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US-12618000-B2 - Friction reduction of acidic treatment fluids

US12618000B2US 12618000 B2US12618000 B2US 12618000B2US-12618000-B2

Abstract

A variety of methods, systems, and compositions are disclosed, including, in one example, a method that includes: introducing a treatment fluid into a wellbore extending into a subterranean formation, wherein the treatment fluid comprises: water; an acid; a corrosion inhibitor; and a friction reducer having a vinyl phosphonic acid moiety, an acrylic acid moiety, a vinyl sulfonate moiety, a diallyl moiety, or an acrylamide moiety; and flowing at least a portion of the treatment fluid into the subterranean formation, wherein the pressure required to achieve a given flow rate of the treatment fluid into the subterranean formation is reduced by at least 1% as compared to the pressure required to achieve the given flow rate of the treatment fluid in the subterranean formation without the friction reducer.

Inventors

  • Nicole Mast
  • Enrique Antonio Reyes
  • Antonio RECIO, III

Assignees

  • HALLIBURTON ENERGY SERVICES, INC.

Dates

Publication Date
20260505
Application Date
20241023

Claims (20)

  1. 1 . A treatment fluid comprising: water; an acid; a corrosion inhibitor; and a friction reducer having a vinyl phosphonic acid moiety, an acrylic acid moiety, a vinyl sulfonate moiety, a diallyl moiety, or an acrylamide moiety, wherein pressure drop of the treatment fluid across two measurement points in a ½ inch diameter friction flow loop system at 10 gallons per minute is reduced by at least 0.05% as compared to the treatment fluid without the friction reducer and wherein the treatment fluid has the property of wherein after 2 hours of exposure to the acid in the treatment fluid, the friction reducer preserves at least 80% of its elongation.
  2. 2 . The treatment fluid of claim 1 , further comprising at least one additive selected from the group consisting of: a surfactant; a diverter; an acid scavenger; a chelating agent, a scale inhibitor, an iron control agent, a viscosifying agent, a cross-linking agent, a breaker or oxidizing agent, a viscosifier, a dispersant, a wetting agent, a non-emulsifying agent; a thermo-chemical agent; a corrosion inhibitor intensifier agent, a foaming agent; carbon dioxide; nitrogen; natural gas; a filter cake removal agent; and any combination thereof.
  3. 3 . The treatment fluid of claim 2 , wherein the at least one additive comprises a thermo-chemical agent comprising ammonium chloride and sodium nitrite.
  4. 4 . The treatment fluid of claim 1 , wherein the friction reducer is a quaternized pendant polyacrylate polymer.
  5. 5 . The treatment fluid of claim 1 , wherein the friction reducer is polymeric and has a molecular weight from about 5,000 kilodaltons to about 25,000 kilodaltons, wherein the friction reducer is amphoteric, cationic, or anionic, and wherein the friction reducer is present in the treatment fluid in an amount between 100 ppm and 1,000 ppm, and wherein the percent reduction in pressure drop is at least 5%.
  6. 6 . The treatment fluid of claim 1 , wherein at least one friction reducing moiety comprises 2-acrylamidoethanesulfonic acid or 2-methyacylamidoethanesulfonic acid.
  7. 7 . The treatment fluid of claim 1 , wherein at least one friction reducing moiety comprises 2-acrylamido-2-methyl-1-propanesulfonic acid.
  8. 8 . The treatment fluid of claim 1 , wherein at least one friction reducing moiety comprises 3-acrylamidopropanesulfonic acid, 2-acrylamidopropanesulfonic acid, 4-acrylamidobutanesulfonic acid, or 2-acrylamidobutanesulfonic acid.
  9. 9 . A treatment fluid comprising: water; an acid, wherein the treatment fluid comprises between 15 wt. % and 45 wt. % of the acid; a corrosion inhibitor; and a friction reducer comprising: an acrylic acid moiety; an acrylamide moiety; and at least one friction reducing moiety selected from the group consisting of: a vinyl phosphonic acid moiety, a vinyl sulfonate moiety, a diallyl moiety, and any combination thereof wherein the treatment fluid has the property of wherein after 2 hours of exposure to the acid in the treatment fluid, the friction reducer preserves at least 80% of its elongation.
  10. 10 . The treatment fluid of claim 9 , wherein the friction reducer is polymeric and has a molecular weight from about 5,000 kilodaltons to about 25,000 kilodaltons.
  11. 11 . The treatment fluid of claim 9 , wherein the friction reducer is amphoteric or cationic.
  12. 12 . The treatment fluid of claim 9 , wherein the friction reducer is anionic.
  13. 13 . The treatment fluid of claim 9 , wherein the friction reducer is a quaternized pendant polyacrylate polymer.
  14. 14 . The treatment fluid of claim 9 , wherein the treatment fluid further comprises proppant.
  15. 15 . The treatment fluid of claim 9 , wherein the treatment fluid further comprises at least one additive selected from the group consisting of: a surfactant; a diverter; an acid scavenger; a chelating agent, a scale inhibitor, an iron control agent, a viscosifying agent, a cross-linking agent, a breaker or oxidizing agent, a viscosifier, a dispersant, a wetting agent, a non-emulsifying agent; a thermo-chemical agent; a corrosion inhibitor intensifier agent, a foaming agent; carbon dioxide; nitrogen; natural gas; a filter cake removal agent; and any combination thereof.
  16. 16 . The treatment fluid of claim 9 , wherein at least one friction reducing moiety comprises 5-ethenyl-1,3-benzenedisulfonic acid, 5-ethenyl-2-hydroxy-1,3-benzenedisulfonic acid, or 4-vinylbenzenesulfonic acid.
  17. 17 . The treatment fluid of claim 9 , wherein at least one friction reducing moiety comprises 2-acrylamidoethanesulfonic acid or 2-methyacylamidoethanesulfonic acid.
  18. 18 . The treatment fluid of claim 9 , wherein at least one friction reducing moiety comprises 2-acrylamido-2-methyl-1-propanesulfonic acid.
  19. 19 . The treatment fluid of claim 9 , wherein at least one friction reducing moiety comprises 3-acrylamidopropanesulfonic acid, 2-acrylamidopropanesulfonic acid, 4-acrylamidobutanesulfonic acid, or 2-acrylamidobutanesulfonic acid.
  20. 20 . The treatment fluid of claim 9 , wherein the acid comprises at least one acid selected from the group consisting of hydrochloric acid, hydrobromic acid, hydroiodic acid, hydrofluoric acid, nitric acid, nitrous acid, carbonic acid, phosphoric acid, oxoacids and oxyhalides having the formula HiXOn where n=1, 2, 3, 4 and X=F, Cl, Br, I, or i=1, 2, 3 and X=B, C, Si, N, P, S, Se, Sb and n=3, 4 or 5, methane sulfonic acid, formic acid, acetic acid, chloroacetic acid, di-chloroacetic acid, trichloroacetic acid, citric acid, glycolic acid, hydroxyacetic acid, lactic acid, 3-hydroxypropionic acid, aspartic acid, gluconic acid, glucaric acid, ethylenediaminetetraacetic acid (EDTA), hydroxyethylethylenediaminetriacetic acid (HEDTA), tetrasodium glutamate diacetate (GLDA), methylglycinediacetic acid (MGDA), N-(2-hydroxyethyl) iminodiacetic acid (HEIDA), acidic or neutralized N-(Phosphonomethyl) iminodiacetic acid (PMIDA) or salts thereof, N-(carboxymethyl)-N-(phosphonomethyl) glycine, glycine, N,N′-1,2-ethanediylbis (N-(phosphonomethyl), glyphosine, sodium aminotris(methylenephosphonate), N-(2-hydroxyethyl) iminobis (methylphosphonic acid), phosphonic acid, P,P′-((2-propen-1-ylimino) bis(methylene)) bis-phosphonic acid, P,P′,P″-(nitrilotris (methylene)) tris-(nitrilotris (methylene)) trisphosphonic aci, ((methylimino)-dimethylene) bisphosphonic acid, P,P′,P″,P″-(oxybis(2,1-ethanediylnitrilobis-(methylene)) tetrakis-((propylimino) bis(methylene)) diphosphonic acid, P,P′,P″-(nitrilotris(methylene)) tris-acid, ethylene-(ethylenedinitrilo)-tetramethylenephosphonic bis(nitrilodimethylene) tetraphosphonic acid; (ethylenebis(nitrilobis(methylene)))tetrakisphosphonic acid, tetrasodium tetrahydrogen (ethane-1,2-diylbis (nitrilobis(methylene)))tetrakisphosphonate, 6-(bis(phosphonomethyl)amino) hexanoic acid, (phenylmethyl)imino) bis(methylene) bisphosphonic acid, 1,2,4-phosphonobutanetricarboxylic acid (PBTCA), aminotris(methylenephosphonic acid) (ATMP), ethylenediaminetetra(methylenephosphonic acid) (EDTMP), diethylenetriaminepenta(methylenephosphonic acid) (DTPMP), hexamethylenediaminetetramethylenephosphonic acid (HDTMP), bishexamethylenetriaminepenta(methylenephosphonic acid) (BHMTMP), 2-hydroxyphosphono dicarboxylic acid, a sodium, potassium, or ammonium salt of any group member herein, phosphonate ester derivatives of any group member herein, and combinations thereof.

Description

BACKGROUND During the drilling, completion, and stimulation of subterranean wells, treatment fluids and crude oil are pumped through wellbores and tubular structures (e.g., pipes, coiled tubing, flowlines, surface pipelines, etc.). A considerable amount of energy may be lost to friction during pumping of these fluids. For example, the fluids may become turbulent or form eddy currents when flowing through wellbore casing or other conduits. As a result of these energy losses, additional horsepower may be needed to achieve the desired treatment. To reduce these energy losses, fluid friction-reducers can be included in these treatment fluids. Fluid friction-reducers are chemical additives that alter fluid rheological properties to reduce friction created within a fluid as it flows through tubulars or other flow paths. Most friction reducers are acid incompatible or intolerant and may lose effectiveness in acidic environments. BRIEF DESCRIPTION OF THE DRAWINGS These drawings illustrate certain aspects of some of the embodiments of the present disclosure and should not be used to limit or define the method. FIG. 1 illustrates surface equipment for delivering a treatment fluid to a wellbore, in accordance with certain examples; FIG. 2 illustrates a wellbore treatment configuration for performing a coiled tubing operation; FIG. 3 illustrates a wellbore treatment configuration for acid fracturing a subterranean formation; FIG. 4 illustrates a friction flow loop system; FIG. 5 is a plot showing results of a friction loop test for a group of polymers using a friction flow loop system; and FIG. 6 is another plot showing results of a friction loop test for a group of polymers using a friction flow loop system. DETAILED DESCRIPTION Disclosed herein are treatment fluids and methods of treating a subterranean formation and, more particularly, disclosed are methods for treating a subterranean formation with a treatment fluid comprising a friction reducer and acid. There are many advantages to the methods and compositions as presently disclosed, only some of which are discussed or alluded to herein. One such advantage is that the treatment fluids of the present disclosure may have improved compatibility with acid. In one or more examples, acid fracturing, matrix acidizing, or other wellbore operations involving treatment fluids may be performed while reducing a total amount of head loss and/or an energy requirement of the operations. For example, flow rates of these treatment fluids may be higher than what can normally be achieved using conventional treatment fluids. Other advantages may include good compatibility between friction reducers and corrosion inhibitors, as well as good polymer elongation. Other examples may include an improved ability to pump above a fracture gradient, improved fracture extension, overcoming of conventional pumping pressure limitations, higher pumping rates than those maximally achievable with presently used viscosifying agents. Treatment fluids of the present disclosure may be used during hydrocarbon resource recovery, such as in matrix acidizing or acid fracturing operations. The treatment fluids may also be used with other forms of energy carriers, such as in geothermal fluids. The treatment fluids may also be used during cleaning of surface pipelines, such as pipelines used for transporting hydrocarbon resources across great distances. Surface pipelines may or may not be connected to a wellbore. The treatment fluids may be used in injector wells, such as an injector well benefiting from an acidizing treatment. In addition, the treatment fluids may be used in wellbore cleanout, coiled tubing procedures, filter cake removal, scale removal, damage removal, hydrate treatment, hydrate inhibition, and open hole diversion, frac-pac clean out, gravel pack clean out, re-fracturing or re-stimulation of previously fractured well, to use non-limiting examples. In general, the treatment fluids generally comprise water, an acid, a corrosion inhibitor, and a friction reducer. In addition to these, various other chemicals or additives may be optionally included in the treatment fluids, as disclosed herein. Treatment fluids of the present disclosure may be aqueous and/or non-emulsified, having a single aqueous continuous phase. For example, water may be present in a treatment fluid in an amount greater than 60 wt. %, such as from about 60 wt. % to about 99.9 wt. %. Alternatively, from about 60 wt. % to about 75 wt. %, about 75 wt. % to about 85 wt. %, about 85 wt. % to about 95 wt. %, about 95 wt. % to about 99.9 wt. %, or any ranges therebetween. Alternatively, treatment fluids of the present disclosure may, in some examples, be nonaqueous and/or emulsified. The treatment fluids may be used in direct emulsions or invert emulsions. A water-in-oil emulsion may be used, for example, where the treatment fluid comprises a water phase comprising an active acid concentration of 7 wt. % to 28 wt. % HCl and an oleagi