38results about How to "EOR effect" patented technology

The invention relates to a method for improving the recovery ratio of a non-homogeneous pay. The method is a method for alternately injecting a foam slug and an alkali and surfactant binary solution slug to improve the recovery ratio of the non-homogeneous pay, and comprises the following steps: injecting the foam slug into an oil layer; and then injecting the alkali and surfactant binary solution slug to complete one injection period, wherein the total injection amount of the foam slug is 60 percent to 100 percent of the total pore volume of the oil layer, the total injection amount of the alkali and surfactant binary solution slug is 20 percent to 40 percent of the total pore volume of the oil layer and the one to four injection periods are carried out. The method for improving the recovery ratio of the non-homogeneous pay, which is provided by the invention, is low in cost, has obvious effect of improving the recovery ratio, can obtain good economic benefits and has wide application prospect.

The invention discloses a composite oil displacing agent for high temperature oil fields, wherein the composite oil displacing agent is prepared from the following raw materials by weight: 10-30 partsof alkyl glycoside, 5-10 parts of glyoxal, 5-10 of nanometer silica sol, 5-15 parts of an alkali, 25-40 parts of linear fatty acid alkanolamide, 0.1-5 parts of a sacrificial agent, 30-60 parts of sodium polyalkylbenzene sulfonate, 15-30 parts of glucoside, 22-30 parts of biological enzyme, and 5-10 parts of glycerin. According to the present invention, the composite oil displacing agent can resist a temperature of 105 DEG C, has good long-term thermal stability and good injection performance, and can significantly improve oil recovery rate.

The invention relates to an oil-displacing agent and an oil-displacing method for enhancing the recovery ratio of high-temperature, high-salinity and high-hardness reservoir crude oil. The oil-displacing agent is composed of the following components in percentage by mass: A, 0.05-0.07% of an amine oxide type amphoteric surfactant; B, 0.15-0.20% of alkylphenol ethoxylate carboxylate; and C, the balance of water. The oil-displacing method disclosed by the invention is implemented through injecting the oil-displacing agent into a natural core subjected to oil-displacing under the conditions that the oil reservoir temperature is 100-120 DEG C, the total salinity of formation water is (10-15)*10<4> mg / L, and the amount of calcium-magnesium divalent metal ions is 7000-10000 mg / L, so that residual oil is in contact with the oil-displacing agent, and then the residual oil is fully displaced. The oil-displacing agent provided by the invention reaches the magnitude order of 10<-3> mN / m under the condition of high-temperature, high-salinity and high-hardness salt reservoirs, and the interfacial tension still can be maintained in an ultra-low interfacial tension state after the oil-displacing agent is aged for a long time under the condition of oil reservoirs, therefore, the oil-displacing agent is applied to the tertiary oil recovery production of oil fields.

The invention relates to a method for enhancing oil recovery of a low permeability sandstone reservoir. A flexible microgel in-depth profile modifying agent is injected into an oil extraction well water distribution water pipeline of an ultralow permeability sandstone reservoir in the middle and later stage of fracture water injection, and the injection concentration of the flexible microgel in-depth profile modifying agent ranges from 100ppm to 10000ppm. According to the method, corresponding affected oil well stable production and increasing production duration of the water injection well is one to five years, after the flexible microgel in-depth profile modifying agent is injected into the water injection well of the ultralow permeability sandstone reservoir, oil increasing of an oil well can correspondingly reach 5% to 20% on the calculation basis generally, and the obvious effect of improving crude oil extraction rate is achieved.

The invention discloses a test simulating device for improving a recovery rate of coal bed methane by injecting carbon dioxide. The test simulating device for improving the recovery rate of the coal bed methane by injecting the carbon dioxide comprises a coal reservoir simulating system, a gas injecting system, a fracture simulating carbon dioxide injecting system, a carbon dioxide absorbing device and a data collection and control system, wherein the coal reservoir simulating system is used for simulating the conditions of pressure and temperature of a coal reservoir, the gas injecting system is used for injecting methane gas or helium gas into the coal reservoir simulating system, the fracture simulating carbon dioxide injecting system is used for injecting high-pressure liquid into the coal reservoir simulating system, enabling the coal reservoir simulating system to simulate the degree of development of fractures, and injecting the carbon dioxide into the coal reservoir simulating system, the carbon dioxide absorbing device is used for absorbing the carbon dioxide exhausted by the coal reservoir simulating system, and the data collection and control system is used for collecting data and carrying out process control. The test simulating device for improving the recovery rate of the coal bed methane by injecting the carbon dioxide is capable of simulating the real conditions of the coal reservoir, simulating on-spot fracturing and the process of pump injection of the carbon dioxide, simulating effects of improvement of the recovery rate of the coal bed methane by injecting different volumes of the carbon dioxide according to different degrees of the development of the fractures and different conditions of the coal reservoir, and achieving an optimal carbon dioxide injection volume aiming at a specific coal reservoir.

The invention provides a carbonate rock reservoir microscopic model, a preparation method and application thereof. The model preparation method includes: cutting the calcite crystal into crystal slices; immersing the crystal slices in molten beeswax to form a wax coating on the surface; using a carbon dioxide laser to remove the corresponding surface of the crystal slice according to the mapping shape of the target pattern channel on the front of the crystal slice. Wax coating, to complete the mapping and engraving of the target pattern channel; immerse the crystal piece in hydrochloric acid with the face up and oscillate ultrasonically to etch the channel pattern exposed by the wax coating; drill the etched channel to communicate with the outside world. ; Cover the front of the crystal sheet with a glass cover sheet and an adhesive to bond the crystal sheet, then clean the channel and wet the channel to obtain a microscopic model of the carbonate reservoir. The preparation method of the microscopic model of the carbonate rock reservoir is simple and fast, the model has a strong pressure bearing capacity, and can be used to study the influence of wettability on the effect of water injection development of the carbonate rock to enhance the recovery factor and the like.

The invention relates to a method for increasing oil recovery in a low-permeability sandstone reservoir; injecting a flexible microgel deep control and displacement agent into the water distribution pipeline of an ultra-low-permeability sandstone reservoir for fracturing water injection in the later stage of oil production well water distribution through a metering pump; The injection concentration of the flexible microgel deep control and displacement agent is 100ppm to 10000ppm; this method: 1) the duration of the stable production and increase of the oil well corresponding to the water injection well is 1 to 5 years; 2) the injection well of the ultra-low permeability sandstone reservoir is injected After the flexible microgel deep control and displacement agent, generally the corresponding oil wells can accumulate oil by 5% to 20%, and the effect of improving oil recovery is obvious.

The invention discloses carboxylic acid higher alcohol ester-trimethyl ammonium chloride and application thereof in a clay stabilizer. The carboxylic acid higher alcohol ester-trimethyl ammonium chloride has double functions of oil displacement and swelling prevention, is particularly suitable for a low-permeability and water-sensitive crude oil reservoir, and consists of the following main components in percentage by mass: 10 to 30 percent of carboxylic acid higher alcohol ester-trimethyl ammonium chloride, 1 to 20 percent of trimethylamine hydrochloride and 50 to 90 percent of water. The carboxylic acid higher alcohol ester-trimethyl ammonium chloride is realized by the technical scheme of: adding an excessive trimethylamine aqueous solution and alpha-chlorinated fatty acid into a pressure reaction kettle; under the condition of the stirring, controlling the reaction temperature to between 50 and 100 DEG C, the reaction pressure to be between 1 and 0.2 MPa, and the reaction time to be between 3 and 5 hours; after the reaction is finished, reducing the temperature to between 40 and 50 DEG C; dripping 30 percent hydrochloric acid into a reaction solution so as to control the PH value of the reaction solution to between 6 and 8; and then diluting the reaction solution to certain concentration by using clear water to obtain an oil displacing type surfactant used for preventing swelling.

The present application discloses a nanomaterial, which is prepared by polymerizing a mixture containing coupled montmorillonite, organic hydrophobic monomer, organic hydrophilic monomer and initiator. The present application proposes a nanomaterial used in low-permeability oil fields. After synergistic action with the surfactant, a gain effect is exhibited, and a nano-oil displacement agent is obtained. Nanomaterials have good long-term stability, low interfacial tension and enhanced oil recovery.

The invention belongs to the field of oilfield chemistry, and in particular relates to an enhanced jelly dispersion deep control and displacement agent suitable for low-permeability, high-temperature and high-salt oil reservoirs. The enhanced jelly dispersion deep control and displacement agent suitable for low-permeability, high-temperature and high-salt reservoirs is composed of functional polymers, cross-linking agents, inorganic reinforcing agents, and water in the following mass fractions: functional polymers, with a mass concentration of 0.4 to 0.6 %; cross-linking agent mass concentration 0.4-0.8%; inorganic reinforcing agent, mass concentration 0.2-0.3%; the balance is water. The average particle size of the enhanced jelly dispersion deep control and displacement agent of the present invention is distributed from nanometer to micron level, can be used for deep control and displacement of low permeability reservoirs, has good deep migration ability, good profile improvement effect, and enhanced recovery factor The effect is remarkable; the deep control and displacement agent can be used for deep control and displacement operations in high-temperature and high-salt oil reservoirs. Effectively improve the formation profile, significantly increase the follow-up water flooding sweep coefficient, and further increase the recovery factor.

The invention provides a low-cost environment-friendly surfactant and a preparation method thereof, and relates to the field of research of surfactant oil displacement agents for improving the recovery ratio of tertiary oil recovery. The low-cost environment-friendly surfactant is prepared from the following components in parts by weight: 100-110g of castor oil acylaminopropyl betaine (the effective content is 98%), 20-30g of lauroyl diethanolamide (the effective content is 99%), 50-60g of double rhamnolipid (the effective content is 50%) and 180-190g of tap water. The low-cost environment-friendly surfactant disclosed by the invention belongs to a bio-based zwitterionic surfactant, has the characteristics of anions and cations, can resist stratum adsorption and dilution, has certain temperature resistance and salt resistance, and has interfacial tension of 10<-3>mN / m under a high-temperature and high-salinity oil reservoir (80 DEG C or above and the mineralization degree of 10000ppm or above), and if the surfactant is compounded with petroleum sulfonate surfactants, the interfacial tension is lower, and the effect of improving the recovery ratio is obvious.

The invention discloses a gas injection oil well selecting method. The gas injection oil well selecting method comprises the step of selecting oil well gas injection effect influence factors, wherein the gas injection influence factors comprise construction positions, reservoir body types, well storage relations, remaining oil types, reserve sizes and water cut rising rules; and the step of conduction gas injection potential estimation on all oil wells in a working section sequentially according to the construction positions, the reservoir body types, the well storage relations, the remaining oil types, the reserve sizes and the water cut rising rules, and therefore the oil well to be subjected to gas injection primarily is selected. By means of the gas injection oil well selecting method, the oil well with gas injection potential can be rapidly selected, the gas injection periodic average oil increment is increased by years, up to now, the gas injection periodic average oil increment is greatly improved, and the gas injection effective rate can reach 96.1%. As a whole, by means of the gas injection oil well selecting method, ultra-deep layer fracture-cavity type oil deposit gas injection is greatly improved, the oil recovery effect is improved, and therefore the production benefits are greatly improved.

The invention discloses a blocking system and a blocking method for channeling inhibition in carbon dioxide non-miscible flooding of a low permeability reservoir. The system is mainly prepared from the following raw materials in percentage by weight: 1%-2% of fine mineral particles, 0.2%-0.3% of polymer, 0.01%-0.02% of compound crosslinking agent, 0.04%-0.1% of retarder, 0.01% of deoxidant, 0.1%-0.5% of surfactant and the balance of water. By virtue of monitoring the steam injection pressure of a wellhead in real time and adjusting the system, graded control of high-pressure steam injection, 'gas channeling' and 'escape channeling' processes in the carbon dioxide non-miscible flooding is realized and the development effect of the carbon dioxide non-miscible flooding of the low permeability reservoir is improved.

The invention relates to the field of oilfield development engineering, and discloses a self-growing gel dispersion active fluidity control system and a fluid channeling control method for a low-permeability-tight reservoir. The system contains 100 parts by weight of a self-growing gel dispersion and 0.15-0.6 part by weight of a surfactant, the self-growing gel dispersoid is prepared by shearing and grinding nano-reinforced chromium-aldehyde double-group cross-linked integral gel, and the preparation method of the nano-reinforced chromium-aldehyde double-group cross-linked integral gel comprises the following steps: adding a functional polymer, a phenolic resin cross-linking agent, an organic chromium cross-linking agent and a nano-reinforcer into water, mixing, and curing. The system can be simply and rapidly prepared, is easy for deep injection by adjusting the size of gel dispersion particles, is wide in action range, high in stability and long in effective period of action, can avoid reservoir pollution, and does not affect the liquid production capacity of the reservoir. The gel dispersion particles can achieve self-growth in the low-permeability-tight reservoir fractures, and the fracture fluid channeling control effect is enhanced.