Low pressure NGL plant configurations

• US 7,713,497 B2
• Filed: 08/15/2002
• Issued: 05/11/2010
• Est. Priority Date: 08/15/2002
• Status: Expired due to Fees

• Current Assignee: Fluor Enterprises Incorporated (Fluor Corporation)
• Original Assignee: Fluor Technologies Corporation (Fluor Corporation)
• Inventors: Mak, John
• Primary Examiner(s): Griffin; Walter D
• Assistant Examiner(s): YOUNG, NATASHA E
• Application Number:
  US10/528,435
• Publication Number:
  US 20050255012A1
• Time in Patent Office: 2,826 Days
• Field of Search: 422/187, 422/211, 626/36, 626/25, 62611-613, 62617-623, 626/34
• US Class Current: 422/187
• 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 2200/30 using a side column in a single pressure 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 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 2245/02 Recycle of a stream in general, e.g. a by-pass stream
• CPC Class Codes: F25J 2270/02 Internal refrigeration with liquid vaporising loop
• CPC Class Codes: F25J 2270/12 External refrigeration with liquid vaporising 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 2290/10 Mathematical formulae, modeling, plot or curves; Design methods
• CPC Class Codes: F25J 2290/40 Vertical layout or arrangement of cold equipments within in the cold box, e.g. columns, condensers, heat exchangers etc.
• 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 natural gas liquid plant includes a separator (103) that receives a cooled low pressure feed gas (4), wherein the separator (103) is coupled to an absorber (108) and a demethanizer (110). Refrigeration duty of the absorber (108) and demethanizer (110) are provided at least in part by expansion of a liquid portion of the cooled low pressure feed gas (4) and an expansion of a liquid absorber bottom product (19), wherein ethane recovery is at least 85 mol % and propane recovery is at least 99 mol %. Contemplated configurations are especially advantageous as upgrades to existing plants with low pressure feed gas where high ethane recovery is desirable.

Claims

1. A natural gas liquid plant, comprising:

a separator that is configured to allow separation of a cooled low pressure feed gas having a feed gas pressure of at or below 1100 psig into a liquid portion and a vapor portion, and a first pressure reduction device that is configured to receive the liquid portion and to allow reduction of pressure of the liquid portion to provide refrigeration for a first cooler that is fluidly coupled to the separator and that is configured to allow cooling of a low pressure feed gas to thereby allow formation of the cooled low pressure feed gas;

a second cooler and a second pressure reduction device fluidly coupled to the separator, wherein the second cooler is configured to allow cooling of at least part of the vapor portion, and wherein the second pressure reduction device is configured to reduce pressure of the part of the vapor portion to a degree effective to provide the part of the vapor portion to an absorber as lean absorber reflux; and

wherein the absorber is configured to produce an absorber overhead product to thereby provide refrigeration for the second cooler, and wherein the absorber is further configured to produce an absorber bottoms product, and a demethanizer fluidly coupled to the absorber and configured to receive the absorber bottoms product as lean reflux.

2. The natural gas liquid plant of claim 1 wherein the low pressure feed gas has a pressure of about 300 psig to about 700 psig.

3. The natural gas liquid plant of claim 1 further comprising a plurality of side reboilers that are thermally coupled to the demethanizer and that are configured to cool a portion of the low pressure feed gas.

4. The natural gas liquid plant of claim 1 wherein the first pressure reduction device comprises a hydraulic turbine, and wherein the second pressure reduction device comprises a Joule-Thomson valve.

5. The natural gas liquid plant of claim 1 wherein the demethanizer is configured to receive the liquid portion that is reduced in pressure as a demethanizer feed stream.

6. The natural gas liquid plant of claim 1 further comprising a turboexpander that is configured to allow expansion of part of the vapor portion, and further comprising a second separator that is configured to receive the expanded part of the vapor portion and to produce a liquid that is employed as a lean demethanizer reflux and a vapor that is fed into the absorber.

7. The natural gas liquid plant of claim 1 wherein ethane recovery is at least 85 mol % and propane recovery is at least 99 mol %.

8. A natural gas liquid plant, comprising:

a primary and secondary cooler that are configured to cool a low pressure feed gas having a feed gas pressure of at or below 1100 psig, and a separator that is configured to separate the cooled low pressure feed gas at about feed gas pressure in a liquid portion and a vapor portion;

a first pressure reduction device that is configured to reduce pressure of the liquid portion to thereby provide refrigeration for the secondary cooler;

a third cooler that is configured to cool at least part of the vapor portion, and a pressure reduction device that is configured to expand the cooled vapor portion to form a lean absorber reflux; and

an absorber that is configured to receive the lean absorber reflux and to produce an overhead product that provides refrigeration for the third cooler and a bottom product that is employed as reflux in a demethanizer.

9. The natural gas liquid plant of claim 8 wherein the low pressure feed gas is at least partially dehydrated and has a pressure of between about 300 psig and about 700 psig.

10. The natural gas liquid plant of claim 8 wherein the first pressure reduction device comprises a hydraulic turbine and wherein the second pressure reduction device comprises a Joule-Thomson valve.

11. The natural gas liquid plant of claim 8 further comprising a plurality of side reboilers that are thermally coupled to the demethanizer and that are configured to cool a portion of the low pressure feed gas.

12. The natural gas liquid plant of claim 8 further comprising a turboexpander that is configured to expand part of the vapor portion and a second separator that is fluidly coupled to the turboexpander and that is configured to produce a liquid that is employed as a lean demethanizer reflux and a vapor that is fed into the absorber.

13. The natural gas liquid plant of claim 8 wherein the primary cooler is configured to employ as least one of external ethane, external propane, and the absorber overhead product as a refrigerant.

14. The natural gas liquid plant of claim 8 wherein ethane recovery is at least 85 mol % and propane recovery is at least 99 mol %.

15. A natural gas liquid plant that comprises a separator that is configured to receive a cooled low pressure feed gas having a feed gas pressure of at or below 1100 psig and that is fluidly coupled to an absorber and a demethanizer, wherein the plant is further configured such that refrigeration duty of the absorber and demethanizer are provided at least in part by expansion of a liquid portion of the cooled low pressure feed gas from the feed gas pressure and an expansion of a vapor portion from the feed gas pressure using a device other than a turboexpander, and wherein the demethanizer is configured to receive the expanded liquid portion as demethanizer feed.

16. The natural gas liquid plant of claim 15 further comprising a cooler that is configured to further cool the cooled low pressure feed gas using an expanded liquid portion of the cooled low pressure feed gas as a refrigerant.

17. The natural gas liquid plant of claim 15 wherein the absorber is configured to produce an absorber bottom product that is fed to the demethanizer as reflux.

18. The natural gas liquid plant of claim 15 wherein the separator is configured to separate a vapor portion from the cooled low pressure feed gas and wherein a Joule-Thomson valve is configured to further cool a first part of the vapor portion for introduction into the absorber.

19. The natural gas liquid plant of claim 18 further comprising a turboexpander that is configured to expand and cool a second part of the vapor portion.