460 results about "Fluid injection" patented technology

The invention relates to a non-linear seepage experiment method for gas breaking through a cover layer based on dark field imaging. The method comprises the following steps: placing a microfluidic rock chip on an objective table of a dark field scattering microscope; the injection end of the microfluidic rock chip is connected with a fluid injection module, and the outlet end of the microfluidic rock chip is connected with a downstream outflow pipeline; injecting the formation water solution into the micro-fluidic rock chip until the micro-fluidic rock chip is filled with the formation water solution; opening a gas injection system, and adjusting the dark field scattering microscope until a clear image of a micro-fluidic rock chip pore structure and carbon dioxide displacement formation water is obtained; injecting carbon dioxide with different pressures into the micro-fluidic rock chip, and observing nonlinear seepage migration images of carbon dioxide and formation water in the micro-fluidic rock chip; when it is observed that carbon dioxide migrates to the outlet end of the rock chip, the breakthrough moment is obtained, and the upstream and downstream pressure difference value of the microfluidic rock chip is the breakthrough pressure. According to the method, the nonlinear seepage of the carbon dioxide displacement formation water in the nanopores can be accurately observed, and the breakthrough pressure can be determined.

The invention discloses an experimental device and method for controlling migration and mineralization of ore-forming fluid in a wrinkle deformation process, and belongs to the technical field of ore deposit geology. The device comprises an ore liquid synthesis unit and a mechanical deformation simulation and mineralization analysis unit. The mechanical deformation simulation unit comprises a box body, an extrusion deformation system, a liquid injection system and a heating temperature control system, and can synchronously realize visual analysis of structure extrusion, fluid injection and mineralization precipitation at high temperature. The experimental method comprises the following steps: firstly, preparing a simulated metallogenic fluid containing FeS2 (pyrite); laying simulated surrounding rock and wrinkles in the box body, arranging a separation layer, and heating; extruding the sand layer and injecting fluid to simulate a mineralization process; and slicing, sampling and analyzing after model consolidation, and establishing a mineralization space distribution model. The device is simple in structure and convenient to operate, the whole process of fold extrusion, crack extension, fluid migration and mineral precipitation can be repeatedly represented, and an experimental basis is provided for hydrothermal deposit mineralization mechanism research and prospecting prediction.

The invention discloses a low-permeability rock breakthrough pressure testing method based on schlieren imaging. The method comprises the following steps: putting a test rock sample into a confining pressure cavity of a rock sample holder; the injection end of the rock sample holder is connected with the fluid injection module, the outlet end of the rock sample holder is connected with the schlieren cavity, and the confining pressure cavity is connected with the confining pressure injection module; vacuumizing a pipeline of the testing device, injecting a degassed purified water medium into the schlieren cavity, and then carrying out optical path debugging until a clear schlieren image is acquired; loading confining pressure stress on the test rock sample, injecting water until the test rock sample is saturated, injecting carbon dioxide, observing a schlieren imaging system, recording a schlieren image of carbon dioxide breakthrough by a high-precision camera when the carbon dioxide breaks through the saturated rock sample, recording the breakthrough moment of the carbon dioxide, and recording the upstream and downstream pressure difference value at the moment; the breakthrough pressure is the breakthrough pressure of the carbon dioxide of the tested rock core sample. According to the invention, a trace concentration of carbon dioxide can be visually observed to break through the rock sample, so that the breakthrough pressure of the low-permeability rock can be accurately detected.

The provided is a test system and method for achieving three-directional multiphase seepage in a true triaxial loading process. The test system includes a three-directional multiphase seepage loading cabin including a sample metal frame, a loading frame, an outer plate, a fluid injection module, a fluid recovery module, and six loading indenter modules as well as a fluid injection and measurement system; the sample metal frame is arranged at a center of the loading frame, the outer plate is arranged on the loading frame, the fluid injection module and the fluid recovery module are arranged respectively at an upper part and a lower part of the loading frame, and the fluid injection and measurement system is connected to the three-directional multiphase seepage loading cabin; and the loading indenter modules are arranged in the loading frame from six directions, and the indenters of the loading indenter modules are arranged.

The invention provides an oil shale formation temperature field simulation method and system for fluid injection heating mining, a storage area is divided into a plurality of unit mining spaces according to geologic feature data of the storage area to be mined, a mass conservation operation model corresponding to fluid injection in-situ mining is constructed for each unit mining space based on the principle of mass conservation, and the temperature field of the oil shale formation is simulated. According to the principle that high-temperature fluid carries heat to conduct heat transfer and exchange with a rock mass system in a conduction and convection mode and the influence on a temperature field in a rock mass, an energy operation model corresponding to fluid injection in-situ mining is built; preset initial parameters are introduced, the mass conservation operation model and the energy operation model are solved based on the discrete process, initial mass field data and energy field data are calculated, and then temperature field data of subsequent time are calculated in combination with a Newton iteration method. According to the scheme, the limitation of low precision of existing temperature field simulation is overcome, and rigorous and accurate temperature field space-time distribution of the oil shale under fluid injection heating is obtained.

The invention discloses a CCUS experimental device and method for carbon dioxide flooding and storage, and relates to the technical field of petroleum engineering. The device comprises a three-dimensional oil reservoir physical model, a fluid injection system, a fluid collecting and metering system, a resistivity monitoring system and a fluid migration observation system. The three-dimensional oil reservoir physical model is used for constructing a simulated stratum, and a development well pattern system is installed on the simulated stratum; the fluid injection system is connected with the injection well; the fluid collecting and metering system is connected with the production well; the resistivity monitoring system is provided with a plurality of monitoring points on the simulated stratum; the fluid migration observation system is used for observing a migration path of supercritical carbon dioxide in the three-dimensional oil reservoir physical model; and the distributed optical fiber monitoring system is arranged in the simulated stratum. According to the device and the method, oil reservoir water injection exploitation and CO2 injection oil displacement and CO2 storage stability simulation experiments in the later development period can be realized.

The invention provides a dynamic strength test system and method for a soft rock biaxial Hopins compression bar, and the system comprises an axial impact loading unit which is used for generating an axial impact load; the confining pressure loading unit is used for applying radial confining pressure to the sample; the high-pressure fluid injection unit is used for injecting high-pressure fluid into the sample and simulating different internal water pressure and water saturation conditions; the data acquisition unit is used for recording impact load, confining pressure, internal water pressure and sample dynamic response data in real time; the control system is used for coordinately controlling the axial impact speed, the confining pressure and the internal water pressure value; by integrating the axial impact loading unit, the hydraulic servo confining pressure loading unit and the high-pressure fluid injection unit, a test platform capable of truly simulating a complex stress-seepage coupling environment where the deep soft rock is located is formed; therefore, the synchronous, independent and accurate control of axial dynamic load, constant or dynamic confining pressure and internal pore water pressure is realized.

The utility model discloses a microfluid device and a system for researching abnormal migration of solute of a fractured porous medium system. The microfluid device for studying abnormal migration of the solute of the fractured porous medium system comprises a chip and a substrate, wherein the lower surface of the chip is bonded with the upper surface of the substrate; a crack and a porous medium area distributed around the crack are patterned on the lower surface of the chip; the porous medium area comprises a plurality of cylinders, gaps are reserved among the cylinders, and flow channels communicated with the cracks are formed; and a part or all of the cylinders in the porous medium area are provided with notches serving as blind ends. The microfluid system for studying abnormal migration of the solute of the fractured porous medium system comprises a fluid injection device, the microfluid device and a fluid collection device which are connected in sequence.

The application discloses a kind of cross-tectonic period diagenesis simulation device and method.The device includes fluid driving system, reaction solution supply system and at least two groups of tectonic period reaction system connected in sequence, and different reaction systems are used to simulate the temperature and pressure conditions when geological fluid passes through each target layer during cross-tectonic period.The method first restores the geological conditions when geological fluid passes through each target layer during cross-tectonic period according to petrology and geochemistry analysis, combined with tectonic evolution history, burial history and fluid injection history, establishes cross-tectonic period diagenesis model, determines geological fluid type, and then determines the process of geological stress driving high-pressure layer fluid to migrate to low-pressure layer, restores the geological conditions when geological fluid passes through each target layer during cross-tectonic period;According to the restored geological process and geological conditions, the forward simulation of fluid dissolution, cementation, metasomatism and other diagenesis during cross-tectonic period is carried out by using cross-tectonic period diagenesis simulation device.Provide basis for judging the diagenetic mechanism of reservoir rock after high temperature and high pressure and multi-stage tectonic evolution.

A compressor includes a housing, a first compression mechanism and a second compression mechanism disposed in the housing, and a housing cover fixed to the housing. Both the first compression mechanism and the second compression mechanism are configured to compress a working fluid from a suction pressure to a discharge pressure. The first compression mechanism includes a first cylinder housing having a first fluid storage plenum. The second compression mechanism includes a second cylinder housing having a second fluid storage plenum. The housing cover defines an intermediate-fluid port in fluid communication with the first fluid storage plenum via a first intermediate-fluid passage and the second fluid storage plenum via a second intermediate-fluid passage. Working fluid at an intermediate pressure enters the intermediate-fluid port. The intermediate pressure is greater than the suction pressure and less than the discharge pressure.

The invention discloses a saline water layer CO2 geological storage salting-out quantitative evaluation device and method. The saline water layer CO2 geological storage salting-out quantitative evaluation device comprises a fluid injection system, a rock core reaction system, a confining pressure system, a back pressure system, a pulse measurement system, a drainage system and a data analysis system. The fluid injection system, the confining pressure system, the back pressure system and the liquid drainage system are respectively communicated with the rock core reaction system, and the pulse measurement system and the data analysis system are respectively and electrically connected with the rock core reaction system. According to the embodiment of the invention, the rock core reaction system provides an experiment environment, the fluid injection system provides scCO2 and saline water required by an experiment, the pulse measurement system provides a sound wave signal for a rock sample, and the data analysis system analyzes various data acquired by the experiment and obtains a saline water layer CO2 geological storage salting-out quantitative evaluation result. And a scientific basis is provided for an injection process and storage safety of geological storage of CO2.

The present disclosure relates to a method for assessing injection of a fluid into a borehole (11) defined by a borehole wall (12) extending into a body (10), the method comprising: - initiating (S1) the injection of the fluid into the borehole (11) using a fluid injection arrangement, - detecting (S2) fluid outside the borehole (11) and the fluid injection arrangement (20) using a detection device (30), and - on the basis of at least one of the following: - a detected position of the detected fluid outside the borehole (11) and the fluid injection arrangement (20), - an injection volume of the fluid, and - a time lapse (TL) from the time of initiation of fluid injection into the borehole (11) to the time of fluid detection outside the borehole (11) and the fluid injection arrangement (20), assessing (S3) the injection of fluid.

A kind of high temperature and high pressure conditions under the fracture of compacted rock permeation resistivity measuring device and method, including: core holder, fluid injection system, resistivity measurement system, pressure applying device and heating device;The device can be carried out under the condition of high temperature and high pressure simultaneously, simulate the fluid permeation process of fractured rock under different temperature and pressure conditions, wherein resistivity measurement system can measure the rock resistivity of permeation process in real time.The device has high measurement accuracy, the test result is intuitive, the device structure is simple, the sealing property, corrosion resistance and heat insulation effect are excellent, can be applied to rock fracture permeation resistivity measurement under different conditions, can quantitatively analyze the influence of temperature, pressure, fluid properties and rock fracture on rock permeability and resistivity, establish the mathematical model of the relationship between permeability and resistivity of fractured rock, can provide theoretical basis for geothermal development reservoir permeability resistivity prediction and evaluation.

A method for fracturing a subsurface rock formation for hydrogen production includes injecting a fluid comprising water into a subsurface rock formation under controlled conditions, generating fractures in the subsurface rock, and recovering hydrogen gas produced by subsurface rock after the generation of the fractures. The fluid is injected at a pressure below the breakdown pressure of the subsurface rock.

The invention provides a blowout control method based on wellhead methane adsorption, which comprises the following steps of: compounding a methane adsorption material with other necessary drilling fluid additives to form high-density composite well killing fluid in a key stage (namely when well control dangerous conditions such as overflow or well kick occur) before blowout; and then, at the position 100-200 m below a well mouth, the composite well killing fluid is injected into a shaft through special well killing fluid injection equipment according to preset injection parameters. According to the method, slipping and rising of methane bubbles invading a shaft are effectively restrained through the high density of well killing fluid, meanwhile, methane gas in the shaft is adsorbed in real time through a methane adsorption material compounded in the well killing fluid, gas column expansion and pressure rising are effectively controlled in the early stage of gas invasion through the dual-action mechanism of density suppression and active adsorption, and the gas invasion safety is effectively improved. Therefore, blowout is prevented or development of blowout is restrained.

A system for implementing and optimizing the storage potential of subterranean carbon mineralization can include a fluid injection well subsystem having an injection wellbore, a pumping system, and a fluid injection completion system disposed at an injection range along the injection wellbore, where the fluid injection completion system is configured to control an injection rate of pressurized fluid from the injection range into an active storage zone within a subterranean rock formation. The system can also include a fluid production well subsystem having a production wellbore and a fluid production completion system disposed at a production range along the production wellbore, where the fluid production completion system is configured to control an inflow rate of production fluid from the active storage zone into the production range of the production wellbore. The system can further include a monitoring subsystem configured to monitor carbon mineralization in the active storage zone.

The invention provides a large-diameter pipeline flow dynamic detection method and system based on temperature gradient tracking, and relates to the technical field of flow detection.The large-diameter pipeline flow dynamic detection method comprises the steps that multiple layers of temperature sensor arrays are arranged on the outer wall of a pipeline, and temperature field distribution data are obtained; determining a thermal fluid injection scheme based on the initial flow parameters; acquiring a temperature characteristic data set by adopting a space-time sampling control unit; utilizing a deep learning algorithm to reconstruct a thermal fluid motion track; and establishing a flow calculation model to obtain a real-time flow value. According to the invention, high-precision, real-time and reliable monitoring of the flow of the large-diameter pipeline can be realized, and the accuracy and stability of flow detection are improved.

A method of calibrating dosing valves of a sprayer system of an agricultural implement comprises initiating calibration by filling a calibrating tube with fluid having a fluid from an auxiliary tank of the sprayer system, measuring a volume of the fluid filled into the calibration tube, pumping the fluid in the calibration tube to the dosing valves to calibrate the dosing valves with respect to flow characteristics of the fluid with the dosing valves being capable of a high fluid flow rate to a low fluid flow rate ratio of at least 100:1 for the fluid. The method also includes pumping, during a pump from concentration tank mode, the fluid in the concentration tank to the dosing valves and then to a mixing apparatus with the fluid to be mixed with a carrier fluid from a primary tank of the sprayer system.

A wellhead, including a fluid injection system disposed in the wellhead, a fiber injection system disposed in the wellhead and operably connected to the fluid injection system to inject fiber into the fluid injection system. A multimodal fluid injection valve, including a body having a check valve therein, a side pocket physically and fluidly connected to the body, the side pocket including a fiber anchor therein. A method for instrumenting a preexisting gas lift or chemical injection system, including cleaning the chemical injection system, and injecting optic fiber through the chemical injection system. A wellbore system including a borehole in a subsurface formation, a string in the borehole, a surface system operably connecting both a chemical or gas injection device and an optic fiber injection device to a gas lift or chemical injection subsystem in the borehole, and an optic fiber disposed in the chemical or gas injection subsystem.

The present disclosure generally relates to microfluidics, and to systems and methods for controlling the introduction of fluids. For example, certain aspects are generally directed to microfluidic devices having ports able to direct the end of a pipette tip into an end portion that is sized so as to allow fluid to flow from the pipette tip into an exit fluidly connected to a microfluidic channel. For example, the port may have a tapered portion that directs the pipette tip to the end portion. The end portion may be sized such that it is difficult for fluid to backflush around the pipette tip, and thus, the fluid is able to flow into microfluidic channels within the device, e.g., without resulting in excessive fluid remaining within the end portion. Other aspects are generally directed to methods of making or using such microfluidic devices, kits including such microfluidic devices, and the like.

A conformance control method includes identifying a target location of a wellbore formed from a terranean surface to two subterranean formations that include a high permeability formation having a first permeability and a low permeability formation having a second permeability that is equal or less than one-third of the first permeability. The method includes forming a first plurality of tunnels in the high permeability formation from the wellbore; injecting, into the high permeability formation and the low permeability formation, a chemical fluid from the wellbore through the first plurality of tunnels; expanding a sweep area of the injected chemical fluid by injecting the chemical fluid into the high permeability formation through the first plurality of tunnels; forming a second plurality of tunnels in the low permeability formation from the wellbore; and increasing a contact area of an injection fluid in the low permeability formation with the second plurality of tunnels.

The invention discloses a bionic fracture network fracturing device for a low-permeability coal seam, and relates to the technical field of efficient exploitation of oil fields. A bionic fracture network fracturing device for a low-permeability coal seam comprises a recycling mechanism 1 and a hole sealing mechanism 2. The recycling mechanism comprises a recycling body, a signal transmission module is fixedly embedded in one side of the recycling body, a liquid injection module is fixedly embedded in the other side of the recycling body, and fixing pieces are clamped to the two ends of the recycling body respectively. A first connecting assembly used for being in butt joint with the hole sealing mechanism is arranged on the lower side of the middle of the recycling body. A rod cracking hole located between the signal transmission module and the fixing piece on the same side is formed in one side of the recycling body in a penetrating mode, and a gas hole located between the liquid injection module and the fixing piece on the same side is formed in the other side of the recycling body in a penetrating mode. A rod cracking mechanism is arranged at the rod cracking hole, and a gas mechanism is arranged at the gas hole; the filling liquid flows through the crack pipes and the branch crack holes to form the bionic cracks of the main channel and the pre-branch, so that the connectivity and the coverage range of the crack network are remarkably improved.

The present invention relates to the technical field of coalbed methane development engineering, and discloses a coalbed methane combined production experimental device and method for multiple layers of stacked thin coal seams, comprising a pressure chamber, wherein a coal rock physical model is axially arranged in the pressure chamber, and adjacent coal rock physical models are connected; a fluid injection system, comprising a plurality of fluid injection parts, which are respectively connected to one end of the coal rock physical models and used to inject fluid into the coal rock physical models; a fluid metering system, comprising a plurality of metering parts, which are respectively connected to the other end of the coal rock physical models and are connected to each other; a processing system, comprising a control and data analysis system and a signal acquisition and processing device, wherein the coal rock physical model, the fluid injection part, the metering part and the control and data analysis system are respectively electrically connected to the signal acquisition and processing device. The present invention can realize the coalbed methane production characteristics of multiple layers of stacked thin coal seams, and quantitatively characterize the interlayer crossflow and the fluid and pressure distribution laws.

The present invention discloses a method for fluid injection-induced earthquake experiments under true triaxial stress conditions. The method first creates a cubic rock model containing a fault, obliquely cuts it to form a fault plane, lays out water injection and water pressure detection holes, and injects water to saturate the fault plane. A true triaxial device is then used to apply three-dimensional unequal stresses and maintain stability. Displacement is then used to drive the fault to spontaneous instability, and the inter-seismic instability period is calculated. Finally, a cyclic or constant-rate water injection scheme is set to simulate industrial fluid activity and explore the mechanism of water injection-induced earthquakes. This method for fluid injection-induced earthquake experiments under true triaxial stress conditions can accurately simulate actual stratum stress and water injection conditions, providing a reliable means for studying water injection-induced earthquakes and having significant implications for earthquake prediction, geological disaster prevention and control, and related industrial safety.

A hydraulically driven fluid injection system comprising a reservoir having a first and second chamber and a piston separating the first and second chamber. A reservoir control valve to control the input of a first fuel source to the first chamber. The reservoir control may operate by having an open and a closed state. Alternatively, the reservoir control may have a first mode, a second mode, and a third mode. A second fuel may be provided to the second chamber and a metering valve may be utilized to control the flow of the second fuel to an injector. When the secondary fuel is desired, the reservoir control valve may open to allow the primary fuel to pressurize the first chamber. The result of the pressure on the first chamber causes the piston to apply a pressure to the second chamber. The metering valve may then allow the secondary fuel to flow from the second chamber to an injector.

The invention discloses a rotating disc type fluid mixing device and a working method thereof.The rotating disc type fluid mixing device comprises a mixing disc and a plurality of fluid injection mechanisms, the mixing disc can rotate, and the discharging ends of the fluid injection mechanisms are opposite to the mixing disc so that fluid can be injected to the mixing disc; along with the rotation of the mixing disc, a plurality of fluids on the mixing disc are gradually spread and mixed, and the mixed fluid is thrown out from the edge of the mixing disc. The mixing disc is arranged in the mixing container, and the mixed fluid is thrown onto the inner wall of the mixing container from the edge of the mixing disc and flows downwards along the inner wall of the mixing container so as to perform secondary mixing. The mixing disc is higher than the bottom of the mixing container, a material storage groove is formed in the area, lower than the mixing disc, in the mixing container, and a discharging opening is formed in the bottom of the material storage groove. Various fluids are injected into the mixing disc, the fluids can be spread and mixed along with the rotation of the mixing disc, and the mixing index of a target fluid medium is effectively controlled by controlling the flow speed and the injection angle of the fluids and the rotation speed and the surface damping of the mixing disc.

The application discloses a sidetracking horizontal well large-diameter open-hole filling and acid washing integrated pipe column and a running method thereof. The pipe column comprises an outer pipe column and an inner pipe column, the inner pipe column is arranged in the outer pipe column, and a casing is arranged outside the outer pipe column. The outer pipe column comprises, from top to bottom, a locking device, an outer channel, a releasing device, a fishing device, a slip, a rubber sleeve, a reverse washing device, a filling outer tool, a backflow prevention device, an open-hole screen pipe and an acid washing outer sealing device. The inner pipe column comprises, from top to bottom, an inner channel, a filling inner tool, a check valve, a jetting pipe, an acid washing inner sealing device, a jet tool, a ball catching device and a bottom liquid flow port. The running method comprises the following steps: drilling fluid injection, pipe releasing, normal mud replacement, tubing pressure test, opening of the locking device, filling, reverse well washing without moving the pipe column, normal rotation releasing, segmented acid washing construction, reverse well washing until the outlet is clean and pipe column lifting. The application has the advantages of short construction period, effective prevention of well wall collapse, short construction period, high safety, and good construction effect.

A system for recovering ammonia from an endothermic reaction in a subsurface formation may comprise a subsurface formation; a wellbore fluidly connected to the subsurface formation; a tubing string positioned within the wellbore, wherein the wellbore and an exterior of the tubing string together define a wellbore annulus; a wellhead comprising one or more injection lines and one or more return lines fluidly connected to the wellbore; one or more fluid injection pumps configured to supply an endothermic fluid composition to the subsurface formation through the one or more injection lines and the tubing string, the endothermic fluid composition operable to form ammonia when reacted; and one or more ammonia retention vessels fluidly connected to the return lines for receiving the ammonia through the wellbore annulus.

The present application relates to oil and gas exploration technology field, disclose a kind of fracture conductivity test method and device of formation condition simulation, the present application is based on similarity criterion selects and actual reservoir and similar material of surrounding rock as model raw material, then according to design size manufacturing surrounding rock model and reservoir model with fracturing fracture;Reservoir model and surrounding rock model are assembled to form reservoir surrounding rock model, and fixedly placed on triaxial loading unit;Reservoir surrounding rock model, triaxial loading unit and fluid injection and monitoring unit and displacement detection unit are connected to form fracture conductivity test experimental device, finally based on the experimental device carries out the fracturing fracture conductivity test experiment of reservoir surrounding rock model, and calculates the fracture conductivity coefficient of model.The present application can more accurately simulate the deformation law of fracture in actual reservoir, provide more accurate parameters for oil and gas reservoir numerical simulation model, so as to more accurately evaluate and calculate gas well productivity.

The present application relates to the field of underground fluid intelligent control, and discloses a method for intervention and extraction of ion type ore body solute migration, comprising: establishing a feedback monitoring network for a fluid injection distribution system, obtaining pressure parameters and flow parameters generated by interaction between a controlled branch and a controlled medium; calculating dynamic impedance parameters of internal seepage resistance state of the controlled medium; extracting a follow-up change rate of the dynamic impedance parameters, identifying nonlinear evolution of pore structure induced by flow resistance mutation; comparing the follow-up change rate with a preset threshold value to determine bypass overflow risk; generating a flow dynamic distribution instruction and adjusting valve opening to make the local flow field stable within a preset flow resistance gradient range, wherein the present application solves the problem of sensing loss induced by formation porosity evolution through a dynamic flow resistance feedback intervention mechanism, drives fluid to penetrate into unconsolidated blind areas, and constructs a continuous and dense seepage interception interface.