24 results about "Fluid type" patented technology

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.

The application provides a dense reservoir fluid identification method based on physical data double driving, comprising: performing abnormal value correction and fluid category direct marking on conventional logging data to obtain labeled logging data; performing signal self-adaptive time-frequency conversion on the labeled logging data, and calculating porosity, permeability and water saturation to output physical prior feature channels; inputting two-dimensional multi-channel time-frequency spectrum and the physical prior feature channels into a pre-constructed MDSC-TAM neural network model to extract hidden logging signal frequency domain spectrum series structure and global sedimentary rule to obtain a dense reservoir fluid identification result; and performing physical perception constraint and decision output on the fusion feature representation to obtain a fluid type and confidence. The application solves the data scarcity and model black box bottleneck, improves the engineering practicability of the algorithm, and realizes high-precision identification of the dense reservoir fluid and enhanced physical interpretability.

The utility model relates to a tubular static mixer. Comprising a tubular mixer main body and a plurality of mixing units which are sequentially arranged along the axial direction of the mixer main body, each group of mixing units comprises a group of spiral twisted blades and a splitter plate; the screw pitch and the twisting angle of the twisted blade are dynamically adjusted according to the fluid viscosity; a left-handed structure and a right-handed structure are arranged at the two ends of the mixing unit respectively and are connected in a cross shape through clamping grooves to form four flow channels; adjustable connectors are arranged at the two ends of each mixing unit and are used for adjusting the distance between the mixing units or replacing the modularized mixing units. The problems that in the prior art, a tubular static mixer still has a certain improvement space in the aspects of mixing efficiency, applicable fluid type range, blockage prevention and the like, for example, when some fluids with large viscosity difference are mixed, ideal mixing uniformity is difficult to achieve, meanwhile, a mixing element is prone to blockage, and the mixing efficiency is poor are solved. And normal operation of equipment is influenced.

The application discloses a multiphase fluid flowmeter, which comprises a flowmeter base, at least two pressure sensors and at least one pressure reducing device; the pressure reducing device is arranged in the flowmeter base, and the pressure sensors are arranged at two ends of the pressure reducing device. The flowmeter does not need movable structures such as impellers to calculate flow, so that the flowmeter is simple and exquisite in structure, differential pressure measurement and flow conversion can provide a wider linear region, and the design without movable structures can ensure accuracy and facilitate replacement, so that the flowmeter can not be limited by fluid types and viscosity, and has a wider application range.

Systems and devices related to smart regulators and smart manifolds for welding-type systems are disclosed. The smart regulators can be coupled to fluid tanks and provide information about current pressure(s) and / or flow rates to remote devices and / or operators. The remote devices can also determine and / or output additional information, such as remaining fluid and / or the time remaining before a fluid runs out or becomes dangerously low. The smart manifolds can be configured to work with several different fluid supply devices. In this way, an operator can easily mix multiple fluid types, switch between different fluid types, and / or switch between different fluid tanks.

The application discloses a fluid type acceleration sensor, a preparation mold and a preparation method. The fluid type angular acceleration sensor comprises a shell, three semi-canal and a container connecting the semi-canal, a channel for liquid circulation is arranged in the semi-canal, the container has a cavity, the cavity is communicated with the channel of each semi-canal to jointly form a closed fluid cavity, wherein the central axis of the three semi-canal respectively bends and extends in three planes, the three planes pass through an original point and are perpendicular to each other, three ampulla caps are correspondingly arranged in the semi-canal, the edge of the ampulla cap is connected with the semi-canal to close the channel, the ampulla cap can be deformed by being pushed by the liquid in the channel, and three strain gauges are correspondingly arranged in the ampulla cap and are configured to follow the deformation of the ampulla cap and convert the deformation into an electric signal output. The fluid type acceleration sensor, the preparation mold and the preparation method can provide more accurate and reliable angular acceleration signals.

This invention provides a fluid component and a method for generating its fluid layout. The fluid component includes: at least one first pipe, each first pipe being connected to a fluid conveying device; wherein the fluid conveying device includes a distributor, at least one second pipe connected to the distributor, and the other end of all or part of the second pipes connected to a fluid storage device; each second pipe is equipped with a power device; the distributor is also connected to the first pipe; a check valve is provided between the power device and the distributor; and a control device is also included, connected to each power device, for generating control commands according to a preset fluid layout, and controlling the opening and closing of the power devices according to the control commands; the fluid layout represents the fluid type at each position in the first pipe. This invention enables fluid to flow in the first pipe according to a preset fluid layout, thereby expressing information through the fluid-carrying first pipe, with a relatively simple structure.

A pump system for selectively extracting nonaqueous phase liquids (NAPLs) from groundwater includes a fuel pump with current monitoring and a control assembly. The system utilizes a conductive probe within a probe body to detect a fluid interface, distinguishing NAPLs from water by measuring conductivity. The control assembly monitors the pump's current draw and adjusts operation to avoid water intake, thereby protecting the pump from damage. The probe body features an insulated shell to ensure accurate readings, and the control assembly uses real-time data to activate or deactivate the pump based on fluid type. The system is further configurable to calibrate for various contaminant conditions, optimizing efficient NAPL extraction from contaminated environments.

A method of identifying inflow locations along a wellbore comprises obtaining an acoustic signal from a sensor within the wellbore, determining a plurality of frequency domain features from the acoustic signal, and identifying, using a plurality of fluid flow models, a presence of at least one of a gas phase inflow, an aqueous phase inflow, or a hydrocarbon liquid phase inflow at one or more fluid flow locations. The acoustic signal comprises acoustic samples across a portion of a depth of the wellbore, and the plurality of frequency domain features are obtained across a plurality of depth intervals within the portion of the depth of the wellbore. Each fluid flow model of the plurality of fluid inflow models uses one or more frequency domain features of the plurality of the frequency domain features, and at least two of the plurality of fluid flow models are different.

This invention provides a method and system for fluid identification in tight sandstone gas-bearing formations. It employs a combined three-porosity logging method, a combined nuclear magnetic resonance (NMR) logging and density logging method, and a combined NMR logging and three-porosity logging method for fluid identification in tight sandstone gas-bearing formations. The method constructs multiple gas-bearing formation sensitive factors through theoretical analysis, amplifying the differences between gas-bearing formations and building fluid identification charts. In the interpretation of new target layers, fluid discrimination is performed based on each chart, and the final interpretation result is determined using the chart consistency rate method or the absolute majority voting method. The fluid sensitive factors constructed in this invention, and the cross-plots built based on these factors, can effectively distinguish fluid types. The comprehensive discrimination strategy organically combines the results of multiple methods, eliminating the limitations of any single method. The interpretation results have been verified by oil testing, showing a significantly improved consistency rate.

The invention relates to the technical field of geophysical well logging interpretation, in particular to a compact sandstone reservoir complex fluid self-adaptive identification method and device, and the method comprises the steps: analyzing the relation between different fluid types and lithology, physical property, pore structure and brittle reservoir characteristic parameters in a histogram and cross plot mode, and qualitatively determining the main control elements of the fluid type difference; constructing required quantization parameters according to the main control elements; performing normalization processing on the logging curve and the quantization parameters; selecting sensitive parameters from the existing logging curve and the constructed quantization parameters by using a spider diagram; fusing the multiple parameters by using a principal component analysis method, and constructing fluid type master control elements; establishing a label database according to the constructed index and the corresponding fluid type; and training and self-adaptive explanation of a complex fluid identification model are carried out. According to the method, the recognition precision of the complex fluid of the compact sandstone reservoir is improved, and a geological foundation is laid for subsequent dessert evaluation and target optimization.

The invention relates to the technical field of oil and gas field exploitation, in particular to a core type adaptive SC-CO2 phase state stress collaborative fracturing method. The method specifically comprises the steps that fracturing experiments under various variable conditions are carried out, and fracturing pump pressure is obtained; the variable conditions comprise a core type, an injection fluid type, an injection flow rate and axial pressure and confining pressure conditions; converting the core type and the injected fluid type into virtual variables; establishing a multiple linear regression model by taking the fracture pump pressure as a dependent variable and taking the core type, the injection fluid type, the injection flow rate and the difference between the axial pressure and the confining pressure as independent variables; fitting by adopting a least square method to obtain a regression coefficient of each independent variable; performing t inspection to obtain a p value of each independent variable, and screening out the independent variables with the p values smaller than or equal to 0.2; and supercritical CO2 phase state stress synergistic fracturing is carried out. The method solves the problems that an existing method is unstable in effect in practical application, and the diversified requirements of different unconventional reservoirs are difficult to meet.

This invention provides a fluid identification method, apparatus, processor, and machine-readable storage medium, relating to the field of reservoir logging evaluation. The method includes: determining logging parameters of the test layer, adjacent standard water layer, and fluid type at multiple test depths of the tested formation; determining the invasion factor and oil-bearing discrimination index at each test depth; establishing a fluid cross-plot using the oil-bearing discrimination index, invasion factor, and fluid type at multiple test depths; determining the oil-water boundary based on the fluid cross-plot; determining the target layer logging parameters and adjacent standard water layer logging parameters at the depth to be tested; determining the invasion factor and oil-bearing discrimination index at the depth to be tested; and determining the fluid type at the depth to be tested using the fluid cross-plot, the oil-water boundary, and the oil-bearing discrimination index and invasion factor at the depth to be tested. This invention simplifies the fluid identification process and accurately identifies the fluid properties in underground reservoirs.

Systems, methods, and apparatuses for generating a fluid analysis report with key issues to improve vehicle maintenance are provided. A processing circuit is configured to: obtain information regarding a plurality of fluids from a plurality of vehicles; determine a plurality of thresholds based on the information; analyze a fluid sample from a particular vehicle to identify a fluid type of the fluid sample; identify a vehicle type of the particular vehicle associated with the fluid sample; retrieve a population of the obtained information pertinent to at least one of the identified fluid type of the fluid sample or the vehicle type of the particular vehicle; retrieve at least one threshold associated with the retrieved population; compare a characteristic of the fluid sample to the retrieved at least one threshold; and generate and provide a dynamic graphical user interface regarding the comparison to a computing device.

A piston for a fluid machine, intended to be mounted at least partially inside a bushing of the fluid machine in such a way as to be relatively reciprocally movable relative to the bushing, the piston extending in a main direction and comprising a head having a first end of the piston and a shaft having a second end of the piston, according to the invention, the first end is intended to define a fluid expansion and / or compression chamber together with a bushing of the machine, the shaft comprising a side wall provided with at least one annular groove defined between a first and a second castellated member, the groove being equipped with a gasket-type seal for cooperating in a sealing manner with the side wall of the bushing, the seal is provided with a through-hole allowing fluid flow from the expansion and / or compression chamber to the second end, the seal comprising a cavity separate from the through-hole, the cavity comprising a compression system for pressing the seal against the first and second castellated members in the main direction, the compression system being of mechanical and / or fluidic type. The invention further relates to a fluid machine.

The invention relates to the technical field of oil-gas exploration and development, and particularly discloses a seismic-electric fusion reservoir fluid identification method, which comprises the following steps of: firstly, obtaining a three-dimensional seismic horizon, further obtaining a geological framework of a work area according to the three-dimensional seismic horizon, and inverting electromagnetic data to obtain an inversion resistivity profile; and the inversion resistivity of the target stratum of the work area is obtained by combining the geological framework and the inversion resistivity profile. And based on the resistivity fluid type cross plot, the fluid type of the target layer can be identified by the inversion resistivity of the target layer. Compared with a traditional fluid identification technology, the reservoir fluid identification method integrates the spatial distribution depiction advantage of well-to-seismic combination and the advantage that an electrical method is sensitive to fluid, is not limited to identification of the fluid at the drilling position, can accurately identify the fluid of each reservoir in a work area, and is high in fluid identification accuracy, large in identification range and easy to operate.

The embodiment of the present application relates to the technical field of oil and gas field exploration and development geology, and discloses a method and equipment for identifying fluid type of tight sandstone gas reservoir by well logging, which comprises the following steps: obtaining sensitive well logging curves of blind wells in the tight sandstone gas reservoir; the fluid type of the blind well is unknown; identifying the fluid type of the blind well according to the sensitive well logging curves of the blind well and a pre-generated fluid determination model; the fluid determination model is generated by a pre-generated convolutional neural network and an integrated algorithm model, the convolutional neural network is used to extract first feature data of the sensitive well logging curves of the blind well, the integrated model is composed of multiple machine learning models and is used to identify the fluid type of the blind well according to the first feature data, and the convolutional neural network comprises a fully connected layer. The method provided by the present application avoids the significant difference of the well logging identification effect of a single algorithm model on the fluid type of the tight sandstone gas reservoir, and significantly improves the overall identification stability and accuracy of the model.

The application discloses a curtain opening system dissolution quantitative evaluation method under a high-temperature closed background, which comprises the following steps: carrying out source partition on a research area, determining mineral composition, interstitial type and pore type of different source areas, and determining compaction intensity sequence of different source areas; reconstructing a time-space sequence of diagenetic fluid activity, establishing a dynamic model of fluid-rock interaction and pore evolution; determining a mineral differential dissolution conversion mechanism; quantifying mineral differential dissolution under a curtain opening / closed system; and based on mineral composition component difference, fluid type and mineral dissolution effect difference, establishing a curtain opening system deep clastic rock reservoir dissolution quantitative evaluation method under a closed background by combining diagenetic mineral quantitative statistics and theoretical calculation. The application realizes quantitative-semi-quantitative prediction of dissolution effect, thereby delimiting a favorable dissolution development area, and effectively improves reservoir prediction precision, provides a scientific basis for drilling deployment, and reduces exploration risk.

This application relates to the field of rock physics research, and discloses a method, apparatus, equipment, and medium for quantitatively testing the fluid saturation inside rocks. The method includes: obtaining a dry rock sample; pressurizing and saturating the dry rock sample, and performing nuclear magnetic resonance (NMR) testing to obtain the T2 spectrum of a fully saturated rock sample; centrifuging the fully saturated rock sample and performing NMR testing to obtain the T2 spectrum of the centrifuged rock sample; and determining the fluid saturation in the rock sample based on the T2 spectrum of the fully saturated rock sample and the T2 spectrum of the centrifuged rock sample. The quantitative testing method for fluid saturation inside rocks provided by this application more accurately determines the type, content, and distribution of fluids inside rocks.

The application provides a reservoir fluid identification method, device, equipment and medium. It relates to the technical field of tight gas reservoir fluid identification. The method comprises the following steps: obtaining well logging data of a target work area; constructing a training sample set based on the well logging data, screening sensitive well logging parameters, and establishing a parameter combination space covering different missing situations; training a missing parameter self-adaptive compensation model for each missing situation; constructing a parameter self-adaptive fluid identification model based on complete samples and compensated samples; obtaining measured parameters of a well to be identified, calling a corresponding compensation model to complete the missing parameters, and then inputting the parameters into the identification model to obtain a fluid type identification result. The application can adapt to changes and missing of well logging parameters, avoid repeated modeling, and improve identification accuracy.

The present application relates to the technical field of oil and gas field exploitation, and particularly relates to a core type adaptive SC-CO2 phase state stress collaborative fracturing method. Specifically comprising: carrying out fracturing experiments under multiple variable conditions to obtain a fracturing pump pressure; the variable conditions are core types and injection fluid types, injection flow rates, and axial pressure and confining pressure conditions; converting the core types and the injection fluid types into virtual variables; taking the fracturing pump pressure as a dependent variable, and taking the differences between the core types and the injection fluid types, the injection flow rates, and the axial pressure and the confining pressure as independent variables to establish a multiple linear regression model; adopting a least square method to perform fitting to obtain a regression coefficient of each independent variable; performing t test to obtain a p value of each independent variable, and screening out independent variables with p values less than or equal to 0.2; and performing supercritical CO2 phase state stress collaborative fracturing. The present application solves the problem that the existing method is unstable in actual application and is difficult to meet the diversified needs of different unconventional reservoirs.

The invention discloses a reservoir fluid identification method and device, electronic equipment and a medium, and is applied to the field of sandstone reservoirs. The method comprises the following steps: acquiring original conventional data and reservoir density of a reservoir corresponding to a to-be-measured well log, and determining an original curve corresponding to the original conventional data; performing correction processing on the original curve based on the correction curve specification to obtain a corrected curve; determining a neutron-sound wave envelope area formed by neutron data and sound wave data in the original conventional data according to the corrected curve; and based on a reservoir fluid identification judgment criterion, determining a fluid type corresponding to the reservoir according to the reservoir density and the neutron-sound wave envelope area. According to the method, the type of the reservoir fluid is judged by comprehensively analyzing the two parameters of the neutron-sound wave envelope area and the reservoir density, the parameters are not influenced by factors such as formation resistivity and human factors, the properties of the reservoir fluid can be accurately, rapidly and visually judged, and the judgment accuracy of the reservoir fluid is improved.

The application discloses a tight gas reservoir fluid occurrence and fracturing fluid water lock damage evaluation system and method, wherein the tight gas reservoir fluid occurrence and fracturing fluid water lock damage evaluation method comprises the following steps: taking out a core sample from a tight gas reservoir; through a series of treatments on the core sample and by using a nuclear magnetic resonance T1-T2 spectrum technology, a fluid occurrence chart capable of distinguishing different fluid types in the core is established; fracturing fluid is injected into the core sample to simulate water lock damage, then gas displacement is carried out under different injection pressure differences, and nuclear magnetic resonance T1-T2 spectrum is analyzed based on the fluid occurrence chart, so that the residence state of the fracturing fluid is qualitatively evaluated. The water lock damage evaluation method based on the nuclear magnetic resonance T2 and T1-T2 technologies can realize accurate quantification of the degree of water lock damage by analyzing the distribution and migration characteristics of the fluid in the reservoir core sample, and provides a theoretical basis and experimental means for formulating a plugging removal measure.