CN110317598B - Enhancement of compact reservoir CO2Flooding effect aqueous solution and preparation method and application method thereof - Google Patents
Enhancement of compact reservoir CO2Flooding effect aqueous solution and preparation method and application method thereof Download PDFInfo
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- CN110317598B CN110317598B CN201810291614.8A CN201810291614A CN110317598B CN 110317598 B CN110317598 B CN 110317598B CN 201810291614 A CN201810291614 A CN 201810291614A CN 110317598 B CN110317598 B CN 110317598B
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/594—Compositions used in combination with injected gas, e.g. CO2 orcarbonated gas
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- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/164—Injecting CO2 or carbonated water
Abstract
The invention discloses an aqueous solution for improving CO2 flooding effect of a compact reservoir and a preparation method and an application method thereof; the aqueous solution comprises, based on the total weight of the aqueous solution: 0.01-0.2wt% of wettability modifier, 0.01-0.1 wt% of penetrant, 0.05-0.5 wt% of surfactant for reducing oil-water interfacial tension and the balance of water. The technical scheme of the invention is to improve the CO content of the compact reservoir by using the surfactant which consists of a wettability modifier, a penetrating agent and a surfactant and reduces the oil-water interfacial tension2Flooding of aqueous solutions with CO2Alternately injecting into oil reservoir, changing the wettability of matrix micropore surface with wettability changing agent, permeating surfactant molecule capable of reducing oil-water interfacial tension into matrix micropore under the promotion of penetrant, driving crude oil out of micropore by imbibition and other action, reaching crack in CO2The displacement of the oil displacement agent achieves the effect of improving the recovery ratio of crude oil.
Description
Technical Field
The invention belongs to the technical field of oilfield development, and particularly relates to a method for improving CO content in a compact reservoir2An aqueous solution with repellent effect, a preparation method and an application method thereof.
Background
At present, foreign CO2The technology for increasing the recovery ratio of crude oil by oil displacement is mature and widely applied, but CO is2Has a low viscosity, and the displacement front is sensitive to viscous fingering which causes injected CO2By-passing the displaced oil, the by-passing reducing CO2The on-site manifestation of the sweep efficiency of the oil well is that the phenomena of liquid production reduction, gas-oil ratio sharp rise and the like caused by premature gas channeling of some oil wells cause CO2The utilization rate decreases and the operation cost increases.
Foreign targeting at CO2The gas outburst in the flooding process is studied in great quantity along the cracks and is applied to mines. The main techniques are the water alternating injection (WAG) method, the gel method, the foam method, etc., and are applied on site. The alternate injection of water and gas, although effective in inhibiting or slowing gas channeling, causes the injected water to also intrude along the fracture due to the large difference in permeability between the matrix and the fracture. The gel can effectively inhibit CO2Gas channeling, but the use of gel is limited by conditions such as reservoir temperature, degree of mineralization and the like, and gas channels are also easily blocked. Foam is foreign CO2The number of applications in the flooding process is large, most of which succeed and some of which fail, mainly due to the reduced effect on the crack foam with larger dimensions. To CO at home and abroad2Foam foamers have been extensively studied and practiced, particularly in the United states and Canada, as lignosulfonates described by USP4086964, alpha-olefin sulfonates described by USP4393937, fatty alcohol polyoxyethylene sulfates described by USP4113011, Lathanol LAL70 from Stepan Chemical Co., Chevrn, CD1045 from Chevrn, and the like. Chengechen et al, in CN101089117, disclose a foaming agent consisting of sodium dodecylbenzenesulfonate, modified guanidine gum and water for adjusting the gas suction profile of a carbon dioxide gas well. CN103721625A describes a water-based water-soluble macromolecular surfactant as a foam stabilizer. CN105238380A discloses a novel inorganic fine particle reinforced foam system for oil and gas fields, which comprises 0.2-0.8 wt% of foaming agent, 0.5-2.0 wt% of novel inorganic fine particles and the balance of water; the novel inorganic fine particles are fine particles with the particle size less than or equal to 2.5 mu m which are captured and screened in the atmosphere. CN104140802A discloses a foam scrubbing agent for gas recovery from gas well drainage, which is prepared from gemini surfactant (quaternary ammonium salt gemini surfactant) and zwitterionic surfactant (coconut)Oleoyl amine propyl betaine or lauroyl amine propyl betaine), a high-bond energy surfactant (fluorocarbon surfactant) and a high-molecular polymer (polyacrylamide). CN85102151 describes a carbon dioxide based fluid fracturing fluid for fracturing, wherein the foaming agent is at least one of betaine, sulfated alkoxide, ethoxylated linear alcohol, alkyl quaternary ammonium, alkyl diethanol amine, and alkylamine oxide. CN103980873 discloses a three-phase foam complex oil displacement system, wherein the foaming agent is one or a combination of tetradecyl hydroxysulfobetaine and cocamidopropyl betaine, and the foam stabilizing system is a complex system of polymer and jelly dispersoid. CN105038756 discloses a carbon dioxide foam system added with hydrophilic nanoparticles for oil displacement, which mainly comprises lauryl polyoxyethylene polyoxypropylene ether, hydrophilic silica nanoparticles and sodium chloride. CN1890346 discloses a carbon dioxide foam fluid for acidification, acid fracturing, gravel packing, diversion and cleaning, and its foaming agent is betaine amphoteric surfactant, dodecyl dimethyl benzyl ammonium chloride, etc. CN101619210 discloses a carbon dioxide foam stabilizer suitable for low permeability oil reservoirs, which consists of modified guar gum, hydroxyethyl cellulose and dodecanol. CN103275693 discloses an acidic CO2The efficient foaming agent for the foam fracturing system consists of alkyl dimethyl betaine, alkyl sulfobetaine, hexadecyl hydroxypropyl sulfobetaine and dodecyl alcohol ether glucoside, wherein the carbon chain of the efficient foaming agent is 16-18. CN103881683 discloses a method for treating CO2A foaming agent for blocking gas channeling in oil displacement is composed of a carboxylic acid type imidazoline amphoteric surfactant, alpha-olefin sulfonate, dodecyl dimethyl betaine and alkylolamide. CN104293334x discloses a soluble in CO2The foaming agent consists of alkylphenol polyoxyethylene and ethanol, amyl alcohol and fluoropentyl alcohol as solubilizer. CN104498016A discloses a foaming agent for carbon dioxide flooding and a preparation method thereof, wherein the foaming agent comprises N-dodecyl sodium amino carboxylate and gemini sodium dodecyl carboxylate, and the foam stabilizer is one or a mixture of polyethylene glycol 6000 with molecular weight of 200-. CN102746841B discloses a surface activity based on nano particles and GeminiA stable foam system of the sex agent.
At the same time, the method of amine salt, underground polymerization, alcohol salt precipitation and CO are carried out abroad2Thickening and other channeling sealing methods, and the technologies only stay in the indoor experimental research stage and are hardly applied on site.
The above techniques are mainly directed to low-permeability, medium-high permeability reservoirs, while for tight reservoirs, CO2The gas cannot enter the micropores of the matrix, crude oil in the matrix cannot be driven out, and the gas drive effect cannot be improved by plugging the crack only.
Disclosure of Invention
The invention aims to solve the problem of CO in a compact oil reservoir2The gas cannot enter the micropores of the matrix, crude oil in the matrix cannot be driven out, and the gas drive effect cannot be improved by plugging cracks only; provides a method for improving CO of a compact reservoir2And (4) displacing the effective water solution, thereby realizing the improvement of the oil reservoir recovery ratio.
In order to achieve the above object, a first aspect of the present invention provides a method for enhancing compact reservoir CO2An aqueous repellent solution comprising, based on the total weight of the aqueous solution: 0.01-0.2wt% of wettability modifier, 0.01-0.1 wt% of penetrant, 0.05-0.5 wt% of surfactant for reducing oil-water interfacial tension and the balance of water.
Preferably, the aqueous solution comprises, based on the total weight of the aqueous solution: 0.02-0.1wt% of wettability modifier, 0.02-0.08 wt% of penetrant, 0.1-0.4 wt% of surfactant for reducing oil-water interfacial tension, and the balance of water.
Preferably, the wettability modifier is selected from at least one of sodium fatty alcohol-polyoxyethylene ether sulfate, sodium alpha-alkenyl sulfonate, disodium lauryl sulfosuccinate monoester, and coconut oil diethanolamide.
Preferably, the wettability modifier is disodium lauryl sulfosuccinate.
Preferably, the penetrating agent is isooctanol polyoxyethylene ether phosphate and/or octyl-quininol polyoxyethylene ether phosphate.
Preferably, the surfactant for reducing oil-water interfacial tension comprises: cocamidopropyl hydroxysultaine and/or lauramidopropyl hydroxysultaine.
Preferably, the water is formation water, tap water, surface water or reservoir reinjection water; preferably reservoir reinjection water.
In a second aspect of the invention, there is provided a method of enhancing tight reservoir CO as described above2A method of preparing an aqueous repellent solution, the method comprising: uniformly mixing water, a wettability modifier, a penetrating agent and a surfactant for reducing the oil-water interfacial tension to obtain the compact reservoir CO2An aqueous repellent solution.
In a third aspect of the invention, there is provided a method of enhancing tight reservoir CO as described above2A method of using an aqueous repellent solution, the method comprising: will increase the compact reservoir CO2Flooding of aqueous solutions with CO2Alternately injecting gas into the oil reservoir;
preferably, the injection enhances tight reservoir CO2Closing the well after flooding effect water solution, and injecting CO after 10-72h2A gas.
The technical scheme of the invention is to improve the CO content of the compact reservoir by using the surfactant which consists of a wettability modifier, a penetrating agent and a surfactant and reduces the oil-water interfacial tension2Flooding of aqueous solutions with CO2Alternately injecting into oil reservoir, changing the wettability of matrix micropore surface with wettability changing agent, permeating surfactant molecule capable of reducing oil-water interfacial tension into matrix micropore under the promotion of penetrant, driving crude oil out of micropore by imbibition and other action, reaching crack in CO2The displacement of the oil displacement agent achieves the effect of improving the recovery ratio of crude oil.
Additional features and advantages of the invention will be set forth in the detailed description which follows.
Drawings
The above and other objects, features and advantages of the present invention will become more apparent by describing in more detail exemplary embodiments thereof with reference to the attached drawings, in which like reference numerals generally represent like parts throughout.
Figure 1 shows a recovery plot for each phase of the displacement process for a test example of the present invention.
Detailed Description
Preferred embodiments of the present invention will be described in more detail below. While the following describes preferred embodiments of the present invention, it should be understood that the present invention may be embodied in various forms and should not be limited by the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the invention to those skilled in the art.
In a first aspect of the invention, a method for enhancing tight reservoir CO is provided2An aqueous repellent solution comprising, based on the total weight of the aqueous solution: 0.01-0.2wt% of wettability modifier, 0.01-0.1 wt% of penetrant, 0.05-0.5 wt% of surfactant for reducing oil-water interfacial tension and the balance of water.
According to the present invention, preferably, the aqueous solution comprises, based on the total weight of the aqueous solution: 0.02-0.1wt% of wettability modifier, 0.02-0.08 wt% of penetrant, 0.1-0.4 wt% of surfactant for reducing oil-water interfacial tension, and the balance of water.
The invention is mainly directed to the implementation of CO2Flooding tight reservoirs of the type which have multiple fracturing operations or primary microfracture development, injecting CO2When the gas is flowing along the crack, the wave and difference to the matrix are caused, and the original matrix is saturated with oil, water and CO2Is not easy to enter and can not realize effective displacement.
CO injection2In the displacement process, the CO for improving the compact reservoir is alternately injected2A flood-effect aqueous solution capable of altering wettability, reducing capillary forces; the invention improves the CO of the compact reservoir2When the water solution with the flooding effect flows in the crack, surfactant molecules are diffused into micropores of the compact substrate to change the wettability of the micropores and reduce the capillary resistance of the liquid flowing out of the micropores, so that oil and water in the water solution are in CO2The crack is easy to flow out under the action of driving pressure, thereby improving CO2And (4) driving effect.
According to the present invention, preferably, the wettability modifier is selected from at least one of sodium fatty alcohol polyoxyethylene ether sulfate (AES), sodium alpha-alkenyl sulfonate (AOS), disodium lauryl sulfosuccinate monoester, and coconut oil diethanolamide.
According to the present invention, preferably, the wettability modifier is disodium lauryl sulfosuccinate.
According to the present invention, preferably, the osmotic agent is isooctanol polyoxyethylene ether phosphate and/or octyl-quinitol polyoxyethylene ether phosphate.
According to the present invention, preferably, the surfactant for reducing oil-water interfacial tension comprises: cocamidopropyl hydroxysultaine and/or lauramidopropyl hydroxysultaine.
According to the invention, preferably the water is formation water, tap water, surface water or reservoir reinjection water; preferably reservoir reinjection water.
In a second aspect of the invention, there is provided a method of enhancing tight reservoir CO as described above2A method of preparing an aqueous repellent solution, the method comprising: uniformly mixing water, a wettability modifier, a penetrating agent and a surfactant for reducing the oil-water interfacial tension to obtain the compact reservoir CO2An aqueous repellent solution.
As a preferred scheme, sequentially adding water, a wettability modifier, a penetrating agent and a surfactant for reducing the oil-water interfacial tension, fully stirring after adding each chemical agent, adding the next chemical agent after the added chemical agents are completely dissolved, and finally forming a uniform and transparent aqueous solution until all the components are added, namely the uniform and transparent aqueous solution for improving the CO content of the compact reservoir2An aqueous repellent solution.
As a preferred scheme, the method for improving compact reservoir CO provided by the invention is prepared2The individual components of the repellent aqueous solution are commercially available.
In a third aspect of the invention, there is provided a method of enhancing tight reservoir CO as described above2A method of using an aqueous repellent solution, the method comprising: will increase the compact reservoir CO2Flooding of aqueous solutions with CO2Alternately injecting gas into the oil reservoir;
according to the invention, preferably, the injection enhances tight reservoir CO2Closing the well after flooding effect water solution, and injecting CO after 10-72h2A gas.
After the water solution of the invention is injected, the well is closed for a period of time, and then CO is injected2Gas, contributing to CO increase2The flooding effect, and further the crude oil recovery rate is improved.
The invention is further illustrated by the following examples:
example 1
This example provides a method for enhancing tight reservoir CO2An aqueous repellent solution comprising, based on the total weight of the aqueous solution: 0.1wt% of wettability modifier, 0.03 wt% of penetrant, 0.4 wt% of surfactant for reducing oil-water interfacial tension, and the balance of water; the wettability modifier is disodium lauryl sulfosuccinate, the penetrant is isooctanol polyoxyethylene ether phosphate, the surfactant for reducing the oil-water interfacial tension is cocamidopropyl hydroxysultaine and lauramidopropyl hydroxysultaine, the mass ratio of the cocamidopropyl hydroxysultaine to the lauramidopropyl hydroxysultaine is 1:1, the water is oil reservoir reinjection water, and the mineralization degree is 14000 mg/L.
The preparation method comprises the following steps: adding water, a wettability modifier, a penetrating agent and a surfactant for reducing the oil-water interfacial tension into a stirring container in sequence, fully stirring after adding one chemical agent, adding the next chemical agent after the added chemical agent is completely dissolved, and finally forming a uniform and transparent aqueous solution until all the components are added, namely the CO in the compact reservoir is improved2An aqueous repellent solution.
Example 2
This example provides a method for enhancing tight reservoir CO2An aqueous repellent solution comprising, based on the total weight of the aqueous solution: 0.03 wt% of wettability modifier, 0.07 wt% of penetrant, 0.15 wt% of surfactant for reducing oil-water interfacial tension, and the balance of water; wherein the wettability modifier is disodium lauryl sulfosuccinate monoester, the penetrant is octyl quininol polyoxyethylene ether phosphate, and the surfactant for reducing the oil-water interfacial tension is cocamidopropyl hydroxysulfobetaineAnd alkali, wherein the water is reservoir reinjection water, and the mineralization degree is 14000 mg/L.
The preparation method is the same as example 1.
Example 3
This example provides a method for enhancing tight reservoir CO2An aqueous repellent solution comprising, based on the total weight of the aqueous solution: 0.06 wt% of wettability modifier, 0.04 wt% of penetrant, 0.25 wt% of surfactant for reducing oil-water interfacial tension, and the balance of water; the wettability modifier is disodium lauryl sulfosuccinate, the penetrant is isooctanol polyoxyethylene ether phosphate and capryl-quinol polyoxyethylene ether phosphate, the mass ratio of the isooctanol polyoxyethylene ether phosphate to the capryl-quinol polyoxyethylene ether phosphate is 1:1, the surfactant for reducing the oil-water interfacial tension is lauramidopropyl hydroxysulfobetaine, the water is oil reservoir reinjection water, and the mineralization degree is 14000 mg/L.
The preparation method is the same as example 1.
Example 4
The difference between this example and example 1 is that the wettability modifier is sodium fatty alcohol-polyoxyethylene ether sulfate, and the other components, the amounts and the preparation methods are the same as those in example 1.
Example 5
The difference between the present example and example 1 is that the wettability modifier is 0.18 wt%, the penetrant is 0.02 wt%, the surfactant for reducing the oil-water interfacial tension is 0.48 wt%, and the other components and the amounts and the preparation method are the same as those of example 1.
Test example
Enhancement of tight reservoir CO Using the preparations of examples 1-52Carrying out an oil displacement experiment on the water solution with the oil displacement effect, measuring the recovery ratio of crude oil, wherein the temperature of the oil displacement experiment is 70 ℃, and the specific experimental process is as follows:
saturated oil is poured into a model used in the experiment, the saturated oil is crude oil of northeast division, and the back pressure is 6MPa at the temperature of 60 ℃;
firstly, performing water flooding on a rock model until the water content is more than 98%; then CO is carried out2Driven to an oil-free streamDischarging; the water solution of the example is injected again at 0.8PV, so that the two ends of the model are sealed, and the well is sealed for 18 hours; finally, CO is injected again2To carry out CO2And (5) driving.
The experimental results are as follows: the displacement pressure difference is higher in the water flooding process and is reduced to be stable in the later period, because the oil saturation is continuously reduced after the crude oil is started, and the later period is basically unchanged;
as shown in FIG. 1, the water flooding recovery rate reaches 48.0% from the recovery rate, and then CO is injected2The effect is very small, the recovery rate is only 1.8%, and then the CO of the compact reservoir is improved by injecting the liquid of example 12A trace amount of crude oil flows out in the process of the water solution with the flooding effect, and the recovery ratio in the process is 0.71 percent; after the injection of the aqueous solution of example 1, CO was again injected2The recovery of this process was 4.61%. By two CO passes2The change of the recovery ratio of the crude oil is removed, and the CO in the compact reservoir is improved2The water solution with the flooding effect is realized in CO2The displacement of the oil displacement agent achieves the effect of improving the recovery ratio of crude oil.
TABLE 1
As shown in Table 1, the recovery ratio of water flooding reaches 47.1 to 48.5% in terms of recovery ratio, and then CO is injected2The effect is very small, the recovery rate is only 1.75-1.96%, and then the CO of the tight reservoir is improved by injecting the embodiment2Trace crude oil flows out in the process of the water solution with the flooding effect, and the recovery ratio in the process is 0.69-0.78%; after the aqueous solution injection of the examples, CO was again injected2The recovery ratio of the process is 3.85-4.61%. By two CO passes2The change of the recovery ratio of the crude oil is removed, and the CO in the compact reservoir is improved2The water solution with the flooding effect is realized in CO2The displacement of the oil displacement agent achieves the effect of improving the recovery ratio of crude oil; after simultaneous injection from the aqueous solution of each example, CO was again injected2The comparison of the recovery ratio values in this process shows that the aqueous solutions of examples 1-3 are better than those of examples 4-5 in increasing the recovery ratio of crude oil.
Having described embodiments of the present invention, the foregoing description is intended to be exemplary, not exhaustive, and not limited to the embodiments disclosed. Many modifications and variations will be apparent to those of ordinary skill in the art without departing from the scope and spirit of the described embodiments.
Claims (7)
1. CO improving compact reservoir2An aqueous flooding solution characterized in that it comprises, based on the total weight of the aqueous solution: 0.01-0.2wt% of wettability modifier, 0.01-0.1 wt% of penetrant, 0.05-0.5 wt% of surfactant for reducing oil-water interfacial tension, and the balance of water;
the wettability modifier is disodium lauryl sulfosuccinate monoester;
the surfactant for reducing the oil-water interfacial tension comprises: cocamidopropyl hydroxysultaine and/or lauramidopropyl hydroxysultaine;
the penetrating agent is isooctanol polyoxyethylene ether phosphate and/or octyl-quinitol polyoxyethylene ether phosphate.
2. Tight reservoir CO enhancement according to claim 12An aqueous efficiency-driving solution, wherein the aqueous solution comprises, based on the total weight of the aqueous solution: 0.02-0.1wt% of wettability modifier, 0.02-0.08 wt% of penetrant, 0.1-0.4 wt% of surfactant for reducing oil-water interfacial tension, and the balance of water.
3. Tight reservoir CO enhancement according to claim 1 or 22An effective flooding aqueous solution, wherein the water is formation water, tap water, surface water, or reservoir reinjection water.
4. Tight reservoir CO enhancement according to claim 32An effective flooding aqueous solution, wherein the water is reservoir reinjection water.
5. Enhancement of tight reservoir CO according to any of claims 1 to 42Driving effectThe method for producing an aqueous solution of (1), comprising: uniformly mixing water, a wettability modifier, a penetrating agent and a surfactant for reducing the oil-water interfacial tension to obtain the compact reservoir CO2An aqueous repellent solution.
6. Enhancement of tight reservoir CO according to any of claims 1 to 42A method of applying an aqueous repellent solution, the method comprising: will increase the compact reservoir CO2Flooding of aqueous solutions with CO2Gas is alternately injected into the reservoir.
7. The method of use of claim 6, wherein injecting enhanced tight reservoir CO2Closing the well after flooding effect water solution, and injecting CO after 10-72h2A gas.
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| CN115711110A (en) * | 2022-10-27 | 2023-02-24 | 新疆敦华绿碳技术股份有限公司 | CO increase in tight reservoirs 2 Miscible-phase flooding recovery method |
| CN116496770B (en) * | 2023-03-09 | 2024-04-23 | 中国石油大学(北京) | Thickened supercritical CO for displacing crude oil2Composition and method for displacing crude oil |
| CN116285935B (en) * | 2023-05-11 | 2023-12-01 | 广州芯联化工产品有限公司 | Foam stabilizing surfactant and preparation method thereof |
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