CN107338033A - A kind of low-permeability sandstone oil reservoir Complex polymer type profile control agent and its application method - Google Patents
A kind of low-permeability sandstone oil reservoir Complex polymer type profile control agent and its application method Download PDFInfo
- Publication number
- CN107338033A CN107338033A CN201710663074.7A CN201710663074A CN107338033A CN 107338033 A CN107338033 A CN 107338033A CN 201710663074 A CN201710663074 A CN 201710663074A CN 107338033 A CN107338033 A CN 107338033A
- Authority
- CN
- China
- Prior art keywords
- profile control
- water
- oil reservoir
- low
- slug
- 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- Withdrawn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 60
- 238000000034 method Methods 0.000 title claims abstract description 24
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 132
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 95
- 239000004927 clay Substances 0.000 claims abstract description 23
- 238000004519 manufacturing process Methods 0.000 claims abstract description 19
- 239000003381 stabilizer Substances 0.000 claims abstract description 17
- 239000004094 surface-active agent Substances 0.000 claims abstract description 15
- 239000003921 oil Substances 0.000 claims description 83
- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid Chemical compound OC(=O)CC(O)(C(O)=O)CC(O)=O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 claims description 78
- GHMLBKRAJCXXBS-UHFFFAOYSA-N resorcinol Chemical compound OC1=CC=CC(O)=C1 GHMLBKRAJCXXBS-UHFFFAOYSA-N 0.000 claims description 44
- 238000002347 injection Methods 0.000 claims description 36
- 239000007924 injection Substances 0.000 claims description 36
- YGSDEFSMJLZEOE-UHFFFAOYSA-N salicylic acid Chemical compound OC(=O)C1=CC=CC=C1O YGSDEFSMJLZEOE-UHFFFAOYSA-N 0.000 claims description 26
- 235000010299 hexamethylene tetramine Nutrition 0.000 claims description 24
- VKYKSIONXSXAKP-UHFFFAOYSA-N hexamethylenetetramine Chemical compound C1N(C2)CN3CN1CN2C3 VKYKSIONXSXAKP-UHFFFAOYSA-N 0.000 claims description 24
- 229960004011 methenamine Drugs 0.000 claims description 24
- 238000002360 preparation method Methods 0.000 claims description 23
- 229920002401 polyacrylamide Polymers 0.000 claims description 20
- FJKROLUGYXJWQN-UHFFFAOYSA-N papa-hydroxy-benzoic acid Natural products OC(=O)C1=CC=C(O)C=C1 FJKROLUGYXJWQN-UHFFFAOYSA-N 0.000 claims description 13
- 229960004889 salicylic acid Drugs 0.000 claims description 13
- 239000000654 additive Substances 0.000 claims description 12
- 230000000996 additive effect Effects 0.000 claims description 12
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 claims description 10
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims description 10
- 238000002156 mixing Methods 0.000 claims description 10
- 239000001301 oxygen Substances 0.000 claims description 10
- 229910052760 oxygen Inorganic materials 0.000 claims description 10
- 238000003756 stirring Methods 0.000 claims description 8
- 235000019270 ammonium chloride Nutrition 0.000 claims description 5
- -1 perfluoroalkyl betain Chemical compound 0.000 claims description 5
- 238000012545 processing Methods 0.000 claims description 5
- 239000000203 mixture Substances 0.000 claims description 4
- 229920003023 plastic Polymers 0.000 claims description 4
- 239000004033 plastic Substances 0.000 claims description 4
- 239000010865 sewage Substances 0.000 claims description 4
- DDXLVDQZPFLQMZ-UHFFFAOYSA-M dodecyl(trimethyl)azanium;chloride Chemical compound [Cl-].CCCCCCCCCCCC[N+](C)(C)C DDXLVDQZPFLQMZ-UHFFFAOYSA-M 0.000 claims description 3
- 150000001412 amines Chemical class 0.000 claims description 2
- 229960004106 citric acid Drugs 0.000 claims description 2
- 238000013461 design Methods 0.000 claims description 2
- 230000007062 hydrolysis Effects 0.000 claims description 2
- 238000006460 hydrolysis reaction Methods 0.000 claims description 2
- 229960001755 resorcinol Drugs 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
- 230000003213 activating effect Effects 0.000 claims 1
- 238000011084 recovery Methods 0.000 abstract description 17
- 238000007789 sealing Methods 0.000 abstract description 11
- 239000002245 particle Substances 0.000 abstract description 9
- 239000000084 colloidal system Substances 0.000 abstract description 5
- 230000008961 swelling Effects 0.000 abstract description 5
- 238000012546 transfer Methods 0.000 abstract description 3
- 230000007812 deficiency Effects 0.000 abstract description 2
- 239000000126 substance Substances 0.000 abstract description 2
- 239000011435 rock Substances 0.000 description 85
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 22
- 238000005086 pumping Methods 0.000 description 21
- 238000002474 experimental method Methods 0.000 description 20
- 230000035699 permeability Effects 0.000 description 16
- 238000006073 displacement reaction Methods 0.000 description 14
- 230000000694 effects Effects 0.000 description 11
- 239000011780 sodium chloride Substances 0.000 description 11
- 230000015572 biosynthetic process Effects 0.000 description 9
- 239000010779 crude oil Substances 0.000 description 9
- 230000008569 process Effects 0.000 description 9
- 239000000725 suspension Substances 0.000 description 8
- 239000012153 distilled water Substances 0.000 description 7
- 238000004088 simulation Methods 0.000 description 7
- 239000005995 Aluminium silicate Substances 0.000 description 6
- 235000012211 aluminium silicate Nutrition 0.000 description 6
- 238000001816 cooling Methods 0.000 description 6
- 238000001035 drying Methods 0.000 description 6
- 238000011156 evaluation Methods 0.000 description 6
- NLYAJNPCOHFWQQ-UHFFFAOYSA-N kaolin Chemical compound O.O.O=[Al]O[Si](=O)O[Si](=O)O[Al]=O NLYAJNPCOHFWQQ-UHFFFAOYSA-N 0.000 description 6
- 238000011017 operating method Methods 0.000 description 6
- 239000002352 surface water Substances 0.000 description 6
- 238000012360 testing method Methods 0.000 description 6
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 4
- 238000004458 analytical method Methods 0.000 description 4
- 239000003153 chemical reaction reagent Substances 0.000 description 4
- XQJMXPAEFMWDOZ-UHFFFAOYSA-N 3exo-benzoyloxy-tropane Natural products CN1C(C2)CCC1CC2OC(=O)C1=CC=CC=C1 XQJMXPAEFMWDOZ-UHFFFAOYSA-N 0.000 description 3
- QQXLDOJGLXJCSE-UHFFFAOYSA-N N-methylnortropinone Natural products C1C(=O)CC2CCC1N2C QQXLDOJGLXJCSE-UHFFFAOYSA-N 0.000 description 3
- ISWSIDIOOBJBQZ-UHFFFAOYSA-N Phenol Chemical compound OC1=CC=CC=C1 ISWSIDIOOBJBQZ-UHFFFAOYSA-N 0.000 description 3
- QIZDQFOVGFDBKW-DHBOJHSNSA-N Pseudotropine Natural products OC1C[C@@H]2[N+](C)[C@H](C1)CC2 QIZDQFOVGFDBKW-DHBOJHSNSA-N 0.000 description 3
- 239000006004 Quartz sand Substances 0.000 description 3
- 230000009471 action Effects 0.000 description 3
- 239000003814 drug Substances 0.000 description 3
- 239000003822 epoxy resin Substances 0.000 description 3
- 239000012530 fluid Substances 0.000 description 3
- 229920000647 polyepoxide Polymers 0.000 description 3
- CYHOMWAPJJPNMW-JIGDXULJSA-N tropine Chemical compound C1[C@@H](O)C[C@H]2CC[C@@H]1N2C CYHOMWAPJJPNMW-JIGDXULJSA-N 0.000 description 3
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 description 2
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 description 2
- 239000002253 acid Substances 0.000 description 2
- 230000008859 change Effects 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 230000018109 developmental process Effects 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 238000005189 flocculation Methods 0.000 description 2
- 230000016615 flocculation Effects 0.000 description 2
- 239000007789 gas Substances 0.000 description 2
- PCHJSUWPFVWCPO-UHFFFAOYSA-N gold Chemical compound [Au] PCHJSUWPFVWCPO-UHFFFAOYSA-N 0.000 description 2
- 239000010931 gold Substances 0.000 description 2
- 229910052737 gold Inorganic materials 0.000 description 2
- 230000001965 increasing effect Effects 0.000 description 2
- 150000002500 ions Chemical class 0.000 description 2
- 230000007246 mechanism Effects 0.000 description 2
- 239000002244 precipitate Substances 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 229910052708 sodium Inorganic materials 0.000 description 2
- 239000011734 sodium Substances 0.000 description 2
- 230000010148 water-pollination Effects 0.000 description 2
- QGZKDVFQNNGYKY-UHFFFAOYSA-O Ammonium Chemical compound [NH4+] QGZKDVFQNNGYKY-UHFFFAOYSA-O 0.000 description 1
- 235000005979 Citrus limon Nutrition 0.000 description 1
- 244000131522 Citrus pyriformis Species 0.000 description 1
- 241000196324 Embryophyta Species 0.000 description 1
- 241000237858 Gastropoda Species 0.000 description 1
- 101150042248 Mgmt gene Proteins 0.000 description 1
- 239000004743 Polypropylene Substances 0.000 description 1
- 241000219000 Populus Species 0.000 description 1
- 208000013201 Stress fracture Diseases 0.000 description 1
- 206010070863 Toxicity to various agents Diseases 0.000 description 1
- 208000027418 Wounds and injury Diseases 0.000 description 1
- 150000001408 amides Chemical class 0.000 description 1
- 230000009286 beneficial effect Effects 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
- 239000003054 catalyst Substances 0.000 description 1
- YCIMNLLNPGFGHC-UHFFFAOYSA-N catechol Chemical compound OC1=CC=CC=C1O YCIMNLLNPGFGHC-UHFFFAOYSA-N 0.000 description 1
- 239000013043 chemical agent Substances 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000005660 chlorination reaction Methods 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 230000006378 damage Effects 0.000 description 1
- 230000000593 degrading effect Effects 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 239000008187 granular material Substances 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 208000014674 injury Diseases 0.000 description 1
- 125000001400 nonyl group Chemical group [H]C([*])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])[H] 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 230000002093 peripheral effect Effects 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 229960003742 phenol Drugs 0.000 description 1
- 229920001155 polypropylene Polymers 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 238000009738 saturating Methods 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
- C09K8/512—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
-
- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
Landscapes
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Organic Chemistry (AREA)
- Materials Engineering (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Curing Cements, Concrete, And Artificial Stone (AREA)
Abstract
A kind of low-permeability sandstone oil reservoir Complex polymer type profile control agent and its application method, are related to field use chemical field.The present invention injects low-permeability sandstone oil reservoir by double slug forms, preposed attributives are polymolecular Compositional type polymer, it can be combined, be formed around core formula molecular coil structural polymer with insoluble suspended particle in oil reservoir, selective shut-off is implemented to oil reservoir microcrack, macropore；Rearmounted slug is low viscosity Complex polymer, and adds appropriate clay stabilizer and surfactant, to implementing transfer drive without sealing region, can suppress low-permeability sandstone oil reservoir clay swelling phenomenon, improves wax, colloid, asphalitine and is deposited near wellbore zone；The present invention can improve Reservoir Heterogeneity, increase sequent water flooding sweep efficiency, suppress low-permeability sandstone oil reservoir region of bypassed oil and formed, to improve the drawbacks such as traditional oil production method, deficiency in economic performance low to low-permeability sandstone oil recovery.
Description
Technical field
The present invention relates to a kind of low-permeability sandstone oil reservoir Complex polymer type profile control agent and its application method, the profile control agent to change
Kind reservoir adaptability, and then low-permeability sandstone type oil reservoir oil increasing effect can be improved, belong to field use chemical agent field.
Background technology
On the definition of low-permeability sandstone oil reservoir, there is kinds of schemes both at home and abroad, it changes with the change of economic civilization technology
Become.Low permeability oil field is divided into 3 classes by Chinese scholar according to oil reservoir mean permeability：1. general low permeability oil field-oil reservoir averagely oozes
Saturating rate is (50~10.1) * 10-3μm2；2. extra permeability oilfield-oil reservoir mean permeability is (10.0~1.1) * 10-3μm2；③
Ultra-low penetration oil field-oil reservoir mean permeability is (1.0~0.1) * 10-3μm2。
As deepening continuously for oil-gas exploration work, the raising year by year of degree of prospecting, oil-gas exploration difficulty are also more and more big,
Unconventional petroleum resources has turned into the focus of exploration and development.Low-permeability sandstone oil reservoir is because oil-layer distribution is complicated, in actual development mistake
There is following drawback in journey：
1st, low-permeability sandstone oil reservoir has the feature that permeability is low, pore throat is narrow and microcrack is developed, and with necessarily non-
Homogenieity.
2nd, due to the influence of the factors such as temperature, pressure, easily cause water breakthrough occurs during water drive, fingering, non-available water follow
Phenomena such as ring and clay swelling.
3rd, in operation process, reservoir is highly prone to the injury of the external fluid that is incompatible, simultaneously because the factor such as temperature, pressure
Influence, easily cause wax, colloid, asphalitine near wellbore zone deposit, formed organic plugging.
4 however research of the tradition to low-permeability sandstone oil reservoir is concentrated mainly on the techniques such as acidifying, pressure break, it is oily to low-permeability sandstone
It is less to hide profile control research.
For low-permeability sandstone oil reservoir improve recovery efficiency technique demand, the present invention provides a kind of applied to low-permeability sandstone oil reservoir
Complex polymer type profile control agent, it is set forth above for solving the problems, such as.
The content of the invention
It is an object of the invention to provide a kind of low-permeability sandstone oil reservoir Complex polymer type profile control agent and its application method, leads to
Double slug form injection low-permeability sandstone oil reservoirs are crossed, preposed attributives are polymolecular Compositional type polymer, can the insoluble suspension with oil reservoir
Composition granule is combined, and is formed around core formula molecular coil structural polymer, implements selective shut-off to oil reservoir microcrack, macropore；
Rearmounted slug is low viscosity Complex polymer, and adds appropriate clay stabilizer and surfactant, to real without sealing region
Transfer drive is applied, low-permeability sandstone oil reservoir clay swelling phenomenon can be suppressed, improves wax, colloid, asphalitine and is deposited near wellbore zone；This hair
It is bright to improve Reservoir Heterogeneity, increase sequent water flooding sweep efficiency, suppress low-permeability sandstone oil reservoir region of bypassed oil and formed, passed with improving
The drawbacks such as oil production method, deficiency in economic performance low to low-permeability sandstone oil recovery of uniting.
To reach above-mentioned purpose, the present invention adopts the following technical scheme that.
A kind of low-permeability 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、800*104、1000*104, clay stabilizer, surfactant, citric acid, isophthalic two
Phenol, salicylic acid, methenamine；Wherein clay stabilizer concretely ammonium chloride, DTAC and other
Be applicable includes NPE, DBSA with the clay stabilizer of low-permeability sandstone oil reservoir, surfactant
Sodium and perfluoroalkyl betain；For low-permeability sandstone oil reservoir, double slug formula profile control agents are designed, below with slug A profile control agents and section
B profile control agents are filled in 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、800*104、1000*104, its mass ratio is 50：35：
15；Additive includes citric acid, resorcinol, methenamine；In slug A profile control agents, Complex polymer mass ratio is 0.1%-
0.15%, citric acid mass ratio is 0.1%-0.2%, and resorcinol mass ratio is 0.02%-0.03%, methenamine mass ratio
For 0.03%-0.06%, remaining components are preparation water.
Preferably, in slug A profile control agents, Complex polymer, citric acid, resorcinol, methenamine mass ratio are
0.11%-0.14%：0.12%-0.18%：0.022%-0.028%：0.04%-0.05%, remaining components are preparation water.
It is highly preferred that in slug A profile control agents, Complex polymer, citric acid, resorcinol, methenamine mass ratio are
0.125%：0.15%：0.025%：0.045%, remaining components are preparation water.
Slug A profile control agent main function mechanism is to be formed by mixing different molecular mass fraction hydrolyzed polyacrylamide
Molecular coil structural polymer, after stratum is injected, it is in contact with the clay particle in stratum or other insoluble suspensions, and phase
With reference to polyacrylamide amine molecule can be increased by forming resorcinol and methenamine in core formula molecular coil type polymer, slug A
The activity of ball of string peripheral groups so that slug A is in contact partly with sandstone has larger viscosity, so as to realize to low-permeability sandstone
Oil reservoir microcrack, macropore implement selective shut-off；Citric acid plays the acidity effect of regulation base fluid, adds first in configuration process
Enter, it is combined with preparing underwater gold category ion, reduce due to prepares in water salinity it is high caused by precipitate, flocculation,
Equally there is certain crosslinked action；Slug A is mainly used as blocking the microcrack or macropore in low-permeability sandstone oil reservoir, improves low
The anisotropism of sandstone oil reservoir is oozed, 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、800*104、1000*104, its mass ratio is 80：15：5；
Additive includes clay stabilizer, surfactant, citric acid, resorcinol, salicylic acid, methenamine；Slug B profile control agents
In, Complex polymer mass ratio is 0.05%-0.1%, and clay stabilizer mass ratio is 0.2%-0.3%, surfactant matter
It is 0.1%-0.3% to measure ratio, and citric acid mass ratio is 0.1%-0.2%, and resorcinol mass ratio is 0.02%-0.03%, water
Poplar acid mass ratio is 0.02%-0.03%, and methenamine mass ratio is 0.02%-0.03%, and remaining components are preparation water.
Preferably, in slug B profile control agents, Complex polymer, clay stabilizer, surfactant, citric acid, isophthalic two
Phenol, salicylic acid, the mass ratio of methenamine are 0.06%-0.09%：0.22%-0.28%：0.15%-0.2%：0.12%-
0.18%：0.022%-0.028%：0.022%-0.028%：0.022%-0.028%, remaining components are preparation water.
It is highly preferred that in slug B profile control agents, Complex polymer, clay stabilizer, surfactant, citric acid, isophthalic two
Phenol, salicylic acid, the mass ratio of methenamine are 0.075%：0.25%：0.175%：0.15%：0.025%：0.025%：
0.025%, remaining components are preparation water.
Slug B main function mechanism is, by mixing low quality fractional part hydrolyzed polyacrylamide and methenamine shape
Into Complex polymer, and appropriate clay stabilizer is added in profile control agent, possess that low viscosity, mobility are strong, shear resistant is strong
Feature, it can lower and ooze phenomena such as water breakthrough, fingering, invalid water circulation and clay swelling occur during sandstone oil reservoir water drive；Between
Benzenediol plays catalyst action, can shorten the time of configuration profile control agent, it is reduced operating cost in operation process；Lemon
Acid, salicylic acid play the acidity effect of regulation base fluid, are firstly added in configuration process, it is mutually tied with preparing underwater gold category ion
Close, reduce due to prepares in water salinity it is high caused by precipitate, flocculation, equally with certain crosslinked action；In slug B
Appropriate surfactant is added, the phenomenon that wax, colloid, asphalitine deposit near wellbore zone can be improved, and sandstone can be improved
The hydrophily of oil reservoir, reaching the poly- purpose driven and improve recovery ratio, surfactant is eventually adding in slug B process for preparation, with
Avoid degrading with citric acid, salicylism reaction in configuration process；After slug A blocks to low-permeability sandstone oil reservoir, slug B
Transfer drive is implemented in the duct that water drive is difficult to involve before being blocked to script, double slug synergies is realized, so as to improve low-permeability sandstone
Oil reservoir oil recovery.
A kind of application method of low-permeability 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
It 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, additive is added then to preparing in water, at the uniform velocity stirs 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 24-48 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 0.4PV, injects slug B profile control agents, then carries out follow-up note and adopts operation.
The specific injection rate of profile control agent is：Slug A profile control agent 0.2PV are injected first into oil reservoir or rock core, wait 24-48 small
When make slug A profile control agents progressively plastic, then in oil reservoir or rock core inject driven water-replacing 0.4PV, then in oil reservoir or rock core
Slug B profile control agent 0.5-0.7PV are injected, follow-up note is then carried out and adopts operation.
The present invention the advantage is that relative to prior art：
1st, for the anisotropism of low-permeability sandstone oil reservoir, and microcrack that may be present, slug A profile control agents can with stratum
Insoluble suspended particle is combined, and is formed around core formula molecular coil structure, can carry out selective envelope to reservoir micro-fractures, macropore
It is stifled, improve the anisotropism of low-permeability sandstone oil reservoir.
2nd, in slug B, Complex polymer is formed by the polyacrylamide and methenamine that mix lower quality fraction, and
Appropriate clay stabilizer is added in profile control agent, possesses the feature that low viscosity, mobility are strong, shear resistant is strong, can lower and ooze sand
Phenomena such as water breakthrough, fingering, invalid water circulation and clay swelling occur during rock reservoir water drive.
3rd, proper amount of surfactant is added in slug B, wax, colloid, asphalitine can be improved and showed what near wellbore zone deposited
As, and the hydrophily of sandstone oil reservoir can be improved, reach the poly- purpose driven and improve recovery ratio.
4th, profile control agent of the present invention uses polymolecular Compositional type polymer, and its molecular structure is suitable for high salinity and prepares water,
Plastic rear stability is high；And preparation water salinity is smaller on the influence of polymer coils size, shear resistant is good.
5th, the present invention injects form by double slugs, and improvement low-permeability sandstone Reservoir Heterogeneity, recovery percent of reserves are low, after increase
Continuous water drive sweep efficiency, suppress region of bypassed oil generation, traditional oil production method is low to low-permeability sandstone oil recovery, 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、800*104、1000*104, effective mass fraction is 90%；Citric acid is the limited public affairs of Nanjing chemical reagent share
Department's production, specification：AR, 99.5%；Resorcinol produces for Guangdong Weng Jiang chemical reagent Co., Ltd, and analysis is pure；Methenamine
Produced for Beijing Peng Cai chemical reagent Co., Ltd, analysis is pure；Salicylic acid produces for Nanjing chemical reagent limited company, point
Analyse pure；Ammonium chloride produces for Nanjing chemical reagent limited company, specification：ACS, 99.5%；Trimethyl chlorination
Ammonium produces for Nanjing chemical reagent limited company, purity 98%；NPE is Jiangsu Province Hai'an oil
Plant produced, No. CAS：9016-45-9, purity 98%；Neopelex is the small chemical limited company in open country in Shandong
Production, 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, water is prepared, is 500mg/L by adding NaCl and adjusting to salinity, to simulate the water used in actual production
Source water.
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、800*104、1000*104, its mass ratio is 50：35：15；Complex polymer, citric acid, resorcinol, crow
Lip river tropine mass ratio is 0.125%：0.15%：0.025%：0.045%, 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、800*104、1000*104, its mass ratio is 80：15：5；Complex polymer, DTAC,
Perfluoroalkyl betain, citric acid, resorcinol, salicylic acid, the mass ratio of methenamine are 0.075%：0.25%：
0.175%：0.15%：0.025%：0.025%：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 three layers of heterogeneous artificial cores, and specific size is 4.5cm*
4.5cm*30cm, perm-plug method are respectively 10*10-3μm2、30*10-3μm2、50*10-3μm2, and add in rock core manufacturing process
Enter the NaCl of 5% volume fraction, to simulated formation microcrack；Low-permeability sandstone oil reservoir is entered by manually manufacturing heterogeneous core
Row simulation.
5th, displacement oil is crude oil, viscosity 35mPa.s in the case of 40 DEG C.
6th, sealing characteristics test operating procedure is as follows：
(1) rock core to be used is put into core holding unit, positive water drive, water drive is distilled water with water, until in rock core
NaCl all with driven water-replacing discharge by dissolving, with injection 10mg/L kaolin (0.5 μm -2 μm of particle diameter) mixing water in after image rock core
0.2PV, to insoluble suspension in simulated formation, rock core is taken out after injection；
(2) 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；
(3) 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；
(4) rock core that saturation is configured to water is put into core holding unit, adds confined pressure 4MPa, then with 0.4mL/min speed
The injection configuration water into rock core is spent, the pressure and flow are recorded when pressure stability；
(5) the positive injection slug A profile control agent 0.2PV into rock core, record pressure during injection profile agent, stand 24 hours
It is stand-by；
(6) 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；
(7) whole experiment is carried out in the case of 40 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, slug A profile control agents pair
Three layers of non-average rock core have a weak seal-off effect, and profile control agent is moveable in rock core, and leaving displacement to be subsequently implanted into slug B leads to
Road.
8th, oil-displacement capacity test operating procedure is as follows：
(1) rock core to be used is put into core holding unit, positive water drive, water drive is distilled water with water, until in rock core
NaCl all with driven water-replacing discharge by dissolving, with injection 10mg/L kaolin (0.5 μm -2 μm of particle diameter) mixing water in after image rock core
0.2PV, to insoluble suspension in simulated formation, rock core is taken out after injection；
(2) 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；
(3) 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；
(4) 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；
(5) 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 40 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；
(6) with the positive injection slug A profile control agent 0.2PV of 0.9mL/min speed, placed 48 hours after having noted, then note
Enter to prepare water 0.4PV, be subsequently injected into slug B profile control agent 0.6PV, termination of pumping；
(7) 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 simulation source water, displacement is carried out in the case of 40 DEG C of oil reservoir is simulated
Experiment, after implementing profile control to three layers of heterogeneous core, simulation core anisotropism is improved, has improved recovery ratio 26.91%, explanation
Profile control agent of the present invention 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, water is prepared, is 8000mg/L by adding NaCl and adjusting to salinity, to simulate what is used in 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、800*104、1000*104, its mass ratio is 50：35：15；Complex polymer, citric acid, resorcinol, crow
Lip river tropine mass ratio is 0.1%：0.1%：0.02%：0.03%, 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、800*104、1000*104, its mass ratio is 80：15：5；Complex polymer, ammonium chloride, DBSA
Sodium, citric acid, resorcinol, salicylic acid, the mass ratio of methenamine are 0.05%：0.2%：0.1%：0.1%：0.02%：
0.02%：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 three layers of heterogeneous artificial cores, and specific size is 4.5cm*
4.5cm*30cm, perm-plug method are respectively 10*10-3μm2、20*10-3μm2、30*10-3μm2, and add in rock core manufacturing process
Enter the NaCl of 5% volume fraction, to simulated formation microcrack；Low-permeability sandstone oil reservoir is entered by manually manufacturing heterogeneous core
Row simulation.
5th, displacement oil is crude oil, and viscosity is 55mPa.s during temperature 50 C.
6th, sealing characteristics test operating procedure is as follows：
(1) rock core to be used is put into core holding unit, positive water drive, water drive is distilled water with water, until in rock core
NaCl all with driven water-replacing discharge by dissolving, with injection 10mg/L kaolin (0.5 μm -2 μm of particle diameter) mixing water in after image rock core
0.2PV, to insoluble suspension in simulated formation, rock core is taken out after injection；
(2) 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；
(3) 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；
(4) rock core that saturation is configured to water is put into core holding unit, adds confined pressure 4MPa, then with 0.4mL/min speed
The injection configuration water into rock core is spent, the pressure and flow are recorded when pressure stability；
(5) the positive injection slug A profile control agent 0.2PV into rock core, record pressure during injection profile agent, stand 36 hours
It is stand-by；
(6) 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；
(7) 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, slug A profile control agents pair
Three layers of non-average rock core have a weak seal-off effect, and profile control agent is moveable in rock core, and leaving displacement to be subsequently implanted into slug B leads to
Road.
8th, oil-displacement capacity test operating procedure is as follows：
(1) rock core to be used is put into core holding unit, positive water drive, water drive is distilled water with water, until in rock core
NaCl all with driven water-replacing discharge by dissolving, with injection 10mg/L kaolin (0.5 μm -2 μm of particle diameter) mixing water in after image rock core
0.2PV, to insoluble suspension in simulated formation, rock core is taken out after injection；
(2) 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；
(3) 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；
(4) 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；
(5) 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；
(6) with the positive injection slug A profile control agent 0.2PV of 0.9mL/min speed, placed 36 hours after having noted, then note
Enter to prepare water 0.4PV, be subsequently injected into slug B profile control agent 0.7PV, termination of pumping；
(7) 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 50 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 24.59%, say
Bright profile control agent of the present invention 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、800*104、1000*104, its mass ratio is 50：35：15；Complex polymer, citric acid, resorcinol, crow
Lip river tropine mass ratio is 0.15%：0.2%：0.03%：0.06%, 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、800*104、1000*104, its mass ratio is 80：15：5；Complex polymer, ammonium chloride, Nonyl pheno
Ether, citric acid, resorcinol, salicylic acid, the mass ratio of methenamine are 0.1%：0.3%：0.3%：0.2%：0.03%：
0.03%：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 three layers of heterogeneous artificial cores, and specific size is 4.5cm*
4.5cm*30cm, perm-plug method are respectively 10*10-3μm2、20*10-3μm2、40*10-3μm2, and add in rock core manufacturing process
Enter the NaCl of 8% volume fraction, to simulated formation microcrack；Low-permeability sandstone oil reservoir is entered by manually manufacturing heterogeneous core
Row simulation.
5th, displacement oil is crude oil, and viscosity is 35mPa.s during temperature 70 C.
6th, sealing characteristics test operating procedure is as follows：
(1) rock core to be used is put into core holding unit, positive water drive, water drive is distilled water with water, until in rock core
NaCl all with driven water-replacing discharge by dissolving, with injection 10mg/L kaolin (0.5 μm -2 μm of particle diameter) mixing water in after image rock core
0.2PV, to insoluble suspension in simulated formation, rock core is taken out after injection；
(2) 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；
(3) 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；
(4) 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；
(5) 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；
(6) 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；
(7) 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, slug A profile control agents pair
Three layers of non-average rock core have a weak seal-off effect, and profile control agent is moveable in rock core, and leaving displacement to be subsequently implanted into slug B leads to
Road.
8th, oil-displacement capacity test operating procedure is as follows：
(1) rock core to be used is put into core holding unit, positive water drive, water drive is distilled water with water, until in rock core
NaCl all with driven water-replacing discharge by dissolving, with injection 10mg/L kaolin (0.5 μm -2 μm of particle diameter) mixing water in after image rock core
0.2PV, to insoluble suspension in simulated formation, rock core is taken out after injection；
(2) 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；
(3) 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；
(4) 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；
(5) 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；
(6) with the positive injection slug A profile control agent 0.2PV of 0.9mL/min speed, placed 24 hours after having noted, then note
Enter to prepare water 0.4PV, be subsequently injected into slug B profile control agent 0.5PV, termination of pumping；
(7) 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 70 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 23.41%, 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 low-permeability 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、800*104、1000*104, its mass ratio is 50：35：15；
Additive includes citric acid, resorcinol, methenamine；In slug A profile control agents, Complex polymer mass ratio is 0.1%-
0.15%, citric acid mass ratio is 0.1%-0.2%, and resorcinol mass ratio is 0.02%-0.03%, methenamine mass ratio
For 0.03%-0.06%, 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 80：15：5；Addition
Agent includes clay stabilizer, surfactant, citric acid, resorcinol, salicylic acid, methenamine；It is multiple in slug B profile control agents
It is 0.05%-0.1% with polymer quality ratio, clay stabilizer mass ratio is 0.2%-0.3%, and surfactant qualities ratio is
0.1%-0.3%, citric acid mass ratio are 0.1%-0.2%, and resorcinol mass ratio is 0.02%-0.03%, salicylic acid matter
It is 0.02%-0.03% to measure ratio, and methenamine mass ratio is 0.02%-0.03%, and remaining components are preparation water.
A kind of 2. low-permeability 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 low-permeability sandstone oil reservoir clay stabilizer.
A kind of 3. low-permeability 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. low-permeability sandstone oil reservoir Complex polymer type profile control agent as claimed in claim 1, it is characterised in that the slug
Complex polymer, citric acid, resorcinol, methenamine mass ratio are 0.11%-0.14% in A profile control agents：0.12%-
0.18%：0.022%-0.028%：0.04%-0.05%, remaining components are preparation water.
A kind of 5. low-permeability sandstone oil reservoir Complex polymer type profile control agent as claimed in claim 1, it is characterised in that the slug
Complex polymer, citric acid, resorcinol, methenamine mass ratio are 0.125% in A profile control agents：0.15%：0.025%：
0.045%, remaining components are preparation water.
A kind of 6. low-permeability sandstone oil reservoir Complex polymer type profile control agent as claimed in claim 1, it is characterised in that the slug
Complex polymer, clay stabilizer, surfactant, citric acid, resorcinol, salicylic acid, the matter of methenamine in B profile control agents
It is 0.06%-0.09% to measure ratio：0.22%-0.28%：0.15%-0.2%：0.12%-0.18%：0.022%-0.028%：
0.022%-0.028%：0.022%-0.028%, remaining components are preparation water.
A kind of 7. low-permeability sandstone oil reservoir Complex polymer type profile control agent as claimed in claim 1, it is characterised in that the slug
Complex polymer, clay stabilizer, surfactant, citric acid, resorcinol, salicylic acid, the matter of methenamine in B profile control agents
Amount is than being 0.075%：0.25%：0.175%：0.15%：0.025%：0.025%：0.025%, remaining components are preparation water.
8. a kind of application method of low-permeability 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 24-48 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 0.4PV, injects slug B profile control agents, then carries out follow-up note and adopts operation.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710663074.7A CN107338033A (en) | 2017-08-06 | 2017-08-06 | A kind of low-permeability sandstone oil reservoir Complex polymer type profile control agent and its application method |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710663074.7A CN107338033A (en) | 2017-08-06 | 2017-08-06 | A kind of low-permeability sandstone oil reservoir Complex polymer type profile control agent and its application method |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN107338033A true CN107338033A (en) | 2017-11-10 |
Family
ID=60217789
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201710663074.7A Withdrawn CN107338033A (en) | 2017-08-06 | 2017-08-06 | A kind of low-permeability sandstone oil reservoir Complex polymer type profile control agent and its application method |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN107338033A (en) |
Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN111622725A (en) * | 2020-06-02 | 2020-09-04 | 中国石油化工股份有限公司 | Profile control method suitable for heterogeneous oil reservoir after polymer flooding |
| CN114989800A (en) * | 2022-06-30 | 2022-09-02 | 常州大学 | Preparation method of surfactant for improving recovery ratio of low-permeability sandstone reservoir |
| CN115058240A (en) * | 2022-06-30 | 2022-09-16 | 常州大学 | Preparation method and application of oil displacement agent for improving recovery ratio of low-permeability sandstone reservoir |
| CN115074101A (en) * | 2022-06-30 | 2022-09-20 | 常州大学 | Preparation method and application of surfactant with reservoir protection effect for oil displacement of low-permeability sandstone reservoir |
| CN116044391A (en) * | 2023-03-09 | 2023-05-02 | 西南石油大学 | Method for determining dosage of profile control agent of low permeability reservoir horizontal well |
-
2017
- 2017-08-06 CN CN201710663074.7A patent/CN107338033A/en not_active Withdrawn
Cited By (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN111622725A (en) * | 2020-06-02 | 2020-09-04 | 中国石油化工股份有限公司 | Profile control method suitable for heterogeneous oil reservoir after polymer flooding |
| CN111622725B (en) * | 2020-06-02 | 2022-07-19 | 中国石油化工股份有限公司 | Profile control method suitable for heterogeneous oil reservoir after polymer flooding |
| CN114989800A (en) * | 2022-06-30 | 2022-09-02 | 常州大学 | Preparation method of surfactant for improving recovery ratio of low-permeability sandstone reservoir |
| CN115058240A (en) * | 2022-06-30 | 2022-09-16 | 常州大学 | Preparation method and application of oil displacement agent for improving recovery ratio of low-permeability sandstone reservoir |
| CN115074101A (en) * | 2022-06-30 | 2022-09-20 | 常州大学 | Preparation method and application of surfactant with reservoir protection effect for oil displacement of low-permeability sandstone reservoir |
| CN114989800B (en) * | 2022-06-30 | 2023-04-21 | 常州大学 | Preparation method of surfactant for improving recovery ratio of hypotonic sandstone oil reservoir |
| CN115058240B (en) * | 2022-06-30 | 2023-08-08 | 常州大学 | Preparation method and application of oil displacement agent for improving recovery ratio of low-permeability sandstone oil reservoir |
| CN115074101B (en) * | 2022-06-30 | 2023-08-08 | 常州大学 | Preparation method and application of surfactant with reservoir protection effect for low-permeability sandstone reservoir oil displacement |
| CN116044391A (en) * | 2023-03-09 | 2023-05-02 | 西南石油大学 | Method for determining dosage of profile control agent of low permeability reservoir horizontal well |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN107338033A (en) | A kind of low-permeability sandstone oil reservoir Complex polymer type profile control agent and its application method | |
| CN107216866B (en) | A kind of method of Carbonate Reservoir seam dictyosome product acidfracturing treatment | |
| CN104514531A (en) | Method for profile control and water shutoff in two-fluid process for three-low sandstone reservoir | |
| CN107254301A (en) | A kind of hypertonic duct type oil reservoir chromium aluminium ion compounding profile control agent 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 | |
| CN107218009A (en) | A kind of low-permeability sandstone oil reservoir chromium aluminium ion compounding 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 | |
| CN107288577A (en) | A kind of double slug type profile control agents of poly- table of low-permeability sandstone oil reservoir 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 | |
| CN107236528A (en) | A kind of hypertonic duct type oil reservoir Complex polymer profile control 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 | |
| CN113136185A (en) | Organic water plugging gel for low-temperature hypersalinity oil reservoir | |
| Fjelde et al. | Improvement of Spontaneous Imbibition in Carbonate Rocks by CO²-saturated Brine | |
| CN107384351A (en) | A kind of double slug compounding profile control agents of hypotonic duct type oil reservoir and its application method | |
| CN107218020A (en) | A kind of double slug type profile control agents of poly- table of hypertonic sandstone oil reservoir and its application method | |
| CN107345132A (en) | A kind of compound rhythm oil reservoir Complex polymer type profile control agent and its application method | |
| CN107384346A (en) | A kind of hypertonic sandstone oil reservoir Complex polymer type profile control agent and its application method | |
| RU2160832C1 (en) | Method of restriction of water influx to well | |
| CN107338029A (en) | A kind of double slug Compositional type profile control agents of Fracture with low permeability oil reservoir and its application method | |
| CN107267128A (en) | A kind of double slug type profile control agents of hypertonic poly- table of duct type oil reservoir 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 | |
| CN107384344A (en) | A kind of double slug Compositional type profile control agents of anti-rhythm oil reservoir and its application method | |
| CN108485634B (en) | Composite organic base reinforced polymer oil displacement composition, preparation method and application | |
| CN107338035A (en) | A kind of compound rhythm oil reservoir chromium aluminium ion Compositional type profile control agent and its application method | |
| CN107365578A (en) | A kind of double slug type profile control agents of poly- table of positive rhythm 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: 20171110 |