CN112922571B - Mud sand blocking prevention and control technology suitable for loose sandstone oil reservoir water injection - Google Patents
Mud sand blocking prevention and control technology suitable for loose sandstone oil reservoir water injection Download PDFInfo
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- CN112922571B CN112922571B CN202110273180.0A CN202110273180A CN112922571B CN 112922571 B CN112922571 B CN 112922571B CN 202110273180 A CN202110273180 A CN 202110273180A CN 112922571 B CN112922571 B CN 112922571B
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 67
- 239000007924 injection Substances 0.000 title claims abstract description 49
- 238000002347 injection Methods 0.000 title claims abstract description 49
- 230000002265 prevention Effects 0.000 title claims abstract description 20
- 239000004576 sand Substances 0.000 title abstract description 34
- 238000005516 engineering process Methods 0.000 title abstract description 13
- 230000000903 blocking effect Effects 0.000 title abstract description 8
- 239000004927 clay Substances 0.000 claims abstract description 45
- 239000000243 solution Substances 0.000 claims abstract description 44
- 239000002245 particle Substances 0.000 claims abstract description 43
- 238000009736 wetting Methods 0.000 claims abstract description 28
- 238000013508 migration Methods 0.000 claims abstract description 27
- 239000012313 reversal agent Substances 0.000 claims abstract description 23
- 238000000034 method Methods 0.000 claims abstract description 13
- 229920006317 cationic polymer Polymers 0.000 claims abstract description 11
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 11
- 239000003381 stabilizer Substances 0.000 claims abstract description 10
- 150000003839 salts Chemical class 0.000 claims abstract description 9
- 239000004094 surface-active agent Substances 0.000 claims abstract description 9
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims abstract description 8
- 239000011780 sodium chloride Substances 0.000 claims abstract description 8
- 150000001412 amines Chemical class 0.000 claims abstract description 6
- 241000237858 Gastropoda Species 0.000 claims description 18
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 claims description 16
- 239000012267 brine Substances 0.000 claims description 11
- 229920001577 copolymer Polymers 0.000 claims description 11
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 claims description 11
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 claims description 10
- FJLUATLTXUNBOT-UHFFFAOYSA-N 1-Hexadecylamine Chemical compound CCCCCCCCCCCCCCCCN FJLUATLTXUNBOT-UHFFFAOYSA-N 0.000 claims description 9
- XAEFZNCEHLXOMS-UHFFFAOYSA-M potassium benzoate Chemical compound [K+].[O-]C(=O)C1=CC=CC=C1 XAEFZNCEHLXOMS-UHFFFAOYSA-M 0.000 claims description 8
- 239000001103 potassium chloride Substances 0.000 claims description 8
- 235000011164 potassium chloride Nutrition 0.000 claims description 8
- 239000000126 substance Substances 0.000 claims description 7
- LMRVIBGXKPAZLP-UHFFFAOYSA-N trimethyl-[2-methyl-2-(prop-2-enoylamino)propyl]azanium;chloride Chemical compound [Cl-].C[N+](C)(C)CC(C)(C)NC(=O)C=C LMRVIBGXKPAZLP-UHFFFAOYSA-N 0.000 claims description 3
- 238000011084 recovery Methods 0.000 abstract description 28
- 239000006185 dispersion Substances 0.000 abstract description 26
- 230000036571 hydration Effects 0.000 abstract description 20
- 238000006703 hydration reaction Methods 0.000 abstract description 20
- 229920000642 polymer Polymers 0.000 abstract description 9
- 230000008569 process Effects 0.000 abstract description 7
- 238000011161 development Methods 0.000 abstract description 6
- 230000035699 permeability Effects 0.000 abstract description 6
- 239000003093 cationic surfactant Substances 0.000 abstract description 5
- 229910017053 inorganic salt Inorganic materials 0.000 abstract description 4
- 238000005406 washing Methods 0.000 abstract description 4
- 230000009286 beneficial effect Effects 0.000 abstract description 3
- 239000012530 fluid Substances 0.000 abstract description 3
- 230000000694 effects Effects 0.000 description 26
- 239000011435 rock Substances 0.000 description 25
- 239000003921 oil Substances 0.000 description 20
- 230000005012 migration Effects 0.000 description 16
- 230000005764 inhibitory process Effects 0.000 description 15
- 238000002474 experimental method Methods 0.000 description 12
- 238000012360 testing method Methods 0.000 description 11
- 230000002401 inhibitory effect Effects 0.000 description 10
- 238000004519 manufacturing process Methods 0.000 description 9
- -1 ammonium ions Chemical class 0.000 description 8
- 230000009467 reduction Effects 0.000 description 7
- 239000004111 Potassium silicate Substances 0.000 description 6
- 230000004913 activation Effects 0.000 description 6
- 238000012986 modification Methods 0.000 description 6
- 230000004048 modification Effects 0.000 description 6
- NNHHDJVEYQHLHG-UHFFFAOYSA-N potassium silicate Chemical compound [K+].[K+].[O-][Si]([O-])=O NNHHDJVEYQHLHG-UHFFFAOYSA-N 0.000 description 6
- 229910052913 potassium silicate Inorganic materials 0.000 description 6
- 235000019353 potassium silicate Nutrition 0.000 description 6
- LZZYPRNAOMGNLH-UHFFFAOYSA-M Cetrimonium bromide Chemical compound [Br-].CCCCCCCCCCCCCCCC[N+](C)(C)C LZZYPRNAOMGNLH-UHFFFAOYSA-M 0.000 description 5
- REYJJPSVUYRZGE-UHFFFAOYSA-N Octadecylamine Chemical compound CCCCCCCCCCCCCCCCCCN REYJJPSVUYRZGE-UHFFFAOYSA-N 0.000 description 5
- VBIIFPGSPJYLRR-UHFFFAOYSA-M Stearyltrimethylammonium chloride Chemical compound [Cl-].CCCCCCCCCCCCCCCCCC[N+](C)(C)C VBIIFPGSPJYLRR-UHFFFAOYSA-M 0.000 description 5
- 230000015572 biosynthetic process Effects 0.000 description 5
- 238000005755 formation reaction Methods 0.000 description 5
- 229960000789 guanidine hydrochloride Drugs 0.000 description 5
- PJJJBBJSCAKJQF-UHFFFAOYSA-N guanidinium chloride Chemical compound [Cl-].NC(N)=[NH2+] PJJJBBJSCAKJQF-UHFFFAOYSA-N 0.000 description 5
- WFIZEGIEIOHZCP-UHFFFAOYSA-M potassium formate Chemical compound [K+].[O-]C=O WFIZEGIEIOHZCP-UHFFFAOYSA-M 0.000 description 5
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 description 4
- 230000002579 anti-swelling effect Effects 0.000 description 4
- 239000002734 clay mineral Substances 0.000 description 4
- 230000003631 expected effect Effects 0.000 description 4
- 238000000605 extraction Methods 0.000 description 4
- 238000009472 formulation Methods 0.000 description 4
- 239000000203 mixture Substances 0.000 description 4
- 239000012071 phase Substances 0.000 description 4
- VEXZGXHMUGYJMC-UHFFFAOYSA-M Chloride anion Chemical compound [Cl-] VEXZGXHMUGYJMC-UHFFFAOYSA-M 0.000 description 3
- 239000002253 acid Substances 0.000 description 3
- 239000003513 alkali Substances 0.000 description 3
- 235000019270 ammonium chloride Nutrition 0.000 description 3
- 150000003863 ammonium salts Chemical class 0.000 description 3
- 150000002357 guanidines Chemical class 0.000 description 3
- 238000005098 hot rolling Methods 0.000 description 3
- 230000002209 hydrophobic effect Effects 0.000 description 3
- 239000003112 inhibitor Substances 0.000 description 3
- 239000011148 porous material Substances 0.000 description 3
- 206010042674 Swelling Diseases 0.000 description 2
- SWLVFNYSXGMGBS-UHFFFAOYSA-N ammonium bromide Chemical compound [NH4+].[Br-] SWLVFNYSXGMGBS-UHFFFAOYSA-N 0.000 description 2
- FLNKWZNWHZDGRT-UHFFFAOYSA-N azane;dihydrochloride Chemical compound [NH4+].[NH4+].[Cl-].[Cl-] FLNKWZNWHZDGRT-UHFFFAOYSA-N 0.000 description 2
- 239000010779 crude oil Substances 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 238000011156 evaluation Methods 0.000 description 2
- 229910052500 inorganic mineral Inorganic materials 0.000 description 2
- 235000010755 mineral Nutrition 0.000 description 2
- 239000011707 mineral Substances 0.000 description 2
- 229910052757 nitrogen Inorganic materials 0.000 description 2
- 125000004433 nitrogen atom Chemical group N* 0.000 description 2
- 125000004430 oxygen atom Chemical group O* 0.000 description 2
- 239000003208 petroleum Substances 0.000 description 2
- SCVFZCLFOSHCOH-UHFFFAOYSA-M potassium acetate Chemical compound [K+].CC([O-])=O SCVFZCLFOSHCOH-UHFFFAOYSA-M 0.000 description 2
- 229910001414 potassium ion Inorganic materials 0.000 description 2
- 230000008961 swelling Effects 0.000 description 2
- 239000008346 aqueous phase Substances 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 150000001768 cations Chemical class 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- QKIUAMUSENSFQQ-UHFFFAOYSA-N dimethylazanide Chemical compound C[N-]C QKIUAMUSENSFQQ-UHFFFAOYSA-N 0.000 description 1
- 239000012153 distilled water Substances 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- DXTIKTAIYCJTII-UHFFFAOYSA-N guanidine acetate Chemical compound CC([O-])=O.NC([NH3+])=N DXTIKTAIYCJTII-UHFFFAOYSA-N 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
- 229920002521 macromolecule Polymers 0.000 description 1
- 239000002736 nonionic surfactant Substances 0.000 description 1
- 239000012466 permeate Substances 0.000 description 1
- 235000011056 potassium acetate Nutrition 0.000 description 1
- 229960004109 potassium acetate Drugs 0.000 description 1
- 238000011112 process operation Methods 0.000 description 1
- 238000012827 research and development Methods 0.000 description 1
- 238000005096 rolling process Methods 0.000 description 1
- 239000000523 sample Substances 0.000 description 1
- 239000012488 sample solution Substances 0.000 description 1
- 230000035945 sensitivity Effects 0.000 description 1
- 239000000344 soap Substances 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- 239000013589 supplement Substances 0.000 description 1
- 229920002554 vinyl polymer Polymers 0.000 description 1
- 230000000007 visual effect Effects 0.000 description 1
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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
- E21B43/20—Displacing by water
-
- 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
- C09K8/56—Compositions for consolidating loose sand or the like around wells without excessively decreasing the permeability thereof
- C09K8/57—Compositions based on water or polar solvents
- C09K8/575—Compositions based on water or polar solvents containing organic compounds
- C09K8/5751—Macromolecular compounds
- C09K8/5753—Macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/56—Compositions for consolidating loose sand or the like around wells without excessively decreasing the permeability thereof
- C09K8/57—Compositions based on water or polar solvents
- C09K8/575—Compositions based on water or polar solvents containing organic compounds
- C09K8/5751—Macromolecular compounds
- C09K8/5755—Macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/584—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- 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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- 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
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/12—Swell inhibition, i.e. using additives to drilling or well treatment fluids for inhibiting clay or shale swelling or disintegrating
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- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Organic Chemistry (AREA)
- Materials Engineering (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
- Soil Conditioners And Soil-Stabilizing Materials (AREA)
Abstract
The invention relates to a silt blockage prevention and control technology suitable for water injection development of a loose sandstone reservoir. The technical scheme is as follows: before injecting water into the stratum through an injection well, a saline slug is injected into the stratum, then a wetting reversal agent solution slug is injected, then a clay stabilizer solution slug is injected, and finally water injection is started. Wherein the salt comprises inorganic salt and organic salt; the wetting reversal agent is mainly a nonionic organic amine surfactant, a cationic surfactant and the like; the clay stabilizer is clay particle anti-migration agent, mainly organic nonionic polymer, organic cationic polymer, etc. The beneficial effects are that: the process is simple to operate, can effectively inhibit hydration expansion and hydration dispersion of clay in a unconsolidated sandstone stratum in the water injection process, can prevent mud and sand particles from migrating and blocking a fluid seepage channel, ensures that the permeability of the water injection stratum is not reduced, can improve the water injection sweep coefficient and the oil washing efficiency, and combines secondary oil recovery and tertiary oil recovery, thereby improving the water injection recovery ratio.
Description
Technical Field
The invention relates to a process technology for water injection and oil extraction of an oil field, in particular to a mud-sand blockage prevention and control technology suitable for water injection of a loose sandstone reservoir.
Background
Oilfield flooding is an important oil extraction technical measure after primary oil extraction, also called secondary oil extraction. The main principle of water injection oil production is to inject water into an oil reservoir through an injection well to supplement formation energy, drive reservoir crude oil into a production well by using the injected water, and then carry out production through artificial lift.
The unconsolidated sandstone reservoir rock has low cementing strength and high clay mineral content, and is easy to generate hydration expansion, hydration dispersion and particle migration of clay in the water injection process, and the particle migration blockage is generated at the pore throat of a seepage channel, so that the permeability of a water injection stratum is reduced, and the water injection efficiency and the recovery ratio of a production well are reduced. In order to overcome the above disadvantages, various chemicals, such as polymer, alkali and surfactant, etc., are usually added into the injection water, which not only increases the cost of water injection oil production, but also prematurely transfers to the chemical flooding (i.e. tertiary oil recovery) stage, so that the water injection oil production cycle is significantly shortened. In addition, the problems of clay hydration and sand blockage caused by particle migration, which are puzzling the water injection process of the unconsolidated sandstone reservoir, are not fundamentally solved. Therefore, research and development of a silt blockage prevention and control technology suitable for water injection development of unconsolidated sandstone reservoirs are urgently needed.
Disclosure of Invention
The invention aims to provide a silt blocking prevention and control technology suitable for water injection of unconsolidated sandstone reservoirs, which is simple in technological process operation, can effectively inhibit hydration expansion and hydration dispersion of clay in unconsolidated sandstone formations in the water injection process, can prevent silt particles from migrating and blocking fluid seepage channels, ensures that the permeability of the water injection formations is not reduced, and can improve the water injection sweep coefficient and the oil washing efficiency, thereby improving the water injection recovery ratio.
The invention provides a mud sand blocking prevention and control technology suitable for loose sandstone oil reservoir water injection, which adopts the technical scheme that: the method comprises the following steps: before injecting water into the stratum through the injection well, firstly injecting a saline slug into the stratum, then injecting a wetting reversal agent solution slug, then injecting a clay stabilizer solution slug, and finally starting injecting water;
the brine slug is inorganic salt, organic brine solution or mixed aqueous solution of the inorganic salt and the organic brine solution, and the mass percentage concentration is 4-15%;
the wetting reversal agent can be a nonionic organic amine surfactant, a cationic surfactant and the like, and the mass percentage concentration is 0.1-0.5%;
the clay stabilizer is a clay particle migration inhibitor, and the mass percentage concentration is 0.1% -0.5%.
Preferably, the inorganic salt is mainly potassium chloride, ammonium chloride or potassium silicate, and the organic salt can be potassium formate, potassium acetate, guanidine hydrochloride or guanidine acetate.
Preferably, the nonionic organic amine surfactant may be hexadecylamine or octadecylamine, and the cationic surfactant may be hexadecyltrimethyl chloride/ammonium bromide or octadecyltrimethyl chloride/ammonium bromide.
Preferably, the clay particle anti-migration agent may be an organic nonionic polymer or an organic cationic polymer.
Preferably, the organic nonionic polymer may be a polymer having a tertiary nitrogen atom in a side chain.
Preferably, the organic cationic polymer may be a polymer having a quaternary nitrogen atom in a side chain.
Compared with the prior art, the invention has the following beneficial effects:
(1) The brine slug is mainly used for carrying out anti-swelling treatment on the formation clay: because the potassium salt and the ammonium salt in the brine have good anti-swelling effect on the clay, the sizes (the diameter is 0.266 nm) of the potassium ions and the ammonium ions are matched with the size of a regular hexagon inscribed circle (the diameter is 0.280 nm) surrounded by 6 oxygen atoms between clay layers and on the surface, so that the potassium ions and the ammonium ions are easily inlaid into the space and coordinated with 12 oxygen atoms on two sides, and the electronegativity of the clay surface can be effectively reduced; the binding force of cations in the organic guanidine salt and the negative charge surface of the clay is stronger than that of potassium salt and ammonium salt, so that the organic guanidine salt has better anti-swelling effect than inorganic potassium salt and ammonium salt; on one hand, the potassium silicate can react with the expansive clay mineral to convert the expansive clay mineral into non-expansive mineral, and the non-expansive mineral covers the surface of the expansive clay mineral to effectively prevent free water from contacting with the expansive clay, so that the anti-swelling aim is achieved; on the other hand, the potassium silicate belongs to strong alkali weak acid salt, can generate corresponding petroleum acid soap surfactant on site with petroleum acid in crude oil, and plays a role of improving recovery ratio by alkali flooding;
(2) The wetting reversal agent solution slug has the effects that the wetting reversal is firstly carried out on the surface of sand-mud particles, namely, the surface is reversed from hydrophilicity to hydrophobicity, and the hydrophobic stratum particles are not easy to move along with injected water, so that the particle movement blockage of the stratum sand-mud is effectively prevented; secondly, the wetting reversal agent belongs to a surfactant, and is beneficial to improving the oil washing efficiency;
(3) The clay particle anti-migration agent solution slug has the main function of connecting the clay particles with the stratum through the adsorption groups of the polymer macromolecules and has certain binding and fixing effects on the migration particles; meanwhile, the polymer can remarkably improve the viscosity of water, reduce the water-oil fluidity ratio and improve the sweep coefficient. Therefore, the technology can effectively inhibit hydration expansion and hydration dispersion of clay in the unconsolidated sandstone stratum in the water injection process, prevent mud and sand particles from migrating and blocking a fluid seepage channel, ensure that the permeability of the water injection stratum is not reduced, improve the water injection sweep coefficient and the oil washing efficiency, and combine secondary oil recovery and tertiary oil recovery, thereby improving the water injection recovery ratio.
Drawings
FIG. 1 is a schematic diagram of a slug for preventing and controlling sand and mud clogging during water injection according to the present invention;
FIG. 2 is a schematic view of an activation index measuring device;
FIG. 3 is a photograph comparing wetting before and after sand surface modification with 0.4% hexadecylamine;
FIG. 4 is a photograph of water droplets on the surface of the silt particle before and after modification;
in the upper diagram: a water injection well A, a production well B, residual oil 1, brine 2, a wetting reversal agent solution 3, a clay stabilizer solution 4 and water 5.
Detailed Description
The preferred embodiments of the present invention will be described in conjunction with the accompanying drawings, and it should be understood that they are presented herein only to illustrate and explain the present invention and not to limit the present invention.
Example 1:
the invention provides a silt blockage prevention and control technology suitable for water injection development of a loose sandstone reservoir, which adopts the technical scheme that: before injecting water into the stratum through an injection well, a saline slug is injected into the stratum, then a wetting reversal agent solution slug is injected, then a clay stabilizer solution slug is injected, and finally water injection is started.
The salt in the brine slug is inorganic potassium salt, specifically industrial potassium chloride, and the mass percentage concentration is 8%.
The wetting reversal agent in the wetting reversal agent solution slug is a nonionic organic amine surfactant, specifically hexadecylamine, and the mass percentage concentration is 0.4%.
The clay particle anti-migration agent in the clay particle anti-migration agent solution slug is an organic cationic polymer, specifically a copolymer of acrylamide and (2-acrylamido-2-methyl) propyl trimethyl ammonium chloride, and the mass percentage concentration of the organic cationic polymer is 0.3%.
The chemical formula of the three slugs is as follows: 8% potassium chloride +0.4% hexadecylamine +0.3% acrylamide/2-acrylamido-2-methyl propyl trimethyl ammonium chloride copolymer.
(1) Inhibiting the hydration expansion and hydration dispersion of clay
The effects of inhibiting clay hydration expansion and hydration dispersion performance of the three slugs are evaluated according to a core linear expansion rate experiment and a rock debris dispersion recovery rate experiment method which are commonly used in the industry.
The linear expansion rate experiment test indexes of the rock core are respectively a linear expansion rate and a relative linear expansion reduction rate. Wherein linear expansion ratio
(in the formula:S linear expansion,%;H 8h the linear expansion of the core is 8h and is mm;Has the original height of the core, mm); relative linear expansionRate of reduction of swelling
(in the formula:S i relative linear expansion reduction,%;S w relative expansion rate of distilled water for 8h,%;S s the relative expansion rate,%) of the sample liquid 8 h. The smaller the linear expansion rate is, the higher the relative linear expansion reduction rate is, and the stronger the inhibition expansion and the inhibition dispersion effect on the clay are.
The test index of the rock debris rolling dispersion recovery rate experiment is the rock debris recovery rate
(in the formula:mg, mass of the recovered rock debris;m 0 g) is the initial total mass of the rock debris, and the higher the recovery rate is generally, the better the clay hydration dispersion inhibition performance is. The primary rock debris recovery rate is the recovery rate measured after the rock debris is subjected to hot rolling for 16 hours in a sample solution, the secondary rock debris recovery rate is the recovery rate measured after the primary recovered rock debris is subjected to hot rolling for 16 hours in clear water, and the tertiary rock debris recovery rate is the recovery rate measured after the secondary recovered rock debris is continuously subjected to hot rolling for 16 hours in clear water. The long-term effect of inhibiting clay dispersion can be further illustrated by the recovery rate of the third rock debris.
The results of the experiment are shown in tables 1 and 2.
As can be seen from Table 1, the three solution slugs all have obvious inhibition effects on the linear expansion of the core, wherein the inhibition effect of 0.3 percent of acrylamide and (2-acrylamide-2-methyl) propyl trimethyl ammonium chloride copolymer is strongest, the inhibition effect of 0.4 percent of hexadecylamine is intermediate, and the inhibition effect of 8 percent of potassium chloride is lowest. The data in Table 2 show that the three solution slugs are highly effective in inhibiting debris dispersion, with 0.3% acrylamide being the highest copolymer with (2-acrylamido-2-methyl) propyltrimethylammonium chloride, followed by 0.4% hexadecylamine and finally by 8% potassium chloride. It can be seen that the cationic polymer has the best ability to inhibit clay swelling and dispersion, the nonionic surfactant is centered, and the potassium chloride is weaker.
TABLE 1 core Linear expansion test results
TABLE 2 experimental results on the dispersion recovery of rock debris
(2) Efficiency of wet reversal
The main function of the hexadecylamine solution slug is to change the surface wettability of the formation sand particles from hydrophilicity to hydrophobicity. The method mainly adopts the activation index and the contact angle index to evaluate the surface wettability of the silt particles.
FIG. 2 shows an apparatus for measuring the activation index.
Index of activationHThe calculation formula of (2) is as follows:
in the formula:Hactivation index,%;m 0 is the total mass of the silt particles, g;m 1 the mass of the silt particles settled at the bottom of the separatory funnel or at the bottom of the beaker, g.
Index of activationHThe larger the size, the more hydrophobic the silt particle.
The method for measuring the contact angle of the silt particles is to press the silt particles into a plane and then measure the contact angle on the silt plane by using a contact angle measuring instrument. The larger the contact angle of the aqueous phase, the more hydrophobic.
And respectively selecting sand grains and mud and sand samples returned from the stratum for evaluation. The visual experimental phenomena are shown in fig. 3 and 4.
As can be seen from fig. 4, the mud sand before modification is dropped with the dyed (for easy observation) water drops on the surface thereof and then quickly infiltrates the mud sand and permeates the pores between the mud sand particles to disappear, while the mud sand after modification is dropped with the dyed water drops on the surface thereof and then fails to infiltrate the pores between the mud sand particles, which shows that the mud sand after modification is dropped with the dyed water drops on the surface thereof and thatThe surface of the particles exhibits strong hydrophobicity. The water phase contact angle is measured by a contact angle measuring instrumentθIs 148 deg..
(3) Prevention and control effect of mud and sand particle migration
In order to comprehensively evaluate the prevention and control effect of the three slugs on the migration and blockage of the silt particles after the three slugs are injected into the rock core, a sand filling pipe is designed (the specification of the sand filling pipe is thatφ25mm multiplied by 320 mm) instead of a core holder, and the critical flow rate of the sand-packed pipe sandstone core column is tested by using a core flow testerv c Permeability damage rate of particulate migration pluggingD t Sand yieldm s And the reduction rate of sand productionm r And (4) indexes. The specific experimental method is carried out according to the evaluation method of reservoir sensitivity flow experiment (SY/T5358-2010) of the oil and gas industry standard of the people's republic of China.
Critical flow rate of sand-filled pipe sand core columnv c The greater the permeability damage rateD t Smaller and smaller sand yieldm s Smaller, lower sand yield reduction ratem r The larger the sand conveying blockage prevention and control effect is, the better. The results of the experiment are shown in table 9, example 1.
Referring to table 9 at the end, the data show that the expected effect of controlling the sand-mud blockage is achieved after the cores are injected sequentially according to the slug solution formulation of example 1.
Example 2:
the invention provides a silt blockage prevention and control technology suitable for water injection development of a loose sandstone reservoir, which adopts the technical scheme that: before injecting water into the stratum through an injection well, a saline slug is injected into the stratum, then a wetting reversal agent solution slug is injected, then a clay stabilizer solution slug is injected, and finally water injection is started.
The salt in the saline water slug is organic potassium salt, specifically potassium formate, and the mass percentage concentration is 6%.
The wetting reversal agent in the wetting reversal agent solution slug is a cationic surfactant, specifically cetyl trimethyl ammonium bromide, and the mass percentage concentration is 0.3%.
The clay particle migration inhibitor in the clay particle migration inhibitor solution slug is an organic nonionic polymer, specifically polyvinyl dimethyl amide, and the mass percentage concentration is 0.4%.
The chemical formula of the three slugs is as follows: 6% potassium formate +0.3% cetyltrimethylammonium bromide +0.4% polyvinyldimethylamide.
(1) Inhibiting the hydration expansion and hydration dispersion of clay
The results of the core linear expansion rate test and the rock debris dispersion recovery rate test are shown in tables 3 and 4.
As can be seen from table 3, the three solution slugs all had significant inhibition of the linear expansion of the core, with 6% potassium formate being the strongest, 0.4% polyvinyldimethylamide being the median, and 0.3% cetyltrimethylammonium bromide being the lowest. The data in table 4 show that the three solution slugs have a pronounced effect in inhibiting the dispersion of rock debris, with 0.4% polyvinyldimethylamide being the highest, followed by 0.3% cetyltrimethylammonium bromide, and finally 6% potassium formate.
TABLE 3 core Linear expansion test results
TABLE 4 experimental results on the dispersion recovery rate of rock debris
(2) Efficiency of wet reversal
Hexadecyl trimethyl ammonium bromide activation indexHThe content was found to be 75%. Its water phase wetting angleθAnd is 88 deg..
(3) Prevention and control effect of sand and mud particle migration
The results of the experiment are shown in table 9, example 2. The data in table 9 show that the expected effect of controlling the sand-mud plugging is achieved after the cores are injected sequentially according to the slug solution formulation of example 2.
Example 3:
the invention provides a silt blockage prevention and control technology suitable for water injection development of a loose sandstone reservoir, which adopts the technical scheme that: before injecting water into the stratum through an injection well, a saline slug is injected into the stratum, then a wetting reversal agent solution slug is injected, then a clay stabilizer solution slug is injected, and finally water injection is started.
The salt in the brine slug is organic guanidine salt, specifically guanidine hydrochloride, and the mass percentage concentration is 5%.
The wetting reversal agent in the wetting reversal agent solution slug is a cationic surfactant, specifically octadecyl trimethyl ammonium chloride, and the mass percentage concentration is 0.3%.
The clay particle anti-migration agent in the clay particle anti-migration agent solution slug is an organic cationic polymer, specifically a copolymer of acrylamide and (2-acrylamido-2-methyl) propyl methylene pentamethyl bis-ammonium chloride, and the mass percentage concentration is 0.2%.
The chemical formula of the three slugs is as follows: 5% guanidine hydrochloride +0.3% octadecyl trimethyl ammonium chloride +0.2% acrylamide and (2-acrylamido-2-methyl) propylmethylene pentamethyl bis ammonium chloride copolymer.
(1) Inhibiting the hydration expansion and hydration dispersion of clay
The results of the core linear expansion rate test and the rock debris dispersion recovery test are shown in tables 5 and 6.
As can be seen from Table 5, the three solution slugs all have significant inhibition effects on the linear expansion of the core, wherein the inhibition effect of the copolymer of 0.2% acrylamide and (2-acrylamido-2-methyl) propyl methylene pentamethyl bis-ammonium chloride is strongest, the inhibition effect of the copolymer of 0.3% octadecyl trimethyl ammonium chloride is in the middle, and the inhibition effect of the copolymer of 5% guanidine hydrochloride is the lowest. The data in Table 6 show that three solution slugs have a pronounced effect in inhibiting the dispersion of rock debris, with 0.2% acrylamide copolymerized with (2-acrylamido-2-methyl) propylmethylenepentamethyldimethylammonium chloride, followed by 0.3% octadecyl trimethyl ammonium chloride and finally 5% guanidine hydrochloride.
TABLE 5 results of core Linear expansion experiments
TABLE 6 experimental results on the dispersion recovery rate of rock debris
(2) Efficiency of wet reversal
Octadecyl trimethyl ammonium chloride activation indexHThe content was 81%. Its water phase wetting angleθAnd was 92.4 deg..
(3) Prevention and control effect of sand and mud particle migration
The results of the experiment are shown in table 9, example 3. The data in table 9 show that the expected effect of controlling the sand-mud plugging is achieved after cores are injected sequentially according to the slug solution formulation of example 3.
Example 4:
the invention provides a silt blockage prevention and control technology suitable for loose sandstone reservoir water injection development, which adopts the technical scheme that: before injecting water into the stratum through an injection well, a saline slug is injected into the stratum, then a wetting reversal agent solution slug is injected, then a clay stabilizer solution slug is injected, and finally water injection is started.
The salt in the brine slug is inorganic potassium salt, specifically potassium silicate, and the mass percentage concentration is 7%.
The wetting reversal agent in the wetting reversal agent solution slug is a nonionic organic amine surfactant, specifically octadecylamine, and the mass percentage concentration is 0.4%.
The clay particle anti-migration agent in the clay particle anti-migration agent solution slug is an organic cationic polymer, specifically polyoxypropylene trimethyl ammonium chloride, and the mass percentage concentration is 0.3%.
The chemical formula of the three slugs is as follows: 7% potassium silicate +0.4% octadecylamine +0.3% polyoxypropylene trimethyl ammonium chloride.
(1) Inhibiting the hydration expansion and hydration dispersion of clay
The results of the core linear expansion test and the rock debris dispersion recovery test are shown in tables 7 and 8.
As can be seen from Table 7, the three solution slugs all have significant inhibition effects on the linear expansion of the core, wherein 0.3% of polyoxypropylene trimethyl ammonium chloride has the strongest inhibition effect, 0.4% of octadecylamine is centered, and 7% of potassium silicate has the lowest effect. The data in table 8 show that the three solution slugs have a prominent effect of inhibiting the dispersion of rock debris, in a sequence consistent with the linear expansion inhibition sequence.
TABLE 7 core Linear expansion test results
TABLE 8 experimental results on the dispersion recovery rate of rock debris
(2) Efficiency of wet reversal
Activation index of octadecylamineHThe content was found to be 96%. Its water phase wetting angleθAnd is 155 deg..
(3) Prevention and control effect of mud and sand particle migration
The results of the experiment are shown in table 9, example 4. The data in table 9 show that the expected effect of controlling the sand-mud plugging is achieved after the cores are injected sequentially according to the slug solution formulation of example 4.
TABLE 9 prevention and control effect of sand migration blockage after three slugs are injected successively
Compared with the injection of standard brine, after the three slugs are respectively injected, the critical flow rate of the core column of the sandstone is obviously reduced, the damage rate of the migration and blockage of the particles is obviously reduced, and the quantity of the produced sand is obviously reduced. The sand production reduction rates of the four embodiments are all higher than 60%, and a good mud and sand migration blocking prevention and control effect is achieved.
The above description is only a few preferred embodiments of the present invention, and any person skilled in the art may modify the above-described embodiments or modify them into equivalent ones. Therefore, the technical solution according to the present invention is subject to corresponding simple modifications or equivalent changes, as far as the scope of the present invention is claimed.
Claims (1)
1. The utility model provides a silt particle blocks up prevention and control technique suitable for loose sandstone oil reservoir water injection, characterized by: the method comprises the following steps: before injecting water into the stratum through the injection well, firstly injecting a saline slug into the stratum, then injecting a wetting reversal agent solution slug, then injecting a clay stabilizer solution slug, and finally starting injecting water;
the salt in the brine slug is inorganic potassium salt, the inorganic potassium salt is industrial potassium chloride, and the mass percentage concentration is 8%;
the wetting reversal agent in the wetting reversal agent solution slug is hexadecylamine serving as a nonionic organic amine surfactant, and the mass percentage concentration of the wetting reversal agent is 0.4%;
the clay particle anti-migration agent in the clay particle anti-migration agent solution slug is an organic cationic polymer, the organic cationic polymer is a copolymer of acrylamide and (2-acrylamido-2-methyl) propyl trimethyl ammonium chloride, and the mass percentage concentration of the organic cationic polymer is 0.3%;
the chemical formula of the three slugs is as follows: 8 percent of potassium chloride, 0.4 percent of hexadecylamine, 0.3 percent of acrylamide and (2-acrylamide-2-methyl) propyl trimethyl ammonium chloride copolymer according to mass percentage concentration.
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