3360results about How to "Enhanced overall recovery" patented technology

An apparatus and method produces nitrate ions on-site from water, natural gas and air extracted in proximity to the apparatus. The apparatus generates nitrate ions and brings the nitrate ions into contact with an aqueous system. Hydrogen sulfide present in the aqueous system is removed and the production of hydrogen sulfide by sulfate-reducing bacteria (SRB) is eliminated by introducing into the system nitrate ions, whereby denitrifying microorganisms, using nitrate, outcompete the sulfate-reducing bacteria for the available carbon nutrients, thus preventing the SRB from producing hydrogen sulfide. Nitrate ions generated by the apparatus and added to the aqueous system which contains the denitrifying microorganisms can enhance oil recovery by means of microbial enhanced oil recovery mechanisms.

An electrical current generating system is disclosed that includes a fuel cell operating at a temperature of at least about 250° C. (for example, a molten carbonate fuel cell or a solid oxide fuel cell), a hydrogen gas separation system or oxygen gas delivery system that includes a compressor or pump, and a drive system for the compressor or pump that includes means for recovering energy from at least one of the hydrogen gas separation system, oxygen gas delivery system, or heat of the fuel cell. The drive system could be a gas turbine system. The hydrogen gas separation system or the oxygen gas delivery system may include a pressure swing adsorption module.

A foam drive method for enhancing oil recovery efficiently is initiated by injecting into a subterranean oil-bearing formation, an aqueous polymer solution as a preceding-slug. This is followed by periodically injecting simultaneously or alternately a non-condensible gas and an aqueous solution of foaming composition to form a combined foam under ground or periodically injecting the combined foam formed beforehand by the gas and said aqueous solution above ground. The aqueous solution of foaming composition comprises an alkali, a surfactant and a polymer. Thereafter, an aqueous polymer solution used as a protecting-slug is injected into the formation; followed by continuing water-flooding.

An aqueous fluid composition useful for the recovery of hydrocarbons from a subterranean formation, including a mixture of water, a water soluble polymer, an inorganic salt and at least one zwitterionic surfactant and methods of using same.

The present invention generally relates to a method and a composition useful in restoring the permeability of a porous underground petroleum containing formation. Restoring permeability to the formation enhances the injectivity thereby accelerating petroleum recovery. The method of the invention comprises treating said formation with a composition which comprises a combination of at least one nonionic compound, preferably an alkoxylated alcohol, with at least one cationic compound, preferably a quaternary ammonium compound, in an amount effective to improve the permeability of the formation. The composition may also optionally contain an alkyl glycoside.

A method and a plant for simultaneous production of a gas for injection into an oil field and production of methanol, dimethyl ether and / or other oxygenated hydrocarbons or production of higher hydrocarbons from natural gas is disclosed. An air separation unit (ATR) for production of pure nitrogen for injection and pure oxygen for production of synthesis gas (“syngas”) by authermal reformation of a natural gas is an essential part of the method and plant.

Methods and systems for low emission power generation in hydrocarbon recovery processes are provided. One system includes integrated pressure maintenance and miscible flood systems with low emission power generation. The system may also include integration of a pressure swing reformer (PSR), air-blown auto-thermal reformer (ATR), or oxygen-blown ATR with a gas power turbine system, preferably a combined cycle gas power turbine system. Such systems may be employed to capture and utilize greenhouse gases (GHG) and generate power for use in hydrocarbon recovery operations.

The present invention relates to an enhanced oil recovery process that is integrated with a synthesis gas generation process, such as gasification or methane reforming, involving combined capture and recycle of carbon dioxide from both processes.

This invention provides a method for controlling production operations using fiber optic devices. An optical fiber carrying fiber-optic sensors is deployed downhole to provide information about downhole conditions. Parameters related to the chemicals being used for surface treatments are measured in real time and on-line, and these measured parameters are used to control the dosage of chemicals into the surface treatment system. The information is also used to control downhole devices that may be a packer, choke, sliding sleeve, perforating device, flow control valve, completion device, an anchor or any other device. Provision is also made for control of secondary recovery operations online using the downhole sensors to monitor the reservoir conditions. The present invention also provides a method of generating motive power in a wellbore utilizing optical energy. This can be done directly or indirectly, e.g., by first producing electrical energy that is then converted to another form of energy.

The present invention relates to an enhanced oil recovery process that is integrated with a synthesis gas generation process, such as gasification or reforming, involving capture and recycle of a sour carbon dioxide stream for EOR use.

The invention discloses a complex foam extinguishing agent for a coal mine and belongs to the technical field of fire prevention and extinguishing. The extinguishing agent is prepared from the following raw materials: main materials are 40 to 60 percent aqueous solution of ammonium bicarbonate or sodium bicarbonate and concentrated sulfuric acid in a solute mass ratio of 2:1-3:1, and auxiliary materials are a stabilizer and a foamer, wherein the auxiliary materials are 0.1 to 2 percent of the total weight of the main materials. Through a test, the extinguishing agent has the foaming coefficient of 20-200 and the foam stabilizing time of more than or equal to 2.5 hours. According to the foam extinguishing agent, the foam of inert gas carbon dioxide is applied to fire prevention and extinguishing of the coal mine, and the foam is diffused in a fire area and fills a fire space, so that the oxygen concentration in the fire area is rapidly reduced, fire is extinguished due to oxygen deficiency in the fire area, temperature is reduced and a fire extinguishing effect is good. The technology also can be applied to coal bed transformation, CO2 foam is easily absorbed by coal to displace partial methane, the recovery ratio of coal seam gas is improved, and CO2 is acid to reduce the generation of secondary precipitates, so that a gas drainage effect is improved. The complex foam extinguishing agent is simple and feasible, and low in cost.

A combustor apparatus is provided, comprising a mixing arrangement for mixing a carbonaceous fuel with enriched oxygen and a working fluid to form a fuel mixture. A combustion chamber is at least partially defined by a porous perimetric transpiration member, at least partially surrounded by a pressure containment member. The combustion chamber has longitudinally spaced apart inlet and outlet portions. The fuel mixture is received by the inlet portion for combustion within the combustion chamber at a combustion temperature to form a combustion product. The combustion chamber directs the combustion product longitudinally toward the outlet portion. The transpiration member is configured to substantially uniformly direct a transpiration substance therethrough toward the combustion chamber, such that the transpiration substance is directed to flow helically about the perimeter and longitudinally between the inlet and outlet portions, for buffering interaction between the combustion product and the transpiration member. Associated systems are also provided.

A kind of mining oil gas method of the convection heating up oil-shale, involves the underground solid state energy and the mineral mining method improvement. The existing technical mining method efficiency is low, the cost is high, the scale is small, the big area implements and lacks the market competition ability with difficulty. This invention through in the ground arrangement group well, and selects the compression fracture method causes the group well to be interlinked, then the gap takes turns to choose the note hot-well and work-well, hot-well pours into 400 deg.C - 700 deg.C steam along the note oil-shale the ore level, heats up the ore level causes cheese root thermal decomposition to form the oil gas, and carries after the low temperature steam or the water along the production separates to the ground, finally forms the oil gas product. In the separation process may simultaneously the pre- hot water, and uses the water-injection well withdraws with work-well the convection way dries up oil-shale and the ore level around shale region afterheat, thus realized the goal of this invention is fast, big scale, low cost from oil-shale ore level mining oil gas.

The invention discloses a method for enhancing recovery ratio through three-dimensional streamline regulation of a water drive reservoir. The method is characterized by comprising the following steps: identifying the planer development segment and vertical development segment of a preferential seepage channel to quantificationally calculate sampling parameters; establishing a three-dimensional geologic model comprising the characteristics of the preferential seepage channel, establishing a reservoir numerical simulation model, and finely determining a residual oil distribution characteristic under current heterogenous condition through reservoir numerical simulation; carrying out pattern modification and optimized water shutoff and profile control design; and determining whether layered injection and recovery is required according to water adsorption characteristics of a vertical water well and liquid generation characteristics of an oil well by utilizing the reservoir numerical simulation result. In the invention, on the basis that the preferential seepage channel is blocked through deep profile control and water shutoff, the planer flow line direction is changed through the combination water shutoff and profile control with pattern modification optimization, water shutoff and profile control are optimally combined with subdivided development layers and layered injection and recovery optimization to control and regulate the density of vertical flow lines, and the purpose of maximally control underground flow lines is achieved through the synergistic effect of different means.

The invention provides a channeling preventing and plugging agent and a construction method for controlling plugging and sealing channeling by utilizing the channeling preventing and plugging agent. The channeling preventing and plugging agent comprises a high-temperature-resistance pre-plugging agent serving as a pre-posed pre-plugging plug, an enhanced gel plugging agent serving as an intermediate enhanced plug and a high-strength resin plugging agent serving as a postposed sealing plug. The channeling preventing and plugging agent has the characteristics of high temperature resistance, long-term stability, good plugging performance and the like. The invention further provides a construction method for controlling plugging and sealing channeling by utilizing the channeling preventing and plugging agent. The method has a simple constructing process, and can be used for constructing after the channeling preventing and plugging agent is directly prepared on the spot. The channeling preventing and plugging agent can be used for effectively solving the adverse impact of the steam / air channeling phenomenon of a heavy oil thermal production well on production, and has an important effect on prolonging the production cycle of a heavy oil well and improving the recovery efficiency.

The invention discloses an intelligent oil well simulation experiment system and a experiment method. The intelligent oil well simulation experiment system comprises a three-dimensional heterogenous reservoir simulating box, a wellbore hole simulator, a fluid injecting module, a fluid generating module, a data acquiring module, an automatic control module, a constant temperature module, a saturation probe, a pressure sensor and a temperature sensor. The wellbore hole simulator is arranged in the three-dimensional heterogenous reservoir simulating box, the automatic control modules realizes the real-time extraction and injection on the wellbore hole simulator through controlling the fluid injecting module and the fluid generating module; and the data acquiring module is used for monitoringinjected and extracted fluid, and monitoring the saturation, the temperature and the pressure in the simulating box in real time, and a computer is used for optimizing and analyzing the monitoring data, controlling the injection and extraction flow in real time through the automatic control module, simulating and realizing multilayer comingling production, sectional extraction of a horizontal well, extraction of a multi-branch well and control strategy of an injection and extracting well, and perfecting the researches of real-time optimization, real-time regulation and the like of the production.

The invention relates to an oil-displacing agent for enhancing crude oil recovery efficiency in tertiary recovery and a preparation method thereof, belonging to the technical field of intensified oilproduction in oil fields. The surface active agent used in the invention comprises following components in percentage by weight: 0.01-0.3 percent of water soluble high molecular polymer, 0-20 percentof non-ionic surface active agent, 5-65 percent of anion active agent, 0-5 percent of ampholytic active agent, 0.01-1.5 percent of additive and the balance of water. The oil-displacing agent and the polymer are based on a novel intensified oil displacing system which has complementary structure and good compatibility and is obtained by various associations and the interaction among molecules. Thesystem has the performances of high temperature resistance, salt resistance, higher viscosity, ultralow interfacial tension, and the like, is in accordance with the environmental requirement and can obviously enhance the oil recovery efficiency of oil fields after being used for oil-displacing.

The invention relates to a high-temperature resistant phenolic resin weak gel profile control plugging agent, which is a profile control plugging agent formed by reacting partially-hydrolyzed polyacrylamide and a cross-linking agent by acylamino of the hydrolytic polyacrylamide. The profile control plugging agent comprises the following components in percentage by weight: 0.25 to 1.2 percent of partially-hydrolyzed polyacrylamide, 0.2 to 1 percent of cross-linking agent, 0.01 to 1 percent of additive and the balance of water. According to the high-temperature resistant phenolic resin weak gel profile control plugging agent, the water plugging rate is more than 80 percent, the oil plugging rate is less than 30 percent, the profile control plugging agent can be resistant to high temperature of over 90 DEG C, mineralization resistance is up to 85,000 mg / L (on the basis of 80,000 mg / L of sodium chloride and 5,000 mg / L of calcium chloride), the strength of gel is high, breaking strength is improved by 68 percent compared with the prior art, the gel-formation time is adjustable, the aims of plugging high-permeability layers in strata and adjusting water absorption profiles of water injection wells deeply can be fulfilled, the deep profile control of oil layers is realized, and the recovery ratio of petroleum is improved greatly.

An oil recovery process is disclosed which uses an alkali(s) and a particular class of alkylaryl sulfonate surfactants. The surfactants are derived from an alpha-olefin stream having a broad distribution of even carbon numbers ranging from 12 to 28 or more. The olefin stream is reacted with aromatic feedstock, such as benzene, toluene, xylene, ethylbenzene, or a mixture thereof to form alkylates, and then reacted with SO3 to form sulfonic acids. Alternatively, the surfactant can be formed by first reacting an alpha-olefin stream having a broad distribution of carbon numbers ranging from 12 to 28 or more with SO3 to form the olefin sulfonic acid that is subsequently used to alkylate an aromatic feedstock. The use of alkali(s) and broad distribution alpha-olefins sulfonate based surfactant has the improvements of requiring ultra-low surfactant concentrations and providing ultra-low interfacial tensions over a wide range of alkali concentrations with crude oils, especially waxy crude oil, having a broad distribution of carbon numbers.

The invention provides a method for analyzing remaining oil distribution of a fractured-vuggy reservoir, belonging to the fields of numerical reservoir simulation and oil-gas field development. In the method, a complex medium consisting of a cave medium, a crack medium and a pore medium is partitioned into a plurality of space unit blocks in a space field; each block consists of V, F and M units which represent a cave, a crack and a substrate in the block respectively and constitute a V-F-M model; the flow of a multi-phase fluid in the complex medium is described by the motion of a fluid among the units in each block and the motion of a fluid among the units of different blocks; and the flow of the fluid among the units can be considered as infiltration flow, pipe flow or laminar flow between parallel walls, Darcy flow or non-Darcy flow. According to the method, scientific description and accurate numerical simulation of the fractured-vuggy reservoir are realized, and technical foundations are laid for the alignment of the remaining oil distribution position of the fractured-vuggy reservoir with a numerical simulation technology, quantitative determination of the reserves abundance of the reservoir, scientific and reasonable development of oil fields provided with the reservoir and final increase in the recovery ratio.

A method for enhancing oil recovery includes the step of providing a subsurface reservoir containing hydrocarbons therewithin. A wellbore is provided in fluid communication with the subsurface reservoir. A surfactant-polymer solution is formed for injection into the reservoir. The surfactant-polymer solution is formed by mixing a composition with at least one surfactant, at least one polymer, and at least one co-solvent or co-surfactant such that the surfactant-polymer solution is clear and aqueous stable. The surfactant-polymer solution is injected through the wellbore into the reservoir. A chaser solution is formed for injection into the reservoir. The chaser solution has an additional predetermined quantity of the co-solvent or co-surfactant. The chaser solution is injected through the injection wellbore into the reservoir to increase the production of hydrocarbons from the reservoir while maintaining the clear and aqueous stability of the surfactant-polymer solution.

The invention discloses an acrylamide modified graft copolymer and a preparation method and usage thereof. The invention is characterized in that 20 parts of acrylamide, 1-20 anionic monomer and / or cationic monomer, 0.1-15 macromonomer, 0.05-10 ionic lyophobic monomer and 50-1000 deionized water are added into a three-necked reaction bottle, the pH value is adjusted to be 3-9, N2 is introduced for 30min, then 0.002-0.5 part of initiator persulfate is added at 30-75 DEG C, the reaction lasts 8-36h, then copolymer PAB is obtained, and finally water is used for dilution to obtain strong PAB solution. During polymerization, no surfactant is used, and the macromonomer with a long chain and the ionic lyophobic monomer with intermolecular association function are introduced into the copolymer PAB, so the capabilities of cooperative tackification and salt-resistance between the rigid conformation of a molecular chain and the intermolecular association can be played optimally, the PAB exhibits unique solution property and has higher colloidal viscosity in high saline solution than in fresh water, and the PAB obtains the capabilities of tackification, salt resistance, low surface tension and strong molecular association and can be used for the oil-displacing acrylamide modified graft copolymer. The copolymer is prepared into water solution with mass concentration of 0.2-3.0g / L and surfactant concentration of 0.01-2 mmol / L, then the water solution is added into a mixing vessel by a stirring device, and then a polymer oil-displacing agent with tackification, salt resistance and cutting resistance is obtained. The PAB has the functions of both a tackifier and a macromolecule surfactant. The copolymer PAB is prepared into water solution which has mass concentration of 0.05-7%, so the macromolecule surfactant with excellent surface activeness can be obtained and then applicable to an emulsifier, an emulsion splitter, a solubilizer and a wetting agent.