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US20130008654A1 - Method for Drilling and Completion Operations with Settable Resin Compositions - Google Patents

Method for Drilling and Completion Operations with Settable Resin Compositions Download PDF

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Publication number
US20130008654A1
US20130008654A1 US13/176,708 US201113176708A US2013008654A1 US 20130008654 A1 US20130008654 A1 US 20130008654A1 US 201113176708 A US201113176708 A US 201113176708A US 2013008654 A1 US2013008654 A1 US 2013008654A1
Authority
US
United States
Prior art keywords
density
resin composition
borehole
resin
drilling fluid
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Abandoned
Application number
US13/176,708
Other languages
English (en)
Inventor
Jay Paul Deville
Kay Ann Morris
Greg Paul Perez
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Halliburton Energy Services Inc
Original Assignee
Halliburton Energy Services Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Halliburton Energy Services Inc filed Critical Halliburton Energy Services Inc
Priority to US13/176,708 priority Critical patent/US20130008654A1/en
Assigned to HALLIBURTON ENERGY SERVICES, INC. reassignment HALLIBURTON ENERGY SERVICES, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: DEVILLE, JAY PAUL, MORRIS, Kay Ann, PEREZ, GREG PAUL
Priority to DK12738305.7T priority patent/DK2729547T3/en
Priority to CA2841788A priority patent/CA2841788C/en
Priority to EA201490207A priority patent/EA027874B1/ru
Priority to EP20120738305 priority patent/EP2729547B1/en
Priority to BR112014000046A priority patent/BR112014000046A2/pt
Priority to MX2013015268A priority patent/MX2013015268A/es
Priority to PCT/US2012/045475 priority patent/WO2013006657A1/en
Priority to ARP120102427A priority patent/AR086458A1/es
Priority to AU2012279069A priority patent/AU2012279069B2/en
Publication of US20130008654A1 publication Critical patent/US20130008654A1/en
Abandoned legal-status Critical Current

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
    • C09K8/02—Well-drilling compositions
    • C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
    • C—CHEMISTRY; METALLURGY
    • C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B26/00—Compositions of mortars, concrete or artificial stone, containing only organic binders, e.g. polymer or resin concrete
    • C04B26/02—Macromolecular compounds
    • C04B26/10—Macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
    • C04B26/14—Polyepoxides
    • 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
    • C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
    • C09K8/44—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing organic binders only
    • 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
    • C09K8/502—Oil-based compositions

Definitions

  • the present invention relates to compositions and methods for drilling, cementing and casing boreholes in subterranean formations, particularly hydrocarbon bearing formations. More particularly, the present invention relates to cementing wellbores in narrow fracture gradient wells.
  • Stabilization includes preventing unwanted fluid or gas flow into or out of the wellbore, preventing the flow of particulates into the wellbore, and mitigating formation compressive or tensile failure.
  • Wellbore stability depends on the mechanical and chemical interaction between the wellbore fluids and the walls of the wellbore itself.
  • a stable wellbore is essential during the drilling, completion, and production phases for maximizing the well's economic potential.
  • the term “fracture gradient” means the hydraulic pressure per unit depth required to be exerted in a subterranean stratum to cause fractures therein.
  • the term “narrow fracture gradient zone” shall be understood to be an area of a subterranean formation where the formation has a formation-fracture pressure and a pore pressure that differ by less than 1 lb/gal in equivalent weight with respect to the narrow fracture gradient and less than 500 psi in other terms.
  • SWF shallow-water-flow
  • the cementing operations focus on providing a competent seal between the cement and the formation, and between the cement and the casing, and on providing a competent sheath to last the life of the well.
  • a principal challenge in slurry design is the small fracture-gradient/pore-pressure window.
  • the zone's fracture gradient may limit the slurry density to 12 lb/gal, while formation pore pressure can wash away a slurry with a density less than 11.5 lb/gal.
  • a string of pipe such as casing is cemented in a wellbore.
  • a hydraulic cement composition is pumped into the annular space between the walls of the wellbore and the exterior of a string of pipe disposed therein.
  • the cement composition is permitted to set in the annular space thereby forming an annular sheath of hardened substantially impermeable cement therein.
  • the cement sheath physically supports and positions the pipe in the wellbore and bonds the pipe to the walls of the wellbore preventing undesirable migration of fluids between zones or formations penetrated by the wellbore.
  • Oil based drilling fluids are normally used to drill swelling or sloughing shales, salt, gypsum, anhydrite or other evaporate formations, hydrogen sulfide-containing formations, and hot or high temperature (greater than about 300 degrees Fahrenheit (“° F.”)) holes, and may be used in other holes penetrating a subterranean formation as well.
  • oil based drilling fluids are commonly used in drilling through formations having narrow fracture gradient zones.
  • cement on the other hand is mixed and used as a water based slurry and thus is inherently incompatible with oil based drilling fluids.
  • the present invention provides improved methods of conducting completion operations through narrow fracture gradients in subterranean formations, following drilling with oil-based drilling fluids or muds.
  • cementing or “cementing operations” shall be generally understood to include operations for casing a borehole as well as operations for cementing a borehole unless stated otherwise.
  • the present invention provides a cement-alternative composition and method that allows for improved equivalent circulating density (ECD) control in narrow fracture gradient zones or wellbores and that is compatible with oil-based drilling fluids.
  • ECD equivalent circulating density
  • the present invention provides an epoxy-based resin system comprising an epoxy resin. Densities are controlled with added solids. According to the method of the invention, through a combination of solids of varying densities and particle sizes, resin density is adjusted to approximate that of the drilling fluid used in the drilling.
  • the resin system of the present invention is highly tunable, with controllable density and rheology that is compatible with oil based drilling fluids. This compatibility reduces the need for spacers that commonly must be used when using cement in a well drilled with oil-based mud to render the surfaces touched by the oil-based mud water-wet.
  • the epoxy-based resin system used in well completion operations in the present invention comprises an epoxy resin.
  • the epoxy-based resin system also comprises an amine hardener and an amine accelerator.
  • various epoxide containing liquids can be used in making the resin composition, preferred such liquids are the diglycidyl ether of 1,4-butanediol, the diglycidyl ether of neopentylglycol, the diglycidyl ether of bisphenol A, and the diglycidyl ether of cyclohexanedimethanol.
  • a suitable epoxide containing liquid comprised of the diglycidyl ether of 1,4-butanediol is commercially available from the Shell Chemical Company under the trade name “HELOXY®67.” This epoxide containing liquid has a viscosity at 25° C. in the range of from about 13 to about 18 centipoises, a molecular weight of 202 and a one gram equivalent of epoxide per about 120 to about 130 grams of the liquid.
  • a suitable diglycidyl ether of neopentylglycol is commercially available from Shell Chemical Company under the trade name “HELOXY®68.” This epoxide containing liquid has a viscosity at 25° C.
  • epoxide containing liquid has a viscosity at 25° C. in the range of from about 55 to about 75 centipoises, a molecular weight of 256 and a one gram equivalent of epoxide per about 155 to about 165 grams of the liquid.
  • the epoxide containing liquid or mixture is generally present in an amount in the range of from about 20% to about 80% by weight of the epoxy composition, and preferably in an amount of about 50%.
  • a variety of hardening agents including, but not limited to, aliphatic amines, amide amines, amido amines, imidazoles, aliphatic tertiary amines, aromatic amines, cycloaliphatic amines, heterocyclic amines, polyamides, polyethylamines and carboxylic acid anhydrides can be used in the epoxy-based resin compositions of this invention containing the above described epoxide containing materials. Of these, aliphatic amines, aromatic amines and carboxylic acid anhydrides are the most suitable.
  • Examples of aliphatic and aromatic amine hardening agents are triethylenetetraamine, ethylenediamine, N-cocoalkyltrimethylenediamine, isophoronediamine, diethyltoluenediamine, and tris(dimethylaminomethylphenol).
  • suitable carboxylic acid anhydrides are methyltetrahydrophthalic anhydride, hexahydrophthalic anhydride, maleic anhydride, polyazelaic polyanhydride and phthalic anhydride.
  • triethylenetetraamine, ethylenediamine, N-cocoalkyltrimethylenediamine, isophoronediamine, diethyltoluenediamine and tris(dimethylaminomethylphenol) are preferred, with isophoronediamine, diethyltoluenediamine and tris(dimethylaminomethylphenol) being the most preferred.
  • the hardening agent or agents used are included in the epoxy-based resin compositions of the present invention in an amount in the range of from about 20% to about 50% by weight of the compositions.
  • the epoxy-based composition of the present invention comprises an amine accelerator such as diethyltoluenediamine for a non-limiting example.
  • the epoxy-based composition of the invention may also include a particulate filler such as crystalline silicas, amorphous silicas, clays, calcium carbonate or barite.
  • a commercial product, STEELSEAL®, resilient carbon based lost circulation material available from Halliburton Inc. in Duncan, Okla. and Houston, Tex. might also be used as a filler in the present invention.
  • a filler it is added to an epoxy composition of this invention in an amount in the range of from about 100% to about 300% by weight of the composition.
  • An organosilane compound can optionally be included in the epoxy-based resin composition.
  • the organosilane functions in the resin to impart high subterranean strata surface bond strengths to the compositions.
  • the organosilane compound undergoes hydrolysis in the presence of trace quantities of water whereby trialkoxysilanols are formed which dehydrate and form strong bonds. That is, the dehydration results in the formation of bonds with silica in the strata.
  • Suitable organosilane compounds include 3-aminopropyltrimethoxysilane, 3-aminopropyltriethoxysilane, N-2-(aminoethyl)-3-aminopropyltriethoxysilane and 3-glycidoxy-propyltrimethoxysilane. Of these, 3-glycidoxypropyltrimethoxysilane is preferred.
  • the organosilane compound is included in an epoxy-based resin composition of this invention in an amount in the range of from about 0.1% to about 5% by weight of the resin composition, preferably in an amount of about 0.5%.
  • Density of the epoxy-resin based composition is controlled with added solids.
  • the resin density is adjusted to approximate that of the drilling fluid used in the drilling.
  • smaller particles and higher volume percentages of solids cause increased or higher rheology.
  • Larger particles contribute less to the rheology of the resins but are more prone to settling out at the cure temperature of the epoxy. Thus, a balance in the particles is obtained to reach the desired density.
  • Non-limiting examples of solids that might be used for this purpose in the invention are silica flour, micronized sand, sand of several mesh sizes, barite, calcium carbonate, polystyrene beads, hematite, manganese tetroxide, graphite. Hollow glass spheres may also be used to lower density, even below the density of the neat resin.
  • cement is often 0.5 to 1.0 lb/gal heavier than the drilling fluid used. However, ideally, the rheology of the drilling fluid and cement or the drilling fluid and the resin of the invention will be the same.
  • An advantage of the present invention is the flexibility the epoxy-based resin composition of the invention affords to adjusting the density and rheology of the composition. This flexibility enables the composition to be used in completing wellbores penetrating narrow gradient zones with substantial reduction in or even elimination of the risk of fracturing the zone that would be associated with cementing the borehole with cement of the prior art.
  • Another advantage of the present invention is its compatibility with oil based muds, so that in use, spacers or treatments of surfaces which the oil based muds have contacted to render them water wet may not be needed.
  • prior art cement used in cementing is aqueous based and must have removal of traces of oil based mud for proper adhesion.
  • the present invention provides improved methods of conducting completion operations through narrow fracture gradients in subterranean formations, following drilling with oil-based drilling fluids.
  • a base or neat epoxy resin composition was prepared comprising 100 grams of epoxy resin, in this example a diglycidyl ether of cyclohexanedimethanol, 28 grams of amine hardener, in this example diethyltoluenediamine, and 3.5 grams of amine accelerator, in this example 2,4,6 tridimethylaminomethylphenol.
  • This base formulation also called “neat resin” herein
  • various solids were added to modify and adjust the density of the formulation, as indicated below in Table 1, to comprise different epoxy-resin based compositions of the invention.
  • Table 1 Each of the formulations in Table 1 used different combinations of solid particles to achieve desired resin densities. At the same time these formulations showed minimal observable settling and maintained reasonable, “mud-like” or drilling fluid type rheology, as indicated in Table 2 below.
  • Table 2 also provides the experimentally determined compressive strength for each sample. Compressive strength is a measure of the strength of the cured material and was measured after the sample was cured in a cube mold for 24 hours at 160° F. A compressive strength of greater than about 500 psi is considered acceptable for the purposes of this invention.
  • compositions of the invention demonstrate the compatibility of the compositions of the invention with oil based drilling fluids (OBM) and the consequent potential of the compositions to accomplish enhanced bonding.
  • OBM oil based drilling fluids
  • a base or neat epoxy resin composition was prepared as discussed above (see Table 1) and then contaminated with oil based drilling fluid and cured at 160° F. for 24 hours in a cube mold. Results for the mud compatibility testing are given in Table 3.
  • Table 3 demonstrates that even at 30% by volume drilling mud contamination, the epoxy-based resin compositions of the invention maintained an acceptable compressive strength. In the samples with substantial mud (20% and 30%), some degree of separation was observed between the mud and the resin formulation. However, despite this separation, the cured cube was solid with no liquid component remaining. The separation then only resulted in a visual distinction between layers of the cured cube.

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  • Chemical & Material Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Organic Chemistry (AREA)
  • Materials Engineering (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Ceramic Engineering (AREA)
  • Structural Engineering (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Epoxy Resins (AREA)
  • Compositions Of Macromolecular Compounds (AREA)
  • Curing Cements, Concrete, And Artificial Stone (AREA)
US13/176,708 2011-07-05 2011-07-05 Method for Drilling and Completion Operations with Settable Resin Compositions Abandoned US20130008654A1 (en)

Priority Applications (10)

Application Number Priority Date Filing Date Title
US13/176,708 US20130008654A1 (en) 2011-07-05 2011-07-05 Method for Drilling and Completion Operations with Settable Resin Compositions
AU2012279069A AU2012279069B2 (en) 2011-07-05 2012-07-04 Method for drilling and completion operations with settable resin compositions
EP20120738305 EP2729547B1 (en) 2011-07-05 2012-07-04 Method for drilling and completion operations with settable resin compositions
CA2841788A CA2841788C (en) 2011-07-05 2012-07-04 Method for drilling and completion operations with settable resin compositions
EA201490207A EA027874B1 (ru) 2011-07-05 2012-07-04 Способ осуществления бурения и заканчивания скважины с использованием смоляных композиций с заданными характеристиками
DK12738305.7T DK2729547T3 (en) 2011-07-05 2012-07-04 A method for drilling and completion operations with the curable resin compositions
BR112014000046A BR112014000046A2 (pt) 2011-07-05 2012-07-04 método para conduzir operações de perfuração e completação em um furo de sondagem para recuperação de hidrocarbonetos em uma formação subterrânea
MX2013015268A MX2013015268A (es) 2011-07-05 2012-07-04 Metodo para perforacion y operaciones de terminacion con composiciones de resina fraguable.
PCT/US2012/045475 WO2013006657A1 (en) 2011-07-05 2012-07-04 Method for drilling and completion operations with settable resin compositions
ARP120102427A AR086458A1 (es) 2011-07-05 2012-07-04 Metodo para operaciones de perforacion y completacion con composiciones de resina fraguables

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US13/176,708 US20130008654A1 (en) 2011-07-05 2011-07-05 Method for Drilling and Completion Operations with Settable Resin Compositions

Publications (1)

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US20130008654A1 true US20130008654A1 (en) 2013-01-10

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US13/176,708 Abandoned US20130008654A1 (en) 2011-07-05 2011-07-05 Method for Drilling and Completion Operations with Settable Resin Compositions

Country Status (10)

Country Link
US (1) US20130008654A1 (es)
EP (1) EP2729547B1 (es)
AR (1) AR086458A1 (es)
AU (1) AU2012279069B2 (es)
BR (1) BR112014000046A2 (es)
CA (1) CA2841788C (es)
DK (1) DK2729547T3 (es)
EA (1) EA027874B1 (es)
MX (1) MX2013015268A (es)
WO (1) WO2013006657A1 (es)

Cited By (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2015126408A1 (en) * 2014-02-21 2015-08-27 Halliburton Energy Services Inc. Cementing compositions and methods
US9796622B2 (en) 2013-09-09 2017-10-24 Saudi Arabian Oil Company Development of high temperature low density cement
CN111218260A (zh) * 2020-03-06 2020-06-02 中国石油大学(华东) 一种适用于油基钻井液的抗高温高吸油树脂颗粒堵漏剂及其制备方法
US10988664B2 (en) 2018-08-30 2021-04-27 Saudi Arabian Oil Company Compositions for sealing a lost circulation zone in a wellbore
WO2021126301A1 (en) * 2019-12-18 2021-06-24 Saudi Arabian Oil Company Lcm composition with controlled viscosity and cure time and methods of treating a lost circulation zone of a wellbore
WO2021126300A1 (en) * 2019-12-18 2021-06-24 Saudi Arabian Oil Company Epoxy-based lcm compositions with controlled viscosity and methods of treating a lost circulation zone of a wellbore
US11168243B2 (en) 2018-08-30 2021-11-09 Saudi Arabian Oil Company Cement compositions including epoxy resin systems for preventing fluid migration
US11193052B2 (en) 2020-02-25 2021-12-07 Saudi Arabian Oil Company Sealing compositions and methods of plugging and abandoning of a wellbore
US11236263B2 (en) 2020-02-26 2022-02-01 Saudi Arabian Oil Company Method of sand consolidation in petroleum reservoirs
US11326087B2 (en) 2018-08-30 2022-05-10 Saudi Arabian Oil Company Compositions for sealing an annulus of a wellbore
US11827841B2 (en) 2021-12-23 2023-11-28 Saudi Arabian Oil Company Methods of treating lost circulation zones

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US4917188A (en) * 1989-01-09 1990-04-17 Halliburton Company Method for setting well casing using a resin coated particulate
US4921047A (en) * 1989-08-10 1990-05-01 Conoco Inc. Composition and method for sealing permeable subterranean formations
US5712314A (en) * 1996-08-09 1998-01-27 Texaco Inc. Formulation for creating a pliable resin plug
US6065539A (en) * 1997-05-28 2000-05-23 Institute Francois Du Petrole Well cementing method and material containing fine particles
US5969006A (en) * 1997-08-18 1999-10-19 Halliburton Energy Services, Inc. Remedial well bore sealing methods
US20030079912A1 (en) * 2000-12-18 2003-05-01 Impact Engineering Solutions Limited Drilling system and method
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Cited By (20)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9796622B2 (en) 2013-09-09 2017-10-24 Saudi Arabian Oil Company Development of high temperature low density cement
GB2535423B (en) * 2014-02-21 2021-06-23 Halliburton Energy Services Inc Cementing compositions and methods
GB2535423A (en) * 2014-02-21 2016-08-17 Halliburton Energy Services Inc Cementing compositions and methods
US20170009122A1 (en) * 2014-02-21 2017-01-12 Halliburton Energy Services, Inc. Cementing compositions and methods
US11359128B2 (en) * 2014-02-21 2022-06-14 Halliburton Energy Services, Inc. Cementing compositions and methods
WO2015126408A1 (en) * 2014-02-21 2015-08-27 Halliburton Energy Services Inc. Cementing compositions and methods
US11168243B2 (en) 2018-08-30 2021-11-09 Saudi Arabian Oil Company Cement compositions including epoxy resin systems for preventing fluid migration
US11326087B2 (en) 2018-08-30 2022-05-10 Saudi Arabian Oil Company Compositions for sealing an annulus of a wellbore
US11472998B2 (en) 2018-08-30 2022-10-18 Saudi Arabian Oil Company Cement compositions including epoxy resin systems for preventing fluid migration
US11352541B2 (en) 2018-08-30 2022-06-07 Saudi Arabian Oil Company Sealing compositions and methods of sealing an annulus of a wellbore
US10988664B2 (en) 2018-08-30 2021-04-27 Saudi Arabian Oil Company Compositions for sealing a lost circulation zone in a wellbore
US10995256B2 (en) 2018-08-30 2021-05-04 Saudi Arabian Oil Company Lost circulation material compositions and methods of isolating a lost circulation zone of a wellbore
US11332656B2 (en) 2019-12-18 2022-05-17 Saudi Arabian Oil Company LCM composition with controlled viscosity and cure time and methods of treating a lost circulation zone of a wellbore
WO2021126300A1 (en) * 2019-12-18 2021-06-24 Saudi Arabian Oil Company Epoxy-based lcm compositions with controlled viscosity and methods of treating a lost circulation zone of a wellbore
US11370956B2 (en) 2019-12-18 2022-06-28 Saudi Arabian Oil Company Epoxy-based LCM compositions with controlled viscosity and methods of treating a lost circulation zone of a wellbore
WO2021126301A1 (en) * 2019-12-18 2021-06-24 Saudi Arabian Oil Company Lcm composition with controlled viscosity and cure time and methods of treating a lost circulation zone of a wellbore
US11193052B2 (en) 2020-02-25 2021-12-07 Saudi Arabian Oil Company Sealing compositions and methods of plugging and abandoning of a wellbore
US11236263B2 (en) 2020-02-26 2022-02-01 Saudi Arabian Oil Company Method of sand consolidation in petroleum reservoirs
CN111218260A (zh) * 2020-03-06 2020-06-02 中国石油大学(华东) 一种适用于油基钻井液的抗高温高吸油树脂颗粒堵漏剂及其制备方法
US11827841B2 (en) 2021-12-23 2023-11-28 Saudi Arabian Oil Company Methods of treating lost circulation zones

Also Published As

Publication number Publication date
EP2729547A1 (en) 2014-05-14
EA201490207A1 (ru) 2014-06-30
CA2841788C (en) 2015-11-24
MX2013015268A (es) 2014-07-09
WO2013006657A1 (en) 2013-01-10
EA027874B1 (ru) 2017-09-29
AR086458A1 (es) 2013-12-18
BR112014000046A2 (pt) 2017-02-07
AU2012279069B2 (en) 2014-11-27
EP2729547B1 (en) 2015-04-22
DK2729547T3 (en) 2015-07-06
CA2841788A1 (en) 2013-01-10

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