LNG vapor handling configurations and methods

• US 8,117,852 B2
• Filed: 04/13/2007
• Issued: 02/21/2012
• Est. Priority Date: 04/13/2006
• Status: Expired due to Fees

• Current Assignee: Fluor Technologies Corporation (Fluor Corporation)
• Original Assignee: Fluor Technologies Corporation (Fluor Corporation)
• Inventors: Mak, John
• Primary Examiner(s): Swann, Judy
• Assistant Examiner(s): Ghosh, Indrajit
• Application Number:
  US12/281,464
• Publication Number:
  US 20090217676A1
• Time in Patent Office: 1,775 Days
• Field of Search: 62/451, 62/481, 62/501, 62/532, 622/40, 626/11, 626/13
• US Class Current: 62/48.1
• CPC Class Codes: F17C 2205/0364 flexible or articulated, e.g. a hose
• CPC Class Codes: F17C 2205/0367 Arrangements in parallel
• CPC Class Codes: F17C 2221/033 Methane, e.g. natural gas, CNG, LNG, GNL, GNC, PLNG
• CPC Class Codes: F17C 2223/0161 cryogenic, e.g. LNG, GNL, PLNG
• CPC Class Codes: F17C 2223/0169 subcooled
• CPC Class Codes: F17C 2223/033 Small pressure, e.g. for liquefied gas
• CPC Class Codes: F17C 2223/035 High pressure (>10 bar)
• CPC Class Codes: F17C 2223/046 in the liquid
• CPC Class Codes: F17C 2225/0123 gaseous, e.g. CNG, GNC
• CPC Class Codes: F17C 2225/0161 cryogenic, e.g. LNG, GNL, PLNG
• CPC Class Codes: F17C 2225/033 Small pressure, e.g. for liquefied gas
• CPC Class Codes: F17C 2227/0135 Pumps
• CPC Class Codes: F17C 2227/0178 in the vessel
• CPC Class Codes: F17C 2227/0302 by heating
• CPC Class Codes: F17C 2227/0339 using the same fluid
• CPC Class Codes: F17C 2227/0388 separate
• CPC Class Codes: F17C 2227/0393 using a vaporiser
• CPC Class Codes: F17C 2260/023 Avoiding overheating
• CPC Class Codes: F17C 2265/017 different phases of a same fluid
• CPC Class Codes: F17C 2265/032 by recovery
• CPC Class Codes: F17C 2265/034 : with condensing the gas phase
• CPC Class Codes: F17C 2265/037 : with pressurising
• CPC Class Codes: F17C 2265/05 : Regasification
• CPC Class Codes: F17C 2270/0105 : Ships
• CPC Class Codes: F17C 2270/0136 : Terminals
• CPC Class Codes: F17C 6/00 : Methods and apparatus for filling vessels not under pressure with liquefied or solidified gases
• CPC Class Codes: F17C 9/00 : Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure

Abstract

LNG from a carrier is unloaded to an LNG storage tank in configurations and methods in which expansion of compressed and condensed boil-off vapors from the LNG storage tank provide refrigeration to subcool the LNG that is being unloaded. Most advantageously, such configuration and methods reduce the amount of boil-off vapors and eliminate the need for a vapor return line and associated compressor.

Claims

1. An unloading plant for transfer of LNG from an LNG carrier to an LNG storage tank comprising:

a compressor configured to receive and compress boil-off from the LNG storage tank;

a condenser or absorber configured to receive compressed boil-off from the compressor and a sendout LNG stream from the LNG storage tank to thereby produce a saturated liquid stream that is composed of the sendout LNG stream and compressed boil-off condensed therein;

a pressure reduction device configured to reduce pressure of a portion of the saturated liquid stream; and

an exchanger that is configured to subcool the LNG coming from the LNG carrier using refrigeration content of the portion after the pressure of the portion has been reduced.

2. The unloading plant of claim 1 further comprising a separator fluidly coupled to and downstream of the exchanger and configured to separate a vapor phase and a liquid phase from the portion.

3. The unloading plant of claim 2 further comprising a return line that is configured to feed the vapor phase to the LNG carrier.

4. The unloading plant of claim 2 further comprising a pump that is configured to pump the liquid phase to the LNG storage tank.

5. A plant comprising:

an LNG source configured to provide an LNG stream to an LNG storage tank that is configured to provide a sendout LNG and an LNG vapor;

a compressor configured to compress the LNG vapor;

a condenser or absorber fluidly coupled to the LNG storage tank and configured to receive the compressed LNG vapor and to provide a pressurized saturated liquid stream that is composed of the sendout LNG and LNG vapor condensed therein;

a pressure reduction device configured to reduce pressure of a portion of the pressurized saturated liquid stream; and

a heat exchanger that is configured to subcool the LNG stream using the portion of the depressurized saturated liquid stream from the pressure reduction device.

6. The plant of claim 5 wherein the pressure reduction device is configured to cool by reduction of pressure of the pressurized saturated liquid stream to a temperature that is lower than the temperature of the unloaded LNG source.

7. The plant of claim 5 further comprising a separator that is located downstream of the heat exchanger and that is configured to receive the depressurized heated saturated liquid stream and to provide a vapor and liquid.

8. The plant of claim 7 further comprising a return arm that is configured to deliver the vapor from the separator to the LNG source, and further comprising a pump that is configured to pump the liquid to the LNG storage tank.

9. A method of transferring an LNG stream from an LNG source comprising:

compressing boil-off from an LNG storage tank;

receiving the compressed boil-off and a sendout LNG stream from the LNG storage tank in a condenser or absorber to form a pressurized saturated liquid stream that is composed of the sendout LNG stream and boil-off condensed therein;

depressurizing a portion of the pressurized saturated liquid stream; and

cooling the LNG stream using a heat exchanger which receives refrigeration content from the portion of the depressurized saturated liquid stream.

10. The method of claim 9 wherein the depressurized LNG saturated liquid stream is heated in the heat exchanger and then separated into a vapor portion and a liquid portion.

11. The method of claim 10 wherein the liquid portion is fed to the LNG storage tank.

12. The method of claim 10 wherein the vapor portion is fed to the LNG source.

13. The method of claim 9 wherein the LNG stream is subcooled at least 1°

F.

14. The method of claim 9 wherein another portion of the pressurized saturated liquid stream is combined with sendout LNG upstream of a vaporizer.

15. The method of claim 9 wherein the LNG source is an LNG carrier.