CN114517657A - Binary composite water control process for high-temperature high-salinity bottom water reservoir - Google Patents
Binary composite water control process for high-temperature high-salinity bottom water reservoir Download PDFInfo
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- GVGUFUZHNYFZLC-UHFFFAOYSA-N dodecyl benzenesulfonate;sodium Chemical group [Na].CCCCCCCCCCCCOS(=O)(=O)C1=CC=CC=C1 GVGUFUZHNYFZLC-UHFFFAOYSA-N 0.000 claims description 13
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/512—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—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
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
Abstract
The invention relates to a profile control and water shutoff process in oil reservoir development, in particular to a binary composite water control process for a high-temperature high-salinity 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 foaming liquid system 1 slug and a second nitrogen slug according to the injection sequence; the transition system is a foaming 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 problem of poor economic and technical adaptability when the single-purification chemical water plugging technology is applied to high-temperature high-salinity bottom water reservoirs.
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 composite water control process for a high-temperature high-salinity bottom water oil reservoir.
Background
The high-temperature high-salinity bottom water reservoir refers to a bottom water reservoir with the temperature of 75-130 ℃ and high salinity, and is an important reserve source of western oil fields in China. Along with the development of bottom water oil reservoirs, the problem of high water content of oil production wells is increasingly serious, almost half of the oil production wells contain more than 80 percent of water, and the normal development of the oil reservoirs is seriously influenced. Taking the talhe oil field clastic rock oil reservoir as an example, the geological reserve is found to be 6.788 multiplied by 104Ton, and recovery is only 30.16%. Therefore, it is urgently needed to develop measures such as profile control/water shutoff and the like to improve the development benefits of the oil field.
At present, the water control method of the bottom water reservoir mainly comprises the following steps: changing the working system of oil well, water draining and controlling method, electromagnetic heating method, gas injecting and controlling method and chemical water controlling method. In development practice, chemical water shutoff gradually becomes the bottom water reservoir leading water shutoff process. The formation conditions of high-temperature 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 dosage of the chemical system is limited by the current low oil price situation, so that the economic adaptability of chemical water plugging is poor. Meanwhile, bottom water has different invasion modes, and a single chemical system has the problem of oil-water co-blocking, so that the water blocking effect and the utilization rate of a high-cost chemical system are reduced, and the technical defect of chemical water blocking of the single chemical system exists.
The patent No. ZL201410718031.0, which is named as a variable parameter perforation water control well completion method and device for a bottom water reservoir horizontal well, is used in the field of horizontal well water control well completion, and is used for determining the liquid production amount of each water control unit which enables each water control unit to simultaneously reach the target ultimate water content, and determining the perforating gun bullet combination of each water control unit which enables the perforation density rounding error to be minimum, so that the perforation density of each perforation unit is determined, and the variable parameter perforation water control well completion operation of the bottom water reservoir horizontal well is carried out. The invention realizes the water control of the bottom water reservoir horizontal well through the variable parameter perforation water control well completion technical device of the bottom water reservoir horizontal well, and has the problems of high construction difficulty and the like. The patent application with the application number of 201310397664.1 and the invention name of the composite plugging agent for oil well water control and the preparation method thereof discloses a temporary plugging agent for water control, which can be used for repeated fracturing, deblocking and acidizing measures of water injection development of old oil fields, the temporary plugging agent is injected from a water-containing (20-40%) oil well to block a dominant water drive channel of a high and medium water-containing oil well, and the purpose of controlling water by the measures of the high and medium water-containing oil well is realized; but only a single chemical system is used, so that the plugging method has the problems of short plugging time, single water control capacity and unsuitability for high-temperature oil reservoirs.
In conclusion, the mechanical water plugging method represented by the variable-parameter perforation water control well completion method has the problem of high construction difficulty, and the conventional single chemical water plugging method only considers the situation of water plugging by a single chemical agent, so that the problems of short plugging time, single water control capability and unsuitability for high-temperature oil reservoirs exist, and the water plugging of the high-temperature high-salinity bottom water oil reservoir becomes a great problem in actual production. Therefore, the development of a water control process suitable for high-temperature high-salinity bottom water reservoirs is urgently needed.
Disclosure of Invention
Aiming at the problems and defects of chemical water plugging of the high-temperature high-salinity bottom water reservoir at present, 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 poor technical adaptability when a single-purification chemical water plugging technology is applied to the high-temperature high-salinity bottom water reservoir are solved.
The invention provides a binary composite water control process for a high-temperature high-salinity 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 foaming liquid system 1 slug and a second nitrogen slug according to the injection sequence; the transition system is a foaming 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 preposed protective liquid system is a preposed protective liquid slug and is used for protecting an oil layer. In some embodiments, the material of the front protection solution is a temperature-resistant salt-tolerant polymer. In some embodiments, the pre-protection solution system contains a temperature and salt resistant polymer at a concentration of 0.25 wt%. In some embodiments, the temperature and salt tolerant polymer is resistant to high temperatures: 75-130 ℃; high salt resistance: degree of mineralization of 0 to 24X 104mg/L, calcium and magnesium ion content of 0-1.0 x 104mg/L. In some embodiments, the temperature and salt resistant polymer in the pre-protection solution system is a polyacrylamide compound, such as polyacrylamide. In some embodiments, the pre-protection solution is a 0.25 wt% aqueous solution of polyacrylamide.
The weak blocking system comprises a first nitrogen slug, a foaming liquid system 1 slug and a second nitrogen slug. The first nitrogen slug refers to the nitrogen slug injected before the slug of the foaming fluid system 1, which is intended to drive off the water near the wellbore and form foam upon subsequent re-spitting. In some embodiments, the foaming fluid system 1 slug contains0.50 wt% of temperature-resistant salt-resistant polymer and 1.00 wt% of foaming agent. In some embodiments, the foaming fluid system 1 is resistant to high temperatures: 75-130 ℃; high salt resistance: degree of mineralization of 0 to 24X 104mg/L, calcium and magnesium ion content of 0-1.0 x 104mg/L; when the concentration is 1.0%, the adsorption capacity is less than 5mg/g (the adsorption capacity refers to the amount of the temperature-resistant and salt-resistant polymer per unit retained on the surface of the rock). The second nitrogen slug refers to a slug of nitrogen injected after the slug of foaming liquid system 1, the purpose of which is to generate foam in the formation. In some embodiments, the temperature and salt tolerant polymer in the slug of the foaming fluid system 1 is a polyacrylamide compound, such as polyacrylamide; the foaming agent is a surfactant, such as sodium dodecylbenzene sulfonate. In some embodiments, the foaming fluid system 1 slug is an aqueous solution formed by mixing polyacrylamide, sodium dodecylbenzenesulfonate and water.
The transition system is a foaming liquid system 2 slug. In some embodiments, the foaming liquid system 2 is prepared from a temperature-resistant salt-tolerant polymer and a foaming agent. In some embodiments, the foaming liquid system 2 slug contains a temperature and salt resistant polymer at a concentration of 0.10 to 0.15 wt% and a foaming agent at a concentration of 1.00 wt%. In some embodiments, the temperature and salt tolerant polymer in the slug 2 of the foaming fluid system is a polyacrylamide compound, such as polyacrylamide; the foaming agent is a surfactant, such as sodium dodecylbenzenesulfonate, or a betaine containing a sulfo group. In some embodiments, the slug 2 of the foaming fluid system is an aqueous solution of polyacrylamide, sodium dodecylbenzenesulfonate, and water.
The strong blocking system is a high-temperature resistant gel slug. In some embodiments, the high temperature resistant gel plug contains a temperature resistant, salt tolerant polymer at a concentration of 0.50 wt% and a cross-linking agent at a concentration of 0.65 wt%. In some embodiments, the refractory gel plug is refractory: 75-130 ℃; high salt resistance: degree of mineralization of 0 to 24 x 104mg/L, calcium and magnesium ion content of 0-1.0 x 104mg/L; can be mixed with saline water to obtain a solution, and has a plugging rate>95 percent; the gelling time can reach dozens of hours; by adjusting the formula, the strength can be in D-H level. In some embodiments, the refractory gel segmentThe temperature-resistant and salt-resistant polymer in the plug is polyacrylamide compounds, such as polyacrylamide; the crosslinking agent is a phenolic compound, such as a phenolic resin. In some embodiments, the refractory gel plug is an aqueous solution of 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 agents. In some embodiments, the polymer solution slug contains a temperature and salt resistant 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 0 to 0.25 wt% aqueous polyacrylamide solution.
In some embodiments, the injection amount of the preposed protection liquid system is 30-40 m3(ii) a The injection amount of the first nitrogen slug is 20000-25000 sm3(ii) a The injection amount of the 1-section plug of the foaming liquid system is 200-250 m3(ii) a The injection amount of the second nitrogen slug is 40000-50000 sm3(ii) a The injection amount of the 2-section plug of the foaming liquid system is 50-60 m3(ii) a The injection amount of the high-temperature-resistant gel slug is 200-250 m3(ii) a The injection amount of the polymer solution slug is 20-30 m3(ii) a And/or the injection amount of the clear water slug is 5-15 m3。
The influence of the profile control and water shutoff action radius, the stratum water storage quantity and the multidirectional channeling-blocking water flooded area on the dosage demand of the plugging agent is comprehensively considered, and the dosage Q of the plugging agent based on the profile control and water shutoff action radius method explained by well testing can be adopted1Or plugging agent dosage Q based on water-flooding empirical method of stratum water storage quantity2。
(1) Well testing-based profile control and flooding radius method
Based on the action radius determined by well testing interpretation, the plugging radius is controlled to be 2/3 of the radius of the inner zone. Therefore, the dosage Q of the plugging agent is calculated by utilizing a profile control water plugging action radius method1The calculation formula is as follows:
Q1＝3.14β1β2β3r2h phi (equation 1)
Wherein Q is1The dosage of the plugging agent, m, is calculated by utilizing the provided profile control and water plugging action radius method3；β1A reference value of 0.45 is used as a plugging radius correction coefficient; beta is a beta2A reference value of 0.5 is used as a plugging thickness correction coefficient; beta is a3A reference value of 0.5 for a microscopic accessible pore volume fraction; r is profile control water plugging action radius m determined by well testing explanation; h is the plugging thickness, the water absorption thickness in the water absorption profile data is taken, and the effective thickness m is directly taken in a single layer; phi is porosity, decimal.
(2) Water drive empirical method based on stratum water storage quantity
Analyzing according to a plurality of oil field plugging adjusting cases, calculating the using amount Q of the plugging agent by using a water drive empirical method based on the stratum water storage amount in a well group range2The calculation formula is as follows:
Q2＝β(Wi-Wp) (formula 2)
Wherein Q is2The dosage of the plugging agent, m, is calculated by utilizing the provided water flooding empirical method3(ii) a Beta is a plugging dosage coefficient of 0.03-0.05; w is a group ofiTo accumulate the injected water amount, m3；WpTo accumulate water production, m3。
The invention realizes the binary composite water control of the high-temperature high-salinity bottom water reservoir 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 blocking system is temperature-resistant salt-tolerant nitrogen foam, and the strong blocking system is high-temperature-resistant gel. The nitrogen foam system has injection selectivity, large blocking and small blocking, water blocking and oil blocking, water-meeting stability and oil-meeting defoaming; the high-temperature resistant gel can effectively block a high-permeability layer, and can strengthen the foam blocking effect by starting a low-permeability layer, so that the high-efficiency chemical water blocking of the high-temperature high-salinity bottom water reservoir is realized. Compared with the prior art, the temperature-resistant and salt-tolerant nitrogen foam system is added in the conventional gel water plugging process, the weak plugging system is used for treating the section of the shaft, the pollution of the conventional technology to the non-channeling position is avoided, the technical application condition is expanded, the subsequent strong plugging system can enter the channeling position as much as possible, and the strong plugging body is improvedUtilization ratio of the system (gel). The binary composite water control process effectively reduces the consumption of a high-cost temperature-resistant salt-tolerant gel system and improves the economic benefit of water shutoff, and is more suitable for different bottom water invasion modes such as heel end water outflow and toe end water outflow, improves the gel utilization rate, obtains higher oil increasing effect, and solves the problem that the existing simple gel water shutoff technology is applied to a high-temperature high-salinity bottom water reservoir (the temperature is 75-130 ℃, and the mineralization degree is 0-21 multiplied by 10)4mg/L) is poor in economic adaptability and technical adaptability.
Drawings
In order to more clearly illustrate the technical solution of the present invention, the drawings of the specification are briefly introduced below, and it should be understood that the drawings described below are only 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 composite water control process for high temperature high salinity bottom water reservoirs according to the present invention.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, rather than all embodiments, and the scope of the present invention is not limited thereto.
Polyacrylamide: molecular formula [ CH2CH(CONH2)]n, Cas number 9003-05-8, and a temperature-resistant and salt-resistant polymer. Sodium dodecylbenzenesulfonate: molecular formula C18H29NaO3S, Cas number 25155-30-0 and an anionic surfactant. Phenolic resin: molecular formula (C)6H6O)n.(CH2O) n, Cas number 9003-35-4, crosslinker. The temperature-resistant salt-tolerant polymer is a polymer with stable property in a 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 conventional in the art; the reagents used, unless otherwise specified, are commercially available or may be formulated according to routine experimentation.
The preferred scheme of the binary composite water control process for the high-temperature high-salinity bottom water reservoir is shown in the table 1.
TABLE 1
sm3Refers to the volume of gas under control conditions (20 degrees celsius, 1 standard atmosphere); the concentration (wt%) of the agent refers to the mass percent concentration of the compound in the solution. The temperature-resistant and salt-resistant polymer is polyacrylamide (molecular weight 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-salinity bottom water reservoir, the well depth is 4726.59m, the oil layer temperature is 118.2 ℃, and the stratum mineralization degree is 21 multiplied by 104mg/L, calcium and magnesium ion concentration of 2.3X 104mg/L, 82% water content. The binary composite water control method is used for controlling the water of the oil well and 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 pre-protection solution system
Injecting 30m into oil well3The preposed protective solution. The front protection solution is 0.25% polyacrylamide (molecular weight is 300 ten thousand) aqueous solution.
Step S12, injecting a weak plug system
After the preposed protection liquid is injected, 20000sm is injected in sequence3First nitrogen slug, 200m3Foaming liquid system 1 slug, 40000sm3A second slug of nitrogen. The section 1 of the foaming liquid system is an aqueous solution formed by mixing a temperature-resistant salt-tolerant polymer, a foaming agent and water. The temperature-resistant salt-resistant polymer is polyacrylamide (with the molecular weight of 300 ten thousand), and the mass fraction is 0.5%; the foaming agent is sodium dodecyl benzene sulfonate with the mass fraction of 1%.
Step S13, injection transition system
After the injection of the weakly plugging system was completed, 50m was injected3Foaming liquid system 2 slug. The section 2 of the foaming liquid system is an aqueous solution formed by mixing a temperature-resistant salt-tolerant polymer, a foaming agent and water. The temperature-resistant salt-tolerant 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 with the mass fraction of 1%.
Step S14, injecting a strong blocking system
After the injection of the transition system is completed, 250m of injection is carried out3High temperature resistant gel slugs. The high-temperature resistant gel slug is an aqueous solution formed by mixing a temperature-resistant salt-tolerant polymer, a cross-linking agent and water. The temperature-resistant salt-resistant polymer is polyacrylamide (with the molecular weight of 300 ten thousand), and the mass fraction is 0.5%; the cross-linking agent is phenolic resin with the mass fraction of 0.65%.
Step S15, injection substitution system
After the injection of the strong plugging system is completed, sequentially injecting 20m3And 15m of the polymer solution3The clear water of (1). The polymer solution is 0-0.25% by mass of polyacrylamide (300 ten thousand molecular weight) aqueous solution.
After the oil well is used for controlling water by the binary composite water control process, the effective period reaches 65 days, and the accumulated oil increment reaches 883m3。
Example 2
The oil well of the embodiment belongs to a high-temperature high-salinity bottom water reservoir, the well depth is 5124.31m, the oil layer temperature is 122 ℃, and the formation mineralization is 21 multiplied by 104mg/L, calcium and magnesium ion concentration of 1.8X 104mg/L, 92% water content. The binary composite water control method is used for controlling the water of the oil well and 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 pre-protection solution system
Injecting 40m into oil well3The preposed protective solution. The preposed protection solution is a polyacrylamide (molecular weight 300 ten thousand) aqueous solution with the mass fraction of 0.25%.
Step S12, injecting a weak plug system
After the preposed protective solution is injected, 25000sm is injected in sequence3First nitrogen slug, 250m3Foaming liquid system 1 slug, 50000sm3A second slug of nitrogen. The section 1 of the foaming liquid system is an aqueous solution formed by mixing a temperature-resistant salt-tolerant polymer, a foaming agent and water. The temperature-resistant salt-resistant polymer is polyacrylamide (with the molecular weight of 300 ten thousand), and the mass fraction is 0.5%; the foaming agent is sodium dodecyl benzene sulfonate with the mass fraction of 1%.
Step S13, injection transition system
After the injection of the weakly plugging system is completed, 60m is injected3Foaming liquid system 2 slug. The section 2 of the foaming liquid system is an aqueous solution formed by mixing a temperature-resistant salt-tolerant polymer, a foaming agent and water. The temperature-resistant salt-tolerant 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 with the mass fraction of 1%.
Step S14, injecting a strong blocking system
After the injection of the transition system is finished, injecting 200m3High temperature resistant gel slugs. The high-temperature resistant gel slug is an aqueous solution formed by mixing a temperature-resistant salt-tolerant polymer, a cross-linking agent and water. The temperature-resistant salt-resistant polymer is polyacrylamide (with the molecular weight of 300 ten thousand), and the mass fraction is 0.5%; the cross-linking agent is phenolic resin, and the mass fraction of the cross-linking agent is 0.65%.
Step S15, injection substitution system
After the injection of the strong plugging system is completed, 30m of strong plugging system is injected into the strong plugging system in sequence3And 10m of the polymer solution3The clear water of (1). The polymer solution is a polyacrylamide (molecular weight 300 ten thousand) aqueous solution with the mass fraction of 0-0.25%.
After the oil well uses the binary composite water control process of the embodiment to control water, the effective period is 240 days, and the accumulated oil increment reaches 669m3。
Example 3
The oil well of the embodiment belongs to a high-temperature high-salinity bottom water reservoir, the well depth is 4531.24m, the oil layer temperature is 113.3 ℃, and the stratum mineralization degree is 20 multiplied by 104mg/L, calcium and magnesium ion concentration of 2.1 × 104mg/L, water content 78%.The binary composite water control method is used for controlling the water of the oil well and 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 pre-protection solution system
Injecting 35m into oil well3The preposed protective solution. The preposed protection solution is 0.25% polyacrylamide (molecular weight 300 ten thousand) aqueous solution.
Step S12, injecting a weak plug system
After the preposed protective liquid is injected, 22000sm is injected in sequence3First nitrogen slug, 220m3Foaming liquid system 1 slug, 45000sm3A second slug of nitrogen. The section 1 of the foaming liquid system is an aqueous solution formed by mixing a temperature-resistant salt-tolerant polymer, a foaming agent and water. The temperature-resistant 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 with the mass fraction of 1%.
Step S13, injection transition system
After the injection of the weakly plugging system was completed, 55m was injected3Foaming liquid system 2 slug. The section 2 of the foaming liquid system is an aqueous solution formed by mixing a temperature-resistant salt-tolerant polymer, a foaming agent and water. The temperature-resistant salt-tolerant 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 with the mass fraction of 1%.
Step S14, injecting a strong blocking system
After the injection of the transition system is completed, 230m is injected3High temperature resistant gel slugs. The high-temperature resistant gel slug is an aqueous solution formed by mixing a temperature-resistant salt-tolerant polymer, a cross-linking agent and water. The temperature-resistant salt-resistant polymer is polyacrylamide (with the molecular weight of 300 ten thousand), and the mass fraction is 0.5%; the cross-linking agent is phenolic resin, and the mass fraction of the cross-linking agent is 0.65%.
Step S15, injection substitution system
After the injection of the strong plugging system is completed, 25m of strong plugging system is injected in sequence3And 5m of the polymer solution3The clear water of (1). The polymer solution is0-025% by mass of polyacrylamide (molecular weight 300 ten thousand) aqueous solution.
After the oil well uses the binary composite water control process of the embodiment to control water, the effective period is 352 days, and the accumulated oil increment reaches 10176m3。
The above-mentioned embodiments are intended to illustrate the objects, technical solutions and advantages of the present invention in further detail, and it should be understood that the above-mentioned embodiments are only examples of the present invention, and are not intended to limit the scope of the present invention, and any modifications, equivalents, improvements and the like made within the spirit and principle of the present invention should be included in the scope of the present invention.
Claims (10)
1. A binary composite water control process for a high-temperature high-salinity 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 foaming liquid system 1 slug and a second nitrogen slug according to the injection sequence; the transition system is a foaming 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.
2. The binary composite water control process for a high-temperature high-salinity bottom water reservoir according to claim 1, characterized in that: the preposed protection liquid system contains a temperature-resistant salt-tolerant polymer with the concentration of 0.25 wt%.
3. The binary composite water control process for a high-temperature high-salinity bottom water reservoir according to claim 1, characterized in that: the slug 1 of the foaming liquid system contains a temperature-resistant salt-tolerant polymer with the concentration of 0.50 wt% and a foaming agent with the concentration of 1.00 wt%.
4. The binary composite water control process for a high-temperature high-salinity bottom water reservoir according to claim 1, characterized in that: the 2-segment plug of the foaming liquid system contains a temperature-resistant salt-tolerant polymer with the concentration of 0.10-0.15 wt% and a foaming agent with the concentration of 1.00 wt%.
5. The binary composite water control process for a high-temperature high-salinity bottom water reservoir according to claim 1, characterized in that: the high-temperature resistant gel slug contains a temperature-resistant salt-tolerant polymer with the concentration of 0.50 wt% and a cross-linking agent with the concentration of 0.65 wt%.
6. The binary composite water control process for high-temperature high-salinity bottom water reservoirs according to claim 1, characterized in that: the polymer solution slug contains a temperature-resistant salt-tolerant polymer with the concentration of 0-0.25 wt%.
7. The binary composite water control process for high-temperature high-salinity bottom water reservoirs according to any one of claims 2 to 6, characterized in that: the temperature-resistant salt-tolerant polymer is polyacrylamide.
8. The binary composite water control process for high-temperature high-salinity bottom water reservoirs according to claim 3 or 4, characterized in that: the foaming agent is sodium dodecyl benzene sulfonate.
9. The binary composite water control process for a high-temperature high-salinity bottom water reservoir according to claim 5, characterized in that: the cross-linking agent is phenolic resin.
10. The binary composite water control process for high-temperature high-salinity bottom water reservoirs according to any one of claims 1 to 9, characterized in that:
the injection amount of the front protection liquid system is 30-40 m3；
The injection amount of the first nitrogen slug is 20000-25000 sm3；
The injection amount of the 1-section plug of the foaming liquid system is 200-250 m3；
The injection amount of the second nitrogen slug is 40000-50000 sm3；
The above-mentionedThe injection amount of the 2-section plug of the foaming liquid system is 50-60 m3；
The injection amount of the high-temperature-resistant gel slug is 200-250 m3；
The injection amount of the polymer solution slug is 20-30 m3；
And/or the injection amount of the clear water slug is 5-15 m3。
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| CN115059430A (en) * | 2022-07-08 | 2022-09-16 | 中海石油(中国)有限公司 | Selective cone pressing water plugging method for bottom water reservoir oil well |
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