Abstract: Provided is a method for inspecting at least a portion of a downhole conveyance device. The method, in one embodiment, includes providing a downhole conveyance device, and providing an ultrasonic defect inspection system adjacent the downhole conveyance device. The method, in this embodiment, further includes detecting defects in the downhole conveyance device using the ultrasonic defect inspection system, wherein the detecting includes transmitting ultrasonic waves from the ultrasonic defect inspection system toward the downhole conveyance device, and obtaining defect data by sensing disruptions in the reflected ultrasonic waves caused by defects in the downhole conveyance device.

Abstract: A method includes creating a digital description of the well construction system, wherein the digital description of the well construction system describes the locational relationship of components in the well construction system, collecting multiple types of data from a well construction system, and tagging the collected data with an identification indicating at least one of a location of a source of collected data and a component in the well construction system from which the data is collected. The multiple types of data include sensor data collected from one or more sensors disposed along the well construction system and operational state data indicating an on/off status of one or more components in the well construction system.

Abstract: A mobile fracking pump trailer 100 includes a gas turbine engine 102 and fracking pump 104, and torque converter 114 that fluidly couples the gas turbine engine 102 to the fracking pump 104. The mobile fracking pump trailer 100 further includes a first reduction gearing 118 connected between the gas turbine engine 102 and the torque converter 114 and a first power takeoff 120 connected to first reduction gearing 118. An electrical machine 128 is connected to the first power takeoff 120 for selectively starting the gas turbine engine 102 and generating electrical power to power the mobile fracking pump trailer 100 after the gas turbine engine 102 has been started.

Abstract: Methods for producing proppants with a fluorinated polyurethane proppant coating are provided. The methods include coating the proppant particles with a strengthening agent, a strengthening agent, and a resin to produce proppants with fluorinated polyurethane proppant coating. Additionally, a proppant comprising a proppant particle and a fluorinated polyurethane proppant coating is provided. The fluorinated polyurethane proppant coating includes a strengthening agent, a strengthening agent, and a resin. The fluorinated polyurethane proppant coating coats the proppant particle. Additionally, a method for increasing a rate of hydrocarbon production from a subsurface formation through the use of the proppants is provided.

Abstract: Systems and methods for measuring a parameter of interest in a borehole in an earth formation are provided. The systems include a downhole sensor having a first sensor component with a first temperature and a second sensor component with a second temperature, the downhole sensor disposed on a downhole component. A temperature control system is configured with a thermal control mechanism operatively connected to at least one of the first and second sensor components. The thermal control mechanism is configured to maintain a temperature difference between the first temperature and the second temperature below a pre-determined temperature difference. The downhole sensor is configured to measure the parameter of interest when the temperature difference is below the pre-determined temperature difference.

Abstract: Disclosed are a monitoring, prevention and management method for preventing a drilling pump from pump suffocation and misoperation, and a pump pressure protection system therefor.

Abstract: Embodiments of the disclosure can include systems and methods for formation fluid sampling. In one embodiment, a method can include monitoring a relationship between a first characteristic of a formation fluid extracted from a formation and a second characteristic of the formation fluid extracted from the formation, determining, based at least in part on the monitoring, that a linear trend is exhibited by the relationship between the first characteristic of the formation fluid extracted from the formation and the second characteristic of the formation fluid extracted from the formation, and determining a reservoir fluid breakthrough based at least in part on the identification of the linear trend, wherein the reservoir fluid breakthrough is indicative of virgin reservoir fluid entering a sampling tool.

Abstract: Systems and methods presented herein enable coordinated pumping operations. An example system may include a treatment fluid system configured to pump a treatment fluid into a wellbore, a pump-down system configured to pump a pump-down fluid into the wellbore to convey a perforating tool, a fluid valve system configured to selectively fluidly connect and disconnect the treatment fluid system and the pump-down system to and from the wellbore, and a controller communicatively connected to the treatment fluid system, the pump-down system, and the fluid valve system. The controller may be configured to monitor operational status of the treatment fluid system, the pump-down system, and the fluid valve system, and control operations of the treatment fluid system, the pump-down system, and the fluid valve system based at least in part on the operational status of the treatment fluid system, the pump-down system, and the fluid valve system.

Abstract: A method of creating a horizontal wellbore section comprises drilling the section in at least two stages. The method comprises drilling a first horizontal bore section. The first horizontal bore section is then provided with a first liner having a wall including initially-closed flow ports. The first liner isolates the wall of the first bore section. A second horizontal bore section is then drilled beyond the first horizontal bore section. The second horizontal bore section is provided with a second liner. Stimulation fluid is then directed into the first and second liners so that the stimulation fluid passes through the wall of the second liner to stimulate the second horizontal bore section. The flow ports in the wall of the first liner are then opened so that the stimulation fluid passes through the wall of the first liner to stimulate the first horizontal bore section.

Abstract: System and methods for detecting a composition in a wellbore during a cementing operation. An electrochemical cell can be disposed towards an end of a wellbore. The electrochemical cell can generate electrical energy in response to a physical presence of a composition at the electrochemical cell. The composition can be pumped from a surface of the wellbore during a cementing operation of the wellbore. Further, a telemetry signal indicating the physical presence of the composition at the electrochemical cell can be generated based on the electrical energy generated by the electrochemical cell. As follows, the telemetry signal can be transmitted to the surface of the wellbore.

Abstract: Systems and methods for conducting a well intervention operation in a well include positioning a conveyance into the well for the well intervention operation, calculating a predicted force based at least in part on a length of the conveyance that is positioned at a depth in the well, measuring a measured force for the conveyance at the depth in the well, and comparing a predicted force for the conveyance at the depth in the well with the measured force in real time to determine if the predicted force is within a predetermined range of the measured force in real time. The method further includes generating an alert if the predicted force is not within the predetermined range of the measured force in real time, and continuing with the well intervention operation if the predicted force is within the predetermined range of the measured force.

Abstract: A downhole plug for well completion is provided, which rapidly degrades after hydraulic fracturing, so that the flow path is recovered in a short time. A downhole plug (10) is provided, which includes: a mandrel (1) made of a degradable material; and a plurality of peripheral members (2, 3, 4, 5, 6a, 6b, 8a, 8b) made of a degradable material and disposed on an outer peripheral surface of the mandrel (1), where at least one of the plurality of peripheral members (6a, 6b) includes: a hollow portion (64) through which a fluid flowing along an axial direction of the mandrel (1) can pass; or a groove in at least a portion of, a surface serving as an outer surface of the downhole plug (10), or a surface in contact with the mandrel (1).

Abstract: The present disclosure relates to a system having an inner structure, wherein the inner structure comprises at least one inner tube made of stainless steel and at least one sensor device with at least one sensor to measure at least one condition of the system. Under an aspect of the present disclosure a system of this type is suggested, wherein the inner structure is coated with at least one layer of at least one plastic material.

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: Safe dynamic handover between MPD and well control operations provides the ability to automate MPD, well control, and transitions therebetween while maintaining the wellbore in a dynamic fluid state at all times. In the event a kick is taken, a safe dynamic handover from MPD to well control operations is made, unknown formation fluids within the wellbore are circulated out of the wellbore, and a safe dynamic handover from well control operations to MPD is made while maintaining the wellbore in dynamic fluid state, without ever going static with respect to fluids within the wellbore. Because the wellbore remains dynamic, the formation of gels is prevented, thereby preventing pressure spikes during the start-up of the mud pumps and improving pressure transmission throughout the well system. Pressure may be more precisely managed during all phases of MPD, well control, and transitions therebetween.

Abstract: Effective prediction of downhole mixing and channeling at an interface between two or more wellbore fluids may prevent the unnecessary consumption of resources at a well site and enhance the performance of wellbore operations, including drilling operations, completion operations, and reservoir management. A model for a length and a volume of the interface between two wellbore fluids may be used to characterize the amount of mixing and channeling. The model may use known properties of the wellbore fluids before mixing and channeling occurs. The model may account for eccentricity in an annulus of the wellbore by partitioning a three dimensional flow profile in the wellbore into a plurality of segments for separate analysis. Outputs from the model may be used to determine one or more locations of the interface at one or more intervals of time as the wellbore fluids circulate through the wellbore.

Abstract: The present disclosure provides for generating multiphase flow properties of porous media based on one or more input parameters. For instance, the multiphase flow properties may be a capillary pressure-saturation relationship for the porous media. The one or more input parameters include an interfacial tension along an interface between a wetting fluid and a non-wetting fluid, a contact angle between the interface and a pore wall of the porous media, and a pore throat size. The pore throat size is based on subparameters including a saturation of the wetting fluid, a saturation of the non-wetting fluid, a porosity of the porous media, and an orientation angle between a representative pore body size and a representative pore throat size.

Abstract: A method for generating a well completion plan includes: evaluating a plurality of different well completion plans using a reservoir simulator to calculate dynamic flows of fluid through a subsurface formation, each well completion plan having a flow control device with location and associated flow setting or rating, and optionally a packer and location to provide output data for each well completion plan evaluation; developing a surrogate reservoir model using the output data and input data for each well completion plan evaluation; using intelligent sequential sampling of the output and input data for each well completion plan evaluation to provide intelligent sequential sampling data in response to the surrogate reservoir model not meeting a validation criterion; updating the surrogate reservoir model using the intelligent sequential sampling data; and iterating the using and the updating using a latest surrogate reservoir model until the latest surrogate reservoir model meets the validation criterion.

Abstract: Determining distance and direction from a first borehole to a second borehole including generating a time-varying magnetic field by axially reciprocating magnets of opposed polarity, at a first location in a second borehole, and detectable in the region of the first borehole. First and second sensors positioned at an observation point in the first borehole measure the amplitude and relative phase of components of the magnetic field. From these measurements, the direction, relative to the sensors, from an observation point to the first location is determined. The distance between these points is determined by measuring amplitude variations with depth of the magnetic field at observation points in the first borehole and computing theoretical variations in the amplitude for different assumed distances between the observation points and the location of the magnetic field source which are compared with theoretical variations to determine the distance between the first and second boreholes.

Abstract: An autonomous intervention system configured to perform an intervention operation in a wellbore comprises a tool housing having a tool storage compartment configured to house an intervention tool. A valve arrangement permits selective communication of tools and fluid between the tool housing and the wellbore. The intervention system is configured to move in response to an activation event between a tool storage configuration in which the tool housing is isolated from the wellbore by the valve arrangement and an activated configuration in which the valve arrangement is open and the tool housing communicates with the wellbore to permit deployment of the intervention tool by a tool deployment arrangement.

Abstract: Systems and methods are provided for transmitting information to and from a downhole tool for detonation at a specified location. Perforating systems and methods may use a digital slickline unit and a telemetry module to autonomously operate within a wellbore. A well system may comprise: a downhole perforating system comprising: at least one perforating gun; a setting tool; and a control unit coupled to the at least one perforating gun and the setting tool in a tool string for conveyance downhole, wherein the control unit comprises a battery pack, electronics, at least one sensor, wherein the electronics are operable to send one or more actuation signals to the at least one perforating gun and the setting tool.

Abstract: A method of recovering oil embedded in an underground matrix adjacent a depleted oil reservoir includes injecting a mixture of polymeric material into the depleted oil reservoir through an injection borehole, applying a pressure to the mixture to free the oil from the matrix and move the oil towards a production well, and drawing the oil from the depleted oil reservoir through the production well. The method additionally includes modeling a shear thickening of the polymeric mixture and an onset of the shear thickening. The model can be incorporated into commercial numerical simulators for predicting the injectivity and recovery due to viscoelastic thickening independently and thereby assist in quick screening polymers for oil recovery applications.

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: A method may comprise obtaining a formation sample, scanning the formation sample to form a data packet, loading the data packet on an information handling machine, performing a digital porous plate experiment with the data packet, and determining geometry of a pore throat in the formation sample. A system may comprise a computer tomographic machine configured to scan a formation sample and create a data packet from the scan and an information handling system. The information handling system may be configured to configured to perform a digital porous plate experiment with the data packet and determine geometry of a pore throat in the formation sample.

Abstract: A subterranean product extraction composition may include a borehole fluid that may include a thiamine based shale inhibitor active to inhibit reactivity of a formation shale to a base fluid of a borehole fluid. A method of extracting a subterranean product via a borehole may include providing a borehole fluid containing a thiamine-based shale inhibitor and inhibiting reactivity of a formation shale contacted with the borehole fluid. A system for extracting a subterranean product via a borehole may include a tubular having an end in proximity to a formation shale and in fluid communication with a container dispensing a borehole fluid containing a thiamine-based shale inhibitor. The thiamine-based shale inhibitor is inert to the borehole fluid and has superior activity as compared to potassium chloride to inhibit shale reactivity. The borehole fluid may be a drilling fluid. The base fluid may be water.

Abstract: A drilling motor provides rotational force within a wellbore and includes a power section within the interior of a housing, a rotor positioned within the power section, and a passage within the rotor. The passage is configured to bypass a portion of the drilling mud from above the power section within the interior of the housing to below the power section within the interior of the housing, and an interior valve at a downstream end of the passage, wherein the valve includes a rupture disc configured to close the passage when the pressure from the drilling mud is less than a threshold pressure, and to rupture to open the passage and pass the drilling mud through the valve when the pressure from the drilling mud is greater than the threshold pressure.

Abstract: System and methods of controlling fluid diversion during stimulation treatments are provided. Real-time measurements are obtained from a plurality of fiber-optic data sources at a well site during a stimulation treatment being performed along a portion of a wellbore within a subsurface formation. Fracture growth and stress within the subsurface formation surrounding the portion of the wellbore are determined as the stimulation treatment is performed, based on the real-time measurements and a fully-coupled diversion model. An amount of diverter for a diversion phase of the stimulation treatment to be performed along the portion of the wellbore is determined, based on the fracture growth and the stress within the subsurface formation. The diversion phase of the stimulation treatment is performed by injecting the amount of diverter into the subsurface formation via at least one injection point located along the portion of the wellbore.

Abstract: Described herein are methods and techniques for determining one or more characteristics of a hydrocarbon source. The method comprises obtaining a hydrocarbon fluid sample, determining at least one measured clumped isotope signature or measured position specific isotope signature for at least one hydrocarbon species of interest in the hydrocarbon fluid sample, determining at least one expected clumped isotope signature or expected position specific isotope signature for the hydrocarbon species of interest, comparing the measured clumped isotope signature or measured position specific isotope signature with the expected clumped isotope signature or expected position specific isotope signature, and determining at least one characteristic of the source of the hydrocarbon sample based on the comparison.

Abstract: Disclosed are a wellbore inspection system and method for an ultra-deep vertical shaft. The wellbore inspection system includes a wire rope moving system, inspection robots, a visual image acquisition system, a wireless communication module, a central control system, and an image post-processing system of an upper computer. The wire rope moving system includes a surface wire rope guide rail, an underground wire rope guide rail, a surface wire rope moving device, an underground wire rope moving device, and a wire rope. The visual image acquisition system includes explosion-proof cameras. After image information acquired by the explosion-proof cameras is processed by a lower computer, the processed image is transmitted by a wireless image transmission module to the image post-processing system of the upper computer. The central control system is connected to the inspection robots and the wire rope moving system, and the inspection robots are connected to the central control system.

Abstract: A pipe guide comprising a first arm comprising a first set of guides; and a second arm comprising at least one guide, wherein all guides of the first set of guides are adapted to bias against an external portion of a pipe, and wherein a pressure of each of the guides against the pipe is adapted to be above a threshold pressure necessary to guide a secondary pipe relative to the pipe. In an embodiment, the first set of guides comprises a plurality of bodies and at least one of the bodies of the first set of guides is adapted to be rotatable about a rotational axis with respect to the first arm.

Abstract: Provided herein are methods systems and compositions of a fracturing fluid comprising an associative polymer and clay nanoparticles. A method may comprise: providing a fracturing fluid comprising: a carrier fluid; an associative polymer; and clay nanoparticles; and injecting the fracturing fluid into a subterranean formation at or above a fracture gradient.

Abstract: A downhole motor for drilling a borehole includes a stator assembly including a helical-shaped stator, a rotor assembly rotatably disposed in the stator assembly, wherein the rotor assembly includes a helical-shaped rotor, and a sensor package received in the rotor assembly, wherein the sensor package includes a first pressure sensor, a second pressure sensor, and a plurality of accelerometers.

Abstract: A flow assembly is deployed downhole in a casing for a cementing operation. The flow assembly has a spool with an optical cable. As cement is pumped downhole and through the flow assembly, a dart attached to the optical cable on the spool is dragged with the flow of cement. Cement flow is stopped based on signals along the optical cable that the dart is at a desired location downhole.

Abstract: The present invention comprises a friction flow loop test method and apparatus that simulates well bore hydraulic conditions during fracturing utilizing large dual tanks with a primary feed tank and a secondary receiving tank wherein friction reducer hydration is controlled in an environment matching the well bore and is unaffected by recirculation mixing.

Abstract: The present invention provides an inversion calculation method of coal-bed gas parameters of fast test while-drilling. The technical solution is that an inversion calculation method of coal-bed gas parameters of fast test while-drilling includes: during drilling in a coal bed, testing a gas flow and a gas concentration of an orifice in real time while-drilling, calculating drilling gas discharge amounts of the orifice, inversely calculating a coal-bed gas pressure at a drill bit based on borehole and coal-bed permeability parameters, and calculating a coal-bed gas content according to a gas content and gas pressure relational expression. The present invention has the beneficial effects that the present invention does not occupy the drilling and drill rod replacement time, is accurate, convenient, real-time and fast, and can test and calculate the coal-bed gas parameters of each section along the whole borehole length.

Abstract: An electric driven hydraulic fracking system is disclosed. A pump configuration that includes the single VFD, the single shaft electric motor, and the single hydraulic pump that is mounted on the single pump trailer. A power distribution trailer distributes the electric power generated by the power generation system at the power generation voltage level to the single VFD and converts the electric power at a power generation voltage level to a VFD voltage level and controls the operation of the single shaft electric motor and the single hydraulic pump. The power distribution trailer converts the electric power generated by the power generation system at the power generation level to an auxiliary voltage level that is less than the power generation voltage level. The power distribution trailer distributes the electric power at the auxiliary voltage level to the single VFD that controls an operation of the of the auxiliary systems.

Abstract: An integrated system includes a desalination plant including a reverse osmosis (RO) array to produce an RO permeate blending stream and a nanofiltration (NF) array to produce an NF permeate blending stream. The integrated system also includes a blending system. a control unit, and an injection system for an injection well that penetrates an oil-bearing layer of a reservoir. The blending system is to blend the RO permeate blending stream and the NF permeate blending stream to produce a blended injection water stream. The control unit is to dynamically alter operation of the blending system to adjust amounts of at least one of the RO permeate blending stream and the NF permeate blending stream to alter the composition of the blended injection water stream from an initial composition to a target composition.

Abstract: Methods for servicing a hydrocarbon well using natural gas in a well intervention operation can include preparing a working fluid having a composition comprising natural gas between about 5 mol % to about 100 mol %. During a well intervention operation at the specified well intervention conditions, the method can include injecting the working fluid into the well and contacting the working fluid with the recovery target material such that at least some of the natural gas dissolves into the recovery target material and forming a liquid phase well servicing mixture of the natural gas and recovery target material. At least some of the well servicing mixture can be recovered at surface.

Abstract: A monitoring well installation comprising metallic casing (2) running down from the surface into a borehole and a sealing material plug (6) provided downhole for blocking the interior of the casing and sealing the borehole against the egress of fluid from a zone below the plug. There is an axial spacing (2A) between adjacent casing portions (2) in the region of the plug (6) such that there is an uncased length of borehole in which the material of the plug seals against the formation. There is provided a sensing tool (3) located below the plug (6) for sensing at least one parameter below the plug (6) and a communication arrangement (3, 4, 5) for use in transmitting data from the sensing tool (3) towards the surface. The communication arrangement comprises across plug communication apparatus (5) for facilitating transmission of signals carrying data across the plug (6) towards the surface.

Abstract: The disclosure pertains to amphiphilic block copolymers comprising an aliphatic polycarbonate chain coupled to a hydrophilic polymer. Such amphiphilic polymers may have the formula A-L-B, where A- is a polycarbonate or polyethercarbonate chain having from about 3 to about 500 repeating units, L is a linker moiety and -B is a hydrophilic oligomer having from about 4 to about 200 repeating units. Provided copolymers are useful as surfactants capable of emulsifying aqueous solutions and supercritical carbon dioxide. Provided copolymers also have utility as additives for use in enhanced oil recovery methods.

Abstract: Carbon nanotubes, graphene nanoplatelets, and/or metal oxides are incorporated in a polymer to form a sensing element that may be applied on to a surface for sensing hydrocarbon leakage, mechanical stress, and/or temperature change of a hydrocarbon transportation and/or storage structure. Electrical signals from the sensing element are processed to check for indicators of leakage, stress and/or temperature change.

Abstract: A system and method for signal communication using a piezoelectric fiber composite (PFC) sensor. A telemetry module is locatable within a borehole intersecting a subterranean earth formation. The PFC sensor is coupled to a carrier in communication with the telemetry module. The PFC sensor is configured to generate a signal indicative of a stress in the carrier. A processor in communication with the PFC sensor is configured to convert the signal generated by the PFC sensor into a telemetry signal transmitted by the telemetry module.

Abstract: The techniques described herein relate to methods, apparatus, and computer readable media for real-time induced seismicity management. A distribution value, such as a b value, and an uncertainty of the distribution value is calculated based on the received magnitude data, wherein the distribution represents the proportion of each magnitude earthquake observed in the distribution. A seismogenic index is calculated based on a set of fluid injection rates and the distribution value, wherein the seismogenic index represents the proportion of earthquakes per volume of fluid injected into the earth at a particular location. A distribution of a number of earthquakes that will be induced of each magnitude from future injection is forecasted based on the seismogenic index. A ground motion prediction model is calculated, representing shaking intensity and distance based on the forecasted distribution of earthquakes. Seismicity can then be managed to not exceed a tolerated chance of induced shaking consequences.

Abstract: A rechargeable power source in an autonomous vehicle (AV) adapted to traverse within a pipe network is charged, the charging using mechanical power derived from a flow of material within the pipe network. A sensor in the AV is powered from the charged rechargeable power source. Using power from the rechargeable power source, the AV is caused to traverse within the pipe network.

Abstract: A system and method for conducting subterranean operations. In an embodiment, the system can include a monitoring system configured to monitor at least one criterion of a plurality of operational systems selected from the group of choke valves, mud pumps, drawworks, backpressure pumps, top drive, mud gas separator, flow line, blowout preventer, inside blowout preventer, or any combination thereof, and a logic device configured to generate a capacity value for each operational system of the plurality of the operational systems based on the at least one criterion, and further configured to change a state of one or more of plurality of the operational systems to control a downhole pressure.

Abstract: A flow monitoring system comprising a first temperature sensor located at a reservoir input for measuring input temperature of a fluid in an enhance oil recovery system, a second temperature sensor located at a reservoir output for measuring temperature of output fluid and a processor in communication with the first temperature sensor and the second temperature sensor wherein the first temperature sensor and the second temperature sensor are operable to measure temperature data and communicate the measured data to the processor. The flow monitoring system further comprises a first flow monitor sensor located at the reservoir input for measuring flow of input fluid and the second flow monitoring sensor located at the reservoir output for measuring output fluid flow wherein the first and second flow monitoring sensors are operable to communicate measured flow data to the processor.

Abstract: The invention relates to a pressure oscillation simulation device of deep coalbed methane and a method thereof. The device includes: a box, a liquid discharge pipe arranged on a bottom portion of the box, a gas source connected to the box through a gas injection pipe, a water source connected to the box through a drainpipe that includes a branch pipe; a measuring system including a pressure measuring member and a liquidometer. The present disclosure can simulate the coalbed pressure oscillation in a coalbed gas exploitation process and be of simple structure and high reliability, and can simulate influences of the pressure oscillation on a wellbore and a stratum environment in the coalbed exploitation process to provide reliable data support for an actual coalbed exploitation; the simulation method of the present disclosure can accurately simulate the pressure oscillation of the wellbore and the stratum.

Abstract: Provided are particulate polyvinyl alcohol-based diverting agents for use in subterranean treatments, which are prepared by compacting a specified polyvinyl alcohol copolymer optionally with certain specified additives and optionally other polyvinyl alcohols.

Abstract: Various embodiments include apparatus and methods implemented to monitor detection of a flood front of a waterflood in a formation. Embodiments can include control of current in a set of three current electrodes to inject current into a formation around a pipe in a wellbore, where the three current electrodes include two of the electrodes to inject current and the third electrode to operatively provide a current return. Response of the formation to the current injections can be communicated by interrogating an optical fiber that extends along a longitudinal axis of the pipe. Determination of progression of the waterflood with respect to the wellbore can be provided from controlling the current and interrogating the optical fiber over time. Additional apparatus, systems, and methods are disclosed.

Abstract: A well component having a main bore and a lateral opening from the main bore, the well component further comprising a deflector surface arranged adjacent the lateral opening on an inner wall of the main bore and defining a path configured to guide one or more guide taps/fingers of a downhole tool away from the opening.