WO2020264289A1 - Procédés de traitement de puits - Google Patents

Procédés de traitement de puits Download PDF

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Publication number
WO2020264289A1
WO2020264289A1 PCT/US2020/039812 US2020039812W WO2020264289A1 WO 2020264289 A1 WO2020264289 A1 WO 2020264289A1 US 2020039812 W US2020039812 W US 2020039812W WO 2020264289 A1 WO2020264289 A1 WO 2020264289A1
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Prior art keywords
particles
drilling fluid
oil
cement
ibm
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PCT/US2020/039812
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English (en)
Inventor
Dominic Vincent PERRONI
Yan Gao
Anatoly Vladimirovich Medvedev
Bernhard Rudolf LUNGWITZ
Original Assignee
Schlumberger Technology Corporation
Schlumberger Canada Limited
Services Petroliers Schlumberger
Schlumberger Technology B.V.
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Publication of WO2020264289A1 publication Critical patent/WO2020264289A1/fr

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    • 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
    • C09K8/84—Compositions based on water or polar solvents
    • C09K8/86—Compositions based on water or polar solvents containing organic compounds
    • 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
    • C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
    • C04B28/006—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing mineral polymers, e.g. geopolymers of the Davidovits type
    • 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
    • C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
    • C04B28/02—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
    • 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
    • C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
    • C04B28/02—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
    • C04B28/021—Ash cements, e.g. fly ash cements ; Cements based on incineration residues, e.g. alkali-activated slags from waste incineration ; Kiln dust cements
    • 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
    • C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
    • C04B28/02—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
    • C04B28/04—Portland cements
    • 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
    • C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
    • C04B28/02—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
    • C04B28/06—Aluminous cements
    • 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
    • C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
    • C04B28/02—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
    • C04B28/08—Slag cements
    • 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
    • C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
    • C04B28/34—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing cold phosphate binders
    • 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
    • C09K8/46—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
    • C09K8/467—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
    • 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
    • C09K8/46—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
    • C09K8/467—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
    • C09K8/493—Additives for reducing or preventing gas migration
    • 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
    • C09K8/84—Compositions based on water or polar solvents
    • C09K8/86—Compositions based on water or polar solvents containing organic compounds
    • C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
    • 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
    • C09K8/84—Compositions based on water or polar solvents
    • C09K8/86—Compositions based on water or polar solvents containing organic compounds
    • C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
    • C09K8/887—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • 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
    • C04B2103/00—Function or property of ingredients for mortars, concrete or artificial stone
    • C04B2103/0068—Ingredients with a function or property not provided for elsewhere in C04B2103/00
    • C04B2103/0078—Sorbent materials
    • 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
    • C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
    • C09K2208/10—Nanoparticle-containing well treatment fluids
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P40/00—Technologies relating to the processing of minerals
    • Y02P40/10—Production of cement, e.g. improving or optimising the production methods; Cement grinding
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02W—CLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO WASTEWATER TREATMENT OR WASTE MANAGEMENT
    • Y02W30/00—Technologies for solid waste management
    • Y02W30/50—Reuse, recycling or recovery technologies
    • Y02W30/91—Use of waste materials as fillers for mortars or concrete

Definitions

  • the present disclosure relates generally to well cementing and stimulation.
  • the disclosure relates to improving zonal isolation by incorporating nanosize silica in fracturing fluids.
  • Hydraulic fracturing operations are those during which fluids are pumped into the well at rates such that the applied fluid pressure exceeds the fracturing pressure of the formation being treated.
  • the fracturing fluids are usually pumped through perforations in casing that are adjacent to the formation to be stimulated.
  • Most fracturing operations involve pumping two fluids.
  • the first fluid known as a pad fluid
  • the fracture may propagate along the pathway of least stress, forming "wings" that extend in two opposing directions away from the wellbore.
  • a second fluid known as a proppant slurry may be pumped through the perforations.
  • Proppant is a particulate material that is deposited inside the fracture, forming a proppant pack. When pumping pressure is released, the fracture closes upon the proppant pack.
  • the proppant pack is sufficiently permeable to allow efficient fluid flow from the formation to the wellbore, enabling the production of hydrocarbons.
  • a complete discussion of fracturing techniques may be found in the following publication. Economides MJ and Nolte KG (eds.): Reservoir Stimulation - 3rd Edition, Chichester, John Wiley & Sons Ltd. (2000).
  • Drilling fluid removal has been a subject of interest in the well-cementing community for many years because of its effect on cement quality and zonal isolation.
  • the principal objective of a primary cement job is to provide complete and permanent isolation of the formations behind the casing.
  • the drilling fluid and the preflushes should be fully removed from the annulus, and the annular space should be completely filled with cement slurry. Once in place, the cement should harden and develop the necessary mechanical properties to maintain a hydraulic seal throughout the life of the well. Therefore, efficient mud removal and proper slurry placement promote well isolation.
  • a cement slurry is prepared that comprises water, a hydraulic cement and particles of an oil-absorbent material.
  • the particles are present in an amount sufficient to interact with a non-aqueous component of a drilling fluid and alter a property of the drilling fluid within the subterranean well.
  • the drilling fluid contains calcium hydroxide.
  • the cement slurry is placed in the subterranean well.
  • the oil- absorbent particles contact the non-aqueous drilling fluid component, thereby altering the property of the non-aqueous component.
  • a hydraulic fracturing operation is performed, wherein a pad fluid comprises nanosize silica particles.
  • embodiments relate to methods for establishing zonal isolation in a subterranean well.
  • a subterranean well is drilled with a drilling fluid that contains calcium hydroxide.
  • a cement slurry is prepared that comprises water and a hydraulic cement.
  • the cement slurry is placed in the subterranean well wherein residual drilling fluid is present along casing and formation surfaces.
  • a hydraulic fracturing operation is performed, wherein a pad fluid comprises nanosize silica particles.
  • the nanosize silica particles contact the residual drilling fluid, thereby altering the property of the drilling fluid and creating a hydraulic seal in the subterranean well.
  • Fig. 1 a is a cross-sectional diagram showing 100% casing centralization in a wellbore.
  • Fig. 1 b is a cross-sectional diagram showing eccentric casing centralization, which may occur in deviated or horizontal well sections.
  • FIG. 2 is a cross-sectional diagram showing a drilling fluid channel arising from poor casing centralization in a wellbore.
  • Fig. 3 is a diagram showing a drilling fluid channel that has been deposited in the narrow region of an eccentric annulus and affected by the cement slurry according to the present disclosure.
  • Fig. 4 compares the rheological properties of diesel-based emulsion drilling fluids after exposure to cement slurries.
  • the amplitude dependent storage and loss moduli of drilling fluid exposed to a cement slurry containing oil-absorbent particles are higher than those of a drilling fluid exposed to a comparative slurry that did not contain absorbent particles.
  • Fig. 5 shows pressure test results for a conventional cement slurry and a cement slurry containing oil-absorbing particles.
  • Fig. 6 shows the viscosities of oils containing various oil-absorbent polymers.
  • Fig. 7 shows rheological data comparing the performance of a drilling fluid containing nanosilica compared to a control system without nanosilica.
  • a concentration range listed or described as being useful, suitable, or the like is intended that any and every concentration within the range, including the end points, is to be considered as having been stated.
  • “a range of from 1 to 10” is to be read as indicating each and every possible number along the continuum between about 1 and about 10.
  • casing 1 is present inside a wellbore having a wall 2.
  • An annulus 3 is therefore present between the casing and the wellbore wall.
  • Optimal drilling-fluid removal may occur when the casing is fully centralized in the wellbore (Fig. 1 a).
  • 100% casing centralization maximizes circulation efficiency because there are no narrow regions that may be resistant to fluid flow.
  • achieving 100% casing centralization may not be achievable in deviated or horizontal well sections (Fig. 1 b). Due to gravity, the casing has a tendency to migrate toward a borehole wall.
  • the present disclosure presents methods for altering drilling-fluid properties as well as achieving zonal isolation.
  • Embodiments may combat drilling fluid channels by interacting with the drilling fluid channels and altering properties of the drilling fluid channels.
  • the present disclosure further presents methods for achieving zonal isolation by performing fracturing operations that employ pad fluids that contain nanosize silica.
  • a cement slurry is prepared that comprises water, a hydraulic cement and particles of an oil-absorbent material.
  • the particles are present in an amount sufficient to interact with a non-aqueous component of a drilling fluid and alter a property of the drilling fluid within the subterranean well.
  • the drilling fluid contains calcium hydroxide.
  • the cement slurry is placed in the subterranean well.
  • the oil- absorbent particles contact the non-aqueous drilling fluid component, thereby altering the property of the non-aqueous component.
  • a hydraulic fracturing operation is performed, wherein a pad fluid comprises nanosize silica particles.
  • the nanosize silica particles contact the residual drilling fluid, thereby further altering the property of the drilling fluid and creating a hydraulic seal in the subterranean well.
  • embodiments relate to methods for establishing zonal isolation in a subterranean well.
  • a subterranean well is drilled with a drilling fluid that contains calcium hydroxide.
  • a cement slurry is prepared that comprises water and a hydraulic cement.
  • the cement slurry is placed in the subterranean well wherein residual drilling fluid is present along casing and formation surfaces.
  • a hydraulic fracturing operation is performed, wherein a pad fluid comprises nanosize silica particles.
  • the nanosize silica particles contact the residual drilling fluid, thereby altering the property of the drilling fluid and creating a hydraulic seal in the subterranean well.
  • an oil-absorbing material may be added to the cement slurry.
  • the oil-absorbing material may begin interacting with drilling fluid first at the interface between the drilling fluid and cement.
  • the oil absorbing material may promote oil diffusion into the set cement material.
  • the drilling fluid Once oil from oil-based drilling fluid is absorbed or diffused into the cement, the rheological properties of the drilling fluid may change. Consequently, the drilling fluid may be converted from a fluid-like material to a paste-like structure. Such conversion inside the drilling-fluid channel may prevent fluid flow inside the channel and serve to provide zonal isolation.
  • oil-absorbing particles in the cement sheath may increase in size, physically blocking small channels or compressing a paste-like mud structure.
  • a process contributing to achieving zonal isolation may include dynamic removal of the mud channel during cement slurry displacement.
  • the oil-absorbing particles 6 flowing near the drilling fluid channel may physically remove a portion of the drilling fluid 5 and transport the portion away from the drilling fluid channel.
  • the particles may significantly reduce the size of the drilling fluid channel or even remove it (Fig. 3).
  • a material that viscosifies oil may be added to the cement slurry.
  • Oil-viscosifying particles may interact and diffuse into oil-based drilling fluid during placement or after the cement setting process, and viscosify the residual oil-based mud to an extent that zonal isolation is achieved.
  • Such cement compositions may contain a sufficient concentration of oil-viscosifying particles to increase the yield point (Ty) to a level higher than that of cement compositions that do not contain the oil-viscosifying particles.
  • the yield point increase may take place within three days of exposure, and the ultimate yield point measured by oscillatory rheometry may be at least 100 Pa. In some cases, the yield point may rise to 4600 Pa (see Example 3). Or the yield point may be between 500 Pa and 3000 Pa. Or the yield point may be between 1000 Pa and 2000 Pa. The higher the yield point, the better the zonal isolation may be.
  • the nanosize particles in the pad fluid may be present at a concentration between 5.0 Ibm/bbl and 50 Ibm/bbl, or 5.0 Ibm/bbl and 10 Ibm/bbl.
  • the abbreviation "bbl” refers to a barrel, which is equivalent to 42 U.S. gallons.
  • the nanosize particles may have a particle size between 1 nm and 100 nm.
  • the nanosize particles may be added to the pad fluid in solid form or as a liquid slurry or suspension.
  • the pad fluid may commingle with the mud channel, thereby exposing the nanosize silica particles to calcium hydroxide.
  • the silica and calcium hydroxide react to form a calcium silicate hydrate, thereby increasing the strength of the mixture and improving zonal isolation.
  • the cement slurry may comprise portland cement, high alumina cement, fly ash, blast furnace slag, microcement, geopolymers, chemically bonded phosphate ceramics, plaster or resins or combinations thereof.
  • the cement slurry further comprises polymers, random copolymers and block polymers comprising alternating sections of one chemical compound separated by sections of a different chemical compound, or a coupling group of low molecular weight.
  • block polymers may have the structure (A-b-B-b-A), wherein A represents a block that is glassy or semi-crystalline and B is a block that is elastomeric.
  • A can be any polymer that is normally regarded as thermoplastic (e.g., polystyrene, polymethylmethacrylate, isotactic polypropylene, polyurethane, etc.), and B can be any polymer that is normally regarded as elastomeric (e.g., polyisoprene, polybutadiene, polyethers, polyesters, etc.).
  • Example thermoplastic block polymers include styrene-isoprene-styrene (SIS), styrene-butadiene-styrene (SBS) and mixtures thereof.
  • the block-polymer-additive may be in one or more shapes, including (but not limited to) spherical, ovoid, fibrous, ribbon-like and in the form of a mesh.
  • the tensile strength of the block polymer may vary between, but not be limited to, about 1 .5 MPa and 40 MPa, or between 3.4 to 34 MPa, or between 2MPa and 3.45 MPa or between 28 MPa and 34 MPa.
  • the thermoplastic block polymers may be present in the cement slurry at a concentration between about 5 Ibm/bbl and 50 Ibm/bbl. Or the block polymer may be present in the cement slurry at a concentration 8 Ibm/bbl and 15 Ibm/bbl.
  • the particle size of the block polymer particles may be between about 1 pm and 850 pm, or between 300 pm and 800 pm.
  • thermoplastic block-particles may be further associated with one or more compounds from the list comprising an emulsion of polymer comprising a betaine group, poly-2, 2, 1 -bicyclo heptene (polynorbornene), alkylstyrene, crosslinked substituted vinyl acrylate copolymers, diatomaceous earth, natural rubber, vulcanized rubber, polyisoprene rubber, vinyl acetate rubber, polychloroprene rubber, acrylonitrile butadiene rubber, hydrogenated acrylonitrile butadiene rubber, ethylene propylene diene monomer, ethylene propylene monomer rubber, styrene- butadiene rubber, styrene/propylene/diene monomer, brominated poly(isobutylene- co-4-methylstyrene), butyl rubber, chlorosulfonated polyethylenes, polyacrylate rubber, polyurethane, silicone rubber, brominated butyl
  • the cement slurries may also comprise customary additives such as retarders, accelerators, extenders, fluid-loss- control additives, lost-circulation additives, gas-migration additives, gas-generating additives, expansion additives and antifoam agents.
  • the cement slurries may contain additives that enhance the flexibility and/or toughness of the set cement.
  • additives include, but are not limited to, flexible particles having a Young’s modulus below about 5000 MPa and a Poisson’s ratio above about 0.3. Such particles may have a Young’s modulus below about 2000 MPa.
  • nonswellable polypropylene examples include, but are not limited to, nonswellable polypropylene, nonswellable polyethylene, acrylonitrile butadiene, styrene butadiene and polyamide.
  • Such additives may also include fibers selected from the list comprising polyamide, polyethylene and polyvinyl alcohol.
  • Metallic microribbons may also be included.
  • the oil-absorbent particles may be elongated, fibrous, cylindrical or asymmetrical. Such particles with an aspect ratio higher than about 1 may interact and form a network inside the cement slurry.
  • the elongated shape may also improve the absorbing ability of the particles.
  • the higher aspect ratio increases the probability that the particles will contact each other throughout the cement slurry, allowing more efficient oil absorption and lower absorbent-particle concentrations to achieve a given result.
  • the particle aspect ratio may be between 1 .1 and 2000, or 10 and 1500, or 15 and 1000 before swelling, and between 2.2 and 3500, or 4 and 1000, or 6 and 350 after swelling.
  • the temperature at which the disclosed fluids operate may be between 80°F and 400°F, or between 100°F and 375°F.
  • the concentration of oil-absorbent particles may vary in the cement sheath. This may be accomplished by varying the rate at which the oil- absorbent particles are added to the cement slurry during mixing and pumping. Certain portions of the cement sheath may not contain oil-absorbent particles. As long as there are regions along the cement sheath providing zonal isolation, the well as a whole may have a hydraulic seal. For example, sections containing the oil- absorbent particles may be located above and below producing zones. This approach may be more economical than scenarios where the oil-absorbent particles are present throughout the cement sheath.
  • the disclosed methods may also be performed during perforating operations.
  • the completion fluid may achieve the same objective as the previously described pad fluid for hydraulic fracturing that contains the nanosized silica particles.
  • the completion fluids may comprise any fluid of proper density and flow characteristics. The density may be chosen such that the completion fluid, plus other fluids in the wellbore, exerts sufficient hydrostatic pressure to maintain well control. The flow characteristics may be chosen such that the completion fluid enters perforation tunnels to an extent sufficient to allow flushing out debris from explosive charges or loose formation material.
  • the completion fluids may comprise aqueous brines containing chloride, bromate or formate salts.
  • a comparative slurry composition is given in Table 1 .
  • a cement composition according to the disclosure is given in Table 2.
  • the cement slurry contained absorbing particles composed of ground rubber particles.
  • the particle size of the rubber varied between 100 pm and 800 pm.
  • Both slurries were conditioned for 35 min at 168°F in an atmospheric consistometer.
  • a representative 13 Ibm/gal (1620 kg/m 3 ) inverse emulsion drilling fluid was chosen that contained diesel as the continuous phase (MegaDrilTM, available from Schlumberger).
  • 15 mL of the conditioned slurry were placed at the bottom of a glass vial.
  • 5 mL of the drilling fluid was carefully added to the top of the conditioned slurry.
  • the glass vials were placed in a Turbiscan AGS instrument (available from Formulaction Inc., Worthington, OH) that was preheated to 140°F (60°C) and allowed to cure for 8 days.
  • the drilling fluid in contact with the slurry containing the absorbent particles increased its yield strength compared to that in contact with the comparative cement system.
  • the yield strength was analyzed on a TA-DHR3 rheometer (available from TA Instruments, New Castle, DE) in a parallel plate configuration. An oscillatory amplitude sweep was conducted at 68°F (20°C) with an angular frequency of 10 rad/s and a logarithmic strain percent sweep from 0.01 % to 100%.
  • the drilling fluid that was exposed to the absorbent slurry exhibited a yield strength in some cases approximately 65 times higher than that of the drilling fluid exposed to the comparative slurry under the same conditions (Fig. 4)
  • Applicant developed a laboratory method to investigate the ability of absorbent containing cement slurry to reduce fluid flow in a drilling-fluid filled channel.
  • Two 600-mL cement slurries were prepared in a Waring blender.
  • the cement was Class FI portland cement.
  • the density of both slurries was 14.5 Ibm/gal (1740 kg/m 3 ). Both slurries were extended with fly ash.
  • a comparative slurry composition is given in Table 3.
  • a 3-in. long by 1 -in. wide steel pipe was capped on one end and filled with slurry and then capped on the other end. Small vent holes were added to the caps to equalize the pressure during high pressure curing.
  • the pipes containing slurry were loaded into a curing chamber and were exposed to 170°F (77°F) and 3000 psi (21 MPa). After the slurry had set, a hole was drilled in the cement leaving a channel of about 1/8-in. (0.3-cm) diameter. The bottom of the hole was plugged, the channel was filled with 13-lbm/gal (1620-kg/m 3 ) MegaDril drilling fluid, and was allowed to set for 6 days at atmospheric conditions.
  • the permeability of the resulting mud channel was probed by the flow of water through the channel.
  • the flow rate was set at 1 mL/min and resulting pressure were measured using a Teledyne ISCO D-series syringe pump.
  • the results, presented in Fig. 5, show that the cement prepared according to the present disclosure was 5 times more pressure resistant compared to the comparative cement.
  • the absorbent additive concentration could be adjusted to increase pressure even higher, up 14 psi, if needed.
  • the ability of an absorbent particle to viscosify oil was investigated.
  • the absorbent particles were made of polystyrene-block-poly(ethylene-ran-butylene)- block-polystyrene and polystyrene-block-polybutadiene-block-polystyrene polymers (manufactured by Sigma-Aldrich Chemie GmbH, Steinheim, Germany).
  • the oil was LVT200 oil, a hydrotreated light distillate manufactured by Deep South Chemical, Inc., Broussard, LA.
  • 3-mm channels were created by inserting wooden dowels into the cement slurries and removing the dowels after 24 hours when the cement slurries had developed sufficient gel strength to maintain the channel structure. Then the channels were filled with 13.0 Ibm/gal (1560 kg/m 3 ) MegaDril mud (available from Ml- Swaco).

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Abstract

Préparation de laitier de ciment comprenant de l'eau, un ciment hydraulique et des particules d'un matériau absorbant l'huile. Les particules sont présentes en une quantité suffisante pour interagir avec un composant non aqueux d'un fluide de forage et modifier une propriété du fluide de forage à l'intérieur du puits souterrain. Le fluide de forage contient de l'hydroxyde de calcium. Le laitier de ciment est placé dans le puits souterrain. Les particules absorbant l'huile entrent en contact avec le composant de fluide de forage non aqueux, modifiant ainsi la propriété du composant non aqueux. Une opération de fracturation hydraulique est effectuée, un fluide tampon comprenant des particules de silice de taille nanométrique. Les particules de silice de taille nanométrique entrent en contact avec le fluide de forage résiduel, ce qui permet de modifier davantage la propriété du fluide de forage et de créer un joint hydraulique dans le puits souterrain.
PCT/US2020/039812 2019-06-28 2020-06-26 Procédés de traitement de puits WO2020264289A1 (fr)

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Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11898088B2 (en) 2019-06-28 2024-02-13 Schlumberger Technology Corporation Cement compositions and methods
US11898415B2 (en) 2018-07-02 2024-02-13 Schlumberger Technology Corporation Cement compositions and methods

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0605113B1 (fr) * 1992-12-30 1997-06-04 Halliburton Company Utilisation de boue de forage
WO2005123871A2 (fr) * 2004-06-14 2005-12-29 Schlumberger Canada Limited Procede servant a consolider une formation
EP2004569B1 (fr) * 2006-04-11 2013-05-01 Halliburton Energy Services, Inc. Boues de forage durcissables comprenant de la poussiere de four a ciment et procedes d'utilisation de celles-ci
WO2015069293A1 (fr) * 2013-11-11 2015-05-14 Halliburton Energy Services, Inc. Procédé d'amélioration de la conductivité de fracture étayée
US20160264842A1 (en) * 2014-02-26 2016-09-15 Halliburton Energy Services, Inc. Settable compositions and uses thereof

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0605113B1 (fr) * 1992-12-30 1997-06-04 Halliburton Company Utilisation de boue de forage
WO2005123871A2 (fr) * 2004-06-14 2005-12-29 Schlumberger Canada Limited Procede servant a consolider une formation
EP2004569B1 (fr) * 2006-04-11 2013-05-01 Halliburton Energy Services, Inc. Boues de forage durcissables comprenant de la poussiere de four a ciment et procedes d'utilisation de celles-ci
WO2015069293A1 (fr) * 2013-11-11 2015-05-14 Halliburton Energy Services, Inc. Procédé d'amélioration de la conductivité de fracture étayée
US20160264842A1 (en) * 2014-02-26 2016-09-15 Halliburton Energy Services, Inc. Settable compositions and uses thereof

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11898415B2 (en) 2018-07-02 2024-02-13 Schlumberger Technology Corporation Cement compositions and methods
US11898088B2 (en) 2019-06-28 2024-02-13 Schlumberger Technology Corporation Cement compositions and methods

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