Selective Removal and Recovery of Acid Gases from Gasification Products

• US 20090220406A1
• Filed: 02/27/2009
• Published: 09/03/2009
• Est. Priority Date: 02/29/2008
• Status: Abandoned Application

• Current Assignee: Sure Champion Investments Limited
• Original Assignee: GreatPoint Energy, Inc.
• Inventors: Rahman, Mustafiz
• Application Number:
  US12/395,344
• Publication Number:
  US 20090220406A1
• Time in Patent Office: Days
• US Class Current: 423/437.100
• CPC Class Codes: B01D 2257/304 Hydrogen sulfide
• CPC Class Codes: B01D 2257/504 Carbon dioxide
• CPC Class Codes: B01D 53/1468 Removing hydrogen sulfide
• CPC Class Codes: B01D 53/1475 Removing carbon dioxide
• CPC Class Codes: B01D 53/52 Hydrogen sulfide
• CPC Class Codes: B01D 53/77 Liquid phase processes
• CPC Class Codes: C01B 2203/0405 Purification by membrane separation
• CPC Class Codes: C01B 2203/0415 Purification by absorption in liquids
• CPC Class Codes: C01B 2203/046 Purification by cryogenic separation
• CPC Class Codes: C01B 2203/0475 the impurity being carbon dioxide
• CPC Class Codes: C01B 2203/048 the impurity being an organic compound
• CPC Class Codes: C01B 2203/0485 the impurity being a sulfur compound
• CPC Class Codes: C01B 2203/049 the impurity being carbon
• CPC Class Codes: C01B 2203/147 Three or more purification steps in series
• CPC Class Codes: C01B 2203/148 involving a recycle stream to the feed of the process for making hydrogen or synthesis gas
• CPC Class Codes: C01B 3/382 Multi-step processes
• CPC Class Codes: C01B 3/52 by contacting with liquids; Regeneration of used liquids C01B3/508 takes precedence
• CPC Class Codes: C10J 3/482 Gasifiers with stationary fluidised bed
• CPC Class Codes: C10K 1/004 Sulfur containing contaminants, e.g. hydrogen sulfide
• CPC Class Codes: C10K 1/005 Carbon dioxide
• CPC Class Codes: C10K 1/165 : at temperatures below zero degrees Celsius
• CPC Class Codes: Y02C 20/40 : of CO2
• CPC Class Codes: Y02P 20/151 : Reduction of greenhouse gas [GHG] emissions, e.g. CO2

Abstract

Processes and apparatuses are described for the selective removal and recovery of acid gases from a gas source comprising at least hydrogen sulfide and carbon dioxide. A step-wise approach is illustrated wherein hydrogen sulfide may be selectively removed from a gas source by treatment with methanol under conditions where substantially all the hydrogen sulfide may be removed. The partially purified gas source may then be provided with a second treatment with methanol under conditions which selectively remove carbon dioxide from the gas stream. Such methods are generally applicable to any gas source comprising at least hydrogen sulfide and carbon dioxide, for example, a gas source produced from the catalytic gasification of a carbonaceous material, the combustion of a carbonaceous material, or the oxy-blown gasification of a carbonaceous material.

Claims

1. A process for removing hydrogen sulfide and carbon dioxide from a gas mixture, the process comprising the steps of:

(A) providing a gas mixture comprising methane, carbon monoxide, hydrogen, hydrogen sulfide, and carbon dioxide;

(B) contacting the gas mixture with a first absorber under a first set of operating conditions to produce a hydrogen sulfide-depleted gas stream and a hydrogen sulfide-laden absorber stream, the hydrogen sulfide-depleted gas stream comprising about 5 ppm or less hydrogen sulfide;

(C) recovering the hydrogen sulfide-laden absorber stream;

(D) contacting the hydrogen sulfide-depleted gas stream with a second absorber under a second set of operating conditions to produce a carbon dioxide-depleted gas stream and a carbon dioxide-laden absorber stream, the carbon dioxide-depleted gas stream comprising about 50 ppm or less of carbon dioxide; and

(E) recovering the carbon dioxide-laden absorber stream;

wherein;

the first operating conditions comprise a first operating temperature and a first operating pressure,

the second operating conditions comprise a second operating temperature and a second operating pressure,

the first operating temperature is greater than the second operating temperature, and

the first and second absorbers substantially comprise methanol.

2. The process of claim 1, further comprising the step of recovering carbon dioxide from the carbon dioxide-laden at a pressure ranging from about 350 psia to about 450 psia.

3. The process of claim 1, wherein step (B) comprises the steps of:

(B1) feeding the gas mixture into a first unit;

(B2) feeding the first absorber into the first unit;

(B3) contacting the gas mixture and the first absorber in the first unit under conditions to produce a first overhead gas stream, and a first bottoms stream that is the hydrogen sulfide-laden absorber stream;

(B4) partially condensing the first overhead gas stream to produce a first condenser recycle stream that is recycled back to the first unit, and the hydrogen sulfide-depleted gas stream that is withdrawn; and

(B5) withdrawing a first reboiler stream from the first unit, that is reboiled then recycled back to the first unit.

4. The process of claim 1, wherein step (D) comprises the steps of:

(D1) feeding the hydrogen sulfide-depleted gas stream into a second unit;

(D2) feeding the second absorber into the second unit;

(D3) contacting the hydrogen sulfide-depleted gas stream and the second absorber in the second unit under conditions to produce a second overhead gas stream, and a second bottoms stream that is the carbon dioxide-laden absorber stream;

(D4) partially condensing the second overhead gas stream to produce a second condenser recycle stream that is recycled back to the second unit, and the carbon dioxide-depleted gas stream that is withdrawn; and

(D5) withdrawing a second reboiler stream from the second unit, that is reboiled then recycled back to the second unit.

5. The process of claim 1, wherein in step (B), the gas mixture is contacted with the first absorber in a first unit having:

(Bi) a first gaseous mixture feed line for feeding the gas mixture into the first unit;

(Bii) a first liquid feed line for feeding the first absorber into the first unit;

(Biii) a first unit top portion,

(Biv) a first condenser having a first condenser inlet line in fluid communication from the first unit top portion, a first condenser recycle line in fluid communication back to the first unit, and a first gaseous product line for withdrawing the hydrogen sulfide-depleted gas stream,

(Bv) a first unit bottom portion,

(Bvi) a first reboiler in fluid communication with the first unit bottom portion, and

(Bvii) a first unit bottoms line in fluid communication with the first unit bottom portion for recovering the hydrogen sulfide-laden absorber stream.

6. The process of claim 1, wherein in step (D), the hydrogen sulfide-depleted gas stream is contacted with the second absorber in a second unit having:

(Di) a second gaseous mixture feed line for feeding the hydrogen sulfide-depleted gas stream into the second unit,

(Dii) a second liquid feed line for feeding the second absorber into the second unit;

(Diii) a second unit top portion,

(Div) a second condenser having an second condenser inlet line in fluid communication from the second unit top portion, a second condenser recycle line in fluid communication back to the first unit, and a second gaseous product line for withdrawing the carbon dioxide-depleted gas stream,

(Dv) a second unit bottom portion,

(Dvi) a second reboiler, having a second reboiler top portion and a second reboiler bottom portion, in fluid communication with the second unit bottom portion, and

(Dvii) a second unit bottom line in fluid communication with the second unit bottom portion or the second reboiler bottom portion for recovering the carbon dioxide-laden absorber stream.

7. The process according to claim 5, wherein the first operating temperature ranges from about −

10°

F. to about −

5°

F. within the first unit top portion and from about 250°

F. to about 350°

F. within the first unit bottom portion, and the first operating pressure ranges from about 400 psia at within the first unit top portion to about 500 psia within the first unit bottom portion.

8. The process according to claim 6, wherein the second operating temperature ranges from about −

45°

F. to about −

30°

F. within the second unit top portion and from about −

40°

F. to about −

35°

F. within the second unit bottom portion, and the first operating pressure ranges from about 420 psia at within the second unit top portion to about 455 psia within the second unit bottom portion.

9. The process according to claim 5, wherein the first reboiler unit has an operating temperature ranging from about 300°

F. to about 375°

F.

10. The process according to claim 6, wherein the second reboiler unit has an operating temperature ranging from about 200°

F. to about 250°

F.

11. A process for converting a carbonaceous composition into a plurality of gaseous products, the process comprising the steps of:

(a) supplying a carbonaceous composition to a gasification reactor;

(b) reacting the carbonaceous composition in the gasifying reactor in the presence of steam and a gasification catalyst under suitable temperature and pressure to form a plurality of gaseous products comprising methane, hydrogen, carbon monoxide, carbon dioxide and hydrogen sulfide, the gasification catalyst comprising an alkali metal;

(c) removing a substantial portion of the hydrogen sulfide and carbon dioxide from the plurality of gaseous products according to the process of claim 1 to produce a hydrogen sulfide and carbon dioxide-depleted product gas stream; and

(d) at least partially separating the hydrogen sulfide and carbon dioxide-depleted product gas stream to produce a stream comprising a predominant amount of one of the remaining gaseous products.

12. An apparatus for the purification of a gaseous mixture comprising:

(a) a first unit comprising;

(a1) a first unit top portion,

(a2) a first unit bottom portion,

(a3) a first gaseous mixture feed line,

(a4) a first liquid feed line,

(a5) a first condenser in fluid communication with the first unit top portion, the first condenser comprising a first condenser overhead portion, a first condenser bottom portion, and a first gaseous product line in fluid communication with the first condenser overhead portion,

(a6) a first reboiler in fluid communication with the first unit bottom portion, and

(a7) a first bottoms line in fluid communication with the first unit bottom portion;

and (b) a second unit comprising;

(b1) a second unit top portion,

(b2) a second unit bottom portion,

(b3) a second gaseous mixture feed line in fluid communication with the first gaseous product line,

(b4) a second liquid feed line,

(b5) a second condenser in fluid communication with the second unit top portion, the second condenser comprising a second condenser overhead portion, a second condenser bottom portion, and a second gaseous product line in fluid communication with the second condenser overhead portion,

(b6) a second reboiler, having a second reboiler top portion and a second reboiler bottom portion, in fluid communication with the second unit bottom portion, and

(b7) a second bottoms line in fluid communication with the second unit bottom portion or the second reboiler bottom portion.

13. The apparatus of claim 12, further comprising a catalytic gasification reactor in fluid communication with the first gaseous mixture feed line.

14. The apparatus of claim 12, further comprising a first liquid-gas separation unit in fluid communication with the first bottoms line, the first liquid-gas separation unit comprising:

a first liquid-gas separation unit top portion,

a first liquid-gas separation unit bottom portion,

a first liquid recycle line in fluid communication with the first liquid-gas separation unit bottom portion, and

a third condenser in fluid communication with the first liquid-gas separation unit top portion, the third condenser comprising;

a third condenser overhead portion,

a third condenser bottom portion, and

a first gas exhaust line in fluid communication with the third condenser overhead portion.

15. The apparatus of claim 14, further comprising a sulfur recovery unit in fluid communication with the first gas exhaust line.

16. The apparatus of any one of claims 12, further comprising a second liquid-gas separation unit in fluid communication with the second bottoms line, the second liquid-gas separation unit comprising:

a second liquid-gas separation unit top portion,

a second liquid-gas separation unit bottom portion,

a second liquid recycle line in fluid communication with the second liquid-gas separation unit bottom portion, and

a fourth condenser in fluid communication with the second liquid-gas separation unit top portion, the fourth condenser comprising;

a fourth condenser overhead portion,

a fourth condenser bottom portion, and

a second gas exhaust line in fluid communication with the fourth condenser overhead portion.