $

(Note 3)

Total Annual

Cost

Estimated

Operating Costs

& Depreciation,

$/MMscf

(Note 4)

500 461,412 1.5 692,118 4,614 64,598 69,212 275

2500 529,812 1.5 794,718 5,298 74,174 79,472 63

Electricity Generated by Cat.

3520 Engineer Biomethane Production

Treatment

Capacity (SCFM)

Cost per MWh, $

(Note 5)

Est. Whole

Sale Price per

Mwh, $ (Note 6)

Cost per Mmbtu,

$ (Note 7)

Est. Whole Sale

Price per

Mmbtu,

$ (Note 8)

500 5.15 40.00 0.55 3.769

2500 1.18 40.00 0.13 3.769

Note 1: A 20% cushion from the VMGsim estimate (bare module Cost) is added.

Note 2: Including the replacement of siloxane sorbents

Note 3:A 30% 5-year end salvage value is

applied

Note 4: Based on total annual treatment volume of gas (350 days)

Note 5: Power Generation = 1.6

MW per engine (Cat. 3520 engine, 500

scfm)

= 53 MW-h per MMscf treated

= 67,200 MW-h per annually treated gas

Note 6: A conservative sale estimate of $0.04 per KWh is used.

Note 7: Assume biogas containing 50% CH4: 1MMscf= 500 MMbtu of LFG

Note 8: National future price of $ 3.769 (MMbtu) is used. (US Energy information Administration: 11/28/2012- http://www.eia.gov)

Economic Analysis III

Complete Installation and Operating Cost Evaluation (including compressor and electrical oil heating)

Treatment Capacity

(SCFM)

System

Material and

Assembly

Cost, $

(Note 1)

Installation

Factor

Estimated

Capital Costs, $

Estimated

Annual

Operating

Costs,$

(Note 2)

Annual 5-yr

Straight Line

Depreciation, $

(Note 3)

Total Annual

Cost

Estimated

Operating Costs

& Depreciation,

$/MMscf

(Note 4)

100 226,332 1.5 339,498 2,263 31,686 33,950 674

200 272,436 1.5 408,654 2,724 38,141 40,865 405

250 299,052 1.5 448,578 2,991 41,867 44,858 356

500 409,452 1.5 614,178 4,095 57,323 61,417 244

Biomethane Production

Treatment Capacity

(SCFM)

Cost per

MMbtu, $

(Note 5)

Est. Whole

Sale Price per

MMbtu, $

(Note 6)

100 1.12 3.769

200 0.68 3.769

250 0.59 3.769

500 0.41 3.769

Note 1: A 20% cushion from the VMGsim estimate (bare module Cost) is added.

Note 2: Including the electricity cost for oil heater and regeneration of the acidic gas removal module

Note 3:A 30% 5-year end salvage value is

applied

Note 4: Based on total annual treatment volume of gas (350 days)

Note 5: Assume biogas containing 60% CH4: 1MMscf= 600 MMbtu of LFG

Note 6: National future price of $ 3.769 (MMbtu) is used. (US Energy information Administration: 11/28/2012- http://www.eia.gov)

Summary of Cost Analysis of SwRI Waste Digester Purification System

(100 to 500 scfm Capacity)


SwRI Proposed Approached for Biogas Upgrading System

• Solid sorbent-based system with commercial

adsorbent for CO2 and unique lab developed gas-

specific adsorbents for N2 and O2 rejection

•

• Effective pressure swing for adsorption and

desorption

• Automatic electronic control system for cycling

• Meets pipeline methane quality criteria with low energy

consumption ( Nitrogen < 4 %: Oxygen < 0.2 %: CO2 < 2 %)

• Simple system maintenance and long useful

equipment life

SwRI Proposed Approached for Biogas Upgrading System – Unique Adsorbents

0

1

2

3

4

5

6

7

0.00 0.20 0.40 0.60 0.80 1.00 1.20

25 oC

30 oC

45 oC

Vo

lum

e A

ds

orb

ed

(mL

/g)

Equilibrium Adsorption Isotherm of N2 :degassed at 150 oC ( no CH4 Adsorption)

0

0.5

1

1.5

2

2.5

3

3.5

0.00 0.20 0.40 0.60 0.80 1.00 1.20

25 oC30 oC45 oC

Pressure (atm)

Equilibrium Adsorption Isotherm of O2: degassed at 150 oC (No CH4 Adsorption))

SwRI Proposed Approached for Biogas Upgrading System – Unique Adsorbents

Vo

lum

e A

ds

orb

ed

(m

L/g

)

SwRI Proposed Approached for Biogas Upgrading– PSA System

Feed from

Purification

Systemr

Waste to

Flare

Be

d 1

Be

d 2

Purified

CH4 to

Pipeline

Waste to

Flare

Be

d 3

Be

d 4

CO2 Removal PSAN2/O2

Rejection

PSA

SwRI Proposed Approached for Biogas Upgrading– PSA Cycles

SwRI: (1) Integrated one process CO2, N2, and O2

Rejection – Unique adsorbents, no hazardous

emission or discharge

(2) Easy Integration with SwRI biogas purification

system for streamline operations

Technology Examples

Cryogenic BCCK –Nitech ™ ( < 5 MMSCFD)

Pressure Swing Adsorption (PSA) Nitrogen Sponge® - IACX

Physical SolventsPG (dimethyl ether of polyethylene glycol), Dialkyl

polyethyene glycol, Methanol, NMP (N-methyl-2-

pyrrolidone), and PC (propylene carbonate)


SwRI Upgrading System Differs from the Current

Commercial Combined Technologies

Cryogenic and solvent-based technologies are costly and difficult to operate

Phase 1. Conceptual development and laboratory scale evaluation

(completed)

Technology studies and market search, catalyst selection and

evaluation, engineering process design and material estimation,

economic analysis

Phase 2. Bench - scale system (1 :100) study and field prototype design

Operation data collection and system optimization studies.

Duration: 12 – 18 months

Phase 3. Field - scale prototype construction and field testing

Mobil unit (skid) for site testing and engineering evaluation. Unit

can be mobile for demonstration or installed for operation.

Duration: 12 months (cost to be determined), and then

Phase 4. Commercialization

IP protection application

Plans for the Development of SwRI

Treatment System



Appendix Slides

Major Gas Engines Gas Quality Requirements

Biogas Quality criteria in electricity production (EPRI, 2006; Ruokomaki, 2009)

Reciprocating

EnginesTurbine Microturbine

Fuel Cell

(SOFC)

Sterling

Engine

Input Pressure, bar 0.2 - 1.4 14 - 24 3.5- 5.0 - 0.14

Total silicon, mg/m3 CH4 10 - 50 0.1 < 0.01 < 0.01 0.48 (as D4)

Sulfur, mg/m3 CH4 720 - 2300 < 13200 32 - 92000 < 1.3 370

Halogens (as Cl),

mg/m3 CH486 - 713 2200 290 < 7.2 340

(Environmental Agency, 2002; Beese, 2007)

Jenbacher Caterpillar

Heat Value Max Variation: < 0.5 % CH4

15.7 - 23.6 MJm-3

(398-598 Btuft-3)

Total silicon , mg/m3

CH4

<10 (without catalyzer) n.d (with catalyzer) < 21

Sulfur, mg/m3 CH4

<2000 (without

catalyzer)<1150 (with catalyzer) < 2140 < 57 mg/MJ

Halogens (as Cl),

mg/m3 CH4

<100 (without catalyzer) n.d (with catalyzer) < 713

Ammonia, mg/m3 CH4 < 55 < 105

Particles, mg/m3 CH4 < 50 size < 3 um < 30 size < 1 um

Conversion factors: Silicone (Si): 1 mg/m3 = 0.87 ppm Halogens (as Cl): 1 mg/m3 = 0.69 ppm

Sulfur (S): 1 mg/m3 = 0.76 ppmCompany Proprietary information

Current Commercial Siloxane Removal Technologies

Technology Trade Name (Company) Features

Adsorption – fixed bed

FAKA (Siloxa Engineering) Chilling and adsorption

SAGTM (Applied Filter Technology) Customized activated carbons and graphites blends

BGAK (PpTek) Regenerable adsorbent (active soil)

GES (Parker Hannifin) Regenerable adsorbents.

TSA (Jenbacher –GE)Temperature Swing Adsorption - Regenerable

activated carbon

Herbst Umwelttechnik Adsorbent by iron hydroxide

Adsorption-fluidized bed SWOPTM (Applied Filter Technology) Fluidized bed followed by two SAGTM vessels

Gas chilling

HELASPORP (Herbst Umwelttechnik)Gas cooling condensate followed by iron peroxide

destruction

Köhler and Ziegler Cold water adsorption

TCR (Pioneer Air Systems – Gas treatment Services ) Condensation at – 25 oC


Current Commercial Biogas Sulfur Removal Technologies (1)

Technology Company Trade Name Features

Liquid

Scavenger

D Three Technology DTM Triazine

Amine-based liquid resins-to form

trazine. Injection of liquid to gas

or gas bubbled through liquid.

No Heat Resources Pte LtdHydrScav

®Liquid oxidization of H2S to

Sulfate

Solid Scavenger

Merichem Co. Sulfur Rite ® Iron sponge- hydrated iron oxide

(Fe2O3) impregnated redwood

chips. Resulted product: iron

pyrite (FeS2 )M-I SWACO SulfaTreat

®

Chemical Products

Industries, Inc.SulfurTrap

® Solid sorbent for absorbing H2S.

Iron-redox

Merichem Co. LO CAT ®

H2S converted to elemental sulfur

by reacting chelated ferric ion

with hydrosulfate ion.

Regeneration by air and

separation of sulfur.Applied Filter Technology SulfrStrip™


Current Commercial Biogas Sulfur Removal Technologies (2)

Technology Company Trade Name Features

Liquid Scrubbing Eco-Tec, Inc.BgPurTM BioGas Purification

System

1. 99+ % H2S removal

2. Automatic adjustment for H2S

and flow level

3. Small, skid-mounted

4. Capacity according to specific

needs

Bioscruber for H2S ShellPaques/Thiopack TM

Technology

Alkaline absorption of H2S

followed by biological oxidation to

S0 at pH = 8-9

Chemical and

Biological H2S

Removal

MVLLC, Inc. H2S PLUSTM Technology Iron sponge with thiobacteria


Current Commercial Biogas Combined Removal

Technologies

Technology Company Trade Name Features Comments

Fixed bed

and catalytic

adsorption

Schmack

Biogass

AGCarboTech

Process and

ZETECH4®

1. Compression

2. Dehumidification

3. Desulfurization

4. Decarbonization

5. Siloxane removal

1. Up to 5 bars

2. By moderate quenching

3. Fixed-bed catalytic

adsorption on AC

4. PSA adsorption on

molecular sieves

PSA Guild Associates,

Inc.

Guild PSA

Technology

1. Compression: 4-7 atm

2. Removes water, CO2, and H2S

3. Tailgas is low in heating value.

Water removed to < 0.11

g/Nm3; H2S to 4 ppm; CO2

to 1 to 3%

Physical

Solvents

1. Coastal

Chemical Co.

2. Dow and UOP

3. Clariant GmbH

4. Lurgi AG

5. Prosernat

6. Lurgi AG

7. Fluor Daniel,

Inc.

1. Coastal AGR

2. Selexol®

3. Genosorb®

4. Rectisol

5. Ifpexol®

6. Purisol

7. Fluor Solvent

1-2 . DEPG (dimethyl ether of

polyethylene glycol)

3. Dialkyl polyethyene glycol

4-5. Methanol

6. NMP (N-methyl-2-pyrrolidone)

7. PC (propylene carbonate)

Removal of acid gases, H2S

and CO2, in large scale

operation. Replenishment

and regeneration of solvent

are required.


proposed approaches for biogas treatment system · proposed approaches for biogas treatment system...

Documents