Calcium methylglycine diacetic acid salt particles and subterranean operations relating thereto

Patent metadata

Field	Value
Publication number	US-10040989-B2
Application number	US-201314908570-A
Country	US
Kind code	B2
Filing date	Nov 27, 2013
Priority date	Nov 27, 2013
Publication date	Aug 7, 2018
Grant date	Aug 7, 2018

Abstract

Particles that comprise calcium methylglycine diacetic acid salt (“Ca-MGDA salt”) may be useful for fluid diversion in subterranean operations. In some instances, the particles may be formed in the subterranean formation. For example, a method may involve introducing a treatment fluid into a wellbore penetrating a subterranean formation, wherein the treatment fluid comprises an aqueous base fluid, MGDA or salt thereof, and an acid in an amount of about 3% or greater by weight of the aqueous base fluid; acidizing a portion of the subterranean formation comprising calcium carbonate resulting in a concentration of calcium in the treatment fluid that exceeds about 50,000 ppm; and precipitating a plurality of particles that comprise a Ca-MGDA salt in the portion of the subterranean formation, thereby reducing fluid flow therethrough. In some instances, the particles that comprise Ca-MGDA salt may be included in a treatment fluid before introduction into the subterranean formation.

First claim

The invention claimed is:

1. A method comprising:
introducing a treatment fluid into a wellbore penetrating a subterranean formation, wherein the treatment fluid comprises an aqueous base fluid, a methylglycine diacetic acid (MGDA) or salt thereof, and a second acid in an amount of about 3% or greater by weight of the aqueous base fluid;
acidizing a first portion of the subterranean formation comprising calcium carbonate resulting in a concentration of calcium in the treatment fluid that exceeds about 50,000 ppm;
adjusting a pH of the treatment fluid to be about 1.5 to about 5.5, thereby precipitating a plurality of particles that comprise a Ca-MGDA salt in the first portion of the subterranean formation, thereby reducing fluid flow therethrough; and
diverting a portion of the treatment fluid or a subsequent treatment fluid from the first portion of the subterranean formation to a second portion of the subterranean formation.

2. The method of claim 1 further comprising:
contacting the plurality of particles with a second treatment fluid having a pH of about 5.5 or greater; and
dissolving at least a portion of the plurality of particles, thereby increasing fluid flow through the portion of the subterranean formation.

3. The method of claim 1 , wherein the treatment fluid further comprises calcium before introducing the treatment fluid into the wellbore.

4. The method of claim 3 , wherein the calcium in the treatment fluid before introducing the treatment fluid into the wellbore is from a calcium salt comprising at least one selected from the group consisting of calcium chloride, calcium bromide, calcium nitrate, calcium sulfate, calcium phosphate, and any combination thereof.

5. The method of claim 3 , wherein the calcium is at a concentration of about 10,000 ppm to about 50,000 ppm in the treatment fluid before introducing the treatment fluid into the wellbore.

6. The method of claim 1 , wherein the MGDA or salt thereof is at a concentration of about 0.5 M to about 1.5 M in the treatment fluid.

7. The method of claim 1 , wherein the wellbore has a bottom hole circulating temperature of about 125° F. or greater.

8. The method of claim 1 , wherein the plurality of particles have a d50 of about 25 microns to about 100 microns.

9. The method of claim 1 , wherein introducing the treatment fluid into the wellbore is at a pressure sufficient to create or extend at least one fracture in the subterranean formation.

10. A method comprising:
introducing a treatment fluid into a wellbore penetrating a subterranean formation, wherein the treatment fluid comprises an aqueous base fluid, a suspending aid, and a plurality of particles that comprise a Ca-methylglycine diacetic acid (MGDA) salt, wherein the plurality of particles that comprise the Ca-MGDA salt are precipitated due to the treatment fluid having a pH of about 1.5 to about 5.5;
placing the plurality of particles in a portion of the subterranean formation, thereby reducing fluid flow therethrough; and
diverting a portion of the treatment fluid or a subsequent treatment fluid from the portion of the subterranean formation to a second portion of the subterranean formation.

11. The method of claim 10 further comprising:
contacting the plurality of particles with a second treatment fluid having a pH of about 5.5 or greater; and
dissolving at least a portion of the plurality of particles, thereby increasing fluid flow through the portion of the subterranean formation.

12. The method of claim 10 , wherein the plurality of particles have a d50 of about 25 microns to about 100 microns.

13. The method of claim 10 , wherein the plurality of particles are at about 1% to about 30% by weight of the treatment fluid.

14. The method of claim 10 , wherein the suspending aid comprises at least one of a polymer and a surfactant.

15. The method of claim 10 , wherein the suspending aid is at about 0.1% to about 20% by weight of the aqueous base fluid.

16. The method of claim 10 , wherein the treatment fluid further comprises an aqueous-miscible fluid.

17. A system comprising:
a pump fluidly coupled to a tubular;
the tubular containing a treatment fluid that comprises an aqueous base fluid, a methylglycine diacetic acid (MGDA) or salt thereof, up to about 50,000 ppm calcium, and a second acid in an amount of about 3% or greater by weight of the aqueous base fluid, wherein a pH of the treatment fluid is about 1.5 to about 5.5, and includes a plurality of particles that comprise a Ca-methylglycine diacetic acid (MGDA) salt.

Assignees

• Halliburton Energy Services Inc

Inventors

• Reyes Enrique Antonio
• Smith Christopher Lynn
• Smith Alyssa
• Beuterbaugh Aaron Michael

Classifications

• E21B43/16

  Enhanced recovery methods for obtaining hydrocarbons · CPC title

• C09K8/70

  characterised by their form or by the form of their components, e.g. foams · CPC title

• C09K8/74

  combined with additives added for specific purposes · CPC title

• C09K8/72 Primary

  Eroding chemicals, e.g. acids · CPC title

• C09K8/68 Primary

  containing organic compounds · CPC title