CN107057671B - A kind of water-in-oil emulsion interface packing system, preparation method and water-oil separating technique and application with self-reparing capability - Google Patents
A kind of water-in-oil emulsion interface packing system, preparation method and water-oil separating technique and application with self-reparing capability Download PDFInfo
- Publication number
- CN107057671B CN107057671B CN201710383528.5A CN201710383528A CN107057671B CN 107057671 B CN107057671 B CN 107057671B CN 201710383528 A CN201710383528 A CN 201710383528A CN 107057671 B CN107057671 B CN 107057671B
- Authority
- CN
- China
- Prior art keywords
- water
- oil
- oil emulsion
- emulsion interface
- surfactant
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Fee Related
Links
- 239000007762 w/o emulsion Substances 0.000 title claims abstract description 73
- 238000012856 packing Methods 0.000 title claims abstract description 46
- 238000002360 preparation method Methods 0.000 title claims abstract description 15
- 238000000034 method Methods 0.000 title claims abstract description 14
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 58
- 239000000243 solution Substances 0.000 claims abstract description 45
- 239000004094 surface-active agent Substances 0.000 claims abstract description 39
- 239000003921 oil Substances 0.000 claims abstract description 32
- 229920005615 natural polymer Polymers 0.000 claims abstract description 25
- 239000007864 aqueous solution Substances 0.000 claims abstract description 23
- 239000000126 substance Substances 0.000 claims abstract description 21
- 239000010779 crude oil Substances 0.000 claims abstract description 13
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 claims abstract description 10
- 239000004519 grease Substances 0.000 claims abstract description 9
- 230000005484 gravity Effects 0.000 claims abstract description 8
- 238000000926 separation method Methods 0.000 claims abstract description 5
- KWIUHFFTVRNATP-UHFFFAOYSA-N glycine betaine Chemical compound C[N+](C)(C)CC([O-])=O KWIUHFFTVRNATP-UHFFFAOYSA-N 0.000 claims description 25
- 229960003237 betaine Drugs 0.000 claims description 19
- 229910052500 inorganic mineral Inorganic materials 0.000 claims description 15
- 239000011707 mineral Substances 0.000 claims description 15
- 239000002994 raw material Substances 0.000 claims description 15
- 235000010987 pectin Nutrition 0.000 claims description 14
- 239000001814 pectin Substances 0.000 claims description 14
- 229920001277 pectin Polymers 0.000 claims description 14
- 238000003756 stirring Methods 0.000 claims description 14
- -1 dimethyl betaine Chemical compound 0.000 claims description 13
- IXPNQXFRVYWDDI-UHFFFAOYSA-N 1-methyl-2,4-dioxo-1,3-diazinane-5-carboximidamide Chemical group CN1CC(C(N)=N)C(=O)NC1=O IXPNQXFRVYWDDI-UHFFFAOYSA-N 0.000 claims description 11
- 239000000203 mixture Substances 0.000 claims description 11
- 235000010413 sodium alginate Nutrition 0.000 claims description 11
- 239000000661 sodium alginate Substances 0.000 claims description 11
- 229940005550 sodium alginate Drugs 0.000 claims description 11
- SNRUBQQJIBEYMU-UHFFFAOYSA-N dodecane Chemical compound CCCCCCCCCCCC SNRUBQQJIBEYMU-UHFFFAOYSA-N 0.000 claims description 10
- LZZYPRNAOMGNLH-UHFFFAOYSA-M Cetrimonium bromide Chemical compound [Br-].CCCCCCCCCCCCCCCC[N+](C)(C)C LZZYPRNAOMGNLH-UHFFFAOYSA-M 0.000 claims description 9
- 239000011734 sodium Substances 0.000 claims description 9
- 229910052708 sodium Inorganic materials 0.000 claims description 9
- 239000003945 anionic surfactant Substances 0.000 claims description 8
- XJWSAJYUBXQQDR-UHFFFAOYSA-M dodecyltrimethylammonium bromide Chemical compound [Br-].CCCCCCCCCCCC[N+](C)(C)C XJWSAJYUBXQQDR-UHFFFAOYSA-M 0.000 claims description 8
- DCAYPVUWAIABOU-UHFFFAOYSA-N hexadecane Chemical compound CCCCCCCCCCCCCCCC DCAYPVUWAIABOU-UHFFFAOYSA-N 0.000 claims description 8
- 229910021645 metal ion Inorganic materials 0.000 claims description 8
- 239000002888 zwitterionic surfactant Substances 0.000 claims description 8
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 claims description 7
- 239000003795 chemical substances by application Substances 0.000 claims description 7
- 238000004132 cross linking Methods 0.000 claims description 7
- 239000011148 porous material Substances 0.000 claims description 7
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims description 6
- 239000002280 amphoteric surfactant Substances 0.000 claims description 6
- 239000003093 cationic surfactant Substances 0.000 claims description 6
- BGHCVCJVXZWKCC-UHFFFAOYSA-N tetradecane Chemical compound CCCCCCCCCCCCCC BGHCVCJVXZWKCC-UHFFFAOYSA-N 0.000 claims description 6
- 230000006698 induction Effects 0.000 claims description 5
- FHVDTGUDJYJELY-UHFFFAOYSA-N 6-{[2-carboxy-4,5-dihydroxy-6-(phosphanyloxy)oxan-3-yl]oxy}-4,5-dihydroxy-3-phosphanyloxane-2-carboxylic acid Chemical compound O1C(C(O)=O)C(P)C(O)C(O)C1OC1C(C(O)=O)OC(OP)C(O)C1O FHVDTGUDJYJELY-UHFFFAOYSA-N 0.000 claims description 4
- 229940072056 alginate Drugs 0.000 claims description 4
- 235000010443 alginic acid Nutrition 0.000 claims description 4
- 229920000615 alginic acid Polymers 0.000 claims description 4
- 150000001413 amino acids Chemical class 0.000 claims description 4
- 239000008367 deionised water Substances 0.000 claims description 4
- 229910021641 deionized water Inorganic materials 0.000 claims description 4
- 239000003129 oil well Substances 0.000 claims description 4
- 239000011435 rock Substances 0.000 claims description 4
- 239000007788 liquid Substances 0.000 claims description 3
- 125000000913 palmityl group Chemical group [H]C([*])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])[H] 0.000 claims description 3
- LQPUCRPHHIWEMI-UHFFFAOYSA-N C(CCCCCCCCCCC)C(C#N)(C)N.[Na] Chemical compound C(CCCCCCCCCCC)C(C#N)(C)N.[Na] LQPUCRPHHIWEMI-UHFFFAOYSA-N 0.000 claims description 2
- 239000004472 Lysine Substances 0.000 claims description 2
- PMZURENOXWZQFD-UHFFFAOYSA-L Sodium Sulfate Chemical compound [Na+].[Na+].[O-]S([O-])(=O)=O PMZURENOXWZQFD-UHFFFAOYSA-L 0.000 claims description 2
- 125000000118 dimethyl group Chemical group [H]C([H])([H])* 0.000 claims description 2
- 150000002148 esters Chemical class 0.000 claims description 2
- 150000002191 fatty alcohols Chemical class 0.000 claims description 2
- 238000002347 injection Methods 0.000 claims description 2
- 239000007924 injection Substances 0.000 claims description 2
- 229960000292 pectin Drugs 0.000 claims description 2
- 229910052938 sodium sulfate Inorganic materials 0.000 claims description 2
- 235000011152 sodium sulphate Nutrition 0.000 claims description 2
- 239000000230 xanthan gum Substances 0.000 claims description 2
- 235000010493 xanthan gum Nutrition 0.000 claims description 2
- 229920001285 xanthan gum Polymers 0.000 claims description 2
- 229940082509 xanthan gum Drugs 0.000 claims description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims 1
- 229910052799 carbon Inorganic materials 0.000 claims 1
- 150000001735 carboxylic acids Chemical class 0.000 claims 1
- 229910052760 oxygen Inorganic materials 0.000 claims 1
- 239000001301 oxygen Substances 0.000 claims 1
- 239000000463 material Substances 0.000 abstract description 11
- 230000000694 effects Effects 0.000 abstract description 6
- 238000005192 partition Methods 0.000 abstract description 5
- 238000011161 development Methods 0.000 abstract description 4
- 238000011065 in-situ storage Methods 0.000 abstract description 3
- 230000002269 spontaneous effect Effects 0.000 abstract description 3
- 238000011084 recovery Methods 0.000 abstract description 2
- 241000406668 Loxodonta cyclotis Species 0.000 abstract 1
- 229910001748 carbonate mineral Inorganic materials 0.000 abstract 1
- 239000012071 phase Substances 0.000 description 11
- 239000003643 water by type Substances 0.000 description 10
- RCEAADKTGXTDOA-UHFFFAOYSA-N OS(O)(=O)=O.CCCCCCCCCCCC[Na] Chemical group OS(O)(=O)=O.CCCCCCCCCCCC[Na] RCEAADKTGXTDOA-UHFFFAOYSA-N 0.000 description 6
- 238000010521 absorption reaction Methods 0.000 description 4
- 239000003513 alkali Substances 0.000 description 4
- 150000001732 carboxylic acid derivatives Chemical class 0.000 description 4
- 238000006243 chemical reaction Methods 0.000 description 4
- 238000004088 simulation Methods 0.000 description 4
- BHPQYMZQTOCNFJ-UHFFFAOYSA-N Calcium cation Chemical compound [Ca+2] BHPQYMZQTOCNFJ-UHFFFAOYSA-N 0.000 description 3
- 230000003213 activating effect Effects 0.000 description 3
- 229910001424 calcium ion Inorganic materials 0.000 description 3
- 238000002474 experimental method Methods 0.000 description 3
- 239000006210 lotion Substances 0.000 description 3
- 235000016068 Berberis vulgaris Nutrition 0.000 description 2
- 241000335053 Beta vulgaris Species 0.000 description 2
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 2
- DBMJMQXJHONAFJ-UHFFFAOYSA-M Sodium laurylsulphate Chemical compound [Na+].CCCCCCCCCCCCOS([O-])(=O)=O DBMJMQXJHONAFJ-UHFFFAOYSA-M 0.000 description 2
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 239000011575 calcium Substances 0.000 description 2
- 150000001768 cations Chemical group 0.000 description 2
- 238000006073 displacement reaction Methods 0.000 description 2
- 239000000839 emulsion Substances 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 230000001771 impaired effect Effects 0.000 description 2
- 239000011256 inorganic filler Substances 0.000 description 2
- 229910003475 inorganic filler Inorganic materials 0.000 description 2
- 238000006116 polymerization reaction Methods 0.000 description 2
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 description 1
- QGZKDVFQNNGYKY-UHFFFAOYSA-O Ammonium Chemical compound [NH4+] QGZKDVFQNNGYKY-UHFFFAOYSA-O 0.000 description 1
- KLSJPMIKRNWQOO-UHFFFAOYSA-N C(=O)O.C(=O)O.N[Na] Chemical compound C(=O)O.C(=O)O.N[Na] KLSJPMIKRNWQOO-UHFFFAOYSA-N 0.000 description 1
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 description 1
- GXGJIOMUZAGVEH-UHFFFAOYSA-N Chamazulene Chemical group CCC1=CC=C(C)C2=CC=C(C)C2=C1 GXGJIOMUZAGVEH-UHFFFAOYSA-N 0.000 description 1
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 1
- IAYPIBMASNFSPL-UHFFFAOYSA-N Ethylene oxide Chemical compound C1CO1 IAYPIBMASNFSPL-UHFFFAOYSA-N 0.000 description 1
- 240000007643 Phytolacca americana Species 0.000 description 1
- 239000005864 Sulphur Substances 0.000 description 1
- 244000269722 Thea sinensis Species 0.000 description 1
- NIXOWILDQLNWCW-UHFFFAOYSA-N acrylic acid group Chemical group C(C=C)(=O)O NIXOWILDQLNWCW-UHFFFAOYSA-N 0.000 description 1
- 150000001336 alkenes Chemical class 0.000 description 1
- 125000000217 alkyl group Chemical group 0.000 description 1
- 125000005211 alkyl trimethyl ammonium group Chemical group 0.000 description 1
- 125000005233 alkylalcohol group Chemical group 0.000 description 1
- 239000008346 aqueous phase Substances 0.000 description 1
- 239000012752 auxiliary agent Substances 0.000 description 1
- 230000031709 bromination Effects 0.000 description 1
- 238000005893 bromination reaction Methods 0.000 description 1
- 239000001110 calcium chloride Substances 0.000 description 1
- 229910001628 calcium chloride Inorganic materials 0.000 description 1
- 239000004568 cement Substances 0.000 description 1
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 239000003638 chemical reducing agent Substances 0.000 description 1
- 230000006835 compression Effects 0.000 description 1
- 238000007906 compression Methods 0.000 description 1
- 235000009508 confectionery Nutrition 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 239000006071 cream Substances 0.000 description 1
- 239000003431 cross linking reagent Substances 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 239000003599 detergent Substances 0.000 description 1
- MOTZDAYCYVMXPC-UHFFFAOYSA-N dodecyl hydrogen sulfate Chemical compound CCCCCCCCCCCCOS(O)(=O)=O MOTZDAYCYVMXPC-UHFFFAOYSA-N 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 239000003999 initiator Substances 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000178 monomer Substances 0.000 description 1
- 229940051841 polyoxyethylene ether Drugs 0.000 description 1
- 229920000056 polyoxyethylene ether Polymers 0.000 description 1
- 235000013406 prebiotics Nutrition 0.000 description 1
- 239000012744 reinforcing agent Substances 0.000 description 1
- 239000011347 resin Substances 0.000 description 1
- 229920005989 resin Polymers 0.000 description 1
- 238000007873 sieving Methods 0.000 description 1
- 239000011593 sulfur Substances 0.000 description 1
- 229910052717 sulfur Inorganic materials 0.000 description 1
- 239000000725 suspension Substances 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
-
- 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
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/584—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
-
- 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
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/588—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
-
- 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
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/38—Arrangements for separating materials produced by the well in the well
- E21B43/385—Arrangements for separating materials produced by the well in the well by reinjecting the separated materials into an earth formation in the same well
Landscapes
- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Organic Chemistry (AREA)
- Materials Engineering (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Geochemistry & Mineralogy (AREA)
- Physics & Mathematics (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- Colloid Chemistry (AREA)
Abstract
The present invention relates to a kind of water-in-oil emulsion interface packing system, preparation method and water-oil separating technique and application with self-reparing capability.It includes oily phase that the interface, which insulates system, aqueous surfactant solution and natural polymer aqueous solution, system is insulated by the way that environmental-friendly natural macromolecular material is prepared into water-in-oil emulsion interface of the density between crude oil and water, oil-water interfaces are delivered to by the way that gravity is spontaneous, and the ingenious condition of water quality using carbonate mineral reserve, chemical clapboard is formed in situ in oil-water interfaces, there is significant effect for the separation at oil-water interfaces, and the interface partition has self-repair function.The grease that separator material is formed by when can be effectively prevented carbonate fracture hole oil reservoir development improves the recovery ratio of crude oil with there is the generation of elephant.
Description
Technical field
The present invention relates to a kind of, and the water-in-oil emulsion interface with self-reparing capability insulates system, preparation method and grease
Separating technology and application, belong to field of oilfield chemistry.
Background technique
Carbonate Reservoir is one of In Oil Field Exploration And Development field important in the world, in the world in explored oil reservoir
Account for 52%.Carbonate reservoir is divided into pore type, crack-pore type and fracture hole type three types.The geology of fracture-pore reservoir
Feature and pore type and crack-pore type oil reservoir are widely different, and large-scale solution cavity and corrosion hole area, which are that fluid is main, to be preserved
Space.Due to the special geologic feature of fracture-pore reservoir, carrying out fracture-cavity units exploitation using positioning well or branch horizontal well is to have
The technical measures of effect, but in oil recovery process there is grease with go out the phenomenon that, cause production efficiency to be restricted, become restriction oil
The most important problem of well Efficient Development.
Chemical clapboard is formed in oil-water interfaces currently, having been reported in the prior art, come solve to occur in oil exploitation
The problem of grease is with going out.As Chinese patent literature CN1752172A is disclosed underground polymerization prepares inorganic filler type water absorption resin
Preparation process reacts at the formation temperature after reaction raw materials are injected underground, reaction raw materials composition are as follows: acrylamide list
Body, acrylic monomers, alkali, inorganic filler, crosslinking agent, initiator, auxiliary agent, eliminate polymerization on the ground, be granulated, be dry, sieving etc.
Process.Biggish swollen plug effect can occur after purpose of horizon water-swellable, be accordingly used in nearly well for product obtained by the invention
Water blockoff and bottom water coning chemical clapboard have preferable effect.But the used raw material of the invention is more, higher cost, it cannot be guaranteed that
Chemical clapboard is formed at oil-water interfaces, and the chemical clapboard formed is difficult to selfreparing Yi Dan destroyed.For another example, Chinese patent text
It offers CN102199418A and discloses the inorganic solidified system and its method for implanting of fractured-cavernous carbonate reservoir control bottom water coning,
Inorganic solidified system is by superfine cement, density adjusting agents, reinforcing agent, suspension dispersive agent, skeleton bridging agent, drag reducer and retarder
Composition, density are 1.06~1.09g/cm3；Method for implanting are as follows: prepare first and inject the relatively large nothing of density to stratum
Then machine curing system is prepared and is injected the relatively small inorganic solidified system of density, finally injected displacement fluid.The invention can
It is formed by curing partition near oil-water interfaces, improves bottom water oil displacement efficiency, improves the development effectiveness of fracture hole type bottom water reservoir.But it should
It invents raw materials used more, and injects stratum several times, required higher cost, and the chemical clapboard one formed in oil-water interfaces
Denier is difficult to selfreparing after destroying.
Current technology and method can not scale be used in oil exploitation, and the chemical clapboard formed in oil-water interfaces
It is difficult to selfreparing after impaired, limits the exploitation of fracture and vug carbonate reservoir.
Summary of the invention
In view of the deficiencies of the prior art, the present invention provides a kind of water-in-oil emulsion interface packer with self-reparing capability
System.Water-in-oil emulsion interface packer of the invention be it is at low cost, preparation method is simple, is delivered to by the way that gravity is spontaneous
After oil-water interfaces, chemical clapboard is formed in situ in oil-water interfaces, to grease in the ingenious condition of water quality using carbonate rock mineral reserve
Separation has significant effect, and the chemical clapboard has self-reparing capability after impaired because of external force.
The preparation method and oil for the water-in-oil emulsion interface packing system with self-reparing capability that the present invention also provides a kind of
Laden water separation process and application.
Technical scheme is as follows:
A kind of water-in-oil emulsion interface packing system with self-reparing capability, the raw material composition including following parts by weight:
Oily phase 4-40 parts；
2-18 parts of aqueous surfactant solution；
0.5-20 parts of natural polymer aqueous solution.
, according to the invention it is preferred to, the water-in-oil emulsion interface with self-reparing capability insulates system, including following
The raw material of parts by weight forms:
Oily phase 28-38 parts；
10-15 parts of aqueous surfactant solution；
2-15 parts of natural polymer aqueous solution.
, according to the invention it is preferred to, the oil is mutually one of dodecane, the tetradecane or hexadecane or a variety of groups
It closes.
, according to the invention it is preferred to, the surfactant is zwitterionic surfactant, anionic surfactant
Or two or more the combination in cationic surfactant.
Preferably, the surfactant is zwitterionic surfactant, anionic surfactant and cation form
The combination of face activating agent.
It is further preferred that the zwitterionic surfactant, anionic surfactant and cation surface activating
Agent mass ratio is 0.5-2:0.5-1.5:1；Preferably 0.9:0.6:1.
Preferably, the zwitterionic surfactant is betaine type amphoteric surfac-tant or amino acid type amphoteric table
One of face activating agent.
It is further preferred that the betaine type amphoteric surfac-tant be glycine betaine, Cetyl dimethyl betaine,
N- (octadecyl oxygen methine) dimethyl betaine or sulfuric ester glycine betaine；The amino acid type amphoteric surfactant is ten
Dialkyl group dimethylene amino sodium diformate, sodium dodecyl aminopropionitrile or Na- acyl-lysine.
Preferably, the cationic surfactant is dodecyl trimethyl ammonium bromide or cetyl trimethyl bromination
One of ammonium.
Preferably, the anionic surfactant is lauryl sodium sulfate, neopelex, poly alkyl alcohol
One of ethylene oxide ether sodium sulfate or AEO carboxylic acid sodium.
, according to the invention it is preferred to, in the aqueous surfactant solution mass concentration of surfactant be 0.1~
1.0%.
, according to the invention it is preferred to, the natural polymer is one of pectin, xanthan gum or alginate.
Preferably, the alginate is sodium alginate.
, according to the invention it is preferred to, the mass concentration of natural polymer is 0.5- in the natural polymer aqueous solution
2%.
, according to the invention it is preferred to, the density of the water-in-oil emulsion interface packing system is 0.7-1.0gcm-3。
The preparation method of the above-mentioned water-in-oil emulsion interface packing system with self-reparing capability, comprises the following steps that
(1) surfactant is dissolved in deionized water, stirs 20-40min persistently at room temperature to get surfactant water
Solution；
(2) natural polymer is dissolved in deionized water, is stirred 30-120 minutes at 25-40 DEG C, obtains natural polymer water
Solution；
(3) it is mutually mixed oily with aqueous surfactant solution, 20-40min is stirred at room temperature, obtains mixed liquor；Under stirring condition,
Natural polymer aqueous solution is added dropwise dropwise into mixed liquor and insulates system to get water-in-oil emulsion interface.
, according to the invention it is preferred to, drop rate described in step (3) is 0.1-0.3mL/min.
Using the water-oil separating technique of the above-mentioned water-in-oil emulsion interface packing system with self-reparing capability, including use
Water-in-oil emulsion interface of the invention insulates system, and steps are as follows:
Water-in-oil emulsion interface packing system is pumped into carbonate rock fractured cave type oil well, because density variation gravity gradient is driven
Dynamic, water-in-oil emulsion interface packer, which ties up in crude oil, migrates to oil-water interfaces downwards, and water-in-oil emulsion interface insulates system
In natural polymer in mineral reserve water crosslinking curing 2-8 hours under the induction of polyvalent metal ion, form chemical clapboard.
, according to the invention it is preferred to, the injection rate of the water-in-oil emulsion interface packing system is the mineral reserve of every 1m depth
1-2 times of the volume of water.
The above-mentioned water-in-oil emulsion interface packing system with self-reparing capability is opened applied to fracture and vug carbonate reservoir
Adopt the separation of middle grease.
It technical characterstic of the invention and has the beneficial effect that:
After water-in-oil emulsion interface packing system of the invention is pumped into crude oil, because density variation gravity gradient drives, cream
Liquid is migrated downwards, until after oil-water interfaces, the induction of natural polymer polyvalent metal ions such as calcium ion in mineral reserve water in lotion
Under, the presetting period elapses successively absorption, the crosslinking curing in 2-8 hours, the change of formation within 3 minutes, then as the time
Partition is learned steadily to be present at oil-water interfaces.
In water-in-oil emulsion interface packing system the effect of surfactant be reduce oil mutually and water phase interfacial tension and
Mixed system is set to reach stable；The natural polymer contained in system can be crosslinked with the calcium ion in mineral reserve water, thus
It is cross-linked into film on mineral reserve water and emulsion contacts face, is successively adsorbed, so that the partition to be formed be made to be stable in the presence of at oil-water interfaces.
Since the oily phase density of the invention used is in 0.74-0.78g cm-3Between, the density of aqueous phase solution is in 1g cm-3Left and right, so
The density of packing system in water-in-oil emulsion interface of the invention is between 0.7-1gcm-3Between.Water-in-oil emulsion interface insulates system
During moving down in crude oil, the natural polymer in lotion will not have loss under the protection of oily phase.
The chemical clapboard formed at oil-water interfaces, if upper layer water-in-oil emulsion interface insulates system because defect occurs for external force
It can be automatically replenished at once to notch, be acted on and crosslinking curing with polyvalent metal ions such as calcium ions in mineral reserve water, and then will be chemical
Partition reparation.
It has the beneficial effect that:
(1) the raw materials used in the present invention is less, and cost is relatively low；Raw material using natural polymer as separator material, green
Environmental protection.
(2) water-in-oil emulsion interface of the invention insulates system, and density is in 0.7-1.0g cm-3Between, it can be driven by gravity
It is dynamic, it is spontaneous to be migrated by oily opposite water phase, and ultimately reside at oil-water interfaces.At oil-water interfaces, the packing of water-in-oil emulsion interface
Natural macromolecular material in system can be with the Ca in mineral reserve water2+Equal polyvalent metal ions crosslink reaction, in grease circle
Separator material is formed at face, and is stable in the presence of interface, the advantage with in-situ preparation chemical clapboard.
(3) water-in-oil emulsion interface packer of the invention, which ties up to the separator material formed at oil-water interfaces, has selfreparing
Function, after forming a film at the oil-water interfaces, if the film is destroyed for some reason, extra water-in-oil emulsion interface insulates system meeting
It is automatically replenished rent at once, with the Ca in mineral reserve water2+Polyvalent metal ions further occurrence cross-linking reaction is waited to be repaired
It is multiple.
(4) separator material is formed by using water-in-oil emulsion interface packing system of the invention be resistant to 95 DEG C~120 DEG C
High temperature 10 days or more, heat-resisting quantity is preferable, and the compression strength of the separator material be 0.1-2.0MPa.The separator material it is close
Degree also insulates the consistent in density of system with water-in-oil emulsion interface.
Specific embodiment
The present invention is described further combined with specific embodiments below, but not limited to this.
Experimental method described in following embodiments is unless otherwise specified conventional method simultaneously；The reagent and material
Material, unless otherwise specified, commercially obtains.
Pectin used in embodiment, Yantai An Deli limited liability company are on sale；Sodium alginate, Qingdao prebiotic hall biology section
Skill Co., Ltd is on sale；Glycine betaine, Jinan Jin Hui Chemical Co., Ltd. are on sale.
Embodiment 1
A kind of water-in-oil emulsion interface packing system with self-reparing capability, the raw material composition including following parts by weight::
30 parts of oily phase；
Mass concentration is 10 parts of aqueous surfactant solution of 0.4%；
Mass concentration is 8 parts of aqueous pectin solution of 0.5%.
Wherein, oil is mutually the mixture of 15 parts of dodecane and 15 parts of hexadecane, and aqueous surfactant solution is 16
Alkyl trimethyl ammonium bromide, lauryl sodium sulfate, the mixed aqueous solution of glycine betaine, cetyl trimethylammonium bromide, 12
The mass ratio of sodium alkyl sulfate and glycine betaine is 1:1.5:1.7.
The preparation method of the above-mentioned water-in-oil emulsion interface packing system with self-reparing capability, comprises the following steps that
(1) by 0.0096 part of cetyl trimethylammonium bromide, 0.0144 part of lauryl sodium sulfate and 0.016 portion of beet
Alkali soluble stirs 30min persistently at room temperature in 9.96 parts of deionized waters to get aqueous surfactant solution；
(2) 1 part of pectin is added in 200 parts of deionized waters, is stirred 60 minutes at 25 DEG C, obtaining mass concentration is 0.5%
Aqueous pectin solution；
(3) 30 parts of oil are mutually mixed with 10 parts of aqueous surfactant solutions, 30min is stirred at room temperature, obtains mixed liquor；Stirring bar
Under part, 8 parts of natural polymer aqueous solutions are added dropwise dropwise into mixed liquor, 20min is dripped off, until solution is creamy white to get oil packet
Aqueous emulsion interface insulates system.
The density of the water-in-oil emulsion interface packing system of the present embodiment is 0.82g/cm3。
Embodiment 2
A kind of water-in-oil emulsion interface packing system with self-reparing capability, the raw material composition including following parts by weight:
30 parts of oily phase；
Mass concentration is 10 parts of aqueous surfactant solution of 0.7%；
Mass concentration is 3 parts of sodium alginate aqueous solution of 1%.
Wherein, oil is mutually dodecane, and aqueous surfactant solution is dodecyl trimethyl ammonium bromide, detergent alkylate sulphur
Sour sodium, the mixed aqueous solution of glycine betaine, dodecyl trimethyl ammonium bromide, the mass ratio of neopelex and glycine betaine
For 1:0.6:0.9.
The preparation method of the above-mentioned water-in-oil emulsion interface packing system with self-reparing capability, comprises the following steps that
(1) by 0.028 part of dodecyl trimethyl ammonium bromide, 0.0168 part of neopelex and 0.0252 part of sweet tea
Dish alkali soluble stirs 30min persistently at room temperature in 9.93 parts of deionized waters to get aqueous surfactant solution；
(2) 1 part of sodium alginate is added in 100 parts of deionized waters, is stirred 100 minutes at 25 DEG C, obtaining mass concentration is
1% sodium alginate aqueous solution
(3) 30 parts of oil are mutually mixed with 10 parts of aqueous surfactant solutions, 30min is stirred at room temperature, obtains mixed liquor；Stirring bar
Under part, 3 parts of sodium alginate aqueous solutions are added dropwise dropwise into mixed liquor, 10min is dripped off, until solution is creamy white to get Water-In-Oil
Emulsion interface insulates system.
The density of the water-in-oil emulsion interface packing system of the present embodiment is 0.78g/cm3。
Embodiment 3
A kind of water-in-oil emulsion interface packing system with self-reparing capability, the raw material composition including following parts by weight:
30 parts of oily phase；
Mass concentration is 10 parts of aqueous surfactant solution of 0.5%；
Mass concentration is 10 parts of sodium alginate aqueous solution of 0.7%.
Wherein, oil is mutually hexadecane, and aqueous surfactant solution is cetyl trimethylammonium bromide, fatty alcohol polyoxy second
Alkene ether carboxylic acid sodium, the mixed aqueous solution of dodecyl dimethylene amino sodium diformate, cetyl trimethylammonium bromide, fat
The mass ratio of alcohol polyoxyethylene ether carboxylic acid sodium and dodecyl dimethylene amino sodium diformate is 1:0.6:0.9.
The preparation method of the above-mentioned water-in-oil emulsion interface packing system with self-reparing capability, comprises the following steps that
(1) by 0.020 part of cetyl trimethylammonium bromide, 0.012 part of AEO carboxylic acid sodium and 0.018
Part dodecyl dimethylene amino sodium diformate is dissolved in 9.95 parts of deionized waters, stirs 30min persistently at room temperature to get table
Face aqueous surfactant solutions；
(2) 1 part of sodium alginate is added in 140 parts of deionized waters, is stirred 100 minutes at 25 DEG C, obtaining mass concentration is
0.7% sodium alginate aqueous solution
(3) 30 parts of oil are mutually mixed with 10 parts of aqueous surfactant solutions, 30min is stirred at room temperature, obtains mixed liquor；Stirring bar
Under part, 10 parts of sodium alginate aqueous solutions are added dropwise dropwise into mixed liquor, 10min is dripped off, until solution is creamy white to get Water-In-Oil
Emulsion interface insulates system.
The density of the water-in-oil emulsion interface packing system of the present embodiment is 0.76g/cm3。
Embodiment 4
A kind of water-in-oil emulsion interface packing system with self-reparing capability, the raw material composition including following parts by weight:
30 parts of oily phase；
Mass concentration is 10 parts of aqueous surfactant solution of 0.6%；
Mass concentration is 3 parts of aqueous pectin solution of 0.9%.
Wherein, oil is mutually dodecane, and aqueous surfactant solution is cetyl trimethylammonium bromide, dodecyl sulphate
Sodium, the mixed aqueous solution of glycine betaine, the mass ratio 1 of cetyl trimethylammonium bromide, lauryl sodium sulfate and glycine betaine:
0.6:0.9。
The preparation method of the above-mentioned water-in-oil emulsion interface packing system with self-reparing capability, comprises the following steps that
(1) by 0.024 part of cetyl trimethylammonium bromide, 0.0144 part of lauryl sodium sulfate and 0.0216 portion of beet
Alkali soluble stirs 30min persistently at room temperature in 9.94 parts of deionized waters to get aqueous surfactant solution；
(2) 1 part of pectin is added in 110 parts of deionized waters, is stirred 100 minutes at 25 DEG C, obtaining mass concentration is 0.9%
Aqueous pectin solution；
(3) 30 parts of oil are mutually mixed with 10 parts of aqueous surfactant solutions, 30min is stirred at room temperature, obtains mixed liquor；Stirring bar
Under part, 3 parts of aqueous pectin solutions are added dropwise dropwise into mixed liquor, 5min is dripped off, until solution is creamy white to get water-in-oil emulsion circle
Face insulates system.
The density of the water-in-oil emulsion interface packing system of the present embodiment is 0.73g/cm3。
Embodiment 5
A kind of water-in-oil emulsion interface packing system with self-reparing capability, the raw material composition including following parts by weight:
36 parts of oily phase；
Mass concentration is 12 parts of aqueous surfactant solution of 0.3%；
Mass concentration is 15 parts of aqueous pectin solution of 0.6%.
Wherein, oil is mutually the tetradecane, and aqueous surfactant solution is dodecyl trimethyl ammonium bromide, dodecyl sulphate
Sodium, the mixed aqueous solution of dodecyl dimethylene amino sodium diformate, dodecyl trimethyl ammonium bromide, dodecyl sulphate
The mass ratio of sodium and dodecyl dimethylene amino sodium diformate is 1:0.6:0.9.
The preparation method of the above-mentioned water-in-oil emulsion interface packing system with self-reparing capability, comprises the following steps that
(1) by 0.012 part of dodecyl trimethyl ammonium bromide, 0.0072 part of lauryl sodium sulfate and 0.0108 part 12
Alkyl dimethylene amino sodium diformate is dissolved in 9.97 parts of deionized waters, stirs 30min persistently at room temperature to get surface-active
Agent aqueous solution；
(2) 1 part of pectin is added in 170 parts of deionized waters, is stirred 120 minutes at 25 DEG C, obtaining mass concentration is 0.6%
Aqueous pectin solution
(3) 36 parts of oil are mutually mixed with 12 parts of aqueous surfactant solutions, 30min is stirred at room temperature, obtains mixed liquor；Stirring bar
Under part, 15 parts of aqueous pectin solutions are added dropwise dropwise into mixed liquor, 20min is dripped off, until solution is creamy white to get water-in-oil emulsion
Interface insulates system.
The density of the water-in-oil emulsion interface packing system of the present embodiment is 0.75g/cm3。
Application examples 1
Water-oil separating simulation is carried out in laboratory conditions using water-in-oil emulsion interface packer system prepared by embodiment 2
Experiment.
Take a clean, volume for the graduated cylinder simulation oil well of 2L, upper layer is the crude oil of 800mL, and crude oil temperature is 90 DEG C, used
Crude oil comes from ground crude oil, density 0.68g/cm3, the content of wax (5.3%), low sulfur-bearing (0.1%)；Lower layer is the mineral reserve of 200mL
Water, the calcium chloride water that mineral reserve hydromining is prepared from laboratory, density 1.046g/cm3。
Water-oil separating technique is as follows: the water-in-oil emulsion interface packing system of 200mL being added in crude oil, because of density variation
Gravity gradient driving, water-in-oil emulsion interface packing system are migrated to oil-water interfaces downwards, water-in-oil emulsion interface packer
Natural polymer in the system crosslinking curing under the induction of polyvalent metal ion in mineral reserve water, the presetting period within 1 minute, so
Successively absorption as time goes by afterwards, forms chemical clapboard at oil-water interfaces in 3 hours.
Being formed by chemical clapboard can be stable in the presence of at oil-water interfaces, the time of at least one month.
Chemical clapboard will be formed by with a clean iron wire to poke, upper layer lotion can be automatically replenished at once will to notch
Chemical clapboard reparation.
Application examples 2
Water-oil separating simulation is carried out in laboratory conditions using water-in-oil emulsion interface packer system prepared by embodiment 4
Experiment, simulation oil well structure is identical as application examples 1, the difference is that crude oil temperature is 120 DEG C.
Water-oil separating technique is as follows: the water-in-oil emulsion interface packing system of 200mL is added in 120 DEG C of crude oil, because
The driving of density variation gravity gradient, water-in-oil emulsion interface packing system are migrated to oil-water interfaces downwards, water-in-oil emulsion circle
Natural polymer in the face packing system crosslinking curing under the induction of polyvalent metal ion in mineral reserve water, the presetting period is at 2 points
Within clock, successively absorption is elapsed then as the time, forms chemical clapboard in 4 hours at oil-water interfaces.
Being formed by chemical clapboard can be stable in the presence of at oil-water interfaces 10 days or more, illustrate that the chemical clapboard to be formed has
Good heat resistance.
Claims (8)
1. a kind of water-in-oil emulsion interface with self-reparing capability insulates system, which is characterized in that including following parts by weight
Raw material composition:
Oily phase 4-40 parts；
2-18 parts of aqueous surfactant solution；
0.5-20 parts of natural polymer aqueous solution；
The oil is mutually one of dodecane, the tetradecane or hexadecane or a variety of combinations；
The surfactant is the group of zwitterionic surfactant, anionic surfactant and cationic surfactant
It closes；The zwitterionic surfactant, anionic surfactant and cationic surfactant mass ratio are 0.5-2:
0.5-1.5:1；The zwitterionic surfactant is that betaine type amphoteric surfac-tant or amino acid type amphoteric surface are living
One of property agent；The betaine type amphoteric surfac-tant is glycine betaine, Cetyl dimethyl betaine, N- (18
Alkyl oxygen methine) dimethyl betaine or sulfuric ester glycine betaine；The amino acid type amphoteric surfactant is dodecyl
Dimethylene amino sodium diformate, sodium dodecyl aminopropionitrile or Na- acyl-lysine；The cationic surfactant is
One of dodecyl trimethyl ammonium bromide or cetyl trimethylammonium bromide；The anionic surfactant is 12
In sodium alkyl sulfate, neopelex, sodium sulfate of polyethenoxy ether of fatty alcohol or AEO carboxylic acid sodium
One kind；The mass concentration of surfactant is 0.1~1.0% in the aqueous surfactant solution；
The natural polymer is one of pectin, xanthan gum or alginate；It is natural in the natural polymer aqueous solution
High molecular mass concentration is 0.5-2%；
The density of the water-in-oil emulsion interface packing system is 0.7-1.0gcm-3。
2. the water-in-oil emulsion interface according to claim 1 with self-reparing capability insulates system, which is characterized in that institute
Water-in-oil emulsion interface packing system is stated, the raw material composition including following parts by weight:
Oily phase 28-38 parts；
10-15 parts of aqueous surfactant solution；
2-15 parts of natural polymer aqueous solution.
3. the water-in-oil emulsion interface according to claim 1 with self-reparing capability insulates system, which is characterized in that institute
Stating zwitterionic surfactant, anionic surfactant and cationic surfactant mass ratio is 0.9:0.6:1.
4. the water-in-oil emulsion interface according to claim 1 with self-reparing capability insulates system, which is characterized in that institute
Stating alginate is sodium alginate.
5. the preparation side of the water-in-oil emulsion interface packing system according to any one of claims 1-4 with self-reparing capability
Method comprises the following steps that
(1) surfactant is dissolved in deionized water, persistently stirring 20-40min is water-soluble to get surfactant at room temperature
Liquid；
(2) natural polymer is dissolved in deionized water, is stirred 30-120 minutes at 25-40 DEG C, obtains natural polymer aqueous solution；
(3) it is mutually mixed oily with aqueous surfactant solution, 20-40min is stirred at room temperature, obtains mixed liquor；Under stirring condition, to mixed
It closes and natural polymer aqueous solution is added dropwise in liquid dropwise to get water-in-oil emulsion interface packing system.
6. utilizing the grease point of the water-in-oil emulsion interface packing system described in any one of claim 1-4 with self-reparing capability
Separating process comprises the following steps that
Water-in-oil emulsion interface packing system is pumped into carbonate rock fractured cave type oil well, because density variation gravity gradient drives,
Water-in-oil emulsion interface packer, which ties up in crude oil, migrates to oil-water interfaces downwards, in water-in-oil emulsion interface packing system
Natural polymer crosslinking curing 2-8 hours under the induction of polyvalent metal ion, forms chemical clapboard in mineral reserve water.
7. the water-oil separating work of the water-in-oil emulsion interface packing system according to claim 6 with self-reparing capability
Skill, which is characterized in that the injection rate of the water-in-oil emulsion interface packing system is the 1-2 of the volume of the mineral reserve water of every 1m depth
Times.
8. the water-in-oil emulsion interface packing system according to any one of claims 1-4 with self-reparing capability is applied to carbon
The separation of grease in the exploitation of Carbonate Rocks fracture-pore reservoir.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710383528.5A CN107057671B (en) | 2017-05-26 | 2017-05-26 | A kind of water-in-oil emulsion interface packing system, preparation method and water-oil separating technique and application with self-reparing capability |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710383528.5A CN107057671B (en) | 2017-05-26 | 2017-05-26 | A kind of water-in-oil emulsion interface packing system, preparation method and water-oil separating technique and application with self-reparing capability |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN107057671A CN107057671A (en) | 2017-08-18 |
| CN107057671B true CN107057671B (en) | 2019-09-27 |
Family
ID=59609920
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201710383528.5A Expired - Fee Related CN107057671B (en) | 2017-05-26 | 2017-05-26 | A kind of water-in-oil emulsion interface packing system, preparation method and water-oil separating technique and application with self-reparing capability |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN107057671B (en) |
Families Citing this family (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112940701B (en) * | 2021-01-27 | 2024-06-07 | 河北光大石化有限公司 | High-rheological continuous phase profile control agent and preparation method thereof |
| CN113403045B (en) * | 2021-06-29 | 2023-03-21 | 中国石油大学(华东) | Water-in-oil type self-adaptive polymer emulsion profile control system and preparation method and application thereof |
| CN116332556B (en) * | 2023-05-31 | 2023-08-04 | 天津大学 | Self-repairing system for water-adaptive cement, and preparation method and application thereof |
Family Cites Families (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US8871695B2 (en) * | 2007-04-25 | 2014-10-28 | Baker Hughes Incorporated | In situ microemulsions used as spacer fluids |
| CN102199418B (en) * | 2011-03-11 | 2013-04-10 | 中国石油大学(华东) | Inorganic solidifying system for controlling bottom water coning in fracture-cavity karst reservoir, and injection method thereof |
| US8763705B2 (en) * | 2011-03-25 | 2014-07-01 | Schlumberger Technology Corporation | Compositions and methods for cleaning a wellbore prior to cementing |
| CN102766447B (en) * | 2012-08-10 | 2014-03-12 | 天津梅森科技有限公司 | Oil well cement efficient spacer fluid and using method thereof |
| CN103045210B (en) * | 2013-01-18 | 2015-06-17 | 中国石油化工股份有限公司 | High-efficiency plugging oil-base drilling fluid and preparation method thereof |
| CN104962251B (en) * | 2015-06-11 | 2018-07-20 | 中国石油集团川庆钻探工程有限公司工程技术研究院 | A kind of microemulsion film forming blocks drilling fluid and preparation method |
-
2017
- 2017-05-26 CN CN201710383528.5A patent/CN107057671B/en not_active Expired - Fee Related
Also Published As
| Publication number | Publication date |
|---|---|
| CN107057671A (en) | 2017-08-18 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN107057671B (en) | A kind of water-in-oil emulsion interface packing system, preparation method and water-oil separating technique and application with self-reparing capability | |
| CA2327744C (en) | A foam drive method | |
| CA1103008A (en) | Treatment of clay formations with organic polycationic polymers | |
| CN102587858B (en) | Method for blocking water for fracture and hole type reservoir | |
| CN107227147B (en) | Foaming agent and foam gas flooding method | |
| CN104059625B (en) | Method for preparing high-stability heat-resistance and salt-tolerance air foam oil displacing agent | |
| CN106170527A (en) | For producing the method and system in high flow conductivity crack | |
| RU2536722C2 (en) | Hydrocarbon production method with pressure maintenance in fractured reservoirs | |
| CN106318358B (en) | A kind of environmental type foam flooding system and the preparation method and application thereof based on alkyl glycosides | |
| EA006813B1 (en) | Compositions and methods for treating a subterranean formation | |
| CN104087275A (en) | High-temperature-resistant and high-salt-resistant fine gel particle as profile control agent as well as preparation method and application of fine gel particle | |
| CN103224777A (en) | Weak-base ternary composite oil displacement composition compounded with surfactant and application thereof | |
| CN109653721A (en) | A kind of saturating oil reservoir pressure break energization displacement of reservoir oil integrated technique of shallow-layer low pressure and low permeability | |
| CN103509544B (en) | A kind of foamed acid and preparation and application thereof | |
| CN106188403A (en) | A kind of anti-CO of high temperature and high salt oil deposit2has channeling blocking agent and preparation method thereof | |
| CN106317321A (en) | Composition used for preparing downhole cross-linked complex gel and cross-linked complex gel prepared thereby | |
| CA2878603A1 (en) | Enhanced oil recovery fluid containing a sacrificial agent | |
| CN109281643A (en) | Delay spontaneous hot system and preparation method thereof | |
| US7374371B2 (en) | Process and composition for forming an earthen hardpan | |
| CN106967406A (en) | A kind of oil displacement system and flooding method for heterogeneous reservoir | |
| US20120285691A1 (en) | Permeability modification and water shut off composition and process | |
| CA1230960A (en) | Modified waterflood technique for enhanced hydrocarbon recovery from argillaceous subterranean reservoirs | |
| Qing et al. | Study and application of gelled foam for in-depth water shutoff in a fractured oil reservoir | |
| CN105385429A (en) | Heterogeneous system for oil displacement or profile control of heterogeneous reservoirs and preparation method for heterogeneous system | |
| CN105199693B (en) | A kind of oil base gel leak stopping slurry |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant | ||
| CF01 | Termination of patent right due to non-payment of annual fee |
Granted publication date: 20190927 |