In-situ emulsification tackifying system with high phase transformation point and application in water-drive reservoirs

A phase transition point, in-situ technology, applied in the fields of production fluids, drilling compositions, chemical instruments and methods, etc., can solve the problems of difficult formation propagation, high injection pressure, affecting production, etc., and achieve outstanding economic benefits and injection. Good performance, and the effect of improving oil recovery

Active Publication Date: 2019-08-02
BEIJING GEPETTO OIL TECH
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  • Summary
  • Abstract
  • Description
  • Claims
  • Application Information

AI Technical Summary

Problems solved by technology

However, the viscosity of the Pickering emulsion is generally relatively high, especially for heavy oil reservoirs. The viscosity of the Picking emulsion in the oil external phase can reach several times to ten times the viscosity of crude oil (Uma A, Saaid I, Sulaimon A, et al. al.A review

Method used

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  • In-situ emulsification tackifying system with high phase transformation point and application in water-drive reservoirs
  • In-situ emulsification tackifying system with high phase transformation point and application in water-drive reservoirs
  • In-situ emulsification tackifying system with high phase transformation point and application in water-drive reservoirs

Examples

Experimental program
Comparison scheme
Effect test

Example Embodiment

[0033] Example 1 Oil-water interfacial tension of in-situ emulsification thickening system with high phase transition point

[0034] Table 1 The stable interfacial tension of in-situ emulsification system with high phase transition point and crude oil

[0035] Salinity (10 4 mg / L)

[0036] Respectively prepare total salinity of 0.1×10 4 mg / L number①, 1.0×10 4 mg / L number②,10×10 4 mg / L number ③, 20×10 4 mg / L mineralized water number ④ (①~④ medium Ca 2+ , Mg 2+ The mass concentration of is 5.0% of the total salinity), stirring for 1.5 hours. Add 0.25% petroleum sulfonate, 0.45% propylene glycol monostearate, 0.05% liquid paraffin, 0.05% carboxymethyl-β-cyclodextrin in ①; add 0.25% in ② Cocamidopropyl betaine, 0.45% polyoxyethylene sorbitan monostearate, 0.05% graphite powder, 0.05% chitosan quaternary ammonium salt; add 0.25% fatty alcohol ether in ③ Sulfonate, 0.45% oleic acid diethanolamide, 0.05% graphite powder, 0.05% xanthan gum; add 0.25% alkanolamide, 0.45% dodecylamine, 0...

Example Embodiment

[0038] Example 2 Viscosity of in-situ emulsification thickening system containing high phase transition point and crude oil to form emulsion

[0039] Respectively prepare total salinity of 0.1×10 4 mg / L number①, 1.0×10 4 mg / L number②,10×10 4 mg / L number ③, 20×10 4 mg / L mineralized water number ④ (①~④ medium Ca 2+ , Mg 2+ The mass concentration of is 5.0% of the total salinity), stirring for 1.5 hours. Add 0.25% petroleum sulfonate, 0.45% propylene glycol monostearate, 0.05% liquid paraffin, 0.05% carboxymethyl-β-cyclodextrin in ①; add 0.25% in ② Cocamidopropyl betaine, 0.45% polyoxyethylene sorbitan monostearate, 0.05% graphite powder, 0.05% chitosan quaternary ammonium salt; add 0.25% fatty alcohol ether in ③ Sulfonate, 0.45% oleic acid diethanolamide, 0.05% graphite powder, 0.05% xanthan gum; add 0.25% alkanolamide, 0.45% octadecyl primary amine, 0.05% in ④. Cage polysilsesquioxane, 0.05% guar gum; stirring for 2.0 hours to obtain an in-situ emulsification and viscosity-increa...

Example Embodiment

[0049] Example 3 Enhanced oil recovery performance of in-situ emulsification viscosity-increasing system with high phase transition point

[0050] The formulated salinity is 20×10 4 mg / L(Ca 2+ , Mg 2+ The mass concentration is 5.0% of the total salinity) of mineralized water, stirred for 1 hour, followed by adding 0.25% alkanolamide, 0.15% octadecyl primary amine, 0.30% oleic acid diethanolamide, 0.05 % Cage polysilsesquioxane, 0.05% xanthan gum; stirred for 2.0 hours to obtain an in-situ emulsified viscosity-increasing system with high phase transition point. Artificial simulated core (45×45×300mm long core, porosity 25%, gas permeability 2000mD), temperature 90℃, crude oil viscosity 60.8mPa·s, original oil saturation 72%, in the water drive stage (water drive speed 2.0mL / min). Affected by the unfavorable water-to-oil mobility ratio, the recovery of crude oil by water flooding is low, and the recovery rate with a water cut of 98% is about 40%; subsequent injection with a high ph...

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Abstract

The invention discloses an in-situ emulsification tackifying system with a high phase transformation point. The system is prepared from components in percentage by weight as follows: 0.2%-0.5% of a water-soluble surfactant, 0.2%-1.5% of an oil-soluble surfactant, 0.02%-0.5% of lipophilic colloidal particles, 0.02%-0.2% of a carrying agent and the balance of mineralized water. The water-soluble surfactant is one of or a combination of petroleum sulfonate, cocamidopropyl betaine, fatty alcohol ether sulfonate, alkanolamide and alkyl glycoside; the oil-soluble surfactant is one of or a combination of propylene glycol monostearate, fatty glyceride, polyoxyethylene sorbitan monostearate, polyoxyethylene fatty alcohol ether, oleic diethanolamide, dodecylamine, octadecyl primary amine, sodium oleate and petroleum acid; the lipophilic colloidal particles are one of liquid paraffin, graphite powder and polyhedral oligomeric silsesquioxane; the carrying agent is one of carboxymethyl-beta-cyclodextrin, chitosan quaternary ammonium salt, chitosan hydrochloride, xanthan gum and guar gum. The system is used for water-drive reservoirs and can significantly improve the development effect of water-drive heavy oil reservoirs.

Description

technical field [0001] The invention relates to an in-situ emulsification viscosity-increasing system containing a high phase transition point and its application in water flooding reservoirs, belonging to the technical fields of oilfield chemistry and water flooding improvement. Background technique [0002] For reservoirs developed by water flooding, the mobility of water and oil differs greatly during water flooding development, and viscous fingering is easily formed at the flooding front, resulting in low water flooding efficiency and high degree of remaining oil saturation. The polymer flooding technology based on mobility control has developed rapidly and has become the second largest technology in the world for enhanced oil recovery (EOR) (Koottungal L.2014 Worldwide EOR Survey[J].Oil and Gas Journal,2014,112(4) :79-91). China is the country with the widest range of chemical flooding applications. The oil production of chemical flooding is about 10.1% of China's tota...

Claims

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Application Information

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IPC IPC(8): C09K8/584
CPCC09K8/584E21B43/26
Inventor 蒲万芬刘锐庞诗师孙琳杜代军芶瑞李科星
Owner BEIJING GEPETTO OIL TECH
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