Process control systems and methods for simultaneous crude oil dehydration, desalting, sweetening, and stabilization

Patent metadata

Field	Value
Publication number	US-11760946-B2
Application number	US-202117330091-A
Country	US
Kind code	B2
Filing date	May 25, 2021
Priority date	May 25, 2021
Publication date	Sep 19, 2023
Grant date	Sep 19, 2023

Abstract

Systems and methods for controlling desalting and dehydration of crude oil, one method including monitoring total dissolved solids (TDS) content at an outlet stream from a crude oil separation unit, the outlet stream comprising water; monitoring basic sediment and water (BS&W) content at an outlet stream from the crude oil separation unit, the outlet stream comprising processed crude oil; determining pounds per thousand barrels (PTB) salt content and volumetric water content of a dried, desalted crude oil product stream using the TDS content and BS&W content; and controlling a process input to the method from a comparison between the PTB salt content and volumetric water content of the dried, desalted crude oil product stream versus a maximum set value for PTB salt content and volumetric water content of the dried, desalted crude oil product stream.

First claim

What is claimed is:

1. A method for controlling desalting and dehydration of crude oil, the method comprising the steps of:
monitoring total dissolved solids (TDS) content at an outlet stream from a crude oil separation unit, the outlet stream comprising water;
monitoring basic sediment and water (BS&W) content at an outlet stream from the crude oil separation unit, the outlet stream comprising dried, desalted processed crude oil;
determining pounds per thousand barrels (PTB) salt content and volumetric water content of the dried, desalted processed crude oil in the outlet stream using the TDS content and BS&W content; and
controlling a process input to the crude oil separation unit based on a comparison between the PTB salt content and volumetric water content of the dried, desalted processed crude oil in the outlet stream versus a maximum set value for PTB salt content and volumetric water content of the dried, desalted processed crude oil, where the controlled process input is selected from the group consisting of: chemical demulsifier injection rate; wash water injection rate; inlet crude oil heating; a pressure drop for mixing preceding the crude oil separation unit; current supply to the crude oil separation unit; inlet crude oil flow rate for processing; outlet crude oil flow rate of the dried, desalted processed crude oil in the outlet stream; crude oil separation unit residence time; crude oil separation unit emulsion level; crude oil separation unit water level; and combinations thereof.

2. The method according to claim 1 , wherein the outlet stream comprising water comprises a bottoms stream from a water-oil emulsion separation unit.

3. The method according to claim 1 , wherein the outlet stream comprising the dried, desalted processed crude oil comprises a top product stream from a water-oil emulsion separation unit.

4. The method according to claim 1 , wherein the step of determining the PTB salt content comprises applying Equation 1 with the TDS content and BS&W content.

5. The method according to claim 1 , further comprising the step of monitoring current and voltage supplied to an electric grid of the crude oil separation unit to control removal of an oil-water emulsion proximate an oil-water interface of the crude oil separation unit.

6. The method according to claim 5 , further comprising the step of monitoring current and voltage supplied to the electric grid of the crude oil separation unit to control removal of water via a water drain of the crude oil separation unit.

7. The method according to claim 6 , wherein when electric current supplied to the electric grid is at between 0% to about 50% of a set, maximum current value, removal of the oil-water emulsion proximate the oil-water interface of the crude oil separation unit proceeds for recycle of the oil-water emulsion to the crude oil separation unit.

8. The method according to claim 6 , wherein when electric current supplied to the electric grid is at between about 50% to about 100% of a set, maximum current value, removal of water via the water drain of the crude oil separation unit proceeds.

9. The method according to claim 6 , further comprising the steps of monitoring the water level of the crude oil separation unit or the oil-water emulsion level of the crude oil separation unit and controlling the water drain of the crude oil separation unit using the monitored water level or monitored emulsion level.

10. The method according to claim 1 , wherein the maximum set value for PTB salt content is about 10 PTB and the maximum set value for volumetric water content is about 0.3 volume percent for the dried, desalted processed crude oil in the outlet stream.

11. The method according to claim 1 , where the step of controlling includes the application of a controller selected from the group consisting of: a distributed control system; a multivariable controller; a multivariable predictive controller; and combinations thereof.

12. The method according to claim 1 , further comprising the steps of monitoring water content and TDS of inlet crude oil for processing in the crude oil separation unit.

13. The method according to claim 1 , further comprising the step of monitoring current and voltage supplied to an electric grid of an inline electrostatic emulsion breaker unit.

14. The method according to claim 13 , wherein when electric current supplied to the electric grid of the inline electrostatic emulsion breaker is at between 0% to about 50% of a set, maximum current value, removal of an oil-water emulsion proximate an oil-water interface of the crude oil separation unit proceeds for recycle of the oil-water emulsion to the crude oil separation unit through the inline electrostatic emulsion breaker.

15. The method according to claim 13 , wherein when electric current supplied to the electric grid of the inline electrostatic emulsion breaker is at between about 50% to about 100% of a set, maximum current value, removal of water via a water drain of the crude oil separation unit proceeds.

16. The method according to claim 15 , further comprising the step of monitoring BS&W content at an inlet of the inline electrostatic emulsion breaker.

17. The method according to claim 1 , wherein the step of monitoring TDS content comprises monitoring TDS content following a first stage desalter and a second stage desalter, wherein the step of monitoring BS&W content comprises monitoring BS&W content following the first stage desalter and the second stage desalter, and wherein the step of determining PTB salt content and volumetric water content of the dried, desalted processed crude oil occurs following both the first stage desalter and second stage desalter.

18. The method according to claim 17 , further comprising the steps of recycling an emulsion layer from the first stage desalter through a first inline electrostatic emulsion breaker back to the first stage desalter and recycling an emulsion layer from the second stage desalter through a second inline electrostatic emulsion breaker back to the first stage desalter.

19. The method according to claim 18 , further comprising the steps of monitoring the current and voltage supplied to the first stage desalter, second stage desalter, first inline electrostatic emulsion breaker, and second stage inline emulsion breaker to control the recycle of the emulsion layers and to control water drained from the first stage desalter and second stage desalter via a water drain.

Assignees

• Saudi Arabian Oil Co

Inventors

• Soliman Mohamed

Classifications

• C10G53/02 Primary

  plural serial stages only · CPC title

• G01N33/2847

  Water in oils · CPC title

• C02F2103/10

  from quarries or from mining activities · CPC title

• C02F2209/10

  Solids, e.g. total solids [TS], total suspended solids [TSS] or volatile solids [VS] · CPC title

• C02F2209/02

  Temperature · CPC title