Fiber suspending agent for lost-circulation materials

Patent metadata

Field	Value
Publication number	US-10138405-B2
Application number	US-201315028366-A
Country	US
Kind code	B2
Filing date	Nov 25, 2013
Priority date	Nov 25, 2013
Publication date	Nov 27, 2018
Grant date	Nov 27, 2018

Abstract

A treatment fluid comprises: a base fluid; a lost-circulation material, wherein the lost-circulation material inhibits or prevents some or all of the treatment fluid from penetrating into a subterranean formation from a wellbore, wherein the wellbore penetrates the subterranean formation; and a suspending agent, wherein the suspending agent consists of a plurality of fibers, and wherein the suspending agent provides a lost-circulation material distribution of at least 30% for a test treatment fluid consisting essentially of the base fluid, the lost-circulation material, and the suspending agent at the temperature of a lost-circulation zone of the subterranean formation and static aging for at least 1 hour.

First claim

What is claimed is:

1. A treatment fluid comprising:
a base fluid;
a lost-circulation material, wherein the lost-circulation material inhibits or prevents some or all of the treatment fluid from penetrating into a subterranean formation from a wellbore, wherein the wellbore penetrates the subterranean formation; and
a suspending agent, wherein the suspending agent consists of a plurality of fibers, wherein the fibers have a length to diameter aspect ratio of about 100:1 to about 5000:1, wherein the fibers have a distribution such that at least 90% of the fibers have a length in the range of about 5 to about 25 millimeters; and wherein the suspending agent is in at least a sufficient concentration to provide a lost-circulation material distribution of at least 30% for a test treatment fluid consisting essentially of the base fluid, the lost-circulation material, and the suspending agent at a temperature of a lost-circulation zone of the subterranean formation and after performing static aging for at least 1 hour.

2. The treatment fluid according to claim 1 , wherein the base fluid comprises an aqueous liquid, an aqueous miscible liquid, or a hydrocarbon liquid.

3. The treatment fluid according to claim 1 , wherein the lost-circulation material is in at least a sufficient concentration such that fluid is inhibited or prevented from flowing into the subterranean formation from the wellbore.

4. The treatment fluid according to claim 1 , wherein the lost-circulation material is in a concentration in the range of about 0.5 to about 200 pounds per barrel of the base fluid.

5. The treatment fluid according to claim 1 , wherein the lost-circulation material is selected from the group consisting of: ground coal; petroleum coke; sized calcium carbonate; asphaltene; perlite; cellophane; cellulose; ground tire material; ground oyster shell; vitrified shale; plastic material; paper fiber; wood; cement; hardened foamed cement; glass; foamed glass; sand; bauxite; ceramic material; a polymeric material; a polytetrafluoroethylene material; nut shell; seed shell piece; fruit pit piece; clay; silica; alumina; fumed carbon; carbon black; graphite; mica; titanium oxide; meta-silicate; calcium silicate; kaolin; talc; zirconia; boron; fly ash; hollow glass microsphere; and any combination thereof.

6. The treatment fluid according to claim 1 , wherein the lost-circulation material has a particle size distribution such that at least 80% of the lost-circulation material particles have a size in the range from about 2 to about 400 mesh.

7. The treatment fluid according to claim 1 , wherein the fibers are in dry form or in a liquid suspension.

8. The treatment fluid according to claim 1 , wherein the fibers are natural, synthetic, biodegradable, biocompatible, or combinations thereof.

9. The treatment fluid according to claim 1 , wherein the fibers are composed of polypropylene, polyaramid, polyester, polyacrylonitrile, polyvinyl alcohol, modified cellulose, chitosan, modified chitosan, polycaprolactone, polylactic acid, poly(3-hydroxybutyrate), polyhydroxy-alkanoates, polyglycolic acid, polyorthoesters, polycarbonates, polyaspartic acid, polyphosphoesters, soya, copolymers thereof, and combinations thereof.

10. The treatment fluid according to claim 1 , wherein the suspending agent provides a lost-circulation material distribution of at least 40% for the test treatment fluid at the temperature of a lost-circulation zone of the subterranean formation and static aging for at least 1 hour.

11. The treatment fluid according to claim 1 , wherein the suspending agent is in a concentration in the range of about 0.1 ppb to about 25 ppb of the base fluid.

12. The treatment fluid according to claim 1 , wherein the treatment fluid further comprises one or more additional ingredients.

13. The treatment fluid according to claim 12 , wherein the additional ingredients are selected from the group consisting of a viscosifier; a filtration control agent; a shale stabilizer; a weighting agent; a pH buffer; an emulsifier; an emulsifier activator; a dispersion aid; a corrosion inhibitor; an emulsion thinner; an emulsion thickener; a gelling agent; a surfactant; a foaming agent; a gas; a breaker; a biocide; a chelating agent; a scale inhibitor; a gas hydrate inhibitor, a mutual solvent; an oxidizer; a reducer; a friction reducer; a clay stabilizing agent; an oxygen scavenger; and any combination thereof.

14. The treatment fluid according to claim 13 , wherein the treatment fluid is a drilling fluid.

15. The treatment fluid according to claim 14 , wherein the weighting agent is in at least a sufficient concentration such that the drilling fluid has a density in the range of about 9 to about 20 pounds per gallon.

16. A method of treating a portion of wellbore comprising:
introducing a treatment fluid into the portion of the wellbore, wherein the treatment fluid comprises:
a base fluid;
a lost-circulation material, wherein the lost-circulation material inhibits or prevents some or all of the treatment fluid from penetrating into a subterranean formation from the wellbore, wherein the wellbore penetrates the subterranean formation; and a suspending agent, wherein the suspending agent consists of a plurality of fibers, wherein the fibers have a length to diameter aspect ratio of about 100:1 to about 5000:1, wherein the fibers have a distribution such that at least 90% of the fibers have a length in the range of about 5 to about 25 millimeters; and wherein the suspending agent is in at least a sufficient concentration to provide a lost circulation material distribution of at least 30% for a test treatment fluid consisting essentially of the base fluid, the lost-circulation material, and the suspending agent at a temperature of 150.degree. F. after hot rolling for 16 hours and static aging for 2 hours.

17. The method according to claim 16 , wherein the wellbore is part of a well, and wherein the well is an oil, gas, or water production well, a geothermal well, or an injection well.

Assignees

• Halliburton Energy Services Inc

Inventors

• Kulkarni Sandeep D
• Miller Matthew L
• Jamison Dale E
• Teke Kushabhau D

Classifications

• C09K8/487

  Fluid loss control additives; Additives for reducing or preventing circulation loss · CPC title

• C09K8/514

  of natural origin, e.g. polysaccharides, cellulose (C09K8/512 takes precedence) · CPC title

• C09K8/50 Primary

  Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls (compositions for consolidating loose sand or the like around wells C09K8/56) · CPC title

• E21B43/16

  Enhanced recovery methods for obtaining hydrocarbons · CPC title

• C09K8/035 Primary

  Organic additives · CPC title