Removal of kinetic hydrate inhibitors

Patent metadata

Field	Value
Publication number	US-11000779-B2
Application number	US-201816223448-A
Country	US
Kind code	B2
Filing date	Dec 18, 2018
Priority date	Sep 23, 2015
Publication date	May 11, 2021
Grant date	May 11, 2021

Abstract

A method includes receiving a water stream from a hydrocarbon production facility, the water stream having a first concentration of a kinetic hydrate inhibitor (KHI); flowing the water stream through a heat exchanger to heat the water stream to a target temperature; mixing the heated water stream with a treatment chemical to form a two-phase mixture, the treatment chemical having an affinity for the KHI; flowing the two-phase mixture into a separator; and physically separating the two-phase mixture into a first phase and a second phase, the first phase including water and having a second concentration of the KHI less than the first concentration, and the second phase including the KHI and the treatment chemical, the density of the second phase being less than the density of the first phase.

First claim

What is claimed is:

1. A method comprising:
receiving a water stream from a hydrocarbon production facility, the water stream having a first concentration of a kinetic hydrate inhibitor (KHI);
flowing the water stream through a heat exchanger to heat the water stream to a target temperature between about 70° F. and about 160° F.;
mixing the heated water stream with a treatment chemical to form a two-phase mixture, the treatment chemical having an affinity for the KHI;
flowing the two-phase mixture into a separator; and
physically separating the two-phase mixture into a first phase and a second phase, the first phase including water and having a second concentration of the KHI less than the first concentration, and the second phase including the KHI and the treatment chemical, the density of the second phase being less than the density of the first phase.

2. The method of claim 1 , wherein receiving the water stream comprises:
receiving a fluid stream from the hydrocarbon production facility; and
separating the fluid stream into a hydrocarbon stream and the water stream.

3. The method of claim 2 , further comprising separating the fluid stream into the hydrocarbon stream, the water stream, and a gas stream.

4. The method of claim 1 , wherein the received water stream is at a first temperature, and wherein the target temperature is at least 5° F. greater than the first temperature.

5. The method of claim 1 , wherein flowing the water stream through a heat exchanger comprises heating the water stream to a temperature sufficient to cause at least some of the KHI to precipitate from the water stream.

6. The method of claim 1 , wherein mixing the heated water stream with a treatment chemical comprises adding the treatment chemical to the water stream such that a ratio of the treatment chemical to the KHI is between 1 and 3.

7. The method of claim 1 , wherein physically separating the two-phase mixture comprises performing a gravity separation.

8. The method of claim 1 , wherein physically separating the two-phase mixture comprises retaining the two-phase mixture in the separator for between 6 hours and 24 hours.

9. The method of claim 1 , further comprising processing the first phase to remove residual KHI.

10. The method of claim 9 , wherein processing the first phase comprises generating a third phase having a third concentration of KHI, the third concentration being less than the second concentration.

11. The method of claim 1 , further comprising removing the KHI from the second phase.

12. The method of claim 11 , comprising:
adding a condensate to the second phase; and
removing the KHI from the second phase including the condensate.

13. The method of claim 11 , further comprising returning the second phase or KHI separated from the second phase to an upstream destination in the hydrocarbon processing or production facility for reuse.

14. The method of claim 1 , wherein the treatment chemical is substantially immiscible with water.

15. The method of claim 1 , wherein the treatment chemical comprises a functional group that has an affinity for a component of the KHI.

16. The method of claim 1 , wherein the second concentration is at least about 40% less than the first concentration.

17. The method of claim 1 , wherein a cloud point temperature of the first phase is at least 40° C.

18. The method of claim 1 , wherein a fouling temperature of the first phase is at least 90° C.

19. The method of claim 1 , wherein mixing the heated water stream with a treatment chemical comprises mixing the heated water stream, the treatment chemical, and an organic acid.

20. The method of claim 1 , wherein mixing the heated water stream with a treatment chemical comprises mixing the heated water stream, the treatment chemical, and a saline solution.

Assignees

• Saudi Arabian Oil Co

Inventors

• Rithauddeen Megat A
• Al-Adel Shadi I
• Mohammad Ahmad Fadzil

Classifications

• C10G75/04 Primary

  by addition of antifouling agents · CPC title

• C02F2101/30

  Organic compounds · CPC title

• C02F1/02

  by heating (methods of steam generation F22B; preheating boiler feed-water or accumulating preheated boiler feed-water F22D) · CPC title

• B01D17/02

  Separation of non-miscible liquids · CPC title

• B01D11/0457 Primary

  comprising rotating mechanisms, e.g. mixers, mixing pumps · CPC title