CN107236528A - A kind of hypertonic duct type oil reservoir Complex polymer profile control agent and its application method - Google Patents
A kind of hypertonic duct type oil reservoir Complex polymer profile control agent and its application method Download PDFInfo
- Publication number
- CN107236528A CN107236528A CN201710661108.9A CN201710661108A CN107236528A CN 107236528 A CN107236528 A CN 107236528A CN 201710661108 A CN201710661108 A CN 201710661108A CN 107236528 A CN107236528 A CN 107236528A
- Authority
- CN
- China
- Prior art keywords
- profile control
- water
- control agent
- slug
- complex polymer
- 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.)
- Withdrawn
Links
- 229920000642 polymer Polymers 0.000 title claims abstract description 59
- 238000000034 method Methods 0.000 title claims abstract description 26
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 111
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 102
- 238000002347 injection Methods 0.000 claims abstract description 31
- 239000007924 injection Substances 0.000 claims abstract description 31
- 229920002401 polyacrylamide Polymers 0.000 claims abstract description 23
- 238000002360 preparation method Methods 0.000 claims abstract description 21
- 239000004094 surface-active agent Substances 0.000 claims abstract description 17
- 239000000654 additive Substances 0.000 claims abstract description 16
- 230000000996 additive effect Effects 0.000 claims abstract description 16
- 239000000126 substance Substances 0.000 claims abstract description 7
- 239000000203 mixture Substances 0.000 claims abstract description 5
- 238000013329 compounding Methods 0.000 claims abstract description 4
- GEHJYWRUCIMESM-UHFFFAOYSA-L sodium sulfite Chemical compound [Na+].[Na+].[O-]S([O-])=O GEHJYWRUCIMESM-UHFFFAOYSA-L 0.000 claims description 50
- GHMLBKRAJCXXBS-UHFFFAOYSA-N resorcinol Chemical compound OC1=CC=CC(O)=C1 GHMLBKRAJCXXBS-UHFFFAOYSA-N 0.000 claims description 30
- UMGDCJDMYOKAJW-UHFFFAOYSA-N thiourea Chemical compound NC(N)=S UMGDCJDMYOKAJW-UHFFFAOYSA-N 0.000 claims description 30
- 235000010265 sodium sulphite Nutrition 0.000 claims description 25
- ZUGAOYSWHHGDJY-UHFFFAOYSA-K 5-hydroxy-2,8,9-trioxa-1-aluminabicyclo[3.3.2]decane-3,7,10-trione Chemical compound [Al+3].[O-]C(=O)CC(O)(CC([O-])=O)C([O-])=O ZUGAOYSWHHGDJY-UHFFFAOYSA-K 0.000 claims description 15
- 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 15
- 229920000877 Melamine resin Polymers 0.000 claims description 14
- 235000010299 hexamethylene tetramine Nutrition 0.000 claims description 13
- VKYKSIONXSXAKP-UHFFFAOYSA-N hexamethylenetetramine Chemical compound C1N(C2)CN3CN1CN2C3 VKYKSIONXSXAKP-UHFFFAOYSA-N 0.000 claims description 13
- 229960004011 methenamine Drugs 0.000 claims description 13
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims description 12
- 229910052760 oxygen Inorganic materials 0.000 claims description 12
- 239000001301 oxygen Substances 0.000 claims description 12
- 238000004519 manufacturing process Methods 0.000 claims description 11
- 229920003023 plastic Polymers 0.000 claims description 6
- 239000004033 plastic Substances 0.000 claims description 6
- 238000012545 processing Methods 0.000 claims description 5
- 244000060011 Cocos nucifera Species 0.000 claims description 4
- 235000013162 Cocos nucifera Nutrition 0.000 claims description 4
- 235000014113 dietary fatty acids Nutrition 0.000 claims description 4
- 229930195729 fatty acid Natural products 0.000 claims description 4
- 239000000194 fatty acid Substances 0.000 claims description 4
- 150000004665 fatty acids Chemical class 0.000 claims description 4
- 239000010865 sewage Substances 0.000 claims description 4
- 230000003068 static effect Effects 0.000 claims description 4
- 238000013461 design Methods 0.000 claims description 3
- 244000269722 Thea sinensis Species 0.000 claims description 2
- 230000003213 activating effect Effects 0.000 claims description 2
- 239000003513 alkali Substances 0.000 claims description 2
- 235000009508 confectionery Nutrition 0.000 claims description 2
- 230000007062 hydrolysis Effects 0.000 claims description 2
- 238000006460 hydrolysis reaction Methods 0.000 claims description 2
- 238000002156 mixing Methods 0.000 claims description 2
- 125000005010 perfluoroalkyl group Chemical group 0.000 claims description 2
- 238000006116 polymerization 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
- 150000001412 amines Chemical class 0.000 claims 1
- 239000011435 rock Substances 0.000 abstract description 63
- 239000000084 colloidal system Substances 0.000 abstract description 5
- 238000012546 transfer Methods 0.000 abstract description 5
- 230000010148 water-pollination Effects 0.000 abstract description 4
- 230000008595 infiltration Effects 0.000 abstract description 3
- 238000001764 infiltration Methods 0.000 abstract description 3
- 239000002994 raw material Substances 0.000 abstract description 2
- 230000015572 biosynthetic process Effects 0.000 abstract 2
- 239000003921 oil Substances 0.000 description 63
- 238000005086 pumping Methods 0.000 description 21
- 238000002474 experimental method Methods 0.000 description 19
- 230000000694 effects Effects 0.000 description 17
- 238000011084 recovery Methods 0.000 description 16
- 238000007789 sealing Methods 0.000 description 12
- 230000035699 permeability Effects 0.000 description 11
- 238000006073 displacement reaction Methods 0.000 description 10
- 239000010779 crude oil Substances 0.000 description 9
- 230000009467 reduction Effects 0.000 description 7
- 238000001816 cooling Methods 0.000 description 6
- 238000001035 drying Methods 0.000 description 6
- 238000011017 operating method Methods 0.000 description 6
- 238000003756 stirring Methods 0.000 description 6
- 239000002352 surface water Substances 0.000 description 6
- 238000012360 testing method Methods 0.000 description 6
- -1 polypropylene Polymers 0.000 description 5
- 230000008569 process Effects 0.000 description 5
- 238000004088 simulation Methods 0.000 description 5
- 229940123973 Oxygen scavenger Drugs 0.000 description 4
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 4
- KWIUHFFTVRNATP-UHFFFAOYSA-N Betaine Natural products C[N+](C)(C)CC([O-])=O KWIUHFFTVRNATP-UHFFFAOYSA-N 0.000 description 3
- 239000006004 Quartz sand Substances 0.000 description 3
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical group O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 3
- UKTDQTGMXUHPIF-UHFFFAOYSA-N [Na].S(O)(O)=O Chemical compound [Na].S(O)(O)=O UKTDQTGMXUHPIF-UHFFFAOYSA-N 0.000 description 3
- 150000001408 amides Chemical class 0.000 description 3
- 229960003237 betaine Drugs 0.000 description 3
- 239000012153 distilled water Substances 0.000 description 3
- 239000003814 drug Substances 0.000 description 3
- 239000003822 epoxy resin Substances 0.000 description 3
- 229920000647 polyepoxide Polymers 0.000 description 3
- 239000004743 Polypropylene Substances 0.000 description 2
- 150000001875 compounds Chemical class 0.000 description 2
- 239000003431 cross linking reagent Substances 0.000 description 2
- 230000003111 delayed effect Effects 0.000 description 2
- 238000001879 gelation Methods 0.000 description 2
- 239000003292 glue Substances 0.000 description 2
- 230000015784 hyperosmotic salinity response Effects 0.000 description 2
- 239000011159 matrix material Substances 0.000 description 2
- 230000007246 mechanism Effects 0.000 description 2
- 125000004430 oxygen atom Chemical group O* 0.000 description 2
- 230000000704 physical effect Effects 0.000 description 2
- 229920001155 polypropylene Polymers 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 239000011780 sodium chloride Substances 0.000 description 2
- 241000196324 Embryophyta Species 0.000 description 1
- 241000237858 Gastropoda Species 0.000 description 1
- 101150042248 Mgmt gene Proteins 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 239000013043 chemical agent Substances 0.000 description 1
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 238000004132 cross linking Methods 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 230000008021 deposition Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000018109 developmental process Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- WSFSSNUMVMOOMR-UHFFFAOYSA-N formaldehyde Substances O=C WSFSSNUMVMOOMR-UHFFFAOYSA-N 0.000 description 1
- 239000010903 husk Substances 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 230000001965 increasing effect Effects 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 229920005989 resin Polymers 0.000 description 1
- 239000011347 resin Substances 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 150000003384 small molecules Chemical class 0.000 description 1
- 239000004575 stone 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
- C09K8/50—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
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5086—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
-
- C—CHEMISTRY; METALLURGY
- 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
- C09K8/512—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
-
- 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
Landscapes
- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Mining & Mineral Resources (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Geochemistry & Mineralogy (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- General Chemical & Material Sciences (AREA)
- Compositions Of Macromolecular Compounds (AREA)
Abstract
A kind of hypertonic duct type oil reservoir Complex polymer profile control agent and its application method, are related to field use chemical field.The present invention is injected in hypertonic duct type oil reservoir by double slug forms, and preposed attributives mix multiple high polymer polyacrylamides and additive formation Complex polymer, and oil reservoir middle and high infiltration area, macropore are implemented to block；Rearmounted slug mixes multiple low molecular weight polyacrylamides and additive, possess that low viscosity, mobility be strong, shear resistant feature, injection oil reservoir carries out transfer drive after preposed attributives closure, water drive is produced after closure small-scale water breakthrough, fingering phenomenon can be suppressed, contain proper amount of surfactant in profile control agent, the hydrophily of formation rock can be improved, suppress the phenomenon that the unmanageable wax of traditional profile control method, colloid, asphalitine are deposited near wellbore zone；Profile control agent compounding method of the present invention is simple, 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 duct type oil reservoir Complex polymer profile control agent and its application method, the profile control agent can change
Kind poly- drive reservoir adaptability, and then hypertonic duct type reservoir polymer drive oil increasing effect can be improved, belong to field use chemical agent
Field.
Background technology
The waterflood recovery efficiency factor aggregate level of China's onshore oil field is relatively low, and generally below 50%, one of its major reason is water
The sweep efficiency of drive is relatively low；A key factor for influenceing water drive sweep efficiency is anisotropism；Hypertonic duct type oil reservoir has
Permeability is high, pore throat is wide and the feature of microcrack development, due to the complexity and rock surface property of pore structure, hypertonic duct
Type oil reservoir equally exists anisotropism so that during water drive, and the propulsion of water equably piston type can not advance, and cause injection water along height
Infiltration layer section is advanced by leaps and bounds, and local water breakthrough phenomenon is occurred, so as to reduce the sweep efficiency of injection water, is constrained waterflood recovery efficiency factor.
Traditional method is that its duct is blocked then to carry out water drive, in such a method, simple profile control and follow-up
Water drive be often difficult in adapt to the complexity of reservoir, cause the phenomenons such as small-scale water breakthrough, fingering after closure so that further carry
The difficulty of high water-flooding performance is larger.
Recovery efficiency technique demand is improved for hypertonic duct type oil reservoir, the present invention provides a kind of applied to hypertonic duct type oil
The Complex polymer type profile control agent of Tibetan, the problem of for solving set forth above.
The content of the invention
It is an object of the invention to provide a kind of hypertonic duct type oil reservoir Complex polymer profile control agent and its application method, lead to
Cross double slug forms to inject in hypertonic duct type oil reservoir, preposed attributives mix multiple high polymer polyacrylamides and additive is formed
Complex polymer, implements to block to oil reservoir middle and high infiltration area, macropore；Rearmounted slug mix multiple low molecular weight polyacrylamides and
Additive, possesses that low viscosity, mobility be strong, shear resistant feature, and injection oil reservoir carries out transfer drive after preposed attributives closure, can press down
Contain proper amount of surfactant in the small-scale water breakthrough of water drive generation, fingering phenomenon, profile control agent after system closure, oil reservoir rock can be improved
The hydrophily of stone, suppresses the phenomenon that the unmanageable wax of traditional profile control method, colloid, asphalitine are deposited near wellbore zone；This
Invention profile control agent compounding method is simple, is suitable for salinity 500mg/L-35000mg/L preparation water, and raw material is inexpensively easy
.
To reach above-mentioned purpose, the present invention is adopted the following technical scheme that.
A kind of hypertonic duct type oil reservoir Complex polymer profile control agent, its main component is：Partially hydrolyzed polyacrylamide (PHPA) phase
It is respectively 500*10 to molecular weight4、800*104、1000*104、1200*104、1800*104、2400*104, chromium acetate, sulfurous acid
Sodium, resorcinol, thiocarbamide, methenamine, surfactant, melamine formaldehyde resin, aluminium citrate；Wherein surface-active
Agent concretely NPE, neopelex, cocoanut fatty acid diethanolamide, perfluoroalkyl sweet tea
Dish alkali or other be applied to hypertonic duct type oil reservoir surfactant；For hypertonic duct type oil reservoir, the double slug formulas of design are adjusted
Agent is cutd open, is described below with slug A profile control agents and slug B profile control agents.
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) is constituted, and molecular mass is respectively 1200*104、1800*104、2400*104, its mass ratio is 15：
35：50；Additive includes chromium acetate, sodium sulfite, resorcinol, thiocarbamide, methenamine；In slug A profile control agents, compounding polymerization
Amount of substance ratio is 0.25%-0.3%, and chromium acetate mass ratio is 0.03%-0.05%, and sodium sulfite mass ratio is 0.2%-
0.4%, resorcinol mass ratio is 0.2%-0.4%, and thiocarbamide mass ratio is 0.1%-0.3%, and methenamine mass ratio is
0.2%-0.25%, remaining components are preparation water.
Preferably, in slug A profile control agents, Complex polymer, chromium acetate, sodium sulfite, resorcinol, thiocarbamide, Wu Luotuo
Quality ratio is 0.26%-0.29%：0.035%-0.045%：0.25%-0.35%：0.25%-0.35%：0.15%-
0.25%：0.21%-0.24%, remaining components are preparation water.
It is highly preferred that in slug A profile control agents, Complex polymer, chromium acetate, sodium sulfite, resorcinol, thiocarbamide, Wu Luo
Tropine mass ratio is 0.27%：0.04%：0.3%：0.3%：0.2%：0.23%, remaining components are preparation water.
Slug A profile control agent main function mechanism is that, by the way that three kinds of high polymer polyacrylamides are compounded, being formed has molecule
The Compositional type polymer of ball of string form, can implement firm closure to the duct in reservoir；By add chromium acetate, resorcinol,
Methenamine can form matrix type cross-linked structure as crosslinking agent, with delayed gelation, stable, the broken glue time length of colloid physical property,
Salt tolerance is acted on；The oxygen that sodium sulfite, thiocarbamide can effectively suppress in process for preparation and in oil reservoir as oxygen scavenger is produced to profile control agent
Raw viscosity reduction effect, so as to strengthen the stability of polymer；Slug A is mainly used as blocking the high permeability area in hypertonic duct type oil reservoir
Domain or macropore, improve the anisotropism of hypertonic duct type oil reservoir so that the slug B for being subsequently implanted into low viscosity avoids small-scale water
Alter, fingering, it is invalid it is poly- drive circulation etc. phenomenon.
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、800*104、1000*104, its mass ratio is 60：25：
15；Additive includes surfactant, melamine formaldehyde resin, sodium sulfite, aluminium citrate；It is multiple in slug B profile control agents
It is 0.05%-0.1% with polymer quality ratio, surfactant qualities ratio is 2%-6%, melamine formaldehyde resin quality
Than for 0.02%-0.03%, sodium sulfite mass ratio is 0.2%-0.4%, aluminium citrate mass ratio is 0.02%-0.03%,
Remaining components are preparation water.
Preferably, in slug B profile control agents, Complex polymer, surfactant, melamine formaldehyde resin, sulfurous acid
Sodium, the mass ratio of aluminium citrate are 0.06%-0.09%：0.25%-0.55%：0.022%-0.028%：0.25%-
0.35%：0.022%-0.028%, remaining components are preparation water.
It is highly preferred that in slug B profile control agents, Complex polymer, surfactant, melamine formaldehyde resin, sulfurous acid
Sodium, the mass ratio of aluminium citrate are 0.075%：0.4%：0.025%：0.3%：0.025%, remaining components are preparation water.
Slug B profile control agent main function mechanism is to hydrolyze polypropylene by the low molecule mass fraction of lower quality fraction
Acid amides, melamine formaldehyde resin and aluminium citrate are cross-linked to form the relatively low Complex polymer of viscosity, and transfer drive sweep efficiency is high,
Injection oil reservoir carries out transfer drive after slug A is blocked, and can suppress water drive is produced after closure small-scale water breakthrough, fingering, invalid poly- drive
The phenomenons such as circulation；Appropriate sodium sulfite is added in profile control agent can effectively suppress in process for preparation and in oil reservoir as oxygen scavenger
The viscosity reduction effect that oxygen is produced to profile control agent；And using two kinds of surfactant compounds in slug B, its using effect is better than single table
Face activating agent, can improve the hydrophily of reservoir rockses, suppress the unmanageable wax of traditional profile control method, colloid, asphalitine and exist
The phenomenon of near wellbore zone deposition, reaches the poly- purpose driven and improve recovery ratio；The present invention improves oil by way of double slug combinations
Anisotropism is hidden, increases sequent water flooding sweep efficiency, suppresses hypertonic duct type oil reservoir region of bypassed oil and is formed, and pass through sequent water flooding pair
Oil reservoir is further developed.
A kind of application method of hypertonic duct type oil reservoir Complex polymer 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. pair prepares water and carries out sudden and violent oxygen processing, 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, is at the uniform velocity stirred 2-3 hours, and additive is added then to preparing in water, is at the uniform velocity stirred 2-3 hours, is obtained 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；
Step 5. slug A profile control agent injection rates reach that static 18-24 hours makes the abundant plastic of profile control agent after preset range；
Step 6. injects driven water-replacing 0.2PV, and static 30-36 hours of slug B profile control agents of injection make the abundant plastic of profile control agent, with
Follow-up note is carried out afterwards adopts operation.
The specific injection rate of profile control agent is：Slug A profile control agent 0.3PV are injected first into oil reservoir or rock core, wait 18-24 small
When make the abundant plastic of slug A profile control agents, then in oil reservoir or rock core inject driven water-replacing 0.2PV, then in oil reservoir or rock core
Slug B profile control agent 0.5-0.7PV are injected, wait allows the abundant plastic of slug B profile control agents for 30-36 hour, then carry out subsequently noting and adopts
Operation.
The present invention the advantage is that relative to prior art：
1st, by the way that multiple high polymer polyacrylamides are compounded, the Compositional type polymer segments with molecular coil form are formed
A is filled in, firm closure can be implemented to the macropore in oil reservoir.
2nd, in slug A, crosslinking agent is used as by adding chromium acetate, resorcinol, methenamine, matrix type crosslinking can be formed
Structure, with delayed gelation, stable, the broken glue time length of colloid physical property, salt tolerance effect.
3rd, in slug A, it can effectively suppress the oxygen atom in oil reservoir as oxygen scavenger by adding sodium sulfite, thiocarbamide and exchange
The viscosity reduction effect of agent generation is cutd open, strengthens the stability of profile control agent.
4th, it is crosslinked by the small molecule polyacrylamide, melamine formaldehyde resin and aluminium citrate of lower quality fraction
Slug B profile control agents are formed, are possessed compared with low-viscosity, transfer drive can be carried out after slug A closure, to enter slug A as felt area
Domain, slug B injection rates are 0.5-0.7PV, can be considered that poly- drive is recovered the oil.
5th, in slug B, it can effectively suppress the oxygen atom in oil reservoir as oxygen scavenger by adding appropriate sodium sulfite and exchange
Cut open the viscosity reduction effect of agent generation；Using two kinds of surfactant compounds in slug B, its using effect is better than single surface-active
Agent, can improve the hydrophily of oil reservoir, reach the poly- purpose driven and improve recovery ratio.
6th, the present invention injects form by double slugs, and the hypertonic duct type Reservoir Heterogeneity of improvement, recovery percent of reserves are low, water suction
Index is low, increases sequent water flooding sweep efficiency, suppresses region of bypassed oil generation, to improve traditional oil production method to hypertonic duct type oil reservoir
The drawbacks such as recovery ratio is low, deficiency in economic performance.
Embodiment
Experimental method used in following embodiments is conventional method unless otherwise specified.
The partially hydrolyzed polyacrylamide (PHPA) used in following embodiments produces for Daqing Refinery company of CNPC, relative point
Protonatomic mass is 500*104、800*104、1000*104、1200*104、1800*104、2400*104, effective mass fraction is 90%；
Chromium acetate produces for Shandong West Asia chemical industry Co., Ltd, analyzes pure；Sodium sulfite is that Tianjin causes remote chemical reagent limited
Company produces, and analyzes pure；Resorcinol produces for Guangdong Weng Jiang chemical reagent Co., Ltd, analyzes pure；Thiocarbamide is the good grain husk in Shandong
Chemical Industry Science Co., Ltd produces, and analyzes pure；Methenamine produces for Beijing Peng Cai chemical reagent Co., Ltd, analyzes pure；Three
Poly cyanamid-formaldehyde resin produces for Jining Hong Ming chemical reagent Co., Ltd, content：>=98%；Aluminium citrate is that Jinan is prosperous refined
Chemical Co., Ltd. produces, top pure grade GR；NPE produces for Jiangsu Hai'an Petrochemical Plant, No. CAS：
9016-45-9, purity 98%；Neopelex is the small wild chemical limited company's production in Shandong, is analyzed pure；Perfluor
Alkyl betaine produces for Wuhan Sai Woer Chemical Co., Ltd.s, content：>=98%；Cocoanut fatty acid diethanolamide is mountain
The small wild chemical limited company's production in east, is analyzed pure.
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, content of oxygen dissolved in water reduction will be prepared
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, water is prepared, is 500mg/L by adding NaCl into distilled water and adjusting to salinity, to simulate actual production
The middle source water used.
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 1200*104、1800*104、2400*104, its mass ratio is 15：35：50；Complex polymer, chromium acetate, sodium sulfite,
Resorcinol, thiocarbamide, methenamine mass ratio are 0.27%：0.04%：0.3%：0.3%：0.2%：0.23%, remaining components
To prepare water.
Slug B：Complex polymer is made up of three kinds of different molecular mass fraction hydrolyzed polyacrylamides, molecular mass difference
For 500*104、800*104、1000*104, its mass ratio is 60：25：15；Complex polymer, neopelex, coconut
Fatty acid oil diglycollic amide, melamine formaldehyde resin, sodium sulfite, the mass ratio of aluminium citrate are 0.075%：
0.2%：0.2%：0.025%：0.3%：0.025%, remaining components are preparation water.
4th, specific rock core manufacture scale is as follows：
Experiment rock core is quartz sand epoxy resin cementitious homogeneous artificial core, and specific size is 4.5cm*4.5cm*
30cm, perm-plug method is 2000*10-3μm2, hypertonic duct type oil reservoir is simulated by high permeability rock core.
5th, displacement oil is viscosity 45mPa.s in the case of crude oil, 30 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 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, during the bubble-free generation of observation core surface
Stop pumping, surface water is removed into rock core taking-up wiping, weighed, quality is designated as m2；
(3) rock core that saturation is configured into water is put into core holding unit, plus confined pressure 4MPa, then with 2mL/min speed
Into rock core, injection configuration water, records the pressure and flow when pressure stability；
(4) positive injection slug A profile control agent 0.3PV, pressure during record injection profile agent into rock core, stand 24 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 and residual resistance factor.
7th, sealing characteristics evaluates such as following table
Can be drawn in from the above, slug A profile control agents to rock core profile control effect substantially, sealing ratiod up to more than 90%,
Illustrate the Complex polymer system after being combined with simulation source water 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 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 configures water, during the bubble-free generation of observation core surface
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 is 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 0.9mL/min speed forward direction injection slug A profile control agent 0.3PV, placed 18 hours after having noted, then note
Enter to prepare water 0.2PV, be subsequently injected into slug B profile control agent 0.5PV, termination of pumping, stand 30 hours it is stand-by；
(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 evaluates such as following table：
Learnt from above-mentioned data, profile control agent is prepared using simulation source water, displacement is carried out in the case of 30 DEG C of oil reservoir of simulation
Experiment, implements after profile control to high permeability rock core, has improved rock core anisotropism, improves recovery ratio 26.64%, illustrates the present 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, content of oxygen dissolved in water reduction will be prepared
To below 3mg/L；(2) under the conditions of 35 DEG C of temperature, partially hydrolyzed polyacrylamide (PHPA) is added in water and at the uniform velocity stir 2.5 to preparing
Hour, additive is added in water then to preparing, and at the uniform velocity stir 2.5 hours, obtain profile control agent；(3) it will be adjusted after the completion of preparing
Cut open agent and be directly injected into rock core.
2nd, water is prepared, is 8000mg/L by adding NaCl into distilled water and adjusting to salinity, to simulate actual life
The oilfield sewage used in 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 1200*104、1800*104、2400*104, its mass ratio is 15：35：50；Complex polymer, chromium acetate, sodium sulfite,
Resorcinol, thiocarbamide, methenamine mass ratio are 0.25%：0.03%：0.2%：0.2%：0.1%：0.2%, remaining components
To prepare water.
Slug B：Complex polymer is made up of three kinds of different molecular mass fraction hydrolyzed polyacrylamides, molecular mass difference
For 500*104、800*104、1000*104, its mass ratio is 60：25：15；Complex polymer, neopelex, perfluor
Alkyl betaine, melamine formaldehyde resin, sodium sulfite, the mass ratio of aluminium citrate are 0.05%：0.1%：0.1%：
0.02%：0.2%：0.02%, remaining components are preparation water.
4th, specific rock core manufacture scale is as follows：
Experiment rock core is quartz sand epoxy resin cementitious homogeneous artificial core, and specific size is 4.5cm*4.5cm*
30cm, perm-plug method is 2000*10-3μm2, hypertonic duct type oil reservoir is simulated by high permeability rock core.
5th, displacement oil is viscosity 55mPa.s in the case of crude oil, 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 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, during the bubble-free generation of observation core surface
Stop pumping, surface water is removed into rock core taking-up wiping, weighed, quality is designated as m6；
(3) rock core that saturation is configured into water is put into core holding unit, plus confined pressure 4MPa, then with 2mL/min speed
Into rock core, injection configuration water, records the pressure and flow when pressure stability；
(4) positive injection slug A profile control agent 0.3PV, pressure during record injection profile agent into rock core, stand 22 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 and residual resistance factor.
7th, sealing characteristics evaluates such as following table
Can be drawn in from the above, slug A profile control agents to rock core profile control effect substantially, sealing ratiod up to more than 90%,
Illustrate the Complex polymer system after being combined with simulating oil field produced water 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 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 configures water, during the bubble-free generation of observation core surface
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 is 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 0.9mL/min speed forward direction injection slug A profile control agent 0.3PV, placed 24 hours after having noted, then note
Enter to prepare water 0.2PV, be subsequently injected into slug B profile control agent 0.7PV, termination of pumping, stand 36 hours it is stand-by；
(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 evaluates such as following table：
Learnt from above-mentioned data, profile control agent is prepared using simulating oil field produced water, driven in the case of 50 DEG C of oil reservoir of simulation
For experiment, high permeability rock core is implemented after profile control, has improved rock core anisotropism, improves recovery ratio 24.49%, illustrates 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, content of oxygen dissolved in water reduction will be prepared
To below 3mg/L；(2) under the conditions of 55 DEG C of temperature, partially hydrolyzed polyacrylamide (PHPA) is added into preparation water and at the uniform velocity stirring 3 is small
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, the oilfield sewage used to simulate 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 1200*104、1800*104、2400*104, its mass ratio is 15：35：50；Complex polymer, chromium acetate, sodium sulfite,
Resorcinol, thiocarbamide, methenamine mass ratio are 0.3%：0.05%：0.4%：0.4%：0.3%：0.25%, remaining components
To prepare water.
Slug B：Complex polymer is made up of three kinds of different molecular mass fraction hydrolyzed polyacrylamides, molecular mass difference
For 500*104、800*104、1000*104, its mass ratio is 60：25：15；Complex polymer, NPE, perfluor
Alkyl betaine, melamine formaldehyde resin, sodium sulfite, the mass ratio of aluminium citrate are 0.1%：0.3%：0.3%：
0.03%：0.4%：0.03%, remaining components are preparation water.
4th, specific rock core manufacture scale is as follows：
Experiment rock core is quartz sand epoxy resin cementitious homogeneous artificial core, and specific size is 4.5cm*4.5cm*
30cm, perm-plug method is 2000*10-3μm2, hypertonic duct type oil reservoir is simulated by high permeability rock core.
5th, displacement oil is viscosity 37mPa.s in the case of crude oil, 70 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 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, during the bubble-free generation of observation core surface
Stop pumping, surface water is removed into rock core taking-up wiping, weighed, quality is designated as m10；
(3) rock core that saturation is configured into water is put into core holding unit, plus confined pressure 4MPa, then with 2mL/min speed
Into rock core, injection configuration water, records the pressure and flow when pressure stability；
(4) positive injection slug A profile control agent 0.3PV, pressure during record injection profile agent into rock core, stand 24 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 and residual resistance factor.
7th, sealing characteristics evaluates such as following table
Can be drawn in from the above, slug A profile control agents to rock core profile control effect substantially, sealing ratiod up to more than 90%,
Illustrate the Complex polymer system after being combined with simulating oil field produced water 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 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 configures water, during the bubble-free generation of observation core surface
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 is 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 0.9mL/min speed forward direction injection slug A profile control agent 0.3PV, placed 20 hours after having noted, then note
Enter to prepare water 0.2PV, be subsequently injected into slug B profile control agent 0.6PV, termination of pumping, stand 33 hours it is stand-by；
(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 evaluates such as following table：
Learnt from above-mentioned data, profile control agent is prepared using simulating oil field produced water, driven in the case of 70 DEG C of oil reservoir of simulation
For experiment, high permeability rock core is implemented after profile control, has improved rock core anisotropism, improves recovery ratio 24.63%, illustrates this hair
Bright profile control agent can improve Reservoir Heterogeneity, and profile control effect is obvious.
Claims (7)
1. a kind of hypertonic duct type oil reservoir Complex polymer 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 is by the part of three kinds of different molecular quality
Hydrolyzed polyacrylamide is constituted, and molecular mass is respectively 1200*104、1800*104、2400*104, its mass ratio is 15：35：
50；Additive includes chromium acetate, sodium sulfite, resorcinol, thiocarbamide, methenamine；In slug A profile control agents, Complex polymer
Mass ratio is 0.25%-0.3%, and chromium acetate mass ratio is 0.03%-0.05%, and sodium sulfite mass ratio is 0.2%-0.4%,
Resorcinol mass ratio is 0.2%-0.4%, and thiocarbamide mass ratio is 0.1%-0.3%, and methenamine mass ratio is 0.2%-
0.25%, 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、800*104、1000*104, its mass ratio is 60：25：15；Add
Plus agent includes surfactant, melamine formaldehyde resin, sodium sulfite, aluminium citrate；In slug B profile control agents, compounding polymerization
Amount of substance ratio is 0.05%-0.1%, and surfactant qualities ratio is 2%-6%, and melamine formaldehyde resin mass ratio is
0.02%-0.03%, sodium sulfite mass ratio is 0.2%-0.4%, and aluminium citrate mass ratio is 0.02%-0.03%, remaining
Component is preparation water.
2. a kind of hypertonic duct type oil reservoir Complex polymer profile control agent as claimed in claim 1, it is characterised in that the surface
Activating agent includes NPE, neopelex, cocoanut fatty acid diethanolamide, perfluoroalkyl sweet tea
Dish alkali or other be applied to hypertonic duct type oil reservoir surfactant.
3. a kind of hypertonic duct type oil reservoir Complex polymer profile control agent as claimed in claim 1, it is characterised in that the slug
Complex polymer, chromium acetate, sodium sulfite, resorcinol, thiocarbamide, methenamine mass ratio are 0.26%- in A profile control agents
0.29%：0.035%-0.045%：0.25%-0.35%：0.25%-0.35%：0.15%-0.25%：0.21%-
0.24%, remaining components are preparation water.
4. a kind of hypertonic duct type oil reservoir Complex polymer profile control agent as claimed in claim 1, it is characterised in that the slug
Complex polymer, chromium acetate, sodium sulfite, resorcinol, thiocarbamide, methenamine mass ratio are 0.27% in A profile control agents：
0.04%：0.3%：0.3%：0.2%：0.23%, remaining components are preparation water.
5. a kind of hypertonic duct type oil reservoir Complex polymer profile control agent as claimed in claim 1, it is characterised in that the slug
Complex polymer, surfactant, melamine formaldehyde resin, sodium sulfite, the mass ratio of aluminium citrate are in B profile control agents
0.06%-0.09%：0.25%-0.55%：0.022%-0.028%：0.25%-0.35%：0.022%-0.028%, it is remaining
The following group is divided into preparation water.
6. a kind of hypertonic duct type oil reservoir Complex polymer profile control agent as claimed in claim 1, it is characterised in that the slug
Complex polymer, surfactant, melamine formaldehyde resin, sodium sulfite, the mass ratio of aluminium citrate are in B profile control agents
0.075%：0.4%：0.025%：0.3%：0.025%, remaining components are preparation water.
7. a kind of application method of hypertonic duct type oil reservoir Complex polymer 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. pair prepares water and carries out sudden and violent oxygen processing, 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, is at the uniform velocity stirred 2-3 hours, and additive is added then to preparing in water, is at the uniform velocity stirred 2-3 hours, is obtained 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；
Step 5. slug A profile control agent injection rates reach that static 18-24 hours makes the abundant plastic of profile control agent after preset range；
Step 6. injects driven water-replacing 0.2PV, and static 30-36 hours of slug B profile control agents of injection make the abundant plastic of profile control agent, with laggard
The follow-up note of row adopts operation.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710661108.9A CN107236528A (en) | 2017-08-06 | 2017-08-06 | A kind of hypertonic duct type oil reservoir Complex polymer profile control agent and its application method |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710661108.9A CN107236528A (en) | 2017-08-06 | 2017-08-06 | A kind of hypertonic duct type oil reservoir Complex polymer profile control agent and its application method |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN107236528A true CN107236528A (en) | 2017-10-10 |
Family
ID=59989681
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201710661108.9A Withdrawn CN107236528A (en) | 2017-08-06 | 2017-08-06 | A kind of hypertonic duct type oil reservoir Complex polymer profile control agent and its application method |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN107236528A (en) |
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107794017A (en) * | 2017-10-30 | 2018-03-13 | 中国石油化工股份有限公司 | Clastic rock low pressure Oil/gas Well reservoir protection liquid and its preparation method and application |
| CN114058354A (en) * | 2021-12-06 | 2022-02-18 | 西南石油大学 | Foam oil displacement agent suitable for high-salinity low-permeability reservoir and preparation method and application thereof |
| CN114634805A (en) * | 2022-04-08 | 2022-06-17 | 中国石油大学(华东) | Self-growing gel dispersion active mobility control system and cross-flow control method for hypotonic-compact reservoir |
-
2017
- 2017-08-06 CN CN201710661108.9A patent/CN107236528A/en not_active Withdrawn
Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107794017A (en) * | 2017-10-30 | 2018-03-13 | 中国石油化工股份有限公司 | Clastic rock low pressure Oil/gas Well reservoir protection liquid and its preparation method and application |
| CN114058354A (en) * | 2021-12-06 | 2022-02-18 | 西南石油大学 | Foam oil displacement agent suitable for high-salinity low-permeability reservoir and preparation method and application thereof |
| CN114058354B (en) * | 2021-12-06 | 2022-12-13 | 西南石油大学 | Foam oil displacement agent suitable for high-salinity low-permeability reservoir and preparation method and application thereof |
| CN114634805A (en) * | 2022-04-08 | 2022-06-17 | 中国石油大学(华东) | Self-growing gel dispersion active mobility control system and cross-flow control method for hypotonic-compact reservoir |
| CN114634805B (en) * | 2022-04-08 | 2023-05-16 | 中国石油大学(华东) | Self-growing gel dispersion active fluidity control system and channeling control method for hypotonic-tight reservoirs |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN107254301A (en) | A kind of hypertonic duct type oil reservoir chromium aluminium ion compounding profile control agent and its application method | |
| CN110952952B (en) | Low-permeability reservoir deep profile control and flooding method | |
| CN107236528A (en) | A kind of hypertonic duct type oil reservoir Complex polymer profile control agent and its application method | |
| CN107338033A (en) | A kind of low-permeability sandstone oil reservoir Complex polymer type profile control agent and its application method | |
| CN107254302A (en) | A kind of Fracture with low permeability oil reservoir deep profile controlling agent and its application method | |
| CN107384349A (en) | A kind of double slug profile control agents of hypotonic duct type oil deposit deep part and its application method | |
| CN107118751A (en) | A kind of inorganic gel profile control agent and its application method for being applicable oil recovery by heating | |
| CN105199703B (en) | A kind of high temperature resistant low cross-linking ternary profile control agent and preparation method thereof | |
| CN107218009A (en) | A kind of low-permeability sandstone oil reservoir chromium aluminium ion compounding profile control agent and its application method | |
| CN107365572A (en) | A kind of double slug profile control agents of Fracture with low permeability oil deposit deep part and its application method | |
| CN107288577A (en) | A kind of double slug type profile control agents of poly- table of low-permeability sandstone oil reservoir and its application method | |
| CN109385257A (en) | A kind of double slug Compositional type profile control agents of low-permeability sandstone oil reservoir and its application method | |
| CN107384351A (en) | A kind of double slug compounding profile control agents of hypotonic duct type oil reservoir and its application method | |
| CN107267129A (en) | A kind of double slug deep electrical structures of hypotonic duct type oil reservoir and its application method | |
| CN113136185A (en) | Organic water plugging gel for low-temperature hypersalinity oil reservoir | |
| CN107218020A (en) | A kind of double slug type profile control agents of poly- table of hypertonic sandstone oil reservoir and its application method | |
| CN105754565A (en) | Organic microsphere and inorganic silicate compounded type channeling sealing agent for thermal extraction of heavy oil and preparation method of channeling sealing agent | |
| CN107267128A (en) | A kind of double slug type profile control agents of hypertonic poly- table of duct type oil reservoir and its application method | |
| CN109852362A (en) | The double slug profile control agents and its method for implanting that heterogeneous reservoir predominant pathway controls after a kind of poly- drive | |
| CN107384346A (en) | A kind of hypertonic sandstone oil reservoir Complex polymer type profile control agent and its application method | |
| CN107345132A (en) | A kind of compound rhythm oil reservoir Complex polymer type profile control agent and its application method | |
| CN107384344A (en) | A kind of double slug Compositional type profile control agents of anti-rhythm oil reservoir and its application method | |
| CN107418539A (en) | A kind of double slug profile control agents of hypertonic duct type oil reservoir and its application method | |
| CN107338035A (en) | A kind of compound rhythm oil reservoir chromium aluminium ion Compositional type profile control agent and its application method | |
| CN107474812A (en) | A kind of double slug type profile control agents of poly- table of compact oil reservoir and its application method |
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 | ||
| WW01 | Invention patent application withdrawn after publication | ||
| WW01 | Invention patent application withdrawn after publication |
Application publication date: 20171010 |