WO2025007953A1 - 中相微乳液及其驱油方法和应用 - Google Patents

中相微乳液及其驱油方法和应用 Download PDF

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WO2025007953A1
WO2025007953A1 PCT/CN2024/103841 CN2024103841W WO2025007953A1 WO 2025007953 A1 WO2025007953 A1 WO 2025007953A1 CN 2024103841 W CN2024103841 W CN 2024103841W WO 2025007953 A1 WO2025007953 A1 WO 2025007953A1
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oil displacement
polymer
phase microemulsion
flooding system
oil
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French (fr)
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关丹
邵洪志
栾和鑫
阙庭丽
唐文洁
云庆庆
麦麦提·帕提古丽
徐崇军
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Petrochina Co Ltd
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    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
    • C09K8/584—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
    • 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
    • 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
    • C09K8/588—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
    • 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
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons

Definitions

  • the invention relates to the field of tertiary oil recovery in oil fields, and in particular to a medium-phase microemulsion and an oil recovery method and application thereof.
  • the distribution range of pore throat size in conglomerate reservoirs is wide, mainly with filling-type complex mode and bimodal characteristics. There are significant differences in the pore structure mode and throat radius distribution characteristics of different lithologies. The complex lithology and pore structure lead to strong spatial heterogeneity of conglomerate reservoir properties, with great differences in plane, interlayer and intralayer. In addition, after years of water injection development, sandstone reservoirs have become more complex in reservoir structure and oil-water distribution, with large differences in plane and vertical heterogeneity.
  • fire drive and natural gas gravity miscible drive can increase the recovery rate by more than 35%, meeting the technical requirements for significantly increasing the recovery rate (more than 25%), but the technical application conditions are harsh.
  • the technologies currently applied and promoted in major oil fields are polymer drive technology, binary composite drive technology and ternary composite drive technology. All three technologies cannot meet the technical requirements for significantly increasing the recovery rate.
  • Medium-phase microemulsion drive is a technology similar to miscible drive that significantly increases the recovery rate. It has the characteristic of significantly reducing the residual oil saturation and is one of the most effective ways to achieve a significant increase in recovery. The total oil recovery efficiency can reach more than 90%.
  • the medium-phase microemulsion flooding is to displace the crude oil in the formation by in-situ formation of Winsor III microemulsion in the reservoir.
  • Winsor III microemulsion solubilizes oil and water at the same time, and the interfacial tension with oil and water is extremely low. There is almost no capillary force in the displacement process, and it has a strong solubilization ability for the remaining oil along the way, and the microscopic sweep efficiency and oil displacement efficiency are greatly improved.
  • the formation of the medium-phase microemulsion is closely related to the structure of the surfactant.
  • Conventional surfactants can also form a stable intermediate phase under the action of alcohol and salt, and the required concentration is usually above 1%.
  • the first petroleum sulfonate (YM-3A) suitable for the L layer performance of Laojunmiao Oilfield was developed in China, and the oil displacement system formula 4401 (4.0% YM-3A, 4.0% n-butanol, 0.1% BPA) was screened out. After testing, it was found that its performance was excellent and reached the level of similar foreign research, but the dosage was large, which affected the economic benefits. Therefore, it is urgent to explore the system and method to significantly improve the recovery rate in the later stage of water injection development of sandstone conglomerate reservoirs.
  • the purpose of the present invention is to overcome the problem of low recovery rate in the later stage of water injection development of sandstone conglomerate reservoirs in the prior art, and to provide a middle phase microemulsion and its oil recovery method and application.
  • the oil recovery method containing the middle phase microemulsion can greatly improve the sweep efficiency and oil recovery efficiency.
  • the first aspect of the present invention provides a middle phase microemulsion, which comprises, by weight, 4-8 parts of alkyl alcohol amide, 1-5 parts of alkyl polyoxypropylene ether sulfate and 1-4.5 parts of alkylphenol polyoxyethylene ether sulfate.
  • the second aspect of the present invention provides the use of the aforementioned middle phase microemulsion in oil displacement.
  • a third aspect of the present invention provides an oil recovery method, comprising:
  • a fourth aspect of the present invention provides the use of the aforementioned middle phase microemulsion or the aforementioned oil recovery method in a conglomerate reservoir.
  • the middle phase microemulsion of the present invention comprises: at least one nonionic surfactant (alkyl alcohol amide) and at least two anionic surfactants (alkyl polyoxypropylene ether sulfate and alkylphenol polyoxyethylene ether sulfate).
  • alkyl alcohol amide alkyl alcohol amide
  • anionic surfactants alkyl polyoxypropylene ether sulfate and alkylphenol polyoxyethylene ether sulfate
  • the present invention adopts a medium-phase microemulsion flooding system for oil displacement, and improves the displacement effect by combining different slugs during the oil displacement process, including adding PPG to the front slug to adjust the profile, adding nitrogen foam flooding to further adjust the reservoir heterogeneity, and adding a protective slug to further highlight the displacement effect, which can greatly improve the sweep efficiency and oil displacement efficiency, and shows great application potential in the field of enhanced oil recovery.
  • FIG1 is a schematic diagram of the structure of a microemulsion state observation device.
  • the first aspect of the present invention provides a middle phase microemulsion, which comprises, by weight, 4-8 parts of alkyl alcohol amide, 1-5 parts of alkyl polyoxypropylene ether sulfate and 1-4.5 parts of alkylphenol polyoxyethylene ether sulfate.
  • alkyl alcohol amide is a nonionic surfactant
  • alkyl polyoxypropylene ether sulfate and alkylphenol polyoxyethylene ether sulfate are anionic surfactants.
  • the present invention can adjust the HLB to about 10 by compounding these three substances, and at the same time can make the system stacking parameter reach about 1, making it easier to form a middle phase system.
  • the middle phase microemulsion comprises, by weight, 5-7 parts of alkyl alcohol amide, 2-4 parts of alkyl polyoxypropylene ether sulfate and 2-4 parts of alkylphenol polyoxyethylene ether sulfate.
  • R 1 is preferably decyl, dodecyl, tetradecyl, hexadecyl, octadecyl or eicosyl.
  • the alkyl alcohol amide is selected from one or more of dodecyl diethanolamide, coconut oil alkyl alcohol amide phosphate and coconut oil fatty acid diethanolamide, preferably dodecyl diethanolamide.
  • the alkyl polyoxypropylene ether sulfate is selected from one or more of sodium dodecyl polyoxypropylene ether sulfate, sodium tetradecyl polyoxypropylene ether sulfate, sodium hexadecyl polyoxypropylene ether sulfate, potassium octadecyl polyoxypropylene ether sulfate and lithium octadecyl polyoxypropylene ether sulfate, preferably sodium dodecyl polyoxypropylene ether sulfate or sodium hexadecyl polyoxypropylene ether sulfate.
  • the alkylphenol polyoxyethylene ether sulfate has a structural formula shown in Formula I:
  • R2 is preferably nonyl, undecyl, tridecyl, pentadecyl, heptadecyl or nonadecyl.
  • the alkylphenol polyoxyethylene ether sulfate is selected from one or more of undecylphenol polyoxyethylene ether sodium sulfate, tridecylphenol polyoxyethylene ether sodium sulfate, tridecylphenol polyoxyethylene ether lithium sulfate, tridecylphenol polyoxyethylene ether potassium sulfate, pentadecylphenol polyoxyethylene ether sodium sulfate, heptadecylphenol polyoxyethylene ether sodium sulfate and nonadecylphenol polyoxyethylene ether sodium sulfate, preferably undecylphenol polyoxyethylene ether sodium sulfate or tridecylphenol polyoxyethylene ether sodium sulfate.
  • the second aspect of the present invention provides the use of the aforementioned middle phase microemulsion in oil displacement.
  • the medium phase microemulsion of the present invention When used for oil displacement, only a relatively low mass concentration ( ⁇ 0.5%) is required. The recovery rate can be greatly improved.
  • the use of the medium phase microemulsion of the present invention for oil displacement can greatly increase the crude oil recovery rate.
  • a third aspect of the present invention provides an oil recovery method, comprising:
  • PPG Preformed Particle Gel in the PPG flooding system refers to a viscoelastic particle flooding agent (a viscoelastic particle-type flooding agent in which polymerized monomers, cross-linking agents, proppants, etc. are polymerized to form a star-shaped or three-dimensional network structure). It is a particle-type flooding agent with viscoelasticity and deformable migration in porous media, and has the characteristics of good viscoelasticity, temperature and salt resistance, and strong migration ability. PPG has three different particle sizes, namely (75-150) ⁇ m, (100-300) ⁇ m, and (300-900) ⁇ m.
  • the heterogeneous composite flooding method using it as the main agent is a new chemical flooding method with great potential for field application, which is conducive to solving the problem of improving the recovery of oil reservoirs after polymer flooding.
  • the method of the present invention adopts a medium-phase microemulsion flooding system, supplemented by a nitrogen foam flooding system, and can greatly improve the crude oil recovery rate.
  • concentration of the agent used in the present invention is low, and has good economic benefits.
  • the polymer flooding system comprises a polymer and PPG, wherein the mass ratio of the polymer to PPG is 1:1-3; and the viscosity of the polymer is 30-80 mPa ⁇ s.
  • the polymer is selected from one or more of a hyperbranched associative polymer, a salt-resistant polymer, a temperature-resistant and salt-resistant polymer, and a partially hydrolyzed polyacrylamide.
  • the polymer flooding system is formulated with in situ water.
  • the total mass concentration of the polymer and PPG is 0.03-0.15%.
  • the injection volume of the polymer flooding system is 0.02-0.07 PV.
  • the medium phase microemulsion flooding system is prepared with on-site water having a salinity of 1-9%.
  • the mass concentration of the middle phase microemulsion in the middle phase microemulsion flooding system, is 0.2-0.5%.
  • the mass concentration of the middle phase microemulsion is preferably between 0.2-0.5% to have a better oil displacement effect. If the mass concentration of the middle phase microemulsion is too small, less than 0.2%, especially less than 0.1%, the oil displacement effect is poor; although the mass concentration of the middle phase microemulsion is higher than 0.5%, a good oil displacement effect can also be achieved, but it will lead to increased costs. It has been found through research that the mass concentration of the middle phase microemulsion is as high as 2%, which is similar to the oil displacement effect of the mass concentration of 0.5%. Therefore, considering the cost and oil displacement effect, the present application preferably has a mass concentration of 0.2-0.5% for the middle phase microemulsion.
  • the injection volume of the medium-phase microemulsion flooding system is 0.05-0.7 PV.
  • step (2) further comprises: before injecting the middle phase microemulsion flooding system, adding a polymer having a viscosity of 10-50 mPa ⁇ s into the middle phase microemulsion flooding system.
  • the polymer is selected from one or more of a hyperbranched associative polymer, a salt-resistant polymer, a temperature-resistant and salt-resistant polymer, and a partially hydrolyzed polyacrylamide.
  • the mass concentration of the polymer in the middle phase microemulsion flooding system, is 0.05-0.25%.
  • a hyperbranched associative polymer and sodium carbonate are added to the middle phase microemulsion flooding system, wherein the mass concentration of the hyperbranched associative polymer is 0.15%, and the mass concentration of the sodium carbonate is 0.6%.
  • step (2) a polymer is added to the middle phase microemulsion oil displacement system to control fluidity and increase the volume of the middle phase microemulsion, thereby further improving the oil displacement efficiency; sodium carbonate is added to increase the volume of the middle phase, thereby further improving the recovery rate.
  • the gas foam flooding system is obtained by filling a foam flooding system with gas; the foam flooding system comprises an anionic surfactant, a polymer compound and urea.
  • the foam flooding system is prepared with water having a salinity of 1-9%.
  • the mass concentration of the anionic surfactant is 0.1-0.8%
  • the mass concentration of the polymer compound is 0.1-0.5%
  • the mass concentration of urea is 0.5-2%.
  • the total mass concentration of the anionic surfactant, the polymer compound and the urea is 0.1-3.5%.
  • the anionic surfactant contains at least one of a fatty acyl-peptide condensate; the general formula of the fatty acyl-peptide condensate is R 3 CONHR 4 COOA, wherein R 3 is a C 8 -C 12 alkyl group, i.e., an alkyl group with a carbon chain length of 8-12, such as C 8 H 17 , C 10 H 21 , C 12 H 23 ; R 4 is a C 1 -C 8 alkyl group; and A is H, Na or K.
  • R4 is an aliphatic amino group.
  • the fatty acyl-peptide condensate is selected from sodium lauroyl sarcosinate and/or sodium lauric monoglyceride sulfate.
  • the anionic surfactant further contains sodium dodecyl sulfate and/or sodium dodecyl sulfonate.
  • the polymer compound is selected from one or more of xanthan gum, sodium carboxymethyl cellulose and sodium carboxymethyl starch.
  • the volume ratio of the gas to the foam flooding system is 2:1-6:1.
  • the gas is selected from one or more of nitrogen, air, oxygen and hypoxic air.
  • the gas foam flooding system comprises: 0.4% sodium dodecyl sulfate, 0.15% xanthan gum and 1% urea; nitrogen is introduced at a ratio of 3:1 (nitrogen to foam flooding system volume ratio).
  • the injection volume of the gas foam flooding system is 0-0.7 PV.
  • step (4) the PPG flooding system is prepared using on-site water having a salinity of 1-9%.
  • the mass concentration of PPG in the PPG flooding system, is 0.1-0.3%.
  • the injection volume of the PPG flooding system is 0-0.15 PV.
  • the polymer flooding system comprises a polymer and PPG, wherein the mass ratio of the polymer to PPG is 1:1-3; and the viscosity of the polymer is 30-80 mPa ⁇ s.
  • the injection volume of the polymer flooding system is 0.03-0.07 PV.
  • the polymer flooding system further comprises one or more of a hyperbranched associative polymer, a salt-resistant polymer, a temperature-resistant and salt-resistant polymer, and a partially hydrolyzed polyacrylamide;
  • the polymer flooding system is formulated with in situ water
  • the total mass concentration of the polymer and PPG is 0.03-0.15%.
  • the on-site water with a mineralization degree of 1-9% is prepared by adding sodium chloride to the on-site water.
  • step (2) and step (3) can be interchanged; and/or, step (2) and step (3) can be injected alternately.
  • step (2) and step (3) can be changed at will.
  • Step (2) can be performed first and then step (3), or step (3) can be performed first and then step (2).
  • Step (2) and step (3) can also be injected alternately.
  • a fourth aspect of the present invention provides the use of the aforementioned middle phase microemulsion or the aforementioned oil recovery method in a conglomerate reservoir.
  • the conglomerate reservoir has a complex modal pore structure.
  • an oil recovery method using a low-concentration medium-phase microemulsion oil recovery system assisted by a nitrogen foam oil recovery system comprises the following steps:
  • a polymer flooding system with a mass concentration of 0.03%-0.15% is prepared using on-site water, wherein the polymer flooding system comprises a polymer and PPG, wherein the mass ratio of the polymer to the PPG is 1:1-1:3, and the viscosity of the polymer is 30mPa ⁇ s-80mPa ⁇ s; the polymer is selected from one or more of a hyperbranched associative polymer, a salt-resistant polymer, a temperature-resistant and salt-resistant polymer, and a partially hydrolyzed polyacrylamide;
  • step (2) injecting a middle phase microemulsion flooding system after step (1), wherein the injection amount of the middle phase microemulsion flooding system is 0.05-0.7 PV;
  • Sodium chloride is used to adjust the mineralization of on-site water to obtain water for preparation with a mineralization of 1%-9%; the water for preparation with a mineralization of 1%-9% is used to prepare a middle-phase microemulsion flooding system with a mass concentration of 0.2%-0.5%; the middle-phase microemulsion flooding system includes: a nonionic surfactant and an anionic surfactant, wherein the nonionic surfactant is an alkyl alcohol amide, and the anionic surfactant is an alkyl polyoxypropylene ether sulfate and an alkylphenol polyoxyethylene ether sulfate.
  • the middle-phase microemulsion flooding system also includes one or more of dodecyl diethanolamide, coconut oil fatty acyl amino acid ethyl sodium and coconut oil fatty acid diethanolamide. Furthermore, in this step, a polymer with a viscosity of 10mPa ⁇ s-50mPa ⁇ s is also added; the polymer is selected from one or more of hyperbranched associative polymers, salt-resistant polymers, temperature-resistant and salt-resistant polymers, and partially hydrolyzed polyacrylamide;
  • step (3) injecting a foam flooding system after step (2), wherein the injection amount of the foam flooding system is 0-0.7 PV;
  • a foam flooding system with a mass concentration of 0.1% to 3.5% is prepared using a solution water with a salinity of 1% to 9%, wherein the foam flooding system comprises an anionic surfactant, a polymer compound and urea, wherein the anionic surfactant is a fatty acyl-peptide condensate, and nitrogen is added, and the volume ratio of nitrogen to the volume of the foam flooding system is 2:1 to 6:1.
  • the anionic surfactant is selected from one or more of sodium dodecyl sulfate, sodium dodecyl sulfonate, sodium lauroyl sarcosinate, and sodium lauric acid monoglyceride sulfate;
  • the polymer compound is selected from one or more of xanthan gum, sodium carboxymethyl cellulose, and sodium carboxymethyl starch;
  • step (4) injecting a polymer flooding system after step (4), wherein the injection amount of the polymer flooding system is 0.03-0.07 PV;
  • a polymer flooding system with a mass concentration of 0.03%-0.15% is prepared using on-site water.
  • the polymer flooding system includes a polymer and PPG, wherein the mass ratio of the polymer to the PPG is 1:1-1:3, and the viscosity of the polymer is 30mPa ⁇ s-80mPa ⁇ s; the polymer is selected from one or more of a hyperbranched associative polymer, a salt-resistant polymer, a temperature-resistant and salt-resistant polymer, and a partially hydrolyzed polyacrylamide.
  • the polymer flooding system in step (5) may be the same as or different from the polymer flooding system in step (1). In order to reduce the number of preparation steps, it is preferred that the polymer flooding system in step (5) is the same as the polymer flooding system in step (1).
  • step (2) and step (3) can be interchanged or used alternately.
  • the present invention in order to more conveniently observe the formation process of the middle phase microemulsion and whether the middle phase microemulsion is formed in the produced fluid, also provides a microemulsion state observation device, as shown in Figure 1, which includes: a fixing device 1, a background light 2, a lifting plate 3 and a fixing screw 4, wherein the fixing device 1 is provided with a through hole 11 and an adjustable test tube rack 12, and the test tube rack 12 can be inserted into the through hole 11.
  • the test tube rack 12 is used to clamp the test tube and keep the test tube 12 balanced.
  • the lifting plate 3 can be adjusted in height to support the test tube to prevent the test tube from falling.
  • the fixing screw 4 is used to fix the lifting plate 3, and when the lifting plate 3 is lifted to a suitable position, it is fixed with the fixing screw 4.
  • the background light 2 is a rectangular white transparent background light, and the color and intensity of the light can be adjusted to clearly observe the phase transition of the microemulsion.
  • the device can be used to visually observe the differences between the oil phase, water phase and intermediate phase formed after the surfactant is emulsified, and can more accurately determine the boundary between each phase.
  • the device can be used to more clearly observe the phase transition of the middle phase microemulsion.
  • the phase state varies with the salt concentration or surfactant concentration added to the system, and the volume of the middle phase is also different. The higher the volume of the middle phase, the more conducive it is to improving the oil recovery efficiency.
  • the present invention adjusts the salinity and compounding ratio of the oil recovery system according to the formation crude oil and the water used for liquid preparation.
  • a conglomerate reservoir in Xinjiang Oilfield was selected as the target reservoir, and water-saturated cores produced from well area A were used to measure permeability; then the crude oil from the oil well was used to drive water until no water was produced; the water produced from well area A was used to drive to a water content of 98%, and the water drive recovery rate was calculated; an oil drive system with a certain PV number (the oil drive system in the embodiment and the comparative example) was injected, and then the water produced from well area A was used to drive to a water content of 98%, and the chemical drive recovery rate was calculated.
  • Preparation of polymer flooding system On-site water is used to prepare the polymer flooding system, which includes partially hydrolyzed polyacrylamide and PPG, and the mass ratio of partially hydrolyzed polyacrylamide to PPG is 1:1; in the polymer flooding system, the total mass concentration of partially hydrolyzed polyacrylamide and PPG is 0.1%.
  • Preparation of a medium-phase microemulsion oil displacement system sodium chloride is used to adjust the mineralization of on-site water to 3% as the preparation water to prepare the medium-phase microemulsion oil displacement system;
  • the medium-phase microemulsion in the medium-phase microemulsion oil displacement system includes: 5 parts of coconut oil fatty acyl amino acid ethyl ester sodium, 1 part of hexadecyl polyoxypropylene sodium sulfate, and 1 part of nonylphenol polyoxyethylene ether sodium sulfate, and the mass concentration of the medium-phase microemulsion in the medium-phase microemulsion oil displacement system is 0.5%.
  • the medium-phase microemulsion oil displacement system also adds a hyperbranched associative polymer with a mass concentration of 0.15% and sodium carbonate with a mass concentration of 0.6%, wherein the viscosity of the hyperbranched associative polymer is 50 mPa ⁇ s.
  • Preparation of nitrogen foam flooding system Sodium chloride is used to adjust the mineralization of on-site water to 3%, and the foam flooding system is prepared as liquid preparation water.
  • the foam flooding system includes: sodium dodecyl sulfate with a mass concentration of 0.4%, xanthan gum with a mass concentration of 0.15%, and urea with a mass concentration of 1.0%.
  • Nitrogen is introduced into the foam flooding system so that the volume ratio of nitrogen to the foam flooding system is 3:1, thereby obtaining the nitrogen foam flooding system.
  • Preparation of PPG flooding system Sodium chloride was used to adjust the mineralization of the on-site water to 3%, and the PPG flooding system with a mass concentration of 0.1% was prepared as the liquid preparation water.
  • the interfacial tension parameters are measured according to SY/T5370-2018 "Surface and interfacial tension determination method”.
  • the permeability, water drive recovery and chemical drive recovery are measured according to QS/Y 1583-2013 Technical Specifications for Surfactants for Binary Flooding.
  • An oil displacement method specifically comprises the following steps:
  • step (4) the polymer flooding system is injected at an injection volume of 0.05 PV.
  • Example 1 The oil displacement method of Example 1 is used, except that the sodium hexadecyl polyoxypropylene sulfate in the microemulsion oil displacement system in step (2) is replaced by sodium tetradecyl polyoxypropylene sulfate. The rest is the same as Example 1. The results are shown in Table 1.
  • Example 1 The oil displacement method of Example 1 is different in that the coconut oil fatty acylamin acid ethyl sodium in the microemulsion oil displacement system in step (2) is replaced by a mixture of coconut oil fatty acylamin acid ethyl sodium (80wt%) and coconut oil fatty acid diethanolamide (20wt%). The rest is the same as in Example 1. The results are shown in Table 1.
  • Example 1 The oil recovery method of Example 1 was used, except that step (4), that is, the step of injecting the nitrogen foam oil recovery system, was not performed. The rest was the same as in Example 1. As shown in Table 1.
  • Example 1 The oil recovery method of Example 1 is different in that step (4) is not performed, that is, the step of injecting the PPG oil recovery system is not performed. The rest is the same as Example 1. The results are shown in Table 1.
  • Example 1 The oil displacement method of Example 1 was used, except that step (1) and step (5) were not performed, that is, the step of injecting the polymer oil displacement system was not performed. The rest was the same as Example 1. The results are shown in Table 1.
  • Example 1 The oil displacement method of Example 1 was used, except that the viscosity of the hyperbranched associative polymer was 10 mPa ⁇ s. The rest was the same as Example 1. The results are shown in Table 1.
  • Example 1 The oil displacement method of Example 1 was followed, except that the mass concentration of the middle phase microemulsion was 0.3%. The rest was the same as Example 1. The results are shown in Table 1.
  • the oil displacement method of Example 1 is different in that the middle phase microemulsion oil displacement system of step (2) comprises: 1 part of coconut oil fatty acyl amino acid ethyl ester sodium, 1 part of hexadecyl polyoxypropylene sodium sulfate, and 1 part of nonylphenol polyoxyethylene ether sodium sulfate. The rest is the same as that of Example 1. The results are shown in Table 1.
  • Example 1 The oil displacement method of Example 1 is different in that the middle phase microemulsion oil displacement system of step (2) does not contain sodium nonylphenol polyoxyethylene ether sulfate, and the rest is the same as Example 1. The results are shown in Table 1.
  • Example 1 The oil displacement method of Example 1 is used, except that the middle phase microemulsion oil displacement system of step (2) does not contain sodium hexadecyl polyoxypropylene sulfate. The rest is the same as Example 1. The results are shown in Table 1.
  • Example 1 The oil displacement method of Example 1 is different in that step (2) is not performed, that is, the step of injecting the middle phase microemulsion oil displacement system is not performed. The rest is the same as Example 1. The results are shown in Table 1.

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Abstract

本发明公开了中相微乳液及其驱油方法和应用。以重量份数计，所述中相微乳液包括：烷基醇酰胺4-8份、烷基聚氧丙烯醚硫酸盐1-5份和烷基酚聚氧乙烯醚硫酸盐1-4.5份。所述驱油方法包括：(1)向目标油藏的储层内注入聚合物驱油体系；(2)注入中相微乳液驱油体系，所述中相微乳液驱油体系包括前述的中相微乳液；可选地，(3)注入泡沫驱油体系；可选地，(4)注入PPG驱油体系；(5)注入聚合物驱油体系。本发明通过采用中相微乳液驱油体系可以大幅提高波及效率和驱油效率，在提高采收率领域展现了巨大的应用潜力。

Description

中相微乳液及其驱油方法和应用
相关申请的交叉引用
本申请要求2023年07月06日提交的中国专利申请202310827687.5的权益，该申请的内容通过引用被合并于本文。
技术领域
本发明涉及油田三次采油领域，具体涉及中相微乳液及其驱油方法和应用。
背景技术
砾岩油藏储层孔喉大小分布范围宽，主要为充填式复模态及双模态特征，不同岩性的孔隙结构模态、喉道半径分布特征存在显著差异，复杂的岩性和孔隙结构导致砾岩储层物性在空间上的强非均质性，平面、层间和层内差异极大。另外，砂岩油藏经过多年注水开发，导致储层结构、油水分布更为复杂，平面及纵向上非均质性差异较大。
三次采油技术中，火驱、天然气重力混相驱提高采收率35％以上，达到了大幅度提高采收率(25％以上)的技术要求，但技术应用条件苛刻。目前各大油田应用推广的技术为聚合物驱技术、二元复合驱技术以及三元复合驱技术，三种技术均无法达到大幅度提高采收率的技术要求。中相微乳液驱是一项类似混相驱的大幅度提高采收率技术，具备大幅降低残余油饱和度的特点，是实现大幅度提高采收率最有效的方式之一，总驱油效率可以达到90％以上。在不增加化学剂成本条件 下，预计现场试验较复合驱提高5个百分点，吨油化学剂成本可降低20％以上。中相微乳液驱是通过油藏中原位形成winsorⅢ型微乳液驱替地层中的原油。WinsorⅢ型微乳液同时增溶油和水，与油、水的界面张力都极低，驱替过程几乎不存在毛管力，对沿程剩余油有较强的增溶能力，微观波及效率和驱油效率大幅度提高。中相微乳液的形成与表面活性剂的结构、密切相关，常规表面活性剂在醇、盐的作用下也能形成稳定的中间相，需要浓度通常在1％以上。国内最早研制出适用于老君庙油田L层性能的石油磺酸盐(YM-3A)，筛选出驱油体系配方4401(4.0％YM-3A，4.0％正丁醇，0.1％BPA)，经过检验发现其性能优良，达到国外同类研究水平，但是用量大，影响经济效益。因此，亟需探索砂砾岩油藏注水开发后期大幅度提高采收率的体系及方法。
发明内容
本发明的目的是为了克服现有技术存在的砂砾岩油藏注水开发后期采收率不高的问题，提供中相微乳液及其驱油方法和应用，采用包含该中相微乳液的驱油方法可以大幅提高波及效率和驱油效率。
为了实现上述目的，本发明第一方面提供一种中相微乳液，以重量份数计，所述中相微乳液包括：烷基醇酰胺4-8份、烷基聚氧丙烯醚硫酸盐1-5份和烷基酚聚氧乙烯醚硫酸盐1-4.5份。
本发明第二方面提供前述的中相微乳液在驱油中的应用。
本发明第三方面提供一种驱油方法，所述驱油方法包括：
(1)向目标油藏的储层内注入聚合物驱油体系；
(2)注入中相微乳液驱油体系，所述中相微乳液驱油体系包括前 述的中相微乳液；
可选地，(3)注入气体泡沫驱油体系；
可选地，(4)注入PPG驱油体系；
(5)注入聚合物驱油体系。
本发明第四方面提供前述的中相微乳液或前述的驱油方法在砾岩油藏中的应用。
通过上述技术方案，本发明所取得的有益技术效果如下：
1)本发明的中相微乳液包括：至少一种非离子表面活性剂(烷基醇酰胺)和至少两种阴离子表面活性剂(烷基聚氧丙烯醚硫酸盐和烷基酚聚氧乙烯醚硫酸盐)，通过这三种物质进行复配，可以调节HLB在10左右，同时可以使体系堆积参数达到1左右，更容易形成中相体系。
2)本发明通过采用中相微乳液驱油体系进行驱油，在驱油过程中通过不同段塞组合方式改善驱替效果，包括前置段塞加入PPG进行调整剖面，过程中加入氮气泡沫驱进一步调整油藏非均质性，后置加入保护段塞进一步突显驱替效果，可以大幅提高波及效率和驱油效率，在提高采收率领域展现了巨大的应用潜力。
附图说明
图1是微乳液状态观测装置的结构示意图。
具体实施方式
在本文中所披露的范围的端点和任何值都不限于该精确的范围或 值，这些范围或值应当理解为包含接近这些范围或值的值。对于数值范围来说，各个范围的端点值之间、各个范围的端点值和单独的点值之间，以及单独的点值之间可以彼此组合而得到一个或多个新的数值范围，这些数值范围应被视为在本文中具体公开。
本发明第一方面提供一种中相微乳液，以重量份数计，所述中相微乳液包括：烷基醇酰胺4-8份、烷基聚氧丙烯醚硫酸盐1-5份和烷基酚聚氧乙烯醚硫酸盐1-4.5份。
本发明中，烷基醇酰胺为非离子表面活性剂；烷基聚氧丙烯醚硫酸盐和烷基酚聚氧乙烯醚硫酸盐为阴离子表面活性剂。
本发明通过这三种物质进行复配，可以调节HLB在10左右，同时可以使体系堆积参数达到1左右，更容易形成中相体系。
在本发明的一些优选施方式中，按重量份数计，所述中相微乳液包括：烷基醇酰胺5-7份、烷基聚氧丙烯醚硫酸盐2-4份和烷基酚聚氧乙烯醚硫酸盐2-4份。
在本发明的一些实施方式中，所述烷基醇酰胺的通式为R1CON(CH2CH2OH)n，R1为C10-C20的烷基，n＝1-40，优选为10-30。
本发明中，R1优选为癸基、十二烷基、十四烷基、十六烷基、十八烷基或二十烷基。
在本发明的一些优选施方式中，所述烷基醇酰胺选自十二烷基二乙醇酰胺、椰子油烷基醇酰胺磷酸酯和椰子油脂肪酸二乙醇酰胺中的一种或多种，优选为十二烷基二乙醇酰胺。
在本发明的一些实施方式中，所述烷基聚氧丙烯醚硫酸盐的通式为CmH2m+1(CH2CH2CH2O)mSO3X，其中，m＝1-30，优选为10-20；X选 自Li、Na或K。
在本发明的一些优选施方式中，所述烷基聚氧丙烯醚硫酸盐选自十二烷基聚氧丙烯醚硫酸钠、十四烷基聚氧丙烯醚硫酸钠、十六烷基聚氧丙烯醚硫酸钠、十八烷基聚氧丙烯醚硫酸钾和十八烷基聚氧丙烯醚硫酸锂中的一种或多种，优选为十二烷基聚氧丙烯醚硫酸钠或十六烷基聚氧丙烯醚硫酸钠。
在本发明的一些实施方式中，所述烷基酚聚氧乙烯醚硫酸盐具有式I所示的结构式：
式I中，R2为C10-C20的烷基，p＝3-15，优选为5-12，Y选自Li、Na或K。
本发明中，R2优选为壬基、十一烷基、十三烷基、十五烷基、十七烷基或十九烷基。
在本发明的一些优选施方式中，所述烷基酚聚氧乙烯醚硫酸盐选自十一烷基酚聚氧乙烯醚硫酸钠、十三烷基酚聚氧乙烯醚硫酸钠、十三烷基酚聚氧乙烯醚硫酸锂、十三烷基酚聚氧乙烯醚硫酸钾、十五烷基酚聚氧乙烯醚硫酸钠、十七烷基酚聚氧乙烯醚硫酸钠和十九烷基酚聚氧乙烯醚硫酸钠中的一种或多种，优选为十一烷基酚聚氧乙烯醚硫酸钠或十三烷基酚聚氧乙烯醚硫酸钠。
本发明第二方面提供前述的中相微乳液在驱油中的应用。
本发明的中相微乳液用于驱油时，只需要较低的质量浓度(≤0.5％) 就可以大幅提高采收率。
采用本发明的中相微乳液进行驱油可大幅度提高原油采收率。
本发明第三方面提供一种驱油方法，所述驱油方法包括：
(1)向目标油藏的储层内注入聚合物驱油体系；
(2)注入中相微乳液驱油体系，所述中相微乳液驱油体系包括前述的中相微乳液；
可选地，(3)注入气体泡沫驱油体系；
可选地，(4)注入PPG驱油体系；
(5)注入聚合物驱油体系。
本发明中，PPG驱油体系中的PPG(Preformed Particle Gel)是指黏弹性颗粒驱油剂(聚合单体、交联剂、支撑剂等通过引发聚合形成星型或三维网络结构的粘弹性颗粒型驱油剂)，其是一种具有粘弹性且在多孔介质中可变形运移的颗粒型驱油剂，具有良好的粘弹性、耐温耐盐、运移能力强等特点。PPG有三种不同的粒径，分别为(75-150)μm、(100-300)μm、(300-900)μm。以其为主剂的非均相复合驱油方法是一种极具矿场应用潜力的新型化学驱油方法，有利于解决聚驱后油藏提高采收率问题。
本发明方法采用中相微乳液驱油体系，辅以氮气泡沫驱油体系，可以大幅度提高原油采收率，本发明所用的药剂浓度较低，具有很好的经济效益。
在本发明的一些实施方式中，步骤(1)中，所述聚合物驱油体系包括聚合物和PPG，其中，所述聚合物和PPG的质量比为1:1-3；所述聚合物的黏度为30-80mPa·s。
在本发明的一些实施方式中，所述聚合物选自超支化缔合聚合物、抗盐聚合物、耐温抗盐聚合物和部分水解聚丙烯酰胺中的一种或多种。
在本发明的一些实施方式中，所述聚合物驱油体系用现场水配制。
在本发明的一些实施方式中，在所述聚合物驱油体系中，所述聚合物和PPG的总质量浓度为0.03-0.15％。
在本发明的一些实施方式中，步骤(1)中，所述聚合物驱油体系的注入量为0.02-0.07PV。
在本发明的一些实施方式中，步骤(2)中，所述中相微乳液驱油体系用矿化度为1-9％的现场水配制。
在本发明的一些实施方式中，在所述中相微乳液驱油体系中，所述中相微乳液的质量浓度为0.2-0.5％。
在本发明中，中相微乳液的质量浓度优选在0.2-0.5％之间具有更好的驱油效效果。如果中相微乳液的质量浓度太小，小于0.2％，尤其是小于0.1％，导致驱油效果较差；虽然中相微乳液的质量浓度高于0.5％，也可以实现很好的驱油效果，但是会导致成本增高，经研究发现，中相微乳液的质量浓度高到2％，与质量浓度为0.5％的驱油效果差不多，因此，从成本及驱油效果综合考虑，本申请优选中相微乳液的质量浓度为0.2-0.5％。
在本发明的一些实施方式中，所述中相微乳液驱油体系的注入量为0.05-0.7PV。
在本发明的一些实施方式中，步骤(2)还包括：在注入所述中相微乳液驱油体系之前，向所述中相微乳液驱油体系中加入黏度为10-50mPa·s的聚合物。
在本发明的一些优选实施方式中，所述聚合物选自超支化缔合聚合物、抗盐聚合物、耐温抗盐聚合物和部分水解聚丙烯酰胺中的一种或多种。
在本发明的一些优选实施方式中，在所述中相微乳液驱油体系中，所述聚合物的质量浓度为0.05-0.25％。
进一步地，在所述中相微乳液驱油体系中加入超支化缔合聚合物和碳酸钠，其中，所述超支化缔合聚合物的质量浓度为0.15％，碳酸钠的质量浓度为0.6％。
本发明中，步骤(2)中，向所述中相微乳液驱油体系中加入聚合物，其作用是控制流度，同时可以增加中相微乳液的体积，进一步提高驱油效率；加入碳酸钠的作用是增加中相体积，进一步提高采收率。
在本发明的一些实施方式中，步骤(3)中，所述气体泡沫驱油体系是在泡沫驱油体系中充入气体得到；所述泡沫驱油体系包括阴离子表面活性剂、高分子化合物和尿素。
在本发明的一些实施方式中，所述泡沫驱油体系用矿化度为1-9％的水配制。
在本发明的一些实施方式中，在所述泡沫驱油体系中，阴离子表面活性剂的质量浓度为0.1-0.8％，高分子化合物的质量浓度为0.1-0.5％，尿素的质量浓度为0.5-2％。
本发明中，在所述泡沫驱油体系中，阴离子表面活性剂、高分子化合物和尿素的总质量浓度为0.1-3.5％。
在本发明的一些实施方式中，所述阴离子表面活性剂含有脂肪酰-肽缩化合物中的至少一种；所述脂肪酰-肽缩化合物的通式为 R3CONHR4COOA，其中，R3为C8-C12的烷基，即碳链长度为8-12的烷基，例如C8H17、C10H21、C12H23；R4为C1-C8的烷基；A为H、Na或K。
本发明中，R4为氨基的脂族基。
在本发明的一些优选实施方式中，所述脂肪酰-肽缩化合物选自月桂酰肌氨酸钠和/或月桂酸单甘油酯硫酸钠。
在本发明的一些优选实施方式中，所述阴离子表面活性剂还含有十二烷基硫酸钠/或十二烷基磺酸钠。
在本发明的一些实施方式中，所述高分子化合物选自黄原胶、羧甲基纤维素钠和羧甲基淀粉钠的一种或多种。
在本发明的一些实施方式中，所述气体与所述泡沫驱油体系的体积比为2:1-6:1。
在本发明的一些实施方式中，所述气体选自氮气、空气、氧气和低氧空气中的一种或多种。
在本发明的一些特别优选实施方式中，所述气体泡沫驱油体系包括：十二烷基硫酸钠0.4％、黄原胶0.15％和尿素1％；通入氮气3:1(氮气与泡沫驱油体系体积比)。
在本发明的一些实施方式中，所述气体泡沫驱油体系的注入量为0-0.7PV。
在本发明的一些实施方式中，步骤(4)中，所述PPG驱油体系用矿化度为1-9％的现场水配制。
在本发明的一些实施方式中，在所述PPG驱油体系中，PPG的质量浓度为0.1-0.3％。
在本发明的一些实施方式中，所述PPG驱油体系的注入量为0-0.15PV。
在本发明的一些实施方式中，步骤(5)中，所述聚合物驱油体系包括聚合物和PPG，其中，所述聚合物和PPG的质量比为1:1-3；所述聚合物的黏度为30-80mPa·s。
在本发明的一些实施方式中，步骤(5)中，所述聚合物驱油体系的注入量为0.03-0.07PV。
在本发明的一些实施方式中，所述聚合物驱油体系还包括超支化缔合聚合物、抗盐聚合物、耐温抗盐聚合物和部分水解聚丙烯酰胺中的一种或多种；
在本发明的一些实施方式中，所述聚合物驱油体系用现场水配制；
在本发明的一些实施方式中，在所述聚合物驱油体系中，所述聚合物和PPG的总质量浓度为0.03-0.15％。
在本发明的一些实施方式中，所述矿化度为1-9％的现场水通过在现场水中加入氯化钠配制而得。
在本发明的一些实施方式中，步骤(2)和步骤(3)的顺序可互换；和/或，步骤(2)和步骤(3)可交替注入。
本发明中，步骤(2)和步骤(3)的顺序可以随意调换，既可以先进行步骤(2)再步骤(3)，也可以先进行步骤(3)再步骤(2)，还可以步骤(2)和步骤(3)交替注入。
本发明第四方面提供前述的中相微乳液或前述的驱油方法在砾岩油藏中的应用。
在本发明的一些实施方式中，所述砾岩油藏具有复模态孔隙结构。
根据本发明一种特别优选的实施方式，一种驱油方法，采用低浓度中相微乳液驱油体系，辅助氮气泡沫驱油体系，包括以下步骤：
(1)向目标油藏的储层内注入聚合物驱油体系；所述聚合物驱油体系的注入量为0.02PV-0.07PV；
采用现场水配制质量浓度为0.03％-0.15％的聚合物驱油体系，所述聚合物驱油体系包括聚合物和PPG，其中，聚合物与PPG的质量比为1:1-1:3，所述聚合物的黏度为30mPa·s-80mPa·s；所述聚合物选自超支化缔合聚合物、抗盐聚合物、耐温抗盐聚合物和部分水解聚丙烯酰胺中的一种或多种；
(2)在步骤(1)之后注入中相微乳液驱油体系，所述中相微乳液驱油体系的注入量为0.05-0.7PV；
采用氯化钠调节现场水的矿化度，得到矿化度为1％-9％的配液用水；采用矿化度为1％-9％的配液用水，配制质量浓度为0.2％-0.5％的中相微乳液驱油体系；所述中相微乳液驱油体系包括：非离子表面活性剂和阴离子表面活性剂，其中，非离子表面活性剂为烷基醇酰胺，阴离子表面活性剂为烷基聚氧丙烯醚硫酸盐和烷基酚聚氧乙烯醚硫酸盐。所述中相微乳液驱油体系还包括十二烷基二乙醇酰胺，椰子油脂肪酰氨酸乙脂钠和椰子油脂肪酸二乙醇酰胺中的一种或多种。进一步地，该步骤中，还加入黏度为10mPa·s-50mPa·s的聚合物；所述聚合物选自超支化缔合聚合物、抗盐聚合物、耐温抗盐聚合物和部分水解聚丙烯酰胺中的一种或多种；
(3)在步骤(2)之后注入泡沫驱油体系，所述泡沫驱油体系的注入量为0-0.7PV；
采用矿化度为1％-9％的配液用水，配制质量浓度为0.1％-3.5％的泡沫驱油体系，所述泡沫驱油体系包括：阴离子表面活性剂、高分子化合物和尿素。其中阴离子表面活性剂为脂肪酰-肽缩化合物，加入氮气，氮气体积与泡沫驱油体系体积比为2:1-6:1。
所述阴离子表面活性剂选自十二烷基硫酸钠、十二烷基磺酸钠、月桂酰肌氨酸钠、月桂酸单甘油酯硫酸钠中的一种或多种；所述高分子化合物选自黄原胶、羧甲基纤维素钠和羧甲基淀粉钠中的一种或多种；
(4)在步骤(3)之后注入PPG驱油体系，所述PPG驱油体系的注入量为0-0.15PV；
采用矿化度为1％-9％的配液用水，配制质量浓度为0.1％-0.3％的PPG驱油体系；
(5)在步骤(4)之后注入聚合物驱油体系，所述聚合物驱油体系的注入量为0.03-0.07PV；
采用现场水配制质量浓度为0.03％-0.15％的聚合物驱油体系，所述聚合物驱油体系包括聚合物和PPG，其中，聚合物与PPG的质量比为1:1-1:3，所述聚合物的黏度为30mPa·s-80mPa·s；所述聚合物选自超支化缔合聚合物、抗盐聚合物、耐温抗盐聚合物和部分水解聚丙烯酰胺中的一种或多种。
步骤(5)中的聚合物驱油体系与步骤(1)中的聚合物驱油体系可以相同可以不同，为了减少配制的步骤，优选步骤(5)中的聚合物驱油体系与步骤(1)中的聚合物驱油体系相同。
步骤(2)和步骤(3)之间的相互顺序可以互换，或者交替使用。
在本发明中，为了更加方便观测中相微乳液的形成过程以及采出液中是否形成了中相微乳液，本发明还提供了一种微乳液状态观测装置，如图1所示，其包括：固定装置1、背景灯2、升降板3和固定螺丝4，其中所述固定装置1上设置有通孔11和可调的试管架12，所述试管架12可插入所述通孔11内。所述试管架12用于夹持试管，并保持试管12平衡。所述升降板3可调节高低，用于支撑试管，以防试管跌落。所述固定螺丝4用于固定升降板3，当述升降板3升降到合适的位置时，用所述固定螺丝4进行固定。所述背景灯2为长方形的白色透明背景灯，可调节灯光的颜色和强度，用以清晰的观察微乳液的相态转变。
采用该装置可直观的观看表面活性剂乳化后形成的油相、水相以及中相之间的区别，能更加准确的判断每个相态之间的分界线。
采用该装置可以更清晰的观测中相微乳液相态转变，相态随着体系中加入的盐浓度或者表活剂浓度的不同而不同，而且中相体积也不同，中相体积越高，越有利于提高驱油效率。本发明根据地层原油以及配液用水，通过调整驱油体系的盐度以及复配比例。
以下将通过实施例对本发明进行详细描述。
以下实施例和对比例中，
选取新疆油田的某砂砾岩油藏为目标油藏，采用A井区产出水饱和岩心，水测渗透率；然后用油井原油驱水至不出水：用A井区产出水驱至含水98％，计算水驱采收率；注入一定PV数的驱油体系(实施例和对比例中的驱油体系)，然后再用A井区产出水水驱至含水98％，计算化学驱采收率。
聚合物驱油体系的配制：采用现场水配制聚合物驱油体系，该聚合物驱油体系包括部分水解聚丙烯酰胺和PPG，部分水解聚丙烯酰胺与PPG的质量比为1:1；在该聚合物驱油体系中，部分水解聚丙烯酰胺和PPG的总质量浓度为0.1％。
中相微乳液驱油体系的配制：采用氯化钠调节现场水的矿化度为3％，作为配液用水，配制中相微乳液驱油体系；该中相微乳液驱油体系中的中相微乳液包括：5份椰子油脂肪酰氨酸乙脂钠、1份十六烷基聚氧丙烯硫酸钠、1份壬基酚聚氧乙烯醚硫酸钠，在该中相微乳液驱油体系中，中相微乳液的质量浓度为0.5％。该中相微乳液驱油体系中还加入质量浓度为0.15％的超支化缔合聚合物和质量浓度为0.6％的碳酸钠，其中，超支化缔合聚合物的黏度为50mPa·s。
氮气泡沫驱油体系的配制：采用氯化钠调节现场水的矿化度为3％，作为配液用水，配制泡沫驱油体系，该泡沫驱油体系包括：质量浓度为0.4％的十二烷基硫酸钠、质量浓度为0.15％的黄原胶和质量浓度为1.0％的尿素，向该泡沫驱油体系中通入氮气，使氮气与泡沫驱油体系体积比为3:1，得到氮气泡沫驱油体系。
PPG驱油体系的配制：采用氯化钠调节现场水的矿化度为3％，作为配液用水，配制质量浓度为0.1％的PPG驱油体系。
采用SYT 5862-2020驱油用聚合物技术要求。
界面张力参数通过SY/T5370-2018《表面及界面张力测定方法》测得。
渗透率、水驱采收率、化学驱采收率通过QS/Y 1583-2013《二元驱用表面活性剂技术规范》测得。
实施例1
一种驱油方法，具体包括以下步骤：
(1)向上述目标油藏的储层内注入上述聚合物驱油体系，注入量为0.05PV；
(2)在步骤(1)之后注入上述中相微乳液驱油体系，注入量为0.2PV；
(3)在步骤(2)之后注入上述氮气泡沫驱油体系，注入量为0.15PV；
(4)在步骤(3)之后注入上述PPG驱油体系，注入量为0.05PV；
(5)在步骤(4)之后注入上述聚合物驱油体系，注入量为0.05PV。
测得的渗透率、界面张力、水驱采收率和化学驱采收率，结果如表1所示。
实施例2
按照实施例1的驱油方法，不同的是，将步骤(2)中相微乳液驱油体系中的十六烷基聚氧丙烯硫酸钠替换为十四烷基聚氧丙烯硫酸钠，其余均与实施例1相同，结果如表1所示。
实施例3
按照实施例1的驱油方法，不同的是，将步骤(2)中相微乳液驱油体系中的椰子油脂肪酰氨酸乙脂钠替换为椰子油脂肪酰氨酸乙脂钠(80wt％)与椰子油脂肪酸二乙醇酰胺(20wt％)的混合物，其余均与实施例1相同，结果如表1所示。
实施例4
按照实施例1的驱油方法，不同的是，不进行步骤(4)，即不进行注入上述氮气泡沫驱油体系的步骤，其余均与实施例1相同，结果 如表1所示。
实施例5
按照实施例1的驱油方法，不同的是，不进行步骤(4)，即不进行注入PPG驱油体系的步骤，其余均与实施例1相同，结果如表1所示。
实施例6
按照实施例1的驱油方法，不同的是，不进行步骤(1)和步骤(5)，即不进行注入聚合物驱油体系的步骤，其余均与实施例1相同，结果如表1所示。
实施例7
按照实施例1的驱油方法，不同的是，超支化缔合聚合物的黏度为10mPa·s，其余均与实施例1相同，结果如表1所示。
实施例8
按照实施例1的驱油方法，不同的是，中相微乳液的质量浓度为0.3％，其余均与实施例1相同，结果如表1所示。
对比例1
按照实施例1的驱油方法，不同的是，步骤(2)的中相微乳液驱油体系包括：1份椰子油脂肪酰氨酸乙脂钠、1份十六烷基聚氧丙烯硫酸钠、1份壬基酚聚氧乙烯醚硫酸钠，其余均与实施例1相同，结果如表1所示。
对比例2
按照实施例1的驱油方法，不同的是，将步骤(2)的中相微乳液驱油体系中不含壬基酚聚氧乙烯醚硫酸钠，其余均与实施例1相同， 结果如表1所示。
对比例3
按照实施例1的驱油方法，不同的是，将步骤(2)的中相微乳液驱油体系中不含十六烷基聚氧丙烯硫酸钠，其余均与实施例1相同，结果如表1所示。
对比例4
按照实施例1的驱油方法，不同的是，不进行步骤(2)，即不进行注入中相微乳液驱油体系的步骤，其余均与实施例1相同，结果如表1所示。
表1

通过表1的结果可以看出，在水驱采收率相近的前提下，采用本发明实施例1-7的驱油方法得到的化学驱采收率均大于20％，实施例1甚至达到51.3％，对比例1-4的驱油方法均小于20％。因此，采用本发明的实施例1-7的驱油方法明显比对比例1-4的驱油方法具有更好的驱油效果。
以上详细描述了本发明的优选实施方式，但是，本发明并不限于此。在本发明的技术构思范围内，可以对本发明的技术方案进行多种简单变型，包括各个技术特征以任何其它的合适方式进行组合，这些简单变型和组合同样应当视为本发明所公开的内容，均属于本发明的保护范围。

Claims (22)

  1. 一种中相微乳液，其特征在于，以重量份数计，所述中相微乳液包括：烷基醇酰胺4-8份、烷基聚氧丙烯醚硫酸盐1-5份和烷基酚聚氧乙烯醚硫酸盐1-4.5份。
  2. 根据权利要求1所述的中相微乳液，其中，所述烷基醇酰胺的通式为R1CON(CH2CH2OH)n，R1为C10-C20的烷基，n＝1-40。
  3. 根据权利要求2所述的中相微乳液，其中，所述烷基醇酰胺选自十二烷基二乙醇酰胺、椰子油烷基醇酰胺磷酸酯和椰子油脂肪酸二乙醇酰胺中的一种或多种。
  4. 根据权利要求1或2所述的中相微乳液，其中，所述烷基聚氧丙烯醚硫酸盐的通式为CmH2m+1(CH2CH2CH2O)mSO3X，其中，m＝1-30；X选自Li、Na或K。
  5. 根据权利要求4所述的中相微乳液，其中，所述烷基聚氧丙烯醚硫酸盐选自十二烷基聚氧丙烯醚硫酸钠、十四烷基聚氧丙烯醚硫酸钠、十六烷基聚氧丙烯醚硫酸钠、十八烷基聚氧丙烯醚硫酸钾和十八烷基聚氧丙烯醚硫酸锂中的一种或多种。
  6. 根据权利要求1或2所述的中相微乳液，其中，所述烷基酚聚氧乙烯醚硫酸盐具有式I所示的结构式：
    式I中，R2为C10-C20的烷基，p＝3-15，Y选自Li、Na或K。
  7. 权利要求1-6中任意一项所述的中相微乳液在驱油中的应用。
  8. 一种驱油方法，其特征在于，所述驱油方法包括：
    (1)向目标油藏的储层内注入聚合物驱油体系；
    (2)注入中相微乳液驱油体系，所述中相微乳液驱油体系包括权利要求1-7中任意一项所述的中相微乳液；
    可选地，(3)注入气体泡沫驱油体系；
    可选地，(4)注入PPG驱油体系；
    (5)注入聚合物驱油体系。
  9. 根据权利要求8所述的驱油方法，其中，步骤(1)和步骤(5)中，所述聚合物驱油体系包括聚合物和PPG，其中，所述聚合物和PPG的质量比为1:1-3；所述聚合物的黏度为30-80mPa·s；
    和/或，步骤(1)中，所述聚合物驱油体系的注入量为0.02-0.07PV；
    和/或，步骤(5)中，所述聚合物驱油体系的注入量为0.03-0.07PV。
  10. 根据权利要求9所述的驱油方法，其中，所述聚合物选自超支化缔合聚合物、抗盐聚合物、耐温抗盐聚合物和部分水解聚丙烯酰胺中的一种或多种；
    和/或，所述聚合物驱油体系用现场水配制；
    和/或，在所述聚合物驱油体系中，所述聚合物和PPG的总质量浓度为0.03-0.15％。
  11. 根据权利要求8所述的驱油方法，其中，步骤(2)中，所述中相微乳液驱油体系用矿化度为1-9％的现场水配制；
    和/或，在所述中相微乳液驱油体系中，所述中相微乳液的质量浓度为0.2-0.5％；
    和/或，所述中相微乳液驱油体系的注入量为0.05-0.7PV。
  12. 根据权利要求8所述的驱油方法，其中，步骤(2)还包括：在注入所述中相微乳液驱油体系之前，向所述中相微乳液驱油体系中加入黏度为10-50mPa·s的聚合物。
  13. 根据权利要求8所述的驱油方法，其中，步骤(3)中，所述气体泡沫驱油体系是在泡沫驱油体系中充入气体得到；所述泡沫驱油体系包括阴离子表面活性剂、高分子化合物和尿素；
    和/或，所述气体泡沫驱油体系的注入量为0-0.7PV。
  14. 根据权利要求13所述的驱油方法，其中，所述泡沫驱油体系用矿化度为1-9％的水配制；
    和/或，在所述泡沫驱油体系中，阴离子表面活性剂的质量浓度为0.1-0.8％，高分子化合物的质量浓度为0.1-0.5％，尿素的质量浓度为0.5-2％。
  15. 根据权利要求13所述的驱油方法，其中，所述阴离子表面活性剂含有脂肪酰-肽缩化合物中的至少一种；所述脂肪酰-肽缩化合物的通式为R3CONHR4COOA，其中，R3为C8-C12的烷基；R4为C1-C8的烷基；A为H、Na或K；
    和/或，所述高分子化合物选自黄原胶、羧甲基纤维素钠和羧甲基淀粉钠的一种或多种。
  16. 根据权利要求13所述的驱油方法，其中，所述脂肪酰-肽缩化合物选自月桂酰肌氨酸钠和/或月桂酸单甘油酯硫酸钠；
    和/或，所述阴离子表面活性剂还含有十二烷基硫酸钠/或十二烷基磺酸钠。
  17. 根据权利要求13所述的驱油方法，其中，所述气体与所述泡 沫驱油体系的体积比为2:1-6:1；
    和/或，所述气体选自氮气、空气、氧气和低氧空气中的一种或多种。
  18. 根据权利要求8所述的驱油方法，其中，步骤(4)中，所述PPG驱油体系用矿化度为1-9％的现场水配制；
    和/或，在所述PPG驱油体系中，PPG的质量浓度为0.1-0.3％；
    和/或，所述PPG驱油体系的注入量为0-0.15PV。
  19. 根据权利要求11-18中任意一项所述的驱油方法，其中，所述矿化度为1-9％的现场水通过在现场水中加入氯化钠配制而得。
  20. 根据权利要求8所述的驱油方法，其中，步骤(2)和步骤(3)的顺序可互换；
    和/或，步骤(2)和步骤(3)可交替注入。
  21. 权利要求1-6中任意一项所述的中相微乳液或权利要求8-20中任意一项所述的驱油方法在砾岩油藏中的应用。
  22. 根据权利要求21所述的应用，其中，所述砾岩油藏具有复模态孔隙结构。
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Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN110358517A (zh) * 2018-03-26 2019-10-22 中国石油化工股份有限公司 一种适合高钙镁油藏的复合表面活性剂驱油体系及其制备方法
CN111004614A (zh) * 2019-03-15 2020-04-14 山东金智瑞新材料发展有限公司 一种油藏驱油的组合物及驱油方法

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN110358517A (zh) * 2018-03-26 2019-10-22 中国石油化工股份有限公司 一种适合高钙镁油藏的复合表面活性剂驱油体系及其制备方法
CN111004614A (zh) * 2019-03-15 2020-04-14 山东金智瑞新材料发展有限公司 一种油藏驱油的组合物及驱油方法

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