CN114517657B - Binary composite water control process for high-temperature high-salt bottom water reservoir - Google Patents
Binary composite water control process for high-temperature high-salt bottom water reservoir Download PDFInfo
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- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims abstract description 50
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- 229920002401 polyacrylamide Polymers 0.000 claims description 33
- 238000005187 foaming Methods 0.000 claims description 24
- 239000004088 foaming agent Substances 0.000 claims description 21
- GVGUFUZHNYFZLC-UHFFFAOYSA-N dodecyl benzenesulfonate;sodium Chemical group [Na].CCCCCCCCCCCCOS(=O)(=O)C1=CC=CC=C1 GVGUFUZHNYFZLC-UHFFFAOYSA-N 0.000 claims description 13
- 229940080264 sodium dodecylbenzenesulfonate Drugs 0.000 claims description 13
- 239000003431 cross linking reagent Substances 0.000 claims description 12
- KXGFMDJXCMQABM-UHFFFAOYSA-N 2-methoxy-6-methylphenol Chemical group [CH]OC1=CC=CC([CH])=C1O KXGFMDJXCMQABM-UHFFFAOYSA-N 0.000 claims description 8
- 241000237858 Gastropoda Species 0.000 claims description 8
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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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- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/512—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
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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
- C09K8/516—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
- C09K8/518—Foams
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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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
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Abstract
The invention relates to a profile control and water shutoff process in oil reservoir development, in particular to a binary compound water control process for a high-temperature high-salt bottom water oil reservoir. The process comprises the following steps: sequentially injecting a preposed protection liquid system, a weak plugging system, a transition system, a strong plugging system and a displacement system into the stratum; the weak blocking system comprises a first nitrogen slug, a bubbling liquid system 1 slug and a second nitrogen slug according to the injection sequence; the transition system is a bubbling liquid system 2-slug; the strong blocking system is a high-temperature-resistant gel slug; the displacement system comprises a polymer solution slug and a clear water slug according to the injection sequence. The process solves the problems of poor economic adaptability and technical adaptability when the pure chemical water plugging technology is applied to a high-temperature high-salt bottom water reservoir.
Description
Technical Field
The invention relates to the field of profile control and water shutoff process design in oil reservoir development and adjustment, in particular to a binary compound water control process for a high-temperature high-salinity bottom water reservoir.
Background
The high-temperature high-salt bottom water oil reservoir is a bottom water oil reservoir with the temperature of 75-130 ℃ and high salt content, and is an important reserve source of western oil fields in China. With the development of bottom water reservoirs, the problem of high water content of oil extraction wells is increasingly serious, and almost half of the water content of the oil extraction wells is more than 80%, so that the normal development of the reservoirs is seriously affected. Taking a clastic rock oil reservoir of a Tahe oil field as an example, the geological reserve is 6.788 X10. 10 4 tons, and the recovery rate is only 30.16%. Therefore, measures such as profile control/water shutoff and the like are urgently needed to improve the oil field development benefits.
At present, the water control method of the bottom water reservoir mainly comprises the following steps: changing the working system of the oil well, the water draining and controlling method, the electromagnetic heating method, the gas injection and controlling method and the chemical water controlling method. In development practice, chemical water shutoff gradually becomes the dominant water shutoff process of the bottom water reservoir. The formation conditions of high temperature and high salinity bottom water reservoirs present new challenges to the water control method: the high-temperature and high-salt resistant chemical system has higher cost, and the current low-oil price situation limits the dosage of the chemical system, so that the economic adaptability of chemical water shutoff is poor. Meanwhile, the bottom water has different invasion modes, and a single chemical system has the problem of oil-water co-plugging, so that the water plugging effect and the utilization rate of a high-cost chemical system are reduced, and the chemical water plugging technology of the single chemical system is insufficient.
In the field of horizontal well water control completion, the patent number ZL201410718031.0 is a variable parameter perforation water control completion method and device for a bottom water reservoir horizontal well, the liquid production amount of each water control unit which enables each water control unit to reach the target limit water content simultaneously is determined, and the perforation gun combinations of each water control unit which enable the perforation density rounding error to be minimum are definitely determined, so that the perforation density of each perforation unit is determined, and the variable parameter perforation water control completion operation of the bottom water reservoir horizontal well is carried out. The invention realizes the water control of the horizontal well of the bottom water reservoir through the variable parameter perforation water control well completion technical device of the horizontal well of the bottom water reservoir, and has the problems of high construction difficulty and the like. The application number is 201310397664.1, the invention name is a compound plugging agent for controlling water of oil well and the patent application of the preparation method discloses a temporary plugging agent for controlling water which can be used for the repeated fracturing, plugging removal and acidification measures of the old oil field developed by water injection, the temporary plugging agent is injected from the water-containing (20-40%) oil well, the dominant water flooding channel of the middle and high water-containing oil well is plugged, and the purpose of controlling water by the middle and high water-containing oil well measures is achieved; however, only a single chemical system is used, so that the plugging method has the problems of short plugging time, single water control capability and inapplicability to high-temperature oil reservoirs.
In summary, the mechanical water plugging method represented by the variable parameter perforation water control completion method has the problem of high construction difficulty, and the conventional single chemical water plugging method only considers the water plugging condition of a single chemical agent, has the problems of short plugging time, single water control capability and inapplicability to high-temperature oil reservoirs, and causes the water plugging of the high-temperature high-salt bottom water reservoirs to be a great problem in actual production. Therefore, there is a great need to develop a water control process suitable for high-temperature high-salt bottom water reservoirs.
Disclosure of Invention
Aiming at the problems and defects of chemical water plugging of the prior high-temperature high-salt bottom water reservoir, a binary composite water control process comprising a weak plugging system and a strong plugging system is designed, and the problems of poor economic adaptability and technical adaptability when the pure chemical water plugging technology is applied to the high-temperature high-salt bottom water reservoir are solved.
The invention provides a binary composite water control process for a high-temperature high-salt bottom water reservoir, which is characterized by comprising the following steps of: sequentially injecting a preposed protection liquid system, a weak plugging system, a transition system, a strong plugging system and a displacement system into the stratum; the weak blocking system comprises a first nitrogen slug, a bubbling liquid system 1 slug and a second nitrogen slug according to the injection sequence; the transition system is a bubbling liquid system 2-slug; the strong blocking system is a high-temperature-resistant gel slug; the displacement system comprises a polymer solution slug and a clear water slug according to the injection sequence.
The prepositive protection liquid system is a prepositive protection liquid slug and is used for protecting an oil layer. In some embodiments, the pre-protection liquid is a temperature-resistant and salt-resistant polymer as a raw material. In some embodiments, the pre-protection liquid system contains a temperature-resistant, salt-resistant polymer at a concentration of 0.25 wt%. In some embodiments, the temperature-resistant, salt-resistant polymer is resistant to high temperatures: 75-130 ℃; high salt resistance: mineralization degree is 0-24 multiplied by 10 4 mg/L, and calcium and magnesium ion content is 0-1.0 multiplied by 10 4 mg/L. In some embodiments, the temperature-resistant and salt-tolerant polymer in the pre-protection solution system is a polyacrylamide-based compound, such as polyacrylamide. In some embodiments, the pre-protection solution is a 0.25wt% aqueous polyacrylamide solution.
The weak blocking system comprises a first nitrogen slug, a bubbling liquid system 1 slug and a second nitrogen slug. The first nitrogen slug refers to a nitrogen slug injected before the frothing liquid system 1 slug, the purpose of which is to drive off water near the wellbore and form a froth upon subsequent spitback. In some embodiments, the foaming liquid system 1 slug contains a temperature resistant salt tolerant polymer at a concentration of 0.50wt% and a foaming agent at a concentration of 1.00 wt%. In some embodiments, the foaming fluid system 1 is resistant to high temperatures: 75-130 ℃; high salt resistance: mineralization degree is 0-24 multiplied by 10 4 mg/L, and calcium and magnesium ion content is 0-1.0 multiplied by 10 4 mg/L; at a concentration of 1.0%, the adsorption amount is less than 5mg/g (adsorption amount refers to the amount of polymer retained on the rock surface per unit of temperature-resistant salt-tolerant polymer). The second nitrogen slug refers to the nitrogen slug injected after the foaming liquid system 1 slug, the purpose of which is to create foam in the formation. In some embodiments, the temperature and salt resistant polymer in the foaming fluid system 1 slug is a polyacrylamide-based compound, such as polyacrylamide; the foaming agent is a surfactant, such as sodium dodecyl benzene sulfonate. In some embodiments, the foaming liquid system 1 slug is an aqueous solution formed by mixing polyacrylamide, sodium dodecylbenzene sulfonate and water.
The transition system is a bubbling liquid system 2-slug. In some embodiments, the foaming liquid system 2 is a temperature and salt resistant polymer and a foaming agent as raw materials. In some embodiments, the foaming liquid system 2 slug contains a temperature resistant salt tolerant polymer at a concentration of 0.10 to 0.15wt% and a foaming agent at a concentration of 1.00 wt%. In some embodiments, the temperature and salt resistant polymer in the foaming fluid system 2 slug is a polyacrylamide-based compound, such as polyacrylamide; the foaming agent is a surfactant, such as sodium dodecyl benzene sulfonate, or a sulfo-containing betaine. In some embodiments, the foaming liquid system 2 slug is an aqueous solution formed by mixing polyacrylamide, sodium dodecylbenzene sulfonate and water.
The strong blocking system is a high-temperature-resistant gel slug. In some embodiments, the high temperature resistant gel slugs contain a concentration of 0.50wt% of the temperature resistant salt resistant polymer and a concentration of 0.65wt% of the cross-linking agent. In some embodiments, the high temperature resistant gel slug is resistant to high temperatures: 75-130 ℃; high salt resistance: mineralization degree is 0-24 multiplied by 10 4 mg/L, and calcium and magnesium ion content is 0-1.0 multiplied by 10 4 mg/L; the plugging rate of the liquid can be more than 95 percent; the gel forming time can reach tens of hours; by adjusting the formulation, the intensity can be between D-H levels. In some embodiments, the temperature-resistant salt-tolerant polymer in the high temperature-resistant gel slug is a polyacrylamide-based compound, such as polyacrylamide; the cross-linking agent is a phenolic compound, such as a phenolic resin. In some embodiments, the high temperature resistant gel slug is an aqueous solution formed by mixing polyacrylamide, phenolic resin, and water.
The displacement system comprises a polymer solution slug and a clear water slug, and is used for positive displacement and removing residual plugging agent. In some embodiments, the polymer solution slugs contain a temperature-resistant salt-tolerant polymer at a concentration of 0 to 0.25 wt%. In some embodiments, the temperature and salt resistant polymer in the polymer solution slug is a polyacrylamide-based compound, such as polyacrylamide. In some embodiments, the polymer solution is an aqueous solution of 0 to 0.25wt% polyacrylamide.
In some embodiments, the injection amount of the pre-protection liquid system is 30-40 m 3; the injection amount of the first nitrogen slug is 20000-25000 sm 3; the injection quantity of the 1-slug of the foaming liquid system is 200-250 m 3; the injection amount of the second nitrogen slug is 40000-50000 sm 3; the injection quantity of the 2 slugs of the foaming liquid system is 50-60 m 3; the injection quantity of the high-temperature-resistant gel slug is 200-250 m 3; the injection quantity of the polymer solution slug is 20-30 m 3; and/or the injection amount of the clear water slug is 5-15 m 3.
The influence of the profile control water shutoff action radius, the stratum water storage capacity and the multidirectional channeling water flooding area on the dosage requirement of the plugging agent is comprehensively considered, and the dosage Q 1 of the plugging agent based on the profile control water shutoff action radius method explained by well testing or the dosage Q 2 of the plugging agent based on the stratum water storage capacity water flooding empirical method can be adopted.
(1) Well testing based profile control and flooding radius method
Based on the action radius determined by well test interpretation, the plugging radius is controlled to be 2/3 of the radius of the inner zone. Therefore, the blocking agent dosage Q 1 is calculated by using a profile control and water blocking action radius method, and the calculation formula is as follows:
Q 1＝3.14β1β2β3r2 h phi (formula 1)
Wherein Q 1 is the dosage of the plugging agent calculated by using the provided profile control and water plugging radius method, m 3;β1 is the plugging radius correction coefficient, and the reference value is 0.45; beta 2 is a plugging thickness correction coefficient, and the reference value is 0.5; beta 3 is the microscopic accessible pore volume fraction, reference value 0.5; r is the profile control water shutoff action radius determined by well test interpretation, m; h is the plugging thickness, the value is taken according to the water absorption thickness in the water absorption profile data, and the effective thickness is directly taken when the water absorption profile data is single-layer, and m is the effective thickness; Φ is the porosity, decimal.
(2) Water flooding empirical method based on stratum water storage capacity
According to the profile of a plurality of oilfield plugging control cases, based on the stratum water storage capacity in the well group range, calculating the plugging agent dosage Q 2 by using a water flooding experience method, wherein the calculation formula is as follows:
Q 2＝β(Wi-Wp) (equation 2)
Wherein, Q 2 is the dosage of the plugging agent calculated by using the provided water flooding empirical method, m 3; beta is the plugging dosage coefficient, 0.03-0.05; w i is the accumulated water injection quantity, m 3;Wp is the accumulated water yield, and m 3.
The binary composite water control of the high-temperature high-salt bottom water reservoir is realized by continuously injecting a preposed protection liquid system, a weak plugging system, a transition system, a strong plugging system and a displacement system into the stratum. The weak plugging system is temperature-resistant and salt-resistant nitrogen foam, and the strong plugging system is high-temperature-resistant gel. The nitrogen foam system has injection selectivity, namely 'large blockage is not small', 'water blockage is not blocked, oil blockage is not blocked', 'stable when meeting water and defoaming when meeting oil'; the high-temperature-resistant gel can effectively block the high-permeability layer, start the low-permeability layer and strengthen the foam blocking effect, so that the high-temperature high-salt bottom water reservoir is subjected to high-efficiency chemical water blocking. Compared with the prior art, the method has the advantages that the temperature-resistant salt-resistant nitrogen foam system is added in the conventional gel water shutoff process, the weak shutoff system is used for treating the section of the shaft, so that the pollution of the conventional technology to the non-crossflow position is avoided, the technical application condition is enlarged, the subsequent strong shutoff system can enter the crossflow position as much as possible, and the utilization rate of the strong shutoff system (gel) is improved. The binary composite water control process effectively reduces the consumption of a high-cost temperature-resistant salt-resistant gel system, improves the water blocking economic benefit, can be more suitable for different bottom water invasion modes such as heel end water outlet and toe end water outlet, improves the gel utilization rate, obtains higher oil increasing effect, and solves the problems of poor economic adaptability and technical adaptability when the existing simple gel water blocking technology is applied to a high-temperature high-salt bottom water reservoir (the temperature is 75-130 ℃, the mineralization degree is 0-21 multiplied by 10 4 mg/L).
Drawings
In order to more clearly illustrate the technical solutions of the present invention, the following brief description of the drawings is provided for the understanding that the drawings described below are merely exemplary embodiments of the present invention and are not intended to limit the scope of the present invention.
FIG. 1 is a schematic flow diagram of a binary compound water control process for a high temperature high salinity bottom water reservoir of the present invention.
Detailed Description
The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings, and it is apparent that the described embodiments are only some embodiments of the present invention, but not all embodiments, and the scope of the present invention is not limited thereto.
Polyacrylamide: molecular formula [ CH 2CH(CONH2) ] n, cas number 9003-05-8, temperature-resistant salt-resistant polymer. Sodium dodecyl benzene sulfonate: molecular formula C 18H29NaO3 S, cas number 25155-30-0, anionic surfactant. Phenolic resin: molecular formula (C 6H6O)n.(CH2 O) n, cas number 9003-35-4, cross-linking agent. The heat-resistant and salt-resistant polymer is a polymer with stable properties under the high-temperature and high-salt environment. Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention belongs.
In the following examples, the technical means used, unless otherwise specified, are all conventional in the art; the reagents used, unless otherwise specified, are commercially available or may be formulated according to conventional experimental methods.
The binary composite water control process for the high-temperature high-salinity bottom water reservoir has the preferable scheme shown in table 1.
TABLE 1
Sm 3 refers to the volume of gas under control conditions (20 degrees celsius, 1 standard atmosphere); the agent concentration (wt%) refers to the mass percent concentration of the compound in the solution. The temperature-resistant and salt-resistant polymer is polyacrylamide (with a molecular weight of 300 ten thousand); the foaming agent is sodium dodecyl benzene sulfonate; the cross-linking agent is phenolic resin.
Example 1
The oil well of the embodiment belongs to a high-temperature high-salt bottom water oil reservoir, the well depth is 4726.59m, the oil layer temperature is 118.2 ℃, the stratum mineralization degree is 21 multiplied by 10 4 mg/L, the calcium-magnesium ion concentration is 2.3 multiplied by 10 4 mg/L, and the water content is 82%. The binary compound water control method for the oil well comprises the following steps: and continuously injecting a preposed protection liquid system, a weak plugging system, a transition system, a strong plugging system and a displacement system into the stratum.
Step S11, injecting a prepositive protection liquid system
A pre-protection fluid of 30m 3 was injected into the well. The pre-protection liquid is a polyacrylamide (molecular weight is 300 ten thousand) aqueous solution with the mass fraction of 0.25%.
Step S12, injecting a weak plugging system
After the injection of the pre-protection liquid is completed, a first nitrogen slug of 20000sm 3, a bubbling liquid system 1 slug of 200m 3 and a second nitrogen slug of 40000sm 3 are sequentially injected. The foaming liquid system 1 slug is an aqueous solution formed by mixing a temperature-resistant and salt-resistant polymer, a foaming agent and water. The temperature-resistant and salt-resistant polymer is polyacrylamide (with a molecular weight of 300 ten thousand), and the mass fraction is 0.5%; the foaming agent is sodium dodecyl benzene sulfonate, and the mass fraction is 1%.
Step S13, injecting a transition system
After the injection of the weak plugging system is completed, 50m 3 foaming liquid system 2 slugs are injected. The foaming liquid system 2 slug is an aqueous solution formed by mixing a temperature-resistant and salt-resistant polymer, a foaming agent and water. The temperature-resistant and salt-resistant polymer is polyacrylamide (with the molecular weight of 300 ten thousand), and the mass fraction is 0.1-0.15%; the foaming agent is sodium dodecyl benzene sulfonate, and the mass fraction is 1%.
Step S14, injecting a strong plugging system
After the transition system injection is completed, 250m 3 high-temperature resistant gel slugs are injected. The high temperature resistant gel slug is an aqueous solution formed by mixing a temperature resistant salt resistant polymer, a cross-linking agent and water. The temperature-resistant and salt-resistant polymer is polyacrylamide (with a molecular weight of 300 ten thousand), and the mass fraction is 0.5%; the cross-linking agent is phenolic resin, and the mass fraction is 0.65%.
Step S15, injecting a displacement system
After the injection of the strong plugging system is completed, the polymer solution of 20m 3 and the clear water of 15m 3 are sequentially injected. The polymer solution is 0-0.25% of polyacrylamide (molecular weight 300 ten thousand) water solution by mass fraction.
After the oil well is controlled by the binary compound water control process, the effective period reaches 65 days, and the accumulated oil increasing amount reaches 883m 3.
Example 2
The oil well of the embodiment belongs to a high-temperature high-salt bottom water oil reservoir, the well depth is 5124.31m, the oil layer temperature is 122 ℃, the stratum mineralization degree is 21 multiplied by 10 4 mg/L, the calcium-magnesium ion concentration is 1.8 multiplied by 10 4 mg/L, and the water content is 92%. The binary compound water control method for the oil well comprises the following steps: and continuously injecting a preposed protection liquid system, a weak plugging system, a transition system, a strong plugging system and a displacement system into the stratum.
Step S11, injecting a prepositive protection liquid system
A 40m 3 pre-protection fluid is injected into the well. The pre-protection liquid is a polyacrylamide (molecular weight 300 ten thousand) aqueous solution with the mass fraction of 0.25%.
Step S12, injecting a weak plugging system
After the injection of the pre-protection liquid is completed, a 25000sm 3 first nitrogen slug, a 250m 3 bubbling liquid system 1 slug and a 50000sm 3 second nitrogen slug are sequentially injected. The foaming liquid system 1 slug is an aqueous solution formed by mixing a temperature-resistant and salt-resistant polymer, a foaming agent and water. The temperature-resistant and salt-resistant polymer is polyacrylamide (with a molecular weight of 300 ten thousand), and the mass fraction is 0.5%; the foaming agent is sodium dodecyl benzene sulfonate, and the mass fraction is 1%.
Step S13, injecting a transition system
After the injection of the weak plugging system is completed, 60m 3 foaming liquid system 2 slugs are injected. The foaming liquid system 2 slug is an aqueous solution formed by mixing a temperature-resistant and salt-resistant polymer, a foaming agent and water. The temperature-resistant and salt-resistant polymer is polyacrylamide (with the molecular weight of 300 ten thousand), and the mass fraction is 0.1-0.15%; the foaming agent is sodium dodecyl benzene sulfonate, and the mass fraction is 1%.
Step S14, injecting a strong plugging system
After the injection of the transition system is completed, 200m 3 high-temperature-resistant gel slugs are injected. The high temperature resistant gel slug is an aqueous solution formed by mixing a temperature resistant salt resistant polymer, a cross-linking agent and water. The temperature-resistant and salt-resistant polymer is polyacrylamide (with a molecular weight of 300 ten thousand), and the mass fraction is 0.5%; the cross-linking agent is phenolic resin, and the mass fraction is 0.65%.
Step S15, injecting a displacement system
After the injection of the strong plugging system is completed, the polymer solution of 30m 3 and the clear water of 10m 3 are sequentially injected. The polymer solution is 0-0.25% of polyacrylamide (molecular weight 300 ten thousand) water solution by mass fraction.
After the oil well is controlled by the binary compound water control process, the effective period is 240 days, and the accumulated oil increasing amount reaches 669m 3.
Example 3
The oil well of the embodiment belongs to a high-temperature high-salt bottom water oil reservoir, the well depth is 4531.24m, the oil layer temperature is 113.3 ℃, the stratum mineralization degree is 20 multiplied by 10 4 mg/L, the calcium-magnesium ion concentration is 2.1 multiplied by 10 4 mg/L, and the water content is 78%. The binary compound water control method for the oil well comprises the following steps: and continuously injecting a preposed protection liquid system, a weak plugging system, a transition system, a strong plugging system and a displacement system into the stratum.
Step S11, injecting a prepositive protection liquid system
35M 3 of pre-protection liquid is injected into the oil well. The pre-protection liquid is a polyacrylamide (molecular weight 300 ten thousand) aqueous solution with the mass fraction of 0.25%.
Step S12, injecting a weak plugging system
After the injection of the pre-protection liquid is completed, a 22000sm 3 first nitrogen slug, a 220m 3 bubbling liquid system 1 slug and a 45000sm 3 second nitrogen slug are sequentially injected. The foaming liquid system 1 slug is an aqueous solution formed by mixing a temperature-resistant and salt-resistant polymer, a foaming agent and water. The temperature-resistant and salt-resistant polymer is polyacrylamide (with a molecular weight of 300 ten thousand), and the mass fraction is 0.5%; the foaming agent is sodium dodecyl benzene sulfonate, and the mass fraction is 1%.
Step S13, injecting a transition system
And after the injection of the weak plugging system is finished, injecting a 55m 3 foaming liquid system 2 slug. The foaming liquid system 2 slug is an aqueous solution formed by mixing a temperature-resistant and salt-resistant polymer, a foaming agent and water. The temperature-resistant and salt-resistant polymer is polyacrylamide (with the molecular weight of 300 ten thousand), and the mass fraction is 0.1-0.15%; the foaming agent is sodium dodecyl benzene sulfonate, and the mass fraction is 1%.
Step S14, injecting a strong plugging system
After the transition system injection is completed, a 230m 3 high-temperature-resistant gel slug is injected. The high temperature resistant gel slug is an aqueous solution formed by mixing a temperature resistant salt resistant polymer, a cross-linking agent and water. The temperature-resistant and salt-resistant polymer is polyacrylamide (with a molecular weight of 300 ten thousand), and the mass fraction is 0.5%; the cross-linking agent is phenolic resin, and the mass fraction is 0.65%.
Step S15, injecting a displacement system
After the injection of the strong plugging system is completed, 25m 3 of polymer solution and 5m 3 of clear water are sequentially injected. The polymer solution is polyacrylamide (molecular weight 300 ten thousand) aqueous solution with mass fraction of 0-025%.
After the oil well is controlled by the binary compound water control process, the effective period is 352 days, and the accumulated oil increasing amount reaches 10176m 3.
The foregoing description of the embodiments has been provided for the purpose of illustrating the general principles of the invention, and is not meant to limit the scope of the invention, but to limit the invention to the particular embodiments, and any modifications, equivalents, improvements, etc. that fall within the spirit and principles of the invention are intended to be included within the scope of the invention.
Claims (5)
1. A binary composite water control process for a high-temperature high-salt bottom water reservoir is characterized by comprising the following steps of: sequentially injecting a preposed protection liquid system, a weak plugging system, a transition system, a strong plugging system and a displacement system into the stratum;
the weak blocking system comprises a first nitrogen slug, a bubbling liquid system 1 slug and a second nitrogen slug according to the injection sequence; the transition system is a bubbling liquid system 2-slug; the strong blocking system is a high-temperature-resistant gel slug; the displacement system comprises a polymer solution slug and a clear water slug according to the injection sequence;
The pre-protection liquid system contains a temperature-resistant and salt-resistant polymer with the concentration of 0.25 weight percent;
the foaming liquid system 1 slug contains a temperature resistant and salt resistant polymer with the concentration of 0.50 weight percent and a foaming agent with the concentration of 1.00 weight percent;
the foaming liquid system 2 slug contains a temperature-resistant and salt-resistant polymer with the concentration of 0.10 to 0.15 weight percent and a foaming agent with the concentration of 1.00 weight percent;
The high temperature resistant gel slug contains a temperature resistant salt resistant polymer with a concentration of 0.50wt% and a cross-linking agent with a concentration of 0.65 wt%;
the polymer solution slug contains the temperature-resistant and salt-resistant polymer with the concentration of 0-0.25 wt%.
2. The binary complex water control process for a high temperature high salt bottom water reservoir of claim 1, wherein: the temperature-resistant and salt-resistant polymer is polyacrylamide.
3. The binary complex water control process for a high temperature high salt bottom water reservoir of claim 1, wherein: the foaming agent is sodium dodecyl benzene sulfonate.
4. The binary complex water control process for a high temperature high salt bottom water reservoir of claim 1, wherein: the cross-linking agent is phenolic resin.
5. The binary complex water control process for a high temperature and high salt bottom water reservoir according to any one of claims 1 to 4, wherein:
the injection amount of the pre-protection liquid system is 30-40 m 3;
The injection amount of the first nitrogen slug is 20000-25000 sm 3;
the injection quantity of the 1-slug of the foaming liquid system is 200-250 m 3;
The injection amount of the second nitrogen slug is 40000-50000 sm 3;
the injection quantity of the 2 slugs of the foaming liquid system is 50-60 m 3;
the injection quantity of the high-temperature-resistant gel slug is 200-250 m 3;
the injection quantity of the polymer solution slug is 20-30 m 3;
and/or the injection amount of the clear water slug is 5-15 m 3.
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