WO2025130809A1 - 化学粘接堵漏剂及包含其的复合堵漏剂、钻井液与其在钻井工程中的应用 - Google Patents

化学粘接堵漏剂及包含其的复合堵漏剂、钻井液与其在钻井工程中的应用 Download PDF

Info

Publication number
WO2025130809A1
WO2025130809A1 PCT/CN2024/139559 CN2024139559W WO2025130809A1 WO 2025130809 A1 WO2025130809 A1 WO 2025130809A1 CN 2024139559 W CN2024139559 W CN 2024139559W WO 2025130809 A1 WO2025130809 A1 WO 2025130809A1
Authority
WO
WIPO (PCT)
Prior art keywords
plugging agent
plugging
core layer
drilling fluid
chemical bonding
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.)
Pending
Application number
PCT/CN2024/139559
Other languages
English (en)
French (fr)
Inventor
刘伟
张小平
杨晓峰
王京光
黎金明
贾俊
蔺文洁
王路路
赵向阳
曲先伟
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.)
China National Petroleum Corp
CNPC Chuanqing Drilling Engineering Co Ltd
Original Assignee
China National Petroleum Corp
CNPC Chuanqing Drilling Engineering Co Ltd
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 China National Petroleum Corp, CNPC Chuanqing Drilling Engineering Co Ltd filed Critical China National Petroleum Corp
Publication of WO2025130809A1 publication Critical patent/WO2025130809A1/zh
Anticipated expiration legal-status Critical
Pending 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
    • C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
    • C09K8/426—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells for plugging
    • 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
    • C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
    • 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
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like

Definitions

  • the invention belongs to the technical field of oilfield chemical development, and more specifically relates to a chemical bonding plugging agent, a composite plugging agent containing the chemical bonding plugging agent, a drilling fluid and the application thereof in drilling engineering.
  • Drilling fluid loss is a global technical problem in drilling engineering.
  • bridging plugging materials are the most commonly used plugging agents on site.
  • Bridging plugging materials include granular, flaky and fibrous fruit shells, calcium carbonate, fiber, mica, etc., which rely on large particles to build bridges and small particles to fill and plug to prevent drilling fluid loss.
  • relying solely on physical accumulation and plugging has weak pressure bearing capacity and a low one-time plugging success rate.
  • a chemical bonding plugging agent which includes a core layer and an inorganic material coated on the outer surface of the core layer; the material of the core layer has a structure shown in Formula I:
  • the number average molecular weight of the material of the core layer is 20,000 to 35,000.
  • the values of m and n can satisfy the number average molecular weight range of the material of the core layer without any special limitation. For example, m represents 10 to 14, and n represents 12 to 20.
  • the core layer material in the plugging agent of the present invention has a strong chemical bonding effect.
  • the inorganic material in the plugging agent is dispersed in the drilling fluid (oil-based drilling fluid and water-based drilling fluid are both acceptable, and the drilling fluid is added to the drilling fluid. Since the drilling fluid has viscosity, it can be dispersed) so that the core layer material is exposed and in contact with each other, chemical bonding occurs under the high temperature ( ⁇ 50°C) extrusion conditions of the formation to form an overall gel, which can more efficiently obtain a plugging layer with higher strength, better pressure bearing capacity and better toughness.
  • the principle of the above chemical bonding is as follows:
  • the present invention can not only greatly improve the plugging success rate, optimize the plugging efficiency, and overcome the problem that the traditional bridging plugging agent relies only on physical accumulation and leads to a low one-time plugging success rate; it also improves the pressure bearing capacity of the plugging system, and overcomes the disadvantage that the traditional bridging plugging agent relies only on physical accumulation and leads to weak pressure bearing capacity.
  • the above-mentioned plugging agent of the present invention also has the following excellent properties: good high temperature resistance, still has stable performance in high-temperature downhole operations; good drilling fluid compatibility, good compatibility with the market water-based and oil-based drilling fluid systems, better applicability; strong anti-pollution ability; and strong salt resistance.
  • the core layer material in the plugging agent of the present invention is coated with inorganic materials on the surface, which effectively prevents the core layer material from bonding during storage and transportation, making storage and transportation more convenient; on-site construction can be directly prepared in the slurry preparation tank, without the need for batch stick prying equipment, and the construction is simple, the required equipment investment is small, the labor intensity is low, the overall cost is low, and it is convenient for large-scale promotion and application, and the industrial application prospect is better.
  • the inorganic materials can be dispersed in the drilling fluid to expose the core layer materials and contact each other.
  • the weight ratio of the inorganic material to the core layer is 2 to 4:1; preferably, the weight ratio of the inorganic material to the core layer is 2 to 3:1.
  • the inorganic material is selected from one or more of calcium carbonate, magnesium carbonate, bentonite or talc.
  • the material of the core layer and the inorganic material are mixed and stirred so that the inorganic material is coated (physically coated) on the outer surface of the core layer.
  • the material of the core layer is granular with a particle size of 8-40 mesh (for example, 8-10 mesh, 10-20 mesh, 20-40 mesh); the inorganic material is granular with a particle size of 1800-2200 mesh (preferably 2000 mesh).
  • the plugging agent material is within the above range, which is easier to enter the leaking layer and has good adaptability; and can be plugged while drilling or by segment plugging, which is simple to operate, and can be subsequently stacked and bonded into a consolidated body to achieve higher pressure bearing strength.
  • the material of the core layer is obtained by polymerization and curing of polypropylene glycol, toluene diisocyanate and bis(2-hydroxyethyl) disulfide.
  • the synthesis route is as follows:
  • polypropylene glycol, toluene diisocyanate and bis(2-hydroxyethyl) disulfide as raw materials for preparing the core layer material can further improve the tensile strength, elongation at break and chemical bonding efficiency of the plugging agent.
  • the core layer material is prepared by the following preparation method: at a temperature of 40 to 70° C., the polypropylene glycol and the toluene diisocyanate are first mixed and reacted for 10 to 40 minutes, and then the bis(2-hydroxyethyl) disulfide is added to the system and reacted for 10 to 40 minutes.
  • the curing temperature is 70-100° C. and the curing time is 5-16 hours.
  • the core layer material is prepared by the following preparation method: at a temperature of 40 to 50°C, polypropylene glycol and toluene diisocyanate are first mixed and stirred for 10 to 20 minutes, bis(2-hydroxyethyl) disulfide is then added to the system for polymerization reaction for 15 to 25 minutes, and the polymerization product is cured at a temperature of 80 to 90°C for 6 to 12 hours to obtain the core layer material.
  • the plugging agent thus obtained has better high temperature resistance, salt resistance and mechanical strength properties.
  • a composite plugging agent which includes a plugging agent A with a particle size of 10-20 mesh, a plugging agent B with a particle size of 20-40 mesh, and an optional plugging agent C with a particle size of 8-10 mesh; plugging agent A, plugging agent B and plugging agent C are each independently selected from the aforementioned plugging agents; the weight ratio of plugging agent A, plugging agent B and plugging agent C is 1-2:1:1-2.
  • 10-20 mesh plugging agent A means that these particles can pass through the 10 mesh mesh but not the 20 mesh mesh
  • 20-40 mesh plugging agent B means that these particles can pass through the 20 mesh mesh but not the 40 mesh mesh
  • 8-10 mesh plugging agent C means that these particles can pass through the 8 mesh mesh but not the 10 mesh mesh.
  • the plugging agent of the present invention has a higher one-time plugging success rate, better pressure bearing capacity, better drilling fluid compatibility, stronger temperature resistance, strong anti-pollution performance, and strong salt resistance.
  • the composite plugging agent thus prepared can achieve the "bridging-filling-bonding-plugging" effect in the cracks, and has a better plugging and leak prevention effect.
  • a drilling fluid which includes the aforementioned plugging agent, or the aforementioned composite plugging agent.
  • the drilling fluid leakage prevention while drilling or plugging during drilling stop of the present invention can effectively solve the technical problems of fracture or pore leakage.
  • the plugging agent and the composite plugging agent of the present invention can be widely used in the field of drilling fluid leakage prevention and plugging, leakage prevention while drilling or plugging while drilling is stopped, and solve the technical problems of fracture or pore leakage; it can also be widely used to solve the problem of instability of the well wall in broken formations, and perform wall consolidation operations through chemical bonding.
  • the target product was sheared and sieved into particles of different sizes between 8 and 10 meshes, between 10 and 20 meshes, and between 20 and 40 meshes, and stirred evenly in 2000 mesh ultrafine calcium carbonate, and then sieved to obtain plugging agent C1 with a particle size between 8 and 10 meshes, plugging agent A1 with a particle size between 10 and 20 meshes, and plugging agent B1 with a particle size between 20 and 40 meshes.
  • plugging agent A1 the weight ratio of inorganic material to core layer is 2.2:1
  • plugging agent B1 the weight ratio of inorganic material to core layer
  • plugging agent C1 the weight ratio of inorganic material to core layer is 2.2:1.
  • the plugging agents of different mesh sizes in Example 1 were added to the drilling fluid base slurry, and after rolling aging at 150°C/16h, the rheology and filtration performance of the drilling fluid were tested.
  • the formula of the drilling fluid base slurry is: 4wt% bentonite slurry + 0.2wt% xanthan gum + 0.2wt% low-viscosity sodium carboxymethyl cellulose + 95.6wt% water.
  • the drilling fluid system formula and evaluation results are shown in Table 1.
  • the weight content of the plugging agent in Table 1 refers to the weight ratio of the material to the drilling fluid base slurry.
  • 2wt% plugging agent C1 (8-10 mesh) means that the amount of plugging agent C1 (8-10 mesh) is 2wt% of the weight of the drilling fluid base slurry.
  • the compatibility experiment shows that the plugging agent of the present invention does not affect the rheology and filtration of the drilling fluid, has good compatibility, and can be directly added to the drilling fluid for plugging.
  • Example 2 The product system in Example 1 was cast into a mold during the curing process to prepare a rectangular parallelepiped with a length of 10 cm, a width of 1 cm, and a thickness of 5 mm. It was then cut in the middle with scissors, and the cut ends were spliced together and placed in an oven at 80°C for 6 hours. It was then placed on a universal testing machine to test the tensile strength. The tensile strength before and after shearing was compared, as shown in Table 2.
  • the plugging agents of different mesh sizes obtained in Example 1 were added to the drilling fluid base slurry, and then the plugging pressure strength was tested using a crack plugging device (the temperature was set to 120°C, and the plugging of cracks during the experiment was in an extrusion state).
  • the formula of the drilling fluid base slurry is: 4wt% bentonite slurry + 0.2wt% xanthan gum + 0.2wt% low-viscosity sodium carboxymethyl cellulose + 95.6wt% water.
  • the drilling fluid formula and evaluation results are shown in Table 3.
  • the weight content of the plugging agent in Table 3 refers to the weight ratio of the material to the drilling fluid base slurry.
  • 2wt% plugging agent C1 (8-10 mesh) means that the amount of plugging agent C1 (8-10 mesh) is 2wt% of the weight of the drilling fluid base slurry.
  • the test results show that the plugging agent of the present invention can achieve a compressive strength of 8MPa at crack openings of 1mm and 3mm, but the traditional walnut shell plugging agent can only reach a compressive strength of 2.5-3MPa.
  • the plugging agent of the present invention has excellent pressure-bearing effect.
  • the target product is sheared and sieved into particles of different sizes between 8 and 10 meshes, between 10 and 20 meshes, and between 20 and 40 meshes, and stirred evenly in 2000 mesh ultrafine calcium carbonate, and then sieved to obtain plugging agent C2 with a particle size between 8 and 10 meshes, plugging agent A2 with a particle size between 10 and 20 meshes, and plugging agent B2 with a particle size between 20 and 40 meshes.
  • the weight ratio of the inorganic material to the core layer is 2.5:1; in plugging agent B2, the weight ratio of the inorganic material to the core layer is 2.5:1; in plugging agent C2, the weight ratio of the inorganic material to the core layer is 2.5:1.
  • the plugging agents of different mesh sizes in Example 2 were added to the drilling fluid base slurry, and the rheological properties and filtration loss properties of the drilling fluid were tested after rolling aging at 150°C/16h.
  • the formula of the drilling fluid base slurry is: 4wt% bentonite slurry + 0.2wt% xanthan gum + 0.2wt% low-viscosity sodium carboxymethyl cellulose + 95.6wt% water.
  • the drilling fluid system formula and evaluation results are shown in Table 4.
  • the weight content of the plugging agent in Table 4 refers to the weight ratio of the material to the drilling fluid base slurry.
  • 2wt% plugging agent C2 (8-10 mesh) means that the amount of plugging agent C2 (8-10 mesh) is 2wt% of the weight of the drilling fluid base slurry.
  • the plugging agent does not affect the rheology and filtration properties of the drilling fluid, has good compatibility, and can be directly added to the drilling fluid for plugging.
  • Example 2 The product system in Example 2 was cast into a mold during the curing process to prepare a rectangular parallelepiped with a length of 10 cm, a width of 1 cm, and a thickness of 5 mm. It was then cut in the middle with scissors, and the cut ends were spliced together and placed in a 90°C oven for 6 hours. It was then placed on a universal testing machine to test the tensile strength. The tensile strength before and after shearing was compared, as shown in Table 5.
  • the plugging agents of different mesh sizes obtained in Example 2 were added to the drilling fluid base slurry, and then the plugging pressure strength was tested using a crack plugging device (the temperature was set to 120°C, and the plugging of cracks during the experiment was in an extrusion state).
  • the formula of the drilling fluid base slurry is: 4wt% bentonite slurry + 0.2wt% xanthan gum + 0.2wt% low-viscosity sodium carboxymethyl cellulose + 95.6wt% water.
  • the drilling fluid formula and evaluation results are shown in Table 6.
  • the weight content of the plugging agent in Table 6 refers to the weight ratio of the material to the drilling fluid base slurry.
  • 2wt% plugging agent C2 (8-10 mesh) means that the amount of plugging agent C2 (8-10 mesh) is 2wt% of the weight of the drilling fluid base slurry.
  • the test results show that the plugging agent of the present invention can form a pressure bearing strength of 8MPa at crack openings of 1 and 3mm, but the traditional walnut shell plugging agent has a pressure of only 2.5-3MPa.
  • the plugging agent has excellent pressure bearing effect.
  • the target product is sheared and sieved into particles of different sizes between 8 and 10 meshes, between 10 and 20 meshes, and between 20 and 40 meshes, and stirred evenly in 2000 mesh ultrafine calcium carbonate, and then sieved to obtain plugging agent C3 with a particle size between 8 and 10 meshes, plugging agent A3 with a particle size between 10 and 20 meshes, and plugging agent B3 with a particle size between 20 and 40 meshes.
  • plugging agent A3 the weight ratio of the inorganic material to the core layer is 2.5:1; in plugging agent B3, the weight ratio of the inorganic material to the core layer is 2.5:1; in plugging agent C3, the weight ratio of the inorganic material to the core layer is 2.5:1.
  • the plugging agents of different mesh sizes in Example 3 were added to the drilling fluid base slurry, and the rheological properties and filtration loss properties of the drilling fluid were tested after rolling aging at 150°C/16h.
  • the formula of the drilling fluid base slurry is: 4wt% bentonite slurry + 0.2wt% xanthan gum + 0.2wt% low-viscosity sodium carboxymethyl cellulose + 95.6wt% water.
  • the drilling fluid system formula and evaluation results are shown in Table 7.
  • the weight content of the plugging agent in Table 7 refers to the weight ratio of the material to the drilling fluid base slurry.
  • 2wt% plugging agent C3 (8-10 mesh) means that the amount of plugging agent C3 (8-10 mesh) is 2wt% of the weight of the drilling fluid base slurry.
  • the plugging agent does not affect the rheology and filtration properties of the drilling fluid, has good compatibility, and can be directly added to the drilling fluid for plugging.
  • Example 3 The product system in Example 3 was cast into a mold during the curing process to prepare a rectangular parallelepiped with a length of 10 cm, a width of 1 cm, and a thickness of 5 mm. It was then cut in the middle with scissors, and the cut ends were spliced together and placed in a 90°C oven for 6 hours. It was then placed on a universal testing machine to test the tensile strength. The tensile strength before and after shearing was compared, as shown in Table 8.
  • the plugging agents of different mesh sizes obtained in Example 2 were added to the drilling fluid base slurry, and then the plugging pressure strength was tested using a crack plugging device (the temperature was set to 120°C, and the plugging of cracks during the experiment was in an extrusion state).
  • the formula of the drilling fluid base slurry is: 4wt% bentonite slurry + 0.2wt% xanthan gum + 0.2wt% low-viscosity sodium carboxymethyl cellulose + 95.6wt% water.
  • the drilling fluid formula and evaluation results are shown in Table 9.
  • the weight content of the plugging agent in Table 8 refers to the weight ratio of the material to the drilling fluid base slurry.
  • 2wt% plugging agent C3 (8-10 mesh) means that the amount of plugging agent C3 (8-10 mesh) is 2wt% of the weight of the drilling fluid base slurry.
  • the test results show that the plugging agent of the present invention can form a pressure bearing strength of 8MPa at crack openings of 1 and 3mm, but the traditional walnut shell plugging agent has a pressure of only 2.5-3MPa.
  • the plugging agent has excellent pressure bearing effect.
  • the target product is sheared and sieved into particles of different particle sizes between 8 and 10 mesh, between 10 and 20 mesh, and between 20 and 40 mesh, and stirred evenly in 2000 mesh ultrafine calcium carbonate, and then continue to sieve to obtain plugging agent D with a particle size between 8 and 10 mesh, plugging agent E with a particle size between 10 and 20 mesh, and plugging agent F with a particle size between 20 and 40 mesh.
  • plugging agent A the weight ratio of the inorganic material to the core layer is 1:1; in plugging agent B, the weight ratio of the inorganic material to the core layer is 1:1; in plugging agent C, the weight ratio of the inorganic material to the core layer is 1:1.
  • the product system in Comparative Example 1 was cast into a mold during the curing process to prepare a rectangular parallelepiped with a length of 10 cm, a width of 1 cm, and a thickness of 5 mm. It was then cut in the middle with scissors and spliced together at the cut ends. The mixture was placed in an oven at 80°C for 6 hours and then placed on a universal testing machine to test the tensile strength. The tensile strength after cutting and splicing was only 25.2 kPa, while the tensile strength of the plugging agent in Example 1 of the present application reached 750.6 kPa.
  • the plugging agent in Comparative Example 1 is added to the drilling fluid base slurry, and then the plugging pressure bearing strength is tested using a crack plugging device.
  • the formula is as follows: drilling fluid base slurry + 2wt% plugging agent D (8-10 mesh) + 1wt% plugging agent E (10-20 mesh) + 2wt% plugging agent F (20-40 mesh) + 3wt% ultrafine calcium carbonate (800 mesh), the pressure bearing strength is only 3.5MPa at a 3mm crack opening, which is much different from the pressure bearing capacity 8MPa of the plugging agent in Example 1 of the present application.
  • the acylhydrazone bond also has a bonding effect, the material cannot achieve bonding under the condition of temperature ⁇ 60°C, because the copolymer molecular chain curls and embeds the acylhydrazone bond when the temperature rises, and the acylhydrazone bond at the incision is difficult to dynamically exchange, so bonding cannot be achieved.
  • the plugging agent in Comparative Example 1 is not resistant to high temperatures compared with the aforementioned plugging agent of the present application, and bonding cannot be achieved in the deep well leaking layer.
  • the target product is sheared and sieved into particles of different sizes between 8 and 10 meshes, between 10 and 20 meshes, and between 20 and 40 meshes, and stirred evenly in 2000 mesh ultrafine calcium carbonate, and then sieved to obtain a plugging agent M with a particle size between 8 and 10 meshes, a plugging agent J with a particle size between 10 and 20 meshes, and a plugging agent K with a particle size between 20 and 40 meshes.
  • the weight ratio of the inorganic material to the core layer is 1:1; in the plugging agent J, the weight ratio of the inorganic material to the core layer is 1:1; in the plugging agent K, the weight ratio of the inorganic material to the core layer is 1:1.
  • the product system in Comparative Example 2 was cast into a mold during the curing process to prepare a rectangular parallelepiped with a length of 10 cm, a width of 1 cm, and a thickness of 5 mm. It was then cut in the middle with scissors and spliced together at the cut ends. The mixture was placed in an oven at 80°C for 6 hours and then placed on a universal testing machine to test the tensile strength. The tensile strength after cutting and splicing was only 40.4 kPa, while the tensile strength of the plugging agent in Example 1 of the present application reached 750.6 kPa.
  • the plugging agent in comparative example 2 was added to the drilling fluid base slurry, and then the plugging pressure bearing strength was tested using a crack plugging device.
  • the formula is as follows: drilling fluid base slurry + 2wt% plugging agent M (8-10 mesh) + 1wt% plugging agent K (10-20 mesh) + 2wt% plugging agent J (20-40 mesh) + 3wt% ultrafine calcium carbonate (800 mesh).
  • the pressure bearing strength at a 3mm crack opening is only 2.5MPa, which is quite different from the pressure bearing capacity of 8MPa of the plugging agent in Example 1 of the present application.
  • the degree of combination of aromatics and polyurethane is low.

Landscapes

  • Life Sciences & Earth Sciences (AREA)
  • Chemical & Material Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Organic Chemistry (AREA)
  • Materials Engineering (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Physics & Mathematics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Inorganic Chemistry (AREA)
  • Adhesives Or Adhesive Processes (AREA)
  • Sealing Material Composition (AREA)

Abstract

本发明提供了一种化学粘接堵漏剂及包含其的复合堵漏剂、钻井液与其在钻井工程中的应用。该化学粘接堵漏剂包括核层以及包覆在核层外表面上的无机材料；核层的材料具有式(I)所示结构。本发明的堵漏剂一次封堵成功率更高、承压能力更好、钻井液配伍性更优、抗温能力更强、抗污染性能强、抗盐能力强。

Description

化学粘接堵漏剂及包含其的复合堵漏剂、钻井液与其在钻井工程中的应用
交叉引用信息
本申请要求于2023年12月22日提交中国专利局、申请号为202311791338.9、发明名称为“堵漏剂及包含其的复合堵漏剂、钻井液与其在钻井工程中的应用”的中国专利申请的优先权，其全部内容通过引用结合在本申请中。
技术领域
本发明属于涉及油田化学品开发技术领域，更具体的是涉及一种化学粘接堵漏剂及包含其的复合堵漏剂、钻井液与其在钻井工程中的应用。
背景技术
钻井液漏失是钻井工程的世界性技术难题，目前桥接堵漏材料是现场最常用的堵漏剂。桥接堵漏材料包括颗粒状、片状和纤维状的果壳、碳酸钙、纤维、云母等，依靠大颗粒架桥、小颗粒填充封堵，以阻止钻井液漏失。但是，仅仅依靠物理作用堆积封堵，承压能力弱，一次性堵漏成功率低。
发明内容
为了改善上述问题，根据本发明的一个方面，提供了一种化学粘接堵漏剂，其包括核层以及包覆在核层外表面上的无机材料；核层的材料具有式Ⅰ所示结构：
式Ⅰ中，表示核层的材料的数均分子量为20000～35000，m、n的数值满足核层的材料的数均分子量范围即可，不做特殊限定，例如m表示10～14，n表示12～20。
首先，本发明堵漏剂中的核层材料具有强有力的化学粘接效应，在后续堵漏应用时，堵漏剂中的无机材料后续应用时分散在钻井液(油基钻井液和水基钻井液都可以，加入到钻井液中，由于钻井液有粘度，可以使其分散)中得以使核层材料裸露并互相接触在地层高温(≥50℃)挤压条件下发生化学粘接形成整体凝胶，可以更高效地得到强度更高、承压能力更佳且韧性更好的封堵层。上述化学粘接的原理如下所示：
基于此，本发明不仅可以大幅度提高堵漏成功率，优化堵漏效率，克服了传统桥接堵漏剂仅靠物理堆积作用而导致一次封堵成功率低的问题；还提高了堵漏体系的承压能力，克服了传统桥接堵漏剂仅靠物理堆积作用而导致承压能力弱的弊端。同时，本发明上述堵漏剂还具有以下优异性能：较好的抗高温性，在高温井下作业中仍然具有稳定的性能；良好的钻井液配伍性，与市场水基和油基钻井液体系配伍性都好，应用性更优；较强的抗污染能力；以及较强的抗盐能力。
其次，本发明堵漏剂中的核层材料外表面包覆有无机材料，这有效防止了核层材料在贮存和运输过程中发生粘接，更方便贮存和运输；现场施工可直接在配浆罐中配制，无需批棍撬设备，施工简便，所需设备投入少，劳动强度低，综合成本低，便于大规模推广应用，工业化应用前景更好。而且，无机材料在后续堵漏应用时，即可分散在钻井液中得以使核层材料裸露并互相接触。
进一步地，无机材料和核层的重量比为2～4：1；优选地，无机材料和核层的重量比为2～3：1。无机材料选自碳酸钙、碳酸镁、膨润土或滑石粉中的一种或多种。在一种可选的实施方式中，将核层的材料和无机材料混合搅拌以使无机材料包覆(物理包覆)在核层的外表面上。
在一种优选的实施方式中，核层的材料具有颗粒状，粒度为8～40目(例如可以为8～10目、10～20目、20～40目)；无机材料具有颗粒状，粒度为1800～2200目(优选粒度为2000目)。堵漏剂材料在上述范围内，更易进入漏层，自适应性好；且可以随钻或段塞堵漏，操作简单，并在后续堆积粘接成固结体，实现较高承压强度。
进一步地，核层的材料由聚丙二醇、甲苯二异氰酸酯和双(2-羟乙基)二硫醚经聚合、固化得到。合成路线如下所示：
以聚丙二醇、甲苯二异氰酸酯和双(2-羟乙基)二硫醚作为核层材料的制备原料，可以进一步提高堵漏剂的拉伸强度、断裂伸长率以及化学粘接效率。
进一步地，核层的材料通过以下制备方法制备得到：在40～70℃温度条件下，先将所述聚丙二醇和所述甲苯二异氰酸酯混合反应10～40min，再向体系中加入所述双(2-羟乙基)二硫醚反应10～40min。
进一步地，固化的温度为70～100℃、时间为5～16h。
在一种优选的实施方式中，核层的材料通过以下制备方法制备得到：在40～50℃温度条件下，先将聚丙二醇和甲苯二异氰酸酯混合搅拌10～20min，再向体系中加入双(2-羟乙基)二硫醚聚合反应15～25min，并将聚合反应产物在80～90℃温度条件下固化6～12h，得到核层的材料。由此得到的堵漏剂具有更优异的抗高温性能、抗盐性能及力学强度性能。
为了改善上述问题，根据本发明的另一个方面，提供了一种复合堵漏剂，其包括粒度为10～20目的堵漏剂A、粒度为20～40目的堵漏剂B以及可选的粒度为8～10目的堵漏剂C；堵漏剂A、堵漏剂B以及堵漏剂C各自独立地选自前述的堵漏剂；堵漏剂A、堵漏剂B以及堵漏剂C的重量比为1～2：1：1～2。
在此说明的是，10～20目的堵漏剂A是指这些颗粒能从10目的网孔漏过而不能从20目的网孔漏过；20～40目的堵漏剂B是指这些颗粒能从20目的网孔漏过而不能从40目的网孔漏过；8～10目的堵漏剂C是指这些颗粒能从8目的网孔漏过而不能从10目的网孔漏过。
基于前文的各项原因，本发明的堵漏剂一次封堵成功率更高、承压能力更好、钻井液配伍性更优、抗温能力更强、抗污染性能强、抗盐能力强。由此复配得到的复合堵漏剂在裂缝中可实现“架桥-填充-粘接-封堵”作用，堵漏防漏效果更佳。
进一步地，堵漏剂A、堵漏剂B和堵漏剂C的重量比为1.5～2：1：1～1.5。
为了改善上述问题，根据本发明的另一个方面，提供了一种钻井液，其包括前述的堵漏剂，或者前述的复合堵漏剂。
基于前文的各项原因，本发明的钻井液随钻防漏或停钻堵漏，可以有效解决裂缝性或孔隙型漏失技术难题。
为了改善上述问题，根据本发明的另一个方面，提供了一种前述的堵漏剂、或者前述的复合堵漏剂在钻井工程中的应用。基于前文的各项原因，本发明的堵漏剂及复合堵漏剂可广泛应用在钻井液防漏堵漏领域，随钻防漏或停钻堵漏，解决裂缝性或孔隙型漏失技术难题；还可广泛应用解决破碎地层井壁失稳问题，通过化学粘接进行固壁作业。
具体实施方式
为了对本发明的技术特征、目的和有益效果有更加清楚的理解，现对本发明的技术方案进行以下详细说明，但不能理解为对本发明的可实施范围的限定。
原料来源：
实施例1
烧杯中加入聚丙二醇50g，加热至45℃并开始搅拌，然后加入甲苯二异氰酸酯5g，搅拌15min。然后加入3g的双(2-羟乙基)二硫醚，继续搅拌20min，得到产物体系。然后将上述产物体系放在80℃烘箱中，加热6h，取出冷却至室温后，得到目标产物(数均分子量为32000)。
将目标产物剪切、并筛分成粒度在8～10目之间、10～20目之间、20～40目之间的不同粒径的颗粒，并分别在2000目超细碳酸钙中搅拌均匀，然后继续筛分，得到粒度在8～10目之间的堵漏剂C1、粒度在10～20目之间的堵漏剂A1以及粒度在20～40目之间的堵漏剂B1。堵漏剂A1中，无机材料和核层的重量比为2.2：1；堵漏剂B1中，无机材料和核层的重量比为2.2：1；堵漏剂C1中，无机材料和核层的重量比为2.2：1。
性能评价：
(一)钻井液配伍性评价
分别将实施例1中不同目数的堵漏剂加入到钻井液基浆中，150℃/16h滚动老化后，测试钻井液流变性和滤失性能。其中，钻井液基浆的配方为：4wt％膨润土浆+0.2wt％黄原胶+0.2wt％低粘羧甲基纤维素钠+95.6wt％水。钻井液体系配方及评价结果见表1所示。
表1
注：表1中堵漏剂的重量含量是指物料占钻井液基浆的重量比。例如，2wt％堵漏剂C1(8～10目)是指堵漏剂C1(8～10目)的用量为钻井液基浆重量的2wt％。
通过配伍性实验得出，本发明上述堵漏剂不影响钻井液流变性和滤失性，配伍性良好，可直接加入钻井液中堵漏使用。
(二)粘接强度评价
将实施例1中的产物体系在固化过程中浇筑模具，制备成长10cm，宽1cm，厚度5mm的长方体状，然后用剪刀从中间剪断，然后剪断处拼接在一起，放在80℃烘箱中静置6h，然后放在万能试验机上测试抗拉强度，对比剪断前后的抗拉强度，见表2所示。
表2

通过剪断前后粘接强度对比实验得出，本发明上述堵漏剂剪断后再进行粘接，粘接后的抗拉强度基本和剪断前持平，粘接性能良好，在漏层中颗粒会紧密粘接在一起，实现堵漏效果。
(三)封堵承压强度测试
将实施例1得到的不同目数的堵漏剂，加入到钻井液基浆中，然后利用裂缝封堵装置(温度设置为120℃，实验过程封堵裂缝就是挤压状态)测试封堵承压强度。其中，钻井液基浆的配方为：4wt％膨润土浆+0.2wt％黄原胶+0.2wt％低粘羧甲基纤维素钠+95.6wt％水。钻井液配方及评价结果见表3所示。
表3
注：表3中堵漏剂的重量含量是指物料占钻井液基浆的重量比。例如，2wt％堵漏剂C1(8～10目)是指堵漏剂C1(8～10目)的用量为钻井液基浆重量的2wt％。
通过测试结果可知，本发明上述堵漏剂在1mm和3mm裂缝开度能达到8MPa的承压强度，但是传统的核桃壳堵漏剂仅能达到2.5-3MPa的承压强度，本发明上述堵漏剂承压效果优异。
实施例2
烧杯中加入聚丙二醇60g，加热至45℃并开始搅拌，然后加入甲苯二异氰酸酯8g，搅拌15min。然后加入5g的双(2-羟乙基)二硫醚，继续搅拌20min，然后将上述混合物放在90℃烘箱中，加热6h，取出冷却至室温后，得到目标产物(数均分子量为30000)。
将目标产物剪切、并筛分成粒度在8～10目之间、10～20目之间、20～40目之间的不同粒径的颗粒，并分别在2000目超细碳酸钙中搅拌均匀，然后继续筛分，得到粒度在8～10目之间的堵漏剂C2、粒度在10～20目之间的堵漏剂A2以及粒度在20～40目之间的堵漏剂B2。
堵漏剂A2中，无机材料和核层的重量比为2.5：1；堵漏剂B2中，无机材料和核层的重量比为2.5：1；堵漏剂C2中，无机材料和核层的重量比为2.5：1。
性能评价：
(一)钻井液配伍性评价
分别将实施例2中不同目数的堵漏剂加入到钻井液基浆中，150℃/16h滚动老化后，测试钻井液流变性和滤失性能。其中，钻井液基浆的配方为：4wt％膨润土浆+0.2wt％黄原胶+0.2wt％低粘羧甲基纤维素钠+95.6wt％水。钻井液体系配方及评价结果见表4。
表4
注：表4中堵漏剂的重量含量是指物料占钻井液基浆的重量比。例如，2wt％堵漏剂C2(8～10目)是指堵漏剂C2(8～10目)的用量为钻井液基浆重量的2wt％。
通过配伍性实验得出，堵漏剂不影响钻井液流变性和滤失性，配伍性良好，可直接加入钻井液中堵漏使用。
(二)粘接强度评价
将实施例2中的产物体系在固化过程中浇筑模具，备成长10cm，宽1cm，厚度5mm的长方体状，然后用剪刀从中间剪断，然后剪断处拼接在一起，放在90℃烘箱中静置6h，然后放在万能试验机上测试抗拉强度，对比剪断前后的抗拉强度，见表5所示。
表5
通过剪断前后粘接强度对比实验得出，堵漏剂剪断后再进行粘接，粘接后的抗拉强度基本和剪断前持平，粘接性能良好，在漏层中颗粒会紧密粘接在一起，实现堵漏效果。
(三)封堵承压强度测试
将实施例2得到的不同目数的堵漏剂，加入到钻井液基浆中，然后利用裂缝封堵装置(温度设置为120℃，实验过程封堵裂缝就是挤压状态)测试封堵承压强度。其中，钻井液基浆的配方为：4wt％膨润土浆+0.2wt％黄原胶+0.2wt％低粘羧甲基纤维素钠+95.6wt％水。钻井液配方及评价结果见表6所示。
表6
注：表6中堵漏剂的重量含量是指物料占钻井液基浆的重量比。例如，2wt％堵漏剂C2(8～10目)是指堵漏剂C2(8～10目)的用量为钻井液基浆重量的2wt％。
通过测试结果可知，本发明上述堵漏剂在1和3mm裂缝开度能形成8MPa的承压强度，但是传统的核桃壳堵漏剂仅为2.5-3MPa的压力，堵漏剂承压效果优异。
实施例3
烧杯中加入聚丙二醇62g，加热至45℃并开始搅拌，然后加入甲苯二异氰酸酯8.2g，搅拌15min。然后加入5.2g的双(2-羟乙基)二硫醚，继续搅拌20min，然后将上述混合物放在90℃烘箱中，加热6h，取出冷却至室温后，得到目标产物(数均分子量为33000)。
将目标产物剪切、并筛分成粒度在8～10目之间、10～20目之间、20～40目之间的不同粒径的颗粒，并分别在2000目超细碳酸钙中搅拌均匀，然后继续筛分，得到粒度在8～10目之间的堵漏剂C3、粒度在10～20目之间的堵漏剂A3以及粒度在20～40目之间的堵漏剂B3。
堵漏剂A3中，无机材料和核层的重量比为2.5：1；堵漏剂B3中，无机材料和核层的重量比为2.5：1；堵漏剂C3中，无机材料和核层的重量比为2.5：1。
性能评价：
(一)钻井液配伍性评价
分别将实施例3中不同目数的堵漏剂加入到钻井液基浆中，150℃/16h滚动老化后，测试钻井液流变性和滤失性能。其中，钻井液基浆的配方为：4wt％膨润土浆+0.2wt％黄原胶+0.2wt％低粘羧甲基纤维素钠+95.6wt％水。钻井液体系配方及评价结果见表7。
表7
注：表7中堵漏剂的重量含量是指物料占钻井液基浆的重量比。例如，2wt％堵漏剂C3(8～10目)是指堵漏剂C3(8～10目)的用量为钻井液基浆重量的2wt％。
通过配伍性实验得出，堵漏剂不影响钻井液流变性和滤失性，配伍性良好，可直接加入钻井液中堵漏使用。
(二)粘接强度评价
将实施例3中的产物体系在固化过程中浇筑模具，备成长10cm，宽1cm，厚度5mm的长方体状，然后用剪刀从中间剪断，然后剪断处拼接在一起，放在90℃烘箱中静置6h，然后放在万能试验机上测试抗拉强度，对比剪断前后的抗拉强度，见表8所示。
表8
通过剪断前后粘接强度对比实验得出，堵漏剂剪断后再进行粘接，粘接后的抗拉强度基本和剪断前持平，粘接性能良好，在漏层中颗粒会紧密粘接在一起，实现堵漏效果。
(三)封堵承压强度测试
将实施例2得到的不同目数的堵漏剂，加入到钻井液基浆中，然后利用裂缝封堵装置(温度设置为120℃，实验过程封堵裂缝就是挤压状态)测试封堵承压强度。其中，钻井液基浆的配方为：4wt％膨润土浆+0.2wt％黄原胶+0.2wt％低粘羧甲基纤维素钠+95.6wt％水。钻井液配方及评价结果见表9所示。
表9
注：表8中堵漏剂的重量含量是指物料占钻井液基浆的重量比。例如，2wt％堵漏剂C3(8～10目)是指堵漏剂C3(8～10目)的用量为钻井液基浆重量的2wt％。
通过测试结果可知，本发明上述堵漏剂在1和3mm裂缝开度能形成8MPa的承压强度，但是传统的核桃壳堵漏剂仅为2.5-3MPa的压力，堵漏剂承压效果优异。
对比例1
烧杯中加入聚丙二醇50g，加热至45℃并开始搅拌，然后加入甲苯二异氰酸酯5g，搅拌15min。然后加入3g的己二酸己二酰肼，继续搅拌20min，得到产物体系。然后将上述产物体系放在80℃烘箱中，加热6h，取出冷却至室温后，得到目标产物。将目标产物剪切、并筛分成粒度在8～10目之间、10～20目之间、20～40目之间的不同粒径的颗粒，并分别在2000目超细碳酸钙中搅拌均匀，然后继续筛分，得到粒度在8～10目之间的堵漏剂D、粒度在10～20目之间的堵漏剂E以及粒度在20～40目之间的堵漏剂F。
堵漏剂A中，无机材料和核层的重量比为1：1；堵漏剂B中，无机材料和核层的重量比为1：1；堵漏剂C中，无机材料和核层的重量比为1：1。
将对比例1中的产物体系在固化过程中浇筑模具，制备成长10cm，宽1cm，厚度5mm的长方体状，然后用剪刀从中间剪断，然后剪断处拼接在一起，放在80℃烘箱中静置6h，然后放在万能试验机上测试抗拉强度，剪断后拼接后的抗拉强度仅为25.2kPa，而本申请实施例1中堵漏剂的抗拉强度达到750.6kPa。
将对比例1中堵漏剂加入到钻井液基浆中，然后利用裂缝封堵装置测试封堵承压强度。配方如下：钻井液基浆+2wt％堵漏剂D(8～10目)+1wt％堵漏剂E(10～20目)+2wt％堵漏剂F(20～40目)+3wt％超细碳酸钙(800目)，在3mm裂缝开度仅为3.5MPa的承压压强，与本申请实施例1堵漏剂的承压能力8MPa相差较大。酰腙键虽然也具有粘接效应，但该材料在温度≥60℃条件下不能实现粘接，这是由于温度升高共聚物分子链卷曲包埋酰腙键，切口处酰腙键难以发生动态交换，因此无法实现粘接。且对比例1中堵漏剂与本申请前述堵漏剂相比不抗高温，在深井漏层中无法实现粘接作用。
对比例2
烧杯中加入聚丙二醇50g，加热至45℃并开始搅拌，然后加入甲苯二异氰酸酯5g，搅拌15min。然后加入3g的2,2’-二硫代二苯甲酸，继续搅拌20min。然后将上述混合物放在80℃烘箱中，加热6h，取出冷却至室温后，得到目标产物。
将目标产物剪切、并筛分成粒度在8～10目之间、10～20目之间、20～40目之间的不同粒径的颗粒，并分别在2000目超细碳酸钙中搅拌均匀，然后继续筛分，得到粒度在8～10目之间的堵漏剂M、粒度在10～20目之间的堵漏剂J以及粒度在20～40目之间的堵漏剂K。
堵漏剂M中，无机材料和核层的重量比为1：1；堵漏剂J中，无机材料和核层的重量比为1：1；堵漏剂K中，无机材料和核层的重量比为1：1。
将对比例2中的产物体系在固化过程中浇筑模具，制备成长10cm，宽1cm，厚度5mm的长方体状，然后用剪刀从中间剪断，然后剪断处拼接在一起，放在80℃烘箱中静置6h，然后放在万能试验机上测试抗拉强度，剪断后拼接后的抗拉强度仅为40.4kPa，而本申请实施例1中堵漏剂的抗拉强度达到750.6kPa。
将对比例2中堵漏剂加入到钻井液基浆中，然后利用裂缝封堵装置测试封堵承压强度。配方如下：钻井液基浆+2wt％堵漏剂M(8～10目)+1wt％堵漏剂K(10～20目)+2wt％堵漏剂J(20～40目)+3wt％超细碳酸钙(800目)，在3mm裂缝开度仅为2.5MPa的承压压强，与本申请实施例1堵漏剂的承压能力8MPa相差较大。芳香族和聚氨酯的结合程度较低。

Claims (15)

  1. 一种化学粘接堵漏剂，其中，包括核层以及包覆在所述核层外表面上的无机材料；所述核层的材料具有式Ⅰ所示结构：
    所述式Ⅰ中，表示m、n的数值满足所述核层的材料的数均分子量为20000～35000。
  2. 根据权利要求1所述的化学粘接堵漏剂，其中，所述核层的材料由聚丙二醇、甲苯二异氰酸酯和双(2-羟乙基)二硫醚经聚合、固化得到。
  3. 根据权利要求2所述的化学粘接堵漏剂，其中，所述聚合包括：在40～70℃温度条件下，先将所述聚丙二醇和所述甲苯二异氰酸酯混合反应10～40min，再向体系中加入所述双(2-羟乙基)二硫醚反应10～40min。
  4. 根据权利要求2所述的化学粘接堵漏剂，其中，所述聚合包括：在40～50℃温度条件下，先将所述聚丙二醇和所述甲苯二异氰酸酯混合反应10～20min，再向体系中加入所述双(2-羟乙基)二硫醚反应15～25min。
  5. 根据权利要求2所述的化学粘接堵漏剂，其中，所述固化的温度为70～100℃、时间为5～16h。
  6. 根据权利要求2所述的化学粘接堵漏剂，其中，所述固化的温度为80～90℃、时间为6～12h。
  7. 根据权利要求1所述的化学粘接堵漏剂，其中，所述无机材料选自碳酸钙、碳酸镁、膨润土和滑石粉中的一种或两种以上的组合。
  8. 根据权利要求1所述的化学粘接堵漏剂，其中，所述无机材料和所述核层的重量比为2～4：1。
  9. 根据权利要求1所述的化学粘接堵漏剂，其中，所述无机材料和所述核层的重量比为2～3：1。
  10. 根据权利要求1所述的化学粘接堵漏剂，其中，所述核层的材料具有颗粒状，粒度为8～40目。
  11. 根据权利要求1所述的化学粘接堵漏剂，其中，所述无机材料具有颗粒状，粒度为1800～2200目。
  12. 一种复合堵漏剂，其中，包括粒度在10～20目之间的堵漏剂A、粒度在20～40目之间的堵漏剂B以及可选地粒度在8～10目之间的堵漏剂C；
    所述堵漏剂A、所述堵漏剂B以及所述堵漏剂C各自独立地选自权利要求1至11中任一项所述的化学粘接堵漏剂；
    所述堵漏剂A、所述堵漏剂B和所述堵漏剂C的重量比为1～2：1：1～2。
  13. 根据权利要求12所述的复合堵漏剂，其中，所述堵漏剂A、所述堵漏剂B和所述堵漏剂C的重量比为1.5～2：1：1～1.5。
  14. 一种钻井液，其中，包括权利要求1至11中任一项所述的化学粘接堵漏剂，或者权利要求12或13所述的复合堵漏剂。
  15. 一种权利要求1至11中任一项所述的化学粘接堵漏剂、权利要求12或13所述的复合堵漏剂、或者权利要求14所述的钻井液在钻井工程中的应用。
PCT/CN2024/139559 2023-12-22 2024-12-16 化学粘接堵漏剂及包含其的复合堵漏剂、钻井液与其在钻井工程中的应用 Pending WO2025130809A1 (zh)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
CN202311791338.9A CN120192756A (zh) 2023-12-22 2023-12-22 堵漏剂及包含其的复合堵漏剂、钻井液与其在钻井工程中的应用
CN202311791338.9 2023-12-22

Publications (1)

Publication Number Publication Date
WO2025130809A1 true WO2025130809A1 (zh) 2025-06-26

Family

ID=96067633

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/CN2024/139559 Pending WO2025130809A1 (zh) 2023-12-22 2024-12-16 化学粘接堵漏剂及包含其的复合堵漏剂、钻井液与其在钻井工程中的应用

Country Status (2)

Country Link
CN (1) CN120192756A (zh)
WO (1) WO2025130809A1 (zh)

Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20080230223A1 (en) * 2007-03-22 2008-09-25 Hexion Specialty Chemicals, Inc. Low temperature coated particles for use as proppants or in gravel packs, methods for making and using the same
US20190203097A1 (en) * 2017-08-08 2019-07-04 Covestro Llc Polyurethanes for water shut-off in oil and gas wells
CN112574727A (zh) * 2019-09-30 2021-03-30 中国石油化工股份有限公司 堵漏组合物、堵漏剂及其制备方法与应用
CN112625667A (zh) * 2020-12-18 2021-04-09 成都劳恩普斯科技有限公司 疏水改性核壳结构环保型缓/控释暂堵剂及其制备方法
CN113416404A (zh) * 2021-06-10 2021-09-21 广东隽隆新型建材科技有限公司 新一代堵漏注浆材料
CN113444501A (zh) * 2020-03-25 2021-09-28 中国石油天然气集团有限公司 一种油基钻井液堵漏剂及其应用
CN114369222A (zh) * 2022-01-19 2022-04-19 四川大学 一种高强度室温快速自修复柔性材料及其制备方法和用途
CN114479779A (zh) * 2020-10-27 2022-05-13 中国石油化工股份有限公司 一种钻井液用堵漏剂及其制备方法
US20220267662A1 (en) * 2021-02-22 2022-08-25 Southwest Petroleum University Pressure-bearing plugging agent and preparation method and use thereof

Patent Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20080230223A1 (en) * 2007-03-22 2008-09-25 Hexion Specialty Chemicals, Inc. Low temperature coated particles for use as proppants or in gravel packs, methods for making and using the same
US20190203097A1 (en) * 2017-08-08 2019-07-04 Covestro Llc Polyurethanes for water shut-off in oil and gas wells
CN112574727A (zh) * 2019-09-30 2021-03-30 中国石油化工股份有限公司 堵漏组合物、堵漏剂及其制备方法与应用
CN113444501A (zh) * 2020-03-25 2021-09-28 中国石油天然气集团有限公司 一种油基钻井液堵漏剂及其应用
CN114479779A (zh) * 2020-10-27 2022-05-13 中国石油化工股份有限公司 一种钻井液用堵漏剂及其制备方法
CN112625667A (zh) * 2020-12-18 2021-04-09 成都劳恩普斯科技有限公司 疏水改性核壳结构环保型缓/控释暂堵剂及其制备方法
US20220267662A1 (en) * 2021-02-22 2022-08-25 Southwest Petroleum University Pressure-bearing plugging agent and preparation method and use thereof
CN113416404A (zh) * 2021-06-10 2021-09-21 广东隽隆新型建材科技有限公司 新一代堵漏注浆材料
CN114369222A (zh) * 2022-01-19 2022-04-19 四川大学 一种高强度室温快速自修复柔性材料及其制备方法和用途

Non-Patent Citations (3)

* Cited by examiner, † Cited by third party
Title
LI TING, ZHENG TIANZE, HAN JIARUI, LIU ZHANLI, GUO ZHAO-XIA, ZHUANG ZHUO, XU JUN, GUO BAO-HUA: "Effects of Diisocyanate Structure and Disulfide Chain Extender on Hard Segmental Packing and Self-Healing Property of Polyurea Elastomers", POLYMERS, vol. 11, no. 5, 1 January 2019 (2019-01-01), CH , pages 1 - 18, XP093324968, ISSN: 2073-4360, DOI: 10.3390/polym11050838 *
TANG LIRONG, WANG WEIBIN; WANG QINGHUA; ZHUANG SENYANG; CHEN CUIXIA; HUANG BIAO: "Esterified cellulose nanocrystals/poly(urea-urethane) self-healing materials based on aromatic disulfide bonds", CHEMICAL INDUSTRY AND ENGINEERING PROGRESS, vol. 36, no. 4, 5 April 2017 (2017-04-05), pages 1381 - 1387, XP093324962, ISSN: 1000-6613, DOI: 10.16085/j.issn.1000-6613.2017.04.030 *
YIN LONG, HE, PENG; QUAN, YIWU; CHEN, QINGMIN: "Synthesis and Properties of Polysulfide Sealant Containing Thio-urea", CHINA ELASTOMERICS, vol. 17, no. 5, 25 October 2007 (2007-10-25), pages 33 - 36, XP093324958, ISSN: 1005-3174, DOI: 10.16665/j.cnki.issn1005-3174.2007.05.012 *

Also Published As

Publication number Publication date
CN120192756A (zh) 2025-06-24

Similar Documents

Publication Publication Date Title
US9834719B2 (en) Methods for servicing subterranean wells
US4215001A (en) Methods of treating subterranean well formations
CN107880862B (zh) 一种提高承压能力的封堵剂及其制备方法
WO2017034637A1 (en) High density, high strength, acid soluble pseudo-crosslinked, lost circulation preventative material
KR20170071563A (ko) 구역 분리 및 갱정의 무결성을 위한 경화성, 재밀봉성, 팽창성, 반응성 실란트 조성물
CN107523281B (zh) 一种钻井液用油基泥浆堵漏剂
CN106867485B (zh) 一种抗高温堵漏剂、制备方法及其应用
CN101693830A (zh) 压裂用低成本水基清洁压裂液及破胶液
CN111925783A (zh) 一种用于裂缝储层的暂堵压井液及其应用和制备方法
CN106590609A (zh) 一种压裂液及其制备方法
CN106883832A (zh) 一种环保型可控暂堵剂及其制备方法
CN103781874A (zh) 在使用水溶性聚合物的粘弹性表面活性剂压裂流体中的流体损失控制
CN107572975A (zh) 一种堵漏剂、制备方法及其应用
US10233377B1 (en) Gel plugging slurry for well drilling and preparation method thereof, and slug plugging method
CN1303463A (zh) 包胶破胶剂浆料组合物及其使用方法
CN114574180A (zh) 一种延时成胶复合堵漏液及其制备方法
WO2025130809A1 (zh) 化学粘接堵漏剂及包含其的复合堵漏剂、钻井液与其在钻井工程中的应用
CN106634911A (zh) 一种逆相态暂堵剂及其制备方法
CN106010496A (zh) 一种co2增能酸性清洁压裂液及其制备方法
CN111073616B (zh) 一种暂堵剂及其应用
WO2020019165A1 (zh) 钻井用凝胶堵漏浆以及堵漏浆的制备方法和段塞堵漏方法
CN106543993A (zh) 钻井液用环保型低荧光封堵剂及其制备方法
CN112210353B (zh) 一种储层堵漏用高滤失高酸溶堵漏剂及其制备方法
CN118530705A (zh) 一种耐高温暂堵凝胶及其制备方法和应用
CN111394087A (zh) 一种压裂用非氧化性破胶剂的制备方法

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: 24906290

Country of ref document: EP

Kind code of ref document: A1