337results about How to "Expand the affected volume" patented technology

The invention provides a foam profile control agent applicable to oil field in-depth profile control. The foam profile control agent provided in the invention comprises a polymer cross-linking solution and gas; under formation pressure, a volume ratio of the gas to the polymer cross-linking solution is 0.2: 1 to 1: 1; and the polymer cross-linking solution of the foam profile control agent comprises, by weight, 0.3 to 1.2 wt% of a surfactant, 0.01 to 0.8 wt% of a polymer, 0.001 to 0.2 wt% of a cross-linking agent, 0.001 to 0.1 wt% of a stabilizing agent and 0.05 to 1.5 wt% of inorganic salt, with the balance being water. The foam profile control agent has an effect on delaying cross-linking, can effectively plug a high-permeability zone, can reduce oil-water interfacial tension and has the effects of enlarging swept volume and improving oil displacement efficiency.

The invention discloses a foam profile control system suitable for advanced profile control of an oilfield. A liquid of the system is prepared from a first surfactant, a second surfactant, granules, a foam stabilizer, a polymer, a crosslinking agent, a stabilizer, an adjustor, inorganic salt, a control agent and water. The foam profile control system has three characteristics of foam, gels and granules at the same time, and has a strong deep sealing capacity to a high-permeability oil layer, namely, has an effect on expanding the swept volume. The system further can reduce the oil-water interface tension, and mainly exerts a gel performance at a low-permeability layer and a foam property at a high-permeability layer, that is, the system has the effects on improving the oil dispelling efficiency and selectively plugging water. When the system is used, as gases exist, the use level of the foam profile control system is reduced, and the foam profile control system has the characteristics of temperature resistance and salt resistance at the same time.

The invention discloses a supercritical multisource multielement thermal fluid injection-production system and injection-production method. The system comprises a supercritical multisource multielement thermal fluid generating system and an oil tube. The oil tube is arranged in an exploiting shaft; the supercritical multisource multielement thermal fluid generating system comprises a supercritical gasification reactor and a supercritical mixed combustion reactor; in the presence of supercritical water, a gasification reaction is performed on fuel slurry in the supercritical gasification reactor, and the gasification product of the reaction and oxygen-containing gas dissolved in the supercritical water combust in the supercritical mixed combustion reactor to form a supercritical multisource multielement thermal fluid containing supercritical water and carbon dioxide; the supercritical mixed combustion reactor is connected to the oil tube. The supercritical multisource multielement thermal fluid injection-production system provided by the invention has the effects that thermal efficiency is high, the viscosity of thickened oil is reduced, the flowability of the thickened oil is improved and the recovery efficiency is increased.

The invention provides polymer microspheres for high temperature hypersalinity reservoir deep profile control and a preparation method thereof. In the method, based on the method that photopolymerization is used to prepare the polymer microspheres, heat and salt resistance polymer materials such as sodium 3-acryloylamino-3-methyl butyrate, 2-acryloylamino-2-methylpropane sulfonic acid, acrylamide monomer and the like and water-soluble anionic monomer are adopted and dispersant and cross-linking agent are added as so to form oil-water mixed emulsion in the mixed medium of surfactant and solvent; then initiator is decomposed by ultraviolet through photopolymerization under controllable temperature so as to initiate emulsion polymerization and 50-500nm of microspheres are formed. The invention utilizes the ability of microspheres that microspheres can be dispersed in arbitrary concentration and injected in the water and can gradually swell after entering in depth of the formation to plug the pore throat so as to effectively plug the high permeable strip of the formation, expand the water swept volume, significantly increase crude oil recovery of water flooding reservoir and is applicable to high temperature hypersalinity reservoir deep profile control.

The invention discloses a method for activating indigenous microorganisms of an oil reservoir for oil displacement after polymer flooding. The method is characterized in that an oil displacement slug capable of activating indigenous microorganisms of the oil reservoir is injected into a target oil reservoir of the oil displacement through an injection well; the oil displacement slug comprises an activating agent slug and an activating agent protection slug; during an injection process, the activating agent slug and the activating agent protection slug are alternately injected for at least more than 2 times; the total volume of the activating agent slug is two times or more bigger than that of the activating agent protection slug (the most suitable range is controlled to be 2-5 times). According to the method disclosed by the invention, the number of the functional microorganisms of the oil reservoir is increased by injecting an exogenous activating agent; the recovery efficiency can be improved by 3-5 percent after the polymer flooding, and the applicability is good.

The invention relates to a method of displacing oil by anionic-cationic composite surfactant and mainly solves the problems that the prior method of displacing oil by surfactant is low in oil displacement efficiency in tertiary oil recovery and an oil displacement system containing inorganic base is harmful to stratums and oil wells, corrosive to equipment and pipelines and difficult for demulsification. According to the technical scheme, crude oil is allowed to contact with oil-displacing agent, and the oil-displacing agent comprises, by weight percent, 0.01-5.0% of anionic-cationic composite surfactant, 0.01-3.0% of polymer, and 92.0-99.98% of injected water. The problems are solved well. The method is applicable to tertiary oil recovery for oil fields.

The invention relates to a thermal developing well pouring steam nitrogen foam adjusting method comprising steam, nitrogen and foaming agent pouring method and nitrogen generating pouring method, wherein the steam is poured via an oil tube, the nitrogen and the foaming agent are poured in via a muffle, while the mass ratio between the foaming agent, steam is 1:250-500, the mass ratio between the nitrogen and the stem is 50-80:1, the pouring speed is steam at 10-13t/h, foaming agent at 0.1-0.5t/h, and nitrogen at 900-1000Nm3/h. And the invention uses four-section plug pouring process, while the first section plug pours nitrogen via the muffle for 12h at 900-1000Nm3/h, the second section plug pours the steam via the oil tube for 24h at 10-13t/h, and the third section plug pours steam via the oil tube and pours nitrogen and foaming agent via the muffle at 10-13t/h, 900-1000Nm3/h, and 0.1-0.5t/h for 2h, the fourth section plug stops pouring foaming agent and holds the pouring speed of the nitrogen and the steam for 12h, repeats the steps of four section plugs until preset demand, closes the well, then opens well to produce.

The invention belongs to the technical field of sewage processing, and concretely relates to a drilling wastes recycling method. The method comprises the following steps: performing primary purifying, removing rock debris and sandstones; performing destabilizing and flocculating treatment, conglomerating the suspending granules into a flocculent body; performing solid-liquid separating, using a separated sludge for profile control of a water injection well in an oil field; performing biological treatment on the separated sewage to reduce COD, carrying out microfiltration and ultrafiltration processing for removing a suspension and a colloid as well as reducing SDI, performing reverse osmosis to obtain fresh water for reuse, evaporating concentrated water obtained by reverse osmosis and crystallization, reusing the fresh water obtained by evaporation, and reusing the common salt and potassium chloride obtained by crystallization as an additive of a drilling fluid. The method realizes harmlessness and recycling of the drilling wastes, eliminates pollution on surrounding environment, and is in favor of protection of resources such as soil, air and underground water at periphery of a well field. The method can be widely used in a recycling treatment process of the drilling wastes in the oil field.

The invention discloses an air foam slug flow driving process for the oil recovery of an oil field, comprising the following steps of: 1 determining type and proportion of the used foam liquid, slug volume ratio and on-site injection manner of the used air and the foam liquid during the air foam slug flow driving by an indoor test; and 2 carrying out the air foam liquid slug flow driving on site,wherein the oil flow driving process comprises the following steps of: preparation before the oil flow driving; slugging a pad fluid; slugging the air foam; alternatively injecting the air and foam liquid slug from a specially manufactured device to a target well for many times; and continuously carrying out the oil flow driving on the target well by a water or air injection method according to the dynamic change condition of the target well and a conventional oil displacement method after the injection of the air foam slug is finished. The invention has the advantages of reasonable design, simple and convenient construction steps, good use effect and convenience of realizing, can effectively solve various practical problems of poor water injection effect, difficult improvement on the water injection capability, poor oil flow driving efficiency and the like during the ultralow reservoir waterflooding.

The invention provides a foam oil displacement system with ultralow interfacial tension and a use method of the foam oil displacement system. The oil displacement system is formed by mixing raw materials in percentage by weight as follows: 0.1%-0.3% of a foaming agent, 0.05%-0.15% of an inorganic reagent, 0.01%-0.10% of a foam stabilizer and the balance of water, wherein the foaming agent is dodecyl dimethyl betaine, dodecyl hydroxysulfobetaine, dodecyl hydroxypropyl sulphobetaine, lauramide propyl hydroxysulfobetaine, lauramide propyl betaine, cocamidopropyl dimethylamine oxide, gemini oxidized tertamine, polyoxyethylene dodecanol ether sulfate or sodium dodecyl sulfate; the inorganic reagent is sodium hydroxide, anhydrous sodium carbonate or sodium metaborate; the foam stabilizer is partially HPAM (hydrolyzed polyacrylamide), acrylamide copolymer, PACHV (high-viscosity polyanionic cellulose) or HPMC (hydroxypropyl methyl cellulose).

The invention relates to a method for carrying out profile control on a fracture-type oil reservoir, which comprises the following steps of injecting 0.1 to 0.3 percent of zwitterionic polymer solution into an oil layer; suspending and carrying expansion-retarding 0.2 to 1.0 percent of salt-resistance high-intensity water-absorbent resin particles by a zwitterionic gel profile control agent and injecting the obtained product into a fracture of the oil layer; injecting 30 to 50m<3> of acrylamide gel; suspending 0.2 to 0.5 percent of water insoluble solid particles by the zwitterionic gel profile control agent and injecting the obtained product into the fracture; and alternately injecting 1,000m<3> of partially hydrolyzed polyacrylamide solution with a molecular weight of 15 million, degree of hydrolysis of 10 to 20 percent and 1,000m<3> of petroleum sulfonate surfactant solution, wherein the concentration of the hydrolyzed polyacrylamide solution is 0.05 to 0.15 percent and the concentration of the petroleum sulfonate surfactant solution is 0.2 to 0.5. According to the method, profile control and flooding effects of the fracture-type oil reservoir can be improved; water content of a fracture main direction oil well is reduced; and yield of crude oil of a fracture side direction oil well is increased.

The invention discloses a method for multi-section equal-fluidity energy-assembled parallel synchronous oil driving in non-uniform oil layer. First, according to the water adsorption ability, dividing the non-uniform oil layer into several sections; then selecting the fluidity of oil driving agent and keep the fluidity of each section same; uses the formula that the fluidity=oil layer filter rate/fluid viscidity to calculate the fluid viscidity of needed oil driving agent; and selecting polymers to attain the fluid in said viscidity; the sub sections in different viscidities are connected to the integrated one; at last, from high to low viscidity, filling sub sections into oil layer. The invention changes the integrated oil driving into separated oil driving, with less driving resistance; the energy-assembled section has high part pressure, and high driving pressure difference. And it can reduce ineffective water cycle, improve efficiency and reduce the consumption of driving agent.

The invention provides a method for developing a heavy oil reservoir of a horizontal well by combining staged volume fracturing and fracturing filling. According to the method, firstly, a steam injection well is deployed at the bottom of the oil reservoir; a production well is deployed at the middle upper part of the oil reservoir; then, the volume fracturing or fracturing filling operation is performed according to the porosity degree and seepage rate distribution condition of the two horizontal wells; then, the two wells form heat communication in a steam throughput mode; next, the two wells transfer to continuous steam injection production; and the production is stopped when the oil-steam ratio is lowered to 0.1. According to the invention, a fracture net system is formed in a compact region by the volume fracturing, so that the seepage capability of the oil reservoir is improved; the fracturing filling process is used in a high-porosity and high-permeability region for performing compaction so as to reduce a formation sand production phenomenon; the seepage mode of a low-permeability region oil reservoir is converted from the single seepage to the sewage and fracture laminar flow; meanwhile, a high-permeability region is filled with small-grain-size sand for filling loose reservoir sandstone particle pores, so that the permeability near the production well is reduced,the oil reservoir anisotropy is reduced and the whole oil reservoir can be uniformly used and developed.

The invention provides a resistivity data collecting and processing method based on an oil-water front, which belongs to a method for measuring the change of the resistivity of a geological stratum with a core containing oil and water in the physical simulation of geophysical exploration and development. The method comprises the steps of simulating an actual stratum (manufacturing an artificial cement rock core model), arranging a simulation well, arranging a front monitoring system and measuring the change of the resistivity in the artificial cement rock core model. The method not only can well simulate and measure the underground geological condition but also can further learn the position of the residual oil of a reservoir and the change rule of the oil-water front.

The invention relates to a natural carboxylate-polymer microballoon binary composite control system, and a preparation and application thereof. The binary composite control system comprises raw materials of: 0.1-0.5% of polymer microballoon, 0.05-0.5% of natural mixed carboxylate, 0.05% of suspending agent polyacrylamide and the balance of water. The binary composite control system of the invention has effects of profile control and plugging, strong oil scrubbing ability, and can effectively solve a problem of crude oil recovery ratio increase after polymer flooding and avoid damages to stratum and oil extraction equipment caused by alkali.

The invention provides a variable intensity water injection exploitation method for a carbonate fracture-cavity oil reservoir. The variable intensity water injection exploitation method includes the following steps that a injection-exploitation well group is selected in a fracture-cavity unit and subjected to water injection, water injection intensity is adjusted in the water injection process, and water injection is stopped until earnings of oil exploitation are smaller than cost of water injection. According to the water injection exploitation method, a flow field is changed through variable intensity water injection, the swept volume can be enlarged, and then oil recovery is improved.

A functional polymeric surfactant reinforced combination flooding composition contains the following ingredients, by weight, 0.05-0.5% of polymer, 0.03-0.5% of a sulfonate surfactant, 0.01-0.3% of a functional polymeric surfactant, 0.0-0.3% of a nonionic surfactant, 0.2-1.5% of alkali and the balance water. The functional polymeric surfactant is a copolymer of an acrylamide monomer and/or a hydrophilic monomer and/or a functional monomer. According to the reinforced combination flooding composition, multiple oil-displacement mechanisms are combined. In a low-concentration system, the purpose that a three-compounds combination flooding has higher crude oil recovery can be achieved. After polymer flooding, oil reservoir also has a certain effect of raising crude oil recovery.