Processing of oil by steam addition

Patent metadata

Field	Value
Publication number	US-10370948-B2
Application number	US-201715819616-A
Country	US
Kind code	B2
Filing date	Nov 21, 2017
Priority date	Nov 21, 2017
Publication date	Aug 6, 2019
Grant date	Aug 6, 2019

Abstract

The invention relates to injecting steam into crude oil for several benefits, primarily of which is to remove salt by transferring the salt into the condensed water from the steam. Steam transfers salt via a different transfer mechanism and therefore doesn't require the high shear mixing of conventional water injection systems. As such, steam injection through a variety of procedures, is more efficient at gathering salt into water that itself is easier to remove from the crude oil.

First claim

The invention claimed is:

1. A process for removing salt from crude oil wherein the salt is in the form of particles of crystalline salt suspended in the crude oil or as small droplets of brine water suspended in the crude oil, or both, wherein the process comprises the steps of:
a) delivering the crude oil into a steam-crude mixing zone:
b) injecting steam into the crude oil in the steam-crude mixing zone to form steam bubbles within the crude oil in the steam-crude mixing zone, where the steam bubbles are larger relative to any of the particles of crystalline salt or relative to any of the droplets of brine water in the crude oil in the steam-crude mixing zone so as to contact the steam bubbles with the crude oil along with any nearby suspended salt particles and brine droplets, wherein the crude oil flows through the steam-crude mixing zone in a defined direction of flow and the steam is injected into the crude oil against the direction of flow;
c) condensing the steam bubbles while in the crude oil into droplets of liquid water while at the same time dissolving available salt particles within the steam-crude mixing zone thereby forming new brine water droplets and also delivering liquid or vaporous water from the steam bubbles into any available small brine droplets resulting in new brine droplets and/or enlarged brine droplets having a size more amenable for separation from the crude oil; and
d) separating liquid water from the crude oil including water with salt dissolved therein, wherein the process does not include imposing high shear mixing of the uncondensed steam bubbles in the crude oil.

2. The process according to claim 1 wherein the step of injecting steam into a steam-crude mixing zone more particularly comprises injecting steam through a plurality of orifices directing steam against the flow of the crude oil.

3. The process according to claim 1 wherein the step of injecting steam into a steam-crude mixing zone more particularly comprises injecting steam into a segment of pipe through which crude oil is conveyed into the desalting process.

4. The process according to claim 1 wherein the step of injecting steam into a steam-crude mixing zone more particularly comprises injecting steam into a segment of pipe that has a larger diameter than the pipe through which crude oil is conveyed into the desalting process by at least 15%.

5. The process according to claim 1 wherein at least 98% of the steam bubbles formed in the crude oil condense and collapse in the crude oil without ever contacting any walls of the steam-crude mixing zone prior to condensing and collapsing.

6. The process according to claim 1 wherein at least 99% of the steam bubbles formed in the crude oil condense and collapse in the crude oil without ever contacting any walls of the steam-crude mixing zone prior to condensing and collapsing.

7. The process according to claim 1 wherein at least 99.5% of the steam bubbles formed in the crude oil condense and collapse in the crude oil without ever contacting any walls of the steam-crude mixing zone prior to condensing and collapsing.

8. The process according to claim 1 wherein at least 99.9% of the steam bubbles formed in the crude oil condense and collapse in the crude oil without ever contacting any walls of the steam-crude mixing zone prior to condensing and collapsing.

9. The process according to claim 1 wherein the steam is injected through a steam injector having a cross sectional area of at least 100 mm 2 up to 2500 cm 2 .

10. The process according to claim 1 wherein the steam is injected in a manner to deliver water droplets having an average diameter of at least 10 microns and up to about 150 microns after the steam bubbles have collapsed and condensed.

11. The process according to claim 1 further including the step of adding demulsifier into the crude oil prior to the step of separating the liquid water from the crude oil.

12. The process according to claim 1 wherein the steam is added to the crude oil at between 1 and 8 percent by weight steam to crude oil.

13. The process according to claim 1 wherein the steam is added to the crude oil at between 2 and 6 percent by weight steam to crude oil.

14. The process according to claim 1 wherein the steam is added to the crude oil at between 4 and 6 percent by weight steam to crude oil.

15. The process according to claim 1 wherein all of the steam bubbles condense in the crude oil within the crude-steam mixing zone.

16. The process according to claim 1 wherein the step of injecting steam into the crude oil in the crude-steam mixing zone further makes steam bubbles where each steam bubble is adapted to be able to contact numerous salt particles and brine droplets that are in the crude oil in proximity to a steam bubble.

Assignees

• Phillips 66 Co

Inventors

• Lawson Keith H
• Willman Derek H

Classifications

• E21B43/2406 Primary

  Steam assisted gravity drainage [SAGD] · CPC title

• C10G33/04 Primary

  with chemical means · CPC title

• B01D17/045

  with coalescers · CPC title