CN114562239B - Method and device for improving hydrate reservoir exploitation efficiency by adopting nanofluid - Google Patents
Method and device for improving hydrate reservoir exploitation efficiency by adopting nanofluid Download PDFInfo
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- CN114562239B CN114562239B CN202210221397.1A CN202210221397A CN114562239B CN 114562239 B CN114562239 B CN 114562239B CN 202210221397 A CN202210221397 A CN 202210221397A CN 114562239 B CN114562239 B CN 114562239B
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- 238000000034 method Methods 0.000 title claims abstract description 33
- 239000002105 nanoparticle Substances 0.000 claims abstract description 90
- NMJORVOYSJLJGU-UHFFFAOYSA-N methane clathrate Chemical compound C.C.C.C.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O NMJORVOYSJLJGU-UHFFFAOYSA-N 0.000 claims abstract description 63
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 38
- 230000002209 hydrophobic effect Effects 0.000 claims abstract description 33
- 230000035699 permeability Effects 0.000 claims abstract description 25
- 239000012530 fluid Substances 0.000 claims abstract description 18
- 239000002245 particle Substances 0.000 claims abstract description 18
- 230000000903 blocking effect Effects 0.000 claims abstract description 12
- 230000008569 process Effects 0.000 claims abstract description 12
- 230000009467 reduction Effects 0.000 claims abstract description 9
- 238000002347 injection Methods 0.000 claims description 203
- 239000007924 injection Substances 0.000 claims description 203
- 238000004519 manufacturing process Methods 0.000 claims description 29
- 238000005253 cladding Methods 0.000 claims description 23
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 14
- 239000003381 stabilizer Substances 0.000 claims description 10
- 238000005086 pumping Methods 0.000 claims description 9
- 239000007788 liquid Substances 0.000 claims description 8
- 239000005543 nano-size silicon particle Substances 0.000 claims description 6
- 235000012239 silicon dioxide Nutrition 0.000 claims description 6
- YXFVVABEGXRONW-UHFFFAOYSA-N Toluene Natural products CC1=CC=CC=C1 YXFVVABEGXRONW-UHFFFAOYSA-N 0.000 claims description 4
- 239000008235 industrial water Substances 0.000 claims description 4
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical group CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 2
- BCKXLBQYZLBQEK-KVVVOXFISA-M Sodium oleate Chemical compound [Na+].CCCCCCCC\C=C/CCCCCCCC([O-])=O BCKXLBQYZLBQEK-KVVVOXFISA-M 0.000 claims description 2
- BOTDANWDWHJENH-UHFFFAOYSA-N Tetraethyl orthosilicate Chemical compound CCO[Si](OCC)(OCC)OCC BOTDANWDWHJENH-UHFFFAOYSA-N 0.000 claims description 2
- YGUFXEJWPRRAEK-UHFFFAOYSA-N dodecyl(triethoxy)silane Chemical compound CCCCCCCCCCCC[Si](OCC)(OCC)OCC YGUFXEJWPRRAEK-UHFFFAOYSA-N 0.000 claims description 2
- 125000003944 tolyl group Chemical group 0.000 claims description 2
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- 239000002734 clay mineral Substances 0.000 abstract description 4
- 238000001179 sorption measurement Methods 0.000 abstract description 4
- 230000036619 pore blockages Effects 0.000 abstract description 3
- 230000009471 action Effects 0.000 abstract description 2
- 230000000694 effects Effects 0.000 abstract description 2
- 239000010410 layer Substances 0.000 description 103
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 14
- 241000530105 Clerodendrum minahassae Species 0.000 description 8
- 239000007789 gas Substances 0.000 description 7
- 239000011247 coating layer Substances 0.000 description 5
- 239000003345 natural gas Substances 0.000 description 5
- 239000013535 sea water Substances 0.000 description 5
- 238000005553 drilling Methods 0.000 description 4
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- GUJOJGAPFQRJSV-UHFFFAOYSA-N dialuminum;dioxosilane;oxygen(2-);hydrate Chemical compound O.[O-2].[O-2].[O-2].[Al+3].[Al+3].O=[Si]=O.O=[Si]=O.O=[Si]=O.O=[Si]=O GUJOJGAPFQRJSV-UHFFFAOYSA-N 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
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- 229910052901 montmorillonite Inorganic materials 0.000 description 1
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- 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
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
-
- 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
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/0099—Equipment or details not covered by groups E21B15/00 - E21B40/00 specially adapted for drilling for or production of natural hydrate or clathrate gas reservoirs; Drilling through or monitoring of formations containing gas hydrates or clathrates
-
- 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
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
-
- 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
- Y02P90/00—Enabling technologies with a potential contribution to greenhouse gas [GHG] emissions mitigation
- Y02P90/70—Combining sequestration of CO2 and exploitation of hydrocarbons by injecting CO2 or carbonated water in oil wells
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- Geology (AREA)
- Mining & Mineral Resources (AREA)
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- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Filling Or Discharging Of Gas Storage Vessels (AREA)
Abstract
The invention provides a method and a device for improving the hydrate reservoir exploitation efficiency by adopting nano-fluid. The method is characterized in that nanofluid containing hydrophilic nanoparticles is respectively injected into the upper covering layer and the lower covering layer of the natural gas hydrate layer to form a water blocking layer, so that pore water of the upper covering layer and the lower covering layer is prevented from invading the natural gas hydrate layer under the action of pressure difference to cause water locking effect in the pressure reduction exploitation process, and further the exploitation efficiency is influenced. And meanwhile, the nano fluid containing hydrophobic nano particles is injected into the natural gas hydrate layer, so that the flow resistance of the decomposed water in the pores of the reservoir and the adsorption characteristic of the decomposed water on the walls of the pores are reduced, and the problem of permeability damage caused by pore blockage due to mass migration of stratum particles and expansion of clay minerals in the pressure reduction mining process is solved.
Description
Technical Field
The invention belongs to the field of sea natural gas hydrate exploitation, and particularly relates to a method and a device for improving hydrate reservoir exploitation efficiency by adopting nanofluid.
Background
Natural gas hydrate mainly exists at the edge of world marine continents and in high-latitude permafrost zones. The natural gas is also called methane hydrate because the natural gas has the characteristics of high energy density, wide distribution, large scale, shallow burial and the like, and the produced natural gas can meet the requirements of energy, economy, environment, efficiency and the like. Under standard conditions, one cubic meter of methane hydrate decomposes to produce up to 164 cubic meters of methane gas and 0.8 cubic meters of water. The energy density of the methane hydrate is very high, 2-5 times of that of the conventional natural gas, the combustion value is very high, and no residue is generated after combustion, so that the methane hydrate is a novel clean energy which is internationally recognized and has the most commercial development prospect, and is also the most ideal alternative energy for petroleum and natural gas.
The overburden and the underburden of natural hydrate reservoirs in nature, particularly in the undersea environment, i.e., the overburden and the underburden, are generally unconsolidated sediments characterized by high permeability, i.e., the overburden is unclosed. Methane gas generated by the decomposition of natural gas hydrate in the exploitation process can be dissipated from an unclosed cover layer in a large area to influence the exploitation efficiency, and meanwhile, serious environmental disasters are caused. In addition, when a hydrate layer is mined by adopting a depressurization method, the hydrate is stimulated to decompose by reducing the original pressure of the hydrate layer, the pressure of the hydrate layer is reduced to generate a pressure difference between the hydrate layer and the cover layer, the pressure of the cover layer is higher than that of the hydrate layer, free water in the cover layer or seawater on the cover layer flows to the hydrate layer, and the pore water content of the hydrate layer is increased to cause water lock damage; meanwhile, the flowing of the water in the pores of the cover layer can cause the migration of stratum particles such as clay minerals, fine sand grains and the like in the stratum to cause the pore blockage of a hydrate layer, reduce the permeability of the hydrate layer, cause the damage of the permeability and further reduce the exploitation efficiency; in addition, the redistribution of stratum particles caused by the migration of particles can generate a stress concentration phenomenon, and the mining safety is influenced.
Therefore, when the mining engineering is carried out on the sea area natural gas hydrate, the existing unclosed cover layer is transformed into the closed cover layer, so that the mining efficiency is improved, and the mining safety is guaranteed.
Disclosure of Invention
In view of the technical problems in the background art, the invention aims to provide a method and a device for improving the exploitation efficiency of a hydrate reservoir by using nanofluid, wherein the nanofluid containing hydrophilic nanoparticles is respectively injected into an upper layer and a lower layer of a natural gas hydrate layer to form a water blocking layer, so that pore water of the upper layer and the lower layer is prevented from invading the natural gas hydrate layer under the action of pressure difference during depressurization exploitation to cause a water locking effect, and the exploitation efficiency is influenced. And meanwhile, the nano fluid containing hydrophobic nano particles is injected into the natural gas hydrate layer, so that the flow resistance of the decomposed water in the pores of the reservoir and the adsorption characteristic of the decomposed water on the walls of the pores are reduced, and the problem of permeability damage caused by pore blockage due to mass migration of stratum particles and expansion of clay minerals in the pressure reduction mining process is solved.
In order to achieve the above object, the present invention provides an apparatus for injecting nanofluid into a natural gas hydrate production zone, comprising: a cannula, an injection tube and a central tube;
the sleeve is provided with a sleeve upper floral tube, a sleeve middle floral tube and a sleeve lower floral tube which are sequentially arranged from top to bottom, and the sleeve upper floral tube, the sleeve middle floral tube and the sleeve lower floral tube respectively correspond to the positions of an upper covering layer, a natural gas hydrate layer and a lower covering layer;
the injection pipe is positioned inside the sleeve, an annular gap is formed between the injection pipe and the sleeve, the injection pipe is provided with an injection pipe upper floral pipe, an injection pipe middle floral pipe and an injection pipe lower floral pipe which are sequentially arranged from top to bottom, the injection pipe upper floral pipe and the sleeve upper floral pipe are correspondingly arranged, the injection pipe middle floral pipe and the sleeve middle floral pipe are correspondingly arranged, the sleeve lower floral pipe and the injection pipe lower floral pipe are correspondingly arranged, an injection pipe upper seal, an injection pipe middle seal, an injection pipe lower seal and an injection pipe bottom seal are sequentially arranged in the annular gap between the injection pipe and the sleeve from top to bottom, the annular gap between the injection pipe and the sleeve is divided into three space areas, a space formed by the injection pipe upper seal and the injection pipe middle seal is used for enabling the injection pipe upper floral pipe and the sleeve upper floral pipe to be uniquely communicated, a space formed by the injection pipe middle seal and the injection pipe lower seal is used for enabling the injection pipe middle floral pipe and the sleeve lower floral pipe to be uniquely communicated;
the central tube is arranged in the injection tube and can move up and down in the axial direction relative to the injection tube, an annular gap is formed between the central tube and the injection tube, the central tube is provided with a central tube floral tube, an upper central tube seal and a lower central tube seal are arranged in the annular gap between the central tube and the injection tube, and the upper central tube seal and the lower central tube seal are used for enabling the central tube floral tube to uniquely correspond to and communicate with the upper central tube floral tube, the middle central tube floral tube or the lower central tube floral tube of the injection tube in the up-and-down movement process of the central tube in the injection tube.
Further, the upper seal of the injection pipe, the middle seal of the injection pipe, the lower seal of the injection pipe, the bottom seal of the injection pipe, the upper seal of the central pipe and the lower seal of the central pipe all adopt bridge plugs.
Furthermore, packers are adopted for the upper seal of the injection pipe, the middle seal of the injection pipe, the lower seal of the injection pipe, the bottom seal of the injection pipe, the upper seal of the central pipe and the lower seal of the central pipe.
The invention also provides a method for improving the exploitation efficiency of the hydrate reservoir by adopting the nanofluid, which is based on the device for injecting the nanofluid into the natural gas hydrate exploitation area, and specifically comprises the following steps:
deploying a production well in a natural gas hydrate production area, and setting a casing to a specified position;
step two, a filling pipe is put in, and the filling pipe is positioned in the sleeve;
thirdly, a central pipe is put into the injection pipe, so that the central pipe flower pipe, the flower pipe in the injection pipe and the flower pipe area in the sleeve pipe correspond to each other in position;
step four, preparing a nanofluid containing hydrophilic nanoparticles, pumping the nanofluid containing the hydrophilic nanoparticles into a central pipe, allowing the nanofluid to sequentially pass through a central pipe floral tube, an injection pipe upper floral tube and a sleeve upper floral tube and enter an upper cladding to form an upper cladding hydrophilic nanoparticle injection area, and accordingly forming a water blocking layer, wherein the upper cladding hydrophilic nanoparticle injection area is axially positioned in a range 1-10 m away from the upper boundary of the natural gas hydrate layer; when the permeability of the upper coating is more than 20 millidarcy, the thickness of a water blocking layer of a hydrophilic nanoparticle injection region of the upper coating is more than 1m; when the permeability of the upper cladding is less than 20 millidarcy, the thickness of the water-blocking layer of the hydrophilic nanoparticle injection region of the upper cladding is less than 1m and more than or equal to 0.5m; stopping injecting when the injection range of the nanofluid completely covers the natural gas hydrate exploitation area;
step five, moving the central tube downwards to enable the central tube floral tube, the filling tube lower floral tube and the sleeve lower floral tube to be corresponding in position, then pumping the configured nanofluid containing the hydrophilic nanoparticles in the step four into the central tube, enabling the nanofluid to sequentially pass through the central tube floral tube, the filling tube lower floral tube and the sleeve lower floral tube to enter a lower layer to form a lower layer hydrophilic nanoparticle filling area, and further forming a water-blocking layer, wherein the position of the lower layer hydrophilic nanoparticle filling area is axially located in the range of 1-10 m away from the lower boundary of the natural gas hydrate layer; when the permeability of the underlying layer is more than 30 millidarcy, the thickness of the water blocking layer of the hydrophilic nanoparticle injection region of the underlying layer is more than 1m; when the permeability of the underlying layer is less than 30 millidarcy, the thickness of the water resistance layer of the hydrophilic nanoparticle injection region of the underlying layer is less than 1m and is more than or equal to 0.5m; stopping injecting when the injection range of the nanofluid completely covers the natural gas hydrate exploitation area;
step six, preparing nanofluid containing hydrophobic nanoparticles, moving the central pipe upwards to correspond to the central pipe floral tube, the floral tube in the injection pipe and the floral tube area in the sleeve, pumping the prepared nanofluid containing the hydrophobic nanoparticles into the central pipe, enabling the nanofluid to sequentially pass through the central pipe floral tube, the floral tube in the injection pipe and the floral tube in the sleeve to enter a natural gas hydrate layer to form a hydrophobic nanoparticle injection area, enabling the area position of the hydrophobic nanoparticle injection area to axially comprise the whole natural gas hydrate layer, and enabling the injection range of the nanofluid to be within a radius of 5-15 m away from the wall of a production well;
and seventhly, after the step one to the step six, standing for 1-3 days after the nano fluid is injected, and then carrying out pressure reduction exploitation on the natural gas hydrate layer.
Further, the exploitation well is drilled to be 4-25 m below the bottom of the natural gas hydrate layer when a vertical well is adopted.
Furthermore, the injection pressure of the nanofluid containing hydrophilic nanoparticles and the nanofluid containing hydrophobic nanoparticles is 1 MPa-10 MPa.
Through the design scheme, the invention can bring the following beneficial effects: the invention provides a method and a device for improving the exploitation efficiency of a hydrate reservoir by adopting nano fluid, wherein a water-blocking layer is formed by injecting hydrophilic nano fluid into upper and lower cover layers (the upper cover layer is an upper cover layer, and the lower cover layer is a lower base layer) of a natural gas hydrate layer, an original permeable cover layer is transformed into a non-permeable cover layer, the upper and lower cover layers and seawater are prevented from invading a reservoir layer in the depressurization exploitation process to cause water lock damage, the method and the device are favorable for improving the gas permeability of depressurization exploitation of the natural gas hydrate layer and improving the gas recovery ratio; meanwhile, the hydrophobic nano fluid is injected into the natural gas hydrate layer, so that the reduction of permeability caused by stratum particle migration is prevented, the gas production efficiency is reduced, and the problem of borehole wall collapse caused by large-scale sand production is solved. Meanwhile, the problems of gas production efficiency reduction and reservoir instability caused by mechanical property weakening due to pore shrinkage caused by clay expansion and permeability reduction caused by blockage are prevented. Therefore, the single well exploitation efficiency is improved, the exploitation period is prolonged, and the probability of geological disasters in the hydrate exploitation process is reduced.
Drawings
FIG. 1 is a schematic diagram of an implementation structure of a method for improving hydrate reservoir production efficiency by using nanofluid.
Description of reference numerals: 1-seawater; 2-an upper cladding layer; 3-natural gas hydrate layer; 4-an underlying layer; 5-an upcoated hydrophilic nanoparticle injection zone; 6-underlying hydrophilic nanoparticle injection zone; 7-a hydrophobic nanoparticle injection region; 8-a sleeve; 9-an injection pipe; 10-a central tube; 81-arranging a perforated pipe on the sleeve; 82-sleeve middle floral tube; 83-sleeve lower floral tube; 91-sealing on the injection pipe; 92-sealing in the injection tube; 93-filling the upper floral tube of the tube; 94-sealing under the injection pipe; 95-floral tube in the injection tube; 96-fill tube bottom seal; 97-filling the floral tube below the tube; 101-an injection channel; 102-seal on center tube; 103-central tube flower tube; 104-seal under base pipe.
Detailed Description
In order to make those skilled in the art better understand the technical solution of the present invention, the technical solution in the embodiment of the present invention will be clearly and completely described below with reference to the drawings in the embodiment of the present invention, and it is obvious that the described embodiment is only a part of the embodiment of the present invention, and not all embodiments.
As shown in fig. 1, an apparatus for injecting nanofluids into a natural gas hydrate production zone comprises a casing 8, an injection pipe 9 and a central pipe 10, wherein after drilling to form a well, the casing 8 is lowered into the well, and the casing 8 does not move during the entire production process.
The sleeve 8 is provided with a sleeve upper perforated pipe 81, a sleeve middle perforated pipe 82 and a sleeve lower perforated pipe 83 which are sequentially arranged from top to bottom, the upper part of the sleeve 8 is a perforated pipe, namely the sleeve upper perforated pipe 81, the corresponding position is the upper cladding 2, and the nanofluid is injected into the upper cladding 2 through the sleeve upper perforated pipe 81; the middle part of the sleeve 8 is a perforated pipe, namely a perforated pipe 82 in the sleeve, the corresponding area is a natural gas hydrate layer 3, nano fluid is injected into the natural gas hydrate layer 3 through the perforated pipe 82 in the sleeve, and decomposed gas and decomposed water produced in the depressurization exploitation process also enter a shaft through the perforated pipe 82 in the sleeve; the lower part of the sleeve 8 is a perforated floral tube, namely a sleeve lower floral tube 83, the corresponding area is positioned as the underlying layer 4, and the nanofluid is injected into the underlying layer 4 through the sleeve lower floral tube 83. The casing 8 is divided into three sections, namely a casing upper perforated pipe 81, a casing middle perforated pipe 82 and a casing lower perforated pipe 83, so that the nano fluid can be accurately injected into a specified stratum.
The injection pipe 9 is positioned inside the sleeve 8, and the injection pipe 9 comprises seven parts, namely an injection pipe upper seal 91, an injection pipe middle seal 92, an injection pipe upper floral tube 93, an injection pipe lower seal 94, an injection pipe middle floral tube 95, an injection pipe bottom seal 96 and an injection pipe lower floral tube 97; the position of the upper perforated pipe 93 of the injection pipe corresponds to the upper perforated pipe 81 of the sleeve, the position of the middle perforated pipe 95 of the injection pipe corresponds to the middle perforated pipe 82 of the sleeve, and the position of the lower perforated pipe 97 of the injection pipe corresponds to the lower perforated pipe 83 of the sleeve, so that the connectivity between each section of perforated pipe structure and different floors after the injection pipe 9 and the sleeve 8 are matched is ensured. The upper injection pipe seal 91, the middle injection pipe seal 92, the lower injection pipe seal 94 and the bottom injection pipe seal 96 divide an annular gap between the injection pipe 9 and the sleeve 8 into three parts and ensure that the injection pipe 9 is communicated with the flower pipe at the corresponding position of the sleeve 8, wherein the upper injection pipe seal 91 and the middle injection pipe seal 92 ensure that the upper injection pipe flower pipe 93 is uniquely communicated with the upper sleeve flower pipe 81, the middle injection pipe seal 92 and the lower injection pipe seal 94 ensure that the middle injection pipe flower pipe 95 is uniquely communicated with the middle sleeve flower pipe 82, and the lower injection pipe seal 94 and the bottom injection pipe seal 96 ensure that the lower injection pipe flower pipe 97 is uniquely communicated with the lower sleeve flower pipe 83, so that the injection pipe 9 is adopted, different nano fluids can be accurately injected into different stratums through the sleeve 8, and the channeling among the layers is avoided.
The center tube 10 includes four sections, namely an injection channel 101, a center tube upper seal 102, a center tube flower tube 103, and a center tube lower seal 104. The central tube 10 can move up and down inside the injection tube 9, and the central tube upper seal 102 and the central tube lower seal 104 ensure that the central tube flower tube 103 is communicated with the flower tube structure of each part of the injection tube 9 only during the process that the central tube 10 moves up and down inside the injection tube 9. When the central tube floral tube 103, the injection tube upper floral tube 93 and the sleeve upper floral tube 81 correspond in position, the nanofluid can be injected into the upper cladding layer 2; when the central tube flower tube 103, the injection tube flower tube 95 and the sleeve tube flower tube 82 correspond in position, the nanofluid can be injected into the natural gas hydrate layer 3; when the central tube flower tube 103, the injection tube lower flower tube 97, and the sleeve lower flower tube 83 are positioned correspondingly, the nanofluid can be injected into the underlying layer 4. The over center tube seal 102 and under center tube seal 103 ensure that the center tube flower 103 only remains in communication with a single flower on the injection tube 9 and does not cross-flow with the other two flowers. The top of the injection tubing seal 91, the middle of the injection tubing seal 92, the bottom of the injection tubing seal 94, the bottom of the injection tubing seal 96, the top of the base pipe seal 102 and the bottom of the base pipe seal 104 are all bridge plugs or packers used in the drilling engineering field.
The upper casing floral tube 81, the middle casing floral tube 82, the lower casing floral tube 83, the upper filling tube floral tube 93, the middle filling tube floral tube 95 and the central tube floral tube 103 in the invention adopt grouting floral tubes used in drilling engineering.
The invention provides a method for improving hydrate reservoir exploitation efficiency by adopting nano fluid, which is characterized in that hydrophilic nano fluid is injected into an upper coating layer 2 and a lower coating layer 4, and nano particles in the hydrophilic nano fluid have higher surface energy and are attached to the surface of a pore wall of a stratum, so that the surface wettability of pores is changed into strong hydrophilicity, the resistance of water flowing in the pores is increased, the adsorption of water on the surface of the pore wall is increased, the flowing of the pore water is limited, a water blocking zone is formed in a hydrophilic nano particle injection area, and the pore water in the coating layer (namely the upper coating layer 2 and the lower coating layer 4) and upper seawater 1 are prevented from invading a natural gas hydrate layer 3. The hydrophobic nano fluid is injected into the natural gas hydrate layer 3, and the nano particles in the nano fluid have higher surface energy and are attached to the surface of the pore wall of the stratum, so that the wettability of the surface of the pore is changed into strong hydrophobicity, the resistance of water flow in the pore is reduced, stratum particles such as clay and silt in the stratum are reduced by the impact force of water flow, and the migration of the stratum particles is inhibited. Meanwhile, the adsorption quantity of water on the pore wall surface is reduced, and the hydration expansion of swelling clay minerals such as montmorillonite is inhibited, and the method specifically comprises the following steps:
step one, forming a production well by adopting a conventional drilling method, and setting a casing 8, wherein the whole casing 8 reaches the bottom of the production well through seawater 1, an upper covering layer 2, a natural gas hydrate layer 3 and a lower covering layer 4 respectively;
step two, a filling pipe 9 is put in, and the filling pipe 9 is positioned inside the sleeve 8;
thirdly, a central pipe 10 is put into the injection pipe 9;
and step four, preparing the nanofluid containing hydrophilic nanoparticles to ensure that the positions of the central tube floral tube 103, the floral tube 95 in the injection tube and the floral tube 82 in the sleeve correspond to each other, pumping the prepared nanofluid containing hydrophilic nanoparticles into the central tube 10, allowing the nanofluid to flow downwards along the injection channel 101 and then to enter the upper cladding 2 through the central tube floral tube 103, the upper floral tube 93 of the injection tube and the upper floral tube 81 of the sleeve in sequence to form an upper cladding hydrophilic nanoparticle injection area 5, and thus forming a water blocking layer. The position of the upper cladding hydrophilic nanoparticle injection region 5 is axially located within 1-10 m from the upper boundary of the natural gas hydrate layer 3; when the permeability of the upper cladding 2 is more than 20 millidarcy, the thickness of a water blocking layer of the hydrophilic nanoparticle injection region 5 of the upper cladding is required to be more than 1m; when the permeability of the upper cladding layer 2 is less than 20 millidarcy, the thickness of the water-blocking layer of the upper cladding layer hydrophilic nanoparticle injection region 5 may be less than 1m, but not less than 0.5m; stopping injecting when the injection range of the nano fluid completely covers the hydrate exploitation area;
and step five, downwards moving the central tube 10 to ensure that the central tube floral tube 103 corresponds to the injection tube lower floral tube 97 and the sleeve lower floral tube 83, pumping the configured nanofluid containing the hydrophilic nanoparticles in the step four into the central tube 10, allowing the nanofluid to sequentially pass through the central tube floral tube 103, the injection tube lower floral tube 97 and the sleeve lower floral tube 83 after the nanofluid flows downwards along the injection channel 101 and enter the underlying layer 4 to form an underlying hydrophilic nanoparticle injection region 6, and thus forming a water blocking layer. The position of the hydrophilic nanoparticle injection region 6 of the underlying layer is located within a range of 1m to 10m from the lower boundary of the natural gas hydrate layer 3 in the axial direction; when the permeability of the underlayer 4 is greater than 30 millidarcies, the thickness of the water-resistant layer of the underlayer hydrophilic nanoparticle injection region 6 is greater than 1 meter; when the permeability of the underlayer 4 is less than 30 millidarcies, the thickness of the water-blocking layer of the underlayer hydrophilic nanoparticle injection region 6 can be less than 1m, but cannot be less than 0.5m; stopping injecting when the injection range of the nanofluid completely covers the hydrate exploitation area;
and sixthly, preparing a nanofluid containing the hydrophobic nanoparticles, moving the central tube 10 upwards to a middle position to ensure that the central tube floral tube 103 corresponds to the positions of the floral tube 95 in the injection tube and the floral tube 82 in the sleeve, pumping the prepared nanofluid containing the hydrophobic nanoparticles into the central tube 10, and enabling the nanofluid to sequentially pass through the central tube floral tube 103, the floral tube 95 in the injection tube and the floral tube 82 in the sleeve and enter the natural gas hydrate layer 3 to form a hydrophobic nanoparticle injection area 7. The region position of the hydrophobic nanoparticle injection region 7 axially comprises the whole natural gas hydrate layer 3, the injection range of the nanofluid is within a radius of 5-15 m away from the wall of a production well, different injection radii are selected according to the permeability of different natural gas hydrate layers 3, the larger the permeability of the natural gas hydrate layer 3 is, the larger the injection range of the injected nanofluid is, but in the nanofluid process, the longer the injection distance is, the required injection pressure is larger, the overlarge injection pressure of the nanofluid can also damage the permeability of the natural gas hydrate layer 3, so that the maximum distance of the injection range of the nanofluid from the wall of the production well is not more than 15mm, and the original permeability of the natural gas hydrate layer 3 can not be damaged by the injection of the nanofluid.
And seventhly, after the step one to the step six, standing for 1-3 days after the nano fluid is injected, enabling the nano particles to be completely attached to the surface of the pore wall, ensuring that the nano particles cannot be carried out of the stratum by gas-water seepage generated by the decomposition of the hydrate in the process of mining to cause reconstruction failure, and then carrying out pressure reduction mining on the natural gas hydrate layer 3.
In the method provided by the invention, the production temperature of depressurization production is not required, and the conventional temperature in the field can be used.
Further, in the method provided by the present invention, preferably, the production well is a vertical well.
Further, in the methods provided herein, preferably, the production well is a plurality of vertical wells, and in the description of the present invention, "plurality" means at least two, e.g., two, three, etc., unless specifically defined otherwise.
And the production well is drilled to 4-25 m below the bottom of the natural gas hydrate layer 3 when a vertical well is adopted.
The nanofluid containing hydrophilic nanoparticles and the nanofluid containing hydrophobic nanoparticles are common formulas in the industrial field, and as a preferred scheme of the invention, the nanofluid containing hydrophilic nanoparticles consists of a base liquid, a stabilizer and hydrophilic nanoparticles, wherein the base liquid is industrial water, the stabilizer is absolute ethyl alcohol or ethyl orthosilicate, and the stabilizer accounts for 0.1-30% of the total mass of the nanofluid; the hydrophilic nano particles are nano silicon dioxide particles with strong hydrophilicity after the surface of the nano silicon dioxide particles is modified by sodium oleate; the nanofluid containing the hydrophobic nanoparticles consists of base liquid, a stabilizer and the hydrophobic nanoparticles, wherein the base liquid is industrial water; the stabilizer is toluene, and accounts for 0.1-30% of the total mass of the nanofluid; the hydrophobic nano-particles are nano-silica particles with strong hydrophobicity after the surface modification of the dodecyl triethoxysilane. The hydrophilic nanoparticles and the hydrophobic nanoparticles have the same particle size, the particle size range is 1 nm-100 nm, the mass of the hydrophilic nanoparticles in the nanofluid containing the hydrophilic nanoparticles accounts for 0.01-50% of the total mass, and the mass of the hydrophobic nanoparticles in the nanofluid containing the hydrophobic nanoparticles accounts for 0.01-50% of the total mass.
Furthermore, the injection pressure of the nanofluid containing hydrophilic nanoparticles and the injection pressure of the nanofluid containing hydrophobic nanoparticles are both 1MPa to 10MPa, different injection pressures are selected according to the thickness and the permeability of different cover layers (namely the upper covering layer 2 and the lower covering layer 4), and the fracture pressure of the upper cover layer of the natural gas hydrate layer 3 is not exceeded under the condition of realizing the water blocking function, so that the stratum is fractured.
Further, in the present invention, the injection range of the nanofluid containing hydrophilic nanoparticles in the overlayer 2 and the underlayer 4 is such that it can completely cover the actual production range of the natural gas hydrate layer 3, and the overlayer 2 and the underlayer 4 refer to the overlayer 2 and the underlayer 4 which completely cover the actual production range of the natural gas hydrate layer 3.
Claims (6)
1. An apparatus for injecting nanofluid into a natural gas hydrate production zone, comprising: a sleeve (8), an injection pipe (9) and a central pipe (10);
the sleeve (8) is provided with a sleeve upper floral tube (81), a sleeve middle floral tube (82) and a sleeve lower floral tube (83) which are sequentially arranged from top to bottom, and the sleeve upper floral tube (81), the sleeve middle floral tube (82) and the sleeve lower floral tube (83) respectively correspond to the upper covering layer (2), the natural gas hydrate layer (3) and the lower covering layer (4) in area positions;
the injection pipe (9) is positioned inside the sleeve (8), an annular gap is formed between the injection pipe (9) and the sleeve (8), the injection pipe (9) is provided with an injection pipe upper flower pipe (93), an injection pipe middle flower pipe (95) and an injection pipe lower flower pipe (97) which are sequentially arranged from top to bottom, the injection pipe upper flower pipe (93) is arranged corresponding to the sleeve upper flower pipe (81), the injection pipe middle flower pipe (95) is arranged corresponding to the sleeve middle flower pipe (82), the sleeve lower flower pipe (83) is arranged corresponding to the injection pipe lower flower pipe (97), the annular gap between the injection pipe (9) and the sleeve (8) is sequentially provided with an injection pipe upper seal (91), an injection pipe middle seal (92), an injection pipe lower seal (94) and an injection pipe bottom seal (96) from top to bottom, the annular gap between the injection pipe (9) and the sleeve (8) is divided into three space areas, the space formed by the injection pipe upper seal (91) and the injection pipe middle seal (92) is used for enabling the injection pipe upper flower pipe (93) and the sleeve upper flower pipe (94) to be communicated with the injection pipe lower flower pipe (96), and the injection pipe middle flower pipe (83) is used for enabling the injection pipe upper flower pipe (94) and the injection pipe (96) to be communicated with the injection pipe bottom seal to be the injection pipe (94), and the injection pipe bottom seal (83) and the injection pipe bottom seal to be communicated with the injection pipe (96), and the injection pipe (94), and the injection pipe (96) Is uniquely connected;
the central tube (10) is arranged in the injection tube (9) and can move up and down in the axial direction relative to the injection tube (9), an annular gap is formed between the central tube (10) and the injection tube (9), the central tube (10) is provided with a central tube floral tube (103), an upper central tube seal (102) and a lower central tube seal (104) are arranged in the annular gap between the central tube (10) and the injection tube (9), and the upper central tube seal (102) and the lower central tube seal (104) are used for enabling the central tube floral tube (103) and the upper injection tube floral tube (93) of the injection tube (9), the middle injection tube floral tube (95) or the lower injection tube floral tube (97) of the injection tube (9) to be uniquely corresponding and communicated in the up-down moving process of the central tube (10) in the injection tube (9).
2. An apparatus for injecting nanofluid into a natural gas hydrate production zone, according to claim 1, wherein: the upper seal (91) of the injection pipe, the middle seal (92) of the injection pipe, the lower seal (94) of the injection pipe, the bottom seal (96) of the injection pipe, the upper seal (102) of the central pipe and the lower seal (104) of the central pipe are all bridge plugs.
3. An apparatus for injecting nanofluid into a natural gas hydrate production zone according to claim 1, wherein: the upper seal (91) of the injection pipe, the middle seal (92) of the injection pipe, the lower seal (94) of the injection pipe, the bottom seal (96) of the injection pipe, the upper seal (102) of the central pipe and the lower seal (104) of the central pipe are all packers.
4. A method for improving the exploitation efficiency of a hydrate reservoir by using nanofluids, the method being based on the apparatus for injecting nanofluids into a natural gas hydrate exploitation area according to claim 1, 2 or 3, and specifically comprising the steps of:
deploying a production well in a natural gas hydrate production area, and lowering a casing (8) to a specified position;
step two, a filling pipe (9) is put in, and the filling pipe (9) is positioned inside the sleeve (8);
thirdly, a central pipe (10) is put into the injection pipe (9) so that the central pipe floral tube (103), the floral tube in the injection pipe (95) and the floral tube in the sleeve (82) are corresponding in area;
step four, preparing a nanofluid containing hydrophilic nanoparticles, pumping the nanofluid containing the hydrophilic nanoparticles into a central pipe (10), and enabling the nanofluid to sequentially pass through a central pipe floral tube (103), an injection pipe upper floral tube (93) and a sleeve upper floral tube (81) to enter an upper cladding (2) to form an upper cladding hydrophilic nanoparticle injection area (5) so as to form a water-blocking layer, wherein the position of the upper cladding hydrophilic nanoparticle injection area (5) is axially located in a range 1-10 m away from the upper boundary of a natural gas hydrate layer (3); when the permeability of the upper cladding (2) is more than 20 millidarcy, the thickness of the water-blocking layer of the upper cladding hydrophilic nanoparticle injection region (5) is more than 1m; when the permeability of the upper cladding (2) is less than 20 millidarcy, the thickness of the water-blocking layer of the upper cladding hydrophilic nanoparticle injection region (5) is less than 1m and more than or equal to 0.5m; stopping injecting when the injection range of the nanofluid completely covers the natural gas hydrate exploitation area;
step five, moving the central tube (10) downwards to enable the central tube floral tube (103), the filling tube lower floral tube (97) and the sleeve lower floral tube (83) to be corresponding in area position, then pumping the nanofluid containing the hydrophilic nanoparticles which is configured in the step four into the central tube (10), enabling the nanofluid to sequentially pass through the central tube floral tube (103), the filling tube lower floral tube (97) and the sleeve lower floral tube (83) to enter the underlying layer (4), forming an underlying layer hydrophilic nanoparticle filling area (6), and further forming a water resisting layer, wherein the underlying layer hydrophilic nanoparticle filling area (6) is axially positioned in a range 1-10 m away from the lower boundary of the natural gas hydrate layer (3); when the permeability of the underlying layer (4) is more than 30 millidarcy, the thickness of the water blocking layer of the hydrophilic nanoparticle injection area (6) of the underlying layer is more than 1m, and when the permeability of the upper underlying layer (4) is less than 30 millidarcy, the thickness of the water blocking layer of the hydrophilic nanoparticle injection area (6) of the underlying layer is less than 1m and is more than or equal to 0.5m; stopping injecting when the injection range of the nanofluid completely covers the natural gas hydrate exploitation area;
step six, preparing nanofluid containing hydrophobic nanoparticles, moving the central pipe (10) up to the central pipe floral pipe (103), enabling the floral pipe (95) in the injection pipe and the floral pipe (82) in the casing to correspond in area position, pumping the prepared nanofluid containing the hydrophobic nanoparticles into the central pipe (10), enabling the nanofluid to sequentially pass through the central pipe floral pipe (103), the floral pipe (95) in the injection pipe and the floral pipe (82) in the casing to enter the natural gas hydrate layer (3) to form a hydrophobic nanoparticle injection area (7), enabling the area position of the hydrophobic nanoparticle injection area (7) to axially comprise the whole natural gas hydrate layer (3), and enabling the injection range of the nanofluid to be within a radius of 5-15 m away from the wall of the exploitation well;
seventhly, after the step one to the step six, after the nano fluid is injected, standing for 1-3 days, and then carrying out pressure reduction exploitation on the natural gas hydrate layer (3);
the nanofluid containing hydrophilic nanoparticles consists of base liquid, a stabilizer and hydrophilic nanoparticles, wherein the base liquid is industrial water, the stabilizer is absolute ethyl alcohol or tetraethoxysilane, and the stabilizer accounts for 0.1-30% of the total mass of the nanofluid; the hydrophilic nano particles are nano silicon dioxide particles with strong hydrophilicity after the surface of the nano silicon dioxide particles is modified by sodium oleate; the nanofluid containing the hydrophobic nanoparticles consists of base liquid, a stabilizer and the hydrophobic nanoparticles, wherein the base liquid is industrial water; the stabilizer is toluene, and accounts for 0.1-30% of the total mass of the nanofluid; the hydrophobic nano-particles are nano silicon dioxide particles with strong hydrophobicity after the surface of the nano silicon dioxide particles is modified by dodecyl triethoxysilane; the hydrophilic nanoparticles and the hydrophobic nanoparticles have the same particle size, the particle size range is 1 nm-100 nm, the mass of the hydrophilic nanoparticles in the nanofluid containing the hydrophilic nanoparticles accounts for 0.01-50% of the total mass, and the mass of the hydrophobic nanoparticles in the nanofluid containing the hydrophobic nanoparticles accounts for 0.01-50% of the total mass.
5. The method for improving hydrate reservoir production efficiency using nanofluids according to claim 4, wherein: and the production well is drilled to 4-25 m below the bottom of the natural gas hydrate layer (3) when a vertical well is adopted.
6. The method for improving hydrate reservoir production efficiency using nanofluids according to claim 4, wherein: the injection pressure of the nanofluid containing hydrophilic nanoparticles and the nanofluid containing hydrophobic nanoparticles is 1 MPa-10 MPa.
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