WO2015072317A1 - 坑井掘削用一時目止め剤 - Google Patents
坑井掘削用一時目止め剤 Download PDFInfo
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- WO2015072317A1 WO2015072317A1 PCT/JP2014/078518 JP2014078518W WO2015072317A1 WO 2015072317 A1 WO2015072317 A1 WO 2015072317A1 JP 2014078518 W JP2014078518 W JP 2014078518W WO 2015072317 A1 WO2015072317 A1 WO 2015072317A1
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- well
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- drilling
- synthetic resin
- temperature
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- 230000008025 crystallization Effects 0.000 description 1
- 125000004122 cyclic group Chemical group 0.000 description 1
- 229940022769 d- lactic acid Drugs 0.000 description 1
- 230000000593 degrading effect Effects 0.000 description 1
- 230000006866 deterioration Effects 0.000 description 1
- NJLLQSBAHIKGKF-UHFFFAOYSA-N dipotassium dioxido(oxo)titanium Chemical compound [K+].[K+].[O-][Ti]([O-])=O NJLLQSBAHIKGKF-UHFFFAOYSA-N 0.000 description 1
- SZXQTJUDPRGNJN-UHFFFAOYSA-N dipropylene glycol Chemical compound OCCCOCCCO SZXQTJUDPRGNJN-UHFFFAOYSA-N 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 238000010828 elution Methods 0.000 description 1
- 239000000839 emulsion Substances 0.000 description 1
- 238000005265 energy consumption Methods 0.000 description 1
- RTZKZFJDLAIYFH-UHFFFAOYSA-N ether Substances CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 239000010419 fine particle Substances 0.000 description 1
- 239000011737 fluorine Substances 0.000 description 1
- 229910052731 fluorine Inorganic materials 0.000 description 1
- 230000004907 flux Effects 0.000 description 1
- 238000009472 formulation Methods 0.000 description 1
- 239000001530 fumaric acid Substances 0.000 description 1
- 239000011521 glass Substances 0.000 description 1
- 239000003365 glass fiber Substances 0.000 description 1
- 235000011187 glycerol Nutrition 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 239000000665 guar gum Substances 0.000 description 1
- 229960002154 guar gum Drugs 0.000 description 1
- 235000010417 guar gum Nutrition 0.000 description 1
- 239000003721 gunpowder Substances 0.000 description 1
- RRAMGCGOFNQTLD-UHFFFAOYSA-N hexamethylene diisocyanate Chemical compound O=C=NCCCCCCN=C=O RRAMGCGOFNQTLD-UHFFFAOYSA-N 0.000 description 1
- XXMIOPMDWAUFGU-UHFFFAOYSA-N hexane-1,6-diol Chemical compound OCCCCCCO XXMIOPMDWAUFGU-UHFFFAOYSA-N 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 230000001939 inductive effect Effects 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- NLYAJNPCOHFWQQ-UHFFFAOYSA-N kaolin Chemical compound O.O.O=[Al]O[Si](=O)O[Si](=O)O[Al]=O NLYAJNPCOHFWQQ-UHFFFAOYSA-N 0.000 description 1
- 238000004898 kneading Methods 0.000 description 1
- JJTUDXZGHPGLLC-UHFFFAOYSA-N lactide Chemical compound CC1OC(=O)C(C)OC1=O JJTUDXZGHPGLLC-UHFFFAOYSA-N 0.000 description 1
- 238000002386 leaching Methods 0.000 description 1
- ZLNQQNXFFQJAID-UHFFFAOYSA-L magnesium carbonate Chemical compound [Mg+2].[O-]C([O-])=O ZLNQQNXFFQJAID-UHFFFAOYSA-L 0.000 description 1
- 239000001095 magnesium carbonate Substances 0.000 description 1
- 229910000021 magnesium carbonate Inorganic materials 0.000 description 1
- VZCYOOQTPOCHFL-UPHRSURJSA-N maleic acid Chemical compound OC(=O)\C=C/C(O)=O VZCYOOQTPOCHFL-UPHRSURJSA-N 0.000 description 1
- 239000011976 maleic acid Substances 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 230000010534 mechanism of action Effects 0.000 description 1
- 238000002844 melting Methods 0.000 description 1
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- 229910052751 metal Inorganic materials 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- VUZPPFZMUPKLLV-UHFFFAOYSA-N methane;hydrate Chemical compound C.O VUZPPFZMUPKLLV-UHFFFAOYSA-N 0.000 description 1
- LVHBHZANLOWSRM-UHFFFAOYSA-N methylenebutanedioic acid Natural products OC(=O)CC(=C)C(O)=O LVHBHZANLOWSRM-UHFFFAOYSA-N 0.000 description 1
- 150000002763 monocarboxylic acids Chemical class 0.000 description 1
- SLCVBVWXLSEKPL-UHFFFAOYSA-N neopentyl glycol Chemical compound OCC(C)(C)CO SLCVBVWXLSEKPL-UHFFFAOYSA-N 0.000 description 1
- 229910000008 nickel(II) carbonate Inorganic materials 0.000 description 1
- ZULUUIKRFGGGTL-UHFFFAOYSA-L nickel(ii) carbonate Chemical compound [Ni+2].[O-]C([O-])=O ZULUUIKRFGGGTL-UHFFFAOYSA-L 0.000 description 1
- 239000004745 nonwoven fabric Substances 0.000 description 1
- 235000014571 nuts Nutrition 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- WXZMFSXDPGVJKK-UHFFFAOYSA-N pentaerythritol Chemical compound OCC(CO)(CO)CO WXZMFSXDPGVJKK-UHFFFAOYSA-N 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 150000003014 phosphoric acid esters Chemical class 0.000 description 1
- 229920003023 plastic Polymers 0.000 description 1
- 239000004033 plastic Substances 0.000 description 1
- 239000004014 plasticizer Substances 0.000 description 1
- 229920001308 poly(aminoacid) Polymers 0.000 description 1
- 229920002454 poly(glycidyl methacrylate) polymer Polymers 0.000 description 1
- 229920002647 polyamide Polymers 0.000 description 1
- 108010064470 polyaspartate Proteins 0.000 description 1
- 229920002857 polybutadiene Polymers 0.000 description 1
- 229920001225 polyester resin Polymers 0.000 description 1
- 239000004645 polyester resin Substances 0.000 description 1
- 229920001223 polyethylene glycol Polymers 0.000 description 1
- 229920001195 polyisoprene Polymers 0.000 description 1
- 238000006116 polymerization reaction Methods 0.000 description 1
- 229920001451 polypropylene glycol Polymers 0.000 description 1
- 229920000166 polytrimethylene carbonate Polymers 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 239000010453 quartz Substances 0.000 description 1
- 230000002787 reinforcement Effects 0.000 description 1
- 238000009418 renovation Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 229910052895 riebeckite Inorganic materials 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 239000003079 shale oil Substances 0.000 description 1
- HQVNEWCFYHHQES-UHFFFAOYSA-N silicon nitride Chemical compound N12[Si]34N5[Si]62N3[Si]51N64 HQVNEWCFYHHQES-UHFFFAOYSA-N 0.000 description 1
- 229920002379 silicone rubber Polymers 0.000 description 1
- 239000004945 silicone rubber Substances 0.000 description 1
- 238000004513 sizing Methods 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- 239000003381 stabilizer Substances 0.000 description 1
- 229910001220 stainless steel Inorganic materials 0.000 description 1
- 239000010935 stainless steel Substances 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- 150000003459 sulfonic acid esters Chemical class 0.000 description 1
- 239000012756 surface treatment agent Substances 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- 229920003051 synthetic elastomer Polymers 0.000 description 1
- 239000005061 synthetic rubber Substances 0.000 description 1
- 239000000454 talc Substances 0.000 description 1
- 229910052623 talc Inorganic materials 0.000 description 1
- KKEYFWRCBNTPAC-UHFFFAOYSA-L terephthalate(2-) Chemical compound [O-]C(=O)C1=CC=C(C([O-])=O)C=C1 KKEYFWRCBNTPAC-UHFFFAOYSA-L 0.000 description 1
- 238000010998 test method Methods 0.000 description 1
- 239000010936 titanium Substances 0.000 description 1
- 229910052719 titanium Inorganic materials 0.000 description 1
- OGIDPMRJRNCKJF-UHFFFAOYSA-N titanium oxide Inorganic materials [Ti]=O OGIDPMRJRNCKJF-UHFFFAOYSA-N 0.000 description 1
- DVKJHBMWWAPEIU-UHFFFAOYSA-N toluene 2,4-diisocyanate Chemical compound CC1=CC=C(N=C=O)C=C1N=C=O DVKJHBMWWAPEIU-UHFFFAOYSA-N 0.000 description 1
- QXJQHYBHAIHNGG-UHFFFAOYSA-N trimethylolethane Chemical compound OCC(C)(CO)CO QXJQHYBHAIHNGG-UHFFFAOYSA-N 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
- 239000002759 woven fabric Substances 0.000 description 1
- 239000011787 zinc oxide Substances 0.000 description 1
- 229910000859 α-Fe Inorganic materials 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—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
- C09K8/5086—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B40/00—Processes, in general, for influencing or modifying the properties of mortars, concrete or artificial stone compositions, e.g. their setting or hardening ability
- C04B40/0092—Temporary binders, mortars or concrete, i.e. materials intended to be destroyed or removed after hardening, e.g. by acid dissolution
-
- 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
- C09K8/035—Organic additives
-
- 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
-
- 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
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
-
- 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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/003—Means for stopping loss of drilling fluid
-
- 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
- E21B33/138—Plastering the borehole wall; Injecting into the formation
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
-
- 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
- E21B33/14—Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/11—Perforators; Permeators
Definitions
- the present invention relates to a temporary sealant for well drilling used in well drilling performed to produce hydrocarbon resources such as oil or natural gas, and a well drilling method.
- Hydrocarbon resources such as petroleum (including shale oil) or natural gas (including shale gas) (hereinafter collectively referred to as “petroleum”) are porous and permeable. It has been mined and produced through wells with an underground layer (oil wells or gas wells, hereinafter sometimes collectively referred to as “wells”).
- oil wells or gas wells hereinafter sometimes collectively referred to as “wells”.
- Well laying (hereinafter sometimes referred to as “well drilling”) is performed, for example, by the following steps. That is, Drilling the borehole using a drill vertically from the ground surface and, if necessary, further horizontally, preventing collapse of the borehole and passing through the inner wall (well wall) of the borehole Casing process for preventing fluid from leaking, cementing process for finishing well wall, and production layer [geosphere that produces oil and the like. For example, a drilling process for perforation of a well wall in order to collect oil etc.
- a high pressure fluid is injected into the well wall
- the well laying is completed through various processes such as a finishing process including a fracturing process for forming and expanding a fracture.
- the renovation of wells that have already been laid is carried out through almost the same process as the laying of new wells.
- the digging waste is removed from the bottom (tip) of the wellbore and the periphery of the drill, the digging scrap is raised to the ground, the drill and its peripheral members are cooled, lubricated, and underground pressure
- mud water sometimes called "drilling fluid”
- the mud is mixed with an anti-sludge agent (lost circulation material, LCM) for preventing the well wall from escaping.
- Anti-sludge agent includes cedar bark, sugarcane fiber, fiber such as mineral fiber; limestone, marble, wood, walnut shell, cotton nut shell, corn cob, synthetic resin, etc.
- Various inorganic materials and organic materials such as granular materials; flakes such as mica pieces, resin film pieces, cellophane pieces, etc. are used.
- a closed space is sequentially formed in the borehole using a sealing member such as a flack plug or a flux leave arranged in advance, and a well is formed by a high-pressure fluid that is press-fitted into the closed space.
- Drill the well wall and further form and expand cracks sometimes using gunpowder to drill). Therefore, if high-pressure fluid escapes from the well wall, the desired fluid pressure cannot be obtained, and as a result, the desired drilling or crack cannot be formed. It is necessary to temporarily stop the well.
- Resin particles or the like may be used as the filler.
- a fracturing method is employed in which fracturing and temporary closing are sequentially repeated without using a plug or other sealing member.
- a method has been adopted in which oil or the like can be re-recovered by fracturing the different places by temporarily closing the fractured holes.
- the well treatment fluid such as mud (drilling fluid), cementing fluid, drilling fluid, fracturing fluid, or finishing fluid used in the above-described processes includes an anti-sludge agent (LCM) together with various compounding agents. ) And diverting agents, and temporary plugs that temporarily seal the well walls are blended. Furthermore, prior to the flow of these well treatment fluids into the well holes, a temporary sealing fluid containing a temporary sealant is also allowed to flow into the well holes.
- LCM anti-sludge agent
- a degradable material that decomposes after a predetermined period of time is used. By using it, recovery processing and disposal processing are not required, and cost reduction and process shortening of well drilling are attempted.
- Patent Document 1 describes an aliphatic polyester solid that is decomposed and removed in hot water to temporarily reduce the permeability of an underground production layer through which a well penetrates. Dispersed well fluid is disclosed.
- Patent Document 2 discloses a processing fluid containing degradable particles such as a degradable resin that can be at least partially decomposed in the presence of water.
- Patent Document 3 discloses a dispersion liquid for excavation assistance used in well excavation for hydrocarbon recovery at a relatively low temperature (40 to 80 ° C.).
- a fluidity control material comprising a fine solid polyglycolic acid resin having a molecular weight and a weight retention in water at a temperature of 80 ° C. is disclosed.
- US Patent Publication No. 2006/0113077 discloses a wellbore that penetrates perforations, fractures and formations by injecting a slurry containing degradable material.
- Patent Document 5 a drilling fluid having a function of preventing lost water loss, containing polyglycolic acid short fibers having a predetermined mass reduction rate in water at a temperature of 60 ° C.
- Well treatment fluids such as fracturing fluids are disclosed.
- HPHT High Pressure High High Temperature
- an HPHT region is a region where the reservoir pressure is 10,000 psi (690 atm) or higher and the temperature is 300 degrees F (149 ° C.) or higher.
- Temporary plug such as mud prevention agent (LCM) and conversion agent, which is blended with well treatment fluid such as mud (drilling fluid), cementing fluid, drilling fluid, fracturing fluid or finishing fluid
- well treatment fluid such as mud (drilling fluid), cementing fluid, drilling fluid, fracturing fluid or finishing fluid
- the polyglycolic acid short fiber described in Patent Document 5 has a mass reduction rate of 10% or more after 14 days in water at a temperature of 60 ° C.
- the drilling fluid containing this as a mudguard agent is Since it has a function of preventing lost water and mud from preventing the drilling fluid from penetrating into the formation in a well having a temperature of less than 150 ° C for at least 3 hours, it provides an excellent well treatment fluid in a relatively low temperature environment.
- An object of the present invention is to provide a temporary sealing function (“temporary sealing characteristics” suitable for use in a relatively high temperature environment such as an HPHT environment under the severe mining conditions such as deepening. It is to provide a temporary sealant for well drilling that can reduce the cost of well drilling and shorten the process.
- the synthetic resin-containing well excavation has a sealing function for a period of 40 days or less at a temperature of 93 ° C. (200 ° F.) to 204 ° C. (400 ° F.).
- a temporary sealant is provided.
- the temporary sealant for well drilling according to (1) which has a seal function for a period of 2 days to 40 days.
- the synthetic resin has a compressive strength of 20% or more with respect to the compressive strength before the start of the period after a period of 40 days or less at a temperature of 93 ° C. (200 ° F.) to 204 ° C. (400 ° F.).
- the temporary closing agent for well excavation according to the above (1) or (2) which is lowered.
- the synthetic resin has a mass reduction rate in deionized water at a temperature of 80 ° C. in a ratio of 0.001 to less than 1 with respect to the mass reduction rate of polyglycolic acid.
- Two or more well drilling sealants each contain a synthetic resin having a sealing function for a period of 40 days or less at a temperature of 93 ° C. (200 ° F.) to 204 ° C. (400 ° F.).
- (11) The temporary sealant for well excavation according to (9) or (10), wherein two or more types of sealants for well excavation contain different synthetic resins.
- a well treatment fluid containing the temporary sealant for well drilling according to any one of (1) to (15).
- the well treatment according to (16) which is at least one selected from the group consisting of drilling fluid, cementing fluid, fracturing fluid, and finishing fluid A fluid is provided.
- the following well drilling methods (19) to (21) are provided.
- the temporary closing agent for well drilling according to any one of (1) to (15) above is used in one or more of a drilling process, a drilling process, a fracturing process, or a finishing process.
- Well drilling method. (20) Eyes for a period exceeding 40 days at a temperature of 93 ° C. (200 ° F.) to 204 ° C.
- the temporary sealant for well excavation can be decomposed after performing the temporary seal using the temporary sealant for well drilling according to any one of (1) to (15).
- the temperature is 93 ° C. (200 ° F.) to 204 ° C. (400 ° F.) [hereinafter, simply referred to as “temperature 93 to 204 ° C.”. ]
- a synthetic resin-containing temporary sealant for well drilling having a sealing function for a period, and / or the contained synthetic resin has a mass reduction rate of polyglycolic acid in deionized water at a temperature of 80 ° C.
- the compressive strength is 20% or more with respect to the compressive strength before the start of the period after the elapse of a period of 40 days or less at a temperature of 93 to 204 ° C. with respect to the mass reduction rate and at a temperature of 93 to 204 ° C. Due to the above-mentioned temporary closing agent for well excavation, which is characterized by a decrease, the mining conditions such as deepening have become severe, and relatively high temperatures such as HPHT environment can be obtained. In the environment By having a temporary first stop function compatible with the use, the effect is exhibited that well drilling costs reduce or shortening the process can be well drilling the temporary first stop agent.
- the well treatment fluid containing the above-described temporary sealant for well excavation has a severe mining condition such as deepening.
- a temporary sealing function suitable for use in a high temperature environment there is an effect that a well treatment fluid capable of reducing the cost of well drilling and shortening the process is provided.
- the drilling method for performing temporary sealing using the above-described temporary sealing agent for drilling is used for severe mining conditions such as deepening. Therefore, having a temporary sealing function suitable for use in a high-temperature environment provides an effect of providing a well treatment method capable of reducing the cost of well drilling and shortening the process.
- the present invention relates to a temporary sealant for well drilling, a well treatment fluid, and a well drilling method used in well drilling performed to produce oil and the like.
- the temporary sealant for well drilling is a temporary sealant for well drilling containing a synthetic resin having a sealing function for a period of 40 days or less, often 2 days or more and 40 days or less at a temperature of 93 to 204 ° C., In particular, it is a synthetic resin-containing temporary sealant for well excavation having a sealing function for a period of 40 days or less at a temperature of 93 to 204 ° C.
- the contained synthetic resin has a temperature of 80 ° C.
- the mass reduction rate in deionized water is a ratio of 0.001 to less than 1 with respect to the mass reduction rate of polyglycolic acid, and / or at a temperature of 93 to 204 ° C. after a period of 40 days or less, Compressive strength
- the temporary sealant for well excavation described above characterized in that the compressive strength is reduced by 20% or more with respect to the compressive strength before the start. Therefore, as will be described in detail later, this is a temporary sealant for well excavation containing a degradable synthetic resin having a property of losing the seal function within a period of 40 days or less at a temperature of 93 to 204 ° C.
- the temporary sealant for well excavation of the present invention has a seal function for a period of 40 days or less at a temperature of 93 to 204 ° C., and the degradability that loses the seal function within the period. It is a temporary sealant for well excavation containing a synthetic resin.
- the period having the sealing function is often 2 days or more and 40 days or less.
- the temperature is 93 to 204 ° C. in an environment of 30 minutes to 1 hour.
- the synthetic resin-containing temporary sealing agent for well excavation according to the present invention can meet such a request.
- the temporary plug for well drilling means a process for drilling (laying a well), specifically, drilling process, cementing
- it is a material used as a compounding agent contained in the well treatment fluid for the purpose of temporarily closing the well wall.
- a formulation referred to as an anti-sludge agent (LCM) a perforated plug agent, a temporary plug agent for fracturing [diverting agent], a bridging agent (sometimes referred to as "finishing agent”).
- LCM anti-sludge agent
- a perforated plug agent a perforated plug agent
- a temporary plug agent for fracturing [diverting agent] a temporary plug agent for fracturing [diverting agent]
- a bridging agent sometimes referred to as "finishing agent”
- the temporary sealant for well drilling of the present invention is a synthetic resin-containing temporary sealant for well drilling.
- a temporary sealant such as an anti-sludge agent
- cedar bark, sugarcane fiber, fiber such as mineral fiber; limestone, marble, wood, walnut shell, cottonseed shell, corn
- inorganic materials and organic materials such as cobs, synthetic resins, etc .; mica pieces, resin film pieces, cellophane pieces, etc. were used.
- One of the features of the stopper is that it contains a synthetic resin.
- the synthetic resin is not particularly limited as long as it is a degradable resin that has a sealing function and then loses the sealing function for a desired period in a high-temperature environment, but it melts in a high-temperature environment. It is preferable not to.
- Preferred degradable synthetic resins include polyurethane, polylactic acid, aliphatic polyesters, aromatic polyesters, aliphatic polyamides, polycarbonates, and the like. What has a stop function should just be selected.
- PGA polyglycolic acid
- a synthetic resin that decreases by 20% or more with respect to the compressive strength before the start of the period is a preferable degradable synthetic resin.
- the ratio at which the compressive strength decreases is more preferably 25% or more, and further preferably 30% or more.
- the compressive strength can be obtained by measuring at a predetermined temperature (predetermined according to the purpose) within a temperature range of 93 to 204 ° C. according to JIS K7181 (ISO 604 compliant).
- the upper limit of the ratio at which the compressive strength decreases is 100%, and at a temperature of 93 to 204 ° C., before the period of 40 days elapses, the synthetic resin loses its shape due to decomposition or elution. If it is lost or disappears, or if it is impossible to measure the compressive strength, the ratio at which the compressive strength decreases is set to 100%.
- the temporary sealant for well excavation exhibits a temporary seal function in a high temperature environment of 93 to 204 ° C.
- a temperature environment lower than 93 ° C. specifically the rate of decrease in compressive strength at a temperature of 80 ° C.
- thermosetting polyurethane durometer type A hardness (based on ISO7619) 82 °.
- thermosetting PU thermosetting PU (A82)”.
- thermosetting polyurethane A composition containing 5% by mass of glycolide which is a decomposition accelerator described later in thermosetting polyurethane (A82) [hereinafter referred to as “thermosetting PU (A82) (containing 5% of glycolide)”] There is. ) And a polybutylene adipate terephthalate random copolymer (hereinafter sometimes referred to as “PBAT”), the rate of decrease in compressive strength when immersed in deionized water at a temperature of 80 ° C. for a predetermined time Table 1 shows.
- PBAT polybutylene adipate terephthalate random copolymer
- thermosetting PU (containing 5% glycolide) have a higher compressive strength of 20% or more at an elapsed time of about 1 day at a temperature of 80 ° C.
- PGA, PLA, and thermosetting PU (containing 5% glycolide) have a higher compressive strength of 20% or more at an elapsed time of about 1 day at a temperature of 80 ° C.
- a temperature of 93 to 204 ° C. for example, it is assumed that it is difficult to exert the sealing function over a period of one day or more. It can be evaluated that it is difficult to apply as a temporary sealant for well drilling.
- these synthetic resins may be applicable if there is a request to cancel the temporary sealing function in an environment of 93 to 204 ° C. for 30 minutes to 1 hour. .
- thermosetting PU (A82) and PBAT at a temperature of 80 ° C., can be said that the compressive strength only decreases below 20% even after 7 days, and can continue to exhibit the sealing function. It can be seen that even in an environment of a higher temperature of 93 to 204 ° C., it may be applicable as a temporary sealant for well excavation having a seal function for a period of 40 days or less.
- the strength (usually the compressive strength is an index) decreases due to resin degradation, molecular weight reduction, and the like.
- the strength reduction rate specifically, the compression strength reduction rate
- a part of the contact surface between the temporary sealant and the target to be sealed for example, the inner wall of a well hole
- Unable to withstand pressure compression pressure, tensile pressure, etc.
- the surface strength reduction rate is remarkably larger than the overall strength reduction rate. Therefore, even when the overall strength reduction rate does not exceed 20%, the surface which is the contact surface It is assumed that the portion cannot receive pressure and cannot maintain the eye stop.
- the synthetic resin that releases an acid as the resin is decomposed such as PGA
- the released acid causes a decrease in the viscosity of the well treatment fluid such as muddy water, and the effect of inducing the release of the seal ( The function as a gel breaker is also inferred.
- the synthetic resin contained in the temporary sealant for well drilling of the present invention has a compressive strength of 93 to 204 ° C. after a period of 40 days or less with respect to the compressive strength before the start of the period. What reduces by 20% or more is desired.
- the initial molecular weight (which is a weight average molecular weight, and may be referred to as “initial molecular weight” hereinafter. Also referred to as “initial MW”) 200,000, the initial compressive strength (hereinafter referred to as “initial strength”). ) PGA having a pressure of 146 MPa is temporarily sealed under a condition where it is immersed in deionized water at a temperature of 80 ° C. or 100 ° C. As a result, the sealing was released in 19 hours at a temperature of 80 ° C.
- Mass reduction rate of synthetic resin in deionized water at a temperature of 80 ° C. also, as an effective index for selecting a resin having a sealing function for a desired period in a high temperature environment, the mass in the deionized water at a temperature of 80 ° C. It is preferable to select a synthetic resin having a reduction rate of 0.001 or more and less than 1 with respect to the mass reduction rate of PGA.
- PGA is a synthetic resin known to have excellent degradability even in a relatively low temperature environment.
- the ratio of the mass decrease rate of the synthetic resin in water at 80 ° C. to the mass decrease rate in deionized water at a temperature of 80 ° C. hereinafter sometimes referred to as “80 ° C.
- PGA relative mass decrease rate in water
- the book has a sealing function for a period of 40 days or less, often 2 days or more and 40 days or less at a temperature of 93 to 204 ° C.
- the temporary sealing agent for well excavation containing the synthetic resin of the invention can be easily obtained.
- a temporary closing period that is suitable for a purpose, for example, a period such as 3, 5, 7, 14, 21, or 35 days.
- the mass reduction rate of the synthetic resin in deionized water at a temperature of 80 ° C. was obtained by immersing 3 g of synthetic resin of particles contained in the temporary sealant for well drilling in 50 g of deionized water at a temperature of 80 ° C. for 21 days. It is obtained by calculating the ratio of the mass of the synthetic resin after immersion to the mass of the synthetic resin before immersion, and further compared with the mass decrease rate of PGA (molecular weight 70 to 500,000) in water at 80 ° C. If the PGA relative mass reduction rate ratio of the synthetic resin is too small, the synthetic resin will not be decomposed or the strength will not be reduced even in a period exceeding 40 days at a temperature of 93 ° C. to 204 ° C.
- the PGA relative mass decrease rate ratio of the synthetic resin contained in the synthetic resin-containing temporary sealant for well drilling of the present invention is a period of time having the temporary seal function of the well drilling temporary sealant in a high temperature environment. From the viewpoint of easy adjustment, it is more preferably 0.0015 or more and 0.3 or less, further preferably 0.002 or more and 0.13 or less, and particularly preferably 0.005 or more and 0.1 or less.
- the mass of the synthetic resin contained in the temporary sealant for well drilling does not significantly decrease, as described above, the strength is reduced (compression strength is reduced by 20% or more, etc.).
- the part may collapse and the eye stop may be released.
- Such an action is a phenomenon that usually occurs in a synthetic resin that undergoes bulk decomposition, and is an action mechanism found in, for example, polyurethane and PLA.
- a temporary sealant for drilling a well containing polyurethane has been confirmed to have no polyurethane fine particles remaining after being decomposed at a high temperature and releasing the seal function as described later. There is an advantage that does not hinder the production of produced hydrocarbon resources.
- the synthetic resin in which the compression strength reduction ratio is 20% or more, preferably the synthetic resin in which the PGA relative mass reduction rate ratio is 0.001 or more and less than 1, is not particularly limited, but is polyurethane, PLA, aromatic Examples thereof include a synthetic resin containing at least one selected from the group consisting of polyester, aliphatic polyamide, and polycarbonate, and a synthetic resin containing at least one of PBAT or unsaturated polyester. The following are known as PGA relative mass reduction rate ratios of these synthetic resins.
- thermosetting polyurethane 0.35 to less than 1
- thermoplastic polyurethane 0.005 to 0.1
- PLA poly-L-lactic acid
- stereocomplex Polylactic acid 0.02 to 0.06
- polybutylene terephthalate 0.005 to 0.05 as an aromatic polyester
- nylon 66 0.002 to 0.01 as an aliphatic polyamide Yes.
- Polycarbonates having a PGA relative mass reduction rate ratio of 0.002 to 0.01 are known.
- PBAT having a PGA relative mass reduction rate ratio of 0.008 to 0.08 is known, and as an unsaturated polyester, a PGA relative mass reduction rate ratio of 0.002 to 0.05 is known.
- an unsaturated polyester derived from maleic anhydride which has a mass reduction rate of 20% or more after 40 days in water at a temperature of 100 ° C.
- These synthetic resins include those satisfying the rate of decrease in compressive strength at a temperature of 93 to 204 ° C. described above.
- the thermosetting polyurethane has a PGA relative mass reduction rate ratio that is not necessarily small, but at a temperature of 93 to 204 ° C., after a period of 40 days or less, the compression strength is less than the compression strength before the start of the period. Decrease by 20% or more.
- the synthetic resin-containing temporary sealant for well drilling of the present invention includes a synthetic resin, thermoplastic polyurethane, stereocomplex polylactic acid, It can be seen that a well-sealing agent for drilling a well containing at least one selected from the group consisting of polylactic acid containing a hydrolysis inhibitor and an aromatic polyester is more preferable.
- the synthetic resin will be further described.
- polyurethane especially thermoplastic polyurethane, has a PGA relative mass reduction rate ratio of 0.005 to 0.1.
- the synthetic resin is particularly preferable for the temporary sealant for well excavation containing the synthetic resin of the present invention.
- the thermoplastic polyurethane particularly preferably contained in the temporary sealant for well drilling containing a synthetic resin is usually a urethane bond (—NH—CO) in the molecule obtained by condensing an isocyanate compound and a compound having a hydroxyl group. -O-).
- Thermoplastic polyurethanes are broadly divided into polyester-type polyurethanes having an ester bond in the main chain and polyether-type polyurethanes having an ether bond in the main chain as compounds having a hydroxyl group, and any of them can be used. . Both cross-linked and non-cross-linked types can be used, but it is easier to control the temporary sealability and the corresponding decomposability and disintegration by adjusting the degree of cross-linking and hardness. In some cases, polyester-type polyurethane is more preferable. Further, as the thermoplastic polyurethane, either a thermoplastic polyurethane elastomer having rubber elasticity or a thermoplastic polyurethane having no rubber elasticity can be used.
- Thermoplastic polyurethane elastomers are often elastic bodies that have both the elasticity (softness) of synthetic rubber and the rigidity (hardness) of plastics. In general, they have excellent wear resistance, chemical resistance, and oil resistance, and mechanical strength. (Compressive strength etc.) is large, and is known to have high elasticity and high energy absorption, and may be suitable for the temporary sealant for well drilling of the present invention. Furthermore, the thermoplastic polyurethane elastomer maintains its sealing property for a longer period due to deformation or the like based on its rubber elasticity, and thus it may be possible to adjust the temporary sealing property more easily. As the polyurethane, thermosetting polyurethane can also be preferably used as a temporary sealant for well drilling according to the present invention, depending on the selection of materials and compositions.
- thermoplastic polyurethane tends to reduce the PGA relative mass reduction rate ratio compared to thermosetting polyurethane
- the PGA relative mass reduction rate ratio can be reduced by increasing the hardness
- the PGA relative mass reduction rate ratio can be further reduced by forming a crosslinked structure by crosslinking in the polymerization step or by adding a crosslinking agent in the processing step.
- the PGA relative mass reduction rate ratio decreases as the addition amount increases to about 10 parts by mass with respect to 100 parts by mass of the polyurethane, and the crosslinking agent exceeds 10 parts by mass.
- the PGA relative mass reduction rate ratio can be further reduced.
- the crosslinking method include a melt kneading method using a crosslinking agent such as a polyfunctional isocyanate compound, a polyfunctional amine compound, or a polyfunctional epoxy compound.
- a crosslinking agent such as a polyfunctional isocyanate compound, a polyfunctional amine compound, or a polyfunctional epoxy compound.
- examples of the polyfunctional isocyanate compound include hexamethylene diisocyanate, xylylene diisocyanate, tolylene diisocyanate, 4,4′-diphenylmethane diisocyanate, 1,5-naphthalene diisocyanate, and the like.
- polyfunctional amine compound examples include 3,3′-dichlorobenzidine, 4,4′-methylenebis-2-chloroaniline, trimethylenebis (4-aminobenzoate), and the like.
- polyfunctional epoxy compound examples include tris (2,3-epoxypropyl) isocyanurate, poly (glycidyl methacrylate), and the like.
- a polyfunctional unsaturated group-containing crosslinking agent for example, a polyfunctional (meth) acrylate monomer such as (meth) acrylate having two or more ethylenically unsaturated bonds in the molecule
- a polyfunctional unsaturated group-containing crosslinking agent for example, a polyfunctional (meth) acrylate monomer such as (meth) acrylate having two or more ethylenically unsaturated bonds in the molecule
- energy beam crosslinking such as electron beam crosslinking (usually in the range of acceleration voltage 10 to 300 kV, and often in the range of 15 to 200 kV).
- the PGA relative mass reduction rate ratio can be further reduced. Based on a combination of one or more of these aspects, a desired range of polyurethane can be obtained, for example, when the PGA relative mass loss rate ratio is in the range of 0.005 to 0.1.
- thermoplastic polyurethanes include durometer type D hardness (based on ISO7619) 74 ° lactone polyester polyurethane (crosslinked type), durometer type A hardness (based on ISO7619) 95 ° polyester type urethane rubber ( Crosslinking type), durometer type D hardness (conforms to ISO7619) 74 ° lactone type polyester urethane rubber (uncrosslinked type), durometer type A hardness (conforms to ISO7619) 85 ° polyester type urethane rubber (uncrosslinked type), etc. Can be mentioned.
- thermoplastic polyurethane for example, maintains a state in which the rate of decrease in compressive strength is low even after lapse of 7 days or more at a temperature of 93 ° C. Therefore, compared with the thermosetting polyurethane, the thermoplastic polyurethane has a higher temperature range (for example, a temperature of 120 ° C. It can be said that it is a synthetic resin that can be applied as a temporary sealant for well excavation used at 149 ° C or the like. The reason why thermoplastic polyurethane significantly improves water resistance and heat resistance over thermosetting polyurethane is not necessarily clear, but it can be presumed that hard segment aggregation or the like has an effect.
- thermoplastic polyurethane when a crosslinking agent is contained in the thermoplastic polyurethane, the period during which the compressive strength is reduced may be extended to about twice as long as when no crosslinking agent is contained [thermoplastic PU at a temperature of 120 ° C. (A85 ) Of the compression strength after 1 day and the compression strength reduction rate after 2 days of thermoplastic PU (A85) (containing 10 phr of the crosslinking agent). ].
- Stereocomplex polylactic acid, polylactic acid containing a hydrolysis inhibitor, aromatic polyester, aliphatic polyamide, and polycarbonate A synthetic resin having a PGA relative mass reduction rate ratio of 0.005 or more and 0.1 or less, It is a particularly preferable synthetic resin contained in the temporary sealant for well excavation containing the synthetic resin of the present invention. Specifically, it is known that by mixing poly-L-lactic acid and poly-D-lactic acid, the respective molecular chains are suitably meshed to form a stereocomplex, which increases heat resistance. Stereocomplex type polylactic acid and polylactic acid containing a hydrolysis inhibitor such as carbodiimide, preferably cyclic carbodiimide (an improvement in heat resistance is known).
- a hydrolysis inhibitor such as carbodiimide, preferably cyclic carbodiimide
- examples of the aromatic polyester include polybutylene terephthalate, and further examples include aromatic polyester copolymers (may be copolymers with aliphatic polyesters).
- polybutylene adipate Specifically, polybutylene adipate.
- a terephthalate random copolymer (PBAT) or the like is a particularly preferable synthetic resin (Table 4 shows the rate of decrease in compressive strength when PBAT is immersed in deionized water at a temperature of 93 ° C. or 107 ° C. for a predetermined time).
- aliphatic polyamide and polycarbonate Is mentioned. More specifically, examples of the aliphatic polyamide include nylon 4, nylon 6, nylon 66, nylon 6-66, nylon 10, and polyamino acids such as polyaspartic acid. Examples of the polycarbonate include polytrimethylene carbonate. And cyclic polycarbonate such as aliphatic polyester carbonate.
- Unsaturated polyester is one of the other preferable synthetic resins contained in the temporary sealant for well excavation containing the synthetic resin of the present invention.
- An unsaturated polyester is a resin obtained by crosslinking a vinyl group-containing polyester obtained by a condensation reaction of a polyvalent carboxylic acid having at least one unsaturated group and a polyhydric alcohol with a vinyl monomer.
- the polyvalent carboxylic acid fumaric acid, maleic acid, itaconic acid, citraconic acid, nadic acid (3,6-endomethylene tetrahydrophthalic acid) and other unsaturated dicarboxylic acids or anhydrides thereof can be used.
- the use of fumaric anhydride or maleic anhydride is preferred.
- saturated dicarboxylic acids such as terephthalic acid, isophthalic acid and sulfoisophthalic acid, or salts thereof (such as ammonium salts) and anhydrides can be used in combination.
- the polyhydric alcohol include ethylene glycol, propylene glycol, 2,3-butanediol, 1,4-butanediol, 1,5-pentanediol, 1,6-hexanediol, neopentyl glycol, 2,2,4- Alkylene glycol such as trimethyl-1,3-pentanediol, diethylene glycol, dipropylene glycol, polyethylene glycol, polypropylene glycol, polyoxyalkylene glycol such as polytetramethylene glycol, and bisphenols such as bisphenol A can be used.
- trimethylolethane, trimethylolpropane, glycerin, pentaerythritol and the like can be used in combination as trihydric or higher alcohols.
- the polyhydric alcohol is preferably ethylene glycol, propylene glycol or 2,3-butanediol.
- the vinyl monomer serving as a crosslinking agent include styrene or alkyl-substituted products thereof, unsaturated monocarboxylic acids such as methyl methacrylate, methacrylic acid, and acrylamide, or derivatives thereof, and allyl compounds such as diallyl phthalate and triallyl isocyanurate. Styrene or methyl methacrylate is preferred.
- Unsaturated polyester is a polycarboxylic acid such as an unsaturated dicarboxylic acid or an anhydride thereof, a polyhydric alcohol, and the selection of the type and content of the crosslinking agent, and the shape and size (for example, the particle size of the particles). Etc.), it is possible to adjust the sealability and decomposability in various well environments, so it is a synthetic resin with high designability to form a temporary sealant for well drilling. be able to. Unsaturated polyester may form a component insoluble in water, such as polystyrene, due to decomposition, which may remain, but polystyrene may be used to produce oil, natural gas, etc. Since it dissolves when it comes into contact with hydrocarbon resources, there is no possibility of hindering production.
- a polycarboxylic acid such as an unsaturated dicarboxylic acid or an anhydride thereof, a polyhydric alcohol, and the selection of the type and content of the crosslinking agent, and the shape and size (for
- the temporary sealant for well excavation containing the synthetic resin of the present invention contains other synthetic resins in addition to those specifically mentioned as preferred synthetic resins in addition to those described above, as long as the object of the present invention is not impaired.
- the temporary sealing agent for well excavation has a sealing function period at a temperature of 93 to 204 ° C. within a period of 40 days or less, often 2 days or more and 40 days or less. It can be adjusted as desired.
- Other synthetic resins are not particularly limited, and other types of rubber materials (for example, non-degradable rubbers such as nitrile rubber, polyisoprene, ethylene propylene rubber, butyl rubber, styrene / butadiene rubber, fluorine rubber, and silicone rubber) Material) and other types of resins.
- degradable resins such as biodegradable, hydrolyzable, and thermally decomposable can be used.
- PGA, PLA when the synthetic resin does not correspond to the synthetic resin contained in the temporary sealant for well drilling, and excluding the stereocomplex type polylactic acid
- glycolic acid / lactic acid copolymer Well-known degradable resin, or a mixture thereof.
- the period of the sealing function at a temperature of 93 to 204 ° C. is within a range of 40 days or less. It can be easily adjusted as desired.
- the content of the polyglycolic acid resin is preferably 1 to 30% by mass, more preferably 3 to 25% by mass, and further preferably 5 to 20% by mass in the synthetic resin component.
- the synthetic resin-containing temporary sealant for well drilling according to the present invention further contains various compounding agents that are usually added in the temporary sealant for well drilling as long as the object of the present invention is not impaired.
- various additives such as a reinforcing material, a stabilizer, a decomposition accelerator, or a decomposition inhibitor. These various additives can be used alone or in combination of two or more.
- examples of the reinforcing material include organic or inorganic fibrous reinforcing materials and granular or powdered reinforcing materials, and these can be used alone or in combination of two or more.
- fibrous reinforcing materials include glass fibers, carbon fibers, asbestos fibers, silica fibers, alumina fibers, zirconia fibers, boron nitride fibers, silicon nitride fibers, boron fibers, potassium titanate fibers, and the like; stainless steel, aluminum And metal fiber materials such as titanium, steel and brass; high melting point organic fiber materials such as aramid fiber, kenaf fiber, polyamide, fluororesin, polyester resin and acrylic resin; and the like.
- Granular or powdery reinforcing materials include mica, silica, talc, alumina, kaolin, calcium sulfate, calcium carbonate, titanium oxide, ferrite, clay, glass powder, zinc oxide, nickel carbonate, iron oxide, quartz powder, magnesium carbonate, Examples include barium sulfate.
- the size (diameter, length, particle size, etc.) of the reinforcing material can be appropriately selected.
- the reinforcing material may be treated with a sizing agent or a surface treatment agent as necessary.
- decomposition accelerator examples include acids or acid precursors, and from the viewpoint of not affecting the chemical structure of the synthetic resin contained in the synthetic resin-containing temporary sealant for well drilling of the present invention.
- Precursors are preferably used. Specific examples include lactones such as glycolide and lactide, and acid anhydrides [3,3 ′, 4,4′-benzophenonetetracarboxylic dianhydride (BTDA). ], Alkyl esters, sulfonic acid esters, phosphoric acid esters and the like.
- aliphatic polyesters such as PGA and PLA can also be used as decomposition accelerators when they do not correspond to the synthetic resin contained in the synthetic resin-containing temporary sealant for well drilling.
- Temporary sealing function (1) It has a sealing function for a period of 40 days or less at a temperature of 93 to 204 ° C.
- the temporary sealing agent for well excavation of the present invention has a temperature of 93 to 204 ° C.
- it is a temporary sealant for well excavation containing a synthetic resin having a seal function for a period of 2 days to 40 days. That is, the temporary sealant for well excavation of the present invention has a seal function at a temperature of 93 ° C. to 204 ° C. for a period of 40 days or less, often 2 days or more and 40 days or less. Synthetic resin-containing temporary sealant for well drilling that loses the seal function.
- the temporary sealant for well excavation of the present invention has a seal function at a temperature of 93 to 204 ° C. for a period of 40 days or less, and in many cases 2 days or more and 40 days or less. It has a temporary sealing function suitable for use in a high temperature environment.
- a synthetic resin whose compressive strength is reduced by 20% or more with respect to the compressive strength before the start of the period is contained.
- a temporary sealant for well drilling can be obtained.
- the temporary sealing function required in well drilling varies depending on the process, but from the viewpoint of process safety, for example, 30 minutes to less than 1 hour, often less than 2 days It is rare that the sealing function is unnecessary in the period, and on the other hand, it is very rare that the sealing function is required over 40 days from the viewpoint of process shortening.
- the temporary sealant for well excavation of the present invention has a seal function at a temperature of 93 to 204 ° C. for a desired period within a period of 40 days or less, and in many cases 2 days or more and 40 days or less. It is a temporary sealant that can be selected. Specifically, it is possible to easily realize a temporary closing period that conforms to a temporary closing period required according to the application, for example, a period of 3, 5, 7, 14, 21, or 35 days. it can.
- the eye stop function uses a commercially available HP-HT Filter Press (HP-HT Filter Press) tester, and a 5 mm thick SUS disk with a slit 3 mm wide and 20 mm long.
- HP-HT Filter Press HP-HT Filter Press
- the slit is filled with a temporary sealant for well drilling, and water is used as a pressure medium, and the pressure is increased to 1,000 psi (7 MPa) at a temperature of 121 ° C., and then the temperature and pressure are maintained. Then, the time until the water leaks from the slit (the temporary sealant for well drilling leaks from the opposite side of the disc-shaped disk) is measured and confirmed by being within 40 days or less.
- the temporary sealant for well excavation has a sealing function of the test apparatus described above at a temperature of 121 ° C. and a pressure of 1,000 psi (7 MPa) for a period of 40 days or less. Although it has a sealing function at 204 ° C. for a period of 40 days or less, it can be evaluated as having a temporary sealing function suitable for use in a high-temperature environment.
- the mass of the material forming the temporary sealant for well excavation (having various shapes such as pellets, powders, and fibers, and various sizes as will be described later) is the initial mass. It can be reduced by 20% or more, or the strength of the material can be lowered to the point where it cannot withstand pressure.
- the strength of the material that forms the temporary sealant for well excavation depends on the molecular weight of the synthetic resin contained, and it goes without saying that a decrease in mass occurs as the molecular weight decreases. That is, there is a general correlation between the sealing function of the temporary sealant for well drilling and the mass reduction of the synthetic resin contained in the temporary sealant. Accordingly, the synthetic resin contained in the temporary sealant of the present invention preferably has an appropriate mass reduction rate.
- the pressure is increased to 500 psi (3.5 MPa) instead of the pressure increase to 1,000 psi (7 MPa) at a temperature of 121 ° C. using water as a pressure medium.
- the well drilling temporary sealant is at a temperature of 121 ° C.
- a well drilling temporary sealant that is suitable for use in a high temperature environment can be more accurately selected.
- the temporary sealant for well excavation has a seal function of the test apparatus described above at a temperature of 121 ° C. and a pressure of 1,000 psi (7 MPa) for a period of 40 days or less.
- the above-mentioned method for example, pressure increase up to 1,000 psi or Instead of at a pressure of up to 500 psi), at one or more other temperatures in the range of 93-204 ° C., and even at pressures higher than 1,000 psi, eg 3,000, 5,000, 10 A test can also be performed to confirm the temporary seal function by increasing the pressure to a pressure such as 15,000 psi or 15,000 psi.
- the shape of the material forming the temporary sealant examples include pellets, powders or granules, fibers (short fibers, whiskers, nonwoven fabrics, woven fabrics, etc.), film pieces (cut or pulverized films, etc.) As long as it has a sealing function, it may be a porous material having small pores. Materials of various shapes and sizes can be obtained by methods known per se. In addition, different shapes and / or sizes of materials obtained from the same type of synthetic resin may be mixed and used, or different shapes and / or sizes of materials obtained from different synthetic resins may be mixed. May be used.
- the synthetic resin-containing temporary sealant for well excavation of the present invention is usually a mixture of materials having various shapes and various sizes, and the kind and physical properties (molecular weight, etc.), composition, and materials of the synthetic resin. Depending on the combination of shape and size, it should be prepared to have a sealing function for a desired period of time within a range of 40 days or less, often 2 days or more and 40 days or less at a temperature of 93 to 204 ° C. Can do.
- a relatively large-diameter well hole is formed by a pellet-like or fibrous material.
- pressure is applied to the plugged portion, and the pores of relatively small diameter between the pellet-shaped materials are pulverized or fibrous (fiber diameter and / or fiber length is A sufficient sealing function can be exhibited by plugging with a relatively small fiber material.
- the physical properties and composition of the synthetic resin contained in the temporary sealant for well drilling, the shape and / or size of the material, and the combination thereof, the size of the well hole, the situation of the formation where the well hole is laid The optimum range is selected depending on the type of synthetic resin used.
- the synthetic resin contained in the temporary sealant for well drilling is an elastomer, that is, a rubber material, the seal function can often be exhibited by deformation under pressure during well drilling. Therefore, it is preferable.
- the temporary sealant for well excavation of the present invention is a temporary sealant for well excavation containing a synthetic resin having a seal function for a period of 40 days or less at a temperature of 93 to 204 ° C.
- It may be a temporary sealant for well drilling formed from two or more well drilling sealants.
- the synthetic resin formed from two or more well drilling sealants and contained in at least one well drilling sealant has a mass reduction rate in deionized water at a temperature of 80 ° C.
- the compressive strength is 20 to the compressive strength before the start of the period after a period of 40 days or less at a temperature of 93 to 204 ° C. % Or more is preferable.
- two or more well drilling sealants are synthetic resin-containing well drilling sealants having a sealing function for a period of 40 days or less at a temperature of 93 to 204 ° C. preferable.
- a synthetic resin-containing well drilling agent having a sealing function for a period of 40 days or less at a temperature of 93 to 204 ° C. and a period of more than 40 days at a temperature of 93 to 204 ° C.
- two or more well drilling sealants contain different synthetic resins temporarily.
- a sealant may be used.
- the different synthetic resins may be the same type of synthetic resins in addition to the case where the types of the synthetic resins are different, and may be synthetic resins having different molecular weights, cross-linked structures, cross-linking degrees, copolymerization components, and the like.
- two or more well drilling sealants differ in at least one of shape or size. It may be a temporary closing agent for excavation.
- a temporary closing agent for excavation for drilling wells with the same shape but different sizes, such as combinations of well drilling agents with different shapes such as pellets, powders or fibers, fiber shapes with different fineness, pellets with different particle sizes, etc.
- Combinations of sealants, and combinations of sealants for well drilling that differ in both shape and size can be mentioned.
- two or more wells obtained by combining a pellet containing a synthetic resin having a large PGA relative mass reduction rate ratio with a powder containing a synthetic resin having a small PGA relative mass reduction rate ratio.
- the temporary sealant for well excavation formed from the sealant for excavation starts to decrease the mass or compressive strength of the pellets (containing a synthetic resin having a large PGA relative mass decrease rate ratio).
- the sealing function as a temporary sealing agent for well drilling is maintained mainly based on the sealing function of the powder-like material containing the synthetic resin having a small PGA relative mass reduction rate ratio. Can then be lost.
- the period for which the well-sealing agent for well drilling formed from the pellet-like material and the powder-like material can maintain the sealing function is used for well-digging formed from the pellet-like material.
- This is an intermediate period between the period in which the sealing agent can maintain the sealing function and the period in which the sealing agent for well excavation formed from the powdery material can maintain the sealing function. Therefore, in the temporary sealant for drilling a well formed from the pellet and powder, the sealing function is maintained by changing the mixing ratio of the pellet and powder. It is possible to adjust and control the period during which the operation can be performed. In addition, the period during which the sealing function can be maintained can be adjusted and controlled by changing the composition of one or both of the pellet-like material and the powder-like material.
- a temporary drilling agent for well excavation formed from two or more kinds of fibrous materials having different finenesses, or a first hole for well excavation formed from two or more types of powdery materials having different particle sizes. It is possible to adjust and control the period during which the sealing function can be maintained by changing the composition, mixing ratio, and the like of the stopper.
- the temporary sealant for well drilling of the present invention as described above for unsaturated polyester, the well drilling that dissolves and disappears by contacting with hydrocarbon resources produced from the well It is also possible to use a temporary sealant for well excavation that decomposes and disappears by contact with the hydrocarbon resource.
- the temporary closing agent for well drilling, the anti-sludge agent or the conversion agent used in one or more of the drilling process, cementing process, drilling process, fracturing process or finishing process of the present invention can be adjusted.
- thermoplastic polyurethane As a thermoplastic polyurethane, a pellet-shaped molded product of a lactone polyester-type polyurethane (crosslinked type and elastomer) having a durometer type D hardness of 74 ° was obtained, and this was further subjected to a rubber crusher to form a powder-shaped molded product. Got. When the pelletized product and the powdered product were mixed and tested for the sealing function described above, the sealing function of the slit continued until the 11th day, and then the sealing function was lost. Was confirmed.
- thermoplastic polyurethane For the thermoplastic polyurethane, the amount of the crosslinking agent used is increased or electron beam crosslinking is performed to obtain a thermoplastic polyurethane having a further increased degree of crosslinking, and the same sealing function test is conducted for 16 days. It can be confirmed that the sealing function of the slit continues to the eyes and then the sealing function is lost.
- thermoplastic polyurethane (polyester type polyurethane, crosslinked type): 3 to 44 days
- thermoplastic polyurethane (polyester type polyurethane, non-crosslinked type): 3 to 18 days
- aromatic polyester (polybutylene terephthalate) : 4 to 40 days
- stereocomplex type polylactic acid 3 to 11 days.
- thermoplastic polyurethane (polyester type polyurethane, crosslinked type): 6 hours to 6 days, aliphatic polyamide: 2 to 6 days, polycarbonate: 3 to 13 days, and the like.
- the unsaturated polyester had a mass reduction rate of 20% or more in about 2 days at a temperature of 149 ° C, but after 3 days at a temperature of 100 ° C, the surface cracked and became extremely brittle. It was confirmed that From these results, it is presumed that the sealing function for well drilling containing the above synthetic resin loses its sealing function after the confirmed number of days in each temperature condition. Further, a temporary sealant for well drilling that has been confirmed to have a seal function for a period of 5 to 30 days, for example, at a temperature of 121 ° C. is used at a higher temperature such as a temperature of 177 ° C. Therefore, it can be used to enable the loss of the sealing function in a shorter time.
- these mass reduction periods vary depending on, for example, the degree of cross-linking, hardness, structural difference, and the presence or absence of additives such as hydrolysis inhibitors and plasticizers for polyurethane. It is presumed that fluctuation occurred within a certain range. Further, other synthetic resins are presumed to have varied within a certain range depending on the molecular weight, structure, crystallinity, and composition with or without additives. That is, the type, physical properties and composition of the synthetic resin are selected. For example, as described above, the temperature is 93 to 204 ° C. by adjusting the degree of crosslinking and hardness, and the presence or absence of additives and the amount of additives.
- the sealing function can be controlled within a period of 40 days or less, in many cases 2 to 40 days, and depending on the use, for example, 3, 5, 7, 14, It was inferred that these synthetic resins could be selected depending on the time period that required a different temporary stop, such as 21 or 35 days.
- the temporary sealant for well excavation containing the synthetic resin of the present invention has a seal function for a period of 40 days or less in a high-temperature well environment at a temperature of 93 to 204 ° C.
- a temporary sealant for well excavation to be used in a temperature environment in a higher temperature range such as a temperature of 149 to 191 ° C. (hereinafter sometimes referred to as “high and high temperature environment”) may be required.
- a synthetic resin suitable for inclusion in a temporary sealant for well drilling used in a high-temperature environment can be evaluated and selected by the following method, for example.
- the shape is maintained after being immersed in deionized water at a temperature of 149 ° C. for 3 hours (or a mass reduction rate of 10% or less), and the shape is lost after being immersed in deionized water at a temperature of 191 ° C. for 3 hours.
- Synthetic resins that have a reduced mass for example, a mass reduction rate of 50% or more
- Table 5 shows the appearance of various synthetic resins when they are immersed in water at a temperature of 149 ° C. or 191 ° C. for 3 hours. (This is a provisional evaluation.)
- Nylon 11, Nylon 12, Nylon 66, MXD Nylon, PET (polyethylene terephthalate), etc. are synthetic resins that are suitable for inclusion in well-sealing agents for well drilling used in high-temperature environments. Can be inferred.
- a synthetic resin that dissolves immediately in water at a temperature of 191 ° C. like nylon 6 is not suitable for use as a temporary sealant for well excavation.
- PBT and PEN polyethylene naphthalate
- Aramid and PEEK are not suitable for use as a temporary sealant for well drilling because no mass reduction behavior is observed at temperatures of 149 ° C. and 191 ° C.
- PBAT and PBS polybutylene succinate
- PBAT and PBS may melt in a high and high temperature environment, and therefore often not suitable for use as a temporary sealant for well drilling in a high and high temperature environment. Inferred.
- Well treatment fluid According to the present invention, the composition containing the synthetic resin of the present invention having a sealing function for a period of 40 days or less, and in many cases 2 days or more and 40 days or less, at the temperature of 93 to 204 ° C. described above.
- a well treatment fluid containing a temporary sealant for well drilling is provided.
- the well treatment fluid is not particularly limited, and includes at least one selected from the group consisting of a drilling fluid, a cementing fluid, a fracturing fluid, and a finishing fluid.
- Well treatment fluid containing a temporary sealant for well excavation containing the synthetic resin of the present invention depending on the environment in the borehole using the well treatment fluid, particularly the temperature and pressure of the high temperature environment, Select the material by selecting the type, physical properties, composition (including additives, etc.), shape, and size of the synthetic resin contained in the temporary sealant for well drilling. A seed or combination of materials is used in the process. Therefore, in each process using the synthetic resin-containing temporary sealant for well excavation of the present invention, the well seal temporary sealant to be used may use a different material or a combination of materials.
- the concentration of the well treatment fluid of the temporary sealing agent for well excavation containing the synthetic resin of the present invention is not particularly limited, and is usually in the range of 1 to 20% by mass, often 5 to 15% by mass.
- the well treatment fluid described above of the present invention is variously added in the well treatment fluid as long as the object of the present invention is not impaired.
- the compounding agent can be contained.
- fluidity control agents such as gravel and calcium carbonate
- inorganic materials such as KCl
- anti-collapse agents such as KCl
- specific gravity adjusting agents such as alkali metal halides or alkaline earth metal halides
- organic colloid agents such as guar gum, inorganic colloids Agents (clays, etc.), dispersed anti-powder agents, surfactants, other anti-sludge agents, conversion agents, antifoaming agents, corrosion inhibitors, etc., and these are wells that use the well treatment fluid.
- it is selected and contained at an appropriate concentration to obtain a well treatment fluid.
- the synthetic resin-containing resin of the present invention having a sealing function at a temperature of 93 to 204 ° C described above has a function of 40 days or less, and in many cases 2 to 40 days.
- the synthetic resin has a mass reduction rate in deionized water at a temperature of 80 ° C. in a ratio of 0.001 to less than 1 with respect to the mass reduction rate of polyglycolic acid, and / or at a temperature of 93 to 204 ° C.
- the compressive strength is reduced by 20% or more with respect to the compressive strength before the start of the period.
- the well drilling method Provided.
- the step of using the synthetic resin-containing temporary sealant for well drilling of the present invention is not particularly limited, but according to the present invention, the drilling process, drilling process, fracturing process or finishing process is performed.
- a well excavation method using the temporary sealant for well excavation containing the synthetic resin of the present invention can be provided.
- the temporary sealing fluid containing the synthetic resin-containing temporary sealant containing the synthetic resin of the present invention is put into the wellbore. It is also possible to use a well drilling method for inflow.
- the type of synthetic resin contained in the temporary sealant for well drilling or A material is selected by selecting physical properties, composition, shape, and size, and a combination of one or more selected materials is used in the process. Therefore, as described above, in each step of using the synthetic resin-containing temporary drilling agent for well drilling according to the present invention, the well drilling temporary sealant to be used is made of different materials or combinations of materials. May be used.
- the synthetic resin-containing temporary sealant for well drilling of the present invention that is, a synthetic resin having a seal function at a temperature of 93 to 204 ° C. for a period of 40 days or less.
- a synthetic resin having a seal function at a temperature of 93 to 204 ° C. for a period of 40 days or less Various well drilling methods described above using the well-sealing agent for well drilling having a sealing function for a period exceeding 40 days at a temperature of 93 to 204 ° C. together with the temporary sealant for well drilling contained You can also In this case, at a temperature of 93 to 204 ° C., the temporary sealing agent for well excavation containing a synthetic resin having a sealing function for a period of 40 days or less loses the sealing function at a temperature of 93 to 204 ° C.
- the well drilling agent having a sealing function for a period exceeding 40 days cannot maintain the initial existence mode suitable for exhibiting the sealing function, so that the temperature of 93 to 204 is eventually obtained.
- the sealing function is lost at 40 ° C. for a period of 40 days or less.
- the temporary sealant for well drilling containing the synthetic resin of the present invention is used to temporarily seal the well, and then the temporary sealant for well drilling is used. It is also possible to use the various well drilling methods described above in which the seal is released by bringing the material into contact with a material that can be decomposed.
- a decrease in strength or mass of the temporary sealant for well drilling such as acid (may be an acid-generating substance) or alkali.
- a fluid containing a substance capable of causing a decrease examples thereof include a fluid containing a substance capable of causing a decrease.
- the present invention relates to a temporary plug for well drilling containing a synthetic resin having a sealing function at a temperature of 93 to 204 ° C. for a period of 40 days or less, often 2 days or more and 40 days or less.
- the synthetic resin-containing temporary sealant for well excavation having a sealing function for a period of 40 days or less at a temperature of 93 to 204 ° C.
- the mass reduction rate in ionic water is a ratio of 0.001 to less than 1 with respect to the mass reduction rate of polyglycolic acid, and / or compression at a temperature of 93 to 204 ° C. after a period of 40 days or less.
- the present invention is a well drilling method for performing temporary sealing using the well treatment fluid containing the above-mentioned temporary sealant for well drilling or the above-mentioned temporary sealant for well drilling.
- the mining conditions such as deepening have become harsh, and it has a temporary sealing function suitable for use in high-temperature environments, thereby reducing the cost of well drilling and shortening the process. Since a well treatment fluid or a well drilling method can be provided, industrial applicability is high.
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Abstract
Description
地表面から垂直方向及び必要により更に水平方向に、ドリルを使用して坑井孔を掘削(drill)する掘削工程、坑井孔の崩壊を防止し、坑井孔の内壁(坑井壁)を通して流体が漏洩することを防止するケーシング(casing)工程、及び、坑井壁を仕上げるセメンティング(cementing)工程、並びに、生産層〔石油等を産出する地層。例えば、シェールガス等を産出するシェール層(頁岩層)など〕に石油等を回収するために坑井壁を穿孔(perforation)する穿孔工程、穿孔内に高圧の流体を圧入して坑井壁に亀裂(fracture)を形成拡大するフラクチャリング(fracturing)工程等を含む仕上げ(completing)工程、などの諸工程を経て、坑井の敷設が完成する。なお、既に敷設された坑井の改修も、新規の坑井の敷設とほぼ同様の工程を経て実施される。
(3)合成樹脂は、温度93℃(200度F)~204℃(400度F)において、40日以下の期間の経過後に、圧縮強度が、期間開始前の圧縮強度に対して20%以上低下するものである前記(1)または(2)の坑井掘削用一時目止め剤。
(4)合成樹脂は、温度80℃の脱イオン水中における質量減少速度が、ポリグリコール酸の該質量減少速度に対して0.001以上1未満の比率である前記(1)~(3)のいずれかの坑井掘削用一時目止め剤。
(5)合成樹脂が、ポリウレタン、ポリ乳酸、芳香族ポリエステル、脂肪族ポリアミド、及びポリカーボネートからなる群より選ばれる少なくとも1種を含有する前記(3)または(4)の坑井掘削用一時目止め剤。
(6)合成樹脂が、熱可塑性ポリウレタン、ステレオコンプレックス型ポリ乳酸、加水分解抑制剤を含有するポリ乳酸及び芳香族ポリエステルからなる群より選ばれる少なくとも1種を含有する前記(3)~(5)のいずれかの坑井掘削用一時目止め剤。
(7)合成樹脂が、ポリブチレンアジペートテレフタレートランダム共重合体または不飽和ポリエステルの少なくとも一方を含有する前記(3)~(6)のいずれかの坑井掘削用一時目止め剤。
(8)合成樹脂が、ポリグリコール酸系樹脂を含有する前記(3)~(7)のいずれかの坑井掘削用一時目止め剤。
(9)2種以上の坑井掘削用目止め剤から形成される前記(1)~(8)のいずれかの坑井掘削用一時目止め剤。
(10)2種以上の坑井掘削用目止め剤が、いずれも温度93℃(200度F)~204℃(400度F)において、40日以下の期間の目止め機能を有する合成樹脂含有の坑井掘削用一時目止め剤である前記(9)の坑井掘削用一時目止め剤。
(11)2種以上の坑井掘削用目止め剤が、異なる合成樹脂を含有する前記(9)または(10)の坑井掘削用一時目止め剤。
(12)2種以上の坑井掘削用目止め剤が、形状または大きさの少なくとも一方において異なる前記(9)~(11)のいずれかの坑井掘削用一時目止め剤。
(13)坑井から産出される炭化水素資源と接触することにより、溶解または分解して消失する前記(1)~(12)のいずれかの坑井掘削用一時目止め剤。
(14)掘削工程、セメンティング工程、穿孔工程、フラクチャリング工程または仕上げ工程の1または複数の工程において使用される前記(1)~(13)のいずれかの坑井掘削用一時目止め剤。
(15)逸泥防止剤または転換剤である前記(1)~(14)のいずれかの坑井掘削用一時目止め剤。
(19)掘削工程、穿孔工程、フラクチャリング工程または仕上げ工程の1または複数の工程において前記(1)~(15)のいずれかの坑井掘削用一時目止め剤を使用する前記(18)の坑井掘削方法。
(20)前記(1)~(15)のいずれかの坑井掘削用一時目止め剤とともに、温度93℃(200度F)~204℃(400度F)において、40日を超える期間の目止め機能を有する坑井掘削用目止め剤を使用する前記(18)または(19)の坑井掘削方法。
(21)前記(1)~(15)のいずれかの坑井掘削用一時目止め剤を使用して一時目止めを行った後に、該坑井掘削用一時目止め剤を分解させることができる材料と接触させることにより目止めを解除する前記(18)~(20)のいずれかの坑井掘削方法。
本発明の第1の側面による坑井掘削用一時目止め剤は、温度93~204℃において、40日以下、多くの場合2日以上40日以下の期間の目止め機能を有する合成樹脂含有の坑井掘削用一時目止め剤、特に、温度93~204℃において、40日以下の期間の目止め機能を有する合成樹脂含有の坑井掘削用一時目止め剤であって、好ましくは、含有される合成樹脂は、温度80℃の脱イオン水中における質量減少速度がポリグリコール酸の該質量減少速度に対して0.001以上1未満の比率であり、及び/または、温度93~204℃において、40日以下の期間の経過後に、圧縮強度が、期間開始前の圧縮強度に対して20%以上低下することを特徴とする前記の坑井掘削用一時目止め剤である。したがって、後に詳述するように、温度93~204℃において、40日以下の期間内に目止め機能を喪失する性質を有する分解性合成樹脂含有の坑井掘削用一時目止め剤である。いいかえると、本発明の坑井掘削用一時目止め剤は、温度93~204℃において、40日以下の期間、目止め機能を有し、かつ、当該期間内に目止め機能を喪失する分解性合成樹脂を含有する坑井掘削用一時目止め剤である。温度93~204℃において、目止め機能を有する期間は、多くの場合2日以上40日以下であるが、例えばフラクチャリング工程によっては、温度93~204℃の環境において、30分間~1時間で一時目止め機能を解除したいという要求もあり、本発明の合成樹脂含有の坑井掘削用一時目止め剤は、そうした要求にも応えることができるものである。
本発明において、坑井掘削用一時目止め剤(temporary plug)とは、坑井掘削(坑井の敷設)の諸工程、具体的には、掘削工程、セメンティング工程、穿孔工程、フラクチャリング工程または仕上げ工程等において、坑井壁を一時的に目止めする目的で、坑井処理流体に含有される配合剤として使用される材料をいう。例えば、逸泥防止剤(LCM)、穿孔プラグ剤、フラクチャリング用一時プラグ剤〔転換剤(diverting agent)〕、ブリッジ剤(「仕上げ目止め剤」ということもある。)等と称される配合剤材料などを意味する。
本発明の坑井掘削用一時目止め剤は、合成樹脂含有の坑井掘削用一時目止め剤である。すなわち、従来、逸泥防止剤等の一時目止め剤としては、杉皮、サトウキビの繊維、鉱物繊維等の繊維状物;石灰岩、大理石、木、クルミの殻、綿の実の殻、トウモロコシの穂軸、合成樹脂等の粒状物;雲母片、樹脂フィルム片、セロファン小片等の薄片状物;など、種々の無機物質及び有機物質が使用されていたが、本発明の坑井掘削用一時目止め剤は、合成樹脂を含有することを特徴の一つとする。合成樹脂としては、高温環境において所期の期間、目止め機能を有し、次いで目止め機能を喪失するものとすることができる分解性の樹脂である限り、特に限定されないが、高温環境において溶融しないものであることが好ましい。好ましい分解性の合成樹脂としては、ポリウレタン、ポリ乳酸、脂肪族ポリエステル、芳香族ポリエステル、脂肪族ポリアミド、及びポリカーボネートなどが挙げられ、これらの合成樹脂の内から、高温環境において所期の期間、目止め機能を有するものを選択すればよい。
本発明の合成樹脂含有の坑井掘削用一時目止め剤において、前記した目止め機能を喪失するものとすることができる分解性の合成樹脂とは、i)例えば、ポリグリコール酸(以下、「PGA」ということがある。)等のように、樹脂の分子構造が分解して、二酸化炭素と水のレベルまで分解する狭義の分解性樹脂のほか、ii)樹脂の分子鎖切断等による分子量低下などによって、強度が低下して分解し、目止め機能を喪失するもの(この場合、材料の質量は減少しないこともある。)、iii)樹脂を含有する材料が、初期の形状に対して微粉・微細化することにより、水等の媒体中に分散して強度を失い、目止め機能を喪失するもの(この場合、材料の質量は減少しないこともある。)、iv)材料に含有される樹脂が、水等の媒体に溶解することにより、強度を失い、目止め機能を喪失するもの、など、を意味する。本発明の坑井掘削用一時目止め剤に含有される合成樹脂としては、温度93~204℃において、40日以下、多くの場合2日以上40日以下の期間の経過後に、圧縮強度が、期間開始前の圧縮強度に対して20%以上低下する合成樹脂が、好ましい分解性の合成樹脂である。圧縮強度が低下する比率は、より好ましくは25%以上、更に好ましくは30%以上である。圧縮強度は、JIS K7181(ISO604準拠)に従って、温度93~204℃の範囲内の所定の温度(目的に応じてあらかじめ定める温度)で測定することにより求めることができる。なお、前記の圧縮強度が低下する比率の上限は100%であり、温度93~204℃において、40日の期間が経過する前に、合成樹脂が、分解したり溶出したりして形状を失ったり消失したりする場合、または、圧縮強度の測定が不可能となる場合は、前記の圧縮強度が低下する比率を100%とする。
また、高温環境において所期の期間、目止め機能を有するものを選択する有効な指標の一つとして、温度80℃の脱イオン水中における質量減少速度が、PGAの該質量減少速度に対して0.001以上1未満の比率である合成樹脂を選択することが好ましい。PGAは、比較的低温環境においても優れた分解性を有することが知られている合成樹脂である。PGAの温度80℃の脱イオン水中における質量減少速度(以下、「80℃水中質量減少速度」ということがある。)に対する、当該合成樹脂の80℃水中質量減少速度の比率(以下、「PGA相対質量減少速度比率」ということがある。)が0.001以上1未満の比率である合成樹脂であれば、後に詳述するように、合成樹脂の物性(分子量、架橋度、結晶構造や結晶化度等)や組成、更に、形状や大きさの組み合わせを調整することによって、温度93~204℃において、40日以下、多くの場合2日以上40日以下の期間の目止め機能を有する、本発明の合成樹脂含有の坑井掘削用一時目止め剤を容易に得ることができる。また、用途に応じて必要とされる一時目止め期間、例えば、3、5、7、14、21または35日等の期間に適合する一時目止め期間の実現を容易に行うことができる。
前記の圧縮強度が低下する比率が20%以上である合成樹脂、好ましくは更にPGA相対質量減少速度比率が0.001以上1未満である合成樹脂は、特に限定されないが、ポリウレタン、PLA、芳香族ポリエステル、脂肪族ポリアミド、及びポリカーボネートからなる群より選ばれる少なくとも1種を含有する合成樹脂や、PBATまたは不飽和ポリエステルの少なくとも一方を含有する合成樹脂などが挙げられる。これらの合成樹脂のPGA相対質量減少速度比率としては、以下のものが知られている。すなわち、ポリウレタンとしては、熱硬化性ポリウレタン:0.35~1未満、熱可塑性ポリウレタン:0.005~0.1、PLAとしては、ポリ-L-乳酸:0.1~0.3、ステレオコンプレックス型ポリ乳酸:0.02~0.06、芳香族ポリエステルとしては、ポリブチレンテレフタレート:0.005~0.05、脂肪族ポリアミドとしては、ナイロン66:0.002~0.01が知られている。また、ポリカーボネートとしてはPGA相対質量減少速度比率が0.002~0.01であるものが知られている。また、PBATとしてはPGA相対質量減少速度比率が0.008~0.08であるものが知られており、不飽和ポリエステルとしては、PGA相対質量減少速度比率が0.002~0.05であり、温度100℃の水中において40日経過後の質量減少率が20%以上である無水マレイン酸由来の不飽和ポリエステルが知られている。これらの合成樹脂としては、先に説明した温度93~204℃における圧縮強度の低下の割合を充足するものが含まれる。例えば、熱硬化性ポリウレタンは、PGA相対質量減少速度比率は必ずしも小さくはないが、温度93~204℃において、40日以下の期間の経過後に、圧縮強度が、期間開始前の圧縮強度に対して20%以上低下する。
ポリウレタン、中でも熱可塑性ポリウレタンは、先に説明したように、PGA相対質量減少速度比率が0.005~0.1であることにより、一時目止め性、及び、それに対応する分解性や崩壊性の制御が容易であることから、本発明の合成樹脂含有の坑井掘削用一時目止め剤に特に好ましい合成樹脂である。合成樹脂含有の坑井掘削用一時目止め剤に特に好ましく含有される熱可塑性ポリウレタンは、通常、イソシアネート化合物と水酸基を有する化合物とを縮合して得られる、分子中にウレタン結合(-NH-CO-O-)を有するポリウレタンである。熱可塑性ポリウレタンは、水酸基を有する化合物として、その主鎖にエステル結合を有するポリエステル型ポリウレタンと、その主鎖にエーテル結合を有するポリエーテル型ポリウレタン、に大別され、そのいずれを使用することもできる。また、架橋タイプ及び未架橋タイプのいずれも使用することができるが、架橋度や硬度の調整により、一時目止め性、及び、それに対応する分解性や崩壊性の制御をすることが一層容易であることから、ポリエステル型ポリウレタンがより好ましい場合が多い。また、熱可塑性ポリウレタンとしては、ゴム弾性を有する熱可塑性ポリウレタンエラストマーとゴム弾性を有しない熱可塑性ポリウレタンのいずれも使用することができる。熱可塑性ポリウレタンエラストマーは多くの場合、合成ゴムの弾性(柔らかさ)とプラスチックの剛性(固さ)を併せ持った弾性体であり、一般に、耐摩耗性、耐薬品、耐油性に優れ、機械的強度(圧縮強度等)が大きく、かつ、高弾性でエネルギー吸収性が高いことが知られており、本発明の坑井掘削用一時目止め剤に適合することがある。さらに、熱可塑性ポリウレタンエラストマーは、そのゴム弾性に基づく変形等によって、目止め性がより長期間維持されるので、一時目止め性の調整をより容易とすることができる場合がある。また、ポリウレタンとしては、熱硬化性ポリウレタンも、その材料や組成の選択等により、本発明の坑井掘削用一時目止め剤として好ましく使用することができる。
(i)一般的に、熱可塑性ポリウレタンは、熱硬化性ポリウレタンと比較して、PGA相対質量減少速度比率を減少させやすい傾向がある、
(ii)熱可塑性ポリウレタンについては、硬度を上げることにより、PGA相対質量減少速度比率を小さくすることができる、
(iii)熱可塑性ポリウレタンについては、重合工程における架橋または加工工程での架橋剤添加等によって架橋構造を形成することにより、PGA相対質量減少速度比率を更に小さくすることができる、
(iv)架橋剤の添加量については、ポリウレタン100質量部に対して10質量部程度までは添加量の増加に応じてPGA相対質量減少速度比率が減少し、また、10質量部を超える架橋剤の添加(通常30質量部以下、多くの場合25質量部以下である。)により、PGA相対質量減少速度比率を更に減少させることができる、
(v)架橋方法としては、多官能イソシアネート化合物、多官能アミン化合物または多官能エポキシ化合物等の架橋剤を使用して溶融混練する方法などが挙げられる。例えば、多官能イソシアネート化合物としては、ヘキサメチレンジイソシアネート、キシリレンジイソシアネート、トリレンジイソシアネート、4,4’-ジフェニルメタンジイソシアネート、1,5-ナフタレンジイソシアネート等が挙げられる。多官能アミン化合物としては、3,3’-ジクロロベンジジン、4,4’-メチレンビス-2-クロロアニリン、トリメチレンビス(4-アミノベンゾアート)等が挙げられる。多官能エポキシ化合物としては、トリス(2,3-エポキシプロピル)イソシアヌレート、ポリ(メタクリル酸グリシジル)等が挙げられる。
(vi)架橋方法としてはまた、多官能の不飽和基含有架橋剤(例えば、分子内にエチレン性不飽和結合を2個以上有する(メタ)アクリレート等の多官能性(メタ)アクリレート系モノマー等が挙げられる。具体的には、エチレングリコールジ(メタ)アクリレート、プロピレングリコールジ(メタ)アクリレート、トリメチロールプロパントリ(メタ)アクリレート、ジペンタエリスリトールトリ(メタ)アクリレート、ジペンタエリスリトールヘキサ(メタ)アクリレート等が例示できる。)を使用する等して、電子線架橋(通常加速電圧10~300kVの範囲であり、多くの場合15~200kVの範囲である。)等のエネルギー線架橋をすることにより、PGA相対質量減少速度比率を更に減少させることができる。
これらの観点の1つまたは複数の組み合わせに基づき、例えばPGA相対質量減少速度比率が0.005~0.1の範囲において所望の範囲のポリウレタンを得ることができる。
PGA相対質量減少速度比率が0.005以上0.1以下である合成樹脂は、本発明の合成樹脂含有の坑井掘削用一時目止め剤に含有される特に好ましい合成樹脂である。具体的には、ポリ-L-乳酸とポリ-D-乳酸とを混合することにより、それぞれの分子鎖が好適に噛み合ってステレオコンプレックスを形成して得られ、耐熱性が高まることが知られているステレオコンプレックス型ポリ乳酸や、カルボジイミド、好ましくは環状カルボジイミド等の加水分解抑制剤を含有するポリ乳酸(耐熱性の向上が知られている。)が挙げられる。また、芳香族ポリエステルとしては、ポリブチレンテレフタレートが挙げられるが、更に、芳香族ポリエステルの共重合体(脂肪族ポリエステルとの共重合体でもよい。)も挙げられ、具体的には、ポリブチレンアジペートテレフタレートランダム共重合体(PBAT)等が特に好ましい合成樹脂である(PBATを温度93℃または107℃の脱イオン水に浸漬し所定時間経過したときの圧縮強度低下率を表4に示す。)。
不飽和ポリエステルは、本発明の合成樹脂含有の坑井掘削用一時目止め剤に含有される他の好ましい合成樹脂の一つである。不飽和ポリエステルは、少なくとも一方が不飽和基を有する多価カルボン酸と多価アルコールとの縮合反応によって得られるビニル基含有ポリエステルを、ビニル系モノマーで架橋してなる樹脂である。多価カルボン酸としては、フマル酸、マレイン酸、イタコン酸、シトラコン酸、ナジン酸(3,6-エンドメチレン・テトラヒドロフタル酸)等の不飽和ジカルボン酸またはそれらの無水物を用いることができ、無水フマル酸または無水マレイン酸の使用が好ましい。また、テレフタル酸、イソフタル酸、スルホイソフタル酸等の飽和ジカルボン酸またはそれらの塩(アンモニウム塩等)や無水物などを併用することができる。多価アルコールとしては、エチレングリコール、プロピレングリコール、2,3-ブタンジオール、1,4-ブタンジオール、1,5-ペンタンジオール、1,6-ヘキサンジオール、ネオペンチルグリコール、2,2,4-トリメチル-1,3-ペンタンジオール等のアルキレングリコール、ジエチレングリコール、ジプロピレングリコール、ポリエチレングリコール、ポリプロピレングリコール、ポリテトラメチレングリコール等のポリオキシアルキレングリコール、ビスフェノールA等のビスフェノール類などを用いることができる。また三価以上のアルコール類としてトリメチロールエタン、トリメチロールプロパン、グリセリン、ペンタエルスリトール等を併用することができる。多価アルコールとしてはエチレングリコール、プロピレングリコールまたは2,3-ブタンジオールの使用が好ましい。架橋剤となるビニルモノマーとしては、スチレンまたはそのアルキル置換体、メチルメタクリレート、メタクリル酸、アクリルアミド等の不飽和モノカルボン酸またはその誘導体、ジアリルフタレート、トリアリルイソシヌレート等のアリル化合物等が挙げられ、スチレンまたはメチルメタクリレートが好ましい。不飽和ポリエステルは、不飽和ジカルボン酸またはそれらの無水物等の多価カルボン酸、多価アルコール、及び、架橋剤の種類や含有量の選択、並びに、形状や大きさ(例えば、粒子における粒径等)の選択により、多様な坑井環境内における目止め性と分解性とを調整することができるので、坑井掘削用一時目止め剤を形成するために設計性が高い合成樹脂であるということができる。なお、不飽和ポリエステルは、分解により、ポリスチレン等の水に不溶の成分が形成され、これが残存することがあるが、ポリスチレンは、坑井掘削終了後に坑井から産出される石油や天然ガス等の炭化水素資源と接触することにより、溶解するものであるので、生産の妨げになるおそれはない。
(他の合成樹脂)
本発明の合成樹脂含有の坑井掘削用一時目止め剤には、先に好ましい合成樹脂として具体的に挙げたもののほか、本発明の目的を阻害しない範囲で、更に他の合成樹脂を含有させることができ、これにより坑井掘削用一時目止め剤が、温度93~204℃において有する目止め機能の期間を、40日以下、多くの場合2日以上40日以下の期間の範囲内において、所望により調整することができる。他の合成樹脂としては、特に限定されず、他の種類のゴム材料(例えば、ニトリルゴム、ポリイソプレン、エチレンプロピレンゴム、ブチルゴム、スチレン・ブタジエンゴム、フッ素ゴム、シリコーンゴムなどの非分解性のゴム材料など)や他の種類の樹脂を選択することができる。好ましい樹脂として、生分解性、加水分解性、熱分解性等の分解性樹脂を使用することができる。特に好ましくは、PGA、PLA(合成樹脂含有の坑井掘削用一時目止め剤に含有される合成樹脂に該当しない場合。また、ステレオコンプレックス型ポリ乳酸を除く。)、グリコール酸・乳酸共重合体等の公知の分解性樹脂、またはそれらの混合物が挙げられる。特に、ポリグリコール酸やグリコール酸・乳酸共重合体等のポリグリコール酸系樹脂を含有させることにより、温度93~204℃において有する目止め機能の期間を、40日以下の期間の範囲内において、所望により調整することが容易にできる。ポリグリコール酸系樹脂の含有量は、合成樹脂成分において、好ましくは1~30質量%、より好ましくは3~25質量%、更に好ましくは5~20質量%である。
本発明の合成樹脂含有の坑井掘削用一時目止め剤には、本発明の目的を阻害しない範囲で、坑井掘削用一時目止め剤において通常添加される種々の配合剤を更に含有させることができ、例えば、強化材、安定剤、分解促進剤または分解抑制剤等の各種の添加剤が挙げられる。これら各種の添加剤は、それぞれ単独で、または2種以上を組み合わせて使用することができる。
例えば、強化材としては、有機または無機の繊維状強化材や、粒状または粉末状強化材等が挙げられ、単独で、または2種以上を組み合わせて使用することができる。繊維状強化材としては、ガラス繊維、炭素繊維、アスベスト繊維、シリカ繊維、アルミナ繊維、ジルコニア繊維、窒化硼素繊維、窒化珪素繊維、硼素繊維、チタン酸カリ繊維等の無機繊維状物;ステンレス、アルミニウム、チタン、鋼、真鍮等の金属繊維状物;アラミド繊維、ケナフ繊維、ポリアミド、フッ素樹脂、ポリエステル樹脂、アクリル樹脂等の高融点有機質繊維状物質;などが例示される。粒状または粉末状強化材としては、マイカ、シリカ、タルク、アルミナ、カオリン、硫酸カルシウム、炭酸カルシウム、酸化チタン、フェライト、クレー、ガラス粉、酸化亜鉛、炭酸ニッケル、酸化鉄、石英粉末、炭酸マグネシウム、硫酸バリウムなどが例示される。強化材の大きさ(径及び長さや粒径等)は適宜選択することができる。強化材は、必要に応じて、集束剤または表面処理剤により処理されていてもよい。
また、分解促進剤としては、酸または酸前駆体が挙げられ、本発明の合成樹脂含有の坑井掘削用一時目止め剤に含有される合成樹脂の化学構造に影響を与えない観点から、酸前駆体が好ましく用いられる。具体的には、グリコリド、ラクチド等のラクトン類、酸無水物〔3,3’,4,4’-ベンゾフェノンテトラカルボン酸二無水物(BTDA)等が挙げられる。〕、アルキルエステル類、スルホン酸エステル類、リン酸エステル類などが挙げられる。さらに、PGAやPLA等の脂肪族ポリエステル類も、これらが合成樹脂含有の坑井掘削用一時目止め剤に含有される合成樹脂に該当しない場合には、分解促進剤として使用することができる。
(1)温度93~204℃において、40日以下の期間、目止め機能を有する
本発明の坑井掘削用一時目止め剤は、温度93~204℃において、40日以下、多くの場合2日以上40日以下の期間、目止め機能を有する、合成樹脂含有の坑井掘削用一時目止め剤である。すなわち、本発明の坑井掘削用一時目止め剤は、温度93℃~204℃において、40日以下、多くの場合2日以上40日以下の期間、目止め機能を有し、当該期間内に目止め機能を喪失する合成樹脂含有の坑井掘削用一時目止め剤である。本発明の坑井掘削用一時目止め剤は、温度93~204℃において、40日以下、多くの場合2日以上40日以下の期間、目止め機能を有し、当該期間内に目止め機能を喪失することによって、高温環境における使用に適合する一時目止め機能を有するものである。好ましくは、温度93~204℃において、40日以下の期間の経過後に、圧縮強度が、期間開始前の圧縮強度に対して20%以上低下するものである合成樹脂を含有することによって、前記の坑井掘削用一時目止め剤を得ることができる。坑井掘削において求められる一時目止め機能は、工程によって必要とされる期間が異なるが、工程の安全性等の観点から、例えば、30分間~1時間未満、多くの場合2日未満のような期間で目止め機能が不要となることは少なく、一方、工程短縮等の観点から40日を超えて目止め機能が必要であることも極めて少ない。本発明の坑井掘削用一時目止め剤は、温度93~204℃において、40日以下、多くの場合2日以上40日以下の期間の範囲内の所望の期間、目止め機能を有するように選択することが可能な一時目止め剤である。具体的には、用途に応じて必要とされる一時目止め期間、例えば、3、5、7、14、21または35日等の期間に適合する一時目止め期間の実現を容易に行うことができる。
目止め機能は、市販のHP-HTフィルタープレス(HP-HT Filter Press)試験機を使用し、幅3mm長さ20mmのスリットを設けた厚み5mmのSUS製の円盤状ディスクを用いて、該スリットに坑井掘削用一時目止め剤を充填し、水を圧力媒体として、温度121℃で、1,000psi(7MPa)まで昇圧した後、その温度と圧力を維持して、スリットから水の漏出が生じる(円盤状ディスクの反対側面から坑井掘削用一時目止め剤が漏出する)までの時間を測定し、40日以下の間であることによって確認する。すなわち、当該坑井掘削用一時目止め剤は、温度121℃において、1,000psi(7MPa)の圧力で、40日以下の期間、前記した試験装置の目止め機能を有することにより、温度93~204℃において、40日以下の期間、目止め機能を有するといえ、高温環境における使用に適合する一時目止め機能を有すると評価することができる。
本発明の温度93~204℃において、40日以下、多くの場合2日以上40日以下の期間、目止め機能を有する、合成樹脂含有の坑井掘削用一時目止め剤は、いうまでもなく固形物であって、好ましくは、温度93~204℃において、40日以下の期間の経過後に、圧縮強度が、期間開始前の圧縮強度に対して20%以上低下するものである合成樹脂、及び/または、温度80℃の脱イオン水中における上記の質量減少速度を有する合成樹脂から形成した種々の形状及び種々の大きさを有する材料の1種または複数を使用して調製することができる。一時目止め剤を形成する材料の形状としては、例えば、ペレット状、粉体状または粒体状、繊維状(短繊維、ウイスカー、不織布、編織布等)、フィルム片(フィルムを裁断または粉砕等して得られる小片)等の形状が挙げられ、また、目止め機能を有する限り、小孔を有する多孔質のものでもよい。種々の形状及び大きさの材料は、それ自体公知の方法によって得ることができる。また、同種の合成樹脂から得られた異なる形状及び/または大きさの材料を混合して使用してもよいし、異なる合成樹脂から得られた異なる形状及び/または大きさの材料を混合して使用してもよい。本発明の合成樹脂含有の坑井掘削用一時目止め剤は、通常、種々の形状及び種々の大きさを有する材料の混合物であり、合成樹脂の種類や物性(分子量等)、組成、材料の形状及び大きさの組み合わせによって、温度93~204℃において、40日以下、多くの場合2日以上40日以下の期間の範囲内において、更に所望の期間、目止め機能を有するように調製することができる。
〔熱可塑性ポリウレタンの目止め機能〕
熱可塑性ポリウレタンとして、デュロメータータイプD硬度74°のラクトン系ポリエステル型ポリウレタン(架橋タイプであり、エラストマーである。)のペレット状成形物を得て、更にこれをゴム用粉砕機にかけて粉体状成形物を得た。ペレット状成形物と粉体状成形物を混合して、先に述べた目止め機能の試験を行ったところ、11日目までスリットの目止め機能が継続し、その後目止め機能を喪失したことが確認できた。上記熱可塑性ポリウレタンについて、架橋剤の使用量を増加し、または電子線架橋を行って、更に架橋度を高めた熱可塑性ポリウレタンを得て、同様の目止め機能の試験を行うことにより、16日目までスリットの目止め機能が継続し、その後目止め機能を喪失したことが確認できる。
合成樹脂が、高温環境下において一時目止め機能を実現することができるかどうかを推認し判定する方法として、高温環境の温度条件の水中における種々の合成樹脂の質量減少を確認した。具体的には、質量減少率が20%以上となるまでの時間を確認したところ、以下のとおりであった。すなわち、温度93℃の下では、PGA:10時間~1.5日、ポリL-乳酸:3~8日、熱硬化性ポリウレタン(ポリエステル型ポリウレタン):20時間~3日であった。温度121℃の下では、熱可塑性ポリウレタン(ポリエステル型ポリウレタン、架橋タイプ):3~44日、熱可塑性ポリウレタン(ポリエステル型ポリウレタン、非架橋タイプ):3~18日、芳香族ポリエステル(ポリブチレンテレフタレート):4~40日、ステレオコンプレックス型ポリ乳酸:3~11日であった。更に温度177℃の下では、熱可塑性ポリウレタン(ポリエステル型ポリウレタン、架橋タイプ):6時間~6日、脂肪族ポリアミド:2~6日、ポリカーボネート:3~13日などであった。また、不飽和ポリエステルについては、温度149℃の下で約2日で質量減少率が20%以上となったが、温度100℃の下で3日間経過後には、表面がひび割れて極めて脆い状態になっていることが確認された。これらの結果から、上記の合成樹脂を含有する坑井掘削用一時目止め剤においては、それぞれの温度条件において、確認された日数経過後には、目止め機能が消失することが推認される。また、温度121℃の下で、例えば5~30日の期間の目止め機能を有することが確認された坑井掘削用一時目止め剤を、温度177℃等のより高い温度の下で使用することにより、更に短時間で目止め機能の喪失を可能とするように使用することもできる。なお、これらの質量減少の期間に幅があるのは、例えば、ポリウレタンについては、架橋度、硬度、構造の違い、また加水分解抑制剤や可塑剤等の添加剤の有無等の組成の如何により、ある程度の範囲内で変動が生じたものと推測される。また、その他の合成樹脂については、分子量、構造、結晶化度、更に添加剤の有無との組成の如何により、ある程度の範囲内で変動が生じたものと推測される。すなわち、合成樹脂の種類、物性や組成を選択する、例えば、先に説明したように、架橋度や硬度を調整したり、添加剤の有無や配合量を調整することにより、温度93~204℃の坑井環境において、40日以下、多くの場合2日以上40日以下の期間の範囲内で目止め機能を制御することができ、その用途に応じて、例えば3、5、7、14、21または35日など、異なる一時目止めが必要な期間に応じて、これらの合成樹脂を選択することができることが推認された。
本発明の合成樹脂含有の坑井掘削用一時目止め剤は、温度93~204℃の高温の坑井環境において、40日以下の期間の目止め機能を有する。中でも、温度149~191℃のような、より高い温度領域の温度環境(以下、「高高温度環境」ということがある。)において使用する坑井掘削用一時目止め剤が求められることもある。高高温度環境で使用する坑井掘削用一時目止め剤に含有するのに適合する合成樹脂は、例えば以下の方法によって、評価し選択することができる。すなわち、温度149℃の脱イオン水に3時間浸漬した後に形状を維持しており(または質量減少率10%以下)、温度191℃の脱イオン水に3時間浸漬した後には形状を喪失したり質量減少する(例えば、質量減少率50%以上)ような合成樹脂は、高高温度環境における一時目止め機能を有しているといえることが多い。表5に、種々の合成樹脂について、温度149℃または191℃の水に3時間浸漬したときの質量減少率(単位:%)と形状等に関する外観を、高高温度領域での適合性の評価(暫定的な評価である。)等とともに示す。
本発明によれば、先に説明した温度93~204℃において、40日以下、多くの場合2日以上40日以下の期間、目止め機能を有する、本発明の合成樹脂含有の坑井掘削用一時目止め剤を含有する坑井処理流体が提供される。坑井処理流体としては、特に限定されないが、掘削流体、セメンティング流体、フラクチャリング流体及び仕上げ流体からなる群より選ばれる少なくとも1種が挙げられる。
本発明によれば、先に説明した温度93~204℃において、40日以下、多くの場合2日以上40日以下の期間、目止め機能を有する、本発明の合成樹脂含有の坑井掘削用一時目止め剤、特に、温度93~204℃において、40日以下の期間の目止め機能を有する合成樹脂含有の坑井掘削用一時目止め剤であって、好ましくは、含有される合成樹脂は、温度80℃の脱イオン水中における質量減少速度がポリグリコール酸の該質量減少速度に対して0.001以上1未満の比率であり、及び/または、温度93~204℃において、40日以下の期間の経過後に、圧縮強度が、期間開始前の圧縮強度に対して20%以上低下することを特徴とする前記の坑井掘削用一時目止め剤を使用して一時目止めを行う坑井掘削方法が提供される。坑井掘削方法において、本発明の合成樹脂含有の坑井掘削用一時目止め剤を使用する工程は特に限定されないが、本発明によれば、掘削工程、穿孔工程、フラクチャリング工程または仕上げ工程の1または複数の工程において本発明の合成樹脂含有の坑井掘削用一時目止め剤を使用する坑井掘削方法とすることができる。さらに、本発明の合成樹脂含有の坑井掘削用一時目止め剤を含有する一時目止め用の流体を、坑井処理流体を坑井孔内に流入させるのに先立って、坑井孔内に流入させる坑井掘削方法とすることもできる。
Claims (21)
- 温度93℃(200度F)~204℃(400度F)において、40日以下の期間の目止め機能を有する合成樹脂含有の坑井掘削用一時目止め剤。
- 2日以上40日以下の期間の目止め機能を有する請求項1記載の坑井掘削用一時目止め剤。
- 合成樹脂は、温度93℃(200度F)~204℃(400度F)において、40日以下の期間の経過後に、圧縮強度が、期間開始前の圧縮強度に対して20%以上低下するものである請求項1または2記載の坑井掘削用一時目止め剤。
- 合成樹脂は、温度80℃の脱イオン水中における質量減少速度が、ポリグリコール酸の該質量減少速度に対して0.001以上1未満の比率である請求項1乃至3のいずれか1項に記載の坑井掘削用一時目止め剤。
- 合成樹脂が、ポリウレタン、ポリ乳酸、芳香族ポリエステル、脂肪族ポリアミド、及びポリカーボネートからなる群より選ばれる少なくとも1種を含有する請求項3または4記載の坑井掘削用一時目止め剤。
- 合成樹脂が、熱可塑性ポリウレタン、ステレオコンプレックス型ポリ乳酸、加水分解抑制剤を含有するポリ乳酸及び芳香族ポリエステルからなる群より選ばれる少なくとも1種を含有する請求項3乃至5のいずれか1項に記載の坑井掘削用一時目止め剤。
- 合成樹脂が、ポリブチレンアジペートテレフタレートランダム共重合体または不飽和ポリエステルの少なくとも一方を含有する請求項3乃至6のいずれか1項に記載の坑井掘削用一時目止め剤。
- 合成樹脂が、ポリグリコール酸系樹脂を含有する請求項3乃至7のいずれか1項に記載の坑井掘削用一時目止め剤。
- 2種以上の坑井掘削用目止め剤から形成される請求項1乃至8のいずれか1項に記載の坑井掘削用一時目止め剤。
- 2種以上の坑井掘削用目止め剤が、いずれも温度93℃(200度F)~204℃(400度F)において、40日以下の期間の目止め機能を有する合成樹脂含有の坑井掘削用一時目止め剤である請求項9記載の坑井掘削用一時目止め剤。
- 2種以上の坑井掘削用目止め剤が、異なる合成樹脂を含有する請求項9または10記載の坑井掘削用一時目止め剤。
- 2種以上の坑井掘削用目止め剤が、形状または大きさの少なくとも一方において異なる請求項9乃至11のいずれか1項に記載の坑井掘削用一時目止め剤。
- 坑井から産出される炭化水素資源と接触することにより、溶解または分解して消失する請求項1乃至12のいずれか1項に記載の坑井掘削用一時目止め剤。
- 掘削工程、セメンティング工程、穿孔工程、フラクチャリング工程または仕上げ工程の1または複数の工程において使用される請求項1乃至13のいずれか1項に記載の坑井掘削用一時目止め剤。
- 逸泥防止剤または転換剤である請求項1乃至14のいずれか1項に記載の坑井掘削用一時目止め剤。
- 請求項1乃至15のいずれか1項に記載の坑井掘削用一時目止め剤を含有する坑井処理流体。
- 掘削流体、セメンティング流体、フラクチャリング流体及び仕上げ流体からなる群より選ばれる少なくとも1種である請求項16記載の坑井処理流体。
- 請求項1乃至15のいずれか1項に記載の坑井掘削用一時目止め剤を使用して一時目止めを行う坑井掘削方法。
- 掘削工程、穿孔工程、フラクチャリング工程または仕上げ工程の1または複数の工程において請求項1乃至15のいずれか1項に記載の坑井掘削用一時目止め剤を使用する請求項18記載の坑井掘削方法。
- 請求項1乃至15のいずれか1項に記載の坑井掘削用一時目止め剤とともに、温度93℃(200度F)~204℃(400度F)において、40日を超える期間の目止め機能を有する坑井掘削用目止め剤を使用する請求項18または19記載の坑井掘削方法。
- 請求項1乃至15のいずれか1項に記載の坑井掘削用一時目止め剤を使用して一時目止めを行った後に、該坑井掘削用一時目止め剤を分解させることができる材料と接触させることにより目止めを解除する請求項18乃至20のいずれか1項に記載の坑井掘削方法。
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WO2018168530A1 (ja) * | 2017-03-16 | 2018-09-20 | 株式会社クレハ | 目止剤及びその利用 |
WO2018168529A1 (ja) * | 2017-03-16 | 2018-09-20 | 株式会社クレハ | 目止剤及びその利用 |
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US20160298017A1 (en) | 2016-10-13 |
CA2930362A1 (en) | 2015-05-21 |
JPWO2015072317A1 (ja) | 2017-03-16 |
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