CN109385257A - A kind of double slug Compositional type profile control agents of low-permeability sandstone oil reservoir and its application method - Google Patents
A kind of double slug Compositional type profile control agents of low-permeability sandstone oil reservoir and its application method Download PDFInfo
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- CN109385257A CN109385257A CN201710663708.9A CN201710663708A CN109385257A CN 109385257 A CN109385257 A CN 109385257A CN 201710663708 A CN201710663708 A CN 201710663708A CN 109385257 A CN109385257 A CN 109385257A
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- 238000000034 method Methods 0.000 title claims abstract description 18
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 73
- 238000004519 manufacturing process Methods 0.000 claims abstract description 23
- 229920000642 polymer Polymers 0.000 claims abstract description 19
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 119
- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid Chemical compound OC(=O)CC(O)(C(O)=O)CC(O)=O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 claims description 42
- 238000002347 injection Methods 0.000 claims description 34
- 239000007924 injection Substances 0.000 claims description 34
- GHMLBKRAJCXXBS-UHFFFAOYSA-N resorcinol Chemical compound OC1=CC=CC(O)=C1 GHMLBKRAJCXXBS-UHFFFAOYSA-N 0.000 claims description 28
- LZZYPRNAOMGNLH-UHFFFAOYSA-M Cetrimonium bromide Chemical compound [Br-].CCCCCCCCCCCCCCCC[N+](C)(C)C LZZYPRNAOMGNLH-UHFFFAOYSA-M 0.000 claims description 13
- DBMJMQXJHONAFJ-UHFFFAOYSA-M Sodium laurylsulphate Chemical compound [Na+].CCCCCCCCCCCCOS([O-])(=O)=O DBMJMQXJHONAFJ-UHFFFAOYSA-M 0.000 claims description 13
- 238000002156 mixing Methods 0.000 claims description 11
- 229920002401 polyacrylamide Polymers 0.000 claims description 11
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims description 10
- 235000010299 hexamethylene tetramine Nutrition 0.000 claims description 10
- VKYKSIONXSXAKP-UHFFFAOYSA-N hexamethylenetetramine Chemical compound C1N(C2)CN3CN1CN2C3 VKYKSIONXSXAKP-UHFFFAOYSA-N 0.000 claims description 10
- 229960004011 methenamine Drugs 0.000 claims description 10
- 239000001301 oxygen Substances 0.000 claims description 10
- 229910052760 oxygen Inorganic materials 0.000 claims description 10
- 239000003814 drug Substances 0.000 claims description 8
- 238000012545 processing Methods 0.000 claims description 5
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- 238000002360 preparation method Methods 0.000 claims description 4
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- 238000013461 design Methods 0.000 claims description 2
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- 230000003068 static effect Effects 0.000 claims description 2
- QGZKDVFQNNGYKY-UHFFFAOYSA-O Ammonium Chemical compound [NH4+] QGZKDVFQNNGYKY-UHFFFAOYSA-O 0.000 claims 1
- 230000031709 bromination Effects 0.000 claims 1
- 238000005893 bromination reaction Methods 0.000 claims 1
- 238000011084 recovery Methods 0.000 abstract description 15
- 239000004094 surface-active agent Substances 0.000 abstract description 11
- 150000001875 compounds Chemical class 0.000 abstract description 5
- 239000000084 colloidal system Substances 0.000 abstract description 4
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- 208000013201 Stress fracture Diseases 0.000 abstract description 3
- 230000007812 deficiency Effects 0.000 abstract description 3
- 239000000126 substance Substances 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 92
- 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 18
- 230000000694 effects Effects 0.000 description 16
- 238000006073 displacement reaction Methods 0.000 description 15
- 238000001035 drying Methods 0.000 description 12
- 239000011780 sodium chloride Substances 0.000 description 11
- 239000010779 crude oil Substances 0.000 description 9
- 239000012153 distilled water Substances 0.000 description 9
- 238000007789 sealing Methods 0.000 description 9
- 239000005995 Aluminium silicate Substances 0.000 description 6
- 235000012211 aluminium silicate Nutrition 0.000 description 6
- 238000001816 cooling Methods 0.000 description 6
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- 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
- 229920006395 saturated elastomer Polymers 0.000 description 6
- 238000004088 simulation Methods 0.000 description 6
- 239000002352 surface water Substances 0.000 description 6
- 238000012360 testing method Methods 0.000 description 6
- 230000008569 process Effects 0.000 description 5
- 239000007789 gas 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
- 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
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical group O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 3
- 230000008859 change Effects 0.000 description 3
- 239000003153 chemical reaction reagent Substances 0.000 description 3
- 238000013329 compounding Methods 0.000 description 3
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- 230000018109 developmental process Effects 0.000 description 3
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- 230000002195 synergetic effect Effects 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
- 239000003945 anionic surfactant Substances 0.000 description 2
- 239000003093 cationic surfactant Substances 0.000 description 2
- 239000004927 clay Substances 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 230000002708 enhancing effect Effects 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 230000007246 mechanism Effects 0.000 description 2
- 239000003208 petroleum 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
- -1 sodium sulfonate compound Chemical class 0.000 description 2
- 238000001179 sorption measurement Methods 0.000 description 2
- SNRUBQQJIBEYMU-UHFFFAOYSA-N Dodecane Natural products CCCCCCCCCCCC SNRUBQQJIBEYMU-UHFFFAOYSA-N 0.000 description 1
- 241000237858 Gastropoda Species 0.000 description 1
- 201000001970 Laryngostenosis Diseases 0.000 description 1
- 208000027418 Wounds and injury Diseases 0.000 description 1
- 230000003213 activating effect Effects 0.000 description 1
- 150000001412 amines Chemical class 0.000 description 1
- SWLVFNYSXGMGBS-UHFFFAOYSA-N ammonium bromide Chemical compound [NH4+].[Br-] SWLVFNYSXGMGBS-UHFFFAOYSA-N 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
- 239000013043 chemical agent Substances 0.000 description 1
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- 238000004132 cross linking Methods 0.000 description 1
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- 208000014674 injury Diseases 0.000 description 1
- 239000003446 ligand Substances 0.000 description 1
- 229910021645 metal ion Inorganic materials 0.000 description 1
- 239000000693 micelle Substances 0.000 description 1
- 230000020477 pH reduction Effects 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 230000002093 peripheral effect Effects 0.000 description 1
- 230000001376 precipitating effect Effects 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 238000009738 saturating Methods 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 230000008961 swelling 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
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- C—CHEMISTRY; METALLURGY
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- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5083—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
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- 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
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
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- 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
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- 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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- 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
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Abstract
A kind of double slug Compositional type profile control agents of low-permeability sandstone oil reservoir and its application method, are related to field use chemical field.The present invention passes through double slug forms and injects in low-permeability sandstone oil reservoir, and preposed attributives are polymolecular Compositional type polymer, can be combined with suspended particle insoluble in oil reservoir, is formed around core formula molecular coil, carries out selective shut-off to reservoir micro-fractures；Postposition slug is compound surfactant, oil reservoir is injected after preposed attributives effectively block, surfactant flooding is implemented to bypassed area domain in oil reservoir, to reduce residual oil content in oil reservoir, increase oil reservoir injectivity index, improves wax, colloid, asphalitine the phenomenon that near wellbore zone deposits；The present invention improves Reservoir Heterogeneity by way of double slug combinations, increases subsequent waterflooding sweep efficiency, and low-permeability sandstone oil reservoir region of bypassed oil is inhibited to be 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 double slug Compositional type profile control agents of low-permeability sandstone oil reservoir 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 technique
About the definition of low-permeability sandstone oil reservoir, there are many 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 according to oil reservoir mean permeability by Chinese scholar: 1. general low permeability oil field-oil reservoir averagely seeps
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。
With deepening continuously for oil-gas exploration work, the raising year by year of degree of prospecting, oil-gas exploration difficulty is also more and more big,
Unconventional petroleum resources have become the hot spot of exploration and development.Low-permeability sandstone oil reservoir is due to oil-layer distribution complexity, in actual development mistake
It is had the following drawbacks in journey:
1, low-permeability sandstone oil reservoir has the feature of low permeability, hole laryngostenosis and microcrack development, and has centainly non-
Homogenieity.
2, due to the influence of the factors such as temperature, pressure, be easy to cause during water drive water breakthrough occurs, fingering, non-available water follow
Phenomena such as ring and clay swelling.
3, in operation process, reservoir is highly prone to the injury of the external fluid that is incompatible, simultaneously because the factors such as temperature, pressure
Influence, be easy to cause wax, colloid, asphalitine near wellbore zone deposit, formed organic plugging.
4 however tradition the techniques such as acidification, pressure break are concentrated mainly on to the research of low-permeability sandstone oil reservoir, to low-permeability sandstone oil
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
Double slug Compositional type profile control agents, it is set forth above for solving the problems, such as.
Summary of the invention
The purpose of the present invention is to provide a kind of double slug Compositional type profile control agents of low-permeability sandstone oil reservoir and its application methods, lead to
It crosses in double slug form injection low-permeability sandstone oil reservoirs, preposed attributives are polymolecular Compositional type polymer, can be insoluble outstanding with oil reservoir
Floating object particle combines, and is formed around core formula molecular coil, carries out selective shut-off to reservoir micro-fractures；Postposition slug is compounding table
Face activating agent injects oil reservoir after preposed attributives effectively block, and implements surfactant flooding to bypassed area domain in oil reservoir, to subtract
Residual oil content, increase oil reservoir injectivity index in few oil reservoir improve wax, colloid, asphalitine the phenomenon that near wellbore zone deposits；
The present invention improves Reservoir Heterogeneity by way of double slug combinations, increases subsequent waterflooding sweep efficiency, inhibits low-permeability sandstone
Oil reservoir region of bypassed oil is formed, to improve the drawbacks such as traditional oil production method, deficiency in economic performance low to low-permeability sandstone oil recovery.
In order to achieve the above objectives, the present invention adopts the following technical scheme that.
A kind of double slug Compositional type profile control agents of low-permeability sandstone oil reservoir, main component are as follows: partially hydrolyzed polyacrylamide (PHPA) phase
It is respectively 500*10 to molecular mass4、800*104、1000*104, citric acid, resorcinol, methenamine, cetyl front three
Base ammonium bromide, dodecyl sodium sulfate；For low-permeability sandstone oil reservoir, double slug formula profile control agents are designed, use slug A profile control agent below
It is described with slug B.
Slug A profile control agent includes Complex polymer and additive；Wherein, Complex polymer is by three kinds of different molecular quality
Partially hydrolyzed polyacrylamide (PHPA) composition, molecular mass is respectively 500*104、800*104、1000*104, mass ratio 50:35:
15；Additive includes citric acid, resorcinol, methenamine；In slug A profile control agent, 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 to prepare water.
Preferably, in slug A profile control agent, Complex polymer, citric acid, resorcinol, methenamine mass ratio are
0.11%-0.14%:0.12%-0.18%:0.02%-0.03%:0.04%-0.05%, remaining components are to prepare water.
It is highly preferred that in slug A profile control agent, Complex polymer, citric acid, resorcinol, methenamine mass ratio are
0.125%:0.15%:0.025%:0.045%, remaining components are to prepare water.
Slug A profile control agent main function mechanism is, by mixing the partially hydrolyzed polyacrylamide (PHPA) of different molecular quality, with
Formed molecular coil structural polymer, after injecting oil reservoir, in oil reservoir clay particle or other insoluble suspended matters be in contact,
And combine, forming resorcinol and methenamine in core formula molecular coil structure, slug A will increase polyacrylamide amine molecule
The activity of ball of string peripheral groups, so that slug A is in contact with sandstone, part has biggish viscosity, thus to low-permeability sandstone oil reservoir
Microcrack is implemented to block；Citric acid plays the role of adjusting base fluid acidity, is firstly added in configuration process, makes it and prepares in water
Metal ion combines, and reduces due to preparing precipitating, flocculation caused by salinity height in water, equally has certain crosslinking
Effect；Slug A is mainly used as blocking the microcrack or macropore in low-permeability sandstone oil reservoir, improves the heterogeneous of low-permeability sandstone oil reservoir
Property, to improve the oil displacement efficiency for being subsequently implanted into slug B.
Slug B includes cetyl trimethylammonium bromide and dodecyl sodium sulfate；In slug B, cetyl trimethyl
Ammonium bromide mass ratio is 1%-2%, and dodecyl sodium sulfate mass ratio is 3%-4%, and remaining components are to prepare water.
Preferably, in slug B, cetyl trimethylammonium bromide, dodecyl sodium sulfate mass ratio are 1.2%-
1.8%:3.2%-3.8%, remaining components are to prepare water.
It is highly preferred that cetyl trimethylammonium bromide, dodecyl sodium sulfate mass ratio are 1.5% in slug B:
3.5%, remaining components are to prepare water.
Slug B main function mechanism is to pass through cationic surfactant cetyl trimethylammonium bromide and anion
Surfactant sodium dodecyl base sodium sulfonate compound synergic, male-female ionic surface active agent generate strong electrical function when compounding,
Thus greatly improve surface-active, playing reduces the efficiency of surface tension, the efficiency for reducing surface tension, reduces critical micell
The effects of concentration, enhancing adsorption；Compound surfactant solution has lower surface and interface tension, therefore compound ligand
System will have stronger wetting ability, can improve rock hydrophily, reach washing oil purpose indirectly, be contained with reducing remaining oil in oil reservoir
Amount increases oil reservoir injectivity index；Two kinds of surfactant compounds, can increase its saline-alkaline tolerance, can adapt to different type
Water flooding；And two kinds of surfactant compound application effects are better than single surfactant；In slug A to low-permeability sandstone oil reservoir
After closure, slug B implements surfactant flooding to reservoir water drive bypassed area domain, to reduce residual oil content in oil reservoir, increase
Oil reservoir injectivity index improves wax, colloid, asphalitine the phenomenon that near wellbore zone deposits, realizes double slug synergistic effects, thus
Improve low-permeability sandstone oil reservoir oil recovery.
A kind of application methods of the double slug Compositional type profile control agents of low-permeability sandstone oil reservoir the following steps are included:
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, dissolves preparing in water
Oxygen content is reduced to 3mg/L or less；
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 stirs
4-6 hours, obtain profile control agent；
Water injection well is connect by step 4. with mixing vessel and supercharging device, starts supercharging device, profile control agent is injected oil reservoir；
Step 5. slug A profile control agent injection rate, which reaches, makes the abundant plastic of profile control agent for static 24-48 hours after preset range；
Step 6. injects driven water-replacing 0.4PV, injects slug B, then carries out subsequent note and adopts operation.
The specific injection rate of profile control agent are as follows: inject slug A profile control agent 0.2PV first into oil reservoir or rock core, wait 24-48 small
When make the abundant plastic of slug A profile control agent, then in oil reservoir or rock core inject driven water-replacing 0.4PV, then in oil reservoir or rock core
Slug B0.2-0.3PV is injected, subsequent note is then carried out and adopts operation.
The present invention compared with the existing technology the advantage is that:
1, the heterogeneity for low-permeability sandstone oil reservoir and microcrack that may be present, slug A profile control agent can in oil reservoir
Insoluble suspended particle combines, and forms the molecular coil structure around core formula, can carry out selective shut-off to reservoir micro-fractures, change
The heterogeneity of kind low-permeability sandstone oil reservoir.
2, it is configured to profile control agent using low molecule mass fraction hydrolyzed polyacrylamide, possessed compared with low-viscosity, injection
After oil reservoir, profile control effect can have not only been played, but also displacement of reservoir oil effect can be played, and can inhibit hair during low-permeability sandstone reservoir water drive
Phenomena such as unboiled water alters, fingering, non-available water circulation.
3, slug A is compounded using different molecular quality polyacrylamide, and plastic stability is high, and prepares water salinity to poly-
The influence of adduct molecule coil dimension is smaller, and shear resistant is good, is suitable for 500mg/L-35000mg/L salinity and prepares water.
4, in slug B, pass through cationic surfactant cetyl trimethylammonium bromide and anionic surfactant
Dodecyl sodium sulfate compound synergic, male-female ionic surface active agent generates strong electrical function when compounding, thus makes surface
Activity greatly improves, and plays the efficiency for reducing surface tension, the efficiency for reducing surface tension, reduces critical micelle concentration, enhancing
The effects of adsorption, application effect are better than single surfactant.
5, the present invention injects form by double slugs, and improvement low-permeability sandstone Reservoir Heterogeneity, recovery percent of reserves are low, water suction refers to
The problems such as number is low increases subsequent waterflooding sweep efficiency, and region of bypassed oil is inhibited to generate, to improve traditional oil production method to low-permeability sandstone oil
Hide the drawbacks such as the low, deficiency in economic performance of recovery ratio.
Specific embodiment
Experimental method used in following embodiments is conventional method unless otherwise specified.
Partially hydrolyzed polyacrylamide (PHPA) used in following embodiments is the production of China Petroleum Daqing Refinery company, opposite to divide
Protonatomic mass is 500*104、800*104、1000*104, effective mass score is 90%；Citric acid is that chemical reagent share in Nanjing has
The production of limit company, specification: AR, 99.5%；Resorcinol is the production of Guangdong Weng Jiang chemical reagent Co., Ltd, is analyzed pure；Wu Luo
Tropine is the production of Beijing Peng Cai chemical reagent Co., Ltd, is analyzed pure；Cetyl trimethylammonium bromide is Nanjing chemical reagent
Limited liability company's production, analyzes pure AR；Dodecyl sodium sulfate is the production of Nanjing chemical reagent limited liability company, is analyzed pure
AR。
Profile control agent plugging effect is evaluated by laboratory core experimental method, specific as follows:
Embodiment one:
1, profile control agent application method: (1) first to the sudden and violent oxygen processing of water progress is prepared, will prepare content of oxygen dissolved in water is reduced
To 3mg/L or less；(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.
2, water is prepared, is 500mg/L by the way that NaCl is added into distilled water to be adjusted to salinity, to make in simulated production
Source water.
3, concrete medicament application amount are as follows:
Slug A: Complex polymer is made of the partially hydrolyzed polyacrylamide (PHPA) of three kinds of different molecular quality, molecular mass point
It Wei not 500*104、800*104、1000*104, mass ratio 50:35:15；Complex polymer, citric acid, resorcinol, crow
Lip river tropine mass ratio is 0.125%:0.15%:0.025%:0.045%, and remaining components are to prepare water.
Slug B: cetyl trimethylammonium bromide, dodecyl sodium sulfate mass ratio are 1.5%:3.5%, remaining components
To prepare water.
4, specific rock core manufacture scale is as follows:
Experiment rock core is quartz sand epoxy resin cementitious three layers of heterogeneous artificial cores, specific size 4.5cm*
4.5cm*30cm, gas permeability are respectively 10*10-3μm2、30*10-3μm2、50*10-3μm2, and add in rock core manufacturing process
The NaCl for entering 5% volume fraction, to simulate oil reservoir microcrack；By manually manufacture heterogeneous core to low-permeability sandstone oil reservoir into
Row simulation.
5, displacement oil is crude oil, viscosity 35mPa.s in the case of 40 DEG C.
6, 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
All dissolution is discharged NaCl with driven water-replacing, with injection 10mg/L kaolin (0.5 μm -2 μm of partial size) mixing water in after image rock core
0.2PV takes out rock core after injection to simulate insoluble suspended matter in oil reservoir；
(2) rock core ready for use is put into 70 DEG C of insulating boxs to drying to constant weight, take out it is cooling after weigh its quality, be denoted 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, rock core is taken out into wiping and removes surface water, is weighed, quality is denoted as m2；
(4) rock core of saturation configuration water is put into core holding unit, adds confining pressure 4MPa, then with the speed of 0.4mL/min
The injection configuration water into rock core is spent, to the pressure steady time recording pressure and flow；
(5) the positive injection slug A profile control agent 0.2PV into rock core, records pressure when injection profile agent, stands 24 hours
For use；
(6) water drive is carried out with the speed of 2mL/min, record outlet brings out the first breakthrough pressure when dripping, steady to pressure
The time recording pressure and flow；
(7) whole experiment is carried out in 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.
7, sealing characteristics evaluation such as following table
Permeability is three layers of non-mean value rock core overall permeability before stifled, from the above in can obtain, slug A profile control agent pair
Three layers of non-mean value rock core have weak seal-off effect, and profile control agent is that movably, to be subsequently implanted into slug B, there are displacements to lead in rock core
Road.
8, 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
All dissolution is discharged NaCl with driven water-replacing, with injection 10mg/L kaolin (0.5 μm -2 μm of partial size) mixing water in after image rock core
0.2PV takes out rock core after injection to simulate insoluble suspended matter in oil reservoir；
(2) rock core ready for use is put into 70 DEG C of insulating boxs to drying to constant weight, take out it is cooling after weigh its quality, be denoted 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, rock core is taken out into wiping and removes surface water, is weighed, quality is denoted as m4；
(4) crude oil is saturated into rock core with the speed of 1.5mL/min, is driven to termination of pumping when outlet end is no longer discharged, record is tired
Water yield is counted, stands 4 hours for use；
(5) rock core for being saturated crude oil being put into core holding unit, whole process experiment is carried out in 40 DEG C of constant temperature, with
The speed of 2mL/min carries out water drive oil, be driven to outlet end it is no longer fuel-displaced when termination of pumping, record oil pump capacity and recovery ratio；
(6) slug A profile control agent 0.2PV is injected with the speed forward direction of 0.9mL/min, places 48 hours after having infused, then infuses
Enter to prepare water 0.4PV, be subsequently injected into slug B0.2PV, termination of pumping stands 48 hours for use；
(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.
9, oil-displacement capacity evaluation is as follows:
It is learnt from above-mentioned data, prepares profile control agent using simulation source water, carry out displacement when simulating 40 DEG C of oil reservoir
Experiment after implementing profile control to three layers of heterogeneous core, has improved simulation core heterogeneity, has improved recovery ratio 28.35%, explanation
Profile control agent of the present invention can improve Reservoir Heterogeneity, and profile control effect is obvious.
Embodiment two:
1, profile control agent application method: (1) first to the sudden and violent oxygen processing of water progress is prepared, will prepare content of oxygen dissolved in water is reduced
To 3mg/L or less；(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.
2, water is prepared, is 8000mg/L by the way that NaCl is added into distilled water to be adjusted to salinity, to simulate practical life
Oilfield sewage used in production.
3, concrete medicament application amount are as follows:
Slug A: Complex polymer is made of the partially hydrolyzed polyacrylamide (PHPA) of three kinds of different molecular quality, molecular mass point
It Wei not 500*104、800*104、1000*104, mass ratio 50:35:15；Complex polymer, citric acid, resorcinol, crow
Lip river tropine mass ratio is 0.1%:0.1%:0.02%:0.03%, and remaining components are to prepare water.
Slug B: cetyl trimethylammonium bromide, dodecyl sodium sulfate mass ratio be 1%:3%, remaining components be with
Water processed.
4, specific rock core manufacture scale is as follows:
Experiment rock core is quartz sand epoxy resin cementitious three layers of heterogeneous artificial cores, specific size 4.5cm*
4.5cm*30cm, 20*10-3μm2、30*10-3μm2, and the NaCl of 5% volume fraction is added in rock core manufacturing process, to mould
Quasi- oil reservoir microcrack；Low-permeability sandstone oil reservoir is simulated by manually manufacturing heterogeneous core.
5, displacement oil is crude oil, and viscosity is 55mPa.s when temperature 50 C.
6, 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
All dissolution is discharged NaCl with driven water-replacing, with injection 10mg/L kaolin (0.5 μm -2 μm of partial size) mixing water in after image rock core
0.2PV takes out rock core after injection to simulate insoluble suspended matter in oil reservoir；
(2) rock core ready for use is put into 70 DEG C of insulating boxs to drying to constant weight, take out it is cooling after weigh its quality, be denoted 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, rock core is taken out into wiping and removes surface water, is weighed, quality is denoted as m6；
(4) rock core of saturation configuration water is put into core holding unit, adds confining pressure 4MPa, then with the speed of 0.4mL/min
The injection configuration water into rock core is spent, to the pressure steady time recording pressure and flow；
(5) the positive injection slug A profile control agent 0.2PV into rock core, records pressure when injection profile agent, stands 24 hours
For use；
(6) water drive is carried out with the speed of 2mL/min, record outlet brings out the first breakthrough pressure when dripping, steady to pressure
The time recording pressure and flow；
(7) whole experiment is carried out in 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.
7, sealing characteristics evaluation such as following table
Permeability is three layers of non-mean value rock core overall permeability before stifled, from the above in can obtain, slug A profile control agent pair
Three layers of non-mean value rock core have weak seal-off effect, and profile control agent is that movably, to be subsequently implanted into slug B, there are displacements to lead in rock core
Road.
8, 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
All dissolution is discharged NaCl with driven water-replacing, with injection 10mg/L kaolin (0.5 μm -2 μm of partial size) mixing water in after image rock core
0.2PV takes out rock core after injection to simulate insoluble suspended matter in oil reservoir；
(2) rock core ready for use is put into 70 DEG C of insulating boxs to drying to constant weight, take out it is cooling after weigh its quality, be denoted 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, rock core is taken out into wiping and removes surface water, is weighed, quality is denoted as m8；
(3) crude oil is saturated into rock core with the speed of 1.5mL/min, is driven to termination of pumping when outlet end is no longer discharged, record is tired
Water yield is counted, stands 4 hours for use；
(4) rock core for being saturated crude oil being put into core holding unit, whole process experiment is carried out in 50 DEG C of constant temperature, with
The speed of 2mL/min carries out water drive oil, be driven to outlet end it is no longer fuel-displaced when termination of pumping, record oil pump capacity and recovery ratio；
(5) slug A profile control agent 0.2PV is injected with the speed forward direction of 0.9mL/min, places 36 hours after having infused, then infuses
Enter to prepare water 0.4PV, 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.
9, oil-displacement capacity evaluation is as follows:
It is learnt from above-mentioned data, prepares profile control agent using simulating oil field produced water, driven when simulating 50 DEG C of oil reservoir
For experiment, after implementing profile control to three layers of heterogeneous core, simulation core heterogeneity is improved, has improved recovery ratio 22.6%, say
Bright profile control agent of the present invention can improve Reservoir Heterogeneity, and profile control effect is obvious.
Embodiment three:
1, profile control agent application method: (1) first to the sudden and violent oxygen processing of water progress is prepared, will prepare content of oxygen dissolved in water is reduced
To 3mg/L or less；(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.
2, prepare water: by the way that solubility salt regulating mineralization degree of injected oil is added into distilled water, final salinity is 35000mg/
L, to simulate oilfield sewage used in actual production.
3, concrete medicament application amount are as follows:
Slug A: Complex polymer is made of the partially hydrolyzed polyacrylamide (PHPA) of three kinds of different molecular quality, molecular mass point
It Wei not 500*104、800*104、1000*104, mass ratio 50:35:15；Complex polymer, citric acid, resorcinol, crow
Lip river tropine mass ratio is 0.15%:0.2%:0.03%:0.06%, and remaining components are to prepare water.
Slug B: cetyl trimethylammonium bromide, dodecyl sodium sulfate mass ratio be 2%:4%, remaining components be with
Water processed.
4, specific rock core manufacture scale is as follows:
Experiment rock core is quartz sand epoxy resin cementitious three layers of heterogeneous artificial cores, specific size 4.5cm*
4.5cm*30cm, gas permeability are respectively 10*10-3μm2、20*10-3μm2、40*10-3μm2, and add in rock core manufacturing process
The NaCl for entering 5% volume fraction, to simulate oil reservoir microcrack；By manually manufacture heterogeneous core to low-permeability sandstone oil reservoir into
Row simulation.
5, displacement oil is crude oil, and viscosity is 35mPa.s when temperature 70 C.
6, 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
All dissolution is discharged NaCl with driven water-replacing, with injection 10mg/L kaolin (0.5 μm -2 μm of partial size) mixing water in after image rock core
0.2PV takes out rock core after injection to simulate insoluble suspended matter in oil reservoir；
(2) rock core ready for use is put into 70 DEG C of insulating boxs to drying to constant weight, take out it is cooling after weigh its quality, be denoted 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, rock core is taken out into wiping and removes surface water, is weighed, quality is denoted as m10；
(4) rock core that saturation prepares water is put into core holding unit, adds confining pressure 4MPa, then with the speed of 0.4mL/min
It spends the injection into rock core and prepares water, to the pressure steady time recording pressure and flow；
(5) into rock core, positive injection slug A profile control agent 0.2PV is placed 36 hours, records pressure when injection profile agent,
Stand 48 hours for use；
(6) water drive is carried out with the speed of 2mL/min, record outlet brings out the first breakthrough pressure when dripping, steady to pressure
The time recording pressure and flow；
(7) whole experiment is carried out in 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.
7, sealing characteristics evaluation such as following table
Permeability is three layers of non-mean value rock core overall permeability before stifled, from the above in can obtain, slug A profile control agent pair
Three layers of non-mean value rock core have weak seal-off effect, and profile control agent is that movably, to be subsequently implanted into slug B, there are displacements to lead in rock core
Road.
8, 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
All dissolution is discharged NaCl with driven water-replacing, with injection 10mg/L kaolin (0.5 μm -2 μm of partial size) mixing water in after image rock core
0.2PV takes out rock core after injection to simulate insoluble suspended matter in oil reservoir；
(2) rock core ready for use is put into 70 DEG C of insulating boxs to drying to constant weight, take out it is cooling after weigh its quality, be denoted 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, rock core is taken out into wiping and removes surface water, is weighed, quality is denoted as m12；
(4) crude oil is saturated into rock core with the speed of 1.5mL/min, is driven to termination of pumping when outlet end is no longer discharged, record is tired
Water yield is counted, stands 4 hours for use；
(5) rock core for being saturated crude oil being put into core holding unit, whole process experiment is carried out in 70 DEG C of constant temperature, with
The speed of 2mL/min carries out water drive oil, be driven to outlet end it is no longer fuel-displaced when termination of pumping, record oil pump capacity and recovery ratio；
(6) slug A profile control agent 0.2PV is injected with the speed forward direction of 0.9mL/min, places 24 hours after having infused, then infuses
Enter to prepare water 0.4PV, be subsequently injected into slug B0.3PV, 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.
9, oil-displacement capacity evaluation is as follows:
It is learnt from above-mentioned data, prepares profile control agent using simulating oil field produced water, driven when simulating 70 DEG C of oil reservoir
For experiment, after implementing profile control to three layers of heterogeneous core, simulation core heterogeneity is improved, has improved recovery ratio 23.44%, say
Bright profile control agent of the present invention can improve Reservoir Heterogeneity, and profile control effect is obvious.
Claims (6)
1. a kind of double slug Compositional type profile control agents of low-permeability sandstone oil reservoir, which is characterized in that including slug A profile control agent and slug B；
Slug A profile control agent includes Complex polymer and additive；Wherein, Complex polymer by three kinds of different molecular quality part
Hydrolyzed polyacrylamide composition, molecular mass is respectively 500*104、800*104、1000*104, mass ratio 50:35:15；
Additive includes citric acid, resorcinol, methenamine；In slug A profile control agent, 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 to prepare water；And
Slug B includes cetyl trimethylammonium bromide and dodecyl sodium sulfate；In slug B, cetyl trimethyl bromination
Ammonium mass ratio is 1%-2%, and dodecyl sodium sulfate mass ratio is 3%-4%, and remaining components are to prepare water.
2. the double slug Compositional type profile control agents of a kind of low-permeability sandstone oil reservoir as described in claim 1, which is characterized in that the slug
Complex polymer, citric acid, resorcinol, methenamine mass ratio are 0.11%-0.14%:0.12%- in A profile control agent
0.18%:0.02%-0.03%:0.04%-0.05%, remaining components are to prepare water.
3. the double slug Compositional type profile control agents of a kind of low-permeability sandstone oil reservoir as described in claim 1, which is characterized in that the slug
Complex polymer, citric acid, resorcinol, methenamine mass ratio are 0.125%:0.15%:0.025% in A profile control agent:
0.045%, remaining components are to prepare water.
4. the double slug Compositional type profile control agents of a kind of low-permeability sandstone oil reservoir as described in claim 1, which is characterized in that the slug
Cetyl trimethylammonium bromide in B, dodecyl sodium sulfate mass ratio are 1.2%-1.8%:3.2%-3.8%, remaining group
It is divided into preparation water.
5. the double slug Compositional type profile control agents of a kind of low-permeability sandstone oil reservoir as described in claim 1, which is characterized in that the slug
Cetyl trimethylammonium bromide, dodecyl sodium sulfate mass ratio are 1.5%:3.5% in B, and remaining components are to prepare water.
6. a kind of application method of the double slug Compositional type profile control agents of low-permeability sandstone oil reservoir, which 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, will prepare oxygen in water and contains
Amount is reduced to 3mg/L or less；
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 stirring 4-6 is small
When, obtain profile control agent；
Water injection well is connect by step 4. with mixing vessel and supercharging device, starts supercharging device, profile control agent is injected oil reservoir；
Step 5. slug A profile control agent injection rate, which reaches, makes the abundant plastic of profile control agent for static 24-48 hours after preset range；
Step 6. injects driven water-replacing 0.4PV, injects slug B, then carries out subsequent note and adopts operation.
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| CN112943192A (en) * | 2021-02-03 | 2021-06-11 | 中国石油天然气股份有限公司 | Mining method suitable for low-permeability conglomerate oil reservoir |
| CN113863923A (en) * | 2021-10-18 | 2021-12-31 | 中国石油大学(北京) | Physical simulation experiment method for remaining oil distribution constrained by lake-bottom fan configuration |
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