WO2020224064A1 - 黏度可控的原位乳化增黏体系及其在水驱油藏的应用 - Google Patents

黏度可控的原位乳化增黏体系及其在水驱油藏的应用 Download PDF

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WO2020224064A1
WO2020224064A1 PCT/CN2019/098263 CN2019098263W WO2020224064A1 WO 2020224064 A1 WO2020224064 A1 WO 2020224064A1 CN 2019098263 W CN2019098263 W CN 2019098263W WO 2020224064 A1 WO2020224064 A1 WO 2020224064A1
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viscosity
water
superfine
controllable
ultrafine
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French (fr)
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刘锐
蒲万芬
杜代军
孙琳
庞诗师
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西南石油大学
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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
    • 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
    • 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
    • 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
    • E21B43/20—Displacing by water
    • 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
    • C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
    • C09K2208/10—Nanoparticle-containing well treatment fluids

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  • the invention relates to an in-situ emulsification and viscosity-increasing system with controllable viscosity and its application in a water drive oil reservoir, and belongs to the technical fields of oil field chemistry and oil field exploitation.
  • the viscosity of emulsion is closely related to the type of emulsion. For this reason, schools at home and abroad have carried out extensive research and formed a variety of judgment methods, such as Winsor ratio R value, lipophilic-hydrophilic balance value HLB, hydrophilic lipophilic Deviation value HLD etc. Winsor ratio is mainly used to determine the hydrophilicity and lipophilicity of (natural) emulsifiers. Based on the relative relationship between R and 1, the emulsion system is divided into 4 categories.
  • reaction energy of the emulsifier and the oil phase is less than that of the water phase, and it is easier to form an O/W emulsion (type I); when R>1, the reaction energy of the emulsifier and the water phase is less than that of the water phase.
  • the reaction energy of the oil phase makes it easier to form a W/O type emulsion (Type II); when R ⁇ 1, one possibility is to form a system with an organic phase in the upper part, an aqueous phase in the lower part, and a microemulsion in the middle part (Type III) ; Another possibility is to form a single-phase homogeneous system, in which oil and water exist in the form of a dual continuous phase or a layered phase.
  • the hydrophilic and lipophilic deviation value is a digital manifestation of the deviation of the optimized formula.
  • the colloidal clay promotes the emulsion to form an O/W or W/O emulsion.
  • the adsorption of paraffin, silica, clay, iron oxide and polymer colloids at the interface stabilizes the emulsion, and the colloid adsorbed through the particle network or the interface stabilizes the interface Membrane, these are affected by particle size, shape, morphology, density, concentration, surface coverage and wettability.
  • Masalova et al. used caged silsesquioxane POSSAM0275 to form high-concentration water-in-oil emulsions (Masalova, I., Tshilumbu, N., Mamedov, E., Kharatyan, E., Katende, J.
  • POSSAM0275 nanomolecules can form a brand new interface layer in the emulsion, which is different from traditional surfactants and the properties of nanoparticles in the oil-water interface layer.
  • the important prerequisite for the emulsion to greatly increase the recovery factor is that the viscosity in the reservoir is controllable, that is, the formation of high-viscosity emulsion in the high water-bearing layer, the increase of seepage resistance, the formation of low-viscosity emulsion in the low-permeability layer, and reduce The heterogeneity of the reservoir to increase the sweep coefficient of the medium and low permeability layers.
  • the purpose of the present invention is to provide a viscosity-controllable in-situ emulsification and viscosity-increasing system, which has excellent fluidity self-control performance, low-cost and easy-to-obtain raw materials, reliable preparation principles, outstanding economic benefits, and can realize high permeability regions (high water content, Piston displacement in low oil saturation) and low permeability areas (low water cut, high oil saturation) greatly improves the recovery of water drive reservoirs, and has broad industrial application prospects.
  • Another object of the present invention is to provide the application of the above-mentioned in-situ emulsification and viscosity-increasing system with controllable viscosity in water-flooding oil reservoirs.
  • the in-situ emulsification and viscosity-increasing system is suitable for water-flooding oil reservoirs with a viscosity of less than 50 mPa ⁇ s, and Unaffected by the temperature and salinity of the reservoir, it covers a wide range of oil reservoirs and has outstanding economic benefits, effectively driving the efficient development of water drive reservoirs.
  • the present invention adopts the following technical solutions.
  • An in-situ emulsification and viscosity-increasing system with controllable viscosity composed of emulsifier + ultrafine colloidal particles + suspending agent.
  • the system is directly dissolved or dispersed in water, and the viscosity is slightly higher than that of the water phase. It is pumped into the formation through an injection device.
  • the emulsifier and the ultrafine colloidal particles have a synergistic effect, and the remaining is emulsified in situ
  • the (residual) oil forms a kinetic stable water external phase emulsion; under high water content conditions (60 ⁇ 80%) the viscosity of the emulsion is 1 ⁇ 1.5 times that of crude oil, while under low water content conditions ( ⁇ 60%) the viscosity of the emulsion
  • the viscosity is slightly lower than that of crude oil but significantly greater than that of water phase, realizing piston displacement in high and low permeability areas, and cooperating with ultra-low interfacial tension to wash oil, greatly improving reservoir conditions for water flooding with crude oil viscosity less than 50 mPa ⁇ s Reservoir recovery factor.
  • In-situ emulsification and viscosity-increasing system with controllable viscosity including emulsifiers with (ultra) low interfacial tension (10 -2 mN/m and below) formed with crude oil, hydrophilic ultra-fine colloidal particles and suspending agents, the system It is composed of the following components by weight percentage:
  • Emulsifier 0.3 ⁇ 1.5%
  • the rest is mineralized water.
  • the emulsifier is petroleum sulfonate, petroleum carboxylate, sodium dodecyl sulfonate, sodium dodecyl benzene sulfonate, alkyl glycoside, fatty alcohol ether carboxylate, fatty alcohol ether sulfonate, One or a combination of hydroxysultaine and alkanolamide, the oil-water interfacial tension can reach 10 -2 mN/m or less.
  • the ultrafine colloidal particles are one of ultrafine silica, ultrafine montmorillonite, ultrafine iron oxide, ultrafine iron tetroxide, ultrafine alumina, and ultrafine titanium dioxide, where ultrafine refers to The particle size of the colloidal particles is 10 nm to 1.0 ⁇ m.
  • the suspending agent is one of partially hydrolyzed polyacrylamide, amylose, carboxymethyl chitosan, hydroxymethyl cellulose, xanthan gum, and sodium alginate.
  • the emulsifier is preferably 0.4% by weight, the ultrafine colloidal particles are preferably 0.15%, the suspending agent is preferably 0.05%, and the rest is Mineralized water.
  • the application of the controllable in-situ emulsification and viscosity-increasing system in a water-flooding reservoir is as follows: the temperature is up to 140°C, the salinity of water is up to 24 ⁇ 10 4 mg/L, and the formation Water flooding reservoirs with crude oil viscosity less than 50mPa ⁇ s.
  • the in-situ emulsification and viscosity-increasing system with controllable viscosity provided by the present invention is directly dissolved or dispersed with mineralized water, the viscosity is slightly higher than that of mineralized water, and the injectability is good; it generates power in-situ with crude oil under 20-90% water content conditions Scientifically stable water-external phase emulsion.
  • the viscosity of the emulsion under high water content conditions (60 ⁇ 80%) is 1 ⁇ 1.5 times that of crude oil, while under low water content conditions ( ⁇ 60%), the viscosity of emulsion is slightly lower than that of crude oil.
  • the formation of a high-viscosity water-external-phase emulsion in the high-permeability area increases the seepage resistance
  • the formation of a low-viscosity water-external-phase emulsion in the low-permeability area reduces the drainage resistance and realizes High-permeability areas and low-permeability areas can be efficiently displaced to greatly improve the recovery factor of water drive reservoirs.
  • the viscosity self-control mechanism of the in-situ emulsification and viscosity-increasing system is as follows: 1The suspending agent and ultrafine colloidal particles in the outer water phase increase the viscosity of the water phase; 2The interfacial tension between the in-situ emulsification and viscosity-increasing system and crude oil reaches 10 -2 mN/ m order of magnitude and below, the Gibbs free energy that promotes the adsorption of the emulsifier system at the oil-water interface is very low, and it is easy to form a water external phase emulsion; 3The adsorption of the emulsifier on the surface of the ultrafine colloidal particles forms a large-scale emulsified compound , So as to realize the accumulation of the smaller-scale water external phase emulsion formed by emulsifier and crude oil and the larger-scale water external phase emulsion formed by emulsifier + ultrafine colloidal particles and
  • the in-situ emulsification viscosity-increasing system controls the viscosity of the emulsion through the above-mentioned mechanism to achieve high-efficiency displacement in high permeability areas (high water content, low oil saturation) and low permeability areas (low water content, high oil saturation).
  • the present invention has the following beneficial effects:
  • the viscosity-controllable in-situ emulsification and viscosity-increasing system is directly dissolved or dispersed with mineralized water, which is not affected by the salinity of mineralized water, has good injectability, and can stay deep in the reservoir;
  • the system Under shearing induction, the system forms a dynamically stable water-external phase emulsion with crude oil under 20-90% water-cut conditions. Under high water-cut conditions (60-80%), the viscosity of the emulsion is moderately higher than that of crude oil. In the low water content condition ( ⁇ 60%), the viscosity of the emulsion is slightly lower than the viscosity of the crude oil but significantly greater than the viscosity of the water phase, reflecting the self-control of fluidity;
  • the present invention is suitable for water drive oil reservoirs with a viscosity of less than 50 mPa ⁇ s, and covers a wide range of oil reservoirs;
  • the raw materials are purchased from the market, and the economic benefits are outstanding, which can greatly improve the recovery factor of water drive reservoirs and have very broad application prospects.
  • Figure 1 is a microscopic view of an in-situ emulsification thickening system with controllable viscosity.
  • Figure 2 is a microscopic view of an emulsion formed by an in-situ emulsification thickening system with controllable viscosity.
  • Figure 3 is the oil displacement effect diagram of the in-situ emulsification viscosity-increasing system with controllable viscosity used in water flooding reservoirs.
  • the preparation of an in-situ emulsification and viscosity-increasing system with controllable viscosity includes the following steps: According to weight percentage, prepare 99.4% mineralized water with a mineralization degree of 0.5-24 ⁇ 10 4 mg/L, and stir for 0.5-2 hours to ensure Fully dissolve and mix evenly; add 0.4% emulsifier, 0.15% ultrafine colloidal particles, 0.05% suspending agent to the prepared mineralized water, and stir for 0.5 to 3 hours to ensure that the components are fully dissolved and uniform Mix to complete the formulation of the in-situ emulsification and viscosity-increasing system with controllable viscosity.
  • Example 1 Oil-water interfacial tension of in-situ emulsification and viscosity-increasing system with controllable viscosity
  • the salinity of 0.5 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ concentration is 0.01 ⁇ 10 4 mg/L) was prepared separately, No. 1#, 3 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ The concentration is 0.1 ⁇ 10 4 mg/L) No. 2#, 5 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ concentration is 0.5 ⁇ 10 4 mg/L) No. 3#, 10 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ concentration is 1.0 ⁇ 10 4 mg/L) No. 4# and 24 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ concentration is 1.5 ⁇ 10 4 mg/L) No. 5# Of mineralized water, stir for 1 hour.
  • the interfacial tension of the viscosity-controllable in-situ emulsification and thickening system and two degassed crude oils were measured with the TX500C rotating drop interfacial tensiometer at 80°C. After 2h, a stable interfacial tension value is obtained.
  • the system can maintain the interfacial tension of oil and water at the order of 10 -2 mN/m and below under the conditions of 0.5-24 ⁇ 10 4 mg/L of mineralized water, showing excellent oil washing performance. The results are shown in Table 1.
  • Example 2 Apparent viscosity of an in-situ emulsification thickening system with controllable viscosity
  • the salinity of 0.5 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ concentration is 0.01 ⁇ 10 4 mg/L) was prepared separately, No. 1#, 3 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ The concentration is 0.1 ⁇ 10 4 mg/L) No. 2#, 5 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ concentration is 0.5 ⁇ 10 4 mg/L) No. 3#, 10 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ concentration is 1.0 ⁇ 10 4 mg/L) No. 4# and 24 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ concentration is 1.5 ⁇ 10 4 mg/L) No. 5# Of mineralized water, stir for 1 hour.
  • Salinity (10 4 mg/L) System apparent viscosity (mPa ⁇ s) 0.5 1.89 3 2.52 5 4.69 10 3.14 twenty four 1.26
  • Example 3 Viscosity of the emulsion formed by the in-situ emulsification thickening system and crude oil with controllable viscosity
  • the salinity of 0.5 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ concentration is 0.01 ⁇ 10 4 mg/L) was prepared separately, No. 1#, 3 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ The concentration is 0.1 ⁇ 10 4 mg/L) No. 2#, 5 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ concentration is 0.5 ⁇ 10 4 mg/L) No. 3#, 10 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ concentration is 1.0 ⁇ 10 4 mg/L) No. 4# and 24 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ concentration is 1.5 ⁇ 10 4 mg/L) No. 5# Of mineralized water, stir for 1 hour.
  • the viscosity controllable in-situ emulsification and viscosity-increasing system and crude oil are based on the water-oil ratio of 2:8, 3:7, 4:6, 5:5, 6:4, 7:3, 8:2, 9:1 (water-containing The rates are 20%, 30%, 40%, 50%, 60%, 70%, 80%, 90%) Configure, seal, and place in an oil bath with a magnetic stirring device; then in an oil bath at 90°C Conditions, stirring for 1 hour, observe the emulsification, after the stirring, use the high temperature and high pressure Marsher rheometer to simulate the reservoir temperature conditions to test the emulsion and crude oil, see Table 3-7.
  • the viscosity of mineralized water is 0.36 ⁇ 0.82mPa ⁇ s, and the fluidity of water and oil varies greatly.
  • the viscosity-controllable in-situ emulsification and viscosity-increasing system forms a dynamically stable water-external phase emulsion with crude oil at 20-90% water content under shear induction; the viscosity of the emulsion is crude oil under high water content conditions (60-80%) The viscosity is 1 to 1.5 times, and in the low water content condition ( ⁇ 60%), the viscosity of the emulsion is slightly lower than the viscosity of the crude oil and significantly greater than the viscosity of the water phase; it reflects the self-control performance of fluidity.
  • the emulsion droplets stabilized by colloidal particles and emulsifier molecules are larger, while the emulsion droplets stabilized by the emulsifier are smaller.
  • the co-existence of these two droplets creates a compact and stable spatial accumulation with a salinity of 5 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ concentration is 0.5 ⁇ 10 4 mg/L)
  • the particle size of an emulsion with a water content of 80% after being diluted 10 times is shown in Figure 2. Large and small emulsions Liquid can exist in a kinetically stable form.
  • Table 6 Viscosity of emulsion formed with different water-oil ratio under the condition of water salinity 10 ⁇ 10 4 mg/L
  • Table 7 Viscosity of emulsion formed with different oil-water ratio under the condition of water salinity 24 ⁇ 10 4 mg/L
  • Example 4 Improved oil recovery performance of in-situ emulsification viscosity-increasing system with controllable viscosity
  • the salinity of 5 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ concentration is 0.5 ⁇ 10 4 mg/L) was prepared separately, No. 3#, 24 ⁇ 10 4 mg/L (Ca 2+ , Mg 2+ The concentration is 1.5 ⁇ 10 4 mg/L) No. 5# mineralized water, stir for 1 hour.
  • Two artificial simulated cores 45 ⁇ 45 ⁇ 300mm long core, average porosity 20%, average gas permeability 300mD), temperature 90°C, crude oil viscosity 15.6mPa ⁇ s, average original oil-water saturation 75%, in water
  • the water-flooding crude oil recovery rate is low, and the recovery rate of crude oil with a water content of 98% is about 48%; subsequent injection in-situ emulsification increases Viscosity system (the viscosity of the in-situ emulsification and viscosity-increasing system at 90°C is 1.2 ⁇ 5.0mPa ⁇ s, the injection rate is 1.5mL/min).

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Abstract

一种黏度可控的原位乳化增黏体系，由以下组分按重量百分比组成：乳化剂0.3～1.5％，超细胶态粒子0.05～0.5％，悬浮剂0.01～0.1％，其余为矿化水。乳化剂为石油磺酸盐、石油羧酸盐、十二烷基磺酸钠、十二烷基苯磺酸钠、烷基糖苷、脂肪醇醚羧酸盐、脂肪醇醚磺酸盐、羟基磺基甜菜碱、烷醇酰胺的一种或组合。超细胶态粒子为超细二氧化硅、超细蒙脱土、超细氧化铁、超细四氧化三铁、超细氧化铝、超细二氧化钛的一种。悬浮剂为部分水解聚丙烯酰胺、直链淀粉、羧甲基壳聚糖、羟甲基纤维素、黄原胶、海藻酸钠的一种。该原位乳化增黏体系适用于黏度小于50mPa•s的水驱油藏，不受油藏温度、矿化度影响，覆盖范围十分宽广，经济效益突出，有效驱动水驱油藏的高效开发。

Description

黏度可控的原位乳化增黏体系及其在水驱油藏的应用 技术领域
本发明涉及黏度可控的原位乳化增黏体系及其在水驱油藏的应用，属油田化学和油田开采技术领域。
背景技术
注水开发的油藏，受非均质的影响，高渗区域的水驱波及程度高、剩余油饱和度低，低渗区域的水驱波及程度低、剩余油饱和度高(Liu R，Du D，Pu W，et al.Enhanced oil recovery potential of alkyl alcohol polyoxyethylene ether sulfonatesurfactants in high-temperature and high-salinity reservoirs[J].Energy&Fuels，2018，32：12128-12140)。水驱油藏乳状液的类型与含水率密切相关，在低含水率条件下易形成油外相乳状液；在高含水率条件下易形成水外相乳状液。基于乳状液粒径均匀的相体积比理论认为，当内相体积分数达到球形颗粒的最大堆积分数时，乳状液将发生突变转相(Galindo-Alvarez J，Sadtler V，Choplin L，Salager J L Viscous oil emulsification by catastrophic phase inversion：influence of oil viscosity and process conditions[J].Industrial&Engineering Chemistry Research，2011，50(9)：5575-5583)，突变转相后乳状液的黏度将发生显著改变。
乳状液的黏度与乳状液的类型密切相关，为此，国内外学者开展了广泛地研究，形成了多种判定方式，如Winsor比R值、亲油-亲水平衡值HLB、亲水亲油偏差值HLD等。Winsor比主要用于判别(天然)乳化剂的亲水亲油性。基于R与1的相对关系，乳液体系总的被分为了4类。R＜1时，乳化剂与油相的反应能小于与水相的反应能，更容易形成O/W型乳液(类型I)；当R＞1时，乳化剂与水相的反应能小于与油相的反应能，更容易形成W/O型乳液(类型II)；当R≈1时，一种可能是形成上部为有机相、下部为水相、中部为微乳液的体系(类型III)；另一种可能是形成单相的均匀体系，其中油水以双连续相或层状相的形式存在。亲水亲油偏差值是最优化配方偏差的数字表现形式。HLD值与HLB值的概念相似，但其同时考虑了乳化剂本身和体系可能发生的变化。根据HLD值的定义， 当HLD＝0是最佳配方所在点，在此条件下乳化剂从油相转移到水相所需的自由能为0。HLD＝0时，体系界面张力处于最低值，体系自发曲率为0。体系任何性质的改变，比如温度、乳化剂类型、原油性质、盐或者助乳化剂的存在都会导致体系偏离最佳值。
1903年Ramsden发现胶体尺度的固相颗粒可以稳定乳状液，1907年Pickering对固相离子稳定乳液开展了独立系统的工作，因此，对固相稳定的乳液称为Pickering乳状液。与传统的乳液相比，Pickering乳液的显著特征是不可逆的界面吸附，超强抗聚并的稳定性能，对巨型乳状液的超强稳定性能(最大能达到几个毫米)，高浓度的内相，不规则的流变性特征。乳液的尺寸和固相均匀颗粒的大小直接相关。呈胶态的黏土促使乳液形成O/W或者W/O乳液，石蜡、二氧化硅、黏土、氧化铁和聚合物胶体在界面的吸附稳定乳液，通过颗粒的网络或者界面吸附的胶体，稳定界面膜，这些受粒子的尺寸、形状、形貌、密度、浓度、表面覆盖物和润湿性影响。Masalova等利用笼状倍半硅氧烷POSSAM0275来形成高浓油包水乳状液(Masalova，I.，Tshilumbu，N.，Mamedov，E.，Kharatyan，E.，Katende，J.Stabilisation of highly concentrated water-in-oil emulsions by polyhedral oligomeric silsesquioxane nanomolecules[J].Journal of Molecular Liquids，2019，279，351-360)，其中分散相浓度大约为90％，油相为十二烷。POSSAM0275纳米分子在乳液中能够形成一种全新的界面层，这种界面层既不同于传统表面活性剂也不同于纳米颗粒在油水界面层的性质。
然而，由于油外相乳状液在相变点附近内相的堆积密度达到极限(史胜龙，王业飞，汪庐山，靳彦欣，王涛，王静.胜坨油田高温高盐油藏自发乳化驱提高采收率[J].油田化学，2015，32(2)：242-246)，乳状液的平均中值粒径最大，油外相乳状液的黏度是原油的数倍～十几倍。Kumar等(Kumar R，Dao E，Mohanty K.Heavy-oil recovery by in-situ emulsion formation[J].SPE Journal，2012，17(02)：326-334)、Alboudwarej等(Alboudwarej H，Muhammad M，Shahraki AK，Dubey S，Vreenegoor L，Saleh J M.Rheology of heavy-oil emulsions[J].SPE Production&Operations，2007，22(03)：285-293)、Tyrode等(Tyrode E，Allouche J，Choplin L，Salager J.Emulsion catastrophic inversion from abnormal to normal morphology.4. Following the emulsion viscosity during three inversion protocols and extending the critical dispersed-phase concept[J].Industrial&engineering chemistry research，2005，44(1)：67-74)分别对轻质油、普通稠油、特稠油的乳状液进行了研究，一致发现在相变点附近乳状液的黏度可达原油黏度的数倍。然而，黏度过大的乳状液在地层传播困难，导致注入压力过高，严重影响生产。另一方面，现场实践表明，由于在高渗层易形成黏度低的水外相乳状液而在低渗层易形成黏度高的油外相乳状液，反而加剧了储层的非均质性。因此，乳状液大幅度提高采收率的重要前提是在储层中黏度可控，即在高含水层形成高黏度的乳状液，提高渗流阻力，在低渗层形成低黏度的乳状液，降低储层的非均质性，以增加中、低渗层的波及系数。
发明概述
技术问题
本发明的目的在于提供黏度可控的原位乳化增黏体系，该体系具有优异的流度自控性能，原材料价廉易得，制备原理可靠，经济效益突出，能够实现高渗区域(高含水、低含油饱和度)、低渗区域(低含水、高含油饱和度)的活塞驱替，大幅度提高水驱油藏的采收率，具有广阔的工业化应用前景。
本发明的另一目的还在于提供上述黏度可控的原位乳化增黏体系在水驱油藏中的应用，该原位乳化增黏体系适用于黏度小于50mPa·s的水驱油藏，并且不受油藏温度、矿化度的影响，覆盖油藏的范围十分宽广，经济效益突出，有效驱动水驱油藏的高效开发。
问题的解决方案
技术解决方案
为达到以上技术目的，本发明采用以下技术方案。
一种黏度可控的原位乳化增黏体系，由乳化剂+超细胶态粒子+悬浮剂组成。该体系直接用水溶解或者分散，黏度略高于水相的黏度，通过注入设备泵入地层，在20～90％含水的油藏，乳化剂与超细胶态粒子产生协同作用，原位乳化剩余(残余)油形成动力学稳定的水外相乳状液；在高含水率条件(60～80％)乳状液的黏度是原油黏度的1～1.5倍，而在低含水条件(＜60％)乳状液黏度略低于 原油黏度而显著大于水相黏度，实现高渗区域、低渗区域的活塞驱替，并协同超低界面张力洗油，大幅度提高油藏条件原油黏度小于50mPa·s的水驱油藏采收率。
黏度可控的原位乳化增黏体系，包括与原油形成(超)低界面张力(10 -2mN/m数量级及以下)的乳化剂、亲水性超细胶态粒子和悬浮剂，该体系由以下组分按重量百分比组成：
乳化剂        0.3～1.5％；
超细胶态粒子  0.05～0.5％；
悬浮剂        0.01～0.1％；
其余为矿化水。
所述乳化剂为石油磺酸盐、石油羧酸盐、十二烷基磺酸钠、十二烷基苯磺酸钠、烷基糖苷、脂肪醇醚羧酸盐、脂肪醇醚磺酸盐、羟基磺基甜菜碱、烷醇酰胺的一种或组合，其油-水界面张力达到10 -2mN/m数量级及以下。
所述超细胶态粒子为超细二氧化硅、超细蒙脱土、超细氧化铁、超细四氧化三铁、超细氧化铝、超细二氧化钛的一种，这里的超细是指胶态粒子的粒径为10nm～1.0μm。
所述悬浮剂为部分水解聚丙烯酰胺、直链淀粉、羧甲基壳聚糖、羟甲基纤维素、黄原胶、海藻酸钠的一种。
上述物质均为市售。
所述黏度可控的原位乳化增黏体系，以重量百分比计，所述乳化剂优选为0.4％，所述超细胶态粒子优选为0.15％，所述悬浮剂优选为0.05％，其余为矿化水。
所述黏度可控的原位乳化增黏体系在水驱油藏中的应用，该油藏的性质如下：温度最高达140℃，水的矿化度最高达24×10 4mg/L，地层原油黏度小于50mPa·s的水驱油藏。
本发明所提供的黏度可控的原位乳化增黏体系直接用矿化水溶解或者分散，黏度略高于矿化水黏度，注入性好；在20～90％含水条件与原油原位生成动力学稳定的水外相乳状液，在高含水率条件(60～80％)乳状液的黏度是原油黏度的1～1.5倍，而在低含水条件(＜60％)乳状液黏度略低于原油黏度而显著大于水相 黏度，体现流度的自控性能：在高渗区域形成黏度高的水外相乳状液提高渗流阻力，而在低渗区域形成黏度较低的水外相乳状液降低排驱阻力，实现高渗区域、低渗区域的高效驱替，大幅度提高水驱油藏的采收率。
原位乳化增黏体系的黏度自控机理为：①水外相中的悬浮剂与超细胶态粒子均增加水相的黏度；②原位乳化增黏体系与原油的界面张力达到10 -2mN/m数量级及以下，促使乳化剂体系在油-水界面吸附的吉布斯自由能很低，极易形成水外相乳状液；③乳化剂在超细胶态粒子表面的吸附形成大尺度乳化复合物，从而实现乳化剂与原油形成的较小尺度水外相乳状液与乳化剂+超细胶态粒子与原油形成的较大尺度的水外相乳状液在三维空间的堆积。原位乳化增黏体系通过上述机理对乳状液黏度控制，实现高渗区域(高含水、低含油饱和度)、低渗区域(低含水、高含油饱和度)的高效驱替。
发明的有益效果
有益效果
与现有技术相比，本发明具有以下有益效果：
(1)黏度可控原位乳化增黏体系直接用矿化水溶解或者分散，不受矿化水矿化度的影响，注入性好，能在油藏深部驻留；
(2)黏度可控原位乳化增黏体系与原油的界面张力达10 -2mN/m数量级及以下；
(3)该体系在剪切诱导下与原油在20～90％含水条件形成动力学稳定的水外相乳状液，在高含水率条件(60～80％)乳状液的黏度适度高于原油黏度，而在低含水条件(＜60％)乳状液黏度略低于原油黏度而显著大于水相黏度，体现流度自控性；
(4)本发明适用于黏度小于50mPa·s的水驱油藏，覆盖油藏的范围十分宽广；
原材料均从市场购买，经济效益突出，能够大幅度提高水驱油藏的采收率，应用前景非常广阔。
对附图的简要说明
附图说明
图1为黏度可控的原位乳化增黏体系微观图。
图2为黏度可控的原位乳化增黏体系形成乳状液的微观图。
图3为黏度可控原位乳化增黏体系用于水驱油藏的驱油效果图。
发明实施例
本发明的实施方式
下面根据附图和实例进一步说明本发明，以便于本技术领域的技术人员理解本发明。但应该清楚，本发明不限于具体实施方式的范围，对本技术领域的普通技术人员来讲，只要各种变化在所附的权利要求限定和确定的本发明的精神和范围内，均在保护之列。
除非另有指明，本文使用的所有技术和科学术语具有与本申请所属技术领域的普通技术人员通常理解的相同含义。
黏度可控的原位乳化增黏体系的配制，包括如下步骤：按重量百分比计，配制99.4％矿化度为0.5～24×10 4mg/L的矿化水，搅拌0.5～2小时，确保充分溶解并混合均匀；向所配制的矿化水中依次加入0.4％的乳化剂，0.15％的超细胶态粒子，0.05％的悬浮剂，搅拌0.5～3小时，确保各组分充分溶解并均匀混合，完成黏度可控原位乳化增黏体系的配制。
实施例1黏度可控的原位乳化增黏体系的油水界面张力
分别配制矿化度为0.5×10 4mg/L(Ca 2+、Mg 2+浓度为0.01×10 4mg/L)编号1#，3×10 4mg/L(Ca 2+、Mg 2+浓度为0.1×10 4mg/L)编号2#，5×10 4mg/L(Ca 2+、Mg 2+浓度为0.5×10 4mg/L)编号3#，10×10 4mg/L(Ca 2+、Mg 2+浓度为1.0×10 4mg/L)编号4#及24×10 4mg/L(Ca 2+、Mg 2+浓度为1.5×10 4mg/L)编号5#的矿化水，搅拌1小时。在1#中依次加入0.2％的石油磺酸钠、0.2％的十二烷基磺酸钠，0.15％的超细二氧化硅，0.05％的部分水解聚丙烯酰胺；在2#中依次加入0.2％的脂肪醇醚羧酸钠、0.2％的十二烷基苯磺酸钠，0.15％的超细蒙脱土，0.05％的羟甲基纤维素；在3#中依次加入0.4％的十二烷基羟基磺基甜菜碱，0.15％的超细氧化铁，0.05％的黄原胶；在4#中依次加入0.4％的烷醇酰胺，0.15％超细四氧化三铁，0.05％的海藻酸钠；在5#中依次加入0.4％的C12/C14烷基糖苷，0.15％超细二氧化钛，0.05％的羧甲基壳聚糖；搅拌1.5小时，获得黏度可控的原位 乳化增黏体系。
在80℃条件用TX500C旋转滴界面张力仪测定黏度可控原位乳化增黏体系与两种脱气原油(80℃条件的黏度分别为10.3mPa·s，21.2mPa·s)的界面张力，测定时间2h，获得稳定的界面张力值。该体系在0.5～24×10 4mg/L的矿化水条件，均能使油水的界面张力保持为10 -2mN/m数量级及以下，表现为优异的洗油性能，结果见表1。
表1黏度可控原位乳化增黏体系与原油的稳定界面张力
Figure PCTCN2019098263-appb-000001
实施例2黏度可控的原位乳化增黏体系的表观黏度
分别配制矿化度为0.5×10 4mg/L(Ca 2+、Mg 2+浓度为0.01×10 4mg/L)编号1#，3×10 4mg/L(Ca 2+、Mg 2+浓度为0.1×10 4mg/L)编号2#，5×10 4mg/L(Ca 2+、Mg 2+浓度为0.5×10 4mg/L)编号3#，10×10 4mg/L(Ca 2+、Mg 2+浓度为1.0×10 4mg/L)编号4#及24×10 4mg/L(Ca 2+、Mg 2+浓度为1.5×10 4mg/L)编号5#的矿化水，搅拌1小时。在1#中依次加入0.2％的脂肪醇醚羧酸钠、0.2％的十二烷基磺酸钠，0.15％的超细蒙脱土，0.05％的直链淀粉；在2#中依次加入0.2％的脂肪醇醚磺酸钠、0.2％的十二烷基苯磺酸钠，0.15％的超细四氧化三铁，0.05％的海藻酸钠；在3#中依次加入0.4％的烷醇酰胺，0.15％的超细氧化铁，0.05％的羟甲基纤维素；在4#中依次加入0.4％的十二烷基羟基磺基甜菜碱，0.15％超细二氧化钛，0.05％的黄原胶；在5#中依次加入0.2％的C12/C14烷基糖苷、0.2％的烷醇酰胺，0.15％超细二氧化硅，0.05％的羧甲基壳聚糖；搅拌1.5小时，获得黏度可控的原位乳化增黏体系。
用光学显微镜观察5#的溶液可知超细胶态粒子均匀分散在液相中，如图1所示。黏度可控的原位乳化增黏体系在90℃条件用高温高压哈克流变仪测试表观黏度(剪切速率7.34s -1)；0.5～24×10 4mg/L矿化水在90℃的黏度为0.3～0.8mPa·s；黏度可控原位乳化增黏体系在0.5～24×10 4mg/L矿化水条件的表观黏度为1.2～5.0mPa·s(见表2)，结果表明黏度可控原位乳化增黏体系在地层中有良好的注入性。
表2黏度可控原位乳化增黏体系的表观黏度(90℃)
[Table 1]
矿化度(10 4mg/L) 体系表观黏度(mPa·s)
0.5 1.89
3 2.52
5 4.69
10 3.14
24 1.26
实施例3黏度可控原位乳化增黏体系与原油形成乳状液的黏度
分别配制矿化度为0.5×10 4mg/L(Ca 2+、Mg 2+浓度为0.01×10 4mg/L)编号1#，3×10 4mg/L(Ca 2+、Mg 2+浓度为0.1×10 4mg/L)编号2#，5×10 4mg/L(Ca 2+、Mg 2+浓度为0.5×10 4mg/L)编号3#，10×10 4mg/L(Ca 2+、Mg 2+浓度为1.0×10 4mg/L)编号4#及24×10 4mg/L(Ca 2+、Mg 2+浓度为1.5×10 4mg/L)编号5#的矿化水，搅拌1小时。在1#中依次加入0.4％的石油羧酸钠，0.15％的超细蒙脱土，0.05％的直链淀粉；在2#中依次加入0.4％的脂肪醇醚磺酸钠，0.15％的超细二氧化硅，0.05％的羟甲基纤维素；在3#中依次加入0.4％的十二烷基羟基磺基甜菜碱，0.15％的超细氧化铁，0.05％的海藻酸钠；在4#中依次加入0.4％的烷醇酰胺，0.15％超细二氧化钛，0.05％的黄原胶；在5#中依次加入0.4％的C12/C14烷基糖苷，0.15％超细四氧化三铁，0.05％的羧甲基壳聚糖；搅拌1.5小时，获得黏度可控的原位乳化增黏体系。
将黏度可控原位乳化增黏体系和原油按水油比为2∶8、3∶7、4∶6、5∶5、6∶4、7∶3、8∶2、9∶1(含水率依次为20％、30％、40％、50％、60％、70％、80％、90％) 配置、密封，放置在带有磁力搅拌装置的油浴锅中；然后在90℃油浴条件，搅拌1h，观察乳化情况，搅拌结束后，用高温高压哈克流变仪模拟油藏温度条件测试乳状液和原油，见表3-7。
在油藏温度条件下(45～140℃)，矿化水的黏度0.36～0.82mPa·s，水油流度差异大。黏度可控原位乳化增黏体系在剪切诱导下与原油在20～90％含水条件形成动力学稳定的水外相乳状液；在高含水率条件(60～80％)乳状液的黏度是原油黏度的1～1.5倍，而在低含水条件(＜60％)乳状液黏度略低于原油黏度而显著大于水相黏度；体现流度的自控性能。胶态粒子与乳化剂分子稳定的乳状液液滴较大，而乳化剂稳定的乳状液液滴较小，这两种液滴的同时存在，构建了紧密稳定的空间堆积，矿化度为5×10 4mg/L(Ca 2+、Mg 2+浓度为0.5×10 4mg/L)含水率为80％的乳状液经过稀释10倍后的粒径如图2所示，大、小乳状液能以动力学稳定的形式存在。
表3水矿化度0.5×10 4mg/L条件不同水油比形成乳状液的黏度
Figure PCTCN2019098263-appb-000002
表4水矿化度3×10 4mg/L条件不同水油比形成乳状液的黏度
Figure PCTCN2019098263-appb-000003
表5水矿化度5×10 4mg/L条件不同水油比形成乳状液的黏度
Figure PCTCN2019098263-appb-000004
表6水矿化度10×10 4mg/L条件不同水油比形成乳状液的黏度
Figure PCTCN2019098263-appb-000005
表7水矿化度24×10 4mg/L条件不同油水比形成乳状液的黏度
Figure PCTCN2019098263-appb-000006
实施例4黏度可控原位乳化增黏体系的提高采收率性能
分别配制矿化度为5×10 4mg/L(Ca 2+、Mg 2+浓度为0.5×10 4mg/L)编号3#，24×10 4mg/L(Ca 2+、Mg 2+浓度为1.5×10 4mg/L)编号5#的矿化水，搅拌1小时。在3#中依次加入0.4％的十二烷基羟基磺基甜菜碱，0.15％的超细氧化铁，0.05％的羟甲基纤维素；在5#中依次加入0.2％的C12/C14烷基糖苷、0.2％的烷醇酰胺，0.15％超细二氧化硅，0.05％的羧甲基壳聚糖；搅拌1.5小时，获得黏度可控的原位乳化增黏体系。
人造模拟岩心两根(45×45×300mm长岩心，平均孔隙度20％，平均气测渗透率300mD)，温度90℃，原油黏度15.6mPa·s，平均原始含油水饱和度75％，在水驱阶段(水驱速度1.5mL/min)，受到不利的水油流度比，水驱的原油采出程度低，含水率98％的原油采收率为48％左右；随后注入原位乳化增黏体系(90℃原位乳化增黏体系的黏度1.2～5.0mPa·s，注入速度1.5mL/min)，在体系注入过程中注入压力升高、含水率降低，重新出油，在岩心的出口端用观察到明显的水外相乳状液，证明原位乳化增黏体系与原油原位乳化，显著改善驱替介质的流度，同时乳状液的贾敏效应改善了岩心的非均质性，增强驱替液的波及体积，从而显著提高原油采收率33％左右，累计采收率达80％以上。
原位乳化增黏体系在超高矿度(24×10 4mg/L，其中Ca 2+、Mg 2+浓度为1.5×10 4mg/L)高温(90℃)条件的驱替效果见图3。

Claims (6)

  1. 黏度可控的原位乳化增黏体系，包括与原油形成(超)低界面张力10 -2mN/m数量级及以下的乳化剂、亲水性超细胶态粒子和悬浮剂，该体系由以下组分按重量百分比组成：
    乳化剂    0.3～1.5％；
    超细胶态粒子    0.05～0.5％；
    悬浮剂   0.01～0.1％；
    其余为矿化水。
  2. 如权利要求1所述的黏度可控的原位乳化增黏体系，其特征在于，所述乳化剂为石油磺酸盐、石油羧酸盐、十二烷基磺酸钠、十二烷基苯磺酸钠、烷基糖苷、脂肪醇醚羧酸盐、脂肪醇醚磺酸盐、羟基磺基甜菜碱、烷醇酰胺的一种或组合。
  3. 如权利要求1所述的黏度可控的原位乳化增黏体系，其特征在于，所述超细胶态粒子为超细二氧化硅、超细蒙脱土、超细氧化铁、超细四氧化三铁、超细氧化铝、超细二氧化钛的一种。
  4. 如权利要求3所述的黏度可控的原位乳化增黏体系，其特征在于，所述超细胶态粒子的粒径为10nm～1.0μm。
  5. 如权利要求1所述的黏度可控的原位乳化增黏体系，其特征在于，所述悬浮剂为部分水解聚丙烯酰胺、直链淀粉、羧甲基壳聚糖、羟甲基纤维素、黄原胶、海藻酸钠的一种。
  6. 如权利要求1、2、3、4或5所述的黏度可控的原位乳化增黏体系在水驱油藏中的应用，该油藏为温度最高达140℃，水的矿化度最高达24×10 4mg/L，地层原油黏度小于50mPa·s的水驱油藏。
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