WO2012127191A1 - Methods of fluid loss control and fluid diversion in subterranean formations - Google Patents
Methods of fluid loss control and fluid diversion in subterranean formations Download PDFInfo
- Publication number
- WO2012127191A1 WO2012127191A1 PCT/GB2012/000263 GB2012000263W WO2012127191A1 WO 2012127191 A1 WO2012127191 A1 WO 2012127191A1 GB 2012000263 W GB2012000263 W GB 2012000263W WO 2012127191 A1 WO2012127191 A1 WO 2012127191A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- fluid
- acid
- subterranean formation
- particulates
- solid particulates
- Prior art date
Links
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/516—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/02—Well-drilling compositions
- C09K8/03—Specific additives for general use in well-drilling compositions
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
- C09K8/528—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
- C09K8/536—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/70—Compositions for forming crevices or fractures characterised by their form or by the form of their components, e.g. foams
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/72—Eroding chemicals, e.g. acids
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/80—Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/92—Compositions for stimulating production by acting on the underground formation characterised by their form or by the form of their components, e.g. encapsulated material
Definitions
- the present invention relates to methods that may be useful in treating subterranean formations, and more specifically, to methods of controlling fluid loss and/or diverting treatment fluids in subterranean formations.
- Treatment fluids may be used in a variety of subterranean treatments, including, but not limited to, stimulation treatments and sand control treatments.
- treatment or “treating,” refers to any subterranean operation that uses a fluid in conjunction with a desired function and/or for a desired purpose.
- treatment and “treating,” as used herein, do not imply any particular action by the fluid or any particular component thereof.
- Examples of common subterranean treatments include, but are not limited to, drilling operations, fracturing operations (including prepad, pad and flush), perforation operations, sand control treatments (e.g., gravel packing, resin consolidation including the various stages such as preflush, afterflush, etc.), acidizing treatments (e.g., matrix acidizing or fracture acidizing), "frac-pack” treatments, cementing treatments, water control treatments, wellbore clean-out treatments, paraffin/wax treatments, scale treatments and "squeeze treatments.”
- Fluid loss refers to the undesirable migration or loss of fluids into a subterranean formation and/or a proppant pack.
- proppant pack refers to a collection of a mass of proppant particulates within a fracture or open space in a subterranean formation. Fluid loss may be problematic in any number of subterranean operations, including drilling operations, fracturing operations, acidizing operations, gravel-packing operations, wellbore clean-out operations, and the like. In fracturing treatments, for example, fluid loss into the formation may result in a reduction in fluid efficiency, such that the fracturing fluid cannot propagate the fracture as desired.
- Fluid loss control materials are additives that lower the volume of a filtrate that passes through a filter medium.
- Certain particulate materials may be used as a fluid loss control material in subterranean treatment fluids to fill the pore spaces in a formation matrix and/or proppant pack and/or to contact the surface of a formation face and/or proppant pack, thereby forming a filter cake that blocks the pore spaces in the formation or proppant pack, and prevents fluid loss therein.
- the use of certain particulate fluid loss control materials may be problematic.
- the sizes of the particulates may not be optimized for the pore spaces in a particular formation matrix and/or proppant pack and, as a result, may increase the risk of invasion of the particulate material into the interior of the formation matrix, which may greatly increase the difficulty of removal by subsequent remedial treatments.
- remedial treatments may be required to remove the previously-placed fluid loss control materials, inter alia, so that a well may be placed into production.
- particulates that have become lodged in pore spaces and/or pore throats in the formation matrix and/or proppant pack may be difficult and/or costly to remove.
- the present invention relates to methods that may be useful in treating subterranean formations, and more specifically, to methods of controlling fluid loss and/or diverting treatment fluids in subterranean formations.
- a method comprising introducing a treatment fluid into a subterranean formation penetrated by a wellbore, wherein the treatment fluid comprises: a base fluid, and a plurality of solid particulates comprising at least one selected from the group consisting of: a scale inhibitor, a chelating agent, and a combination thereof, wherein the solid particulates are substantially insoluble in the base fluid; and allowing at least a portion of the solid particulates to form a barrier that provides fluid loss control or seals the rock surfaces for fluid diversion.
- a method comprising introducing a treatment fluid into a subterranean formation penetrated by a wellbore, wherein the treatment fluid comprises a base fluid, and a plurality of solid particulates comprising at least one selected from the group consisting of: a scale inhibitor, a chelating agent, and a combination thereof, wherein the solid particulates are substantially insoluble in the base fluid; and allowing at least a portion of the solid particulates to form a barrier that provides fluid loss control or seals the rock surfaces for fluid diversion of the base fluid or a subsequent fluid into the subterranean formation.
- a method comprising introducing a treatment fluid into a subterranean formation penetrated by a wellbore, wherein the treatment fluid comprises: a base fluid, and a plurality of solid particulates comprising a scale inhibitor, wherein the solid particulates are substantially insoluble in the base fluid, and wherein the treatment fluid does not comprise any proppant particulates; and allowing at least a portion of the solid particulates to form a barrier that provides fluid loss control or seals the rock surfaces for fluid diversion.
- a method comprising introducing a treatment fluid into a subterranean formation penetrated by a wellbore at a pressure at or above the fracture pressure of the subterranean formation, wherein the treatment fluid comprises: a base fluid, and a plurality of solid particulates comprising at least one selected from the group consisting of a scale inhibitor, a chelating agent, and a combination thereof, wherein the solid particulates are substantially insoluble in the base fluid; and allowing at least a portion of the solid particulates to form a barrier that provides fluid loss control or seals the rock surfaces for fluid diversion.
- the present invention relates to methods that may be useful in treating subterranean formations, and more specifically, to methods of controlling fluid loss and/or diverting treatment fluids in subterranean formations.
- the methods of the present invention generally comprise: introducing a treatment fluid into a subterranean formation penetrated by a wellbore, wherein the treatment fluid comprises: a base fluid and a plurality of solid particulates comprising a scale inhibitor or a chelating agent, wherein the particulates are substantially insoluble in the base fluid; and allowing the plurality of particulates to form a barrier to at least partially divert a treatment fluid and/or at least partially control fluid loss.
- the term "barrier” refers to a partial or complete obstruction or impediment to the passage of a substance through an area for a desired period of time.
- the solid particulates may be contacted with a solubilizing agent for a sufficient period of time such that at least a portion of the particulates are solubilized.
- a solubilizing agent for a sufficient period of time such that at least a portion of the particulates are solubilized.
- substantially insoluble refers to less than about 1% weight percent soluble in distilled water at room temperature (about 72 °F, 22 °C.) for the anticipated duration of the treatment.
- the treatment fluids of the present invention may be used in a variety of subterranean applications including, but not limited to, drilling operations, fracturing operations (including prepad, pad and flush), perforation operations, sand control treatments (e.g. , gravel packing, resin consolidation including the various stages such as preflush, afterflush, etc.), acidizing treatments (e.g. , matrix acidizing or fracture acidizing), "frac-pack” treatments, cementing treatments, water control treatments, wellbore clean-out treatments, paraffin/wax treatments, scale treatments, "squeeze treatments” and as a fluid loss pill.
- fracturing operations including prepad, pad and flush
- perforation operations e.g., gravel packing, resin consolidation including the various stages such as preflush, afterflush, etc.
- acidizing treatments e.g. , matrix acidizing or fracture acidizing
- "frac-pack” treatments cementing treatments
- water control treatments wellbore clean-out treatments
- paraffin/wax treatments scale
- the methods of the present invention may reduce or prevent loss of fluid into a subterranean formation (for example, to less than about 10 barrels of fluid per hour.)
- the methods of the present invention may facilitate improved control over the placement of treatment fluids in a subterranean formation, increased fluid efficiency in various subterranean treatments, diversion of subsequently injected fluids to other portions of the subterranean formation, and/or more complete treatment of certain portions of a subterranean formation.
- treatment fluids comprising a scale inhibitor may also provide a further benefit, such as scale inhibition.
- the treatment fluids may be removed from a subterranean formation without the need for additional breakers or other additives.
- Treatment fluids suitable for use in the present invention generally comprise a base fluid and a plurality of particulates comprising a scale inhibitor and/or a chelating agent, wherein the particulates are substantially insoluble in the base fluid.
- Suitable base fluids may include aqueous fluids such as freshwater, saltwater, brine, seawater, produced water, chelate solutions, and acidic solutions (e.g. , hydrochloric acid, acetic acid, formic acid, lactic acid, hydrofluoric acid, boronic acid, etc.).
- Suitable base fluids may also include nonaqueous fluids such as hydrocarbon based fluids (e.g., diesel, glycols).
- the base fluid may be from any source, provided that it does not contain components that may adversely affect other components in the treatment fluid.
- the treatment fluids of the present invention may be foamed or unfoamed.
- One of ordinary skill in the art with the benefit of this disclosure would be able to select an appropriate base fluid based on the application in which the treatment fluid would be used, the type of particulates used, etc.
- the treatment fluids of the present invention may comprise a plurality of particulates comprising a scale inhibitor, wherein the particulates are substantially insoluble in the base fluid.
- suitable scale inhibitors for use in the present invention may be any scale inhibitor in particulate form that is substantially insoluble in the base fluid.
- Suitable scale inhibitors generally include, but are not limited to bis(hexamethylene triamine penta(methylene phosphonic acid)); diethylene triamine penta(methylene phosphonic acid); ethylene diamine tetra(methylene phosphonic acid); hexamethylenediamine tetra(methylene phosphonic acid); 1 -hydroxy ethylidene-1 ,1-diphosphonic acid; 2-hydroxy phosphonocarboxylic acid; 2-phosphonobutane-1 ,2,4-tricarboxylic acid; phosphino carboxylic acid; diglycol amine phosphonate; aminotris(methanephosphonic acid); methylene phosphonates; phosphonic acids; aminoalkylene phosphonic acids; aminoalkyl phosphonic acids; polyphosphates, salts thereof (such as but not limited to: sodium, potassium, calcium, magnesium, ammonium); and combinations thereof.
- the treatment fluids of the present invention may comprise a plurality of particulates comprising a chelating agent, wherein the particulates are substantially insoluble in the base fluid.
- the chelating agents useful in the present invention may be any suitable chelating agent in particulate form that is substantially insoluble in the base fluid.
- Suitable chelating agents generally include, but are not limited to, the acidic forms of the following: ethylenediaminetetraacetic acid (EDTA), hydroxyethyl ethylenediamine triacetic acid (HEDTA), nitrilotriacetic acid (NTA), diethylene triamine pentaacetic acid (DTPA), glutamic acid diacetic acid (GLDA), glucoheptonic acid (CSA), propylene diamine tetraacetic acid (PDTA), ethylenediaminedisuccinic acid (EDDS), diethanolglycine (DEG), ethanoldiglycine (EDG), glucoheptonate, citric acid, malic acid, phosphates, amines, citrates, derivatives thereof, and combinations thereof.
- EDTA ethylenediaminetetraacetic acid
- HEDTA hydroxyethyl ethylenediamine triacetic acid
- NTA nitrilotriacetic acid
- DTPA diethylene triamine pent
- chelating agents may include the acidic forms of chelating agents classified as polyphosphates (such as sodium tripolyphosphate and hexametaphosphoric acid), aminocarboxylic acids (such as N-dihydroxyethylglycine), aminopolycarboxylates, 1 ,3-diketones (such as acetylacetone, trifluoroacetylacetone, and thenoyltrifluoroacetone), hydroxy carboxylic acids (such as tartaric acid, gluconic acid and 5-sulfosalicylic acid), polyamines (such as ethylenediamine, dethylentriamine, triethylenetetramine, and triaminotriethylamine), aminoalcohols (such as triethanolamine, N- hydroxyethylethylenediamine), aromatic heterocyclic bases (such as dipyridyl and o- phenanthroline), phenols (such as salicylaldehyde, disulfopyrocatechol,
- particulates comprising a scale inhibitor and/or a chelating agent suitable for use in the present invention are substantially insoluble in a base fluid, but are substantially soluble when contacted with a solubilizing agent. Therefore, once the treatment operation has been completed, a solubilizing agent may be introduced into the wellbore (or may be already present in the subterranean formation) whereby the particulate comprising a scale inhibitor or a chelating agent is dissolved.
- the solubilizing agent may have the effect of causing the particulate comprising a scale inhibitor and/or a chelating agent to form its free acid, to dissolve, to hydrolyze into solution, to form its salt, to change salts, etc. and thereby become soluble.
- solubilizing agents include salts, including ammonium salts, aqueous fluids (e.g., brine), formation fluids (e.g., produced formation water, returned load water, etc.), acidic fluids, and spent acid.
- aqueous fluids e.g., brine
- formation fluids e.g., produced formation water, returned load water, etc.
- acidic fluids e.g., sodium bicarbonate
- spent acid e.g., sodium bicarbonate
- the type of solubilizing agent used generally depends upon the type of particulate to be solubilized.
- solubilizing agents comprising acidic fluids may be suitable for use with polymeric scale inhibitors.
- One of ordinary skill in the art with the benefit of this disclosure will be able to select an appropriate solubilizing agent based on the type of scale inhibitor and/or chelating agent used.
- Particulates comprising a scale inhibitor and/or a chelating agent may be present in the treatment fluids of the present invention in an amount ranging from a lower limit of about 0.5% by weight of the treatment fluid, 1 %, 2%, 3%, or 4%, to an upper limit of about 15% by weight of the treatment fluid, 12%, 10%, 8%, 7%, 6%, or 5%, and wherein the percentage of particulates may range from any lower limit to any upper limit and encompass any subset between the upper and lower limits.
- the treatment fluids of the present invention generally comprise a plurality of substantially insoluble particulates comprising a scale inhibitor and/or a chelating agent.
- the size of the particulates present in the treatment fluid may vary depending upon the application in which they will be used, the type of base fluid, screen size, slot size, and the pore sizes, proppant sizes, and/or permeability of the formation.
- the particulates may have a size range from a lower limit of greater than about 2 microns, 4 microns, 6 microns, 8 microns, 10 microns, 12 microns, or 15 microns to an upper limit of less than about 1000 microns, 500 microns, 400 microns, 300 microns, 200 microns, 175 microns, or 150 microns, where the size may range from any lower limit to any upper limit and encompass an subset between the upper and lower limits.
- the particulates comprising a scale inhibitor or a chelating agent may be smaller than the proppant.
- Additional additives may be included in the treatment fluids of the present invention as deemed appropriate for a particular application by one skilled in the art, with the benefit of this disclosure.
- additives include, but are not limited to, acids, weighting agents, surfactants, antifoaming agents, bactericides, salts, foaming agents, fluid loss control additives, relative permeability modifiers, viscosifying agents, proppant particulates, gel breakers, clay stabilizers, friction reducers, corrosion inhibitors, cross-linking agents, scale inhibitors, chelating agents, and combinations thereof.
- the treatment fluids of the present invention may comprise no proppant particulates.
- the treatment fluids may optionally comprise an acid generating compound.
- acid generating compounds that may be suitable for use in the present invention include, but are not limited to, esters, aliphatic polyesters, ortho esters, which may also be known as ortho ethers, poly(ortho esters), which may also be known as poly(ortho ethers), poly(lactides), poly(glycolides), poly(e- caprolactones), poly(hydroxybutyrates), poly(anhydrides), or copolymers thereof. Derivatives and combinations also may be suitable.
- copolymer as used herein is not limited to the combination of two polymers, but includes any combination of polymers, e.g., terpolymers and the like.
- esters including, but not limited to, ethylene glycol monoformate, ethylene glycol diformate, diethylene glycol diformate, glyceryl monoformate, glyceryl diformate, glyceryl triformate, triethylene glycol diformate and formate esters of pentaerythritol.
- esters including, but not limited to, ethylene glycol monoformate, ethylene glycol diformate, diethylene glycol diformate, glyceryl monoformate, glyceryl diformate, glyceryl triformate, triethylene glycol diformate and formate esters of pentaerythritol.
- Particulates comprising a scale inhibitor and/or a chelating agent suitable for use in the present invention may be at least partially coated and/or encapsulated with slowly water soluble or other similar encapsulating materials.
- water soluble and other similar encapsulating materials which can be utilized include, but are not limited to, porous solid materials such as precipitated silica, elastomers, polyvinylidene chloride (PVDC), nylon, waxes, polyurethanes, cross-linked partially hydrolyzed acrylics and the like.
- the treatment fluids of the present invention may be used for diversion in a variety of subterranean operations.
- the methods comprise: providing a treatment fluid of the present invention that comprises a base fluid and a plurality of particulates comprising a scale inhibitor and/or a chelating agent, wherein the particulates are substantially insoluble in the base fluid; introducing the treatment fluid into a wellbore that penetrates a subterranean formation; and allowing at least a first portion of the treatment fluid to penetrate into a portion of the subterranean formation so that the particulates present in the portion of the subterranean formation substantially divert a second portion of the treatment fluid or another fluid to another portion of the subterranean formation.
- particulates in the portion of the subterranean formation should form a barrier such that any fluid subsequently introduced into the wellbore should be substantially diverted to another portion of the subterranean formation.
- particulates comprising scale inhibitors may also provide the additional benefit of inhibiting scale formation.
- the plurality of particulates comprising a scale inhibitor and/or a chelating agent may be mixed with the base fluid and introduced into a portion of the subterranean formation between stages of a treatment or as a pretreatment.
- the treatment fluids of the present invention may be self-diverting.
- the plurality of particulates comprising a scale inhibitor and/or a chelating agent may be included in the treatment fluid during the subterranean treatment.
- the plurality of particulates comprising a scale inhibitor andA>r a chelating agent may progressively divert the treatment fluid to another portion of the subterranean formation. For instance, as a first portion of the treatment fluid penetrates into a portion of the subterranean formation a second portion of the treatment fluid may be diverted to another portion of the subterranean formation.
- the particulates comprising a scale inhibitor or a chelating agent of the present invention may be added to any treatment fluid in which it is desirable to control fluid loss.
- examples may include, but are not limited to, fracturing fluids, drill-in fluids, gravel pack fluids, and fluid loss control pills.
- Hydraulic fracturing operations are stimulation techniques that generally involve pumping a treatment fluid ⁇ e.g., a fracturing fluid) into a wellbore that penetrates a subterranean formation at a sufficient hydraulic pressure to create or enhance one or more cracks, or "fractures," in the subterranean formation.
- the fracturing fluid may comprise particulates, often referred to as "proppant,” that are deposited in the fractures.
- the proppant particulates inter alia, prevent the fractures from fully closing upon the release of hydraulic pressure, forming conductive channels through which fluids may flow to the wellbore.
- the fracturing fluid may be "broken" (i.e., the viscosity is reduced), and the fracturing fluid may be recovered from the formation. Any fracturing fluid that is suitable for use in subterranean formations may be used in conjunction with the present invention.
- the methods of the present invention may be used prior to, during, or subsequent to a variety of subterranean operations known in the art.
- operations include, but are not limited to, drilling operations, fracturing operations (including prepad, pad and flush), perforation operations, sand control treatments (e.g., gravel packing, resin consolidation including the various stages such as preflush, afterflush, etc.), acidizing treatments (e.g., matrix acidizing or fracture acidizing), "frac-pack” treatments, cementing treatments, water control treatments, wellbore clean-out treatments, paraffin/wax treatments, scale treatments, and "squeeze treatments.”
- the treatment fluids of the present invention may be placed into the subterranean formation at a pressure below the fracture pressure of the subterranean formation.
- the treatment fluids of the present invention may be placed into the subterranean formation at a pressure above the fracture pressure of the subterranean formation.
- the treatment fluids of the present invention may be placed into the subterranean formation at a pressure equal to the fracture pressure of the subterranean formation.
Abstract
Description
Claims
Priority Applications (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CA2827973A CA2827973C (en) | 2011-03-24 | 2012-03-22 | Methods of fluid loss control and fluid diversion in subterranean formations |
AU2012232911A AU2012232911B2 (en) | 2011-03-24 | 2012-03-22 | Methods of fluid loss control and fluid diversion in subterranean formations |
MX2013010866A MX2013010866A (en) | 2011-03-24 | 2012-03-22 | Methods of fluid loss control and fluid diversion in subterranean formations. |
EP12712705.8A EP2688975A1 (en) | 2011-03-24 | 2012-03-22 | Methods of fluid loss control and fluid diversion in subterranean formations |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/070,511 | 2011-03-24 | ||
US13/070,511 US20110168395A1 (en) | 2009-07-30 | 2011-03-24 | Methods of Fluid Loss Control and Fluid Diversion in Subterranean Formations |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2012127191A1 true WO2012127191A1 (en) | 2012-09-27 |
Family
ID=45932440
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/GB2012/000263 WO2012127191A1 (en) | 2011-03-24 | 2012-03-22 | Methods of fluid loss control and fluid diversion in subterranean formations |
Country Status (6)
Country | Link |
---|---|
US (1) | US20110168395A1 (en) |
EP (1) | EP2688975A1 (en) |
AU (1) | AU2012232911B2 (en) |
CA (1) | CA2827973C (en) |
MX (1) | MX2013010866A (en) |
WO (1) | WO2012127191A1 (en) |
Cited By (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2014070599A1 (en) * | 2012-10-30 | 2014-05-08 | Halliburton Energy Services, Inc. | Compositions and methods related to mitigating aluminum and ferric precipitates in subterranean formations after acidizing operations |
US9803134B2 (en) | 2008-01-09 | 2017-10-31 | Akzo Nobel Chemicals International B.V. | Acidic aqueous solution containing a chelating agent and the use thereof |
WO2018203884A1 (en) * | 2017-05-02 | 2018-11-08 | Halliburton Energy Services, Inc. | Nanosized particulates for downhole applications |
WO2021209795A1 (en) * | 2020-04-17 | 2021-10-21 | Italmatch Chemicals S.P.A. | New synergic composition for scale inhibition |
Families Citing this family (13)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN102358834B (en) * | 2011-08-02 | 2013-03-20 | 东北石油大学 | Solid descaling acid rod for oil well |
JP6056183B2 (en) * | 2012-04-27 | 2017-01-11 | 富士電機株式会社 | Scale suppression device, geothermal power generation system using the device, and scale suppression method |
JP5906926B2 (en) * | 2012-04-27 | 2016-04-20 | 富士電機株式会社 | Scale suppression device, geothermal power generation system using the device, and scale suppression method |
US9879503B2 (en) | 2012-09-19 | 2018-01-30 | Halliburton Energy Services, Inc. | Methods of treating long-interval and high-contrast permeability subterranean formations with diverting fluids |
WO2014164835A1 (en) * | 2013-03-13 | 2014-10-09 | M-I Drilling Fluids U.K. Limited | Chelant acid particulate bridging solids for acid based wellbore fluids |
GB2542080B (en) * | 2014-09-30 | 2021-08-04 | Halliburton Energy Services Inc | Non-reducing stabilization complexant for acidizing compositions and associated methods |
US10421893B2 (en) | 2015-11-04 | 2019-09-24 | Halliburton Energy Services, Inc. | Encapsulated scale inhibitor for downhole applications in subterranean formations |
CA3009163C (en) | 2016-03-29 | 2020-08-25 | Halliburton Energy Services, Inc. | Multifunctional solid particulate diverting agent |
MX2018014196A (en) | 2016-06-13 | 2019-06-03 | Halliburton Energy Services Inc | Methods and systems incorporating n-(phosphonoalkyl)iminodiacetic acid particulates. |
US10723939B2 (en) | 2016-06-27 | 2020-07-28 | Halliburton Energy Services, Inc. | Methods and compositions for treating a subterranean formation with a polymeric additive composite |
US10982124B2 (en) * | 2017-11-06 | 2021-04-20 | Saudi Arabian Oil Company | Drill-in fluid compositions and methods |
CN108384528B (en) * | 2018-03-12 | 2020-07-10 | 中国石油天然气股份有限公司 | Diverting agent for diverting and acidifying water injection well and preparation method thereof |
WO2020106273A1 (en) | 2018-11-19 | 2020-05-28 | Halliburton Energy Services, Inc. | Oil-based drill-in fluid with enhanced fluid loss properties |
Citations (8)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB2298440A (en) * | 1995-02-28 | 1996-09-04 | Atomic Energy Authority Uk | Well treatment |
US5624886A (en) * | 1992-07-29 | 1997-04-29 | Bj Services Company | Controlled degradation of polysaccharides |
US20040043906A1 (en) * | 2000-06-06 | 2004-03-04 | Heath Stephen Mark | Microcapsule well treatment |
WO2004046494A2 (en) * | 2002-11-18 | 2004-06-03 | Saudi Arabian Oil Company | Method using particulate chelates to stimulate production of petroleum in carbonate formations |
US20050028976A1 (en) * | 2003-08-05 | 2005-02-10 | Nguyen Philip D. | Compositions and methods for controlling the release of chemicals placed on particulates |
US6877563B2 (en) | 2003-01-21 | 2005-04-12 | Halliburton Energy Services, Inc. | Methods of drilling and completing well bores |
US20070173418A1 (en) * | 2003-09-09 | 2007-07-26 | Halliburton Energy Services,Inc. | Treatment fluids comprising starch and ceramic particulate bridging agents and methods of using these fluids to provide fluid loss control |
WO2009016545A2 (en) * | 2007-07-27 | 2009-02-05 | Schlumberger Canada Limited | System, method, and apparatus for combined fracturing treatment and scale inhibition |
Family Cites Families (13)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4051900A (en) * | 1974-06-13 | 1977-10-04 | Dale Hankins | Propping material for hydraulic fracturing |
US4986354A (en) * | 1988-09-14 | 1991-01-22 | Conoco Inc. | Composition and placement process for oil field chemicals |
GB9611422D0 (en) * | 1996-05-31 | 1996-08-07 | Bp Exploration Operating | Coated scale inhibitors |
US6114410A (en) * | 1998-07-17 | 2000-09-05 | Technisand, Inc. | Proppant containing bondable particles and removable particles |
WO2003099890A2 (en) * | 2002-05-24 | 2003-12-04 | Castrol Limited | Preparation of monomers for grafting to polyolefins, and lubricating oil compositions containing grafted copolymer |
US6985816B2 (en) * | 2003-09-15 | 2006-01-10 | Pinnacle Technologies, Inc. | Methods and systems for determining the orientation of natural fractures |
US7380600B2 (en) * | 2004-09-01 | 2008-06-03 | Schlumberger Technology Corporation | Degradable material assisted diversion or isolation |
US7237610B1 (en) * | 2006-03-30 | 2007-07-03 | Halliburton Energy Services, Inc. | Degradable particulates as friction reducers for the flow of solid particulates and associated methods of use |
US7699106B2 (en) * | 2007-02-13 | 2010-04-20 | Bj Services Company | Method for reducing fluid loss during hydraulic fracturing or sand control treatment |
US7886822B2 (en) * | 2007-07-27 | 2011-02-15 | Schlumberger Technology Corporation | System, method, and apparatus for acid fracturing with scale inhibitor protection |
US7806182B2 (en) * | 2007-10-25 | 2010-10-05 | Schlumberger Technology Corporation | Stimulation method |
US8697612B2 (en) * | 2009-07-30 | 2014-04-15 | Halliburton Energy Services, Inc. | Increasing fracture complexity in ultra-low permeable subterranean formation using degradable particulate |
US20110188347A1 (en) * | 2010-01-29 | 2011-08-04 | Schlumberger Technology Corporation | Volume imaging for hydraulic fracture characterization |
-
2011
- 2011-03-24 US US13/070,511 patent/US20110168395A1/en not_active Abandoned
-
2012
- 2012-03-22 WO PCT/GB2012/000263 patent/WO2012127191A1/en active Application Filing
- 2012-03-22 EP EP12712705.8A patent/EP2688975A1/en not_active Withdrawn
- 2012-03-22 CA CA2827973A patent/CA2827973C/en active Active
- 2012-03-22 MX MX2013010866A patent/MX2013010866A/en unknown
- 2012-03-22 AU AU2012232911A patent/AU2012232911B2/en not_active Ceased
Patent Citations (9)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5624886A (en) * | 1992-07-29 | 1997-04-29 | Bj Services Company | Controlled degradation of polysaccharides |
GB2298440A (en) * | 1995-02-28 | 1996-09-04 | Atomic Energy Authority Uk | Well treatment |
US20040043906A1 (en) * | 2000-06-06 | 2004-03-04 | Heath Stephen Mark | Microcapsule well treatment |
WO2004046494A2 (en) * | 2002-11-18 | 2004-06-03 | Saudi Arabian Oil Company | Method using particulate chelates to stimulate production of petroleum in carbonate formations |
US6877563B2 (en) | 2003-01-21 | 2005-04-12 | Halliburton Energy Services, Inc. | Methods of drilling and completing well bores |
US7021383B2 (en) | 2003-01-21 | 2006-04-04 | Halliburton Energy Services, Inc. | Subterranean treatment fluids and methods of using these fluids to stimulate subterranean formations |
US20050028976A1 (en) * | 2003-08-05 | 2005-02-10 | Nguyen Philip D. | Compositions and methods for controlling the release of chemicals placed on particulates |
US20070173418A1 (en) * | 2003-09-09 | 2007-07-26 | Halliburton Energy Services,Inc. | Treatment fluids comprising starch and ceramic particulate bridging agents and methods of using these fluids to provide fluid loss control |
WO2009016545A2 (en) * | 2007-07-27 | 2009-02-05 | Schlumberger Canada Limited | System, method, and apparatus for combined fracturing treatment and scale inhibition |
Cited By (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9803134B2 (en) | 2008-01-09 | 2017-10-31 | Akzo Nobel Chemicals International B.V. | Acidic aqueous solution containing a chelating agent and the use thereof |
WO2014070599A1 (en) * | 2012-10-30 | 2014-05-08 | Halliburton Energy Services, Inc. | Compositions and methods related to mitigating aluminum and ferric precipitates in subterranean formations after acidizing operations |
US8887805B2 (en) | 2012-10-30 | 2014-11-18 | Halliburton Energy Services, Inc. | Compositions and methods related to mitigating aluminum and ferric precipitates in subterranean formations after acidizing operations |
WO2018203884A1 (en) * | 2017-05-02 | 2018-11-08 | Halliburton Energy Services, Inc. | Nanosized particulates for downhole applications |
US11572501B2 (en) | 2017-05-02 | 2023-02-07 | Halliburton Energy Services, Inc. | Nanosized particulates for downhole applications |
WO2021209795A1 (en) * | 2020-04-17 | 2021-10-21 | Italmatch Chemicals S.P.A. | New synergic composition for scale inhibition |
Also Published As
Publication number | Publication date |
---|---|
EP2688975A1 (en) | 2014-01-29 |
CA2827973C (en) | 2016-05-03 |
CA2827973A1 (en) | 2012-09-27 |
MX2013010866A (en) | 2013-10-17 |
US20110168395A1 (en) | 2011-07-14 |
AU2012232911A1 (en) | 2013-09-05 |
AU2012232911B2 (en) | 2015-04-23 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
CA2827973C (en) | Methods of fluid loss control and fluid diversion in subterranean formations | |
US20110028358A1 (en) | Methods of Fluid Loss Control and Fluid Diversion in Subterranean Formations | |
CA2587430C (en) | Composition and method for treating a subterranean formation | |
US20140124205A1 (en) | Process to fracture a subterranean formation using a chelating agent | |
AU2011343384B2 (en) | Treatment of illitic formations using a chelating agent | |
US9803130B2 (en) | Methods of activating enzyme breakers | |
US20140116710A1 (en) | Treatment of shale formatons using a chelating agent | |
EP2841525A1 (en) | Foam or viscosified composition containing a chelating agent | |
WO2006030383A2 (en) | Selective fracture face dissolution | |
MX2007001741A (en) | Methods for controlling fluid loss. | |
US10150910B2 (en) | Well treatment fluids comprising cross-linkable polysaccharides | |
WO2013160334A1 (en) | One step process to remove filter cake and treat a subterranean formation with a chelating agent | |
WO2004046494A2 (en) | Method using particulate chelates to stimulate production of petroleum in carbonate formations | |
US20170349818A1 (en) | Methods of activating enzyme breakers | |
US11466200B2 (en) | Multi-functional diverter particulates | |
MX2007005574A (en) | Composition and method for treating a subterranean formation |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 12712705 Country of ref document: EP Kind code of ref document: A1 |
|
ENP | Entry into the national phase |
Ref document number: 2827973 Country of ref document: CA |
|
ENP | Entry into the national phase |
Ref document number: 2012232911 Country of ref document: AU Date of ref document: 20120322 Kind code of ref document: A |
|
WWE | Wipo information: entry into national phase |
Ref document number: MX/A/2013/010866 Country of ref document: MX |
|
NENP | Non-entry into the national phase |
Ref country code: DE |
|
REEP | Request for entry into the european phase |
Ref document number: 2012712705 Country of ref document: EP |
|
WWE | Wipo information: entry into national phase |
Ref document number: 2012712705 Country of ref document: EP |