CN114456782A - High-viscosity system for regulating and controlling oil deposit fluidity in strongly water flooded zone and preparation method and application thereof - Google Patents
High-viscosity system for regulating and controlling oil deposit fluidity in strongly water flooded zone and preparation method and application thereof Download PDFInfo
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- CN114456782A CN114456782A CN202011137658.9A CN202011137658A CN114456782A CN 114456782 A CN114456782 A CN 114456782A CN 202011137658 A CN202011137658 A CN 202011137658A CN 114456782 A CN114456782 A CN 114456782A
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 93
- 230000001105 regulatory effect Effects 0.000 title claims abstract description 42
- 230000001276 controlling effect Effects 0.000 title claims abstract description 39
- 238000002360 preparation method Methods 0.000 title abstract description 11
- 229920000642 polymer Polymers 0.000 claims abstract description 32
- 239000003381 stabilizer Substances 0.000 claims abstract description 23
- 239000008139 complexing agent Substances 0.000 claims abstract description 20
- 238000003756 stirring Methods 0.000 claims abstract description 19
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 6
- 238000007789 sealing Methods 0.000 claims abstract description 6
- 238000002347 injection Methods 0.000 claims description 24
- 239000007924 injection Substances 0.000 claims description 24
- 239000002736 nonionic surfactant Substances 0.000 claims description 21
- -1 polyoxyethylene Polymers 0.000 claims description 18
- 239000000243 solution Substances 0.000 claims description 18
- LYPJRFIBDHNQLY-UHFFFAOYSA-J 2-hydroxypropanoate;zirconium(4+) Chemical compound [Zr+4].CC(O)C([O-])=O.CC(O)C([O-])=O.CC(O)C([O-])=O.CC(O)C([O-])=O LYPJRFIBDHNQLY-UHFFFAOYSA-J 0.000 claims description 13
- KCXVZYZYPLLWCC-UHFFFAOYSA-N EDTA Chemical compound OC(=O)CN(CC(O)=O)CCN(CC(O)=O)CC(O)=O KCXVZYZYPLLWCC-UHFFFAOYSA-N 0.000 claims description 13
- PEDCQBHIVMGVHV-UHFFFAOYSA-N Glycerine Chemical compound OCC(O)CO PEDCQBHIVMGVHV-UHFFFAOYSA-N 0.000 claims description 9
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 claims description 9
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 claims description 8
- 239000007864 aqueous solution Substances 0.000 claims description 8
- 238000000034 method Methods 0.000 claims description 7
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 6
- KFZMGEQAYNKOFK-UHFFFAOYSA-N Isopropanol Chemical compound CC(C)O KFZMGEQAYNKOFK-UHFFFAOYSA-N 0.000 claims description 6
- 229920003171 Poly (ethylene oxide) Polymers 0.000 claims description 6
- BDERNNFJNOPAEC-UHFFFAOYSA-N propan-1-ol Chemical compound CCCO BDERNNFJNOPAEC-UHFFFAOYSA-N 0.000 claims description 6
- 238000005406 washing Methods 0.000 claims description 6
- 230000015572 biosynthetic process Effects 0.000 claims description 5
- 239000000203 mixture Substances 0.000 claims description 5
- 150000003973 alkyl amines Chemical class 0.000 claims description 3
- 125000000008 (C1-C10) alkyl group Chemical group 0.000 claims description 2
- 125000004169 (C1-C6) alkyl group Chemical group 0.000 claims description 2
- 230000000903 blocking effect Effects 0.000 claims description 2
- 235000014113 dietary fatty acids Nutrition 0.000 claims description 2
- 150000002148 esters Chemical class 0.000 claims description 2
- 239000000194 fatty acid Substances 0.000 claims description 2
- 229930195729 fatty acid Natural products 0.000 claims description 2
- 150000004665 fatty acids Chemical class 0.000 claims description 2
- 150000002191 fatty alcohols Chemical class 0.000 claims description 2
- 229940051841 polyoxyethylene ether Drugs 0.000 claims description 2
- 229920000056 polyoxyethylene ether Polymers 0.000 claims description 2
- 239000003921 oil Substances 0.000 description 68
- 238000011161 development Methods 0.000 description 7
- 230000018109 developmental process Effects 0.000 description 7
- 230000000694 effects Effects 0.000 description 7
- 239000003129 oil well Substances 0.000 description 5
- 229920006037 cross link polymer Polymers 0.000 description 4
- 238000012360 testing method Methods 0.000 description 4
- 239000003153 chemical reaction reagent Substances 0.000 description 3
- UIIMBOGNXHQVGW-UHFFFAOYSA-M Sodium bicarbonate Chemical compound [Na+].OC([O-])=O UIIMBOGNXHQVGW-UHFFFAOYSA-M 0.000 description 2
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 2
- 238000006073 displacement reaction Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 125000001495 ethyl group Chemical group [H]C([H])([H])C([H])([H])* 0.000 description 2
- 125000002496 methyl group Chemical group [H]C([H])([H])* 0.000 description 2
- 125000004123 n-propyl group Chemical group [H]C([H])([H])C([H])([H])C([H])([H])* 0.000 description 2
- 239000003973 paint Substances 0.000 description 2
- APLNAFMUEHKRLM-UHFFFAOYSA-N 2-[5-[2-(2,3-dihydro-1H-inden-2-ylamino)pyrimidin-5-yl]-1,3,4-oxadiazol-2-yl]-1-(3,4,6,7-tetrahydroimidazo[4,5-c]pyridin-5-yl)ethanone Chemical compound C1C(CC2=CC=CC=C12)NC1=NC=C(C=N1)C1=NN=C(O1)CC(=O)N1CC2=C(CC1)N=CN2 APLNAFMUEHKRLM-UHFFFAOYSA-N 0.000 description 1
- 125000003229 2-methylhexyl group Chemical group [H]C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])(C([H])([H])[H])C([H])([H])* 0.000 description 1
- BHPQYMZQTOCNFJ-UHFFFAOYSA-N Calcium cation Chemical compound [Ca+2] BHPQYMZQTOCNFJ-UHFFFAOYSA-N 0.000 description 1
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 description 1
- JLVVSXFLKOJNIY-UHFFFAOYSA-N Magnesium ion Chemical compound [Mg+2] JLVVSXFLKOJNIY-UHFFFAOYSA-N 0.000 description 1
- XUIMIQQOPSSXEZ-UHFFFAOYSA-N Silicon Chemical compound [Si] XUIMIQQOPSSXEZ-UHFFFAOYSA-N 0.000 description 1
- PMZURENOXWZQFD-UHFFFAOYSA-L Sodium Sulfate Chemical compound [Na+].[Na+].[O-]S([O-])(=O)=O PMZURENOXWZQFD-UHFFFAOYSA-L 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 125000000217 alkyl group Chemical group 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 229910001424 calcium ion Inorganic materials 0.000 description 1
- 239000003431 cross linking reagent Substances 0.000 description 1
- 125000001995 cyclobutyl group Chemical group [H]C1([H])C([H])([H])C([H])(*)C1([H])[H] 0.000 description 1
- 125000000113 cyclohexyl group Chemical group [H]C1([H])C([H])([H])C([H])([H])C([H])(*)C([H])([H])C1([H])[H] 0.000 description 1
- 125000001511 cyclopentyl group Chemical group [H]C1([H])C([H])([H])C([H])([H])C([H])(*)C1([H])[H] 0.000 description 1
- 125000001559 cyclopropyl group Chemical group [H]C1([H])C([H])([H])C1([H])* 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000010790 dilution Methods 0.000 description 1
- 239000012895 dilution Substances 0.000 description 1
- 239000012153 distilled water Substances 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- WGCNASOHLSPBMP-UHFFFAOYSA-N hydroxyacetaldehyde Natural products OCC=O WGCNASOHLSPBMP-UHFFFAOYSA-N 0.000 description 1
- 125000000959 isobutyl group Chemical group [H]C([H])([H])C([H])(C([H])([H])[H])C([H])([H])* 0.000 description 1
- 125000004491 isohexyl group Chemical group C(CCC(C)C)* 0.000 description 1
- 125000001972 isopentyl group Chemical group [H]C([H])([H])C([H])(C([H])([H])[H])C([H])([H])C([H])([H])* 0.000 description 1
- 125000001449 isopropyl group Chemical group [H]C([H])([H])C([H])(*)C([H])([H])[H] 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 229940050906 magnesium chloride hexahydrate Drugs 0.000 description 1
- DHRRIBDTHFBPNG-UHFFFAOYSA-L magnesium dichloride hexahydrate Chemical compound O.O.O.O.O.O.[Mg+2].[Cl-].[Cl-] DHRRIBDTHFBPNG-UHFFFAOYSA-L 0.000 description 1
- 229910001425 magnesium ion Inorganic materials 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 238000013508 migration Methods 0.000 description 1
- 230000005012 migration Effects 0.000 description 1
- 125000004108 n-butyl group Chemical group [H]C([H])([H])C([H])([H])C([H])([H])C([H])([H])* 0.000 description 1
- 125000003136 n-heptyl group Chemical group [H]C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])* 0.000 description 1
- 125000001280 n-hexyl group Chemical group C(CCCCC)* 0.000 description 1
- 125000000740 n-pentyl group Chemical group [H]C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])* 0.000 description 1
- 125000005244 neohexyl group Chemical group [H]C([H])([H])C(C([H])([H])[H])(C([H])([H])[H])C([H])([H])C([H])([H])* 0.000 description 1
- 125000001971 neopentyl group Chemical group [H]C([*])([H])C(C([H])([H])[H])(C([H])([H])[H])C([H])([H])[H] 0.000 description 1
- 230000000704 physical effect Effects 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 229910052710 silicon Inorganic materials 0.000 description 1
- 239000010703 silicon Substances 0.000 description 1
- 239000002210 silicon-based material Substances 0.000 description 1
- 235000017557 sodium bicarbonate Nutrition 0.000 description 1
- 229910000030 sodium bicarbonate Inorganic materials 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- 229910052938 sodium sulfate Inorganic materials 0.000 description 1
- 235000011152 sodium sulphate Nutrition 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 125000001424 substituent group Chemical group 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- 125000000999 tert-butyl group Chemical group [H]C([H])([H])C(*)(C([H])([H])[H])C([H])([H])[H] 0.000 description 1
- 125000001973 tert-pentyl group Chemical group [H]C([H])([H])C([H])([H])C(*)(C([H])([H])[H])C([H])([H])[H] 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5083—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
-
- 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
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Geochemistry & Mineralogy (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Detergent Compositions (AREA)
- Sealing Material Composition (AREA)
- Lubricants (AREA)
Abstract
The invention discloses a high-viscosity system for regulating and controlling the oil deposit fluidity in a strong water flooded area, which comprises the following components in parts by mass: 0.1-0.8 part of high molecular polymer A; 0.1-0.3 parts of a stabilizer; 0.01-0.05 parts of a complexing agent; 90-150 parts of water. The preparation method of the high-viscosity system for regulating and controlling the oil deposit fluidity in the strong water flooded area comprises the following steps: (1) adding water with the formula amount into a container, stirring, slowly adding the high molecular polymer A with the formula amount into the edge of a water vortex, and continuously stirring for more than 2 hours until the polymer A is completely dissolved to obtain a solution B; (2) sealing the solution B obtained in the step (1) at RT-85 ℃, standing for 24-48 h, then sequentially adding a stabilizer and a complexing agent in a formula amount into the solution B, and uniformly stirring to obtain the high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly water flooded area. The invention also discloses application of the high-viscosity system as a strong water flooded zone oil deposit plugging agent.
Description
Technical Field
The invention belongs to the field of oilfield development, and particularly relates to a high-viscosity system for regulating and controlling the oil deposit fluidity of a strong water flooded area, and a preparation method and application thereof.
Background
Most of domestic oil fields are developed by water injection, and part of oil fields with better physical properties are developed by chemical flooding. However, in the later stage of high-water-content development of a water-drive reservoir or after polymer flooding, the reservoir heterogeneity is intensified, so that an injection and production flow line flows along a high-permeability strip, the medium-high-permeability reservoir is poor in utilization, and the overall development effect of the reservoir is influenced.
Various profile control and plugging agents are applied to various large oil fields to improve development contradictions, and many oil fields are subjected to profile control and water plugging for multiple times, but the effect is increasingly poor; the existing block integral deep profile control and flooding technology can effectively improve a water absorption profile and realize stratum deep liquid flow diversion, so that the injected water wave and volume can be enlarged and the washing strength can be improved, and the technology gradually becomes an important means for improving the water area development effect and the oil field recovery ratio. However, the common plugging and adjusting system has poor migration performance and unsatisfactory plugging effect, affects the development effect of a high-water-cut oil reservoir, and particularly affects the development effect of a high-water-cut oil reservoir in a strong water flooding zone (the strong water flooding zone refers to a region in a water flooding oil reservoir, in which the residual oil saturation formed gradually by water flooding is between the residual oil saturation and the leading-edge oil saturation, namely a region in which the injected water wave and the oil saturation in the system are between the residual oil saturation and the leading-edge oil saturation), and the effect of the common plugging and adjusting method is not obvious. The field test and the indoor physical model test research show that the mobility of the oil reservoir in the strongly water-flooded zone is regulated and controlled, so that the subsequent water drive can furthest reach the relatively oil-enriched area. Therefore, a profile control agent and an oil displacement agent with both profile control function and oil displacement function are needed, and the system is required to have good temperature resistance, salt resistance, strong dilution resistance and shear resistance, good viscoelasticity, high effective viscosity in the stratum and good fluidity ratio control capability.
Disclosure of Invention
The purpose of the invention is as follows: aiming at the defects of the prior art, the invention discloses a high-viscosity system for regulating and controlling the oil deposit fluidity of a strong water flooded area, and a preparation method and application thereof.
The technical scheme is as follows: the high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly water flooded area comprises the following components in parts by mass:
0.1-0.8 part of high molecular polymer A, which has the following structural formula:
wherein n is more than or equal to 20 and more than or equal to 2, m is more than or equal to 100 and more than or equal to 2, R is C1-C10Alkyl groups of (a);
0.1-0.3 parts of a stabilizer;
0.01-0.05 parts of a complexing agent;
90-150 parts of water.
Further, the stabilizer is one or more of glycerol, glycol, methanol, ethanol, 1-propanol and 2-propanol.
Further, the complexing agent is a mixture of zirconium lactate and EDTA, wherein the mass ratio of EDTA to zirconium lactate is 0.01-0.05: 1.
furthermore, the mass ratio of the EDTA to the zirconium lactate is 0.02-0.04: 1.
Further, in the structural formula of the high molecular polymer a: n is more than or equal to 15 and more than or equal to 3, and m is more than or equal to 80 and more than or equal to 10.
Further, in the structural formula of the high molecular polymer a: n is more than or equal to 10 and more than or equal to 4, and m is more than or equal to 30 and more than or equal to 15.
Further, in the structural formula of the high molecular polymer a: r is C1-C6Alkyl group of (1).
Further, the paint comprises 0.3-0.5 part of high molecular polymer A.
Further, the stabilizer comprises 0.15-0.25 part of stabilizer.
Further, the water-soluble organic silicon-based organic silicon material comprises 0.02-0.03 part of complexing agent.
Further, the water-based paint comprises 98.85-99.79 parts of water.
The preparation method of the high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly water flooded area comprises the following steps:
(1) adding water with the formula amount into a container, stirring, slowly adding the high molecular polymer A with the formula amount into the edge of a water vortex, and continuously stirring for more than 2 hours until the polymer A is completely dissolved to obtain a solution B;
(2) sealing the solution B obtained in the step (1) at RT-85 ℃, standing for 24-48 h, then sequentially adding a stabilizer and a complexing agent in a formula amount into the solution B, and uniformly stirring to obtain the high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly water flooded area.
The high-viscosity system is used as a strong water flooded zone oil reservoir plugging agent.
The application comprises the following steps:
s1, injecting a certain amount of the high-viscosity system for regulating and controlling the oil deposit fluidity of the strong water flooding zone into the water injection well;
s2, injecting a certain amount of non-ionic surfactant aqueous solution into the water injection well to improve the oil washing efficiency;
further, the nonionic surfactant in step S2 is one or more of long-chain fatty alcohol polyoxyethylene ether, alkylphenol polyoxyethylene, fatty acid polyoxyethylene ester, and polyoxyethylene alkylamine.
Furthermore, the concentration of the non-ionic surfactant aqueous solution is 0.1-5%.
Further, the injection amount of the high viscosity system in step S1 is calculated according to the following formula:
W＝BπR2hΦ
in the formula: w-amount of injection, m3；
h-oil layer thickness, m;
r-plugging radius, m;
Φ — formation porosity,%;
b-dosage coefficient, the dosage coefficient is 0.95.
Furthermore, the plugging radius R is 20-70 m.
Furthermore, the plugging radius R is 25-60 m.
Furthermore, the plugging radius R is 45-55 m.
Further, the amount of the nonionic surfactant used in step S2 is 10% to 30% of the amount of the high viscosity system used in step S1.
More specifically, the amount of the nonionic surfactant used in step S2 is 24% to 26% of the amount of the high viscosity system used in step S1.
The high-viscosity system for regulating and controlling the oil deposit fluidity of the strong water flooded area, the preparation method and the application thereof disclosed by the invention have the following beneficial effects:
1. the high-viscosity system for regulating and controlling the oil deposit fluidity in the strong water flooded area is placed at the temperature of RT-85 ℃ for 24-48 hours and can react to generate a more high-viscosity gel system, and the gel system has higher viscosity than the high-viscosity system and has higher strength than cross-linked polymer gel formed by adding a cross-linking agent into a polymer commonly used in an oil field.
2. The high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly water flooded area is simple to prepare, and all components of the product can be purchased in the market;
3. the field process flow is simple and easy to operate.
The specific implementation mode is as follows:
the present invention is further described below with reference to examples, which are intended to be illustrative only, and are not intended to limit the scope of the present invention in any way.
Unless otherwise specified, the reagents used in the following examples are commercially available.
In the present invention, C1-C10The alkyl group of (A) includes methyl, ethyl, n-propyl, isopropyl, n-butyl, isobutyl, tert-butyl, n-pentyl, isopentyl, neopentyl, tert-pentyl, n-hexyl, isohexyl, neohexyl, tert-hexyl, n-heptyl, isoheptyl, neoheptyl, tert-heptyl, n-octyl, isooctyl, neooctyl, tert-octyl, n-nonyl, isononylNeononyl, tert-nonyl, n-decyl, isodecyl, neodecyl, tert-decyl, cyclopropyl, cyclobutyl, cyclopentyl, cyclohexyl.
In the experiment of the embodiment, the water for preparing the high-viscosity system is indoor prepared simulated water, and the preparation method comprises the following steps: placing a 5L narrow-necked flask on a 10kg balance, adding 4970.74g of distilled water to the narrow-necked flask, placing it on a magnetic stirrer after adding the magnetic stirrer, starting the stirrer to swirl the solution, and adding the following substances in the order listed: 0.6650g of sodium sulfate, 23.5500g of sodium chloride, 1.1100g of anhydrous calcium chloride, 1.1850g of magnesium chloride hexahydrate and 2.7550g of sodium bicarbonate. Each reagent is added until it is completely dissolved before the other reagent is added. Stirring with a magnetic stirrer for 15 minutes for later use. The total mineralization of the resulting solution was 5727 mg/L. Wherein the total amount of calcium ion and magnesium ion is 108 mg/L. The prepared brine is required to be homogeneous and transparent, has no precipitation phenomenon and has the validity period of 7 d.
The viscosity is measured by an Antopa MCR101 rheometer, the measurement temperature is 70 ℃, and the rotation speed is 7s-1。
Example 1
The high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly water flooded area comprises the following components in parts by mass:
0.3 part of high-molecular polymer A, the structural formula of which is as follows:
wherein n is 8, m is 20, and R is methyl;
0.2 part of a stabilizer;
0.03 part of complexing agent;
99.47 parts of water.
Further, the stabilizer is glycerol.
Further, the complexing agent is a mixture of zirconium lactate and EDTA, wherein the mass ratio of EDTA to zirconium lactate is 0.03: 1.
the preparation method of the high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly water flooded area comprises the following steps:
(1) adding water with the formula amount into a container, stirring, slowly adding the high molecular polymer A with the formula amount into the edge of a water vortex, and continuously stirring for more than 2 hours until the polymer A is completely dissolved to obtain a solution B;
(2) sealing the solution B obtained in the step (1) at 70 ℃, standing for 24h, then sequentially adding a stabilizer and a complexing agent in a formula amount into the solution B, and uniformly stirring to obtain the high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly water flooded zone.
The viscosity of the high-viscosity system obtained in the example is 1253.7mPa.s, while the viscosity of the high-viscosity system commonly used in oil fields with the same concentration is 256.9 mPa.s. The high-viscosity system obtained in the embodiment is placed in an oven at 70 ℃ for 24 hours, and is taken out to test the viscosity to be 22314.8mPa.s, and the viscosity to be 8425.7mPa.s after the gel is formed by the common cross-linked polymer in the oil field with the same concentration.
The oil reservoir temperature of a certain water injection well A is 60 ℃, the average thickness of the oil reservoir is 26.5m, the average porosity of the stratum is 38.8 percent, and the water content of the corresponding oil well is 98 percent.
The water well A is plugged by a high-viscosity system for regulating and controlling the oil deposit fluidity of the strong water flooded zone prepared in the embodiment 1, and the method comprises the following steps:
s1, injecting 1850m into water injection well3The high-viscosity system for regulating and controlling the oil deposit fluidity of the strong water flooding zone;
s2, and then injecting 450m into the water injection well3The non-ionic surface active agent water solution improves the oil washing efficiency;
further, the nonionic surfactant in step S2 is alkylphenol ethoxylate.
Further, the concentration of the nonionic surfactant aqueous solution was 0.5%.
Further, the injection amount of the high viscosity system in step S1 is calculated according to the following formula:
W＝BπR2hΦ
in the formula: w-amount of injection, m3；
h-oil layer thickness, m;
r-plugging radius, m;
Φ — formation porosity,%;
b-dosage coefficient, the dosage coefficient is 0.95.
Further, the amount of the nonionic surfactant used in step S2 is 24.32% of the amount of the high viscosity system used in step S1.
After the implementation, the water content of the corresponding oil well is finally reduced by 3 percent, and the oil is increased by 2800 t.
Example 2
The high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly water flooded area comprises the following components in parts by mass:
0.1 part of high-molecular polymer A, the structural formula of which is as follows:
wherein n is 2, m is 2, and R is ethyl;
0.1 part of a stabilizer;
0.01 part of complexing agent;
99.79 parts of water.
Further, the stabilizer is ethylene glycol.
Further, the complexing agent is a mixture of zirconium lactate and EDTA, wherein the mass ratio of EDTA to zirconium lactate is 0.01: 1.
the preparation method of the high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly water flooded area comprises the following steps:
(1) adding water with the formula amount into a container, stirring, slowly adding the high molecular polymer A with the formula amount into the edge of a water vortex, and continuously stirring for more than 2 hours until the polymer A is completely dissolved to obtain a solution B;
(2) and (2) sealing the solution B obtained in the step (1) and standing for 48h at room temperature, then sequentially adding a stabilizer and a complexing agent in a formula amount into the solution B, and uniformly stirring to obtain the high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly water flooded area.
The viscosity of the high-viscosity system obtained in the example is 1423.8mPa.s, while the viscosity of the high-viscosity system commonly used in oil fields with the same concentration is 256.9 mPa.s. The high-viscosity system obtained in the embodiment is placed in an RT oven for 48 hours, and the viscosity is measured to be 25321.9mPa.s after being taken out, and the viscosity is 8425.7mPa.s after the gel of the common crosslinked polymer with the same concentration in the oil field is formed.
The oil reservoir temperature of a certain water injection well B is 55 ℃, the average thickness of the oil reservoir is 27.5m, the average porosity of the stratum is 40.2 percent, and the water content of the corresponding oil well is 97 percent.
The water well B is plugged by a high-viscosity system for regulating and controlling the oil deposit fluidity of the strong water flooded zone prepared in the embodiment 2, and the method comprises the following steps:
s1, injecting 1957m into water injection well3The high-viscosity system for regulating and controlling the oil deposit fluidity of the strong water flooding zone;
s2, and then injecting 510m into the water injection well3The non-ionic surfactant aqueous solution improves the oil washing efficiency;
further, the nonionic surfactant in step S2 is alkylphenol ethoxylate.
Further, the concentration of the nonionic surfactant aqueous solution was 0.1%.
Further, the injection amount of the high viscosity system in step S1 is calculated according to the following formula:
W＝BπR2hΦ
in the formula: w-amount of injection, m3；
h-oil layer thickness, m;
r-plugging radius, m;
Φ — formation porosity,%;
b-dosage coefficient, the dosage coefficient is 0.95.
Further, the amount of the nonionic surfactant used in step S2 is 26% of the amount of the high viscosity system used in step S1.
After the application, the water content of the corresponding oil well is finally reduced by 2.5 percent, and the oil is increased by 2350 t.
Example 3
The high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly water flooded area comprises the following components in parts by mass:
0.8 part of high-molecular polymer A, the structural formula of which is as follows:
n is 10, m is 40, and R is n-propyl;
0.3 part of a stabilizer;
0.05 part of a complexing agent;
98.85 parts of water.
Further, the stabilizer is methanol.
Further, the complexing agent is a mixture of zirconium lactate and EDTA, wherein the mass ratio of EDTA to zirconium lactate is 0.05: 1.
the preparation method of the high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly water flooded area comprises the following steps:
(1) adding water with the formula amount into a container, stirring, slowly adding the high molecular polymer A with the formula amount into the edge of a water vortex, and continuously stirring for more than 2 hours until the polymer A is completely dissolved to obtain a solution B;
(2) sealing the solution B obtained in the step (1) at 85 ℃ and standing for 24h, then sequentially adding a stabilizer and a complexing agent in a formula amount into the solution B, and uniformly stirring to obtain the high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly flooded area.
The viscosity of the high-viscosity system obtained in the embodiment is 1015.8mPa.s, while the viscosity of the high-viscosity system commonly used in oil fields with the same concentration is 256.9 mPa.s. The high-viscosity system obtained in the embodiment is placed in an oven at 85 ℃ for 24 hours, and is taken out to test the viscosity to be 19326.4mPa.s, and the viscosity to be 8425.7mPa.s after the gel is formed by the common cross-linked polymer in the oil field with the same concentration.
In an offshore oil field, the reservoir temperature of an implementation well C is 65 ℃, the average thickness of an oil layer is 31.2m, the average porosity of a stratum is 37.2 percent, the water content is 95 percent,
the high-viscosity system for regulating and controlling the oil deposit fluidity of the strongly flooded zone prepared in the embodiment 3 is adopted for plugging, and the method comprises the following steps:
s1, injecting 3200m into water injection well3The high-viscosity system for regulating and controlling the oil deposit fluidity of the strong water flooding zone;
s2, and injecting 800m into the water injection well3The nonionic surfactant improves the oil washing efficiency;
further, the nonionic surfactant in step S2 is polyoxyethylene alkylamine.
Further, the concentration of the nonionic surfactant aqueous solution was 5%.
Further, the injection amount of the high viscosity system in step S1 is calculated according to the following formula:
W＝BπR2hΦ
in the formula: w-amount of injection, m3；
h-oil layer thickness, m;
r-plugging radius, m;
Φ — formation porosity,%;
b-dosage coefficient, the dosage coefficient is 0.95.
Further, the amount of the nonionic surfactant used in step S2 is 25% of the amount of the high viscosity system used in step S1.
After the implementation, the water content of the corresponding oil well is finally reduced by 4.5 percent, and the oil is increased by 5720 t.
Examples 4 to 10
Substantially the same as in example 1, except that m and n in the polymer a are different, specifically, as shown in the following table:
| n | m | |
| example 4 | 4 | 100 |
| Example 5 | 10 | 2 |
| Example 6 | 6 | 80 |
| Example 7 | 3 | 10 |
| Example 8 | 15 | 30 |
| Example 9 | 2 | 25 |
| Example 10 | 20 | 15 |
Examples 11 to 19
The same as example 1, except for the stabilizer:
example 20
Substantially the same as example 1, except that: the mass ratio of EDTA to zirconium lactate was 0.02: 1.
Example 21
Substantially the same as example 1, except that: the mass ratio of EDTA to zirconium lactate was 0.04: 1.
Examples 22 to 55
Substantially the same as example 1, except that: the substituents R in the high-molecular polymer a are different:
examples 56 to 58
The difference is essentially the same as in example 1, except that the parts of high molecular polymer a, stabilizer, and polymer b are different:
| high molecular Polymer A | Stabilizing agent | Complexing agents | Water (W) | |
| Example 56 | 0.2 | 0.15 | 0.02 | 99.45 |
| Example 57 | 0.4 | 0.25 | 0.25 | 99.1 |
| Example 58 | 0.5 | 0.22 | 0.28 | 99 |
Examples 59 to 65
The difference is essentially the same as in example 1, only in the nonionic surfactant, the blocking radius R:
examples 66 to 69
The method is approximately the same as the example 1, and only differs in that the content of water in the high-viscosity system for regulating the reservoir fluidity in the strong water flooding zone is different:
| content of Water (parts) | |
| Example 66 | 90 |
| Example 67 | 150 |
| Example 68 | 120 |
| Example 69 | 100 |
The embodiments of the present invention have been described in detail. However, the present invention is not limited to the above-described embodiments, and various changes can be made within the knowledge of those skilled in the art without departing from the spirit of the present invention.
Claims (16)
1. High viscous system for regulating and controlling oil deposit fluidity in a strong water flooding zone is characterized by comprising the following components in parts by mass:
0.1-0.8 part of high-molecular polymer A, which has the following structural formula:
wherein n is more than or equal to 20 and more than or equal to 2, m is more than or equal to 100 and more than or equal to 2, R is C1-C10Alkyl groups of (a);
0.1-0.3 parts of a stabilizer;
0.01-0.05 parts of a complexing agent;
90-150 parts of water.
2. The high-viscosity system for regulating and controlling reservoir fluidity in a strongly flooded water reservoir as claimed in claim 1, wherein the stabilizer is one or more of glycerol, ethylene glycol, methanol, ethanol, 1-propanol and 2-propanol.
3. The high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly flooded areas as claimed in claim 1, wherein the complexing agent is a mixture of zirconium lactate and EDTA, wherein the mass ratio of EDTA to zirconium lactate is 0.01-0.05: 1, preferably 0.02 to 0.04: 1.
4. The high-viscosity system for regulating and controlling reservoir fluidity in a strongly flooded zone as claimed in claim 1, wherein the structural formula of the high-molecular polymer A is as follows: 15. gtoreq.n.gtoreq.3, 80. gtoreq.m.gtoreq.10, preferably 10. gtoreq.n.gtoreq.4, 30. gtoreq.m.gtoreq.15.
5. The high-viscosity system for regulating reservoir fluidity in a strongly flooded zone as claimed in claim 1, wherein the high-molecular polymer A has the following structural formula: r is C1-C6Alkyl group of (1).
6. The high-viscosity system for regulating and controlling the reservoir fluidity in the strongly flooded zone as claimed in claim 1, which comprises 0.3-0.5 parts of high-molecular polymer A.
7. The high-viscosity system for regulating and controlling the reservoir fluidity in the strongly flooded areas as claimed in claim 1, which comprises 0.15 to 0.25 parts of stabilizer.
8. The high-viscosity system for regulating and controlling the reservoir fluidity in the strongly flooded areas as claimed in claim 1, which comprises 0.02-0.03 parts of complexing agent and 98.85-99.79 parts of water.
9. The method for preparing the high-viscosity system for regulating and controlling the reservoir fluidity of the strongly flooded zone as claimed in any one of claims 1 to 8, comprising the following steps:
(1) adding water with the formula amount into a container, stirring, slowly adding the high molecular polymer A with the formula amount into the edge of a water vortex, and continuously stirring for more than 2 hours until the polymer A is completely dissolved to obtain a solution B;
(2) sealing the solution B obtained in the step (1) at RT-85 ℃, standing for 24-48 h, then sequentially adding a stabilizer and a complexing agent in a formula amount into the solution B, and uniformly stirring to obtain the high-viscosity system for regulating and controlling the oil deposit fluidity in the strongly water flooded area.
10. Use of the high viscosity system according to any one of claims 1 to 8 as a strong water flooded zone reservoir plugging agent.
11. Use according to claim 10, comprising the following steps:
s1, injecting a certain amount of high-viscosity system for regulating and controlling the oil deposit fluidity of the strong water flooding zone into the water injection well;
and S2, injecting a certain amount of non-ionic surfactant aqueous solution into the water injection well, and improving the oil washing efficiency.
12. The use according to claim 10, wherein the nonionic surfactant in step S2 is one or more selected from long-chain fatty alcohol polyoxyethylene ether, alkylphenol ethoxylate, fatty acid polyoxyethylene ester, and polyoxyethylene alkylamine.
13. The use according to claim 11, wherein the concentration of the aqueous solution of the nonionic surfactant is 0.1 to 5%.
14. The use according to claim 11, wherein the injection amount of the high viscosity system in step S1 is calculated according to the following formula:
W＝BπR2hΦ
in the formula: w-amount of injection, m3；
h-oil layer thickness, m;
r-plugging radius, m;
Φ — formation porosity,%;
b-dosage coefficient, the dosage coefficient is 0.95.
15. Use according to claim 11, wherein the blocking radius R is 20 to 70m, preferably 25 to 60m, more preferably 45 to 55 m.
16. Use according to claim 11, wherein the amount of non-ionic surfactant used in step S2 is 10% to 30%, preferably 24% to 26% of the amount of high viscosity system used in step S1.
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| US4526947A (en) * | 1982-05-14 | 1985-07-02 | The Goodyear Tire & Rubber Company | N,N-Dimethylacrylamide copolymer injection water viscosifier for enhanced oil recovery |
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| CN104403658A (en) * | 2014-12-08 | 2015-03-11 | 中国石油大学(华东) | High-temperature-resistant crosslinking acid liquor system as well as preparation method thereof |
| CN106433599A (en) * | 2016-08-17 | 2017-02-22 | 富象油气技术服务有限公司 | Weakly-acidic copolymer fracturing fluid system and preparation method therefor |
| CN110616066A (en) * | 2019-10-14 | 2019-12-27 | 大庆市唯品科技开发有限公司 | Modified acrylamide microsphere gel plugging agent |
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| US4526947A (en) * | 1982-05-14 | 1985-07-02 | The Goodyear Tire & Rubber Company | N,N-Dimethylacrylamide copolymer injection water viscosifier for enhanced oil recovery |
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| US4736005A (en) * | 1982-05-14 | 1988-04-05 | The Goodyear Tire & Rubber Company | Injection water viscosifier for enhanced oil recovery |
| CN104403658A (en) * | 2014-12-08 | 2015-03-11 | 中国石油大学(华东) | High-temperature-resistant crosslinking acid liquor system as well as preparation method thereof |
| CN106433599A (en) * | 2016-08-17 | 2017-02-22 | 富象油气技术服务有限公司 | Weakly-acidic copolymer fracturing fluid system and preparation method therefor |
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