CN107384346A - A kind of hypertonic sandstone oil reservoir Complex polymer type profile control agent and its application method - Google Patents
A kind of hypertonic sandstone oil reservoir Complex polymer type profile control agent and its application method Download PDFInfo
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- CN107384346A CN107384346A CN201710663636.8A CN201710663636A CN107384346A CN 107384346 A CN107384346 A CN 107384346A CN 201710663636 A CN201710663636 A CN 201710663636A CN 107384346 A CN107384346 A CN 107384346A
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- 229920000642 polymer Polymers 0.000 title claims abstract description 72
- 238000000034 method Methods 0.000 title claims abstract description 22
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 99
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 98
- 238000002347 injection Methods 0.000 claims abstract description 30
- 239000007924 injection Substances 0.000 claims abstract description 30
- 238000002360 preparation method Methods 0.000 claims abstract description 27
- 229920002401 polyacrylamide Polymers 0.000 claims abstract description 25
- 239000004927 clay Substances 0.000 claims abstract description 23
- 239000000654 additive Substances 0.000 claims abstract description 15
- 230000000996 additive effect Effects 0.000 claims abstract description 15
- 238000013329 compounding Methods 0.000 claims abstract description 4
- 238000002156 mixing Methods 0.000 claims abstract description 4
- 239000000203 mixture Substances 0.000 claims abstract description 3
- 239000003921 oil Substances 0.000 claims description 91
- WYYQVWLEPYFFLP-UHFFFAOYSA-K chromium(3+);triacetate Chemical compound [Cr+3].CC([O-])=O.CC([O-])=O.CC([O-])=O WYYQVWLEPYFFLP-UHFFFAOYSA-K 0.000 claims description 26
- GHMLBKRAJCXXBS-UHFFFAOYSA-N resorcinol Chemical compound OC1=CC=CC(O)=C1 GHMLBKRAJCXXBS-UHFFFAOYSA-N 0.000 claims description 24
- 239000003381 stabilizer Substances 0.000 claims description 15
- 235000010299 hexamethylene tetramine Nutrition 0.000 claims description 14
- VKYKSIONXSXAKP-UHFFFAOYSA-N hexamethylenetetramine Chemical compound C1N(C2)CN3CN1CN2C3 VKYKSIONXSXAKP-UHFFFAOYSA-N 0.000 claims description 14
- 229960004011 methenamine Drugs 0.000 claims description 14
- 235000013162 Cocos nucifera Nutrition 0.000 claims description 13
- 244000060011 Cocos nucifera Species 0.000 claims description 13
- 235000014113 dietary fatty acids Nutrition 0.000 claims description 13
- 239000000194 fatty acid Substances 0.000 claims description 13
- 229930195729 fatty acid Natural products 0.000 claims description 13
- 150000004665 fatty acids Chemical class 0.000 claims description 13
- 238000004519 manufacturing process Methods 0.000 claims description 12
- 239000004094 surface-active agent Substances 0.000 claims description 11
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims description 10
- 229910052760 oxygen Inorganic materials 0.000 claims description 10
- 239000001301 oxygen Substances 0.000 claims description 10
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 claims description 8
- 238000003756 stirring Methods 0.000 claims description 8
- 239000010865 sewage Substances 0.000 claims description 7
- -1 perfluoroalkyl betain Chemical compound 0.000 claims description 5
- 238000012545 processing Methods 0.000 claims description 5
- 235000019270 ammonium chloride Nutrition 0.000 claims description 4
- 229920003023 plastic Polymers 0.000 claims description 4
- 239000004033 plastic Substances 0.000 claims description 4
- 230000003213 activating effect Effects 0.000 claims description 2
- 238000013461 design Methods 0.000 claims description 2
- DDXLVDQZPFLQMZ-UHFFFAOYSA-M dodecyl(trimethyl)azanium;chloride Chemical compound [Cl-].CCCCCCCCCCCC[N+](C)(C)C DDXLVDQZPFLQMZ-UHFFFAOYSA-M 0.000 claims description 2
- 230000007062 hydrolysis Effects 0.000 claims description 2
- 238000006460 hydrolysis reaction Methods 0.000 claims description 2
- 229910001220 stainless steel Inorganic materials 0.000 claims description 2
- 239000010935 stainless steel Substances 0.000 claims description 2
- 230000003068 static effect Effects 0.000 claims description 2
- 150000001412 amines Chemical class 0.000 claims 1
- 238000011084 recovery Methods 0.000 abstract description 20
- 230000035699 permeability Effects 0.000 abstract description 13
- 230000008569 process Effects 0.000 abstract description 5
- 230000008961 swelling Effects 0.000 abstract description 5
- 239000000126 substance Substances 0.000 abstract description 4
- 238000012546 transfer Methods 0.000 abstract description 3
- 239000002994 raw material Substances 0.000 abstract description 2
- 235000019198 oils Nutrition 0.000 description 80
- 239000011435 rock Substances 0.000 description 54
- 238000005086 pumping Methods 0.000 description 21
- 238000002474 experimental method Methods 0.000 description 18
- 238000006073 displacement reaction Methods 0.000 description 15
- 230000000694 effects Effects 0.000 description 15
- 238000007789 sealing Methods 0.000 description 12
- 239000010779 crude oil Substances 0.000 description 9
- 238000012360 testing method Methods 0.000 description 9
- 238000001816 cooling Methods 0.000 description 6
- 238000001035 drying Methods 0.000 description 6
- 238000011156 evaluation Methods 0.000 description 6
- 238000011017 operating method Methods 0.000 description 6
- 239000002352 surface water Substances 0.000 description 6
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 5
- 238000004458 analytical method Methods 0.000 description 5
- UIIMBOGNXHQVGW-UHFFFAOYSA-M Sodium bicarbonate Chemical compound [Na+].OC([O-])=O UIIMBOGNXHQVGW-UHFFFAOYSA-M 0.000 description 4
- 150000001408 amides Chemical class 0.000 description 4
- 238000004088 simulation Methods 0.000 description 4
- MPNXSZJPSVBLHP-UHFFFAOYSA-N 2-chloro-n-phenylpyridine-3-carboxamide Chemical compound ClC1=NC=CC=C1C(=O)NC1=CC=CC=C1 MPNXSZJPSVBLHP-UHFFFAOYSA-N 0.000 description 3
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 description 3
- 239000006004 Quartz sand Substances 0.000 description 3
- YCIMNLLNPGFGHC-UHFFFAOYSA-N catechol Chemical compound OC1=CC=CC=C1O YCIMNLLNPGFGHC-UHFFFAOYSA-N 0.000 description 3
- 238000011161 development Methods 0.000 description 3
- 230000018109 developmental process Effects 0.000 description 3
- 239000003814 drug Substances 0.000 description 3
- 239000003822 epoxy resin Substances 0.000 description 3
- 230000001965 increasing effect Effects 0.000 description 3
- 229920000647 polyepoxide Polymers 0.000 description 3
- BVKZGUZCCUSVTD-UHFFFAOYSA-M Bicarbonate Chemical compound OC([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-M 0.000 description 2
- BHPQYMZQTOCNFJ-UHFFFAOYSA-N Calcium cation Chemical compound [Ca+2] BHPQYMZQTOCNFJ-UHFFFAOYSA-N 0.000 description 2
- 241000370738 Chlorion Species 0.000 description 2
- 241000237858 Gastropoda Species 0.000 description 2
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 2
- JLVVSXFLKOJNIY-UHFFFAOYSA-N Magnesium ion Chemical compound [Mg+2] JLVVSXFLKOJNIY-UHFFFAOYSA-N 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 230000000903 blocking effect Effects 0.000 description 2
- 229910001424 calcium ion Inorganic materials 0.000 description 2
- 230000008859 change Effects 0.000 description 2
- 239000003153 chemical reaction reagent Substances 0.000 description 2
- 235000019864 coconut oil Nutrition 0.000 description 2
- 239000003240 coconut oil Substances 0.000 description 2
- 235000019197 fats Nutrition 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 150000002500 ions Chemical class 0.000 description 2
- 229910001425 magnesium ion Inorganic materials 0.000 description 2
- 230000007246 mechanism Effects 0.000 description 2
- 230000002093 peripheral effect Effects 0.000 description 2
- BITYAPCSNKJESK-UHFFFAOYSA-N potassiosodium Chemical compound [Na].[K] BITYAPCSNKJESK-UHFFFAOYSA-N 0.000 description 2
- 239000004576 sand Substances 0.000 description 2
- 229910000030 sodium bicarbonate Inorganic materials 0.000 description 2
- 239000000725 suspension Substances 0.000 description 2
- 230000010148 water-pollination Effects 0.000 description 2
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 1
- VYZAMTAEIAYCRO-UHFFFAOYSA-N Chromium Chemical compound [Cr] VYZAMTAEIAYCRO-UHFFFAOYSA-N 0.000 description 1
- 241000196324 Embryophyta Species 0.000 description 1
- 101150042248 Mgmt gene Proteins 0.000 description 1
- IGFHQQFPSIBGKE-UHFFFAOYSA-N Nonylphenol Natural products CCCCCCCCCC1=CC=C(O)C=C1 IGFHQQFPSIBGKE-UHFFFAOYSA-N 0.000 description 1
- 239000004743 Polypropylene Substances 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000011575 calcium Substances 0.000 description 1
- 229910052791 calcium Inorganic materials 0.000 description 1
- 239000013043 chemical agent Substances 0.000 description 1
- 238000009388 chemical precipitation Methods 0.000 description 1
- 229910052804 chromium Inorganic materials 0.000 description 1
- 239000011651 chromium Substances 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 239000012153 distilled water Substances 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 239000002552 dosage form Substances 0.000 description 1
- 235000013399 edible fruits Nutrition 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 239000004519 grease Substances 0.000 description 1
- JEGUKCSWCFPDGT-UHFFFAOYSA-N h2o hydrate Chemical compound O.O JEGUKCSWCFPDGT-UHFFFAOYSA-N 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- SNQQPOLDUKLAAF-UHFFFAOYSA-N nonylphenol Chemical compound CCCCCCCCCC1=CC=CC=C1O SNQQPOLDUKLAAF-UHFFFAOYSA-N 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 229920001155 polypropylene Polymers 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 239000003079 shale oil Substances 0.000 description 1
- 235000017557 sodium bicarbonate Nutrition 0.000 description 1
- 230000001629 suppression Effects 0.000 description 1
Classifications
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5083—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5086—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
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- 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
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
-
- 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
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
- E21B37/06—Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting, e.g. eliminating, the deposition of paraffins or like substances
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- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- General Chemical & Material Sciences (AREA)
- Curing Cements, Concrete, And Artificial Stone (AREA)
Abstract
A kind of hypertonic sandstone oil reservoir Complex polymer type profile control agent and its application method, are related to field use chemical field.The present invention forms Complex polymer by mixing the partially hydrolyzed polyacrylamide (PHPA) of three kinds of different molecular quality, mix Complex polymer and additive forms profile control agent, by adjusting the ratio of partially hydrolyzed polyacrylamide (PHPA) and additive, so as to prepare the profile control agent slug of two kinds of different qualities；In implementation process, closure is implemented to hypertonic sandstone oil reservoir high permeability area, macropore by preposed attributives, rearmounted slug implements transfer drive, and the hypertonic sandstone oil reservoir of tradition is poly- to be driven low recovery ratio, invalid poly- drive circulation, clay swelling, suppress the problems such as region of bypassed oil generates to solve；Profile control agent compounding method of the present invention is simple, the low easily injection of viscosity before curing, is suitable for salinity 500mg/L 35000mg/L preparation water, and raw material is cheap and easy to get.
Description
Technical field
The present invention relates to a kind of hypertonic sandstone oil reservoir Complex polymer type profile control agent and its application method, the profile control agent to change
Kind reservoir adaptability, and then hypertonic sandrock-type oil reservoir oil increasing effect can be improved, belong to field use chemical agent field.
Background technology
In recent years, polymer displacement of reservoir oil tech has carried out large-scale application in the oil field such as grand celebration, triumph, Xinjiang and Bohai Sea at home
And field test, obvious oil increasing precipitation effect is obtained, techno-economic effect is very notable.But sent out in polymer flooding practice
Existing, for hypertonic sandstone oil reservoir, recovery percent of reserves is relatively low, and it is less efficient to show that polymer is applied to hypertonic sandstone oil reservoir；Hypertonic sand
Shale oil is hidden because oil-layer distribution is complicated, has following drawback during actual development：
1st, permeability gradually reduces in hypertonic sandstone oil reservoir recovery process, and its main cause is clay particulate in production process
The mobile blocking to reservoir pore, blocked up caused by the chemical precipitation of fouling and calcium, iron as caused by reservoir pressure, temperature change
Plug etc., it is big to result in hypertonic sandstone oil reservoir water injection pressure, and unplugged duct easily forms channelling, has a strong impact on that oil field development is imitated
Benefit.
2nd, during hypertonic sandstone oil reservoir waterflooding extraction, due to the anisotropism of oil reservoir, cause to inject water along Thief zone
Layer band or duct channelling, advance by leaps and bounds, seriously reduce the swept volume of injection water and the development effectiveness in oil field.
3rd, preferable oil displacement efficiency is being generally unattainable with polymer flooding at present, when polymer viscosity is low, often gone out
Existing invalid poly- drive is circulated, when polymer viscosity is high, it may appear that closure excessively tightly causes water injection pressure too high；And traditional poly- drive
Recover the oil in hypertonic sandstone oil reservoir, it is difficult to overcome and shake out and phenomena such as clay swelling.
4th, region of bypassed oil branch is more, during conventional water drive, because most of displacing fluid flows through high permeability zone band, result in
Intake profile branch is uneven, and affected area does not gradually form region of bypassed oil to displacing fluid, has a strong impact on hypertonic sandstone oil reservoir exploitation effect
Fruit.
Recovery efficiency technique demand is improved for hypertonic sandstone oil reservoir, the present invention proposes a kind of Complex polymer type profile control agent,
The problem of overcoming above-mentioned hypertonic sandstone oil reservoir.
The content of the invention
It is an object of the invention to provide a kind of hypertonic sandstone oil reservoir Complex polymer type profile control agent and its application method, leads to
The partially hydrolyzed polyacrylamide (PHPA) for crossing three kinds of different molecular quality of mixing forms Complex polymer, mixes Complex polymer and addition
Dosage form is into profile control agent, by adjusting the ratio of partially hydrolyzed polyacrylamide (PHPA) and additive, so as to prepare two kinds of different qualities
Profile control agent slug；In implementation process, closure is implemented to hypertonic sandstone oil reservoir high permeability area, macropore by preposed attributives, it is rearmounted
Slug implements transfer drive, and to solve, the hypertonic sandstone oil reservoir of tradition is poly- to drive low recovery ratio, invalid poly- drive circulation, clay swelling, suppression
The problems such as region of bypassed oil generates；Profile control agent compounding method of the present invention is simple, the low easily injection of viscosity before plastic, is suitable for salinity
500mg/L-35000mg/L preparation water, and raw material is cheap and easy to get.
To reach above-mentioned purpose, the present invention adopts the following technical scheme that.
A kind of hypertonic sandstone oil reservoir Complex polymer type profile control agent, its main component are：Partially hydrolyzed polyacrylamide (PHPA) phase
It is respectively 500*10 to molecular mass4、1000*104、2500*104, chromium acetate, methenamine, clay stabilizer, resorcinol,
Cocoanut fatty acid diethanolamide, surfactant；Wherein clay stabilizer concretely ammonium chloride, trimethyl
Ammonium chloride and other be applicable with the clay stabilizer of hypertonic sandstone oil reservoir, surfactant include NPE,
Neopelex and perfluoroalkyl betain；For hypertonic sandstone oil reservoir, double slug formula profile control agents are designed, by preposition
Slug blocks to hypertonic sandstone oil reservoir, and rearmounted slug carries out the poly- drive of low viscosity, represents preposed attributives with slug A profile control agents below,
Slug B profile control agents represent rearmounted slug to be described.
Slug A profile control agents include Complex polymer and additive；Wherein, Complex polymer is by three kinds of different molecular quality
Partially hydrolyzed polyacrylamide (PHPA) forms, and molecular mass is respectively 500*104、1000*104、2500*104, its mass ratio is 20：
35：45；Additive includes chromium acetate, methenamine, resorcinol, cocoanut fatty acid diethanolamide；Slug A profile control agents
In, Complex polymer mass ratio is 0.25%-0.35%, and chromium acetate mass ratio is 0.04%-0.055%, methenamine quality
Than for 0.02%-0.03%, resorcinol mass ratio is 0.04%-0.06%, cocoanut fatty acid diethanolamide mass ratio
For 0.05%-0.08%, remaining components are preparation water.
Preferably, in slug A profile control agents, Complex polymer, chromium acetate, methenamine, resorcinol, coco-nut oil fatty acid
The mass ratio of diglycollic amide is 0.28%-0.32%：0.045%-0.05%：0.022%-0.028%：0.045%-
0.055%：0.06%-0.07%, remaining components are preparation water.
It is highly preferred that in slug A profile control agents, Complex polymer, chromium acetate, methenamine, resorcinol, coconut oil fat
The mass ratio of sour diglycollic amide is 0.3%：0.047%：0.025%：0.05%：0.065%, remaining components are preparation water.
Slug A profile control agent main function mechanism is to pass through the partially hydrolyzed polyacrylamide (PHPA) and acetic acid of different molecular quality
Chromium, methenamine are mixed to form molecular coil form polymer, after oil reservoir is injected, with the clay particle in oil reservoir or other not
Molten suspension is in contact, and is combined, and is formed around core formula molecular coil structure, increases its acting surface in hypertonic sandstone oil reservoir
Product, improve plugging effect；Resorcinol and cocoanut fatty acid diethanolamide can increase polyacrylamide molecular line in slug A
The activity of group's peripheral groups so that slug A is in contact partly with sandstone has larger viscosity, so as to increase slug A to hypertonic
The intensity of sandstone oil reservoir closure；Slug A is mainly used as blocking hypertonic region or macropore in hypertonic sandstone oil reservoir, improves hypertonic
The anisotropism of sandstone oil reservoir, so as to improve the oil displacement efficiency for being subsequently implanted into slug B.
Slug B profile control agents include Complex polymer and additive；Wherein, Complex polymer is by three kinds of different molecular Quality Mgmt Dept
Divide hydrolyzed polyacrylamide composition, molecular mass is respectively 500*104、1000*104、2500*104, its mass ratio is 80：15：
5；Additive includes chromium acetate, clay stabilizer, surfactant；In slug B profile control agents, Complex polymer mass ratio is
0.05%-0.1%, chromium acetate mass ratio are 0.02%-0.04%, and clay stabilizer mass ratio is 2%-3%, surfactant
Mass ratio is 1%-3%, and remaining components are preparation water.
Preferably, in slug B profile control agents, Complex polymer, chromium acetate, clay stabilizer, surfactant qualities ratio are
0.06%-0.09%：0.025%-0.035%：2.2%-2.8%：1.5%-2.5%, remaining components are preparation water.
It is highly preferred that in slug B profile control agents, Complex polymer, chromium acetate, clay stabilizer, the quality of surfactant
Than for 0.07%：0.028%：2.5%：2%, remaining components are preparation water.
Slug B main function mechanism is to mix low molecule mass fraction hydrolyzed polyacrylamide and chromium acetate formation compounding
Polymer, there is the characteristic that viscosity is low, mobility is strong, shear resistant is strong；Contain appropriate clay stabilizer and surface in slug B
Activating agent, the generation of clay swelling phenomenon can be suppressed during polymer flooding is implemented, and improve the hydrophily of sandstone oil reservoir,
Reach the poly- purpose driven and improve recovery ratio；After slug A forms stable closure, the slug B of low viscosity is injected to not blocked
In ooze region, hypotonic region carry out polymer flooding, the form injected by double slugs, can to oil reservoir carry out effectively closure, transfer drive,
And excessively will not tightly cause water injection pressure too high because of closure, and the invalid poly- drive of the low appearance of polymer viscosity can be avoided to follow
Ring, so as to improve the oil recovery of hypertonic sandstone oil reservoir.
A kind of application method of hypertonic sandstone oil reservoir Complex polymer type profile control agent comprises the following steps：
Step 1. combines oil field actual production design data profile control agent injection rate, injection rate and other injection parameters；
Step 2. carries out sudden and violent oxygen processing to preparing water, prepares water and uses oilfield sewage or source water, is dissolved preparing in water
Oxygen content is reduced to below 3mg/L；
Under the conditions of 15-55 DEG C of step 3. temperature range, in the mixing container, partial hydrolysis polypropylene is added in water to preparing
Acid amides, 2-3 hours are at the uniform velocity stirred, add additive then to preparing in water, at the uniform velocity stir 2-3 hours, obtain profile control agent；
Water injection well is connected by step 4. with stainless steel and supercharging device, starts supercharging device, profile control agent is injected into oil reservoir；
Static 48-72 hours make the abundant plastic of profile control agent after step 5. slug A profile control agent injection rates reach preset range；
Step 6. injects driven water-replacing 0.3PV, injects slug B profile control agents and carries out follow-up note and adopts operation.
The specific injection rate of profile control agent is：Slug A profile control agent 0.1-0.3PV are injected first into oil reservoir or rock core, wait 48-
Make within 72 hours the abundant plastic of slug A profile control agents, then to driven water-replacing 0.3PV is injected in oil reservoir or rock core, then to oil reservoir or rock
Slug B profile control agent 2-3PV are injected in the heart, to be considered as polymer flooding, are then carried out follow-up note and are adopted operation.
The present invention the advantage is that relative to prior art：
1st, recovery efficiency technique demand is improved for hypertonic sandstone oil reservoir, the present invention proposes a kind of Complex polymer type profile control
Agent, it is characterised in that Complex polymer type profile control agent slug A molecular coil sizes branch is wider, and can be with clay in oil reservoir
Grain, tiny sand body or insoluble suspension combine, and form resorcinol and coconut grease in core formula ball of string structure, slug A
Fat acid diglycollic amide can increase the activity of polyacrylamide molecular coil peripheral groups so that slug A connects contact portion with sandstone
Dividing has larger viscosity, so as to implement firm closure to hypertonic sandstone oil reservoir.
2nd, surfactant and clay stabilizer are added in slug B, when implementing polymer displacement of reservoir oil, oil reservoir conformability is stronger,
And clay swelling can be suppressed, improve the hydrophily of sandstone oil reservoir, to improve poly- drive recovery ratio.
3rd, by adjusting polyacrylamide and chromium acetate mass fraction in slug B, low viscosity Compositional type polymer can be formed,
Follow-up poly- drive is carried out after slug A injections, its effect of increasing production is better than direct water drive after closure.
4th, the present invention injects form by double slugs, and it is low to improve hypertonic sandstone oil reservoir anisotropism, recovery percent of reserves, after increase
Continuous water drive sweep efficiency, suppress region of bypassed oil generation, traditional oil production method is low to hypertonic sandstone oil reservoir recovery ratio, economic effect to improve
The drawbacks such as beneficial difference.
Embodiment
Experimental method used in following embodiments is conventional method unless otherwise specified.
The partially hydrolyzed polyacrylamide (PHPA) used in embodiment produces for Daqing Refinery company of CNPC, average molecular matter
Measure as 500*104、1000*104、2500*104, effective mass fraction is 90%；Chromium acetate is that Shandong West Asia chemical industry is limited
Company produces, and analysis is pure；Methenamine produces for Beijing Peng Cai chemical reagent Co., Ltd, and analysis is pure；Resorcinol is Guangdong
Weng Jiang chemical reagent Co., Ltd produces, and analysis is pure；Cocoanut fatty acid diethanolamide is that the small chemical share in open country in Shandong is limited
Company produces, and analysis is pure；Ammonium chloride produces for Nanjing chemical reagent limited company, specification：ACS, 99.5%；Dodecyl
Trimethyl ammonium chloride produces for Nanjing chemical reagent limited company, purity 98%；NPE is Jiangsu Province
Hai'an petrochemical plant production, No. CAS：9016-45-9, purity 98%；Neopelex is the small chemical stock in open country in Shandong
The production of part Co., Ltd, analysis are pure；Perfluoroalkyl betain produces for Wuhan Sai Woer Chemical Co., Ltd.s, content：>=98%.
Profile control agent plugging effect is evaluated by laboratory core experimental method, it is specific as follows：
Embodiment one：
1st, profile control agent application method：(1) sudden and violent oxygen processing is carried out to preparing water first, will prepare content of oxygen dissolved in water reduces
To below 3mg/L；(2) under the conditions of 15 DEG C of temperature, partially hydrolyzed polyacrylamide (PHPA) is added into preparation water and at the uniform velocity stirring 2 is small
When, additive is added in water then to preparing, and at the uniform velocity stir 3 hours, obtain profile control agent；(3) by profile control agent after the completion of preparing
It is directly injected into rock core.
2nd, preparation water, salinity 3126.31mg/L, specific ion concentration are as follows：
| Sodium potassium content (mg/L) | 1056.85 |
| Magnesium ion content (mg/L) | 6.7 |
| Calcium ion content (mg/L) | 6.54 |
| Chlorion content (mg/L) | 845.81 |
| Bicarbonate ion content (mg/L) | 1023.41 |
| Carbanion content (mg/L) | 187 |
| Total hardness (mg/L) | 47 |
| Total alkalinity (mol/L) | 22.99 |
| Total salinity (mg/L) | 3126.31 |
| Water type | NaHCO3 |
Preparation water is Liaohe Oil Field JinMa Co., Ltd actual production oilfield sewage.
3rd, concrete medicament application amount is：
Slug A：Complex polymer is made up of the partially hydrolyzed polyacrylamide (PHPA) of three kinds of different molecular quality, molecular mass point
Wei not 500*104、1000*104、2500*104, its mass ratio is 20：35：45；Complex polymer, chromium acetate, methenamine,
Benzenediol, the mass ratio of cocoanut fatty acid diethanolamide are 0.3%：0.047%：0.025%：0.05%：0.065%,
Remaining components are preparation water.
Slug B：Complex polymer is made up of three kinds of different molecular mass fraction hydrolyzed polyacrylamides, molecular mass difference
For 500*104、1000*104、2500*104, its mass ratio is 80：15：5；Complex polymer, chromium acetate, ammonium chloride, nonyl phenol
The mass ratio of APEO is 0.07%：0.028%：2.5%：2%, remaining components are preparation water.
4th, specific rock core manufacture scale is as follows：
Experiment rock core is quartz sand epoxy resin cementitious three layers of heterogeneous artificial cores, and specific size is 4.5cm*
4.5cm*30cm, perm-plug method are respectively 500*10-3μm2、1500*10-3μm2、3000*10-3μm2, pass through heterogeneous core
Hypertonic sandstone oil reservoir is simulated.
5th, displacement oil is crude oil, viscosity 40mPa.s in the case of 50 DEG C.
6th, sealing characteristics test operating procedure is as follows：
(1) rock core to be used is put into 70 DEG C of insulating boxs and is dried to constant weight, weighed its quality after taking out cooling, be designated as
m1；
(2) rock core after drying is put into saturation in vacuum pumping device and prepares water, when observation core surface bubble-free generates
Stop pumping, surface water is removed into rock core taking-up wiping, weighed, quality is designated as m2；
(3) rock core that saturation is prepared to water is put into core holding unit, adds confined pressure 4MPa, then with 0.4mL/min speed
Spend the injection into rock core and prepare water, the pressure and flow are recorded when pressure stability；
(4) the positive injection slug A profile control agent 0.1PV into rock core, record pressure during injection profile agent, stand 60 hours
It is stand-by；
(5) water drive is carried out with 2mL/min speed, record outlet brings out the first breakthrough pressure when dripping, and treats that pressure is steady
The time recording pressure and flow；
(6) whole experiment is carried out in the case of 50 DEG C of constant temperature, is permeated after calculating original permeability according to record result, block up
Rate, sealing ratiod, breakthrough pressure gradient, resistance coefficient.
7th, sealing characteristics evaluation such as following table
Permeability is three layers of non-average rock core overall permeability before stifled, from the above in can draw, Complex polymer type
Profile control agent is acted on substantially three layers of non-average rock core profile control, and sealing ratiod has reached more than 95%, illustrates to do using oilfield sewage and matches somebody with somebody
Water processed is to profile control agent without negative effect.
8th, oil-displacement capacity test operating procedure is as follows：
(1) rock core to be used is put into 70 DEG C of insulating boxs and is dried to constant weight, weighed its quality after taking out cooling, be designated as
m3；
(2) rock core after drying is put into saturation in vacuum pumping device and prepares water, when observation core surface bubble-free generates
Stop pumping, surface water is removed into rock core taking-up wiping, weighed, quality is designated as m4；
(3) with 1.5mL/min speed into rock core saturation crude oil, be driven to the port of export no longer water outlet when termination of pumping, record is tired
Count water yield, stand 4 hours it is stand-by；
(4) rock core of the complete crude oil of saturation being put into core holding unit, whole process experiment is carried out in the case of 50 DEG C of constant temperature, with
2mL/min speed carries out water drive oil, be driven to the port of export it is no longer fuel-displaced when termination of pumping, record oil pump capacity and recovery ratio；
(5) with the positive injection Complex polymer slug A profile control agent 0.2PV of 0.9mL/min speed, it is small that 72 are placed after having noted
When, it is subsequently injected into and prepares water 0.3PV, is subsequently injected into slug B profile control agent 2PV, termination of pumping；
(6) positive water drive experiment is carried out, stops experiment when being driven to aqueous 98%, records oil pump capacity, and it is final to calculate rock core
Recovery ratio value.
9th, oil-displacement capacity evaluation such as following table：
Learnt from above-mentioned data, profile control agent is prepared using oilfield sewage, it is real that displacement is carried out in the case of 50 DEG C of oil reservoir is simulated
Test, after implementing profile control to three layers of heterogeneous core, improved simulation core anisotropism, improved recovery ratio 24.25%, illustrated this
Invention profile control agent can improve Reservoir Heterogeneity, and profile control effect is obvious.
Embodiment two：
1st, profile control agent application method：(1) sudden and violent oxygen processing is carried out to preparing water first, will prepare content of oxygen dissolved in water reduces
To below 3mg/L；(2) under the conditions of 35 DEG C of temperature, into preparation water, it is small at the uniform velocity to stir 2.5 for addition partially hydrolyzed polyacrylamide (PHPA)
When, additive is added in water then to preparing, and at the uniform velocity stir 2.5 hours, obtain profile control agent；(3) by profile control after the completion of preparing
Agent is directly injected into rock core.
2nd, preparation water, salinity 625.2mg/L, specific ion concentration are as follows：
| Sodium potassium content (mg/L) | 211.37 |
| Magnesium ion content (mg/L) | 1.34 |
| Calcium ion content (mg/L) | 1.308 |
| Chlorion content (mg/L) | 169.162 |
| Bicarbonate ion content (mg/L) | 204.682 |
| Carbanion content (mg/L) | 37.4 |
| Total hardness (mg/L) | 9.4 |
| Total alkalinity (mol/L) | 4.598 |
| Total salinity (mg/L) | 625.262 |
| Water type | NaHCO3 |
Preparation water is lake water, the source water used in being produced to simulation oil field.
3rd, concrete medicament application amount is：
Slug A：Complex polymer is made up of the partially hydrolyzed polyacrylamide (PHPA) of three kinds of different molecular quality, molecular mass point
Wei not 500*104、1000*104、2500*104, its mass ratio is 20：35：45；Complex polymer, chromium acetate, methenamine,
Benzenediol, the mass ratio of cocoanut fatty acid diethanolamide are 0.25%：0.04%：0.02%：0.04%：0.05%, it is remaining
The following group is divided into preparation water.
Slug B：Complex polymer is made up of three kinds of different molecular mass fraction hydrolyzed polyacrylamides, molecular mass difference
For 500*104、1000*104、2500*104, its mass ratio is 80：15：5；Complex polymer, chromium acetate, trimethyl
Ammonium chloride, the mass ratio of perfluoroalkyl betain are 0.05%：0.02%：2%：1%, remaining components are preparation water.
4th, specific rock core manufacture scale is as follows：
Experiment rock core is quartz sand epoxy resin cementitious three layers of heterogeneous artificial cores, and specific size is 4.5cm*
4.5cm*30cm, perm-plug method are respectively 500*10-3μm2、1500*10-3μm2、3000*10-3μm2, pass through heterogeneous core
Hypertonic sandstone oil reservoir is simulated.
5th, displacement oil is crude oil, and viscosity is 30mPa.s during temperature 70 C.
6th, sealing characteristics test operating procedure is as follows：
(1) rock core to be used is put into 70 DEG C of insulating boxs and is dried to constant weight, weighed its quality after taking out cooling, be designated as
m5；
(2) rock core after drying is put into saturation in vacuum pumping device and prepares water, when observation core surface bubble-free generates
Stop pumping, surface water is removed into rock core taking-up wiping, weighed, quality is designated as m6；
(3) rock core that saturation is prepared to water is put into core holding unit, adds confined pressure 4MPa, then with 0.4mL/min speed
Spend the injection into rock core and prepare water, the pressure and flow are recorded when pressure stability；
(4) the positive injection slug A profile control agent 0.3PV into rock core, record pressure during injection profile agent, stand 66 hours
It is stand-by；
(5) water drive is carried out with 2mL/min speed, record outlet brings out the first breakthrough pressure when dripping, and treats that pressure is steady
The time recording pressure and flow；
(6) whole experiment is carried out in the case of 70 DEG C of constant temperature, is permeated after calculating original permeability according to record result, block up
Rate, sealing ratiod, breakthrough pressure gradient, resistance coefficient.
7th, sealing characteristics evaluation such as following table
Permeability is three layers of non-average rock core overall permeability before stifled, from the above in can draw, Complex polymer type
Profile control agent is acted on substantially three layers of non-average rock core profile control, and sealing ratiod has reached more than 95%, illustrates to prepare using source water
Water is to profile control agent without negative effect.
8th, oil-displacement capacity test operating procedure is as follows：
(1) rock core to be used is put into 70 DEG C of insulating boxs and is dried to constant weight, weighed its quality after taking out cooling, be designated as
m7；
(2) rock core after drying is put into saturation in vacuum pumping device and prepares water, when observation core surface bubble-free generates
Stop pumping, surface water is removed into rock core taking-up wiping, weighed, quality is designated as m8；
(3) with 1.5mL/min speed into rock core saturation crude oil, be driven to the port of export no longer water outlet when termination of pumping, record is tired
Count water yield, stand 4 hours it is stand-by；
(4) rock core of the complete crude oil of saturation being put into core holding unit, whole process experiment is carried out in the case of 70 DEG C of constant temperature, with
2mL/min speed carries out water drive oil, be driven to the port of export it is no longer fuel-displaced when termination of pumping, record oil pump capacity and recovery ratio；
(5) with the positive injection slug A profile control agent 0.25PV of 0.9mL/min speed, placed 48 hours after having noted, then note
Enter to prepare water 0.3PV, be subsequently injected into slug B profile control agent 3PV, termination of pumping；
(6) positive water drive experiment is carried out, stops experiment when being driven to aqueous 98%, records oil pump capacity, and it is final to calculate rock core
Recovery ratio value.
9th, oil-displacement capacity evaluation such as following table：
Learnt from above-mentioned data, prepare profile control agent using source water, displacement test is carried out in the case of 70 DEG C of oil reservoir is simulated,
After implementing profile control to three layers of heterogeneous core, simulation core anisotropism is improved, has improved recovery ratio 25.46%, illustrate this hair
Bright profile control agent can improve Reservoir Heterogeneity, and profile control effect is obvious.
Embodiment three：
1st, profile control agent application method：(1) sudden and violent oxygen processing is carried out to preparing water first, will prepare content of oxygen dissolved in water reduces
To below 3mg/L；(2) under the conditions of 55 DEG C of temperature, into preparation water, it is small at the uniform velocity to stir 3 for addition partially hydrolyzed polyacrylamide (PHPA)
When, additive is added in water then to preparing, and at the uniform velocity stir 2 hours, obtain profile control agent；(3) by profile control agent after the completion of preparing
It is directly injected into rock core.
2nd, water is prepared：By adding solubility salt regulating mineralization degree of injected oil into distilled water, final salinity is 35000mg/
L, to simulate the oilfield sewage used in actual production.
3rd, concrete medicament application amount is：
Slug A：Complex polymer is made up of the partially hydrolyzed polyacrylamide (PHPA) of three kinds of different molecular quality, molecular mass point
Wei not 500*104、1000*104、2500*104, its mass ratio is 20：35：45；Complex polymer, chromium acetate, methenamine,
Benzenediol, the mass ratio of cocoanut fatty acid diethanolamide are 0.35%：0.055%：0.03%：0.06%：0.08%, it is remaining
The following group is divided into preparation water.
Slug B：Complex polymer is made up of three kinds of different molecular mass fraction hydrolyzed polyacrylamides, molecular mass difference
For 500*104、1000*104、2500*104, its mass ratio is 80：15：5；Complex polymer, chromium acetate, trimethyl
Ammonium chloride, the mass ratio of neopelex are 0.1%：0.04%：3%：3%, remaining components are preparation water.
4th, specific rock core manufacture scale is as follows：
Experiment rock core is quartz sand epoxy resin cementitious three layers of heterogeneous artificial cores, and specific size is 4.5cm*
4.5cm*30cm, perm-plug method are respectively 500*10-3μm2、1500*10-3μm2、3000*10-3μm2, pass through heterogeneous core
Hypertonic sandstone oil reservoir is simulated.
5th, displacement oil is crude oil, and viscosity is 30mPa.s during 30 DEG C of temperature.
6th, sealing characteristics test operating procedure is as follows：
(1) rock core to be used is put into 70 DEG C of insulating boxs and is dried to constant weight, weighed its quality after taking out cooling, be designated as
m9；
(2) rock core after drying is put into saturation in vacuum pumping device and prepares water, when observation core surface bubble-free generates
Stop pumping, surface water is removed into rock core taking-up wiping, weighed, quality is designated as m10；
(3) rock core that saturation is prepared to water is put into core holding unit, adds confined pressure 4MPa, then with 0.4mL/min speed
Spend the injection into rock core and prepare water, the pressure and flow are recorded when pressure stability；
(4) the positive injection slug A profile control agent 0.2PV into rock core, record pressure during injection profile agent, stand 48 hours
It is stand-by；
(5) water drive is carried out with 2mL/min speed, record outlet brings out the first breakthrough pressure when dripping, and treats that pressure is steady
The time recording pressure and flow；
(6) whole experiment is carried out in the case of 30 DEG C of constant temperature, is permeated after calculating original permeability according to record result, block up
Rate, sealing ratiod, breakthrough pressure gradient, resistance coefficient.
7th, sealing characteristics evaluation such as following table
Permeability is three layers of non-average rock core overall permeability before stifled, from the above in can draw, Complex polymer type
Profile control agent is acted on substantially three layers of non-average rock core profile control, and sealing ratiod has reached more than 95%, illustrates salinity 35000mg/L moulds
Intend oilfield sewage to profile control agent without negative effect.
8th, oil-displacement capacity test operating procedure is as follows：
(1) rock core to be used is put into 70 DEG C of insulating boxs and is dried to constant weight, weighed its quality after taking out cooling, be designated as
m11；
(2) rock core after drying is put into saturation in vacuum pumping device and prepares water, when observation core surface bubble-free generates
Stop pumping, surface water is removed into rock core taking-up wiping, weighed, quality is designated as m12；
(3) with 1.5mL/min speed into rock core saturation crude oil, be driven to the port of export no longer water outlet when termination of pumping, record is tired
Count water yield, stand 4 hours it is stand-by；
(4) rock core of the complete crude oil of saturation being put into core holding unit, whole process experiment is carried out in the case of 30 DEG C of constant temperature, with
2mL/min speed carries out water drive oil, be driven to the port of export it is no longer fuel-displaced when termination of pumping, record oil pump capacity and recovery ratio；
(5) with the positive injection slug A profile control agent 0.1PV of 0.9mL/min speed, placed 60 hours after having noted, then note
Enter to prepare water 0.3PV, be subsequently injected into slug B profile control agent 2.5PV, termination of pumping；
(6) positive water drive experiment is carried out, stops experiment when being driven to aqueous 98%, records oil pump capacity, and it is final to calculate rock core
Recovery ratio value.
9th, oil-displacement capacity evaluation such as following table：
Learnt from above-mentioned data, prepare profile control agent using simulating oil field produced water, driven in the case of 30 DEG C of oil reservoir is simulated
For experiment, after implementing profile control to three layers of heterogeneous core, simulation core anisotropism is improved, has improved recovery ratio 25.74%, say
Bright profile control agent of the present invention can improve Reservoir Heterogeneity, and profile control effect is obvious.
Claims (8)
1. a kind of hypertonic sandstone oil reservoir Complex polymer type profile control agent, it is characterised in that adjusted including slug A profile control agents and slug B
Cut open agent；
Slug A profile control agents include Complex polymer and additive；Wherein, Complex polymer by three kinds of different molecular quality part
Hydrolyzed polyacrylamide forms, and molecular mass is respectively 500*104、1000*104、2500*104, its mass ratio is 20：35：45；
Additive includes chromium acetate, methenamine, resorcinol, cocoanut fatty acid diethanolamide；In slug A profile control agents, compounding
Polymer quality ratio is 0.25%-0.35%, and chromium acetate mass ratio is 0.04%-0.055%, and methenamine mass ratio is
0.02%-0.03%, resorcinol mass ratio are 0.04%-0.06%, and cocoanut fatty acid diethanolamide mass ratio is
0.05%-0.08%, remaining components are preparation water；And
Slug B profile control agents include Complex polymer and additive；Wherein, Complex polymer is by three kinds of different molecular mass fraction water
Polyacrylamide composition is solved, molecular mass is respectively 500*104、1000*104、2500*104, its mass ratio is 80：15：5；Add
Agent is added to include chromium acetate, clay stabilizer, surfactant；In slug B profile control agents, Complex polymer mass ratio is 0.05%-
0.1%, chromium acetate mass ratio is 0.02%-0.04%, and clay stabilizer mass ratio is 2%-3%, surfactant 1%-
3%, remaining components are preparation water.
A kind of 2. hypertonic sandstone oil reservoir Complex polymer type profile control agent as claimed in claim 1, it is characterised in that the clay
Stabilizer include ammonium chloride, DTAC and other be applied to hypertonic sandstone oil reservoir clay stabilizer.
A kind of 3. hypertonic sandstone oil reservoir Complex polymer type profile control agent as claimed in claim 1, it is characterised in that the surface
Activating agent includes NPE, neopelex and perfluoroalkyl betain.
A kind of 4. hypertonic sandstone oil reservoir Complex polymer type profile control agent as claimed in claim 1, it is characterised in that the slug
Complex polymer, chromium acetate, methenamine, resorcinol, the mass ratio of cocoanut fatty acid diethanolamide are in A profile control agents
0.28%-0.32%：0.045%-0.05%：0.022%-0.028%：0.045%-0.055%：0.06%-0.07%, it is remaining
The following group is divided into preparation water.
A kind of 5. hypertonic sandstone oil reservoir Complex polymer type profile control agent as claimed in claim 1, it is characterised in that the slug
Complex polymer, chromium acetate, methenamine, resorcinol, the mass ratio of cocoanut fatty acid diethanolamide are in A profile control agents
0.3%：0.047%：0.025%：0.05%：0.065%, remaining components are preparation water.
A kind of 6. hypertonic sandstone oil reservoir Complex polymer type profile control agent as claimed in claim 1, it is characterised in that the slug
Complex polymer, chromium acetate, clay stabilizer, surfactant qualities ratio are 0.06%-0.09% in B profile control agents：
0.025%-0.035%：2.2%-2.8%：1.5%-2.5%, remaining components are preparation water.
A kind of 7. hypertonic sandstone oil reservoir Complex polymer type profile control agent as claimed in claim 1, it is characterised in that the slug
Complex polymer, chromium acetate, clay stabilizer, the mass ratio of surfactant are 0.07% in B profile control agents：0.028%：
2.5%：2%, remaining components are preparation water.
8. a kind of application method of hypertonic sandstone oil reservoir Complex polymer type profile control agent, it is characterised in that comprise the following steps：
Step 1. combines oil field actual production design data profile control agent injection rate, injection rate and other injection parameters；
Step 2. carries out sudden and violent oxygen processing to preparing water, prepares water and uses oilfield sewage or source water, will prepare oxygen in water and contains
Amount is reduced to below 3mg/L；
Under the conditions of 15-55 DEG C of step 3. temperature range, in the mixing container, partial hydrolysis polyacrylamide is added in water to preparing
Amine, 2-3 hours are at the uniform velocity stirred, add additive then to preparing in water, at the uniform velocity stir 2-3 hours, obtain profile control agent；
Water injection well is connected by step 4. with stainless steel and supercharging device, starts supercharging device, profile control agent is injected into oil reservoir；
Static 48-72 hours make the abundant plastic of profile control agent after step 5. slug A profile control agent injection rates reach preset range；
Step 6. injects driven water-replacing 0.3PV, injects slug B profile control agents and carries out follow-up note and adopts operation.
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Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN108865089A (en) * | 2018-08-10 | 2018-11-23 | 宁夏朔光石油科技有限公司 | Water blockoff system and its construction method |
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2017
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Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN108865089A (en) * | 2018-08-10 | 2018-11-23 | 宁夏朔光石油科技有限公司 | Water blockoff system and its construction method |
| CN108865089B (en) * | 2018-08-10 | 2019-06-25 | 宁夏朔光石油科技有限公司 | Water blockoff system and its construction method |
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Application publication date: 20171124 |