Methods for removal of components of a subsea oilfield facility

Patent metadata

Field	Value
Publication number	US-10181706-B2
Application number	US-201715473268-A
Country	US
Kind code	B2
Filing date	Mar 29, 2017
Priority date	Mar 11, 2016
Publication date	Jan 15, 2019
Grant date	Jan 15, 2019

Abstract

Disclosed are processes for removing carbon steel components of a subsea oilfield facility in a subsea environment by accelerating the corrosion of the carbon steel components in the surrounding seawater, by a passive and/or active impressed current method. In the passive method, the facility is connected to a cathodic metal of greater electrical potential, such as copper. In order to cause the maximum and uniform corrosion, it is preferred that a wire of the chosen cathodic metal be extended along the facility and through pipelines. In the active impressed current method, an external DC electrical supply is used to apply an electrical potential difference between the steel components of the facility and the cathodic metal.

First claim

What is claimed is:

1. A process for removal of a component of a subsea oilfield facility located in a subsea environment wherein the component comprises a corrodible metal pipeline having a length and is surrounded by seawater, comprising:
establishing electrical connection between the component and a second metal comprising a conductive material in the form of a wire comprising the second metal; wherein the wire extends along a central axis of the pipeline along the length of the pipeline and further comprises radially extending filaments to centralize the wire within the pipeline; such that the component is corroded at an accelerated rate.

2. A process for removal of a component of a subsea oilfield facility located in a subsea environment wherein the component comprises a corrodible metal and is surrounded by seawater, comprising:
establishing electrical connection between the component and a second metal comprising a conductive material;
connecting the component to a direct current power source selected from the group consisting of a rectifier connected to a solar cell, wind generated electricity, and electricity generated from tidal activity, thereby increasing the electrical potential difference between the components and the second metal; and
applying current when power is available thereby pulsing the current over time;
such that the component is corroded at an accelerated rate.

3. A process for removal of a component of a subsea oilfield facility located in a subsea environment wherein the component comprises a corrodible metal and is surrounded by seawater, comprising:
establishing electrical connection between the component and a second metal comprising a conductive material; and
connecting the component to a direct current power source selected from the group consisting of a rectifier connected to an alternating current power supply, a solar cell, wind generated electricity, electricity generated from tidal activity and gas power, thereby increasing the electrical potential difference between the components and the second metal;
such that the component is corroded at an accelerated rate.

4. The process of any of claim 3 , 1 or 2 , wherein the electrical connection is established between the second metal and the component over a concentrated area of the component such that the concentrated area of the component is corroded at an accelerated rate; and further comprising breaking the component into a plurality of pieces to facilitate the removal of the component.

5. The process of any of claim 3 , 1 or 2 , wherein the electrical connection is maintained for up to about 10 years.

6. The process of any of claim 3 , 1 or 2 , wherein the electrical connection is maintained for between about 1 year and about 10 years.

7. The process of any of claim 3 , 1 or 2 , wherein the second metal has an electrical potential greater than an electrical potential of the corrodible metal.

8. The process of any of claim 3 , 1 or 2 , wherein the second metal comprises copper.

9. The process of any of claim 3 , 1 or 2 , wherein the component comprises a corrodible metal selected from alloy steels and carbon steels.

10. The process of claim 9 , wherein at least a portion of the component is corroded to form one or more iron oxides.

11. The process of claim 3 or claim 2 , wherein the component comprises a pipeline having a length; and wherein the second metal is in the form of a wire comprising the second metal and extending along the length of the pipeline.

12. The process of claim 11 , wherein the wire is wrapped around the pipeline.

13. The process of claim 11 , wherein the wire is inserted within the pipeline and wherein the wire has a three-dimensional form such that the wire contacts an inner surface of the pipeline.

14. The process of any of claim 3 , 1 or 2 , wherein at least a portion of the component is corroded to form one or more metal oxides.

15. The process of claim 14 , wherein a portion of the component does not have an electric connection with the second metal; and the corroded portion of the component has an increased porosity and an increased surface area as compared with a porosity and a surface area of the portion of the component not having an electric connection with the second metal.

16. The process of claim 3 or claim 2 , further comprising applying current at a predetermined frequency thereby pulsing the current over time.

Assignees

• Chevron Usa Inc

Inventors

• Kemp Ian Paul
• Thomas David Glynn
• Benson Ursula Louise

Classifications

• E21B29/02

  by explosives or by thermal or chemical means {(freeing stuck objects by explosives E21B31/002)} · CPC title

• H02G1/08 Primary

  through tubing or conduit, e.g. rod or draw wire for pushing or pulling {(inserting electrical cables into tubes using wallbores E21B17/206; for optical cables G02B6/4401)} · CPC title

• F16L1/16

  on the bottom · CPC title

• H02G1/10

  in or under water · CPC title

• B09C2101/00

  In situ · CPC title