244results about How to "Change wettability" patented technology

The use of poly(oxyethylene)-poly(oxybutylene) block copolymers in pharmaceutical compositions useful for modifying the surfaces of contact lenses and other medical devices is disclosed. The present invention is based in-part on a discovery that this class of compounds is particularly efficient in wetting hydrophobic surfaces, such as the surfaces of silicone hydrogel contact lenses and other types of ophthalmic lenses. Such compounds are also useful for cleaning purposes. The use of the compounds as surfactants in various types of compositions for treating contact lenses therefore represents a preferred embodiment of the present invention.

The invention provides a fracturing method for supplementing stratum energy of dense oil reservoir. The method includes the steps that in combination with characteristics of the dense oil reservoir, characteristics of non-darcy seepage are considered, and CMG oil reservoir value simulation software is utilized to simulate and calculate a discharge area controlled by a single fracture under the modes of subdivision cutting and a complex fracture net with the starting pressure gradient considered; in combination with a fracture spacing chemical interference theory, the horizontal well improvement segment spacing improved by dense oil reservoir size fracturing, cluster spacing and perforating parameters are optimized; the dense oil reservoir transformation parameter is determined through a non-darcy seepage equation and the CMG oil reservoir value simulation software; the ram material composition of fracturing liquid is determined according to the wettability and sensitivity of the reservoir; the fracturing liquid and a propping agent are poured, the flow velocity of the eyelet of a single liquid suction and injection hole of the fracturing liquid is 0.25 m<3>/min-0.4 m<3>/min, and the pouring intensity is 10 m<3>/min-15 m<3>/min; the well closing time is determined through the CMG oil reservoir value simulation software, a well is closed according to the determined well closing time, and the fracturing method integrates pressing, pouring, driving and exploiting.

Of the many embodiments provided herein, one embodiment includes a method comprising: providing a drilling fluid comprising: an aqueous fluid; and a surfactant; and drilling a well bore in a subterranean formation comprising an oleaginous fluid using the drilling fluid, wherein the surfactant forms a micelle within the well bore; and removing an oil block in the formation.

The invention discloses a hydraulic power pulse oil displacement experimental facility and an experimental method thereof. The experimental facility comprises a core clamping device, an annular pressure supply device, a hydraulic power pulse wave generating device, a water storage tank and an oil storage tank which are connected with the liquid inlet of the core clamping device by virtue of a water pipeline and an oil pipeline as well as a liquid container which is connected with the liquid outlet of the core clamping device; wherein the water pipeline and the oil pipeline are all provided with an intermediate container, a pumping device used for generating high pressure liquid flow and an energy storage tank. The experimental method includes the following steps: firstly, oil displacementexperiment is carried out under the condition that no hydraulic power pulse is added; secondly, oil displacement experiment is carried out while frequency and amplitude hydraulic power pulse wave of core are replaced, and meanwhile hydraulic power pulse auxiliary chemical oil displacement experiment is completed; thirdly, data processing is carried out. The invention has reasonable design, mounting convenience, simple operation and good simulation effect, can improve efficiency of oil displacement by water and crude oil recovery ratio, and experiment of hydraulic pulse wave oil displacement and hydraulic pulse wave auxiliary reservoir core oil displacement by water can be realized.

The invention relates to a pressure-reducing and injection-increasing agent for a water injection well of a low-permeability oilfield, and a preparation method and application thereof. The pressure-reducing and injection-increasing agent is prepared from the following components by weight: 2.0 to 6.5% of a multifunctional surface treating agent, 0.75 to 3.15% of hydrophobic nanometer silica or nanometer poly-silicon and 2 to 8% of a pH conditioning agent, with the balance being deionized water, wherein the multifunctional surface treating agent comprises, by weight, 30 to 80% of a nonionic surfactant, 2 to 25% of an anionic surfactant and 10 to 50% of an ampholytic surfactant. The pressure-reducing and injection-increasing agent is free of pollution to strata and can overcome the problems of high water injection pressure, unqualified injection allocation of a water injection rate and a short action period of injection increase in the later stage of development. The preparation method is simple in process, free of emission of pollutants and easy for industrial large-scale production.

The invention provides an amphiphilic Janus nano particle and a preparation method and application thereof. The preparation method comprises the following steps: dispersing silicon dioxide nanoparticles in water to obtain a dispersion liquid, mixing the dispersion liquid and liquid paraffin, heating and stirring in a water bath to form a Pickering emulsion, cooling to obtain small wax balls, adding a silane coupling agent into the small wax balls for modification to obtain modified small wax balls, mixing the modified small wax balls, an amidation catalyst and C12-C18 saturated fatty acid, andcarrying out an amidation reaction process to obtain organic hydrophobic chain grafted oil-water amphiphilic nanoparticles, and removing paraffin in the organic hydrophobic chain grafted oil-water amphiphilic nanoparticles to obtain the amphiphilic Janus nano particles. When the surfactant is used as an oil-displacing agent, oil-water interfacial tension can be effectively reduced at low concentration, rock wettability is changed, oil-displacing efficiency of nanofluid is remarkably improved, economic cost is reduced, and the surfactant has a wide application prospect.

The invention discloses a fracturing prepad fluid, comprising the following ingredients: 1-10 wt% of biological enzyme, 0.1-1 wt% of clay stabilizing agent, 0.01-0.1 wt% of fluorocarbon surfactant, 0.01-0.5 wt% of wettability reversal agent, 0.01-1 wt% of composite activator, and the balance of water. The fracturing prepad fluid disclosed herein not only overcomes the disadvantages of routine prepad fluids and has the advantage of fracture forming of routine prepad fluids, but also has the effects of peeling off residual oil on the surface of a rock core, cleaning and unblocking oil gas seepage channels, reducing the viscosity of crude oil, changing the wetability of the rock core, reducing the surface and interfacial tension to benefit for flowback, and preventing the clay from expansionand migration, and the like. The more the fracturing prepad fluid enters a reservoir, the larger the spread range is, and the larger the action scopes of the fracturing prepad fluid on cleaning and unblocking of the oil gas seepage channels are. The fracturing prepad fluid is beneficial for increasing the oil gas yield.

The invention provides a gel composition and a nitrogen-foamed gel composite temporary plugging agent containing the same. The gel composition comprises the following components in percentage by mass: 1.0% of partially hydrolyzed polyacrylamide, 1.5% of formaldehyde, 0.5% of hydroquinone and the balance of water. The nitrogen-foamed gel composite temporary plugging agent comprises nitrogen and foamed gel, wherein the foamed gel is a mixture of the gel composition and a high-temperature-resistant foaming agent; and the volume ratio of the nitrogen to the foamed gel is (40-60):1. The invention also provides a coupled internal/external swirl foam generator which can be used as a facility for preparing the nitrogen-foamed gel composite temporary plugging agent. The invention also provides a method for inhibiting high-throughput-frequency well steam channeling interference of thick oil, which has the characteristics of small formation damage, strong selectivity for measures and the like and has the effect of gas energization.

The invention provides a slick-water fracturing fluid with high imbibition efficiency. The slick-water fracturing fluid comprises the following components in percentages by weight: 0.08 to 0.1% of a slick-water drag-reducing agent, 0.3 to 0.5% of a surfactant, 0.1 to 0.3% of hydrophilic nanoparticles and 0.3 to 0.5% of a clay stabilizer, with the balance being water. According to the invention, the surfactant and the hydrophilic nanoparticles are utilized to change wetting performance of a reservoir, so the slick-water fracturing fluid entering a well can enter fine pore channels of matrix rock through spontaneous imbibition after breaking of a gel under the driving of capillary force; and crude oil is gradually collected into large pore channels and main fractured fractures through oil-water displacement, so the dual purposes of supplementing stratum energy and improving the yield of an oil well are realized. The slick-water fracturing fluid provided by the invention can increase theimbibition efficiency of a gel breaking fluid of the slick-water fracturing fluid, thereby finally improving recovery efficiency.

The invention relates to a method for increasing the success rate of chemical plugging of a leaking casing damage well. A casing pipe horizontal pushing method and a three-slug theory are adopted for the casing damage well with a casing damage part located within 1,000 m, wherein the front section is a washing slug, formation water is replaced, oil dirt and corrosive products on the outer wall of a casing pipe are washed, the wettability is changed, and a good gelling environment is provided for a plugging slug; the middle plugging stratum is a main body cementing section and can effectively prevent leaking and plug the stratum, and a pressure bearing section can be built to isolate the formation water from the casing pipe; the tail section is an intermittent replacement slug, multiple times of replacement are performed intermittently, the main body cementing section can be checked and improved, the plugging success rate is increased, and the validity is prolonged.

The invention relates to an active water oil displacement method used for low permeability reservoirs, in particular to a strengthened oil displacement method, and mainly solves the problem of low efficiency of oil displacement of the low permeability reservoirs in the prior art. According to the oil displacement method, a positive-negative system surfactant containing a 0.01-1.0wt% anionic-nonionic surfactant and a cationic surfactant in a molar ratio of 1:0.01-0.99 is injected into a water solution to form active water, dehydrated crude is enabled to be in contact with the active water under the condition of injected water at the oil displacement temperature of 40-100 DEG C with total mineralization (total dissolved solid) TDS more than 200mg/L, and crude in the core is displaced sufficiently. The problem is well solved, and the strengthened oil displacement method can be applied to tertiary recovery production of the low permeability reservoirs.

The invention discloses a testing device for the vertical bonding strength of ice layers on the surface of a material and a testing method thereof. The method comprises the following steps: firstly preparing the ice layers with equal volume and equal contact area by utilizing a conical drum in the testing device, and then peeling the ice layers by utilizing a drawing device to lift the conical drum; reading the maximum normal force in the peeling process and representing the vertical bonding strength of the ice layers on the surface of the material by utilizing the ratio of the maximum normal force to the contact area of the ice layers and a sample. The testing device and the testing method disclosed by the invention can be used for testing the vertical bonding strength of the ice layers on the surfaces of multiple materials, coating layers and natural organisms and on the surface of a special wettability sample, provides a simple and effective evaluation method and means for material and coating-layer selection and the surface modification technology in engineering and also provides a good representation means for scientific research simultaneously.

The invention relates to a chemical agent used in the exploitation process of thickened oil, in particular to a viscosity-reducing oil-displacing agent for water drive thickened oil and with effects of changing reservoir wettability and permeation depolymerization. The permeable modified viscosity-reducing oil-displacing agent is formed by performing free radical polymerization on 2-acrylic amide-2-methylpropanesulfonic acid and allyl alcohol polyoxyethylene ether in water, wherein the molar ratio of the 2-acrylic amide-2-methylpropanesulfonic acid to the allyl alcohol polyoxyethylene ether is1:(0.1-7), preferably 1:1.5. The molecular weight of the permeable modified viscosity-reducing oil-displacing agent is 8000 to 100000 g/mol. The viscosity reducer can resist mineralization degree of50000, can resist temperature of 150 DEG C, can adapt to a water drive thickened oil reservoir with the viscosity of 500 to 5000 mPa*s; and when the use concentration is 500 ppm, the viscosity of thethickened oil can be reduced to be less than 100 mPa*s. Therefore, the permeable modified viscosity-reducing oil-displacing agent can be widely applied to development of the water drive thickened oil.

Disclosed is a three-in-one composite profile control and displacement process used for oilfield deep profile control. The process includes that injecting a prepared liquid polymer microsphere solution, then injecting a three-adoption oil displacing agent solution, and finally injecting two-fluid process profile control agent, wherein liquid polymer microspheres selectively enter strata, expand when encountering water and play a role in deep sealing, the oil displacing agent can facilitate expansion of the liquid polymer microspheres and can play a role in oil displacement, and the two-fluid process profile control technology plays a role in sealing and improving profile control strength. Through combining of three products, deep profile control and sweeping area increase can be realized, and crude oil recovery efficiency can be effectively improved.

The invention provides a coated proppant used for unconventional reservoir hydraulic fracturing as well as preparation and application of the coated proppant. The proppant comprises the following components: A, particles with an amount of 70-99.99% based on a total weight of the proppant, and B, a nanoparticle-reinforced composite material coating layer which coats the surfaces of the particles and accounts for 0.01-30% of the total weight of the proppant, wherein the nanoparticle reinforced composite material comprises nanoparticles and a composite material. According to the coated proppant and preparation provided by the invention, nanoparticles are added into resin and polymer powder for reinforcement, so that affinity between the proppant coating film and aggregate is better, adhesionbetween the aggregate and the coating film is stronger, and the coated proppant has an intact surface and high sphericity after film coating.

The invention belongs to a fracturing fluid additive, and in particular relates to a formulation of a gas-well water-lock damage treating agent. The formulation is characterized in that the treating agent is formed by matching the following components in weight percentage: 20.0 to 25.0 percent of benzyltributylammonium bromide or benzyltributylammonium chloride as a main agent, 2.0 to 5.0 percent of polyoxyethylene nonyl phenyl ether or sucrose fatty acid ester as nonionic surfactant, 0.5 to 1.0 percent of SR18Y fluorocarbon surfactant produced by Shaanxi Senrui Science and Technology Co., Ltd, 12.0 to 15.0 percent of dodecyl benzyl dimethyl ammonium chloride or hexadecyl trimethyl ammonium bromide as cationic surfactant, and the balance being distilled water. The gas-well water-lock damage treating agent prepared according to the formulation has the advantages of reducing gas-well water-lock damage, lowering starting pressure, improving the gas phase permeability of rock cores and protecting reservoirs.

The invention discloses an oil-based mud flushing fluid suitable for high temperature high salt environment and a preparation method of the oil-based mud flushing fluid. The oil-based mud flushing fluid comprises the following components based on 100 parts by weight: 35-40 parts of inorganic salt CaCl2, 2.5-3.5 parts of ionic surfactant, 2.5-3.89 parts of nonionic surfactant, and the balance of clear water; the nonionic surfactant is a mixture of C12EO4 and C12EO23 in a lauric alcohol ethoxylate nonionic surfactant in a weight ratio of 2: 3-3: 2; the preparation method comprises the following steps: mixing above components; heating to 80 DEG.C under stirring, uniformly mixing, naturally cooling to room temperature to obtain the oil-based mud flushing fluid. The prepared oil-based mud flushing fluid is suitable for high temperature and high salt environments and other severe rugged environments, capable of effectively changing wettability of sleeve wall and well wall interface, the contact angle after flushing is less than 27 DEG, the flushing efficiency is more than 95%, the preparation is simple, the cost is low, and the environment-friendly and various industrial requirements are satisfied.

The invention relates to active mixed acid plugging removal solution applicable to a low permeability reservoir and mainly solves the problems of short period of validity and poor plugging removal and augmented injection effects when conventional mud acid and composite acid methods are adopted for plugging removal treatment on low permeability formation. The active mixed acid plugging removal solution consists of the following components in proportions according to weight percent: 9-10% of acetic acid, 5-7% of formic acid, 2%-3% of bifluorid acid ammonium, 2%-4% of boric acid, 1.0-2.0% of corrosion inhibitor, 2.0-4.0% of mutual solvent, 2.0% of clay stabilizer, 0.5-1.0% of dewetting active agent and 67.0-76.5% of water. The active mixed acid plugging removal solution applicable to the low permeability reservoir can delay the reaction rate of acid rock, increase the effective operating distance of acid solution, and realize the acidification of deep formation, and simultaneously can improve the oil and water seepage characteristics and increase the water phase permeability.

The invention discloses a composite nanometer SiO<2> pressure-lowering and injection-augmenting agent and a preparation method thereof and belongs to the technical field of improvement of the crude oil recovery ratio in the oilfield waterflood recovery process in the petroleum industry. The composite nanometer SiO<2> pressure-lowering and injection-augmenting agent is composed of nanometer SiO<2>, anionic surfactant, surface modification agents and active water. The composite nanometer SiO<2> pressure-lowering and injection-augmenting agent is characterized in that good heat resistance is achieved, a good pressure-lowering and injection-augmenting effect is achieved at the temperature of 120 DEG C, the technological process is simple, operation is convenient, and meanwhile the problems of reduction of the pore diameter, blocking of a pore throat and the like caused by clay swelling and scale formation can be effectively inhibited. The composite nanometer SiO<2> pressure-lowering and injection-augmenting agent can be used for pressure-lowering and injection-augmenting of a low-permeability water injection well and can effectively supplement stratum energy, improve reservoir permeability and comprehensively improve the water injection development effect of an oil field.

The invention discloses a compound acid blockage removing fluid. The blockage removing fluid is prepared from raw materials in parts by weight as follows: 4-6 parts of a foam flushing fluid, 20-30 parts of a prepad fluid, 70-100 parts of main acid and 10-20 parts of postpad fluid. The acid fluid has higher capacity of removing organic sediment pollution and high acid residue and emulsifying resistance. The acid fluid has low corrosion speed and good swelling inhibition and does not change the original water wetting characteristic of the stratum.

The invention relates to a method for finishing nano anti-ultraviolet and antibacterial hydrophobic fabrics. The method comprises the following steps: (1) adding citric acid with mass being 0.5-2 times that of zinc salt to zinc salt aqueous solution with mass percent concentration being 0.1-5.0% and stirring the mixture until the citric acid is completely dissolved to obtain nano zinc sol; (2) mixing long chain fatty acid, water and alcohol or mixing long chain fatty acid salt, organic acid, water and alcohol to obtain a water repellent; and (3) padding or impregnating the fabrics in the nanozinc sol and then pre-drying the fabrics, then padding or impregnating the fabrics in the water repellent and pre-drying and baking the finished fabrics, thus obtaining the nano anti-ultraviolet and antibacterial hydrophobic fabrics. The method has the following beneficial effects: the method is simple and is easy to industrialize; the used raw materials have low cost and do not have toxic or side effects; and the fabrics finished by the method have excellent hydrophobic property, simultaneously have excellent anti-ultraviolet and antibacterial properties and have good application prospects.

A method of recovering in situ hydrocarbons from a subterranean formation includes injecting a volume of fluid with composition comprising 0.01 mass % or more of at least one ketone and 50 mass % or more of water into an injection well completed in the subterranean formation; and producing at least a fraction of the injected volume of fluid and in situ hydrocarbons from the subterranean formation through a production well completed in the subterranean formation. A hydrocarbon recovery system includes an injection apparatus connected to a well formed in a subterranean formation and a storage container in fluid communication with the injection apparatus. The container includes the at least one ketone and water.

The invention relates to a salt-resistant and high-temperature-resistant foam discharge agent and a method for preparing the same, and belongs to the technical field of oil and gas field development.The salt-resistant and high-temperature-resistant foam discharge agent comprises, by weight, 0.2-0.5% of anionic-nonionic surfactant composite systems, 0.02-0.08% of microbial fermentation liquor andthe balance water. The microbial fermentation liquor is glycolipid producing biological surfactant or lipopeptide producing biological surfactant microbial strain fermentation liquor. The salt-resistant and high-temperature-resistant foam discharge agent and the method have the advantages that the salt-resistant and high-temperature-resistant foam discharge agent has salt-resistant and high-temperature-resistant foaming, foam stabilizing and liquid carrying ability and is excellent in condensate oil resistance and methanol tolerance, and accordingly the salt-resistant and high-temperature-resistant foam discharge agent and the method are favorable for environmental protection and sustainable development of oil and gas fields.