Method for removing iron sulfide scale from oil well equipment

Patent metadata

Field	Value
Publication number	US-2017362492-A1
Application number	US-201715697888-A
Country	US
Kind code	A1
Filing date	Sep 7, 2017
Priority date	Jan 12, 2016
Publication date	Dec 21, 2017
Grant date	—

Abstract

A method of removing an iron sulfide scale from a surface in fluid communication with a wellbore and/or subterranean formation comprising contacting the iron sulfide scale on the surface with a composition to dissolve the iron sulfide scale in the composition. The composition comprises (a) at least one chelating agent selected from the group consisting of DTPA, EDTA HEDTA, GLDA, CDTA, and MGDA, and salts thereof, and (b) at least one converting agent selected from the group consisting of potassium carbonate (K 2 CO 3 ), potassium formate (HCOOK), potassium hydroxide (KOH), potassium chloride (KCl), cesium formate (HCOOCs), and cesium chloride (CsCl). In the composition, the weight ratio of(a):(b) lies in the range 7-60:2-20.

First claim

1 . A method of removing an iron sulfide scale from a surface in fluid communication with a wellbore, comprising:
contacting the iron sulfide scale on the surface in fluid communication with the wellbore and/or subterranean formation with a composition to dissolve the iron sulfide scale in the composition, wherein the composition has a pH of from 8 to 11 and comprises: (a) at least one chelating agent selected from the group consisting of DTPA, EDTA, HEDTA, GLDA, CDTA, and MGDA, salts thereof, and (b) at least one converting agent selected from the group consisting of potassium carbonate (K 2 CO 3 ), potassium formate (HCOOK), potassium hydroxide (KOH), and cesium formate (HCOOCs), (c) a liquid aromatic solvent as a dispersed phase for solid or semisolid organic materials, and (d) an effective amount of at least one emulsifier to form an emulsion, wherein a weight ratio of the at least one chelating agent and the at least one converting agent lies in the range 7-60:2-20; wherein the at least one chelating agent and the at least one converting agent are dissolved in an aqueous solution as a continuous phase, and wherein the iron sulfide scale comprises at least one selected from the group consisting of pyrrhotite (Fe 7 S 8 ), troilite (FeS), marcasite (FeS 2 ), pyrite (FeS 2 ), greigite (Fe 2 S 4 ), and mackinawite (Fe 9 S 8 ).

2 . The method of claim 1 , further comprising:
acidifying the composition containing the dissolved iron sulfide scale to form a precipitant of the at least one chelating agent and a precipitant of at least one insoluble iron salt, isolating the precipitant of the at least one chelating agent and the precipitant of at least one insoluble iron salt from the composition, selectively dissolving the precipitated at least one chelating agent in another composition, and removing the precipitated at least one insoluble iron salt from the another composition.

3 . The method of claim 1 , wherein the composition comprises at least one chelating agent selected from the group consisting of DTPA, EDTA, HEDTA, and CDTA, and salts thereof.

4 . (canceled).

5 . The method of claim 1 , wherein at least about 70% of the iron sulfide scale is removed from the surface in fluid communication with the wellbore and/or subterranean formation.

6 . (canceled)

7 . The method of claim 1 , wherein the wellbore has a bottom hole temperature in the range of from about 100° F. to about 400° F.

8 . The method of claim 1 , wherein the contacting lasts at least 24 hours.

9 . (canceled)

10 . The method of claim 1 , wherein the composition further comprises at least one surfactant.

11 . (canceled)

12 . The method of claim 1 , wherein the liquid aromatic solvent comprises at least one selected from the group consisting of toluene, benzene, and xylene.

13 . The method of claim 1 , wherein the at least one emulsifier comprises at least one selected from the group consisting of a polyamide emulsifier having the formula R 3 O—C(O)—R 4 —C(O)—N(R 1 )—(CH 2 ) n —NH—C(O)—R 2 (where R 1 and R 2 are independently selected from C 10 -C 24 alkylene groups, R 3 is a hydrogen or a C 1 -C 5 alkyl group, R 4 is a C 1 -C 5 alkyl/alkene group, and n is a integer of from 2-5), a phosphate ester of an ethoxylated straight chain alcohol containing 8 to 10 carbon atoms and containing ethylene oxide in reacted form at a 4:1 or greater molar ratio relative to the straight chain alcohol, and a phosphate ester of an ethoxylated tridecyl alcohol containing ethylene oxide in reacted form at 6:1 or greater molar ratio relative to the tridecyl alcohol.

14 . The method of claim 1 , wherein a volume proportion of the aqueous solution as the continuous phase to the liquid aromatic solvent as the dispersed phase ranges from about 80:20 to about 50:50.

15 . The method of claim 1 , wherein the wellbore is present in at least one of an oil well, a gas well, a production well, an injection well, a naturally flowing well, an artificially lifted well, a high temperature well, a steam assisted gravity drainage well, a steam injector well, and a geothermal well.

16 . The method of claim 1 , wherein the surface in fluid communication with the wellbore and/or subterranean formation comprises a surface of an oil and/or gas reservoir, a geological surface, and/or a surface of at least one piece of equipment selected from the group consisting of heating turbines, heat exchangers, safety valves, casings, production tubing, mandrels, pipes, separators, pumps, tubulars, vessels, completion equipment, screens, and downhole tools.

17 - 20 . (canceled)

Assignees

• Univ King Fahd Pet & Minerals

Inventors

• Nasreldin Mahmoud Mohamed Ahmed
• Ba Geri Badr Salem
• Hussein Ibnelwaleed A

Classifications

• C09K8/532 Primary

  Sulfur · CPC title

• C09K8/528

  inorganic depositions, e.g. sulfates or carbonates · CPC title

• E21B37/06

  using chemical means for preventing or limiting {, e.g. eliminating,} the deposition of paraffins or like substances · CPC title