CN107218020A - A kind of double slug type profile control agents of poly- table of hypertonic sandstone oil reservoir and its application method - Google Patents
A kind of double slug type profile control agents of poly- table of hypertonic sandstone oil reservoir and its application method Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 19
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 95
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 76
- 229920000642 polymer Polymers 0.000 claims abstract description 28
- 238000004519 manufacturing process Methods 0.000 claims abstract description 12
- 229920002401 polyacrylamide Polymers 0.000 claims abstract description 12
- 239000000654 additive Substances 0.000 claims abstract description 6
- 230000000996 additive effect Effects 0.000 claims abstract description 6
- 238000002347 injection Methods 0.000 claims description 30
- 239000007924 injection Substances 0.000 claims description 30
- 235000013162 Cocos nucifera Nutrition 0.000 claims description 27
- 244000060011 Cocos nucifera Species 0.000 claims description 27
- 235000014113 dietary fatty acids Nutrition 0.000 claims description 26
- 229930195729 fatty acid Natural products 0.000 claims description 26
- 239000000194 fatty acid Substances 0.000 claims description 26
- 150000004665 fatty acids Chemical class 0.000 claims description 26
- 238000002360 preparation method Methods 0.000 claims description 25
- GHMLBKRAJCXXBS-UHFFFAOYSA-N resorcinol Chemical compound OC1=CC=CC(O)=C1 GHMLBKRAJCXXBS-UHFFFAOYSA-N 0.000 claims description 24
- DDXLVDQZPFLQMZ-UHFFFAOYSA-M dodecyl(trimethyl)azanium;chloride Chemical compound [Cl-].CCCCCCCCCCCC[N+](C)(C)C DDXLVDQZPFLQMZ-UHFFFAOYSA-M 0.000 claims description 15
- 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 13
- 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 13
- MRUAUOIMASANKQ-UHFFFAOYSA-N cocamidopropyl betaine Chemical compound CCCCCCCCCCCC(=O)NCCC[N+](C)(C)CC([O-])=O MRUAUOIMASANKQ-UHFFFAOYSA-N 0.000 claims description 11
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims description 10
- 229910052760 oxygen Inorganic materials 0.000 claims description 10
- 239000001301 oxygen Substances 0.000 claims description 10
- 239000003814 drug Substances 0.000 claims description 8
- 239000010865 sewage Substances 0.000 claims description 6
- 238000012545 processing Methods 0.000 claims description 5
- 238000003756 stirring Methods 0.000 claims description 4
- 238000013461 design Methods 0.000 claims description 3
- 238000002156 mixing Methods 0.000 claims description 3
- 229920003023 plastic Polymers 0.000 claims description 3
- 239000004033 plastic Substances 0.000 claims description 3
- 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
- 238000013329 compounding Methods 0.000 claims 1
- 238000011084 recovery Methods 0.000 abstract description 18
- 239000004094 surface-active agent Substances 0.000 abstract description 12
- 150000001875 compounds Chemical class 0.000 abstract description 4
- 230000015572 biosynthetic process Effects 0.000 abstract description 3
- 230000007812 deficiency Effects 0.000 abstract description 3
- 239000000126 substance Substances 0.000 abstract description 3
- 239000003921 oil Substances 0.000 description 89
- 235000019198 oils Nutrition 0.000 description 89
- 239000011435 rock Substances 0.000 description 55
- 238000005086 pumping Methods 0.000 description 21
- 238000002474 experimental method Methods 0.000 description 20
- 230000000694 effects Effects 0.000 description 19
- 238000006073 displacement reaction Methods 0.000 description 12
- 238000007789 sealing Methods 0.000 description 12
- 230000035699 permeability Effects 0.000 description 11
- 239000010779 crude oil Substances 0.000 description 9
- 238000004088 simulation Methods 0.000 description 7
- 238000012360 testing method Methods 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
- 239000002352 surface water Substances 0.000 description 6
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 5
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 4
- 239000004927 clay Substances 0.000 description 4
- 230000009467 reduction Effects 0.000 description 4
- 239000006004 Quartz sand Substances 0.000 description 3
- 150000001408 amides Chemical class 0.000 description 3
- YCIMNLLNPGFGHC-UHFFFAOYSA-N catechol Chemical compound OC1=CC=CC=C1O YCIMNLLNPGFGHC-UHFFFAOYSA-N 0.000 description 3
- 235000019864 coconut oil Nutrition 0.000 description 3
- 239000003240 coconut oil Substances 0.000 description 3
- 238000011161 development Methods 0.000 description 3
- 230000018109 developmental process Effects 0.000 description 3
- 239000012153 distilled water Substances 0.000 description 3
- 239000003822 epoxy resin Substances 0.000 description 3
- -1 oleoyl amine Chemical class 0.000 description 3
- 229920000647 polyepoxide Polymers 0.000 description 3
- 230000008569 process Effects 0.000 description 3
- 241000237858 Gastropoda Species 0.000 description 2
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 2
- QQHSIRTYSFLSRM-UHFFFAOYSA-N alumanylidynechromium Chemical compound [Al].[Cr] QQHSIRTYSFLSRM-UHFFFAOYSA-N 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 230000000903 blocking effect Effects 0.000 description 2
- 230000008859 change Effects 0.000 description 2
- 230000002079 cooperative effect Effects 0.000 description 2
- 235000019197 fats Nutrition 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 230000001965 increasing effect Effects 0.000 description 2
- 230000007246 mechanism Effects 0.000 description 2
- 239000002736 nonionic surfactant Substances 0.000 description 2
- 239000002245 particle Substances 0.000 description 2
- 230000002093 peripheral effect Effects 0.000 description 2
- 239000004576 sand Substances 0.000 description 2
- 239000011780 sodium chloride Substances 0.000 description 2
- 239000000725 suspension Substances 0.000 description 2
- 239000002888 zwitterionic surfactant Substances 0.000 description 2
- 235000016068 Berberis vulgaris Nutrition 0.000 description 1
- 241000335053 Beta vulgaris Species 0.000 description 1
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 1
- 230000003213 activating effect Effects 0.000 description 1
- 239000003513 alkali Substances 0.000 description 1
- 239000002585 base Substances 0.000 description 1
- 229960003237 betaine Drugs 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 229910052791 calcium Inorganic materials 0.000 description 1
- 239000011575 calcium Substances 0.000 description 1
- 239000003093 cationic surfactant Substances 0.000 description 1
- 239000013043 chemical agent Substances 0.000 description 1
- 238000009388 chemical precipitation Methods 0.000 description 1
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 238000004132 cross linking Methods 0.000 description 1
- 239000003431 cross linking reagent Substances 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- KWIUHFFTVRNATP-UHFFFAOYSA-N glycine betaine Chemical compound C[N+](C)(C)CC([O-])=O KWIUHFFTVRNATP-UHFFFAOYSA-N 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- QLNJFJADRCOGBJ-UHFFFAOYSA-N propionamide Chemical compound CCC(N)=O QLNJFJADRCOGBJ-UHFFFAOYSA-N 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 239000003079 shale oil Substances 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 230000008961 swelling Effects 0.000 description 1
- 230000002195 synergetic effect Effects 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
- 230000010148 water-pollination Effects 0.000 description 1
- 238000009736 wetting Methods 0.000 description 1
Classifications
-
- 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
-
- 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
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Organic Chemistry (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Materials Engineering (AREA)
- Geochemistry & Mineralogy (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Curing Cements, Concrete, And Artificial Stone (AREA)
Abstract
A kind of double slug type profile control agents of poly- table of hypertonic sandstone oil reservoir and its application method, are related to field use chemical field.The present invention injects hypertonic sandstone oil reservoir by double slug forms, and preposed attributives mix the partially hydrolyzed polyacrylamide (PHPA) formation Complex polymer of three kinds of different molecular quality, additive formation profile control agent is added in Complex polymer, and the hypertonic region of oil reservoir can be implemented to block；Rearmounted slug be compound surfactant, inject oil reservoir after preposed attributives are effectively blocked, to being oozed in oil reservoir, hypotonic region carry out surfactant flooding, with reduce residual oil content in oil reservoir, increase injectivity index；Improve Reservoir Heterogeneity by way of double slug combinations, increase sequent water flooding sweep efficiency, suppress hypertonic sandstone oil reservoir region of bypassed oil and formed, to improve traditional oil production method to drawbacks such as the hypertonic low, deficiencies in economic performance of sandstone oil reservoir recovery ratio.
Description
Technical field
The present invention relates to a kind of double slug type profile control agents of hypertonic poly- table of sandstone oil reservoir and its application method, the profile control agent can change
Kind reservoir adaptability, and then hypertonic sandrock-type oil reservoir oil increasing effect can be improved, belong to field use chemical agent field.
Background technology
In recent years, polymer displacement of reservoir oil tech has carried out large-scale application in the oil field such as grand celebration, triumph, Xinjiang and Bohai Sea at home
And field test, obvious oil increasing precipitation effect is obtained, techno-economic effect is very notable.But sent out in polymer flooding practice
Existing, for hypertonic sandstone oil reservoir, recovery percent of reserves is relatively low, shows that polymer is applied to hypertonic sandstone oil reservoir less efficient；Hypertonic sand
Shale oil is hidden because oil-layer distribution is complicated, has following drawback during actual development：
1st, permeability is gradually reduced in hypertonic sandstone oil reservoir recovery process, and its main cause is clay particulate in production process
It is stifled that the mobile blocking to reservoir pore, the fouling caused by reservoir pressure, temperature change and calcium, the chemical precipitation of iron are caused
Plug etc., result in hypertonic sandstone oil reservoir water injection pressure greatly, and unplugged duct easily forms channelling, have a strong impact on oil field development effect
Benefit.
2nd, during hypertonic sandstone oil reservoir waterflooding extraction, due to the anisotropism of oil reservoir, injection water is caused along Thief zone
Layer band, is advanced by leaps and bounds at duct channelling, seriously reduces the swept volume of injection water and the development effectiveness in oil field.
3rd, preferable oil displacement efficiency is being generally unattainable with polymer flooding at present, when polymer viscosity is low, often gone out
Existing invalid poly- drive is circulated, when polymer viscosity is high, it may appear that closure excessively tightly causes water injection pressure too high；And traditional poly- drive
Recover the oil in hypertonic sandstone oil reservoir, it is difficult to overcome and shake out and the phenomenon such as clay swelling.
4th, region of bypassed oil branch is more, during conventional water drive, because most of displacing fluid flows through high permeability zone band, result in
Intake profile branch is uneven, and affected area does not gradually form region of bypassed oil to displacing fluid, has a strong impact on hypertonic sandstone oil reservoir exploitation effect
Really.
Recovery efficiency technique demand is improved for hypertonic sandstone oil reservoir, the present invention proposes a kind of double slug type profile control agents of poly- table,
The problem of overcoming above-mentioned hypertonic sandstone oil reservoir.
The content of the invention
It is an object of the invention to provide a kind of double slug type profile control agents of hypertonic poly- table of sandstone oil reservoir and its application method, lead to
Cross double slug forms and inject hypertonic sandstone oil reservoir, preposed attributives mix the partially hydrolyzed polyacrylamide (PHPA) of three kinds of different molecular quality
Complex polymer is formed, additive formation profile control agent is added in Complex polymer, the hypertonic region of oil reservoir can be implemented to block；Afterwards
Slug is put for compound surfactant, oil reservoir is injected after preposed attributives are effectively blocked, to being oozed in oil reservoir, hypotonic region carry out table
Face surfactant flooding, to reduce residual oil content in oil reservoir, increase injectivity index；Improve oil reservoir by way of double slug combinations non-
Homogenieity, increases sequent water flooding sweep efficiency, suppresses hypertonic sandstone oil reservoir region of bypassed oil and is formed, to improve traditional oil production method to height
Ooze the drawbacks such as the low, deficiency in economic performance of sandstone oil reservoir recovery ratio.
To reach above-mentioned purpose, the present invention is adopted the following technical scheme that.
A kind of double slug type profile control agents of poly- table of hypertonic sandstone oil reservoir, its main component is：Partially hydrolyzed polyacrylamide (PHPA) phase
It is respectively 500*10 to molecular mass4、1000*104、2500*104, chromium acetate, aluminium citrate, resorcinol, coconut oil fat
Sour diglycollic amide, DTAC, Cocoamidopropyl betaine；For hypertonic sandstone oil reservoir, design is double
Slug formula profile control agent, is blocked by preposed attributives to hypertonic sandstone oil reservoir, and rearmounted slug carries out surfactant flooding, below with section
Plug A profile control agents represent preposed attributives, and slug B represents rearmounted slug to be described.
Slug A profile control agents include Complex polymer and additive；Wherein, Complex polymer is by three kinds of different molecular quality
Partially hydrolyzed polyacrylamide (PHPA) is constituted, and molecular mass is respectively 500*104、1000*104、2500*104, its mass ratio is 20：
35：45；Additive includes chromium acetate, aluminium citrate, resorcinol, cocoanut fatty acid diethanolamide；Slug A profile control agents
In, Complex polymer mass ratio is 0.2%-0.4%, and chromium acetate mass ratio is 0.1%-0.25%, and aluminium citrate mass ratio is
0.1%-0.25%, resorcinol is 0.04%-0.06%, and cocoanut fatty acid diethanolamide mass ratio is 0.05%-
0.08%, remaining components are preparation water.
Preferably, in slug A profile control agents, Complex polymer, chromium acetate, aluminium citrate, resorcinol, coco-nut oil fatty acid
The mass ratio of diglycollic amide is 0.25%-0.35%：0.15%-0.2%：0.15%-0.2%：0.045%-0.055%：
0.06%-0.07%, remaining components are preparation water.
It is highly preferred that in slug A profile control agents, Complex polymer, chromium acetate, aluminium citrate, resorcinol, coconut oil fat
The mass ratio of sour diglycollic amide is 0.3%：0.18%：0.19%：0.05%：0.065%, remaining components are preparation water.
Slug A profile control agent main function mechanism is, by the partially hydrolyzed polyacrylamide (PHPA)s of three kinds of different molecular quality with
Chromium aluminium ion crosslinking agent is combined, and forms molecular coil structural polymer, with the clay particle in oil reservoir, insoluble after injection oil reservoir
Suspension is combined, and is formed around core formula molecular coil structure, increases its active area in hypertonic sandstone oil reservoir, improves closure effect
Really；Resorcinol and cocoanut fatty acid diethanolamide can increase polyacrylamide molecular coil peripheral groups in slug A
Activity so that slug A is in contact part with sandstone with larger viscosity, is blocked so as to increase slug A to hypertonic sandstone oil reservoir
Intensity；Slug A is mainly used as blocking hypertonic region or macropore in hypertonic sandstone oil reservoir, improves the non-of hypertonic sandstone oil reservoir
Homogenieity so that be subsequently implanted into slug B can enter oozed in oil reservoir, hypotonic region, so as to form double slugs synergies.
Slug B includes cocoanut fatty acid diethanolamide, DTAC, cocamidopropyl propyl amide beet
Alkali；In slug B, cocoanut fatty acid diethanolamide mass ratio is 1%-2%, and DTAC mass ratio is
2%-4%, Cocoamidopropyl betaine mass ratio is 1%-2%, and remaining components are preparation water.
Preferably, in slug B, cocoanut fatty acid diethanolamide, DTAC, coconut oleoyl amine third
Base glycine betaine mass ratio is 1.2%-1.8%：2.5%-3.5%：1.2%-1.8%, remaining components are preparation water.
It is highly preferred that in slug B, cocoanut fatty acid diethanolamide, DTAC, coconut oleoyl amine
CAB mass ratio is 1.5%：3%：1.5%, remaining components are preparation water.
Slug B main function mechanism is, by mixing nonionic surfactant cocoanut fatty acid diethanolamide, sun
Ionic surface active agent DTAC and zwitterionic surfactant Cocoamidopropyl betaine, are played
Surfactant cooperative effect；Compound surfactant solution has relatively low surface and interface tension force, and stronger wetting
Ability, can improve rock hydrophily, and washing oil purpose is reached indirectly, be referred to reducing residual oil content in oil reservoir, increase oil reservoir water suction
Number；Three kinds of surfactant compounds, can increase its saline-alkaline tolerance, can adapt to different types of stratum water；And three kinds of tables
Face activating agent composite usage effect is better than single surfactant；After slug A forms effectively closure, slug B is injected into oil reservoir,
Oozed in can entering, hypotonic region carries out surfactant flooding, to be oozed in reduction, the envelope that hypotonic region residual oil is caused to oil reservoir
It is stifled, strengthen its flow conductivity, so as to realize double slug synergies, improve hypertonic sandstone oil reservoir oil recovery.
A kind of application method of the double slug type profile control agents of poly- table of hypertonic sandstone oil reservoir 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. 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, medicament is added to preparing in water, is at the uniform velocity stirred
4-6 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；
Step 5. slug A profile control agent injection rates reach that static 48-72 hours makes the abundant plastic of profile control agent after preset range；
Step 6. injects driven water-replacing 0.3PV, and injection slug B and the follow-up note of progress adopt operation.
The specific injection rate of profile control agent is：Slug A profile control agent 0.2-0.3PV are injected first into oil reservoir or rock core, 48- is waited
Make within 72 hours the abundant plastic of slug A profile control agents, then to driven water-replacing 0.3PV is injected in oil reservoir or rock core, then to oil reservoir or rock
Slug B0.2-0.3PV is injected in the heart, is then carried out follow-up note and is adopted operation.
The present invention the advantage is that relative to prior art：
1st, recovery efficiency technique demand is improved for hypertonic sandstone oil reservoir, the present invention proposes a kind of double slug type profile controls of poly- table
Agent, it is characterised in that slug A profile control agent molecular coil sizes branch is wider, and can be with clay particle, tiny sand body in oil reservoir
Or insoluble suspension is combined, formed around core formula molecular coil so that slug A is in contact part with sandstone with larger viscosity,
Realize and hypertonic sandstone oil reservoir is blocked.
2nd, Complex polymer combination chromium aluminium ion crosslinking method can strengthen the salinity adaptability of polymeric system, can fit
Answer salinity 500mg/L-35000mg/L preparation water.
3rd, resorcinol and cocoanut fatty acid diethanolamide can increase polyacrylamide molecular coil peripheral groups
Activity so that slug A is in contact part with sandstone with larger viscosity, is blocked so as to increase slug A to hypertonic sandstone oil reservoir
Intensity.
4th, in slug B, nonionic surfactant cocoanut fatty acid diethanolamide, cationic surfactant are passed through
DTAC and zwitterionic surfactant Cocoamidopropyl betaine compound synergic, play surface work
Property agent cooperative effect, its application effect be better than single surfactant.
5th, the present invention injects form by double slugs, and the hypertonic sandstone oil reservoir anisotropism of improvement, recovery percent of reserves are low, water suction refers to
The low problem of number, increases sequent water flooding sweep efficiency, suppresses region of bypassed oil generation, to improve traditional oil production method to hypertonic sandstone oil
Hide the drawbacks such as the low, deficiency in economic performance of recovery ratio.
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、1000*104、2500*104, effective mass fraction is 90%；Chromium acetate is Shandong West Asia chemical industry
Co., Ltd produces, and analyzes pure；Aluminium citrate produces for Jinan Xin Ya Chemical Co., Ltd.s, top pure grade GR；Resorcinol is wide
Dong Wengjiang chemical reagent Co., Ltd produces, and analyzes pure；Cocoanut fatty acid diethanolamide is that the small wild chemical share in Shandong has
Limit company produces, and analyzes pure；DTAC produces for Nanjing chemical reagent limited company, purity
98%；Cocoamidopropyl betaine produces for Guangzhou Ying Hong Chemical Co., Ltd.s, technical grade.
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, medicament is added to preparing in water, at the uniform velocity stirs 4 hours, obtains profile control agent；(3)
Profile control agent is directly injected into rock core after the completion of preparation.
2nd, water is prepared, is 500mg/L by adding NaCl into distilled water and adjusting to salinity, to make in simulated 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、1000*104、2500*104, its mass ratio is 20：35：45；Complex polymer, chromium acetate, aluminium citrate,
Benzenediol, the mass ratio of cocoanut fatty acid diethanolamide are 0.3%：0.18%：0.19%：0.05%：0.065%, it is remaining
The following group is divided into preparation water.
Slug B：Cocoanut fatty acid diethanolamide, DTAC, Cocoamidopropyl betaine
Mass ratio is 1.5%：3%：1.5%, 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 is respectively 500*10-3μm2、1500*10-3μm2、3000*10-3μm2, pass through heterogeneous core
Hypertonic sandstone oil reservoir is simulated.
5th, displacement oil is viscosity 40mPa.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
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 prepared into water is put into core holding unit, plus confined pressure 4MPa, then with 0.4mL/min speed
Spend the injection into rock core and prepare water, the pressure and flow are recorded when pressure stability；
(4) positive injection slug A profile control agent 0.2PV, pressure during record injection profile agent into rock core, stand 60 hours
It is stand-by；
(5) water drive is carried out with 2mL/min speed, record outlet brings out the first breakthrough pressure when dripping, and treats that pressure is steady
The time recording pressure and flow；
(6) whole experiment is carried out in the case of 50 DEG C of constant temperature, is permeated after calculating original permeability according to record result, block up
Rate, sealing ratiod, breakthrough pressure gradient, resistance coefficient.
7th, sealing characteristics evaluates 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 profile control effect are obvious, and sealing ratiod has reached more than 90%, illustrate to do preparation water to profile control using source water
Agent is 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 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 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 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 0.25PV, placed 72 hours after having noted, then note
Enter to prepare water 0.3PV, be subsequently injected into slug B0.2PV, termination of pumping；
(6) positive water drive experiment is carried out, stops experiment when being driven to aqueous 98%, records oil pump capacity, and it is final to calculate rock core
Recovery ratio value.
9th, oil-displacement capacity 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 50 DEG C of oil reservoir of simulation
Three layers of heterogeneous core are implemented after profile control by experiment, have improved simulation core anisotropism, improve recovery ratio 25.24%, 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, content of oxygen dissolved in water reduction will be prepared
To below 3mg/L；(2) under the conditions of 35 DEG C of temperature, medicament is added to preparing in water, at the uniform velocity stirs 5 hours, obtains profile control agent；(3)
Profile control agent is directly injected into rock core after the completion of preparation.
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 500*104、1000*104、2500*104, its mass ratio is 20：35：45；Complex polymer, chromium acetate, aluminium citrate,
Benzenediol, the mass ratio of cocoanut fatty acid diethanolamide are 0.2%：0.1%：0.1%：0.04%：0.05%, remaining group
It is divided into preparation water.
Slug B：Cocoanut fatty acid diethanolamide, DTAC, Cocoamidopropyl betaine
Mass ratio is 1%：2%：1%, remaining components are preparation water.
4th, specific rock core manufacture scale is as follows：
Experiment rock core is quartz sand epoxy resin cementitious three layers of heterogeneous artificial cores, and specific size is 4.5cm*
4.5cm*30cm, perm-plug method is respectively 500*10-3μm2、1500*10-3μm2、3000*10-3μm2, pass through heterogeneous core
Hypertonic sandstone oil reservoir is simulated.
5th, displacement oil is crude oil, and viscosity is 30mPa.s during temperature 70 C.
6th, sealing characteristics test operating procedure is as follows：
(1) rock core to be used is put into 70 DEG C of insulating boxs and 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 prepared into water is put into core holding unit, plus confined pressure 4MPa, then with 0.4mL/min speed
Spend the injection into rock core and prepare water, the pressure and flow are recorded when pressure stability；
(4) positive injection slug A profile control agent 0.3PV, pressure during record injection profile agent into rock core, stand 72 hours
It is stand-by；
(5) water drive is carried out with 2mL/min speed, record outlet brings out the first breakthrough pressure when dripping, and treats that pressure is steady
The time recording pressure and flow；
(6) whole experiment is carried out in the case of 70 DEG C of constant temperature, is permeated after calculating original permeability according to record result, block up
Rate, sealing ratiod, breakthrough pressure gradient, resistance coefficient.
7th, sealing characteristics evaluates 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
Substantially, sealing ratiod has reached more than 90% to three layers of non-average rock core profile control effect, illustrates that doing preparation water using oilfield sewage exchanges
Agent is cutd open 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 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 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 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 0.2PV, placed 48 hours after having noted, then note
Enter to prepare water 0.3PV, be subsequently injected into slug B0.3PV, termination of pumping；
(6) positive water drive experiment is carried out, stops experiment when being driven to aqueous 98%, records oil pump capacity, and it is final to calculate rock core
Recovery ratio value.
9th, oil-displacement capacity 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, three layers of heterogeneous core are implemented after profile control, have improved simulation core anisotropism, improves recovery ratio 27.13%, says
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, content of oxygen dissolved in water reduction will be prepared
To below 3mg/L；(2) under the conditions of 55 DEG C of temperature, medicament is added to preparing in water, at the uniform velocity stirs 6 hours, obtains profile control agent；(3)
Profile control agent is directly injected into rock core after the completion of preparation.
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 500*104、1000*104、2500*104, its mass ratio is 20：35：45；Complex polymer, chromium acetate, aluminium citrate,
Benzenediol, the mass ratio of cocoanut fatty acid diethanolamide are 0.4%：0.25%：0.25%：0.06%：0.08%, it is remaining
Component is preparation water.
Slug B：Cocoanut fatty acid diethanolamide, DTAC, Cocoamidopropyl betaine
Mass ratio is 2%：4%：2%, remaining components are preparation water.
4th, specific rock core manufacture scale is as follows：
Experiment rock core is quartz sand epoxy resin cementitious three layers of heterogeneous artificial cores, and specific size is 4.5cm*
4.5cm*30cm, perm-plug method is respectively 500*10-3μm2、1500*10-3μm2、3000*10-3μm2, pass through heterogeneous core
Hypertonic sandstone oil reservoir is simulated.
5th, viscosity is 46mPa.s when displacement oil is crude oil, 30 DEG C of temperature.
6th, sealing characteristics test operating procedure is as follows：
(1) rock core to be used is put into 70 DEG C of insulating boxs and 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 prepared into water is put into core holding unit, plus confined pressure 4MPa, then with 0.4mL/min speed
Spend the injection into rock core and prepare water, the pressure and flow are recorded when pressure stability；
(4) positive injection slug A profile control agent 0.25PV, pressure during record injection profile agent into rock core, stand 48 small
When it is stand-by；
(5) water drive is carried out with 2mL/min speed, record outlet brings out the first breakthrough pressure when dripping, and treats that pressure is steady
The time recording pressure and flow；
(6) whole experiment is carried out in the case of 30 DEG C of constant temperature, is permeated after calculating original permeability according to record result, block up
Rate, sealing ratiod, breakthrough pressure gradient, resistance coefficient.
7th, sealing characteristics evaluates 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
Substantially, sealing ratiod has reached more than 90% to three layers of non-average rock core profile control effect, illustrates that doing preparation water using oilfield sewage exchanges
Agent is cutd open 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 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 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 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 0.25PV, placed 60 hours after having noted, then note
Enter to prepare water 0.3PV, be subsequently injected into slug B0.25PV, termination of pumping；
(6) positive water drive experiment is carried out, stops experiment when being driven to aqueous 98%, records oil pump capacity, and it is final to calculate rock core
Recovery ratio value.
9th, oil-displacement capacity 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 30 DEG C of oil reservoir of simulation
For experiment, three layers of heterogeneous core are implemented after profile control, have improved simulation core anisotropism, improves recovery ratio 26.89%, says
Bright profile control agent of the present invention can improve Reservoir Heterogeneity, and profile control effect is obvious.
Claims (6)
1. the double slug type profile control agents of a kind of poly- table of hypertonic sandstone oil reservoir, it is characterised in that including slug A profile control agents and slug B；
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 500*104、1000*104、2500*104, its mass ratio is 20：35：45；
Additive includes chromium acetate, aluminium citrate, resorcinol, cocoanut fatty acid diethanolamide；In slug A profile control agents, compounding
Polymer quality ratio is 0.2%-0.4%, and chromium acetate mass ratio is 0.1%-0.25%, and aluminium citrate mass ratio is 0.1%-
0.25%, resorcinol is 0.04%-0.06%, and cocoanut fatty acid diethanolamide mass ratio is 0.05%-0.08%, remaining
The following group is divided into preparation water；And
Slug B includes cocoanut fatty acid diethanolamide, DTAC, Cocoamidopropyl betaine；
In slug B, cocoanut fatty acid diethanolamide mass ratio is 1%-2%, and DTAC mass ratio is
2%-4%, Cocoamidopropyl betaine mass ratio is 1%-2%, and remaining components are preparation water.
2. a kind of double slug type profile control agents of hypertonic poly- table of sandstone oil reservoir as claimed in claim 1, it is characterised in that the slug
Complex polymer, chromium acetate, aluminium citrate, resorcinol, the mass ratio of cocoanut fatty acid diethanolamide are in A profile control agents
0.25%-0.35%：0.15%-0.2%：0.15%-0.2%：0.045%-0.055%：0.06%-0.07%, remaining group
It is divided into preparation water.
3. a kind of double slug type profile control agents of hypertonic poly- table of sandstone oil reservoir as claimed in claim 1, it is characterised in that the slug
Complex polymer, chromium acetate, aluminium citrate, resorcinol, the mass ratio of cocoanut fatty acid diethanolamide are in A profile control agents
0.3%：0.18%：0.19%：0.05%：0.065%, remaining components are preparation water.
4. a kind of double slug type profile control agents of hypertonic poly- table of sandstone oil reservoir as claimed in claim 1, it is characterised in that the slug
Cocoanut fatty acid diethanolamide, DTAC, Cocoamidopropyl betaine mass ratio are in B
1.2%-1.8%：2.5%-3.5%：1.2%-1.8%, remaining components are preparation water.
5. a kind of double slug type profile control agents of hypertonic poly- table of sandstone oil reservoir as claimed in claim 1, it is characterised in that the slug
Cocoanut fatty acid diethanolamide, DTAC, Cocoamidopropyl betaine mass ratio are in B
1.5%：3%：1.5%, remaining components are preparation water.
6. the application method of the double slug type profile control agents of a kind of poly- table of hypertonic sandstone oil reservoir, 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, medicament is added to preparing in water, at the uniform velocity stir 4-6 small
When, 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；
Step 5. slug A profile control agent injection rates reach that static 48-72 hours makes the abundant plastic of profile control agent after preset range；
Step 6. injects driven water-replacing 0.3PV, and injection slug B and the follow-up note of progress adopt operation.
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