Systems and methods for LNG production with propane and ethane recovery

• US 10,330,382 B2
• Filed: 05/18/2016
• Issued: 06/25/2019
• Est. Priority Date: 05/18/2016
• Status: Active Grant

• Current Assignee: Fluor Technologies Corporation (Fluor Corporation)
• Original Assignee: Fluor Technologies Corporation (Fluor Corporation)
• Inventors: Mak, John, Thomas, Jacob, Graham, Curt
• Primary Examiner(s): Alosh, Tareq
• Application Number:
  US15/158,143
• Publication Number:
  US 20170336137A1
• Time in Patent Office: 1,133 Days
• 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 1/0052 by vaporising a liquid refrigerant stream
• CPC Class Codes: F25J 1/0055 originating from an incorporated cascade
• CPC Class Codes: F25J 1/0212 as a single flow MCR cycle
• CPC Class Codes: F25J 1/0216 using a C3 pre-cooling cycle
• CPC Class Codes: F25J 1/0228 Coupling of the liquefaction unit to other units or processes, so-called integrated processes combined plants, e.g. engine plant combined with an industrial process F01K23/064; gas turbine plants in combination with other processes F02C6/00
• CPC Class Codes: F25J 1/0239 Purification or treatment step being integrated between two refrigeration cycles of a refrigeration cascade, i.e. first cycle providing feed gas cooling and second cycle providing overhead gas cooling
• CPC Class Codes: F25J 1/0291 Refrigerant compression by combined gas compression and liquid pumping
• CPC Class Codes: F25J 1/0292 Refrigerant compression by cold or cryogenic suction of the refrigerant gas
• CPC Class Codes: F25J 2200/02 in a single pressure main column system
• CPC Class Codes: F25J 2200/04 in a dual pressure main column system
• CPC Class Codes: F25J 2200/08 in a triple 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 2200/76 Refluxing the column with condensed overhead gas being cycled in a quasi-closed loop refrigeration cycle
• CPC Class Codes: F25J 2200/78 Refluxing the column with a liquid stream originating from an upstream or downstream fractionator column
• CPC Class Codes: F25J 2205/50 using absorption, i.e. with selective solvents or lean oil, heavier CnHm and including generally a regeneration step for the solvent or lean oil
• CPC Class Codes: F25J 2210/06 Splitting of the feed stream, e.g. for treating or cooling in different ways
• CPC Class Codes: F25J 2215/04 Recovery of liquid products
• CPC Class Codes: F25J 2215/60 : Methane
• CPC Class Codes: F25J 2215/62 : Ethane or ethylene
• CPC Class Codes: F25J 2215/64 : Propane or propylene
• CPC Class Codes: F25J 2230/30 : Compression of the feed stream
• 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 2260/20 : Integration in an installation for liquefying or solidifying a fluid stream
• CPC Class Codes: F25J 2270/12 : External refrigeration with liquid vaporising loop
• CPC Class Codes: F25J 2270/18 : External refrigeration with incorporated cascade loop
• CPC Class Codes: F25J 2270/60 : Closed external refrigeration cycle with single component refrigerant [SCR], e.g. C1-, C2- or C3-hydrocarbons
• CPC Class Codes: F25J 2270/66 : Closed external refrigeration cycle with multi component refrigerant [MCR], e.g. mixture of hydrocarbons
• 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
• CPC Class Codes: F25J 3/0242 : separation of CnHm with 3 carbon atoms or more

Abstract

A LNG liquefaction plant includes a propane recovery unit including an inlet for a feed gas, a first outlet for a LPG, and a second outlet for an ethane-rich feed gas, an ethane recovery unit including an inlet coupled to the second outlet for the ethane-rich feed gas, a first outlet for an ethane liquid, and a second outlet for a methane-rich feed gas, and a LNG liquefaction unit including an inlet coupled to the second outlet for the methane-rich feed gas, a refrigerant to cool the methane-rich feed gas, and an outlet for a LNG. The LNG plant may also include a stripper, an absorber, and a separator configured to separate the feed gas into a stripper liquid and an absorber vapor. The stripper liquid can be converted to an overhead stream used as a reflux stream to the absorber.

Claims

1. A LNG liquefaction plant comprising:

a feed stream comprising methane, ethane, and propane;

a propane recovery unit configured to produce LPG and an ethane-rich feed gas from the feed stream;

an ethane recovery unit including;

a compressor configured to compress the ethane-rich feed gas to form a compressed stream, wherein the compressed stream is configured to split into a first portion and a second portion, wherein the first portion of the compressed stream, the second portion of the compressed stream, and the ethane-rich feed gas are each ethane-rich, wherein the compressed stream and the second portion of compressed stream have the same composition;

a demethanizer configured to produce an ethane liquid in an ethane bottom liquid stream and a residue gas in a methane overhead vapor stream, wherein a first portion of the residue gas is configured to flow to the demethanizer as a first reflux stream, wherein a second portion of the residue gas from the demethanizer is a methane-rich feed gas, wherein the first portion of the compressed stream is configured to flow to the demethanizer as a second reflux stream;

a first heat exchanger configured to heat the methane overhead vapor stream, cool the first portion of the residue gas, and cool the first portion of the compressed stream; and

an expander configured to expand the second portion of the compressed stream prior to entering the demethanizer; and

a LNG liquefaction unit configured to receive the methane-rich feed gas, cool the methane-rich feed gas with a refrigerant cycle, and recover LNG from the methane-rich feed gas.

2. The LNG liquefaction plant of claim 1, wherein the propane recovery unit comprises:

a second heat exchanger configured to cool the feed stream to form a cooled feed stream;

a chiller configured to chill the cooled feed stream to form a chilled feed gas;

an absorber configured to separate the chilled feed gas into an absorber bottom stream, a flashed liquid stream, and an absorber overhead vapor stream;

a stripper configured to receive the absorber bottom stream and the flashed liquid stream and to form a stripper overhead stream and a LPG stream containing the LPG, wherein the stripper overhead stream contains ethane and methane,

wherein the second heat exchanger is further configured to heat the absorber overhead stream to form a heated absorber overhead stream,

wherein the heated absorber overhead stream contains the ethane-rich feed gas.

3. The LNG liquefaction plant of claim 2, wherein the stripper overhead stream is configured to be an absorber reflux stream to the absorber, wherein the stripper is configured to receive the absorber bottom stream at a first location above a second location where the stripper receives the flashed liquid stream.

4. The LNG liquefaction plant of claim 3, wherein the propane recovery unit further comprises:

a first pump;

a second pump;

a second chiller; and

a letdown valve,

wherein the first pump is configured to pump the absorber bottom stream to the stripper, wherein the second pump is configured to pump the flashed liquid stream to the stripper,

wherein the second chiller is configured to chill the stripper overhead stream,

wherein the letdown valve is configured to let down in pressure the stripper overhead stream to thereby provide the absorber reflux stream as a two-phase reflux to the absorber.

5. The LNG liquefaction plant of claim 2, wherein the stripper is a non-refluxed stripper.

6. The LNG liquefaction plant of claim 3, wherein the stripper overhead stream is configured to be directed to the absorber as the absorber reflux stream for cooling and reflux in the absorber to recover propane from the chilled feed gas without turbo-expansion, wherein the stripper is configured to operate at least 30 psi higher than the absorber, such that the stripper overhead stream generates Joule Thomson cooling to reflux the absorber.

7. The LNG liquefaction plant of claim 3, wherein 99% of the propane content of the chilled feed gas is recovered as the LPG.

8. The LNG liquefaction plant of claim 1, wherein the first reflux stream and the second reflux stream combine to form a single reflux stream into a top of the demethanizer.

9. The LNG liquefaction plant of claim 1, wherein the ethane recovery unit further comprises a chiller configured to chill the second portion of the compressed stream utilizing propane refrigeration.

10. The LNG liquefaction plant of claim 9, wherein the first reflux stream and the second reflux stream are configured to flow to a top of the demethanizer at a first location above a second location where the second portion of the compressed stream enters the demethanizer.

11. The LNG liquefaction plant of claim 10, wherein 90% of the ethane content of the ethane-rich feed gas is recovered as the ethane liquid.

12. The LNG liquefaction plant of claim 1, wherein the refrigerant cycle is configured to cool and condense the methane-rich feed gas to form the LNG with 95% purity methane, wherein the refrigerant cycle comprises:

a first compressor configured to compress a single mixed refrigerant to form a first compressed stream;

a first separator configured to separate the first compressed stream into a first vapor stream and a first liquid stream;

a second compressor configured to receive and compress the first vapor stream to form a second compressed stream, wherein the second compressed stream and the first liquid stream are combined to form a mixed stream;

a second separator configured to separate the mixed stream into a second vapor stream and a second liquid stream;

an exchanger cold box configured to cool and condense the second vapor stream and the second liquid stream, wherein the second vapor stream and the second liquid stream are combined after exiting the exchanger cold box; and

a let down valve configured to let down a pressure of a stream comprising the combined second vapor stream and second liquid stream to form a let-down stream,

wherein the let-down stream is configured to flow through the exchanger cold box to provide refrigeration for the methane-rich feed gas.

13. The LNG liquefaction plant of claim 1, wherein the feed stream comprises a shale gas supplied at a pressure of 400 to 600 psig.

14. The LNG liquefaction plant of claim 1, wherein the feed stream further comprises heavier hydrocarbons.

15. The LNG liquefaction plant of claim 1, wherein the feed stream is pre-treated to remove carbon dioxide and mercury, and dried in a molecular sieve unit.

16. The LNG liquefaction plant of claim 2, wherein the absorber bottom stream comprises 50 to 70 mol % ethane.

17. The LNG liquefaction plant of claim 1, wherein the refrigerant cycle is configured to provide refrigeration only to the LNG liquefaction unit.

18. The LNG liquefaction plant of claim 1, wherein the feed stream comprises 50 to 80 mol % methane.

19. The LNG liquefaction plant of claim 18, wherein the feed stream further comprises 10 to 30 mol % ethane.

20. The LNG liquefaction plant of claim 1, wherein the feed stream has a liquid content of 5 to 12 GPM.