NO20171578A1 - Method and system for preventing leakage from a well - Google Patents
Method and system for preventing leakage from a well Download PDFInfo
- Publication number
- NO20171578A1 NO20171578A1 NO20171578A NO20171578A NO20171578A1 NO 20171578 A1 NO20171578 A1 NO 20171578A1 NO 20171578 A NO20171578 A NO 20171578A NO 20171578 A NO20171578 A NO 20171578A NO 20171578 A1 NO20171578 A1 NO 20171578A1
- Authority
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- Norway
- Prior art keywords
- liquid composition
- well
- trigger means
- activation
- reaction
- Prior art date
Links
- 238000000034 method Methods 0.000 title claims description 28
- 239000000203 mixture Substances 0.000 claims description 132
- 239000007788 liquid Substances 0.000 claims description 124
- 230000004913 activation Effects 0.000 claims description 51
- 238000006243 chemical reaction Methods 0.000 claims description 44
- 239000000126 substance Substances 0.000 claims description 37
- 238000010438 heat treatment Methods 0.000 claims description 33
- 239000002861 polymer material Substances 0.000 claims description 31
- 238000007789 sealing Methods 0.000 claims description 17
- 229920005989 resin Polymers 0.000 claims description 11
- 239000011347 resin Substances 0.000 claims description 11
- 239000003112 inhibitor Substances 0.000 claims description 10
- 239000003999 initiator Substances 0.000 claims description 10
- 230000000977 initiatory effect Effects 0.000 claims description 7
- 239000008247 solid mixture Substances 0.000 claims description 7
- 230000007480 spreading Effects 0.000 claims description 5
- 238000003892 spreading Methods 0.000 claims description 5
- 230000003213 activating effect Effects 0.000 claims description 4
- 239000003822 epoxy resin Substances 0.000 claims description 4
- 239000000463 material Substances 0.000 claims description 4
- 229920000647 polyepoxide Polymers 0.000 claims description 4
- 229920002635 polyurethane Polymers 0.000 claims description 4
- 239000004814 polyurethane Substances 0.000 claims description 4
- 238000007711 solidification Methods 0.000 claims description 4
- 230000008023 solidification Effects 0.000 claims description 4
- XQUPVDVFXZDTLT-UHFFFAOYSA-N 1-[4-[[4-(2,5-dioxopyrrol-1-yl)phenyl]methyl]phenyl]pyrrole-2,5-dione Chemical compound O=C1C=CC(=O)N1C(C=C1)=CC=C1CC1=CC=C(N2C(C=CC2=O)=O)C=C1 XQUPVDVFXZDTLT-UHFFFAOYSA-N 0.000 claims description 2
- KXGFMDJXCMQABM-UHFFFAOYSA-N 2-methoxy-6-methylphenol Chemical compound [CH]OC1=CC=CC([CH])=C1O KXGFMDJXCMQABM-UHFFFAOYSA-N 0.000 claims description 2
- 229920000178 Acrylic resin Polymers 0.000 claims description 2
- 239000004925 Acrylic resin Substances 0.000 claims description 2
- 229920000877 Melamine resin Polymers 0.000 claims description 2
- 239000004640 Melamine resin Substances 0.000 claims description 2
- 229920001807 Urea-formaldehyde Polymers 0.000 claims description 2
- GZCGUPFRVQAUEE-SLPGGIOYSA-N aldehydo-D-glucose Chemical compound OC[C@@H](O)[C@@H](O)[C@H](O)[C@@H](O)C=O GZCGUPFRVQAUEE-SLPGGIOYSA-N 0.000 claims description 2
- 239000004643 cyanate ester Substances 0.000 claims description 2
- 239000007849 furan resin Substances 0.000 claims description 2
- 229920000876 geopolymer Polymers 0.000 claims description 2
- 229920001568 phenolic resin Polymers 0.000 claims description 2
- 229920003192 poly(bis maleimide) Polymers 0.000 claims description 2
- 229920000728 polyester Polymers 0.000 claims description 2
- 229920001296 polysiloxane Polymers 0.000 claims description 2
- 229920006305 unsaturated polyester Polymers 0.000 claims description 2
- 125000000391 vinyl group Chemical group [H]C([*])=C([H])[H] 0.000 claims description 2
- 229920002554 vinyl polymer Polymers 0.000 claims description 2
- 239000004568 cement Substances 0.000 description 21
- 238000012360 testing method Methods 0.000 description 21
- 238000002474 experimental method Methods 0.000 description 20
- 230000001960 triggered effect Effects 0.000 description 12
- 239000012530 fluid Substances 0.000 description 6
- 239000000523 sample Substances 0.000 description 6
- 230000004888 barrier function Effects 0.000 description 5
- 150000001875 compounds Chemical class 0.000 description 5
- 238000005553 drilling Methods 0.000 description 5
- 239000002002 slurry Substances 0.000 description 5
- 239000012528 membrane Substances 0.000 description 4
- 230000015572 biosynthetic process Effects 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- 238000005755 formation reaction Methods 0.000 description 3
- 239000000178 monomer Substances 0.000 description 3
- 210000002445 nipple Anatomy 0.000 description 3
- 238000006116 polymerization reaction Methods 0.000 description 3
- 239000003566 sealing material Substances 0.000 description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 3
- AZQWKYJCGOJGHM-UHFFFAOYSA-N 1,4-benzoquinone Chemical compound O=C1C=CC(=O)C=C1 AZQWKYJCGOJGHM-UHFFFAOYSA-N 0.000 description 2
- 241000251468 Actinopterygii Species 0.000 description 2
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 description 2
- CPLXHLVBOLITMK-UHFFFAOYSA-N Magnesium oxide Chemical compound [Mg]=O CPLXHLVBOLITMK-UHFFFAOYSA-N 0.000 description 2
- 239000000654 additive Substances 0.000 description 2
- 150000001491 aromatic compounds Chemical class 0.000 description 2
- 230000001419 dependent effect Effects 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- 239000000945 filler Substances 0.000 description 2
- AMWRITDGCCNYAT-UHFFFAOYSA-L hydroxy(oxo)manganese;manganese Chemical compound [Mn].O[Mn]=O.O[Mn]=O AMWRITDGCCNYAT-UHFFFAOYSA-L 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 239000004848 polyfunctional curative Substances 0.000 description 2
- 229920000642 polymer Polymers 0.000 description 2
- 239000011414 polymer cement Substances 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- KRDXTHSSNCTAGY-UHFFFAOYSA-N 2-cyclohexylpyrrolidine Chemical compound C1CCNC1C1CCCCC1 KRDXTHSSNCTAGY-UHFFFAOYSA-N 0.000 description 1
- OMPJBNCRMGITSC-UHFFFAOYSA-N Benzoylperoxide Chemical compound C=1C=CC=CC=1C(=O)OOC(=O)C1=CC=CC=C1 OMPJBNCRMGITSC-UHFFFAOYSA-N 0.000 description 1
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- PHOQVHQSTUBQQK-SQOUGZDYSA-N D-glucono-1,5-lactone Chemical compound OC[C@H]1OC(=O)[C@H](O)[C@@H](O)[C@@H]1O PHOQVHQSTUBQQK-SQOUGZDYSA-N 0.000 description 1
- FEWJPZIEWOKRBE-JCYAYHJZSA-N Dextrotartaric acid Chemical compound OC(=O)[C@H](O)[C@@H](O)C(O)=O FEWJPZIEWOKRBE-JCYAYHJZSA-N 0.000 description 1
- 229920001732 Lignosulfonate Polymers 0.000 description 1
- 229920001730 Moisture cure polyurethane Polymers 0.000 description 1
- 239000011398 Portland cement Substances 0.000 description 1
- CZMRCDWAGMRECN-UGDNZRGBSA-N Sucrose Chemical compound O[C@H]1[C@H](O)[C@@H](CO)O[C@@]1(CO)O[C@@H]1[C@H](O)[C@@H](O)[C@H](O)[C@@H](CO)O1 CZMRCDWAGMRECN-UGDNZRGBSA-N 0.000 description 1
- 229930006000 Sucrose Natural products 0.000 description 1
- FEWJPZIEWOKRBE-UHFFFAOYSA-N Tartaric acid Natural products [H+].[H+].[O-]C(=O)C(O)C(O)C([O-])=O FEWJPZIEWOKRBE-UHFFFAOYSA-N 0.000 description 1
- 230000001133 acceleration Effects 0.000 description 1
- 230000000996 additive effect Effects 0.000 description 1
- 150000004645 aluminates Chemical class 0.000 description 1
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 description 1
- 150000001408 amides Chemical class 0.000 description 1
- 150000001412 amines Chemical class 0.000 description 1
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 description 1
- 239000010428 baryte Substances 0.000 description 1
- 229910052601 baryte Inorganic materials 0.000 description 1
- 239000011324 bead Substances 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 235000019400 benzoyl peroxide Nutrition 0.000 description 1
- 229910000019 calcium carbonate Inorganic materials 0.000 description 1
- 229920005551 calcium lignosulfonate Polymers 0.000 description 1
- RYAGRZNBULDMBW-UHFFFAOYSA-L calcium;3-(2-hydroxy-3-methoxyphenyl)-2-[2-methoxy-4-(3-sulfonatopropyl)phenoxy]propane-1-sulfonate Chemical group [Ca+2].COC1=CC=CC(CC(CS([O-])(=O)=O)OC=2C(=CC(CCCS([O-])(=O)=O)=CC=2)OC)=C1O RYAGRZNBULDMBW-UHFFFAOYSA-L 0.000 description 1
- 150000004649 carbonic acid derivatives Chemical class 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 150000003841 chloride salts Chemical class 0.000 description 1
- -1 clays Substances 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 230000021615 conjugation Effects 0.000 description 1
- 239000002270 dispersing agent Substances 0.000 description 1
- 239000010881 fly ash Substances 0.000 description 1
- 239000011521 glass Substances 0.000 description 1
- 229910052602 gypsum Inorganic materials 0.000 description 1
- 239000010440 gypsum Substances 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 230000002706 hydrostatic effect Effects 0.000 description 1
- 150000004679 hydroxides Chemical class 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 229910001853 inorganic hydroxide Inorganic materials 0.000 description 1
- 239000000395 magnesium oxide Substances 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- GYVGXEWAOAAJEU-UHFFFAOYSA-N n,n,4-trimethylaniline Chemical compound CN(C)C1=CC=C(C)C=C1 GYVGXEWAOAAJEU-UHFFFAOYSA-N 0.000 description 1
- 150000002823 nitrates Chemical class 0.000 description 1
- 150000002826 nitrites Chemical class 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 230000037361 pathway Effects 0.000 description 1
- 150000002978 peroxides Chemical class 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 235000011007 phosphoric acid Nutrition 0.000 description 1
- 150000003016 phosphoric acids Chemical class 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 230000036632 reaction speed Effects 0.000 description 1
- 239000011342 resin composition Substances 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 150000004760 silicates Chemical class 0.000 description 1
- 239000002893 slag Substances 0.000 description 1
- 239000005720 sucrose Substances 0.000 description 1
- 150000003467 sulfuric acid derivatives Chemical class 0.000 description 1
- 235000002906 tartaric acid Nutrition 0.000 description 1
- 239000011975 tartaric acid Substances 0.000 description 1
- GJBRNHKUVLOCEB-UHFFFAOYSA-N tert-butyl benzenecarboperoxoate Chemical compound CC(C)(C)OOC(=O)C1=CC=CC=C1 GJBRNHKUVLOCEB-UHFFFAOYSA-N 0.000 description 1
- 150000004764 thiosulfuric acid derivatives Chemical class 0.000 description 1
- 239000012745 toughening agent Substances 0.000 description 1
- 150000003623 transition metal compounds Chemical class 0.000 description 1
- 239000004034 viscosity adjusting agent Substances 0.000 description 1
Classifications
-
- 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
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
- C04B28/006—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing mineral polymers, e.g. geopolymers of the Davidovits type
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
- C04B28/006—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing mineral polymers, e.g. geopolymers of the Davidovits type
- C04B28/008—Mineral polymers other than those of the Davidovits type, e.g. from a reaction mixture containing waterglass
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
- C04B28/02—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- 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
- C04B40/06—Inhibiting the setting, e.g. mortars of the deferred action type containing water in breakable containers ; Inhibiting the action of active ingredients
- C04B40/0691—Thermally activated mortars, e.g. by melting ingredients
-
- 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
-
- 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
- C09K8/56—Compositions for consolidating loose sand or the like around wells without excessively decreasing the permeability thereof
-
- 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
- C09K8/56—Compositions for consolidating loose sand or the like around wells without excessively decreasing the permeability thereof
- C09K8/57—Compositions based on water or polar solvents
- C09K8/575—Compositions based on water or polar solvents containing organic compounds
- C09K8/5751—Macromolecular compounds
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P20/00—Technologies relating to chemical industry
- Y02P20/141—Feedstock
Landscapes
- Chemical & Material Sciences (AREA)
- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Ceramic Engineering (AREA)
- Organic Chemistry (AREA)
- Materials Engineering (AREA)
- Structural Engineering (AREA)
- Geology (AREA)
- Geochemistry & Mineralogy (AREA)
- Environmental & Geological Engineering (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Inorganic Chemistry (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Fluid Mechanics (AREA)
- Electrical Discharge Machining, Electrochemical Machining, And Combined Machining (AREA)
- Diaphragms For Electromechanical Transducers (AREA)
- Lift-Guide Devices, And Elevator Ropes And Cables (AREA)
Description
METHOD AND SYSTEM FOR PREVENTING LEAKAGE FROM A WELL
The invention concerns a liquid composition, a method of gradual solidification of said liquid composition, as well as a sealing system and a method of preventing leakage in a well.
Prior art
During the lifetime of a petroleum well, there are several situations which may occur where leakage from the well must be stopped or prevented.
One example is during drilling of the well, when lost-circulation may occur. Drilling fluid then flows into one or more geological formations instead of returning up the annulus. Lost-circulation may cause serious problems during drilling. In the case of severe losses, a sealing material is necessary to be introduced to the loss-zone to stop losses and to allow drilling to continue.
Another example is during cementing of the well. At this stage, a well barrier material is necessary to be placed in the annulus between the casing/liner and the formation to prevent fluid communication and additionally to anchor and support the casing.
Even another example is at the end of the life of the well, a well barrier is necessary to be introduced to plug and abandon (P&A) the well temporarily or permanently.
In the prior arts, cement and resin are used for P&A applications. However, shrinkage of cement or resin plugs happens and causes uncertainty about sealing ability. Therefore, the P&A plug must be long enough to ensure the sealing ability. There are different standards for P&A in different countries, for example, according to Norwegian standard, a good cement plug needs to be 100 m long to ensure a good sealing. There are several ways to do P&A. However, the most common is to cut and mill the casing before placing a cement plug to ensure sufficient sealing ability. This process is time-consuming, and due to rig costs also very expensive. Several attempts have been made in the art to solve this problem by providing a cementing and/or plugging material with reduced shrinkage. Experiments have for instance been performed with cement and/or resin. In a few experiments, performed under special conditions, zero shrinkage has been obtained. This has not been reproducible under varying well conditions. In practice, there are a lot of uncertain factors involved, and it is difficult to know the exact conditions in a well.
The prior art also discloses resin mixed with cement for sealing a hydrocarbon well. Patent publication US 9688578 B2 describes a composition, wherein the composition comprises a prepolymer, a monomer, a cement slurry, an initiator and an inhibitor, wherein setting time and a hardening time of the composition are set by choosing the amounts of initiator and inhibitor for precisely tailoring of the composition to the relevant well conditions and placement times of composition at downhole locations. The composition with different components of organic components (prepolymer, monomer), inorganic components (cement), water, initiator and inhibitor limits the possibility to control setting time and hardening time due to limited compatibility of the components. This causes limitation for well applications as in most of the cases the composition does not have long enough setting time to place the composition at the required downhole depth.
In case of loss of circulation in the well, as mentioned above, cement or resin can be introduced to stop a loss. In the case of the severe loss or total loss, it is in the prior art preferred to use a resin due to the possibility to control the setting time exactly and seal the loss in a short time. However, setting time of the resin highly depends on the temperature at the loss zone. A few-degree difference in temperature estimation or calculation may lead to use of the wrong resin composition. This results in low success rate of the loss treatment as well as high risk of curing the drill pipe, or other downhole tools, inside a placed composition.
The invention has for its object to remedy or to reduce at least one of the drawbacks of the prior art, or at least to provide a useful alternative to prior art.
The object is achieved through features, which are specified in the description below and in the claims that follow.
General description of the invention
The invention is defined by the independent patent claims. The dependent claims define advantageous embodiments of the invention.
In a first aspect, the invention relates more particularly to method of solidification of a liquid composition, said method comprising the steps of:
- providing a volume of the liquid composition;
- arranging a trigger means in connection with a portion of the liquid composition;
- activating the trigger means to influence said portion of liquid composition such that the liquid composition starts to solidify; and
- activating liquid composition adjoining said portion of liquid composition via the portion of liquid composition such as to provide a reaction spreading from said portion of liquid composition and throughout the entire volume of liquid composition to form a volume of solid composition.
Herein, the word “volume” of liquid composition means that the liquid composition in itself doesn't have a specific shape. It can take on any form depending on the space in which it is provided.
The word “in connection with” in this context means that the trigger means may either be in touch with or introduced so close to the portion of liquid composition that an initiation of a reaction is possible.
The trigger means is activated to influence on said portion of the liquid composition such that said portion reacts and starts to solidify. The reacted portion activates liquid composition adjoining it and provides a reaction spreading from said portion of liquid composition and throughout the entire volume of liquid composition to form a volume of solid composition.
The trigger means may be one of or both of a heat source and a chemical source.
Said portion of liquid composition can be activated by a heat source or by a chemical source or a combination thereof. In one embodiment it is also possible to activate more than one portion of the liquid composition either at the same time or at different times, by means of the same or different trigger means, depending on the positioning of the liquid composition and the trigger means relative to one another, and depending on the location of the liquid composition.
It must be understood that also other trigger means than heat sources and chemical sources may be possible. In one embodiment, the trigger means may for instance be one or more of a UV source, a microwave source, and an ultrasonic source. These possible trigger means may also be used in combination with one or both of a heat source and a chemical source.
The volume of liquid composition may be arranged in a well. This is a possible embodiment of the invention. The liquid composition can in other embodiments be placed at the surface. When placed downhole in a well, the liquid composition may be arranged to form a plug, an annular barrier, or a placed sealing volume. The well can be any type of well such as an oil well, a gas well, or a water production well, a geothermal well, an injection well, or a high temperature and high pressure well.
One possible effect of arranging the liquid composition in a well for providing a plug, is that part of the liquid composition of the invention remedies the shrinkage problem of polymer material and/or cement. Shrinkage is in the nature of a chemical reaction of both cement and polymer material, and cannot be avoided or controlled at all well conditions. The method according to the first aspect of the invention will remedy the shrinkage problem. In the case of P&A application, after placing a liquid composition at a required downhole depth, the liquid composition is triggered to react at the bottom of the liquid composition. Shrinkage happens at the bottom when the portion of liquid composition starts to react and solidify. The liquid composition in the upper part is squeezed into the shrinkage channel and seals off the shrinkage channel thanks to the hydrostatic pressure of the upper liquid composition. When the reaction occurs gradually at a thin layer scale, the shrinkage is easily sealed off by the upper liquid composition. This sealing mechanism repeats multiple times to ensure sealing ability of the formed solid composition. The reaction spreads through the entire volume in the manner where spreading speed of the reaction can be controlled by adjusting composition of the liquid composition.
Another effect of the invention is that it increases the success rate of the loss circulation treatment. In the prior arts, to stop a severe loss in a loss zone by using polymer material, it is very important to know the exact temperature at a loss zone to design the polymer material composition. However, it is not possible to predict or calculate exactly the temperature at such severe loss situation because the loss cools down the surrounding formation. The method according to the first aspect uses a trigger means to start the reaction and then spread the reaction to the entire placed volume of liquid composition which is less effected by surrounding temperature. This eliminates the effect of the surrounding temperature to the reaction, thus increasing the success rate of loss treatment. The spreading speed in this case can be fast, in a short time or immediate and seal off the loss efficiently.
The trigger means may be arranged in the well. In some embodiments the trigger means may be arranged in the well before the liquid composition, while in other embodiments it may be brought into the well after or together with the liquid composition. Examples of this will be explained in more details hereinafter.
The liquid composition may comprise a polymer material.
The polymer material may comprise a pre-polymer, a monomer, or a two-component polymer
The polymer material may comprise at least one of the following materials: unsaturated polyester, vinyl polyester, epoxy resin, polyurethane, furan resin, urea-formaldehyde resin, phenol formaldehyde resin, melamine resin, silicones, acrylic resin, cyanate ester resin, bismaleimide resin, geopolymer, or combinations thereof.
The two-component polymer may for example be epoxy resin or polyurethane.
The polymer material may further comprise one or more of a filler, a viscosity modifier, a stability agent, or any possible combinations thereof. The filler may be selected from the group including, fly ash, sand, clays, glass beads, trimanganese tetroxide, calcium carbonate, barite, and combinations thereof.
In another embodiment of the method according to the invention, the polymer material may further comprise a cement slurry (cement and water), wherein the cement is selected from the group consisting of Portland cements, gypsum cements, high alumina content cements, slag cements, high magnesia content cements, and combinations thereof.
The liquid composition may comprise one or more of an initiator, an inhibitor and an accelerator.
The cement may comprise a setting inhibitor, wherein the setting inhibitor is selected from a group consisting of sucrose, tartaric acid, gluconic acid δ-lactone, lignosulfonates, and organic phosphoric acids. An example of a setting inhibitor is calcium lignosulfonate.
The cement may further comprise a setting accelerator, wherein the setting accelerator is selected from a group consisting of chloride salts, carbonates, silicates, aluminates, nitrates, nitrites, sulphates, thiosulphates and hydroxides.
When a mixture of polymer material and cement slurry is used, the mixture may further comprise a dispersing agent.
When an initiator is used, the initiator may comprise a dissociable compound, wherein the dissociable compound is selected from the group including peroxides and azo compounds, wherein the dissociable compound is selected from the group consisting of dibenzoyl peroxide, tert-butyl peroxybenzoate, tert-butyl cumyl peroxide, and combinations thereof.
The inhibitor may comprise p- benzoquinone.
The accelerator may comprise a compound, wherein the compound is selected from the group including inorganic salts, transition metal compounds, inorganic hydroxides amides, amines and aromatic compounds, wherein the aromatic compound comprises N, N-dimethyl-p-toluidine.
The polymer material may further comprise a hardener. In an example of this embodiment the epoxy resin or the polyurethane comprises the hardener.
The polymer material may further comprise one or more additives such as for instance a low-profile additive, a toughening agent, and/or an adhesion improver.
In a second aspect, the invention relates more particularly to a liquid composition for forming a plug in a well, comprising a polymer material arranged to solidify upon influence by a trigger means.
The polymer material can or cannot react by itself at a well condition without trigger means. The polymer material by itself does not need to react in a manner of controllable setting time to be placed successfully in a well. When a trigger means is introduced, the trigger means decides when the reaction starts and spreads gradually or immediately to the entire polymer material volume. This results in that the well conditions do not have much influence to the reaction of the polymer material. The polymer material in this second aspect of the invention may be composed as already described above for the first aspect of the invention.
When a portion of the polymer material is triggered to react, this generates a heat due to the exothermic reaction, and this heat causes the reaction to spread to the adjoining portion and continuously and gradually throughout the entire liquid composition volume. The reaction spreads to the liquid composition adjoining the reacting portion as long as the generated heat can activate the adjoining liquid composition which cannot react by itself at the time.
The liquid composition comprises a polymer material as described herein. The liquid composition can be triggered at any position, but preferably at the bottom position for P&A applications. The liquid composition can be placed in a well through a coiled tubing tool, a production tubing, or a drill pipe or it can be bullheaded, i.e. pumped into the well at a high pressure.
The trigger means can be arranged in the well by means of an activation tool.
In a third aspect, the invention relates more particularly to a sealing system for preventing leakage from a well, said system comprising:
- a liquid composition for being arranged in the well; and
- an activation means for activation of a reaction in the liquid composition such that the liquid composition solidifies.
The term “preventing leakage” is herein meant to cover both preventing existing leakage, i.e. stopping an ongoing leakage, and preventing a leakage from occurring. To prevent leakage in a well thus includes to plug and abandon a well, to set a barrier in an annular, and to stop a lost circulation in a loss zone.
When a polymer material is mixed with a cement slurry, the setting time and hardening time cannot be easily controlled because of the poor compatibility of cement slurry, polymer material, initiator and inhibitor. The method according to the first aspect of the invention provides a method for placing a liquid composition in a well which does not need a reaction manner of controllable setting time. The liquid composition is triggered at a certain portion of the liquid composition by a heat source and/or a chemical source. Then the reaction of the portion of the liquid composition will spread gradually and continuously to the entire volume of the liquid composition, whereas the volume of the liquid composition can be a plug shape, a barrier shape or a volume mass. The trigger means can be arranged in a well by introducing an activation tool.
The activation means may be a liquid. This is a possible embodiment of the invention. The liquid can generate a heat source by an exothermic chemical reaction. The liquid can be arranged in the well at any time, but is preferably brought into the well just after the liquid composition. A dart may preferably be placed between the liquid and the liquid composition to prevent mixing during pumping. The liquid includes a polymer material. The polymer material may be composed as described hereinabove for the first aspect of the invention. The activation means may be an activation tool. This is another embodiment of the invention.
In a fourth aspect, the invention relates more particularly to an activation tool for the sealing system according to the third aspect, wherein the activation tool comprises:
- a trigger means for initiating the reaction in the liquid composition; and
- a placing means for arranging the trigger means in a desired position in the well.
In one embodiment of the invention, the placing means constitute part of a coiled tubing. In another embodiment of the invention, the activation tool may be a separate tool which may be launched into the well. In still another embodiment the activation tool may be two-piece tool wherein one part is placed in the well before the other part. In one such embodiment one part is connected to a mechanical plug. In another such two-piece embodiment, one part is a small sub containing the trigger means.
The trigger means may comprise a heating device.
The trigger means may comprise a chemical.
In a fifth aspect, the invention more particularly relates to a method of preventing leakage from a well, said method comprising the steps of:
- placing an activation tool according to the forth aspect of the invention at a desired location in the well;
- providing a liquid composition according to the second aspect of the invention in the well, such that at least a portion of the liquid composition is in connection with the activation tool; and - initiating a reaction in the liquid composition by means of the trigger means of the activation tool, such that the liquid composition solidifies.
In the following are described examples of preferred embodiments illustrated in the accompanying drawings, wherein:
Fig. 1 shows, in a planar view, an embodiment of the activation tool according to the fourth aspect of the invention;
Fig. 2 shows, at a different scale, a second embodiment of the activation tool according to the fourth aspect of the invention;
Fig. 3 shows a third embodiment of the activation tool according to the fourth aspect of the invention;
Fig. 4 shows a fourth embodiment of the activation tool according to the fourth aspect of the invention;
Fig. 5 shows an experimental test setup for the method according to the first aspect of the invention;
Fig. 6 shows reaction results from the test setup of Fig.5;
Fig. 7 shows another experimental test setup for the method according to the first aspect of the invention; and
Fig.8 shows reaction results from the test setup of Fig.7.
Figure 1 illustrates an example of an activation tool 1 which may be run at the bottom of a coiled tubing bottom hole assembly (BHA), not shown. The activation tool 1 comprises a trigger means 2 for initiating a reaction in a liquid composition 3 (shown in Figs.5 and 7), and a placing means 4, in this particular embodiment arranged to be connected to the not shown coiled tubing. In this embodiment the trigger means 2 is shown in the form of a heat source 21, i.e. a heating device 21, and the placing means 4 is shown in the form of a hydraulic setting and disconnecting tool 41 for disconnecting the trigger means 2 from the coiled tubing. The heating device 21 comprises at least one battery section 21a, an electronic control section 21b for heating and timer control, and at least one heating element 21c. The battery section 21a is arranged to store the energy for the heating element 21c. The heating element 21c will use the electrical energy stored in the battery section 21a to heat up its surrounding environment.
The heating device 21 may be put together in various ways, i.e. the battery section 21a, the electronic control section 21b, and the at least one heating element 21c may be arranged in different orders. The battery section 21a may for example be placed on top of the other two elements 21b, 21c, or below, or between.
The placing means 4, in this embodiment the hydraulic disconnecting tool 41, is placed above the heating device 21 to disconnect the heating device 21 from the BHA. The hydraulic disconnecting tool 41 can be activated by dropping a ball or a dart through the coil tubing. The disconnecting may be used to activate the heating device 21.
The activation tool 1 in this embodiment is arranged to allow fluid flow through both the trigger means 2 and the placing means 4, which means that the activation tool is provided with a pathway 11, or internal cavity 11, allowing fluid from the coiled tubing to pass through the activation tool 1 downward, or fluid from below the activation tool 1 to pass upward through said internal cavity 11.
Other coiled tubing tools 5 can be connected above the hydraulic disconnecting tool 41.
Figure 2 illustrates an embodiment of the activation tool 1 in the form of a pump down sub. Also in this embodiment the trigger means 2 is in the form of a heating device 21 for heating up the liquid composition 3 in a well to create a temperature gradient.
The activation tool 1 in this embodiment further comprises a fish neck 6, a pump dart 7 and a housing 12. The heating device 21 is also in this embodiment shown comprising the battery section 21a, the electronic control section 21b and the at least one heating element 21c.
The fish neck 6 provides a contingency option to retrieve the activation tool 1 by a fishing operation. The pump down dart 7 provides flow resistance to push the activation tool 1 down into the well with the flow. The housing 12 provides a pressure isolated chamber to accommodate the heating device 21. The mutual location of the battery section 21a, the electronic control section 21b, and the heating element 21c can be interchangeable.
The heating device 21 can be activated by the electronic control section 21b. It also can be activated by other means, for example but not limited to, a mechanical switch (not shown) at the bottom of the activation tool 1 activated when the activation tool 1 collides with other objects (impact) or activated by the sudden stop of the activation tool 1 when it hits other objects (acceleration). The activation can be done by more than one method in the same activation tool 1.
Figure 3 illustrates another embodiment of the activation tool 1 which comprises a bridge plug 8 attached to the heating device 21 which is set by a coiled tubing hydraulic setting tool (not shown).
In addition to the heating device 21, and the bridge plug 8, the activation tool 1 in this embodiment also comprises the hydraulic setting and disconnecting tool 41. The battery section 21a, the electronic control section 21b, and the heating element 21c of the heating device 21 are in this embodiment all arranged in the bridge plug 8. So, the heating device 21 is attached to the bridge plug 8 which is set by the coiled tubing hydraulic setting and disconnecting tool 41 inside a casing 9. The mutual position of the battery section 21a, the electronic control section 21b, and the heating element 21c can be interchangeable.
The bridge plug 8 comprises traditional plug components like an anchor and a sealing element, and is, as mentioned, in this embodiment connected to the heating device 21.
The bridge plug 8 is connected to the coiled tubing hydraulic setting and disconnecting tool 41 which is conveyed by other coil tubing tools 5 to setting depth. When the bridge plug 8 is set, the coil tubing hydraulic setting and disconnecting tool 41 is released from the bridge plug 8. The release may activate the heating device 21. Otherwise, the heating device 21 can be activated by the electronic control section 21b, or by both. After the bridge plug 8 is set, fluid can be pumped from surface through the other coiled tubing tools 5 and the coiled tubing hydraulic setting and disconnecting tool 41.
The battery section 21a provides the energy which is used by the heating elements 21c to heat up its surrounding environment. It must be understood that in all the embodiments of figures 1-3, the heating element 21c may comprise a plurality of heating elements 21c.
Figure 4 illustrates an embodiment of the activation tool 1 in the form of a launching system for arranging the trigger means 2 in the well. The trigger means 2 is here shown in the form of a chemical source 22, namely a chemical launching sub 22, for launching a chemical 22c into the well and initiating the reaction of the liquid composition 3.
The placing means 4 of the activation tool 1 in this embodiment comprises a locator sub 42 comprising a locating nipple profile 421 (in the art often named a no-go 421) for receiving and stopping the chemical launching sub 2 when it enters in the locator sub 42. The chemical launching sub 22 comprises a rupture disk 22a, a flexible membrane 22b and the chemical 22c.
The locator sub 42 is installed as part of a drilling bottom hole assembly (BHA) or as part of the coiled tubing BHA. The locating nipple profile 421 of the locator sub 42 acts as a no-go which stops the chemical launching sub 22 from passing through.
The chemical launching sub 22 can be launched from surface. The chemical launching sub 22 may have a dart shape as illustrated in Figure 4, a ball shape, or any other suitable shape. The chemical launching sub 22 is provided with an inner space wherein the chemical 22c which can trigger the reaction of the liquid composition 3, is provided.
The rupture disk 22a and the flexible membrane 22b will protect the chemical 22c from turbulence flow outside the chemical launching sub 22. The flexibility of the membrane 22b will provide pressure compensating between the inside and the outside the chemical launching sub 22.
After launching from surface, the chemical launching sub 22 will travel in a drill pipe or coiled tubing and land at the locating nipple profile 421. Once landed, the pumping pressure will surge and break the rupture disk 22a as well as the flexible membrane 22b and release the chemical 22c into the flow.
An upper portion, in a position of use, of the chemical launching sub 22 provides the support for a further chemical launching sub 22 to sit properly. Multiple chemical launching subs 22 can be launched if needed.
The chemical 22c includes at least one of an initiator or an accelerator.
It must be understood that the above examples of possible activation tools 1, are indeed examples only. A person skilled in the art and with knowledge about the activation tools 1 described herein would be able to also make other varieties of the activation tool 1 also falling within the scope of this invention.
Figure 5 illustrates an example of an experimental test setup 10 for reaction of the liquid composition 3 which is triggered by a heat source 21. The liquid composition 3 is arranged in a test tube 101. The setup 10 further comprises a plurality of thermocouple probes 102, herein shown as seven points T1-T7 each indicating a thermocouple probe 102.The experiment is carried out in the test tube 101 which is filled with the liquid composition 3 at any temperature. The test tube 101 can have any dimension.
Figure 6 shows test results from an experiment according to the experiment test setup 10 of Figure 5. The experiment has been carried out at room temperature. In this experiment the test tube 101 used was 1000mm long and 38.1 mm in diameter.
The liquid composition 3 can be any polymer material as described hereinbefore. The polymer material by itself can or cannot set/ cure at the reaction condition (for example at room temperature in the results) or it can set at the manner which does not need a controllable setting time.
The temperature may be recorded during the experiment. This can be carried out by the thermocouple probes 102 at different positions along the test tube 1 from the position of T1 to the position of T7. In the experiment results of Figure 6, the bottom of the test tube 101 is heated up to 60 ºC by the heating device 21, to trigger a polymerization reaction.
Transferring this experiment to a location in a well, in another embodiment, the heat source 21 can be introduced at any position of the plug and at any temperature as long as the heat source 21 provides a temperature which is higher than the temperature of the liquid composition 3 in the placed environment or position. The plug can be any shape such as a plug or a volume mass
In the experiment results in Figure 6, the reaction is triggered at the bottom of the liquid composition 3 by the heat source 21 and then gradually and continually spread up to through the entire volume of liquid composition 3, such that a solid composition is provided. This method, and this liquid composition, may therefore be used for providing a solid plug, or solid sealing material, in a well.
In another embodiment, the reaction can spread fast, in a short time or immediately to the entire volume of liquid composition. This depends on the power of the heat source 21 provided for the liquid composition 3 at the triggered portion, and on the composition of the liquid composition.
When polymerization reaction occurs, it generates exothermic peak, which is recorded as the results shown in Figure 6.
Figure 6 shows the results of an experiment where the reaction is triggered at the bottom of the liquid composition 3 and moves up to the T1 position, then to the T2 position, and finally up to the T7 position. The total time for the reaction to spread from T1 to T7 is, in this example, around one hour.
Figure 7 illustrates an example of an experimental test setup 20 for reaction of the liquid composition 3 when triggered by a chemical source 22.
The experiment test setup 20 comprises a test tube 201, the liquid composition 3, a plurality of thermocouple probes 202, and a trigger means 2 in the form of a chemical source 22. The thermocouple probes 202 are shown herein as eight points numbered T1-T8.
The experiment is carried out in the test tube 201 which is filled with the liquid composition 3 at any temperature. The results of an experiment carried out according to the test setup 20 of Figure 7, are shown in Figure 8. This particular experiment is carried out at room temperature. The test tube 201 can have any dimension. In the experiment results in Figure 8, the test tube 201 was 1000mm long and 38.1 mm in diameter.
The liquid composition 3 can be any polymer material described hereinabove. The polymer material by itself can or cannot set/ cure at the environment temperature (for example at room temperature in the results in Figure 8) or it can set at the manner which does not need a controllable setting time.
Temperature during the experiment may be recorded by the thermocouple probes 202 at different positions along the test tube 201 from position T1 to position T8.
In the results in Figure 8, the top portion of the liquid composition 3 is introduced to a chemical source 22 to trigger a reaction in a portion of the liquid composition 3. In another embodiment, the chemical source can be introduced at any position of the liquid composition 3. The volume of the liquid composition 3 can be any shape such as an elongate volume or a volume mass. The reaction of the liquid composition 3 turns the liquid composition 3 into a solid composition, suitable as a plugging/sealing material. A volume of the liquid composition 3 arranged in a well, may therefore be triggered to react and thus form a plug or a seal in a well, to prevent leakage from the well.
The reaction is, in the example of Figures 7 and 8, triggered at the top of the liquid composition 3 by the chemical source 22 and then gradually and continually spread to the entire volume of liquid composition 3.
The chemical source 22 includes at least one of an initiator, an accelerator, or combinations thereof.
The chemical source 22 can be introduced at multiple times and at multiple positions in order to adjust for instance the solidification time of the liquid composition 3.
In another embodiment, the reaction can spread fast, in a short time or immediately to the entire volume of liquid composition, to form a solid composition suitable for plugging or sealing a well. The reaction speed depends on the amount of chemical 22c of the chemical source 22.
When polymerization reaction occurs, it generates exothermic peak, which is recorded as the results shown in Figure 8.
Figure 8 shows the results of an experiment where reaction is triggered at the top of the liquid composition 3 by an accelerator at the T1 position, then the reaction moves down to the T2 position and finally down to the T8 position. The total time for the reaction to spread from T1 to T8 is, in this particular experiment, around 230 minutes.
It should be noted that the above-mentioned embodiments illustrate rather than limit the invention, and that those skilled in the art will be able to design many alternative embodiments without departing from the scope of the appended claims. In the claims, any reference signs placed between parentheses shall not be construed as limiting the claim. Use of the verb "comprise" and its conjugations does not exclude the presence of elements or steps other than those stated in a claim. The article "a" or "an" preceding an element does not exclude the presence of a plurality of such elements.
The mere fact that certain measures are recited in mutually different dependent claims does not indicate that a combination of these measures cannot be used to advantage.
Claims (14)
1. Method of solidification of a liquid composition (3), said method comprising the steps of:
- providing a volume of the liquid composition (3);
- arranging a trigger means (2) in connection with a portion of the liquid composition (3); - activating the trigger means (2) to influence said portion of liquid composition (3) such that the liquid composition (3) starts to solidify; and
- activating liquid composition (3) adjoining said portion of liquid composition via the portion of liquid composition (3) such as to provide a reaction gradually spreading from said portion of liquid composition (3) and throughout the entire volume of liquid composition (3) to form a volume of solid composition.
2. Method according to claim 1, wherein the trigger means (2) is one of or both of a heat source (21) and a chemical source (22).
3. Method according to claim 1 or 2, wherein the volume of liquid composition (3) is arranged in a well.
4. Method according to claim 3, wherein the trigger means (2) is arranged in the well.
5. Method according to any of the preceding claims, wherein the liquid composition (3) comprises a polymer material.
6. Method according to claim 5, wherein the polymer material comprises at least one of or a combination of two or more of the following materials: unsaturated polyester, vinyl polyester, epoxy resin, polyurethane, furan resin, urea-formaldehyde resin, phenol formaldehyde resin, melamine resin, silicones, acrylic resin, cyanate ester resin, bismaleimide resin, and geopolymer.
7. Method according to any of the preceding claims, wherein the liquid composition (3) comprises one or more of an initiator, an inhibitor, and an accelerator.
8. Liquid composition (3) for forming a plug in a well, comprising a polymer material arranged to solidify upon influence by a trigger means (2).
9. Sealing system for preventing leakage from a well, said system comprising:
- a liquid composition (3) for being arranged in the well; and
- an activation means for activation of a reaction in the liquid composition such that the liquid composition solidifies.
10. Sealing system according to claim 9, wherein the activation means is a liquid.
11. Sealing system according to claim 9, wherein the activation means is an activation tool (1).
12. Activation tool (1) for the sealing system according to claim 11, wherein the activation tool (1) comprises:
- a trigger means (2) for initiating the reaction in the liquid composition (3); and
- a placing means (4) for arranging the trigger means (2) in a desired position in the well.
13. Activation tool (1) according to claim 12, wherein the trigger means (2) comprises a heating device (21) and/or a chemical (22c).
14. Method of preventing leakage from a well, said method comprising the steps of:
- placing an activation tool (1) according to any one of claims 12-13 at a desired location in the well;
- providing a liquid composition (3) according to claim 8 in the well, such that at least a portion of the liquid composition (3) is in connection with the activation tool (1); and
- initiating a reaction in the liquid composition (3) by means of the trigger means (2) of the activation tool (1), such that the liquid composition (3) gradually solidifies.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| NO20171578A NO20171578A1 (en) | 2017-10-03 | 2017-10-03 | Method and system for preventing leakage from a well |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| NO20171578A NO20171578A1 (en) | 2017-10-03 | 2017-10-03 | Method and system for preventing leakage from a well |
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| Publication Number | Publication Date |
|---|---|
| NO20171578A1 true NO20171578A1 (en) | 2019-04-04 |
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| Application Number | Title | Priority Date | Filing Date |
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| NO20171578A NO20171578A1 (en) | 2017-10-03 | 2017-10-03 | Method and system for preventing leakage from a well |
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| US20100051275A1 (en) * | 2007-04-02 | 2010-03-04 | Sam Lewis | Methods of activating compositions in subterranean zones |
| US20110079389A1 (en) * | 2009-10-06 | 2011-04-07 | Mackay Bruce A | Method for treating well bore within a subterranean formation |
| US20140083702A1 (en) * | 2012-09-21 | 2014-03-27 | Schlumberger Technology Corporation | In situ polymerization for completions sealing or repair |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US6177484B1 (en) * | 1997-11-03 | 2001-01-23 | Texaco Inc. | Combination catalyst/coupling agent for furan resin |
| US20080023205A1 (en) * | 2003-02-20 | 2008-01-31 | Schlumberger Technology Corporation | System and Method for Maintaining Zonal Isolation in a Wellbore |
| US20060086503A1 (en) * | 2004-10-26 | 2006-04-27 | Halliburton Energy Services | Casing strings and methods of using such strings in subterranean cementing operations |
| US20100051275A1 (en) * | 2007-04-02 | 2010-03-04 | Sam Lewis | Methods of activating compositions in subterranean zones |
| US20110079389A1 (en) * | 2009-10-06 | 2011-04-07 | Mackay Bruce A | Method for treating well bore within a subterranean formation |
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