WO2014190793A1 - 一种凝胶及其用于堵漏的方法和堵漏压井的方法 - Google Patents

一种凝胶及其用于堵漏的方法和堵漏压井的方法 Download PDF

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WO2014190793A1
WO2014190793A1 PCT/CN2014/073091 CN2014073091W WO2014190793A1 WO 2014190793 A1 WO2014190793 A1 WO 2014190793A1 CN 2014073091 W CN2014073091 W CN 2014073091W WO 2014190793 A1 WO2014190793 A1 WO 2014190793A1
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monomer
gel
well
sodium
nonionic
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PCT/CN2014/073091
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English (en)
French (fr)
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罗平亚
郭拥军
王平全
张新民
冯茹森
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西南石油大学
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Priority to CA2882213A priority Critical patent/CA2882213C/en
Priority to US14/425,615 priority patent/US20160069153A1/en
Priority to EP14803882.1A priority patent/EP2876119B1/en
Publication of WO2014190793A1 publication Critical patent/WO2014190793A1/zh

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    • C—CHEMISTRY; METALLURGY
    • C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
    • C08F—MACROMOLECULAR COMPOUNDS OBTAINED BY REACTIONS ONLY INVOLVING CARBON-TO-CARBON UNSATURATED BONDS
    • C08F220/00—Copolymers of compounds having one or more unsaturated aliphatic radicals, each having only one carbon-to-carbon double bond, and only one being terminated by only one carboxyl radical or a salt, anhydride ester, amide, imide or nitrile thereof
    • C08F220/02—Monocarboxylic acids having less than ten carbon atoms; Derivatives thereof
    • C08F220/04—Acids; Metal salts or ammonium salts thereof
    • C08F220/06—Acrylic acid; Methacrylic acid; Metal salts or ammonium salts thereof
    • 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
    • E21B33/134—Bridging plugs
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B65—CONVEYING; PACKING; STORING; HANDLING THIN OR FILAMENTARY MATERIAL
    • B65B—MACHINES, APPARATUS OR DEVICES FOR, OR METHODS OF, PACKAGING ARTICLES OR MATERIALS; UNPACKING
    • B65B63/00—Auxiliary devices, not otherwise provided for, for operating on articles or materials to be packaged
    • B65B63/08—Auxiliary devices, not otherwise provided for, for operating on articles or materials to be packaged for heating or cooling articles or materials to facilitate packaging
    • C—CHEMISTRY; METALLURGY
    • C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
    • C08F—MACROMOLECULAR COMPOUNDS OBTAINED BY REACTIONS ONLY INVOLVING CARBON-TO-CARBON UNSATURATED BONDS
    • C08F220/00—Copolymers of compounds having one or more unsaturated aliphatic radicals, each having only one carbon-to-carbon double bond, and only one being terminated by only one carboxyl radical or a salt, anhydride ester, amide, imide or nitrile thereof
    • C08F220/02—Monocarboxylic acids having less than ten carbon atoms; Derivatives thereof
    • C08F220/52—Amides or imides
    • C08F220/54—Amides, e.g. N,N-dimethylacrylamide or N-isopropylacrylamide
    • C—CHEMISTRY; METALLURGY
    • C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
    • C08F—MACROMOLECULAR COMPOUNDS OBTAINED BY REACTIONS ONLY INVOLVING CARBON-TO-CARBON UNSATURATED BONDS
    • C08F220/00—Copolymers of compounds having one or more unsaturated aliphatic radicals, each having only one carbon-to-carbon double bond, and only one being terminated by only one carboxyl radical or a salt, anhydride ester, amide, imide or nitrile thereof
    • C08F220/02—Monocarboxylic acids having less than ten carbon atoms; Derivatives thereof
    • C08F220/52—Amides or imides
    • C08F220/54—Amides, e.g. N,N-dimethylacrylamide or N-isopropylacrylamide
    • C08F220/56—Acrylamide; Methacrylamide
    • 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
    • C09K8/424—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells using "spacer" 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
    • 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
    • C09K8/42—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
    • C09K8/504—Compositions based on water or polar solvents
    • C09K8/506—Compositions based on water or polar solvents containing organic compounds
    • C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
    • C—CHEMISTRY; METALLURGY
    • C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
    • C08F—MACROMOLECULAR COMPOUNDS OBTAINED BY REACTIONS ONLY INVOLVING CARBON-TO-CARBON UNSATURATED BONDS
    • C08F226/00—Copolymers of compounds having one or more unsaturated aliphatic radicals, each having only one carbon-to-carbon double bond, and at least one being terminated by a single or double bond to nitrogen or by a heterocyclic ring containing nitrogen
    • C08F226/02—Copolymers of compounds having one or more unsaturated aliphatic radicals, each having only one carbon-to-carbon double bond, and at least one being terminated by a single or double bond to nitrogen or by a heterocyclic ring containing nitrogen by a single or double bond to nitrogen
    • C—CHEMISTRY; METALLURGY
    • C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
    • C08F—MACROMOLECULAR COMPOUNDS OBTAINED BY REACTIONS ONLY INVOLVING CARBON-TO-CARBON UNSATURATED BONDS
    • C08F228/00—Copolymers of compounds having one or more unsaturated aliphatic radicals, each having only one carbon-to-carbon double bond, and at least one being terminated by a bond to sulfur or by a heterocyclic ring containing sulfur
    • C08F228/02—Copolymers of compounds having one or more unsaturated aliphatic radicals, each having only one carbon-to-carbon double bond, and at least one being terminated by a bond to sulfur or by a heterocyclic ring containing sulfur by a bond to sulfur

Definitions

  • the invention relates to the field of drilling, in particular to a gel and a method thereof for plugging and a method for plugging and killing a well.
  • Well leakage refers to the phenomenon that there are cracks or karst caves in the rock, and the leakage pressure is less than the pressure of the drilling fluid column. Under the positive pressure difference, the drilling fluid enters the leakage layer and leaks. After the occurrence of the leak, the drilling fluid is continuously lost to the cracks or caves, and the circulation cannot be completed. The phenomenon of “only inaccessible” occurs. In serious cases, the wellhead can not return to the working fluid at all, making the drilling operation unable to continue.
  • Blowout refers to the phenomenon that fluid in the formation is ejected from the ground when there is fluid (oil, gas or water, etc.) in the drilling formation and the fluid pressure is greater than the pressure of the drilling fluid in the well.
  • Well leakage and spurting coexistence refers to the phenomenon that both the fluid and the leakage layer exist in the drilling formation, and when the leakage pressure of the leakage layer is less than the fluid pressure, the fluid flows into the leakage layer, resulting in the phenomenon of underground blowout and ground blowout.
  • plugging material In the drilling plugging operation, the plugging material is usually transported to the leakage layer by the transport equipment, and the plugging material is formed in the drain layer to form the partition layer, and then the subsequent drilling work is performed.
  • plugging materials mainly include cement materials such as ordinary cement slurry, colloidal cement slurry and diesel bentonite cement slurry, bridging plugging materials for walnut shell, rubber pellet, perlite, raw shell and asphalt, plant fiber and animal fiber.
  • fibrous bridging plugging materials Such as fibrous bridging plugging materials, sheet-like bridging plugging materials such as mica flakes and cellophane.
  • the killing operation the killing is usually performed.
  • the liquid is injected into the well and the kill fluid is circulated in the well for circulation killing.
  • the killing fluid usually adopts a heavy mud with a relatively high density to balance the pressure of the formation fluid, that is, the killing fluid must be capable of generating a sufficiently high liquid column pressure.
  • the plugging material in the related technology cannot successfully stop or plug the well, mainly because The existing plugging material has poor compression resistance.
  • the killing fluid is injected, the high liquid column pressure generated by the killing fluid presses the high pressure fluid, but the plugging material is diluted under the high pressure of the killing fluid. Or it is scattered, and it is impossible to exert a plugging effect in the leakage layer, and then repeated leakage occurs. In severe cases, the well fluid is seriously lost and the fluid pressure cannot be balanced, and a blowout occurs.
  • the invention provides a gel and a method thereof for plugging and a method for plugging and killing a well, aiming at solving the above problems.
  • the present invention provides a gel obtained by copolymerization of a hydrophobic monomer and a nonionic monomer, or a copolymerization of a hydrophobic monomer, a nonionic monomer and an enoate monomer, wherein the introduction of the enoate monomer
  • the gel can be made to have more excellent flow properties.
  • the preparation method of the gel provided by the invention may be a post-copolymerization hydrolysis method and a copolymerization co-hydrolysis method.
  • the hydrophobic monomer is one or more of alkyldimethylallyl ammonium chloride and N-alkyl acrylamide; the nonionic monomer is acrylamide, methacrylamide, N-tert-butyl One or more of acrylamide, N-isopropylacrylamide; one or more of sodium methacrylate, sodium vinyl sulfonate and sodium acrylate;
  • the ratio between the three materials of the hydrophobic monomer, the nonionic monomer and the enoate monomer is: 1-5 parts of the hydrophobic monomer, 70-90 parts of the nonionic monomer, and the olefin according to the amount of the substance. 5-20 parts of acid salt monomer;
  • the time for introducing nitrogen gas is 40-120 min;
  • the polymerization temperature is 5-50 ° C;
  • the initiator is a redox initiator, wherein the oxidizing agent is one or more of potassium persulfate, ammonium persulfate, and sodium persulfate; and the reducing agent is one or more of sodium sulfite, sodium hydrogen sulfite, urea, and triethanolamine.
  • the oxidizing agent is one or more of potassium persulfate, ammonium persulfate, and sodium persulfate
  • the reducing agent is one or more of sodium sulfite, sodium hydrogen sulfite, urea, and triethanolamine.
  • the initiator is added in an amount of 0.05-2% of the total mass of the hydrophobic monomer, the nonionic monomer and the enoate monomer;
  • the hydrolyzing agent sodium hydroxide or sodium carbonate is added in an amount of 5-15% of the total mass of the hydrophobic monomer, the nonionic monomer and the olefin monomer;
  • the hydrolysis temperature is 80-110 ° C, and the hydrolysis time is 2-4 h;
  • the drying temperature is 80-120 ° C, and the drying time is 1-4 h.
  • the concentration of the monomer solution is 20-30%;
  • the time for introducing nitrogen gas is 60-100 min;
  • the polymerization temperature is 10-30 ° C; the polymerization time is 8-10 h;
  • the initiator is added in an amount of 0.1-0.5% of the total mass of the hydrophobic monomer, the nonionic monomer, and the enoate monomer;
  • the hydrolysis agent sodium hydroxide or sodium carbonate is added in an amount of 8-12% of the total mass of the hydrophobic monomer, the nonionic monomer and the enoate monomer;
  • the hydrolysis temperature is 90-95 ° C, the hydrolysis time is 2.5-3 h;
  • the drying temperature is 100-110 ° C and the drying time is 1.5-2 h.
  • the gel of the present invention can also be prepared by copolymerization co-hydrolysis, which eliminates the need for a separate hydrolysis operation, which reduces production costs and saves production cycles.
  • the steps of preparing the gel by copolymerization co-hydrolysis include:
  • the hydrophobic monomer is one or more of alkyldimethylallyl ammonium chloride and N-alkyl acrylamide; the nonionic monomer is acrylamide, methacrylamide, N-tert-butyl One or more of acrylamide, N-isopropylacrylamide; one or more of sodium methacrylate, sodium vinyl sulfonate and sodium acrylate;
  • the ratio between the three materials of the hydrophobic monomer, the nonionic monomer and the enoate monomer is: hydrophobic monomer according to the amount of the substance 1-5 parts, 70-90 parts of nonionic monomer, 5-20 parts of olefin monomer;
  • the sodium hydroxide or sodium carbonate is added in an amount of 5-15% of the total mass of the hydrophobic monomer, the nonionic monomer and the olefin monomer;
  • the time for introducing nitrogen gas is 40-120 min;
  • the polymerization temperature is 5-50 ° C;
  • the initiator is a redox initiator, wherein the oxidizing agent is one or more of potassium persulfate, ammonium persulfate, and sodium persulfate; and the reducing agent is one or more of sodium sulfite, sodium hydrogen sulfite, urea, and triethanolamine.
  • the oxidizing agent is one or more of potassium persulfate, ammonium persulfate, and sodium persulfate
  • the reducing agent is one or more of sodium sulfite, sodium hydrogen sulfite, urea, and triethanolamine.
  • the initiator is added in an amount of 0.05-2% of the total mass of the hydrophobic monomer, the nonionic monomer and the enoate monomer;
  • the drying temperature is 80-120 ° C, and the drying time is 1-4 h.
  • the concentration of the monomer solution is 20-30%;
  • the sodium hydroxide or sodium carbonate is added in an amount of 8-12% of the total mass of the hydrophobic monomer, the nonionic monomer and the enoate monomer;
  • the time for introducing nitrogen gas is 60-100 min;
  • the polymerization temperature is 10-30 ° C; the polymerization time is 8-10 h;
  • the initiator is added in an amount of 0.1-0.5% of the total mass of the hydrophobic monomer, the nonionic monomer, and the enoate monomer;
  • the drying temperature is 100-110 ° C and the drying time is 1.5-2 h.
  • the present invention also provides a method for plugging the above gel, comprising the following steps:
  • Step A 8-18 g of the gel is added to 1 kg of water by stirring, to obtain a hydrogel;
  • Step B injecting the hydrogel into the drain layer
  • Step C Inject the spacer into the well.
  • the method further comprises: injecting quick-setting cement into the well.
  • the present invention also provides a method for using the above gel for plugging a well, comprising the following steps:
  • Step 1 Add 8-18 g of the gel to 1 kg of water by stirring, to obtain a hydrogel;
  • Step two injecting the hydrogel into the drain layer
  • Step 3 inject a spacer into the well
  • Step 4 Inject the well with the heavy mud circulation killing well into the well.
  • the method further includes:
  • the injection speed of the hydrogel is equal to or greater than 4 m 3 /min;
  • the injection volume of the killing mud is 1.5-2 times of the volume of the annulus in the well.
  • the gel provided by the present invention is a binary copolymerization of a monomer having a hydrophobic group and a carbon-carbon double bond with a nonionic monomer having a carbon-carbon double bond to form a hydrogen bond and a hydrophobic group.
  • a macromolecular polymer which can be molecularly associated by intramolecular hydrogen bonding, intermolecular hydrogen bonding, and van der Waals force between hydrophobic groups. The association allows for higher viscoelasticity and thus can be in the drain layer.
  • the present invention also provides a method for using the gel for plugging and plugging a well, injecting a gel into the drain layer, and then injecting the killing mud, and the gel is used to block the drain layer.
  • the killing mud is used to kill the well, and because the gel can resist the pressure of the heavy mud of the killing well, the heavy mud of the killing well will not cause damage to the fault layer of the leakage layer, thereby effectively blocking the leakage and well working at the same time;
  • the gel can also be used for plugging during lost circulation.
  • FIG. 1 is a schematic flow chart of a method for plugging a leak using a gel according to an embodiment of the present invention
  • FIG. 2 is a schematic flow chart of a method for plugging and killing a well using a gel according to an embodiment of the present invention.
  • This embodiment provides a gel obtained by copolymerization of a hydrophobic monomer and a nonionic monomer, or a copolymerization of a hydrophobic monomer, a nonionic monomer, and an enoate monomer.
  • This embodiment provides a method for preparing the above gel by post-copolymerization hydrolysis, and the steps are as follows:
  • the hydrophobic monomer is one or more of alkyldimethylallyl ammonium chloride and N-alkyl acrylamide; the nonionic monomer is acrylamide, methacrylamide, N-tert-butyl One or more of acrylamide and N-isopropylacrylamide.
  • the hydrophobic monomer and the nonionic monomer may be added in any proportion of 1-5:70-90 according to the amount of the substance;
  • the concentration of the monomer solution is 10-40% (ie 10-40g/100mL), further recommended is 20-30%;
  • the time for introducing nitrogen gas is 40-120 min, and further recommended is 60-100 min;
  • the polymerization temperature is 5-50 ° C, and further recommended is 10-30 ° C;
  • the initiator is a redox initiator, wherein the oxidizing agent is one or more of potassium persulfate, ammonium persulfate, and sodium persulfate; and the reducing agent is one or more of sodium sulfite, sodium hydrogen sulfite, urea, and triethanolamine.
  • the oxidizing agent is one or more of potassium persulfate, ammonium persulfate, and sodium persulfate
  • the reducing agent is one or more of sodium sulfite, sodium hydrogen sulfite, urea, and triethanolamine.
  • the concentration of the initiator is 0.05-2% of the total mass of the hydrophobic monomer, the nonionic monomer and the enoate monomer, and further recommended to be 0.1-0.5%;
  • the polymerization time is 6-12h, and is further recommended to be 8-10h;
  • the hydrolyzing agent sodium hydroxide or sodium carbonate is added in an amount of 5-15% of the total mass of the hydrophobic monomer, the nonionic monomer and the olefin monomer, and is further recommended to be 8-12%;
  • the hydrolysis temperature is 80-110 ° C, the hydrolysis time is 2-4 h, and further recommended hydrolysis temperature is 90-95 ° C, hydrolysis time 2.5-3 h;
  • the drying temperature is 80-120 ° C, the drying time is 1-4 h, and the drying temperature is further recommended to be 100-110 ° C, and the drying time is 1.5-2 h.
  • the gel of the present invention can also be prepared by copolymerization co-hydrolysis, which eliminates the need for a separate hydrolysis operation, which reduces production costs and saves production cycles.
  • the steps of preparing the gel by copolymerization co-hydrolysis include:
  • the hydrophobic monomer is one or more of alkyldimethylallyl ammonium chloride and N-alkyl acrylamide;
  • the nonionic monomer is acrylamide, methacrylamide, N-tert-butyl One or more of acrylamide and N-isopropylacrylamide;
  • the hydrophobic monomer and the nonionic monomer may be added in any proportion of 1-5:70-90 according to the amount of the substance;
  • the concentration of the monomer solution is 10-40%, and further recommended is 20-30%;
  • the sodium hydroxide or sodium carbonate is added in an amount of 5-15% of the total mass of the hydrophobic monomer, the nonionic monomer and the olefin monomer, and is further recommended to be 8-12%;
  • the time for introducing nitrogen gas is 40-120 min, and further recommended is 60-100 min;
  • the polymerization temperature is 5-50 ° C, and further recommended is 10-30 ° C;
  • the initiator is a redox initiator, wherein the oxidizing agent is one or more of potassium persulfate, ammonium persulfate, and sodium persulfate; and the reducing agent is one or more of sodium sulfite, sodium hydrogen sulfite, urea, and triethanolamine.
  • the oxidizing agent is one or more of potassium persulfate, ammonium persulfate, and sodium persulfate
  • the reducing agent is one or more of sodium sulfite, sodium hydrogen sulfite, urea, and triethanolamine.
  • the concentration of the initiator is 0.05-2% of the total mass of the hydrophobic monomer, the nonionic monomer and the enoate monomer, and further recommended to be 0.1-0.5%;
  • the polymerization time is 6-12h, and is further recommended to be 8-10h;
  • the drying temperature is 80-120 ° C, the drying time is 1-4 h, and the drying temperature is further recommended to be 100-110 ° C, and the drying time is 1.5-2 h.
  • a gel may be prepared by copolymerization of a hydrophobic monomer, a nonionic monomer, and an enoate monomer.
  • the preparation steps using the post-copolymerization hydrolysis method are as follows:
  • deionized water is added according to the feed ratio, hydrophobic monomer, nonionic monomer and enoate monomer are added, and after stirring, a certain concentration of the monomer solution is formed, and nitrogen is removed to remove oxygen, and then the monomer solution is controlled to The polymerization temperature is required, the initiator is added to carry out the polymerization reaction, and after the polymerization for a period of time, the colloid is taken out for granulation, and then the hydrolysis agent sodium hydroxide or sodium carbonate is added for hydrolysis, and then dried, and after pulverization and packaging, the condensate is obtained.
  • Glue sample is added according to the feed ratio, hydrophobic monomer, nonionic monomer and enoate monomer are added, and after stirring, a certain concentration of the monomer solution is formed, and nitrogen is removed to remove oxygen, and then the monomer solution is controlled to The polymerization temperature is required, the initiator is added to carry out the polymerization reaction, and after the polymerization for a period
  • the hydrophobic monomer is one or more of alkyldimethylallyl ammonium chloride and N-alkyl acrylamide; the nonionic monomer is acrylamide, methacrylamide, N-tert-butyl One or more of acrylamide, N-isopropylacrylamide; and the enoate monomer is one or more of sodium methacrylate, sodium vinylsulfonate and sodium acrylate.
  • the ratio between the three materials of the hydrophobic monomer, the nonionic monomer and the enoate monomer is: 1-5 parts of the hydrophobic monomer, 70-90 parts of the nonionic monomer, and the olefin according to the amount of the substance. 5-20 parts of the acid salt monomer; the above three substances can be used in the proportion of the parts within the range of the composition of the three components;
  • the concentration of the monomer solution is 10-40%, and further recommended is 20-30%;
  • the time for introducing nitrogen gas is 40-120 min, and further recommended is 60-100 min;
  • the polymerization temperature is 5-50 ° C, and further recommended is 10-30 ° C;
  • the initiator is a redox initiator, wherein the oxidizing agent is one or more of potassium persulfate, ammonium persulfate, and sodium persulfate; and the reducing agent is one or more of sodium sulfite, sodium hydrogen sulfite, urea, and triethanolamine.
  • the oxidizing agent is one or more of potassium persulfate, ammonium persulfate, and sodium persulfate
  • the reducing agent is one or more of sodium sulfite, sodium hydrogen sulfite, urea, and triethanolamine.
  • the concentration of the initiator is 0.05-2% of the total mass of the hydrophobic monomer, the nonionic monomer and the enoate monomer, and further recommended to be 0.1-0.5%;
  • the polymerization time is 6-12h, and is further recommended to be 8-10h;
  • the hydrolyzing agent sodium hydroxide or sodium carbonate is added in an amount of 5-15% of the total mass of the hydrophobic monomer, the nonionic monomer and the olefin monomer, and is further recommended to be 8-12%;
  • the hydrolysis temperature is 80-110 ° C, the hydrolysis time is 2-4 h, and further recommended hydrolysis temperature is 90-95 ° C, hydrolysis time 2.5-3 h;
  • the drying temperature is 80-120 ° C, the drying time is 1-4 h, and the drying temperature is further recommended to be 100-110 ° C, and the drying time is 1.5-2 h.
  • the hydrophobic monomer is one or more of alkyldimethylallyl ammonium chloride and N-alkyl acrylamide; the nonionic monomer is acrylamide, methacrylamide, N-tert-butyl One or more of acrylamide, N-isopropylacrylamide; and the enoate monomer is one or more of sodium methacrylate, sodium vinylsulfonate and sodium acrylate.
  • the ratio between the three materials of the hydrophobic monomer, the nonionic monomer and the enoate monomer is: 1-5 parts of the hydrophobic monomer, 70-90 parts of the nonionic monomer, and the olefin according to the amount of the substance.
  • the acid salt monomer is 5-20 parts; similarly, the three substances can be combined in any fraction within the range of their fractions.
  • the concentration of the monomer solution is 10-40%, and further recommended is 20-30%;
  • the sodium hydroxide or sodium carbonate is added in an amount of 5-15% of the total mass of the hydrophobic monomer, the nonionic monomer and the olefin monomer, and is further recommended to be 8-12%;
  • the time for introducing nitrogen gas is 40-120 min, and further recommended is 60-100 min;
  • the polymerization temperature is 5-50 ° C, and further recommended is 10-30 ° C;
  • the initiator is a redox initiator, wherein the oxidizing agent is one or more of potassium persulfate, ammonium persulfate, and sodium persulfate; and the reducing agent is one or more of sodium sulfite, sodium hydrogen sulfite, urea, and triethanolamine.
  • the oxidizing agent is one or more of potassium persulfate, ammonium persulfate, and sodium persulfate
  • the reducing agent is one or more of sodium sulfite, sodium hydrogen sulfite, urea, and triethanolamine.
  • the concentration of the initiator is 0.05-2% of the total mass of the hydrophobic monomer, the nonionic monomer and the enoate monomer, and further recommended to be 0.1-0.5%;
  • the polymerization time is 6-12h, and is further recommended to be 8-10h;
  • the drying temperature is 80-120 ° C, the drying time is 1-4 h, and the drying temperature is further recommended to be 100-110 ° C, and the drying time is 1.5-2 h.
  • the nitrogen used in the above method is preferably a high purity nitrogen gas, and the effect is better.
  • Embodiment 6 Gel plugging method
  • the above gel is a macromolecular polymer having a hydrogen bond and a hydrophobic group by binary copolymerization of a monomer having a hydrophobic group and a carbon-carbon double bond with a nonionic monomer having a carbon-carbon double bond, and the polymer can pass Molecular association by intramolecular hydrogen bonding, intermolecular hydrogen bonding, and van der Waals force between hydrophobic groups.
  • the association makes it have high viscoelasticity, so that gaps or formation fluids and wells can be formed in the drain layer.
  • the gel provided by the invention can be used for plugging leakage during a lost circulation or a plugging and killing well when the well is leaking.
  • the high pressure fluid layer usually refers to a pressure greater than 40 Fluid layer of MPa.
  • the gel can be mixed with materials such as bridge plug particles and cement without affecting its own characteristics, so that it can be mixed with other materials when the leakage is not serious.
  • the gel provided by the present embodiment has high compressive performance compared with the existing plugging material, and the well leaking in the treatment for the leakage of the ground layer and the wellbore of the same wellbore in the drain hole and the high pressure gas layer are disposed. Leakage and coexistence, the use of the gel can shorten the time to rescue, reduce construction risks, and reduce economic costs.
  • the two types of monomers contained in the above gel may be selected from any of the reagents satisfying the conditions, for example, the monomer containing a hydrophobic group and a carbon-carbon double bond may be: alkyl dimethylallyl chlorination One or a combination of two of ammonium and N-alkyl acrylamide; the nonionic monomer containing a carbon-carbon double bond may be: acrylamide, methacrylamide, N-tert-butyl acrylamide, One or any combination of four reagents of N-methacrylamide.
  • the method of plugging using the above gel includes the following steps:
  • Step 101 adding 8-18 g of the gel to 1 kg of water by weight, to obtain a hydrogel;
  • Step 102 injecting the hydrogel into the drain layer
  • Step 103 Inject a spacer into the well.
  • the concentration of the gel in the above step 101 is very important, which directly affects the viscosity of the hydrogel.
  • the optimum mass ratio of the gel to the water is 8 g: 1 kg. -18g: 1kg, the viscosity can reach 30,000-60000 mPa•s, in this range, it can guarantee the viscosity required for plugging and has certain pumpability. In actual use, it can be adjusted as needed. Stirring can be carried out during the preparation. After stirring for 1 hour, the gel dry powder is dissolved to form a gel, and the insoluble matter in the gel should be observed by the naked eye.
  • the viscosity is measured by sampling to reach 30,000-60000 mPa•s. If viscosity ⁇ 30000 For mPa•s, it is necessary to increase the gel concentration and the gel viscosity is >30000 mPa•s; or change the gel dry powder for the test.
  • the concentration used for recording is recorded as the basis for on-site preparation; The dissolution time used was recorded, and the on-site preparation time was added 0.5-1.0 hours on the basis of this time for future reference.
  • the prepared gel should be tested for contamination with killing fluid and cement slurry.
  • the gel injected in step 102 forms a slug (ie, partition) in the drain layer, and a barrier layer may be formed on the high pressure gas layer or the oil layer, and the partition liquid is added through step 103 to avoid gel and subsequent drilling fluid.
  • the liquids are contaminated with each other.
  • the injection in the two steps of steps 102-103 can select the injection mode according to actual needs, such as positive injection, reverse injection or positive and negative injection.
  • the method of using the above gel for plugging and killing the well includes the following steps:
  • Step 201 adding 8-18 g of the gel to 1 kg of water by weight to obtain a hydrogel
  • Step 202 injecting the hydrogel into the drain layer
  • Step 203 injecting a spacer liquid into the well
  • Step 204 Injecting a well killing heavy mud circulation kill into the well.
  • the method adds the step 204 to the above-mentioned plugging method, and finally the step 204 re-injects the killing mud slurry to the well, until the pressure in the well reaches the requirement, and the normal drilling exploration or development operation can be performed.
  • the spacer liquid is preferably water, which is convenient to obtain and low in cost.
  • the injection in the three steps of steps 202-204 can select the injection mode according to actual needs, such as positive injection, reverse injection or positive and negative injection.
  • a hydrogel can be prepared in a tank with a stirrer, for example, 40 m 3 and 35 m 3 tanks can be equipped with two stirrers, 60 m 3 tanks can be equipped with 3 stirrers, and all stirrers must be working properly.
  • the gel preparation tank must be cleaned and rust-removed; the tank is equipped with a submersible pump or a screw pump or a sand pump; when multiple tanks are used, the tanks are connected with a pipeline of 10 inches or more; a special cement truck or a fracturing pump is required.
  • Send gel, the displacement should be more than 4m 3 /min; cement truck and / or fracturing truck for killing, cement truck or fracturing truck and the tank with 6 inches or more.
  • the geological and drilling data of the well and adjacent wells should be collected, including formation pressure, formation fracture pressure, formation leakage, drilling fluid performance, formation oil and gas display, drilling structure, vertical pressure, Set pressure, blowout type, etc.
  • the concentration of the gel is determined according to the natural gas production, the leakage of the leakage layer, the position of the leakage layer and the gas layer, the target of the plugging and killing, the structure of the well body and the condition of the well string.
  • the gel should be squeezed into the lost formation about 100 m 3 (if the loss rate is too high, it can increase by 30%-50%); while the wellbore remains filled with the amount of wellbore.
  • the amount can usually be designed in accordance with 100 m 3 (1.0-1.5 times the effective volume of the annulus in the well).
  • the density of the killing fluid is calculated according to the vertical pressure of the well, the pressure of the casing, and the density of the drilling fluid at that time; the dosage is generally 1.5-2 times the effective volume of the annulus.
  • the gel has high viscosity and strong structural characteristics.
  • the recommended liquid supply mode is as follows: the lower outlet pipe of the preparation tank is directly pumped with the pump truck or the fracturing truck. The upper water pipe of the pump is connected, and the pump is injected into the well from the preparation tank by a pump truck or a fracturing truck.
  • the connecting line for the pumped gel should be greater than or equal to 6 inches.
  • use one or several submersible pumps screw pumps or sand pumps to pour the gel into the pump or fracturing truck separately or simultaneously from the different preparation tanks and then into the well.
  • a 4-5 m 3 iron can the lower opening (one or more) of which is sized to match and be associated with the pump or fracturing water line.
  • the can is placed on an iron frame higher than the fracturing cart as a liquid supply transition tank.
  • one or several submersible pumps screw pump or sand pump are used to separate the gel from the different preparation tanks into the liquid supply transition tank separately or simultaneously, and then injected into the well by the pump truck or the fracturing truck.
  • this embodiment also provides a test example:
  • the formulated water was added to each of the preparation tanks as required, and the amount of gel dry powder (Kg) added per tank of water was calculated according to the test concentration.
  • the screw pump (submersible pump or sand pump) is installed in each tank, and the outlet end is placed at the feeding port to realize the circulation inside the tank.
  • the gel can be used immediately after it is used. Stirring should not be stopped during this time; if it is not immediately pressed, the stirring can be stopped.
  • the gel placed for 1-2 days does not affect its use. Stir for more than 20 minutes before use, and restore the fluidity of the gel before use.
  • the gel can be supplied with water as required and the water can be discharged normally. Whether the displacement can meet the requirements of the killing scheme.
  • the equipment, pipelines, gates and liquid supply method should be rectified until the requirements are met.
  • the test can be carried out using a short cycle from the formulation tank to the tank by means of a cement truck or a fracturing truck.
  • the gel With agitation, the gel is in a flow state in the formulation tank and pumping is initiated (pressing the well plan requires positive or negative injection or simultaneous positive and negative injection).
  • the pump can't interrupt the stop and guarantee the displacement.
  • the agitator cannot be stopped until the pump is completed.
  • the killing parameters (such as density, displacement, and killing fluid dosage)
  • the initial setting time of the cement slurry depends on the conditions on the well.
  • the operation requirements are the same as for conventional high pressure natural gas wells (in the case where the kill fluid is not leaking and not atomized).
  • the cement slurry is injected for sealing or sealing.
  • the displacement can be reduced to continue the solidification of the slurry to the cement slurry, and the pressure in the drill pipe is coagulated.
  • the killing fluid circulation channel When plugging or sealing with cement slurry, the killing fluid circulation channel must be retained; the top of the cement slurry must be replaced with a suitable position between the leaking layer and the gas layer.
  • the kill fluid can be poured into the annulus.
  • the gels prepared in the above embodiments have different methods for plugging and killing wells in drilling, as follows:
  • the leakage velocity of the leakage layer is not too large, and the leakage pressure is not much different from the pressure of the fluid layer (for example, less than 2 MPa). If the natural gas does not contain H 2 S, the following method can be used:
  • the leak rate of the leakage layer is large, the difference between the leakage layer pressure and the fluid layer pressure is large, and the natural gas contains high H 2 S; or other complicated ground conditions, it is best to adopt the following method:
  • the isolation liquid After injecting a certain amount of gel according to the design, inject the isolation liquid, and then follow the cement and cement plug to directly seal the gas layer; inject the isolation liquid, then use the killing fluid to establish a cycle, and then perform other operations after the circulation and killing.
  • the performance and dosage of the mud are determined according to the depth of the well, the temperature at the bottom of the well, the pressure, the position and length of the sealing section, the performance of the well mud and the operation time of the well.
  • the spacer liquid may be water or the like.
  • control the kill fluid and mud displacement according to the type of blowout and the killing process (if possible, try to be as large as possible). Also note: control sleeve pressure Less than the maximum allowable shut-in casing pressure.
  • control sleeve pressure Less than the maximum allowable shut-in casing pressure.
  • the present embodiment also provides two test cases:
  • the Luojia 2 well is a pre-exploration well in the Luojiazhai gas field with a well depth of 3404 m.
  • the unobstructed flow of the well is 265 ⁇ 104 m 3 /d, and the test output is 63 ⁇ 104 m 3 /d.
  • March 2006 the well was fractured in the second completion.
  • the natural gas containing a large amount of H 2 S from the bottom of the well was leaked from the outer ring of the Luojia injection water well to the ground through the fault, causing natural gas containing H 2 S.
  • the Luojia 2 well is very complicated and has become a rare problem of well killing: (1) Spraying and leaking are in the same section.
  • the distance between the center of Luojia 2 well and Luojia injection water 1 is 2.52 m, and the borehole distance is 124.29 m at 2180 m.
  • Both the Luojia 2 well and the Luojia injection water 1 well lost tens of thousands of cubic meters of liquid when drilling to the Jia 5 section.
  • the Luojia 2 well casing has a large well inclination in the Jia 5 member stratum, and the inner wall is seriously worn by the drilling tool.
  • the Luojia injection water 1 well is drilled and perforated and once 30 m 3 acidification operation.
  • the casing of Luojia 2 well ruptured, and the killing fluid and the bottom hole gas entered the leakage layer through the breach, and the leakage occurred in the same stratum, making the well plugging a difficult problem.
  • the drain layer contains a large amount of water.
  • the well depth of the clear water surface of the Luojia injection water well was 158 m, and the bottom pressure of the Jiawu section (238-2223 m) was about 19.82 MPa.
  • the stratum contains a large amount of water, so that the 3H plugging slurry, the bridge plug leaking slurry, the cement slurry can not be re-accumulated after being blown away by the high-pressure airflow, and it is washed away and can not be piled up to form a structure near the break. It is 4 times in the previous period. The main reason for the failure of plugging. (5) The falling fish is not good for plugging the drain.
  • the design of the plug-in of the Luojia 2 well can not be continued due to the hydrogen embrittlement fracture of the drill.
  • the length of the falling fish is 525m, and the bottom end of the falling fish is A177.8 mm scraper.
  • the gap between the falling fish and the casing is only a few millimeters.
  • the leakage of the bridge plug is easy to block in this small gap, so the bridge plug is used.
  • the slurry leakage and plugging scheme is not feasible, which increases the difficulty of plugging.
  • the natural gas that is ejected contains high H 2 S.
  • the H 2 S content of the natural gas at the bottom of the well is 125.53 g/m 3 , and the H 2 S content in the air at the ground leakage gradually increases from no to 9.8 mg/m 3 .
  • Gases containing high H 2 S are highly susceptible to corrosion of the drill. The longer the time, the more complex the condition of the bottom hole and the more dangerous the wellhead.
  • the gel of 235 m 3 (large displacement, large dose) of the present invention having a mass concentration of 1.5% is used to slow down the fluid (gas) enthalpy, reduce the leak rate, and increase the flow resistance of the plugging agent.
  • the anti-injection cement slurry is 67.5 m 3 , and the well is condensed.
  • the sleeve pressure and vertical pressure are both 0.
  • the flame of the nozzle of Luojia injection water 1 continued to decrease, and the flame appeared to be fluctuating from small to small and intermittently extinguished.
  • the ground leakage ignition potential was also significantly reduced, and the sealing was basically successful.
  • the annular injection gel is 185 m 3
  • the annular grouting cement slurry is 86 m 3 to block the gas layer of Feixianguan Formation.
  • the vertical pressure and casing pressure are 0. Shujing waiting for condensation. Continuous observation, the wellhead pressure of Luojia 2 well is 0. It has been confirmed that the gas layer of Feixianguan Formation has been completely cut off, the rescue and rescue mission of the well is basically completed, and the Luojia 2 well has been successfully blocked and well-killed.
  • Dazhou Shuangmiao 1 well is a vertical exploration well of Sinopec Southern Company in the eastern Sichuan region, with a designed well depth of 4373 m. Drilled to 3573 m, the open hole section was 1622 m, and 6 leaky layers were drilled in the open hole section, of which 3 were lost in the loss-return type.
  • drilling high pressure gas layer gas layer
  • the pressure coefficient is between 1.71-1.88 g/cm 3
  • the initial test unobstructed flow is 60 ⁇ 104 m 3 /d).
  • the bottom hole overflow is 1.97-1.80 g/cm 3 high density drilling hydraulic well due to gas layer pressure coefficient.
  • the gas layer formation has a pressure bearing capacity of only 1.81 g/cm 3 , which is lower than that of the upper formation, and the gas layer is leaked during the killing process.
  • the original cracks in the gas layer become wider and the connectivity is better, resulting in a serious loss of the lost-back type, and a complex leak of the same layer in the same layer is formed.
  • the field technicians have used the bridge plugging (maximum particle size up to 3 cm), 9 times to block the cement plugging, and the bridge plug and cement composite plugging method have not been effective. The phenomenon of leakage and coexistence has not been controlled.
  • High-pressure gas reservoir overflow and well leakage are not effectively controlled for a long time, which seriously threatens the stability of the well wall of the upper formation. Since the well leakage of the high-pressure gas layer causes the liquid level in the well to drop, the pressure of the liquid column used to balance the upper formation decreases, causing a large amount of back-draining of the bridge plug in the upper stratum to seal the lost layer, and the original upper layer is lost again, and When the casing pressure is high, there is also a case where the lower high-pressure gas enters the upper leakage layer and the underground blowout occurs. The bridge material that is discharged from the upper leakage layer is deposited in the annulus borehole, causing stuck drills.
  • the rotor position In the initial stage of the stuck drill, the rotor position can move up and down nearly 100 m (3573-3484 m), but due to the long time of the wellbore Soaking, the shale minerals in this area are mainly in the Yi/Mongolian disordered layer, the smectite content in the interlayer is high, the hydration expansion is more serious, and the erosion of the well wall is caused by the high-pressure gas slippage. Some of the well walls collapsed and the drill bit was finally stuck. The card points were 2500m and 3474m respectively. After the drill bit was stuck, several times of cement plugging were used, and the overflow and lost circulation of the lower high pressure gas layer were not effectively controlled.
  • the double gate blowout preventer of the wellhead is under high pressure for a long time and the lower gate is hit by the solid phase particles carried by the high pressure gas, the piercing failure occurs, and the safety of the wellhead is seriously threatened.
  • the drilling pump continuously supplies the high-density drilling fluid to the wellsite mud tank.
  • Special gel 40 m 3 was injected into the drill because the density of the special gel was only 1.01 g/cm 3 .
  • the gel with a concentration of 1.0% at 40 m 3 was fractured.
  • the car was divided into two injections, and 10m 3 high-density drilling fluid (1.95 g/cm 3 ) was injected in the middle.
  • the pump pressure was observed and the pump pressure was controlled to be less than or equal to 25 MPa.
  • the quick-setting cement slurry was injected into the drill from 25 m 3 , and the cement slurry density was greater than or equal to 1.85 g/cm 3 .
  • the pump pressure was observed and the pump pressure was controlled to be less than 25 MPa.
  • the well is condensed to make the gel form its strength and the cement slurry solidifies.
  • the cement slurry After the cement slurry has been condensed for 24 h, it is discharged (pressure), vertical pressure, and sleeve pressure, and the vertical pressure is 0, which achieves the purpose of sealing the annulus (successful separation) and blocks the high-pressure gas layer at the bottom of the well.
  • the gel provided by the invention, the preparation method thereof and the plugging and killing method in the drilling well can cope with the complicated well leakage blowout accident in the oil and gas well.

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Abstract

本发明涉及钻井领域，具体涉及一种凝胶及其用于堵漏的方法和堵漏压井的方法。该凝胶为疏水单体和非离子单体共聚而成的水溶性疏水缔合聚合物，或是由疏水单体、非离子单体和烯酸盐单体共聚而成的水溶性疏水缔合聚合物，其聚合方法可为共聚后水解法或共聚共水解法。使用该凝胶进行堵漏的方法包括：向1kg水中，加入8-18g凝胶，并向漏层中注入；再注入隔离液。该凝胶用于堵漏压井的方法在堵漏方法的基础上增加了：向井中注入压井重泥浆循环压井。本发明提供一种凝胶，相比现有堵漏材料，具有更高的抗压性能，可用于解决地层裂缝性溶洞型恶性井漏，以及漏层和高压气层在同一井眼的井喷井漏同存。

Description

一种凝胶及其用于堵漏的方法和堵漏压井的方法 技术领域
本发明涉及钻井领域，具体涉及一种凝胶及其用于堵漏的方法和堵漏压井的方法。
 背景技术
井漏是指岩石中存在裂缝或溶洞等漏层，且漏层压力小于钻井液柱压力时，在正压差的作用下钻井液进入漏层发生漏失的现象。井漏发生后，钻井液不断漏失到裂缝或溶洞中，而无法完成循环，出现“只进不出”的现象，严重时井口可完全不返工作液，使得钻井作业无法继续。
井喷是指钻井地层中存在流体（油、气或水等），且流体压力大于井内钻井液压力时，地层中流体喷出地面的现象。
井漏井喷同存是指钻井地层中既存在流体，又存在漏层，且漏层漏失压力小于流体压力时，流体流入漏层，导致发生地下井喷和地面井喷的现象。
解决井漏问题，需要进行堵漏作业，在钻井堵漏作业中，通常是通过运输设备将堵漏材料运送至漏层，待堵漏材料在漏层形成隔断层后，再进行后续钻井工作。目前，国内外开发了很多种堵漏材料。现有堵漏材料主要包括普通水泥浆、胶质水泥浆、柴油膨润土水泥浆等水泥材料，核桃壳、橡胶粒、珍珠岩、生贝壳、沥青等颗粒的桥接堵漏材料，植物纤维、动物纤维等纤维状的桥接堵漏材料，云母片、玻璃纸等片状的桥接堵漏材料。
解决井漏井喷同存问题，需要堵漏压井，即先进行堵漏作业（与上述井漏中的堵漏作业相同），再进行压井作业，在压井作业中，通常是将压井液注入井中，并使压井液在井中循环以进行循环压井。相关技术中，压井液通常采用密度较大的重泥浆，才能平衡地层流体压力，即压井液必须能够产生足够高的液柱压力。
但针对地层漏失裂缝较宽的井漏，以及漏层和高压气层在同一井眼的井喷井漏同存，相关技术中的堵漏材料并不能成功堵漏或堵漏压井，主要原因是：现有的堵漏材料抗压性能差，当注入压井液时，压井液产生的高液柱压力虽然压住了高压流体，但堵漏材料在压井液的高压作用下被冲稀或冲散，而无法在漏层发挥堵漏作用，进而发生重复性漏失，严重时压井液严重漏失而无法平衡流体压力，进而发生井喷。
 技术问题
本发明提供了一种凝胶及其用于堵漏的方法和堵漏压井的方法，旨在解决上述问题。
 技术解决方案
本发明提供了一种凝胶，由疏水单体和非离子单体共聚而成，或由疏水单体、非离子单体和烯酸盐单体共聚而成，其中烯酸盐单体的引入可使凝胶具有更加优异的流动性能。
本发明提供的凝胶的制备方法，可为共聚后水解法和共聚共水解法。
其中共聚后水解法制备凝胶的步骤为：
首先按照投料比加入去离子水，加入疏水单体和非离子单体，或者根据凝胶流动性能要求继续加入烯酸盐单体，搅拌均匀后形成浓度为10-40%的单体溶液，并通入氮气除氧，然后将单体溶液控制到聚合温度，加入引发剂进行聚合反应，经聚合6-12h后，取出胶体进行造粒，然后加入水解剂氢氧化钠或碳酸钠进行水解，再进行干燥，经粉碎和包装，即可得到凝胶样品；
所述疏水单体为烷基二甲基烯丙基氯化铵和N-烷基丙烯酰胺的一种或几种；所述非离子单体为丙烯酰胺、甲基丙烯酰胺、N-叔丁基丙烯酰胺、N-异丙基丙烯酰胺的一种或几种；所述烯酸盐单体为甲基丙烯酸钠、乙烯基磺酸钠和丙烯酸钠的一种或几种；
所述疏水单体、非离子单体和烯酸盐单体三个物质之间的配比为：按照物质的量计，疏水单体1-5份，非离子单体70-90份，烯酸盐单体5-20份；
所述通入氮气的时间为40-120min；
所述聚合温度为5-50℃；
所述引发剂为氧化还原引发剂，其中氧化剂为过硫酸钾、过硫酸铵、过硫酸钠的一种或几种；还原剂为亚硫酸钠、亚硫酸氢钠、尿素、三乙醇胺的一种或几种；
所述引发剂的加入量为疏水单体、非离子单体和烯酸盐单体总质量的0.05-2%；
所述水解剂氢氧化钠或碳酸钠的加入量为疏水单体、非离子单体和烯酸盐单体总质量的5-15%；
所述水解温度为80-110℃，水解时间为2-4h；
所述干燥温度为80-120℃，干燥时间为1-4h。
进一步地，所述单体溶液的浓度为20-30%；
所述通入氮气的时间为60-100min；
所述聚合温度为10-30℃；所述聚合时间为8-10h；
所述引发剂的加入量为疏水单体、非离子单体和烯酸盐单体总质量的0.1-0.5%；
所述水解剂氢氧化钠或碳酸钠的加入量为疏水单体、非离子单体和烯酸盐单体总质量的8-12%；
所述水解温度为90-95℃，水解时间为2.5-3h；
所述干燥温度为100-110℃，干燥时间为1.5-2h。
除共聚后水解法制备凝胶外，本发明所述的凝胶还可采用共聚共水解法制备，这样就不需要进行单独的水解操作，既降低生产成本，又能节省生产周期。共聚共水解法制备凝胶的步骤包括：
按照投料比加入去离子水，加入疏水单体和非离子单体，或者根据凝胶流动性能要求继续加入烯酸盐单体，搅拌均匀后形成浓度为10-40%的单体溶液，再加入氢氧化钠或碳酸钠，并通入氮气除氧，然后将聚合体系控制到聚合温度，加入引发剂进行聚合反应，经聚合6-12h后，取出胶体进行造粒，经干燥，粉碎和包装，即可得到凝胶样品；
所述疏水单体为烷基二甲基烯丙基氯化铵和N-烷基丙烯酰胺的一种或几种；所述非离子单体为丙烯酰胺、甲基丙烯酰胺、N-叔丁基丙烯酰胺、N-异丙基丙烯酰胺的一种或几种；所述烯酸盐单体为甲基丙烯酸钠、乙烯基磺酸钠和丙烯酸钠的一种或几种；
所述疏水单体、非离子单体和烯酸盐单体三个物质之间的配比为：按照物质的量计，疏水单体 1-5份，非离子单体70-90份，烯酸盐单体5-20份；
所述氢氧化钠或碳酸钠的加入量为疏水单体、非离子单体和烯酸盐单体总质量的5-15%；
所述通入氮气的时间为40-120min；
所述聚合温度为5-50℃；
所述引发剂为氧化还原引发剂，其中氧化剂为过硫酸钾、过硫酸铵、过硫酸钠的一种或几种；还原剂为亚硫酸钠、亚硫酸氢钠、尿素、三乙醇胺的一种或几种；
所述引发剂的加入量为疏水单体、非离子单体和烯酸盐单体总质量的0.05-2%；
所述干燥温度为80-120℃，干燥时间为1-4h。
进一步地，所述单体溶液的浓度为20-30%；
所述氢氧化钠或碳酸钠的加入量为疏水单体、非离子单体和烯酸盐单体总质量的8-12%；
所述通入氮气的时间为60-100min；
所述聚合温度为10-30℃；所述聚合时间为8-10h；
所述引发剂的加入量为疏水单体、非离子单体和烯酸盐单体总质量的0.1-0.5%；
所述干燥温度为100-110℃，干燥时间为1.5-2h。
除提供上述凝胶的制备方法外，本发明还提供了上述凝胶用于堵漏的方法，包括下列步骤：
步骤A：按重量计，向1 kg水中，边搅拌边加入8-18 g所述凝胶，得到水凝胶；
步骤B：向漏层中注入所述水凝胶；
步骤C：向井中注入隔离液。
进一步地，所述步骤C之后还包括：向井中注入快凝水泥。
除提供上述凝胶的制备方法外，本发明还提供了上述凝胶用于堵漏压井的方法，包括下列步骤：
步骤一：按重量计，向1 kg水中，边搅拌边加入8-18 g所述凝胶，得到水凝胶；
步骤二：向漏层中注入所述水凝胶；
步骤三：向井中注入隔离液；
步骤四：向井中注入压井重泥浆循环压井。
进一步地，所述步骤四之后还包括：
向井中注入快凝水泥。
进一步地，所述步骤二中，所述水凝胶的注入速度等于或大于4 m3/min；
和/或，所述步骤四中，所述压井重泥浆的注入量为井内环空容积的1.5-2倍。
 有益效果
与现有技术相比，本发明提供的凝胶是由疏水基和碳-碳双键的单体与含碳-碳双键的非离子性单体二元共聚形成具有氢键和疏水基的大分子聚合物，该聚合物可以通过分子内氢键、分子间氢键和疏水基间范德华力等方式进行分子缔合，该缔合作用使其具有较高的粘弹性，因而可以在漏层中形成将缝隙或地层流体与压井液隔断的凝胶隔断层；并且缔合作用使得其分子间作用力很大，即内聚力较大，并且大于该聚合物与水之间的亲和力，因而其很难与水混合并被冲稀，并且在凝胶静置后，该内聚力随时间增加而增强，因此凝胶隔断层被破坏需要的压力较大，并且大于压井液的压力，因而凝胶隔断层不会被压井液冲稀或冲散，由此可见，本发明提供的凝胶相比现有技术，具备更好的抗压性能。
除此之外，本发明还提供了一种使用该凝胶进行堵漏和堵漏压井的方法，向漏层中注入凝胶，再注入压井重泥浆，凝胶用来堵塞漏层，阻止漏失，压井重泥浆用来压井，同时由于凝胶可以抵抗压井重泥浆的压力，所以压井重泥浆不会对漏层的隔断层造成破坏，从而实堵漏压井同时作业；同理该凝胶还可以用于井漏时的堵漏。
 附图说明
为了更清楚地说明本发明的具体实施方式，下面将对具体实施方式中所需要使用的附图作简单介绍，显而易见地，下面描述中的附图是本发明的一些实施方式，对于本领域普通技术人员来讲，在不付出创造性劳动的前提下，还可以根据这些附图获得其他的附图。
图1为本发明的实施例提供的使用凝胶进行堵漏的方法流程示意图；
图2为本发明的实施例提供的使用凝胶进行堵漏压井的方法流程示意图。
 本发明的实施方式
为使本发明的目的、技术方案和优点更加清楚，下面将对本发明的技术方案进行清楚、完整的描述，基于本发明中的具体实施例，本领域普通技术人员在没有做出创造性劳动的前提下所得到的所有其它实施例，都属于本发明所保护的范围。
实施例一 凝胶
本实施例提供了一种凝胶，所述凝胶由疏水单体和非离子单体共聚而成，或由疏水单体、非离子单体和烯酸盐单体共聚而成。
实施例二 凝胶制备一
本实施例提供了共聚后水解法制备上述凝胶的方法，步骤如下：
首先按照投料比加入去离子水，加入疏水单体和非离子单体，搅拌均匀后形成一定浓度的单体溶液，并通入氮气除氧，然后将单体溶液控制到要求的聚合温度，加入引发剂进行聚合反应，经聚合一段时间后，取出胶体进行造粒，然后加入水解剂氢氧化钠或碳酸钠进行水解、再进行干燥，经粉碎和包装，即可得到凝胶样品。
所述疏水单体为烷基二甲基烯丙基氯化铵和N-烷基丙烯酰胺的一种或几种；所述非离子单体为丙烯酰胺、甲基丙烯酰胺、N-叔丁基丙烯酰胺、N-异丙基丙烯酰胺的一种或几种。
所述疏水单体和非离子单体，按照物质的量计，其加入量比例可为1-5:70-90之间的任何比例；
所述单体溶液的浓度为10-40%（即10-40g/100mL），进一步推荐为20-30%；
所述通入氮气的时间为40-120min，进一步推荐为60-100min；
所述聚合温度为5-50℃，并进一步推荐为10-30℃；
所述引发剂为氧化还原引发剂，其中氧化剂为过硫酸钾、过硫酸铵、过硫酸钠的一种或几种；还原剂为亚硫酸钠、亚硫酸氢钠、尿素、三乙醇胺的一种或几种；
所述引发剂的浓度为疏水单体、非离子单体和烯酸盐单体总质量的0.05-2%，并进一步推荐为0.1-0.5%；
所述聚合时间为6-12h，并进一步推荐为8-10h；
所述水解剂氢氧化钠或碳酸钠的加入量为疏水单体、非离子单体和烯酸盐单体总质量的5-15%，并进一步推荐为8-12%；
所述水解温度为80-110℃，水解时间为2-4h，并进一步推荐水解温度为90-95℃、水解时间2.5-3h；
所述干燥温度为80-120℃，干燥时间为1-4h，并进一步推荐干燥温度为100-110℃、干燥时间1.5-2h。
实施例三 凝胶制备二
除共聚后水解法制备凝胶外，本发明所述的凝胶还可采用共聚共水解法制备，这样就不需要进行单独的水解操作，既降低生产成本，又能节省生产周期。共聚共水解法制备凝胶的步骤包括：
首先按照投料比加入去离子水，加入疏水单体和非离子单体，搅拌均匀后形成一定浓度的单体溶液，再加入一定量的氢氧化钠或碳酸钠，并通入氮气除氧，然后将聚合体系控制到要求的聚合温度，加入引发剂进行聚合反应，经聚合一段时间后，取出胶体进行造粒，经干燥，粉碎和包装，即可得到凝胶样品。
所述疏水单体为烷基二甲基烯丙基氯化铵和N-烷基丙烯酰胺的一种或几种；所述非离子单体为丙烯酰胺、甲基丙烯酰胺、N-叔丁基丙烯酰胺、N-异丙基丙烯酰胺的一种或几种；
所述疏水单体和非离子单体，按照物质的量计，其加入量比例可为1-5:70-90之间的任何比例；
所述单体溶液的浓度为10-40%，进一步推荐为20-30%；
所述氢氧化钠或碳酸钠的加入量为疏水单体、非离子单体和烯酸盐单体总质量的5-15%，并进一步推荐为8-12%；
所述通入氮气的时间为40-120min，进一步推荐为60-100min；
所述聚合温度为5-50℃，并进一步推荐为10-30℃；
所述引发剂为氧化还原引发剂，其中氧化剂为过硫酸钾、过硫酸铵、过硫酸钠的一种或几种；还原剂为亚硫酸钠、亚硫酸氢钠、尿素、三乙醇胺的一种或几种；
所述引发剂的浓度为疏水单体、非离子单体和烯酸盐单体总质量的0.05-2%，并进一步推荐为0.1-0.5%；
所述聚合时间为6-12h，并进一步推荐为8-10h；
所述干燥温度为80-120℃，干燥时间为1-4h，并进一步推荐干燥温度为100-110℃、干燥时间1.5-2h。
实施例四 凝胶制备三
为增加凝胶的流动性，可采用疏水单体、非离子单体和烯酸盐单体共聚制备凝胶。其中采用共聚后水解法制备步骤如下：
首先按照投料比加入去离子水，加入疏水单体、非离子单体和烯酸盐单体，搅拌均匀后形成一定浓度的单体溶液，并通入氮气除氧，然后将单体溶液控制到要求的聚合温度，加入引发剂进行聚合反应，经聚合一段时间后，取出胶体进行造粒，然后加入水解剂氢氧化钠或碳酸钠进行水解、再进行干燥，经粉碎和包装，即可得到凝胶样品。
所述疏水单体为烷基二甲基烯丙基氯化铵和N-烷基丙烯酰胺的一种或几种；所述非离子单体为丙烯酰胺、甲基丙烯酰胺、N-叔丁基丙烯酰胺、N-异丙基丙烯酰胺的一种或几种；所述烯酸盐单体为甲基丙烯酸钠、乙烯基磺酸钠和丙烯酸钠的一种或几种。
所述疏水单体、非离子单体和烯酸盐单体三个物质之间的配比为：按照物质的量计，疏水单体1-5份，非离子单体70-90份，烯酸盐单体5-20份；以上三种物质可以采用其份数范围内的人以分数组成三者的配比；
所述单体溶液的浓度为10-40%，进一步推荐为20-30%；
所述通入氮气的时间为40-120min，进一步推荐为60-100min；
所述聚合温度为5-50℃，并进一步推荐为10-30℃；
所述引发剂为氧化还原引发剂，其中氧化剂为过硫酸钾、过硫酸铵、过硫酸钠的一种或几种；还原剂为亚硫酸钠、亚硫酸氢钠、尿素、三乙醇胺的一种或几种；
所述引发剂的浓度为疏水单体、非离子单体和烯酸盐单体总质量的0.05-2%，并进一步推荐为0.1-0.5%；
所述聚合时间为6-12h，并进一步推荐为8-10h；
所述水解剂氢氧化钠或碳酸钠的加入量为疏水单体、非离子单体和烯酸盐单体总质量的5-15%，并进一步推荐为8-12%；
所述水解温度为80-110℃，水解时间为2-4h，并进一步推荐水解温度为90-95℃、水解时间2.5-3h；
所述干燥温度为80-120℃，干燥时间为1-4h，并进一步推荐干燥温度为100-110℃、干燥时间1.5-2h。
实施例五 凝胶制备四
也可采用共聚共水解法制备具有优异流动性能的凝胶，步骤如下：
首先按照投料比加入去离子水，加入疏水单体、非离子单体和烯酸盐单体，搅拌均匀后形成一定浓度的单体溶液，再加入一定量的氢氧化钠或碳酸钠，并通入氮气除氧，然后将聚合体系控制到要求的聚合温度，加入引发剂进行聚合反应，经聚合一段时间后，取出胶体进行造粒，经干燥，粉碎和包装，即可得到凝胶样品。
所述疏水单体为烷基二甲基烯丙基氯化铵和N-烷基丙烯酰胺的一种或几种；所述非离子单体为丙烯酰胺、甲基丙烯酰胺、N-叔丁基丙烯酰胺、N-异丙基丙烯酰胺的一种或几种；所述烯酸盐单体为甲基丙烯酸钠、乙烯基磺酸钠和丙烯酸钠的一种或几种。
所述疏水单体、非离子单体和烯酸盐单体三个物质之间的配比为：按照物质的量计，疏水单体1-5份，非离子单体70-90份，烯酸盐单体5-20份；同样，三种物质可以采用其分数范围内的任意份数组成配比。
所述单体溶液的浓度为10-40%，进一步推荐为20-30%；
所述氢氧化钠或碳酸钠的加入量为疏水单体、非离子单体和烯酸盐单体总质量的5-15%，并进一步推荐为8-12%；
所述通入氮气的时间为40-120min，进一步推荐为60-100min；
所述聚合温度为5-50℃，并进一步推荐为10-30℃；
所述引发剂为氧化还原引发剂，其中氧化剂为过硫酸钾、过硫酸铵、过硫酸钠的一种或几种；还原剂为亚硫酸钠、亚硫酸氢钠、尿素、三乙醇胺的一种或几种；
所述引发剂的浓度为疏水单体、非离子单体和烯酸盐单体总质量的0.05-2%，并进一步推荐为0.1-0.5%；
所述聚合时间为6-12h，并进一步推荐为8-10h；
所述干燥温度为80-120℃，干燥时间为1-4h，并进一步推荐干燥温度为100-110℃、干燥时间1.5-2h。
上述方法中所用的氮气优选使用高纯氮气，效果更佳。
实施例六 凝胶堵漏方法
上述凝胶是由疏水基和碳-碳双键的单体与含碳-碳双键的非离子性单体二元共聚形成具有氢键和疏水基的大分子聚合物，该聚合物可以通过分子内氢键、分子间氢键和疏水基间范德华力等方式进行分子缔合，该缔合作用使其具有较高的粘弹性，因而可以在漏层中形成将缝隙或地层流体与压井液隔断的凝胶隔断层；并且缔合作用使得其分子间作用力很大，即内聚力较大，并且大于该聚合物与水之间的亲和力，因而其很难与水混合并被冲稀，并且在凝胶静置后，该内聚力随时间增加而增强，因此凝胶隔断层被破坏需要的压力较大，并且大于钻井液及压井液的压力，因而凝胶隔断层不会被压井液或者钻井液冲稀或冲散，由此可见，本发明提供的一种凝胶可用于井漏时的堵漏，或者井喷井漏同存时的堵漏压井。其中，高压流体层通常指压力大于40 MPa的流体层。此外，该凝胶还能与桥塞粒子、水泥等材料混合而不影响自身的特性，因而在漏失情况不严重时，也可以与其它材料混用。
可见，与现有的堵漏材料相比，本实施例提供的凝胶抗压性能高，在处置针对地层漏失裂缝较宽的井漏，以及漏层和高压气层在同一井眼的井喷井漏同存，运用该凝胶，可以缩短抢险时间、降低施工风险，同时降低了经济成本。
在实际运用中，上述凝胶中包含的两类单体可以分别选用符合条件的任意试剂，例如含疏水基和碳-碳双键的单体可以为：烷基二甲基烯丙基氯化铵和N-烷基丙烯酰胺两种中的一种或者两者组合；含碳-碳双键的非离子性单体可以为：丙烯酰胺、甲基丙烯酰胺、N-叔丁基丙烯酰胺、N-甲基丙烯酰胺四种试剂中的一种或者任意组合。
使用上述凝胶进行堵漏的方法，如图1所示，包括下列步骤：
步骤101：按重量计，向1 kg水中，边搅拌边加入8-18 g所述凝胶，得到水凝胶；
步骤102：向漏层中注入所述水凝胶；
步骤103: 向井中注入隔离液。
上述步骤101的凝胶的浓度很重要，其直接影响水凝胶的粘度，经过多次试验总结，凝胶与水中的最佳质量比为8 g:1kg -18g:1kg，此时粘度可以达到30000-60000 mPa•s，在此范围内既可以保证堵漏所需的粘度，又具有一定的可泵性。在实际运用中，可根据需要适当调节。配制时可进行搅拌，搅拌1小时观查凝胶干粉溶解形成凝胶的情况，肉眼观察凝胶内应无不溶物。待观查不到不溶物时 (淡水配制此时间一般不超过2小时)，取样测定其粘度，达到30000-60000 mPa•s即可。若粘度<30000 mPa•s，则需增加凝胶浓度直致凝胶粘度>30000 mPa•s；或者另换凝胶干粉重作试验。此时记录所用浓度作为现场配制依据; 记录所用溶解时间，现场配制时间在此时间基础上附加0.5-1.0小时，以备以后参考。同时还要对配制的凝胶进行其与压井液及水泥浆的污染实验。
步骤102注入的凝胶在漏层形成段塞（即隔断），同时也可以在高压气层或油层上形成一层隔断层，再通过步骤103加入隔离液，避免凝胶与后续的钻井液等液体互相污染。步骤102-103两步中的注入可以根据实际需要选择注入方式，例如正注、反注或者正反同注。
使用上述凝胶用于堵漏压井的方法，如图2所示，包括下列步骤：
步骤201：按重量计，向1 kg水中，边搅拌边加入8-18 g所述凝胶，得到水凝胶；
步骤202：向漏层中注入所述水凝胶；
步骤203：向井中注入隔离液；
步骤204：向井中注入压井重泥浆循环压井。
该方法是在上述堵漏方法的基础上添加了所述步骤204，最后步骤204再注入压井重泥浆循环压井，直至井内压力达到要求，即可进行正常钻井勘探或开发作业。其中，隔离液优选使用水，获取方便，成本较低。步骤202-204三步中的注入可以根据实际需要选择注入方式，例如正注、反注或者正反同注。
步骤201中可用带搅拌器的配制罐配制水凝胶，例如40 m3和35 m3罐可带两个搅拌器，60 m3罐可带3个搅拌器，且要保证所有搅拌器工作正常；凝胶配制罐必须清洗干净，除铁锈；罐上配备潜水泵或螺杆泵或砂泵；用多个配制罐时，罐间用10寸以上管线联结；需用专用水泥车或压裂车泵送 凝胶，排量宜大于4m3/min；压井用水泥车和/或压裂车，水泥车或压裂车与配制罐用6寸以上管线联结。
此外，在进行堵漏压井前，应收集该井及邻井地质、钻井资料，包括地层压力、地层破裂压力、地层漏失情况、钻井液性能、地层油气水显示、钻具结构、立压、套压、井喷类型等。同时，根据天然气产量、漏层漏失情况，漏层与气层位置、封堵压井目标、井身结构与井内管柱状况等情况确定凝胶的浓度。并且凝胶应挤入漏失地层100 m3左右 （若漏失速度过大可增加30%-50%）；同时井筒内保持装满井筒的量。通常可按100m3（井内环空有效容积的1.0-1.5倍）设计用量。而压井液密度根据关井立压、套压、当时钻井液密度计算；用量一般为环空有效容积的1.5-2倍。
步骤102和步骤202中凝胶的注入：凝胶具有高粘度和强结构特性，为确保泵注凝胶顺利，推荐供液方式：配制罐下部出水口管线直接与泵车或压裂车抽液泵的上水管连接，由泵车或压裂车从配制罐中抽出凝胶注入井中。泵送凝胶的连接管线应大于等于6寸。或者用一台或几台潜水泵（螺杆泵或砂泵）从不同的配制罐中分别或同时把凝胶倒入泵车或压裂车中，再注入井中。或者用一个4-5m3的铁罐，下部开口（一个或多个）其大小与泵车或压裂车上水管线相匹配并与之相联。使用时将此罐置于高于压裂车的铁架上用作供液过渡罐。注凝胶时用一台或几台潜水泵（螺杆泵或砂泵）从不同配制罐中分别或同时把凝胶倒入供液过渡罐中，再由泵车或压裂车注入井中。
为了更进一步说明本是发明的效果，本实施例还提供了一个试验例：
配制水凝胶：
按要求在每个配制罐中加入配制水，并按试验浓度计算好每罐水中加入凝胶干粉量(Kg)。
在每个罐中将螺杆泵（潜水泵或砂泵）装好，其出口端放置在加料口处，可实现罐内循环。
打开罐上搅拌器，同时打开螺杆泵（潜水泵或砂泵）形成罐内循环，将凝胶干粉均匀倒在螺杆泵（潜水泵或砂泵）的出口处，用此水流冲刷分散凝胶干粉使之与水均匀混合。注意控制干粉加入速度以免产生不溶团块，每罐所需加入的凝胶干粉约半小时内全部加完为宜。（也可采用其它的“聚合物溶液均匀加料的配制方法”）
加料进行过程中和完成后，保持搅拌并保持螺杆泵（潜水泵或砂泵）继续罐内循环。加料完成后搅拌时间一般为2小时（或由前述实验确定）。搅拌直致干粉全部溶解后观查并取样测定凝胶粘度，应达到试验相同结果。
凝胶配好后可立即使用,此间不可停止搅拌；若不立即压井，则可停止搅拌。配好的凝胶放置1-2天不影响其使用效果。使用前应搅拌20分钟以上，恢复凝胶的流动性后使用。
检验所配凝胶在现有设备及连接方式的情况下能否按要求供液并正常上水，排量能否达到压井方案要求。
若泵不能正常上水或排量达不到要求，则需对设备、管线、闸门以及供液上水方式进行整改直至达到要求。
试验可以用从配制罐经水泥车或压裂车再打回配制罐的短循环来进行。
施工准备：
按照压井工艺要求配制凝胶、压井液和水泥浆。
摆放和连接好水泥车或压裂车。
连接向水泥车或压裂车供压井液、供水、供胶液的管线。
按标准对管线、闸门试压。
泵注凝胶：
在搅拌情况下，凝胶在配制罐中处于流动状态，开始泵注（按压井方案要求进行正注或反注或正、反同时注入）。
泵注不能中断停止，且保证排量。泵注完成之前搅拌器不能停止。
注重泥浆压井作业：
注完凝胶再注清水1-3 m3作隔离液后，立即按封堵压井方案要求打入压井重泥浆循环压井；其压井参数(如密度、排量、压井液用量,水泥浆初凝时间…)和压井方案依井上情况而定。作业要求与高压天然气井(在压井液不漏和不被雾化情况下的)常规压井作业相同。
注水泥浆封堵或封隔作业：
注完凝胶再注清水1-3 m3作隔离液后，立即按封堵压井方案要求注入快凝水泥浆打水泥塞封住漏层或/和气层进行封堵或封隔。
根据压井方案也可在压井成功后，注入水泥浆进行封堵或封隔。
替浆后期，可降低排量继续替浆至水泥浆凝固，钻杆内憋压候凝。
利用水泥浆封堵或封隔时，必须保留压井液循环通道;水泥浆顶部必须替到漏层与气层中间合适的位置。
候凝期间，可向环空内灌注压井液。
实施例七 凝胶堵漏压井方法
针对不同情况，上述实施例制备的凝胶在钻井中的堵漏压井使用方法不同，具体如下：
第一种情况
漏层漏速不太大,漏层压力与流体层压力相差不大(如小于2 MPa)，天然气中不含H2S，则可采用如下方法：
按设计注入一定量的凝胶后, 注入隔离液，再跟进压井液建立循环，完成循环压井后再进行其它作业。
第二种情况
漏层漏速大, 漏层压力与流体层压力相差大，天然气中高含H2S；或其它地面环境复杂情况，则最好采用如下方法：
按设计注入一定量的凝胶后，注入隔离液，再跟进水泥打水泥塞直接封住气层；在注入隔离液，再用压井液建立循环，完成循环压井后再进行其它作业。根据井深、井底温度、压力、封固段位置与长度、压井重泥浆性能、压井作业时间等确定泥浆的性能和用量。所述隔离液可以采用水等。
根据井喷类型、压井工艺控制压井液和泥浆排量（若情况允许应尽量大一些）。还要注意：控制套压 小于最大允许关井套压。根据井况和压井目的确定正注或反注或正、反同时注的作业方式进行封堵压井。利用水泥浆封堵或封隔时，宜在水泥浆初凝后停止替浆。利用水泥浆封堵或封隔时，必须保留压井液循环通道; 水泥浆顶部必须替到漏层与气层中间合适的位置。施工结束后，钻具内应憋压；若环空液面较低，可向环空注入或连续灌入压井液。
为了更进一步说明该凝胶的良好堵漏压井性能，本实施例还提供了两个试验例：
试验例一
事故情况：
罗家2井是罗家寨气田的一口预探井，井深为3404 m，该井无阻流量为265×104 m3/d，测试产量63×104 m3/d。2006年3月该井在第二次完井中发生套管破裂，井底含大量H2S的天然气从罗家注水1井套管外环空经断层泄漏至地面，含H2S的天然气造成罗家2井情况十分复杂，成为罕见的压井堵漏难题：（1） 喷、漏同在一个井段。罗家2井和罗家注水1井井口中心间距为2.52 m，在垂深2180 m处井眼距为124.29 m。罗家2井和罗家注水1井都曾在钻至嘉五段时漏失各种液体上万立方米。罗家2井套管在嘉五段地层的井斜大，内壁受钻具磨损较为严重，而且罗家注水1井完钻后对该层进行了射孔和1次30 m3酸化作业。罗家2井套管发生破裂，压井液和井底气体经此破口进入漏层，喷漏在同一地层，使得压井堵漏成为一个难题。随着时间推移，气体沿着罗家注水1井套管外环空浅层断层泄漏出地面，加剧了地面情况的复杂性。（2）井底飞仙关组气层产气量极大。井底飞先关组气层无阻流量高达265×104 m3/d，套管破口以下几乎为纯气柱，无法建立液柱压力，高压气体进入破口把堵漏材料吹散成雾化并带走，使得堵漏材料很难在破口附近重新堆积。（3）漏层破碎、裂缝四通八达,为一“无底洞”。（4）漏层中含大量水。罗家2 井第二次完井作业前，测得罗家注水1 井清水液面井深为158 m ，嘉五段（238-2223 m）井底压力为19.82 MPa左右。地层中含有大量的水使得3H堵漏浆、桥塞堵漏浆、水泥浆被高压的气流吹散后无法重新聚积，被冲稀流走，无法在破口附近堆积形成结构，是前期4次堵漏不能成功的主要原因。（5）井下落鱼对堵漏极为不利。在实施下入封隔器封堵的方案时，由于钻具发生氢脆断裂，造成罗家2 井下入封隔器封堵设计方案无法继续实施。落鱼长度为525m，落鱼底端为A177.8 mm刮管器，它与套管的间隙只有几毫米,注桥塞堵漏浆在此小间隙极易造成堵死，因而采用桥塞堵漏浆堵漏方案不可行，增加了堵漏的难度。喷出的天然气高含H2S。井底的天然气H2S含量为125.53 g/m3，地面泄漏处空气中H2S含量从无逐渐增大到9.8 mg/m3。高含H2S的气体极易腐蚀钻具，时间越长，井底钻具的状况越复杂，井口越危险。
本发明的凝胶堵漏压井：
采用质量浓度为1.5%的本发明的凝胶235 m3 （大排量、大剂量），减缓流体（气体）上窜速度，降低漏失速度，增加堵漏剂的流动阻力。反注水泥浆67.5 m3，关井候凝。套压、立压均为0。罗家注水1 井放喷管口的火焰持续减小，火焰呈忽大忽小至间断熄灭的波动状态，地面泄漏点火势也明显减小，封堵基本成功。环空注凝胶185 m3，环空注水泥浆86 m3封堵飞仙关组气层，立压、套压为0。关井候凝。连续观察，罗家2 井井口压力为0，经证实已将飞仙关组气层完全切断，压井封堵抢险任务基本完成，成功地对罗家2井进行了堵漏压井作业。
试验例二
事故情况：
达州双庙1井是中国石化南方公司在川东地区的一口垂直勘探井，设计井深4373 m。钻至3573 m，裸眼井段为1622 m，而且在裸眼井段钻遇了6个漏层，其中失返型严重漏失3 处，当钻至3446-3448 m，钻遇高压气层（气层压力系数在1.71-1.88 g/cm3之间,初步测试无阻流量为60×104 m3/d）井底溢流,采用1.79-1.80 g/cm3高密度钻井液压井，由于气层压力系数在1.88 g/cm3左右，该气层地层的承压能力只有1.81 g/cm3 ,比上部地层低，在压井过程中压漏该气层。在超压作用下，气层原来的裂缝变得更宽，连通性更好，造成了失返型的严重漏失，并且形成了喷漏同层的复杂井漏情况。为了封堵漏层，保护气层，现场技术人员先后采用桥塞堵漏（最大粒径达3 cm），9次打水泥堵漏，以及桥塞和打水泥复合堵漏方法，均未见效，喷漏同存的现象未能得到控制。高压气层溢流和井漏较长时间得不到有效控制，严重威胁上部地层的井壁稳定。由于高压气层的井漏使井内环空液面下降，用于平衡上部地层的液柱压力下降，造成上部地层封堵漏失层的桥塞大量反吐，原来上部的地层又发生漏失，并且在套压较高时，还存在下部的高压气体进入上部的漏层，发生地下井喷的情况。上部漏层反吐出的桥堵材料沉积在环空井眼内，造成卡钻，在卡钻的最初阶段,转头位置可以上下活动近100 m（3573-3484 m），但是由于井眼的长时间浸泡，该地区泥页岩矿物主要以伊/蒙无序间层为主，间层中蒙皂石含量较高，其水化膨胀较严重，又由于高压气体滑脱上升对井壁的冲刷，造成部分井壁垮塌，最终钻头被卡死，卡点分别为2500m和3474m。在钻头被卡死后，先后采用多次打水泥堵漏，均未能有效控制下部高压气层的溢流和井漏。在这种情况下，井口的双闸板防喷器长期处于高压的工作状态下并且下闸板由于高压气体携带的固相颗粒的冲刷打击，发生刺穿失效，井口安全受到严重威胁，形成了高压气井多压力系统、多漏层,伴有高压气层喷漏同层和高压层向低压层的地下井喷，导致卡钻和防喷器部件刺穿的复杂井况。
本发明的凝胶堵漏压井方法：
先用压裂车向钻具正注浓度特殊凝胶4 m3，接着改用钻井泵向钻具内正注高密度钻井液34 m3，保证水眼畅通。用压裂车通过压井管汇向环空反挤高密度钻井液60 m3，排量由小至大，控制套压小于等于18 MPa，将环空中的高压流体挤回产层或漏层，观察立压、套压、套压降为零后，停止反挤，降压过程中，钻井泵持续向井场泥浆罐补充高密度钻井液。从钻具内注入特殊凝胶40 m3，因为特殊凝胶的密度只有1.01 g/cm3，为防止压差过大造成过高的施工压力，40 m3浓度1.0%的凝胶采用压裂车分为两次注入，中间夹注10m3高密度钻井液（1.95 g/cm3），注替过程中，观察泵压变化，控制泵压小于等于25 MPa 。从钻具内注入速凝水泥浆25 m3，水泥浆密度大于等于1.85 g/cm3，注入过程中，观察泵压变化，控制泵压小于25 MPa。从钻具内替注高密度钻井液33 m3。关井候凝，使凝胶形成其强度,水泥浆凝固。水泥浆侯凝24 h 后，经卸(泄)压、立压、套压，立压为0，达到封隔环空目的(封隔成功) ,隔断井底高压气层。
由此可见，本发明提供的凝胶及其制备方法及其在钻井中的堵漏压井方法，能够应对石油天然气井中复杂井漏井喷事故。
最后应说明的是：以上具体实施例仅用以说明本发明的技术方案，而非对其限制；尽管参照前述具体实施例对本发明进行了详细的说明，本领域的普通技术人员应当理解：其依然可以对前述实施方式所记载的技术方案进行修改，或者对其中部分技术特征进行等同替换；而这些修改或者替换，并不使相应技术方案的本质脱离本发明各实施方式和具体实施例技术方案的精神和范围。

Claims (11)

  1. 一种凝胶，其特征在于，所述凝胶由疏水单体和非离子单体共聚而成，或由疏水单体、非离子单体和烯酸盐单体共聚而成。
  2. 根据权利1要求所述的凝胶，其特征在于，所述凝胶的制备步骤为：首先按照投料比加入去离子水，加入疏水单体和非离子单体，或者根据凝胶流动性能要求继续加入烯酸盐单体，搅拌均匀后形成浓度为10-40%的单体溶液，并通入氮气除氧，然后将单体溶液控制到聚合温度，加入引发剂进行聚合反应，经聚合6-12h后，取出胶体进行造粒，然后加入水解剂氢氧化钠或碳酸钠进行水解，再进行干燥，经粉碎和包装，即可得到凝胶样品；
    所述疏水单体为烷基二甲基烯丙基氯化铵和N-烷基丙烯酰胺的一种或几种；所述非离子单体为丙烯酰胺、甲基丙烯酰胺、N-叔丁基丙烯酰胺、N-异丙基丙烯酰胺的一种或几种；所述烯酸盐单体为甲基丙烯酸钠、乙烯基磺酸钠和丙烯酸钠的一种或几种；
    所述疏水单体、非离子单体和烯酸盐单体三个物质之间的配比为：按照物质的量计，疏水单体1-5份，非离子单体70-90份，烯酸盐单体5-20份；
    所述通入氮气的时间为40-120min；
    所述聚合温度为5-50℃；
    所述引发剂为氧化还原引发剂，其中氧化剂为过硫酸钾、过硫酸铵、过硫酸钠的一种或几种；还原剂为亚硫酸钠、亚硫酸氢钠、尿素、三乙醇胺的一种或几种；
    所述引发剂的加入量为疏水单体、非离子单体和烯酸盐单体总质量的0.05-2%；
    所述水解剂氢氧化钠或碳酸钠的加入量为疏水单体、非离子单体和烯酸盐单体总质量的5-15%；
    所述水解温度为80-110℃，水解时间为2-4h；
    所述干燥温度为80-120℃，干燥时间为1-4h。
  3. 根据 权利2要求所述的凝胶，其特征在于，所述单体溶液的浓度为20-30%；
    所述通入氮气的时间为60-100min；
    所述聚合温度为10-30℃；所述聚合时间为8-10h；
    所述引发剂的加入量为疏水单体、非离子单体和烯酸盐单体总质量的0.1-0.5%；
    所述水解剂氢氧化钠或碳酸钠的加入量为疏水单体、非离子单体和烯酸盐单体总质量的8-12%；
    所述水解温度为90-95℃，水解时间为2.5-3h；
    所述干燥温度为100-110℃，干燥时间为1.5-2h。
  4. 根据 权利1要求所述的凝胶，其特征在于，所述凝胶的制备步骤为：按照投料比加入去离子水，加入疏水单体和非离子单体，或者根据凝胶流动性能要求继续加入烯酸盐单体，搅拌均匀后形成浓度为10-40%的单体溶液，再加入氢氧化钠或碳酸钠，并通入氮气除氧，然后将聚合体系控制到聚合温度，加入引发剂进行聚合反应，经聚合6-12h后，取出胶体进行造粒，经干燥，粉碎和包装，即可得到凝胶样品；
    所述疏水单体为烷基二甲基烯丙基氯化铵和N-烷基丙烯酰胺的一种或几种；所述非离子单体为丙烯酰胺、甲基丙烯酰胺、N-叔丁基丙烯酰胺、N-异丙基丙烯酰胺的一种或几种；所述烯酸盐单体为甲基丙烯酸钠、乙烯基磺酸钠和丙烯酸钠的一种或几种；
    所述疏水单体、非离子单体和烯酸盐单体三个物质之间的配比为：按照物质的量计，疏水单体1-5份，非离子单体70-90份，烯酸盐单体5-20份；
    所述氢氧化钠或碳酸钠的加入量为疏水单体、非离子单体和烯酸盐单体总质量的5-15%；
    所述通入氮气的时间为40-120min；
    所述聚合温度为5-50℃；
    所述引发剂为氧化还原引发剂，其中氧化剂为过硫酸钾、过硫酸铵、过硫酸钠的一种或几种；还原剂为亚硫酸钠、亚硫酸氢钠、尿素、三乙醇胺的一种或几种；
    所述引发剂的加入量为疏水单体、非离子单体和烯酸盐单体总质量的0.05-2%；
    所述干燥温度为80-120℃，干燥时间为1-4h。
  5. 根据 权利4要求所述的凝胶，其特征在于，所述单体溶液的浓度为20-30%；
    所述氢氧化钠或碳酸钠的加入量为疏水单体、非离子单体和烯酸盐单体总质量的8-12%；
    所述通入氮气的时间为60-100min；
    所述聚合温度为10-30℃；所述聚合时间为8-10h；
    所述引发剂的加入量为疏水单体、非离子单体和烯酸盐单体总质量的0.1-0.5%；
    所述干燥温度为100-110℃，干燥时间为1.5-2h。
  6. 权利要求1-5任一项所述的凝胶用于堵漏的方法，其特征在于，包括下列步骤：
    步骤A：按重量计，向1 kg水中，边搅拌边加入8-18 g所述凝胶，得到水凝胶；
    步骤B：向漏层中注入所述水凝胶；
    步骤C：向井中注入隔离液。
  7. 如权利要求6所述的凝胶用于堵漏的方法，其特征在于，所述步骤C之后还包括：
    向井中注入快凝水泥。
  8. 权利要求1-5任一项所述的凝胶用于堵漏压井的方法，其特征在于，包括下列步骤：
    步骤一：按重量计，向1 kg水中，边搅拌边加入8-18 g所述凝胶，得到水凝胶；
    步骤二：向漏层中注入所述水凝胶；
    步骤三：向井中注入隔离液；
    步骤四：向井中注入压井重泥浆循环压井。
  9. 如权利要求8所述的凝胶用于堵漏压井的方法，其特征在于，所述步骤四之后还包括：
    向井中注入快凝水泥。
  10. 如权利要求8所述的凝胶用于堵漏压井的方法，其特征在于，所述步骤二中，所述水凝胶的注入速度等于或大于4 m3/min。
  11. 如权利要求 8 所述的凝胶用于堵漏压井的方法，其特征在于，所述步骤四中所述压井重泥浆的注入量为井内环空容积的
    1.5-2 倍。
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