Abstract: A system and method for deploying and retrieving a welltracker in a well include coupling a Christmas tree to the well, coupling a sensor deployment capsule to the Christmas tree, inserting and storing the welltracker into the cylindrical housing via a removable cap screw, and deploying the welltracker through the Christmas tree and into the well. The system and method further include dissolving a dissolvable weight on the welltracker at a well fluid pressure threshold, retrieving the welltracker to the cylindrical housing, bleeding off trapped pressure in the cylindrical housing from retrieval, via the drain valve, through the pressure transfer line, and controlling pressure in the sensor deployment capsule via the pressure gauge. The sensor deployment capsule includes a cylindrical housing including a removable cap screw, a drain valve coupled to the cylindrical housing and a pressure transfer line, and a pressure gauge coupled to the removable cap screw.

Abstract: Systems and methods are disclosed for providing virtual assays of an oil sample such as crude oil based on Fourier transform ion cyclotron resonance (FT-ICR) mass spectroscopy carried out on the oil sample, and the density of the oil sample. The virtual assay provides a full range of information about fractions of the oil sample including naphtha, gas oil, vacuum gas oil, vacuum residue, and other information about the properties of the oil sample. Using the system and method herein, the virtual assay data pertaining to these several fractions of the oil sample and the oil sample itself are obtained without fractionation of the oil sample into the several components.

Abstract: Described herein are systems, devices, and methods for generating and delivering an inhalable vapor or aerosol. In some embodiments, the systems, devices, and methods described herein are used to generate and deliver a vapor or aerosol containing tobacco for use in, for example, traditional smoking or, for example, to deliver a smoking cessation therapy. In some embodiments, the systems, devices, and methods described herein are used for generating and delivering a vapor or aerosol comprising a medicament. For example, in some embodiments, the systems, devices, and methods described herein are used to deliver an inhalable medicament to the lungs of a patient.

Abstract: Provided is a method for shale gas production prediction, including: acquiring real shale gas production data, and determining a target production decline curve model according to the real shale gas production data; setting a time step for production prediction, and obtaining a linear production decline curve by performing production prediction by using the target production decline curve model based on the time step; determining target shale gas production residuals according to the linear production decline curve and the real shale gas production data, inputting the target shale gas production residuals to a long short-term memory, and obtaining a residual prediction result by performing production prediction according to the long short-term memory and the time step; and determining a target production prediction result of shale gas well to be subjected to production prediction based on the linear production decline curve and the residual prediction result.

Abstract: A smart device located in a wellbore head during production operations in a well is disclosed. The smart device has a transceiver that exchanges signals with a wellhead sensor, the wellhead sensor monitoring a hydraulic line with T-connection for bleed-off. The transceiver communicates with the wellhead sensor through a first communication link established by the smart device. A localization system identifies pressure information relating to information of the well, including sizes of an inner casing and of an outer casing of the well, and a processor implements a combination of artificial intelligence and machine learning to pre-emptively provide warnings relating to possible estimated CCA behavior. Report information is generated that includes whether a source from a bleed-off is downhole or from trapped compressed fluid due to heat expansion, and provides a forward plan for a remedial job based on previous history of similar CCA behavior in the well.

Abstract: A method of performing a remediation process on a flowline comprises: calculating an asphaltene deposition profile characterizing blockage of the flowline by a deposit of asphaltene; determining, based on the asphaltene deposition profile, whether the blockage exceeds a predetermined level of blockage; and treating the flowline with an asphaltene solvent to dissolve at least a portion of the deposit when the blockage exceeds the predetermined level. A computer program product comprises instructions that are stored on a computer-readable medium and that, when executed by a processor, cause an apparatus to: calculate an asphaltene deposition profile characterizing blockage of a flowline by a deposit of asphaltene; determine, based on the asphaltene deposition profile, whether the blockage exceeds a predetermined level of blockage; and determine to treat the flowline with an asphaltene solvent to dissolve at least a portion of the deposit when the blockage exceeds the predetermined level.

Abstract: A flow measurement apparatus can include a main flow passage, a bypass flow passage having an inlet and an outlet connected with the main flow passage, a mass flowmeter connected in the bypass flow passage between the inlet and the outlet, and a flow restrictor connected in the bypass flow passage between the inlet and the outlet. A method can include connecting the flow measurement apparatus, so that a fluid flow in the well also flows through the flow measurement apparatus, and determining at least one rheological parameter of a non-Newtonian fluid, based on an output of the flow measurement apparatus.

Abstract: An apparatus to test a drilling fluid in a laboratory includes a test cell configured to test the fluid to determine a Sag Factor of the fluid. The test cell may be heated with a heating jacket to a predefined temperature. A plurality of densitometers are configured to continuously measure a density of the fluid circulating in the test cell. A computing device processes the density measurements to determine a Sag Factor of the drilling fluid.

Abstract: Methods for optimization of liquid oil production by huff-n-puff in shale reservoirs to achieve an improved (and optimal) oil recovery factor. The process determines and utilizes the optimum huff and puff times, number of cycles and soaking time under practical operation and reservoir conditions. The huff time in the process is a period so long that the pressure near the wellbore reaches the set maximum injection pressure during the huff period. The puff time in the process is the time required for the pressure near the wellbore to reach the set minimum production pressure during the puff period. Soaking is typically not necessary during the huff-n-puff gas injection in shale oil reservoirs. The number of huff-n-puff cycles is determinable by the time in which the economic rate cut-off is reached.

Abstract: Provided are a depth information processing method, an apparatus, and a storage medium, which relate to the field of image processing and, in particular, to computer vision, deep learning and autonomous driving. A specific implementation includes: determining intermediate depth information of a target scene according to sparse depth information of the target scene by a sub-model unit in a depth information supplementing model; and using intermediate depth information determined by a tail sub-model unit in the depth information supplementing model as dense depth information of the target scene.

Abstract: A water detection and measurement system for a resource extraction system includes a controller configured to receive first sensor signal(s) indicative of a pressure of a multiphase fluid and second sensor signal(s) indicative of a temperature of the multiphase fluid. Furthermore, the controller is configured to determine a fraction of condensed water within the multiphase fluid based on the pressure and the temperature. The controller is also configured to determine a flow rate of the condensed water based on the fraction of the condensed water within the multiphase fluid and a gas flow rate of the multiphase fluid. In addition, the controller is configured to receive third sensor signal(s) indicative of a fluid parameter of the multiphase fluid, and the controller is configured to determine a flow rate of formation water within the multiphase fluid based on the fluid parameter and the flow rate of the condensed water.

Abstract: An actuator with an embedded motherboard is provided. Firmware on the motherboard executes a kickoff mode to bring an oil well online by controlling a control valve of a gas injection line to change pressures and gas flow rates in the injection line. The kickoff mode includes four phases based on the gas flow rates and pressures associated with the gas injection line. Firmware also executes an optimization mode that optimally finds a bottom hole pressure for the oil well by decreasing and increasing the gas injection rates. The optimization mode can continuously be executed after kickoff exits to maintain optimal oil extraction and bottom hole pressures for the well. Firmware further executes a well protection mode that continuously monitors current pressures and flow rates and jumps directly to a needed phase of kickoff based thereon.

Abstract: Downhole display systems and methods. A display of one or more portions of a well log of a well during drilling may be displayed together with a display of one or more portions of one or more reference well logs, which may be presented as projected onto one or more planes, respectively. The logs may be segmented and correlated, with the segments or correlated portions displayed in different colors. A user may manipulate the display of the logs or log segments to assist in correlating them. The user may also manipulate the display so that the view provided of the wellbore and the projected logs changes in any one or all of three dimensions. In addition, the user may manipulate the display by navigating along the length of the borehole to view the projected logs at any point along the well path.

Abstract: A wellbore that supplies production fluid from a first production zone and a second production zone is produced. Production fluids from the first and second production zone are comingled within a same production tubular. A first tracer is pulsed into the first production zone. A second tracer is pulsed into the second production zone. The first tracer and the second tracer are barcoded such that the first tracer and the second tracer can be differentiated from one another. A first tracer decay is measured at a topside facility. A second tracer decay is measured at the topside facility. A water cut of the first production zone and the second production zone is determined based upon the first tracer decay and the second tracer decay.

Abstract: A pumping system for performing a borehole operation including pumping a fluid into a borehole. The system may include a motor, a transmission, a pump, and a control system. The motor, transmission, and pump may each include sensors. The transmission may be operatively coupled to the motor. The pump may be operatively coupled to the transmission and configured to pump fluid into the borehole. The control system may be in communication with the motor sensors, the transmission sensors, and the pump sensors. The control system may be configured to monitor the operation of the motor, the transmission, and the pump, determine if at least one of the motor, the transmission, or the pump is operating outside of predetermined parameters, and determine at least one component of the motor, the transmission, or the pump that is most likely to cause the operation to be outside of the predetermined parameters.

Abstract: Methods and systems for monitoring an annulus pressure of a well. The method includes performing periodic surveys to monitor an annulus pressure of the well, determining the annulus pressure of the well over a period of time, comparing the annulus pressure to a Maximum Allowable Wellhead Operating Pressure (MAWOP), and generating a decision on whether the well is a workover candidate based on results of the comparison. The system includes a collecting tool that performs periodic surveys to monitor an annulus pressure of the well, determines the annulus pressure of the well over a period of time, and broadcasts information relating to the periodic surveys. The system further includes a processor that obtains the information relating the periodic surveys, compares the annulus pressure to a Maximum Allowable Wellhead Operating Pressure (MAWOP), and generates a decision on whether the well is a workover candidate based on the results of the comparison.

Abstract: A wireless flow control device includes a shiftable apparatus and a power source configured to provide power to shift the shiftable apparatus from a first position to a second position. The wireless flow control device also includes a valve that forms a first fluid flow path through the wireless flow control device while the shiftable apparatus is in the first position. The wireless flow control device further includes an actuation assembly, which, when actuated, forms a second fluid flow path through the wireless flow control device, and a turbine configured to recharge the power source.

Abstract: A modified gathering manifold is disclosed, including a sampling header coupled to each of multiple production lines of wells, and a plurality of diverters, each coupled to one of the production lines, upstream of a relief header coupled to each of the plurality of production lines and a production header associated with the manifold and coupled to each of the plurality of production lines. The sampling header receives a production fluid diverted by a diverter in the open position. The manifold also includes a three-phase separator coupled to the sampling header downstream of the plurality of diverters that separates the production fluid into crude oil, water, and gas, and detects a volume flow rate for each. A return header passes the crude oil, the water, and the gas from the three-phase separator into the production header where they are combined into a hydrocarbon fluid flow.

Abstract: Piston-less downhole tools and piston-less pressure compensation tools are presented. The piston-less downhole tool includes a first chamber comprising a first fluid, the first fluid being a fluid that thermally expands in response to an increase in a temperature of the first fluid. The piston-less downhole tool also includes a tubular having a first end that is fluidly sealed and a second end that is in fluid communication with the first fluid, wherein the tubular is configured to expand in response to thermal expansion of the first fluid. The piston-less downhole tool further includes a second chamber configured to store a second fluid. The tubular of the piston-less downhole tool is configured to contract in response to pressure applied by the second fluid.

Abstract: Described herein are systems and techniques for monitoring for monitoring and evaluating conditions associated with a wellbore and wellbore operations that use neural operators instead of computationally intensive iterative differential equations. Such systems and techniques allow for determinations to be made as operations associated with a wellbore are performed. Instead of having to wait for computationally intensive tasks to be performed or take risks of proceeding with a wellbore operation without real-time evaluations being performed, these wellbore operations may be continued while determinations are timely made, thus improving operation of computing systems that perform evaluations and that make decisions regarding safely and efficiently performing wellbore operations such as drilling a wellbore, cementing wellbore casings in place, or injecting fluids into formations of the Earth.

Abstract: A downhole tool includes a body configured to move in a wellbore formed from a terranean surface to a subterranean formation in a direction downhole of the terranean surface independent of a downhole conveyance attached to the body; one or more sensors positioned in the body, the one or more sensors configured to measure a value associated with at least one of the wellbore or the terranean surface; and at least one mass positioned in the body and configured to adjust an orientation of the body in response to one or more forces acting on the body as the downhole tool moves in the wellbore in the direction downhole of the terranean surface.

Abstract: A system monitors operation of a component in a hydraulic fracturing fleet. A sensor exposed to an external environment of the component is configured to detect external indicia of the operation of the component. Memory stores an artificial intelligence (AI) model, the AI model being trained to monitor the operation of the component in the system. One or more processors are operatively coupled to the memory and the sensor. The one or more processors are configured to obtain data of the external indicia detected with the sensor; input the obtained data into the AI model; detect, with the AI model and based on the input data of the external indicia, one of a plurality of predetermined states corresponding to the operation of the component; and perform a predetermined function based on the detected one of the plurality of predetermined states.

Abstract: A downhole tool includes a choke, a controller, a communication and power element, instrumentation, and a stabilizer. The choke is configured to vary an annular well pressure. The choke includes an expandable element having an expanded position, an expanding position, and an unexpanded position. The controller is connected to the choke and is configured to place the choke in the expanded position, the expanding position, and the unexpanded position. The communication and power element is electronically connected to the controller. Power and instructions are sent to the controller from the communication and power element. The instrumentation is electronically connected to the communication and power element. The instrumentation comprises sensors configured to obtain downhole data and the downhole data is sent to the communication and power element. The stabilizer is configured to centralize the choke within the casing string.

Abstract: A method may include obtaining reservoir data for a geological region of interest. The method may further include obtaining production data regarding one or more wells coupled to the geological region of interest. The method may further include obtaining carbon emission data for the one or more wells. The method may further include determining predicted carbon emission data and predicted production data using a machine-learning model. The method may further include determining one or more stimulation parameters for a stimulation operation based on the predicted carbon emission data and the predicted production data. The method may further include transmitting a command to a control system coupled to an injection well. The command adjusts an amount of carbon dioxide that is supplied to the injection well based on the one or more stimulation parameters.

Abstract: Methods and apparatus for hydrocarbon monitoring are provided. An example method (e.g., performed by a monitoring system) includes receiving one or more first downhole measurements including a first speed of sound (SoS) measurement of a flowing fluid at a first location, wherein a pressure of the flowing fluid at the first location is greater than a bubble-point pressure of the flowing fluid; receiving one or more second downhole measurements including a second SoS measurement of the flowing fluid at a second location, wherein a pressure of the flowing fluid at the second location is less than the bubble-point pressure of the flowing fluid and wherein the flowing fluid is a 3-phase fluid mixture at the second location; and calculating one or more phase flow rates of the 3-phase fluid mixture, based on the first SoS measurement, the second SoS measurement, and a measurement of a bulk velocity of the flowing fluid.

Abstract: There is described a method of locating an area of interest in a conduit, comprising: measuring multiple acoustic signals at multiple locations along the conduit; for each acoustic signal, determining its autocorrelation; and applying a relationship to the determined autocorrelations to estimate a location of the area of interest, wherein the relationship is between autocorrelations of acoustic signals measured in a modelled conduit and modelled areas of interest in the modelled conduit, wherein it is assumed that acoustic signals propagating along the modelled conduit reflect from at least one point in the modelled conduit.

Abstract: A divisible device and a method for sand production and sand control experiment for natural gas hydrate exploitation. The experimental device includes a reactor system, a feeding system, a separation and measurement system, a water-bath jacket system, a support and safety system, and a software recording and analyzing system. In the reactor system, the reactor units can be combined in different ways depending on the experimental conditions and purposes. The reactor units include: left/right reactor units, secondary reactor units, central reactor units, and caps. The combination of a left/right reactor unit with a cap gives a hydrate formation reactor without sand control screens. Combining the left/right reactor unit, secondary left/right reactor units and central reactor units with other accessories allows the reactor system to carry out the simulation experiments with either zero, one, or two view zones, and with either one or two wells.

Abstract: A downhole sub has a body defined by a wall extending in an axial direction from a first end to a second end. An inner surface of the wall defines a flow path through the downhole sub and an outer surface of the wall defines an outer diameter of the downhole sub. A compartment extends from the outer surface into the wall to having a depth less than a thickness of the wall. A housing may be removably fixed in the compartment. One or more mobile devices may be disposed in the housing. Each of the one or more mobile devices includes a sensor encapsulated in a protective material. A control element may block an opening of the housing, the control element is made of a dissolvable material configured to dissolve at a predetermined depth in a wellbore and release the one or more mobile devices into the wellbore.

Abstract: A downhole monitoring system for continuously measuring in real-time a fluid produced from a reservoir includes a tubing extending into a wellbore, spaced apart packers forming annular seals between the tubing and a wall of the wellbore, isolated compartments formed between the spaced apart packers, each compartment having an opening in the tubing to allow fluid communication from the reservoir to surface equipment, and an ultraviolet spectrometer installed in each compartment. The ultraviolet spectrometer includes an ultra-violet source that excites diamondoids, a photomultiplier to quantify the excited diamondoids, and an electronic circuit that digitizes a response from the photomultiplier and sends the response to the surface of the wellbore. Additionally, a method includes continuously monitoring and in real-time a fluid produced from a reservoir and determining reservoir connectivity and reservoir profiling.

Abstract: A power tong includes a lower tong and an upper tong, each with multiple grippers distributed around a tubular passage, for gripping a lower tubular and ripping an upper tubular respectively. A torque actuator includes a first hydraulic drive and a second hydraulic drive, for rotating the upper tong relative to the lower tong. The first hydraulic drive and the second hydraulic drive each have a drive shaft that supports a guide wheel for cooperating with a guide track, and a pinion for cooperating with a rack, which guide wheel and pinion are concentrically, mounted on the drive shaft of the hydraulic drive. The hydraulic drives are mounted with the drive shafts parallel to the main axis, and the upper tong or the lower tong comprises a guide track receiving the guide wheel and a rack cooperating with the pinion.

Abstract: Systems, computer-readable media, and methods for valuating measurement data, of which the method includes obtaining a first model of a subsurface volume, determining a baseline control parameter based on the first model, receiving new measurement data measured using a data collection device, the new measurement data representing one or more characteristics of the subsurface volume, and obtaining a second model of the subsurface volume based in part on the new measurement data. The first model is not based on the new measurement data. Further, the method includes determining an enhanced control parameter based on the second model, determining an enhanced value corresponding to the second model using the enhanced control parameter, determining a realized value corresponding to the second model using the baseline control parameter, and calculating a value of the new measurement data by comparing the enhanced value and the realized value.

Abstract: The disclosure provides for a bottom hole assembly that comprises a housing and a caliper arm. The caliper arm is pivotally coupled to the housing at a hinge disposed within the housing, wherein the caliper arm is operable to rotate about the hinge between a first position within the housing and a second position external to the housing. The bottom hole assembly further comprises a linear actuator coupled to the caliper arm and operable to extend the caliper arm to the second position, wherein the caliper arm is biased to remain in the second position in contact with a borehole wall. The bottom hole assembly further comprises a sensor disposed within the housing and operable to monitor a position of the caliper arm.

Abstract: The present disclosure provides an in-situ method for removing sulfates. The method comprises delivering at least one low molecular weight organic compound (LMWOC) to soil or groundwater to attain a concentration of the LMWOC of 750-3000 mg/L, such as 1000-2000 mg/L, or about 1500 mg/L, especially whereby sulfate is reduced to below 250 mg/L in the soil or groundwater. The method may further comprise contacting the soil or groundwater with an oxidizer, such as hydrogen peroxide, whereby the concentration of metals or metalloids is reduced in the soil or groundwater.

Abstract: The present invention provides a composition and a method for mitigating formation or activity of a corrosion-associated biofilm on metal surfaces of pipelines. The pipelines are first treated with pigs i.e. bi-di pigs for removing/disturbing biofilm, followed by microbial treatment i.e. application of microbecidal composition. The microbecidal composition comprising at least one alcohol, one corrosion inhibitor, one surfactant, one biocide and a lignin-based nanoparticle. The lignin-based nano particle is functionalized with amine functionalizing agent. The present composition and method is eco-friendly, as low concentration is sufficient and further, regular dosing is not required for MIC control.

Abstract: A method for performing a maintenance operation of a well in an oil/gas field. The method includes identifying an extent of corrosion deposit of the well, predicting, using a descaling model of the oil/gas field and based on the extent of corrosion deposit, expected descaling metal loss in a tubular of the well, calculating, based on the expected descaling metal loss, a tubular burst/collapse pressure for a predicted thickness of the tubular, comparing the tubular burst/collapse pressure against a well operating pressure to generate a comparison result, and performing the maintenance operation of the well based on the comparison result.

Abstract: A mandrel in production tubing within a well has a side pocket with an inlet port for connection to an upper control line segment that extends upward alongside the production tubing. An outlet port is below the inlet port for connection to a lower control line segment extending below the pocket. A filter assembly is lowered through the production tubing into the pocket. A valve at a lower end of the pocket is movable from a closed position closing the outlet port to an open position opening the outlet port. A probe mounted to a lower end of the filter assembly engages and pushes the valve from the closed position to the open position while the filter assembly is being seated in the pocket.

Abstract: A water transfer monitoring system includes a meter skid to monitor water flow at a first location along the water transfer line, the meter skid having one or more meter skid sensors to detect and collect data associated with water flow at the first location; a control panel skid configured to receive and implement commands along a water transfer line, the control panel skid having a controller in communication with the one or more meter skid sensors, the controller to implement commands based on data received from the one or more meter skid sensors; the meter skid and the control panel skid are portable and re-usable; and data from the one or more meter skid sensors and the controller is transmitted to a remote data services for operator monitoring.

Abstract: Methods and apparatus for hydrocarbon monitoring are provided. A method that may be performed by a flowmeter or monitoring system includes receiving downhole measurements of a flowing fluid from a flowmeter; determining a standard phase fraction of the flowing fluid based on the downhole measurements from the flowmeter; receiving surface measurements of the flowing fluid; determining a surface phase fraction of the flowing fluid based on the surface measurements; comparing the standard phase fraction to the surface phase fraction; based on the comparison being greater than a predetermined threshold, using the surface measurements as a reference to adjust a speed of sound (SoS) of a first phase until a target value is achieved; and receiving additional downhole measurements of the flowing fluid from the flowmeter, wherein the flowmeter is operating using the adjusted SoS of the first phase.

Abstract: A method for enhanced oil recovery may comprise inputting into a computer system data related to properties of a hydrocarbon reservoir and depletion of the hydrocarbon reservoir; calculating, with the computer system, a current oil saturation and a current gas saturation of the hydrocarbon reservoir based on the data; determining, with the computer system, that the current reservoir pressure is less than a bubble point pressure based on the data; calculating, with the computer system, a time to repressure the hydrocarbon reservoir by waterflooding based on the data; comparing, with the computer system, the data related to properties of the hydrocarbon reservoir to oil recovery screening criteria; selecting a flooding technique from a plurality of flooding techniques, with the computer system, based on satisfying the oil recovery screening criteria with the data related to properties of the hydrocarbon reservoir.

Abstract: A method of controlling an output relay of a chemical controller is disclosed. The output relay is coupled to a pump configured to introduce at least one chemical into the aquatic application. The chemical controller controls the operation of the pump using the output relay. The method includes the step of utilizing a watchdog timer circuit to determine that a processor has failed to send a reset signal to the watchdog timer circuit before a timer of the watchdog timer circuit reaches zero. The method further includes the step of outputting a processor fault signal from the watchdog timer circuit.

Abstract: A downhole tool system includes an electrical submersible pump (ESP) assembly configured to couple to a downhole conveyance that includes a production fluid flow path for a production fluid from a subterranean formation; and a logging sub-assembly directly coupled to a downhole end of the ESP assembly and including a length of logging cable spoolable off a cable spool of the logging sub-assembly within a wellbore.

Abstract: Aspects of the subject technology relate to systems and methods for determining cement barrier quality of a cementing process. Systems and methods are provided for receiving data from a distributed acoustic sensing fiber optic line positioned proximate to cement barrier of a wellbore, determining at least one zonal isolation in the cement barrier based on the data received from the distributed acoustic sensing fiber optic line, and compiling a cement bond log based on the determining of the at least one zonal isolation in the cement barrier.

Abstract: An inline inspection vehicle includes an auto-adjustable, self-adaptive structure. The inline inspection vehicle includes a plurality of self-adjustable carrier racks carrying inspection device carts with positioning rollers, and self-adaptive driving turbine wheels at a front part and a back end for auto-adjustable driving speeds. The inline inspection vehicle also includes intelligent self-control mechanisms implemented using self-adaptive schema and algorithms for a finite set of control states to integrate the adaptive controller and actuators. Furthermore, it may conduct virtual pressure tests by carrying intelligent inline data acquisition devices to converge the Pipeline Integrity Management with SCADA monitoring system.

Abstract: System and methods for simulating fluid flow during downhole operations are provided. Measurements of an operating variable at one or more locations within a formation are obtained from a downhole tool disposed in a wellbore within the formation during a current stage of a downhole operation being performed along the wellbore. The obtained measurements are applied as inputs to a hybrid model of the formation. The hybrid model includes physics-based and machine learning models that are coupled together within a simulation grid. Fluid flow within the formation is simulated, based on the inputs applied to the hybrid model. A response of the operating variable is estimated for a subsequent stage of the downhole operation along the wellbore, based on the simulation. Flow control parameters for the subsequent stage are determined based on the estimated response. The subsequent stage of the operation is performed according to the determined flow control parameters.

Abstract: A multi-vessel reservoir assembly is provided. The multi-vessel reservoir assembly comprises a first fluid vessel, a second fluid vessel, and at least one linkage positioned between the first and second fluid vessels. The at least one linkage serves to maintain the first and second fluid vessels in fixed and spaced-apart relationship relative to one another. The first and second fluid vessels are independent and separately operable.

Abstract: Systems and methods for exchanging fracturing components of a hydraulic fracturing unit and may include an exchangeable fracturing component section to facilitate quickly exchanging a fracturing component of a hydraulic fracturing unit. The fracturing component section may include a section frame including a base, and a fracturing component connected to the base. The fracturing component section also may include a component electrical assembly and a component fluid assembly connected to the section frame. The fracturing component section further may include a coupling plate connected to the section frame. The fracturing component section also may include one or more of a plurality of quick-connect electrical couplers or a plurality of quick-connect fluid couplers connected to a coupling plate.

Abstract: Embodiments of an enclosure assembly to enhance cooling of a hydraulic fracturing direct drive unit (DDU) during operation are included. The enclosure assembly may include an enclosure body extending at least partially around an enclosure space to house the DDU for driving a fluid pump. The enclosure assembly may include one or more heat exchanger assemblies connected to the enclosure body for cooling a process fluid associated with one or more of the DDU and the fluid pump, and which may be configured to draw air into the enclosure space from and external environment, toward one or more radiator assemblies to cool the process fluid, and along an airflow path through the enclosure space. One or more outlet fan assemblies may be operative to discharge air from the enclosure space to the external environment to maintain a desired temperature of the enclosure space.

Abstract: Various apparatus or methods are arranged to determine a first isotope ratio of an effluent drilling fluid, wherein the effluent drilling fluid is a drilling fluid after the drilling fluid has interacted with a plasma discharge produced via one or more electrodes of a drill bit of a pulsed power drill string disposed in a borehole. A second isotope ratio is estimated based on the first isotope ratio and a downhole reaction generated by the plasma discharge.

Abstract: System and methods of controlling fluid flow during reservoir stimulation treatments are provided. A flow distribution of treatment fluid injected into formation entry points along a wellbore path is monitored during a current stage of a multistage stimulation treatment. Upon determining that the monitored flow distribution meets a threshold, a remainder of the current stage is partitioned into a plurality of treatment cycles and at least one diversion phase for diverting the fluid to be injected away from one or more formation entry points between consecutive treatment cycles. A portion of the fluid to be injected into the formation entry points is allocated to each of the treatment cycles of the partitioned stage. The treatment cycles are performed for the remainder of the current stage using the treatment fluid allocated to each treatment cycle, wherein the flow distribution is adjusted so as not to meet the threshold.

Abstract: The present invention considers bringing a mobile unit closer to the site of interest and conduct the quantification of the tracers by performing the detection methods in situ and in real time at the wellhead, and that can be moved to the site on numerous occasions for the preparation of results during the test where the quantification of tracers is necessary, helping to speed up and reduce times that, until now, have not been achieved with stationary laboratories and that depending on the laboratory can last up to three months providing results.