LNG production in cryogenic natural gas processing plants

• US 5,615,561 A
• Filed: 11/08/1994
• Issued: 04/01/1997
• Est. Priority Date: 11/08/1994
• Status: Expired due to Term

• Current Assignee: Williams Industrial Services Incorporated
• Original Assignee: Williams Industrial Services Incorporated
• Inventors: Belhateche, Noureddine, Ostaszewski, Ricardo, Kruger, Kimberly A., Houshmand, Mory, Alves, Gerald W.
• Primary Examiner(s): KILNER, CHRISTOPHER B
• Application Number:
  US08/335,902
• Time in Patent Office: 875 Days
• Field of Search: 62/9, 62/11, 62/13, 62/23, 62/42, 62/24, 62/620, 62/611
• US Class Current: 62/611
• CPC Class Codes: F25J 1/0022 Hydrocarbons, e.g. natural gas
• CPC Class Codes: F25J 1/0035 by gas expansion with extraction of work
• CPC Class Codes: F25J 1/004 by flash gas recovery F25J1/0267 takes precedence
• CPC Class Codes: F25J 1/0042 by liquid expansion with extraction of work
• CPC Class Codes: F25J 1/0045 by vaporising a liquid return stream
• CPC Class Codes: F25J 1/0208 in combination with an internal quasi-closed refrigeration loop, e.g. with deep flash recycle loop F25J1/021 takes precedence
• CPC Class Codes: F25J 1/0237 integrating refrigeration provided for liquefaction and purification/treatment of the gas to be liquefied, e.g. heavy hydrocarbon removal from natural gas details related to rectification F25J3/02; details related to partial condensation F25J3/06; working-up natural gas C10L3/10
• CPC Class Codes: F25J 1/0274 Retrofitting or revamping of an existing liquefaction unit
• CPC Class Codes: F25J 2200/02 in a single pressure main column system
• CPC Class Codes: F25J 2200/70 Refluxing the column with a condensed part of the feed stream, i.e. fractionator top is stripped or self-rectified
• CPC Class Codes: F25J 2205/04 in the feed line, i.e. upstream of the fractionation step
• CPC Class Codes: F25J 2220/62 Separating low boiling components, e.g. He, H2, N2, Air
• CPC Class Codes: F25J 2230/20 Integrated compressor and process expander; Gear box arrangement; Multiple compressors on a common shaft
• CPC Class Codes: F25J 2230/60 the fluid being hydrocarbons or a mixture of hydrocarbons
• CPC Class Codes: F25J 2235/60 the fluid being (a mixture of) hydrocarbons
• CPC Class Codes: F25J 2240/02 Expansion of a process fluid in a work-extracting turbine (i.e. isentropic expansion), e.g. of the feed stream
• CPC Class Codes: F25J 2240/30 Dynamic liquid or hydraulic expansion with extraction of work, e.g. single phase or two-phase turbine
• CPC Class Codes: F25J 2240/40 Expansion without extracting work, i.e. isenthalpic throttling, e.g. JT valve, regulating valve or venturi, or isentropic nozzle, e.g. Laval
• CPC Class Codes: F25J 2245/02 Recycle of a stream in general, e.g. a by-pass stream
• CPC Class Codes: F25J 2245/90 the recycled stream being boil-off gas from storage
• CPC Class Codes: F25J 2270/90 : External refrigeration, e.g. conventional closed-loop mechanical refrigeration unit using Freon or NH3, unspecified external refrigeration
• CPC Class Codes: F25J 2290/80 : Retrofitting, revamping or debottlenecking of existing plant
• CPC Class Codes: F25J 3/0209 : Natural gas or substitute natural gas
• CPC Class Codes: F25J 3/0233 : separation of CnHm with 1 carbon atom or more
• CPC Class Codes: F25J 3/0238 : separation of CnHm with 2 carbon atoms or more

Abstract

A method and system for liquifying natural gas using a cryogenic process is described. The method is well suited for producing high methane purity natural gas which can be used as a vehicle fuel. The invention utilizes residue gas from a cryogenic plant as a natural gas feedstock. The natural gas feedstock is condensed by heat exchange with overhead gas from the demethanizer of the cryogenic plant. In the preferred embodiment of the invention the pressure of the condensed natural gas is reduced to a level at which it can be readily stored and transported by expansion through one or more Joule-Thomson valves.

Claims

1. A method for liquifying a natural gas stream, comprising the step of

a) cooling and condensing the natural gas stream in a heat exchanger to produce a condensed natural gas stream;

wherein said natural gas stream is in gaseous form and comprises compressed residue gas from a cryogenic plant;

wherein said cryogenic plant utilizes a separation means to separate methane gas from liquified heavier hydrocarbons; and

wherein cooling is provided in said heat exchanger by a slipstream of said separated methane gas taken as overhead from said separation means.

2. A method in accordance with claim 1, further comprising the step of:

b) expanding said condensed natural gas stream to produce a liquid natural gas product.

3. A method in accordance with claim 2, wherein step b) comprises performing at least one isenthalpic "flash" expansion of said condensed natural gas stream through a Joule-Thomson valve.

4. A method in accordance with claim 2, wherein said compressed residue gas from said cryogenic plant has a pressure of about 100 to 1200 psig and a temperature of about 0 to 400 degrees F.;

wherein said condensed natural gas stream has a pressure of about 100 to 700 psig and a temperature of about -203 to -100 degrees F.; and

wherein said liquid natural gas product has a pressure of about 0 to 100 psig and a temperature of about -259 to -200 degrees F.

5. A method in accordance with claim 2, wherein said compressed residue gas from said cryogenic plant has a pressure of about 300 to 900 psig and a temperature of about 20 to 200 degrees F.;

wherein said condensed natural gas stream has a pressure of about 300 to 700 psig and a temperature of about -159 to -100 degrees F.; and

wherein said liquid natural gas product has a pressure of about 0 to 100 psig and a temperature of about -259 to -200 degrees F.

6. A method in accordance with claim 2, wherein step b) comprises the substeps of:

i) performing a first isenthalpic "flash" expansion of said condensed natural gas stream through a first Joule-Thomson valve to produce a first liquid fraction and first vapor fraction;

ii) performing a second isenthalpic "flash" expansion of said first liquid fraction through a second Joule-Thomson valve to produce a second liquid fraction and a second vapor fraction; and

iii) performing a third isenthalpic "flash" expansion of said second liquid fraction through a third Joule-Thomson valve to produce a liquid natural gas product and a third vapor fraction.

7. A method in accordance with claim 4 wherein said gas from the overhead of said separation means has a temperature of about -200 to -100 degrees F.

8. A method for liquifying a natural gas stream in accordance with claim 6 wherein at least a portion of at least one of said first vapor fraction, said second vapor fraction, and said third vapor fraction is routed to said heat exchanger for use as an auxilliary cooling medium for providing cooling to said natural gas stream.

9. A method in accordance with claim 8, wherein said compressed residue gas from said cryogenic plant has a pressure of about 100 to 1200 psig and a temperature of about 0 to 400 degrees F.;

wherein said condensed natural gas stream has a pressure of about 100 to 700 psig and a temperature of about -203 to -100 degrees F.; and

wherein said liquid natural gas product has a pressure of about 0 to 100 psig and a temperature of about -259 to -200 degrees F.

10. A method in accordance with claim 8, wherein said compressed residue gas from said cryogenic plant has a pressure of about 300 to 900 psig and a temperature of about 20 to 200 degrees F.;

wherein said condensed natural gas stream has a pressure of about 300 to 700 psig and a temperature of about -159 to -100 degrees F.; and

wherein said liquid natural gas product has a pressure of about 0 to 100 psig and a temperature of about -259 to -200 degrees F.

11. A method in accordance with claim 8 wherein said gas from the overhead of said separation means has a temperature of about -200 to -100 degrees F.

12. A process for producing liquid natural gas comprising the steps of:

a) cooling a natural gas feedstock with a cooling means to obtain a cooled liquid/gas mixture;

b) separating said cooled liquid/gas mixture in a separation means to obtain a gas fraction comprising primarily methane and a liquid fraction comprising primarily ethane and heavier hydrocarbons;

c) compressing said gas fraction to obtain a compressed gas fraction; and

d) condensing at least a part of said compressed gas fraction via heat exchange with at least a portion of the gas fraction taken from said separation means, to obtain a liquified natural gas fraction;

wherein said natural gas feedstock consists primarily of natural gas in gaseous form.

13. A process in accordance with claim 12, further comprising the step of:

e) expanding said liquified natural gas fraction to reduce the temperature and pressure of said liquified natural gas fraction.

14. The process of claim 13, wherein said separation means comprises a demethanizer and wherein said gas fraction taken from said separation means comprises overhead gasses from said demethanizer.

15. The process of claim 13, wherein said separation means comprises an expander outlet separator and a demethanizer and wherein said gas fraction taken from said separation means comprises overhead gasses from said demethanizer and said expander outlet separator.

16. The process of claim 13, wherein said separation means comprises an expander outlet separator and a demethanizer and wherein said gas fraction taken from said separation means comprises overhead gasses from said demethanizer.

17. A process for producing liquid natural gas comprising the steps of:

a) cooling a natural gas feedstock with a cooling means to obtain a cooled liquid/gas mixture;

b) separating said cooled liquid/gas mixture in a separation means to obtain a gas fraction comprising primarily methane and a liquid fraction comprising primarily ethane and heavier hydrocarbons and a small amount of methane;

c) recovering methane from said liquid fraction with a fractionation means;

d) combining said gas fraction and said methane recovered from said liquid fraction to form a residue gas;

e) compressing said residue gas to obtain a compressed gas fraction;

f) cooling at least a part of said compressed gas fraction via heat exchange with at least a portion of said residue gas to obtain a liquified natural gas/fraction; and

g) expanding said liquified natural gas fraction to reduce the temperature and pressure of said liquified natural gas fraction to produce a liquid natural gas product.

18. A process in accordance with claim 17 wherein said fractionation means comprises a demethanizer.

19. A process in accordance with claim 18 wherein said separation means is a liquid/gas separator.

20. A method in accordance with claim 17 wherein said compressed gas fraction has a pressure of about 100 to 1200 psig and a temperature of about 0 to 400 degrees F.;

wherein said residue gas has a pressure of about 100 to 600 psig and a temperature of about -200 to -100 degrees F.;

wherein said liquified natural gas fraction has a pressure of about 100 to 700 psig and a temperature of about -203 to -100 degrees F.; and

wherein said liquid natural gas product has a pressure of about 0 to 100 psig and a temperature of about -259 to -200 degrees F.

21. A method in accordance with claim 17 wherein said compressed gas fraction has a pressure of about 300 to 900 psig and a temperature of about 20 to 200 degrees F.;

wherein said residue gas has a pressure of about 100 to 600 psig and a temperature of about -200 to -100 degrees F.;

wherein said liquified natural gas fraction has a pressure of about 300 to 700 psig and a temperature of about -159 to -100 degrees F.; and

wherein said liquid natural gas product has a pressure of about 0 to 100 psig and a temperature of about -259 to -200 degrees F.

22. A process for producing liquid natural gas comprising the steps of:

a) cooling a natural gas feedstock with a cooling means to obtain a cooled liquid/gas stream;

b) separating said cooled liquid/gas stream into a gaseous fraction and a liquid fraction in an expander inlet separator;

c) performing a first expansion of said gaseous fraction to obtain an expanded gaseous/fraction;

d) introducing said expanded gaseous fraction to a demethanizer;

e) introducing said liquid fraction to said demethanizer;

f) dividing the overhead gasses from said demethanizer into a slipstream and a mainstream;

g) routing said slipstream through a residue gas condenser as a cooling medium;

h) recombining said slipstream and said mainstream to form a residue gas stream;

i) compressing said residue gas stream to obtain a compressed residue gas stream;

j) cooling said compressed residue gas stream to obtain a cooled, compressed gas stream;

k) further cooling at least a part of said cooled, compressed residue gas stream in said residue gas condenser to obtain a condensed residue gas stream; and

l) performing a second expansion of said condensed residue gas stream to obtain a liquid natural gas product and a flash vapor fraction.

23. A process in accordance with claim 22, wherein at least a portion of said flash vapor fraction is routed to said residue gas condenser as a coolant.

24. A process in accordance with claim 22, wherein distribution of overhead gas from said demethanizer between said slipstream and said mainstream is regulated by a valve;

and wherein the opening of said valve is controlled such that the flow of slipstream gas in said residue gas condenser is sufficient to maintain said condensed residue gas stream at a constant temperature.

25. A process in accordance with claim 22, wherein distribution of demethanizer overhead gas from said demethanizer between said slipstream and said mainstream is regulated by a valve;

and wherein the opening of said valve is controlled such that the flow of slipstream gas in said residue gas condenser is sufficient to maintain said condensed residue gas stream at the bubble point of said residue gas stream.

26. A process in accordance with claim 22, wherein distribution of overhead gas from said demethanizer between said slipstream and said mainstream is regulated by a valve;

and wherein the opening of said valve is controlled such that the flow of slipstream gas in said residue gas condenser is sufficient to maintain said condensed residue gas stream at a temperature below the bubble point of said residue gas stream.

27. A process in accordance with claim 22 wherein said first expansion comprises isentropic expansion in a turboexpander and said second expansion comprises isenthalpic expansion through at least one Joule-Thomson valve.

28. A process in accordance with claim 22 wherein said first expansion comprises isenthalpic expansion through at least one Joule-Thomson valve and said second expansion comprises isenthalpic expansion through at least one Joule-Thomson valve.

29. A process in accordance with claim 22 wherein said first expansion comprises isenthalpic expansion through at least one Joule-Thompson valve and said second expansion comprises isentropic expansion in a turboexpander.

30. A process in accordance with claim 22 wherein said first expansion comprises isentropic expansion in a turboexpander and said second expansion comprises isentropic expansion in a turboexpander.

31. A process in accordance with claim 22 wherein said cooled, compressed residue gas is at a pressure of about 100 to 680 psig and a temperature of about 0 to 400 degrees Fahrenheit;

and wherein said condensed residue gas stream is at a temperature of about -203 to -100 degrees Fahrenheit and a pressure of about 100 to 700 psig.

32. A process in accordance with claim 22 wherein said cooled, compressed residue gas is at a pressure of about 300 to 900 psig and a temperature of about 20 to 200 degrees Fahrenheit;

and wherein said condensed residue gas stream is at a temperature of about -159 to -100 degrees Fahrenheit and a pressure of about 300 to 700 psig.

33. A process in accordance in accordance with claim 22 wherein said slipstream has a temperature of about -200 to -100 degrees Fahrenheit.

34. A process in accordance with claim 22 wherein said first expansion comprises isentropic expansion in a turboexpander and wherein said second expansion comprises the following steps:

i) a first isenthalpic expansion of said condensed residue gas stream through a first Joule-Thomson valve into a first flash chamber, forming thereby a first liquid fraction and a first gaseous fraction;

ii) a second isenthalpic expansion of said first liquid fraction through a second Joule-Thomson valve into a second flash chamber, forming thereby a second liquid fraction and a second gaseous fraction; and

iii) a third isenthalpic expansion of said second liquid fraction through a third Joule-Thomson valve into a liquid natural gas storage tank, forming thereby a liquid natural gas product and a third gaseous fraction.

35. A process in accordance with claim 31 wherein said slipstream has a temperature of about -200 to -100 degrees F.

36. A process in accordance with claim 32 wherein said slipstream has a temperature of about -200 to -100 degrees F.

37. A process in accordance with claim 34 wherein said process is carried out at least in part in a cryogenic plant, wherein said first liquid fraction has a pressure which is the same as the high pressure fuel line of said cryogenic plant and wherein said second liquid fraction has a pressure which is the same as the low pressure fuel line of said cryogenic plant.

38. A process for producing liquid natural gas comprising the steps of:

a) cooling a natural gas feedstock with a cooling means to obtain a cooled liquid/gas stream;

b) separating said cooled liquid/gas stream into a gaseous fraction and a liquid fraction in an expander inlet separator;

c) performing a first expansion of said gaseous fraction to obtain an expanded gaseous fraction;

d) introducing said expanded gaseous fraction to a demethanizer;

e) introducing said liquid fraction to said demethanizer;

f) fractionating said expanded gaseous fraction and said liquid fraction in said demethanizer to obtain an overhead stream comprising primarily methane in gaseous form and a bottoms stream comprising liquid ethane and heavier hydrocarbons;

g) dividing said overhead stream into a slipstream and a mainstream;

h) routing said slipstream through a residue gas condenser as a cooling medium;

i) recombining said slipstream and said mainstream to form a residue gas stream;

j) compressing said residue gas stream to obtain a compressed residue gas stream;

k) cooling said compressed residue gas stream to obtain a cooled, compressed gas stream;

l) cooling at least part of said cooled, compressed residue gas stream in said residue gas condenser to obtain a condensed residue gas stream; and

m) performing a second expansion of said condensed residue gas stream to obtain a liquid natural gas product and a flash vapor fraction.

39. A process in accordance with claim 38, wherein said overhead stream has a temperature of about -200 to -100 degrees F., and a pressure of about 100 to 600 psig, wherein said compressed residue gas has a temperature of 0 to 400 degrees F., and a pressure of 100 to 1200 psig;

and wherein said liquid natural gas product has a temperature of -259 to -200 degrees F., and a pressure of 0 to 100 psig.

40. A process in accordance with claim 38, wherein said overhead stream has a temperature of -200 to -100 degrees F., and a pressure of 100 to 600 psig;

wherein said compressed residue gas has a temperature of 20 to 200 degrees F., and a pressure of 300 to 900 psig; and

wherein said liquid natural gas product has a temperature of -259 to -200 degrees F., and a pressure of about 0 to about 100 psig.

41. A process in accordance with claim 38, wherein said cooled, compressed gas stream is sub-cooled to produce a condensed residue gas stream which has been cooled to below its bubble point.

42. A process in accordance with claim 38, wherein said second expansion comprises the following steps:

i) a first isenthalpic expansion comprising expansion of said condensed residue gas stream through a first Joule-Thomson valve into a first flash chamber, forming thereby a first liquid fraction and a first gaseous fraction;

ii) a second isenthalpic expansion of said first liquid fraction through a second Joule-Thomson valve into a second flash chamber, forming thereby a second liquid fraction and a second gaseous fraction; and

iii) a third isenthalpic expansion of said second liquid fraction through a third Joule-Thomson valve into a liquid natural gas storage tank, forming thereby a liquid natural gas product and a third gaseous fraction.

43. A process in accordance with claim 42, wherein at least a portion of at least one of said first gaseous fraction, said second gaseous fraction, and said third gaseous fraction, is returned to said residue gas condenser to serve as an auxiliary cooling medium.

44. A process in accordance with claim 42, wherein at least a portion of at least one of said first liquid fraction, said second liquid fraction, and said liquid natural gas product is returned to said residue gas condenser to serve as auxiliary cooling medium.

45. An apparatus for liquifying a natural gas stream, comprising:

a) a heat exchanger;

wherein the natural gas stream comprises compressed residue gas from a cryogenic plant;

wherein said cryogenic plant utilizes a separation means;

wherein cooling is provided in said heat exchanger by a slipstream of gas taken from the overhead of said separation means; and

wherein the cooling provided by said heat exchanger is sufficient to condense said natural gas stream to produce a liquid natural gas stream.

46. An apparatus in accordance with claim 45, further comprising:

b) an expansion means;

wherein the pressure and temperature of said liquid natural gas stream are reduced to a level suitable for storage and transportation by expansion of said condensed natural gas stream in said expansion means.

47. An apparatus as in claim 46 wherein said expansion means comprises at least one Joule-Thomson valve.

48. An apparatus in accordance with claim 46, wherein said expansion means comprises a turboexpander.

49. An apparatus in accordance with claim 46 wherein said expansion means comprises:

i) a first Joule-Thomson valve;

ii) a first flash chamber;

iii) a second Joule-Thomson valve;

iv) a second flash chamber;

v) a third Joule-Thomson valve; and

vi) a liquid natural gas storage tank;

wherein said compressed natural gas stream is expanded into said first flash chamber through said first Joule-Thomson valve to produce a first liquid fraction and a first gaseous fraction;

wherein said first liquid fraction is expanded into said second flash chamber through said second Joule-Thomson valve to produce a second liquid fraction and a second gaseous fraction; and

wherein said second liquid fraction is expanded into said liquid natural gas storage tank through said third Joule-Thomson valve to produce a liquid natural gas product and a third gaseous fraction.

50. An apparatus in accordance with claim 49 wherein said heat exchanger has multiple flow channels to accomodate said natural gas stream, said slipstream of gas taken from the overhead of said separation means and at least one supplementary cooling medium stream.

51. An apparatus for producing liquid natural gas comprising:

a) a cooling means;

b) a separation means;

c) a compression means;

d) a heat exchanger; and

e) an expansion means;

wherein a natural gas feedstock is cooled in said cooling means to produce a cooled liquid/gas mixture;

wherein said cooled liquid/gas mixture is separated in said separation means into a gas fraction comprising primarily methane and a liquid fraction comprising primarily ethane and heavier hydrocarbons;

wherein at least a portion of said gas fraction is routed through said heat exchanger where it serves as a cooling medium, and subsequently through said compression means where it is compressed to form a compressed gas fraction;

wherein said compressed gas fraction is cooled in said heat exchanger such that it is condensed to a liquid; and

wherein said liquid is expanded in said expansion means, thereby reducing the temperature and pressure of said liquid, to form a liquid natural gas product.

52. An apparatus in accordance with claim 51 wherein said expansion means comprises at least one Joule-Thomson valve.

53. An apparatus in a accordance with claim 51 wherein said expansion means comprises a turboexpander.

54. An apparatus in a accordance with claim 51 wherein said expansion means comprises:

i) a first Joule-Thomson valve;

ii) a first flash chamber;

iii) a second Joule-Thomson valve;

iv) a second flash chamber;

v) a third Joule-Thomson valve; and

vi) a liquid natural gas storage tank;

wherein said compressed natural gas stream is expanded into said first flash chamber through said first Joule-Thomson valve to produce a first liquid fraction and a first gaseous fraction;

wherein said first liquid fraction is expanded into said second flash chamber through said second Joule-Thomson valve to produce a second liquid fraction and a second gaseous fraction; and

wherein said second liquid fraction is expanded into said liquid natural gas storage tank through said third Joule-Thomson valve to produce a liquid natural gas product and a third gaseous fraction.

55. An apparatus for producing liquid natural gas:

a) a cooling means;

b) a liquid/gas separator;

c) a first expansion means;

d) a demethanizer;

e) a compression means;

g) a residue gas condenser; and

h) a second expansion means;

wherein a natural gas feedstock is cooled in said cooling means to produce a cooled liquid/gas mixture;

wherein said cooled liquid/gas mixture is separated in said liquid/gas separator into a first gas fraction and a first liquid fraction;

wherein said gas fraction is expanded in said first expansion means to form a second liquid/gas mixture;

wherein said first liquid fraction and said liquid/gas mixture are introduced to said demethanizer, in which they are fractionated to obtain an overhead gas comprising primarily methane and a bottoms stream comprising primarily liquid ethane and heavier hydrocarbons;

wherein at least a portion of said overhead gas is routed through said heat exchanger where it serves as a cooling medium, and subsequently through said compression means where it is compressed to form a compressed gas fraction;

wherein said compressed gas fraction is cooled in said heat exchanger such that it is condensed to a liquid; and

wherein said liquid is expanded in said expansion means, thereby reducing the temperature and pressure of said liquid, to form a liquid natural gas product.

56. An apparatus in accordance with claim 55 wherein said expansion means comprises at least one Joule-Thomson valve.

57. An apparatus in a accordance with claim 55 wherein said expansion means comprises a turboexpander.

58. An apparatus in a accordance with claim 55 wherein said expansion means comprises:

i) first Joule-Thomson valve;

ii) a first flash chamber;

iii) a second Joule-Thomson valve;

iv) a second flash chamber;

v) a third Joule-Thomson valve; and

vi) a liquid natural gas storage tank;

wherein said compressed natural gas stream is expanded into said first flash chamber through said first Joule-Thomson valve to produce a first liquid fraction and a first gaseous fraction;

wherein said first liquid fraction is expanded into said second flash chamber through said second Joule-Thomson valve to produce a second liquid fraction and a second gaseous fraction; and

wherein said second liquid fraction is expanded into said liquid natural gas storage tank through said third Joule-Thomson valve to produce a liquid natural gas product and a third gaseous fraction.

59. An apparatus in accordance with claim 55 wherein said heat exchanger has multiple flow channels to accomodate said natural gas stream, said slipstream of gas taken from the overhead of said separation means and at least one supplementary cooling medium stream.