Abstract: Disclosed herein are embodiments of engineered geothermal systems (EGS). Also disclosed are methods and devices for the construction and use of planar artificial fractures in EGS wells, including wells that contain both an injection and extraction points.

Abstract: Various implementations directed to using a rotary steerable system (RSS) drilling tool based on dogleg severity are provided. In one implementation, a method may include receiving a predetermined dogleg severity for a portion of a wellbore to be drilled using the RSS drilling tool. The method may also include determining a first displacement of actuators of the RSS drilling tool from a housing of the RSS drilling tool based on the predetermined dogleg severity. The method may further include activating the actuators based on the first displacement. The method may additionally include receiving displacement data from position sensors disposed in the RSS drilling tool during drilling of the portion of the wellbore, where the displacement data corresponds to a second displacement of the actuators from the housing. The method may also include activating the actuators based on the displacement data.

Abstract: The static push-the-bit articulated high-built-rate rotary steerable tool has the main body of a non-rotary measurement and control unit articulated with the main body of a non-rotary actuator, rather than an integral structure. Due to the fact that the drilling tool is easy to bend in a wellbore, the bending stress in an upper portion of the steerable tool is low, and the consumption of the pushing force for bending deformation of the drilling tool is minimized. Since the steering sleeve around the main body of a load-bearing actuator only slides along the well wall in an axial direction without rotational friction there-between, the service life of the steering sleeve is long. Besides, since hydraulic pressure is used instead of pressure difference of mud to act on the pistons to form the pushing force, the pushing force is greatly improved, and the sealing life of the pistons is longer.

Abstract: An apparatus is disposed on a drillstring for deviating a borehole advanced by a drill bit. The assembly includes a housing, at least one director, and at least one actuator. The housing is disposed on the drillstring and transfers rotation to the drill bit. The housing has a bore communicating fluid from the drillstring to the drill bit. The at least one director is disposed on the housing to rotate therewith. The at least one director at least includes a piston movable in a chamber, a pad pivotable about a pivot point between an extended condition and a retracted condition relative to the housing, and a linkage arm pivotably connected between the piston and the pad. The at least one actuator is disposed on the housing in fluid communication with the bore.

Abstract: A downhole cutting tool includes a tool body with a cutting element or cutting element pocket thereon. At least a portion of the tool body or an attachment thereto is a metal matrix composite formed from metal carbide particles dispersed in a continuous metal matrix. The metal carbide particles make up less than 45 wt % of the metal matrix composite and/or less than 30 vol % of the metal matrix composite. The continuous metal matrix may also be formed from a metal or metal alloy other than Ni—Si—B and/or have a transverse rupture strength greater than 150 ksi and a fracture toughness over 22 ksi*in0.5.

Abstract: A cutting element assembly may include a support structure and a pin having a cylindrical exterior bearing surface. Retention elements may couple opposing ends of the pin to the support structure. The cutting element assembly also includes a rotatable cutting element including a table of polycrystalline hard material having an end cutting surface and a supporting substrate. The rotatable cutting element may have an interior sidewall defining a longitudinally extending through hole. The pin may be positioned within the through hole of the rotatable cutting element and may be supported on the opposing ends thereof by the support structure. Methods include drilling a subterranean formation including engaging a formation with one or more of the rotatable cutting elements.

Abstract: A sacrificial shroud is disposed over a packing element of a downhole packer to provide isolation from incompatible wellbore fluids and to minimize a tendency for swabbing or packer preset due to fluid flow past the packing element during run-in, thereby allowing for faster run-in speeds. The shroud may be depletive or consumable, such as by dissolution into a wellbore fluid or by melting at a predetermined downhole thermodynamic condition. The shroud may take the form of a sleeve or an applied coating.

Abstract: A threaded coupling comprising a first end, a second end, a first portion of the threaded coupling defining a first thread profile, a second portion of the threaded coupling defining a second thread profile different from the first thread profile, where at least two threads of the second thread profile proximate to the second end are reduced in height according to an extra machining angle.

Abstract: A drill string management apparatus is disclosed. The apparatus may comprise a reel that stores a length of drill string and supplies the drill string to a drilling system. The drill string may be wrapped around a circumference of a reel in a coil. The radius of the coil may be large enough that the drill string is not deformed inelastically by wrapping it around the reel. The apparatus may be designed to allow the drill string to rotate about its longitudinal axis, even as the drill string is wrapped in a coil around the reel.

Abstract: A catwalk and crane system for transporting equipment of a well system includes a substructure, a directing frame pivotally coupled to the substructure, a pipe transporter configured to transport a tubular along the directing frame, a first actuator coupled to the directing frame and configured to rotate the directing frame relative to the substructure, and a crane coupled to the directing frame, wherein the crane is extendable from a first end of the directing frame.

Abstract: A rod handling system for a drilling activity includes i) a rod support defining a first axis, ii) a rod dispensing device positioned adjacent to the rod support for moving a rod between a first lateral side of the rod dispensing device and the rod support, and iii) a rod positioning device that is positioned adjacent to the rod dispensing arm on a second lateral side thereof for moving the rod between a first position, on the rod support, and a second position on a lateral side of the rod positioning device that is opposite the rod dispensing device in a generally vertical orientation. The system has a first advantage of dedicating a different device for each of the two main tasks necessary in order to complete a cycle of inserting or removing drill rods from a drill head. Furthermore, it has a second advantage of reducing the time required to complete an inserting/removing cycle because the whole cycle is performed by two independent devices that can be simultaneously operated.

Abstract: A system includes a processing device configured to determine a tripping operation to be undertaken. The processing device is configured to also calculate a variable tripping speed for the tripping operation to vary a speed of the tripping operation. The processing device is further generate an output to control the operation of a portion of a continuous tripping system to implement the tripping operation at the variable tripping speed.

Abstract: A method to manipulate a well, comprising running an apparatus having a container and an electrically powered pump into the well. The well is isolated, and a wireless control signal, such as an electromagnetic or acoustic signal, is sent to operate the pump in response in order to pump fluid from within the container to the surrounding portion of the well. The apparatus may comprise a pressure balancing means, such as a floating piston between two ports of the container, and/or an in well charging means.

Abstract: A downhole apparatus and method for expelling fluid which comprises a container defining a void which is separated into three separate sections by a floating piston and control member, each having a dynamic seal. A portion of the container defining one of the void sections has a different cross-sectional area than the portion of the container defining another void section. In use, a fluid to be expelled is provided in one void section, and a reduced pressure (compared to the well) is sealed in another void section. The apparatus also comprises a wireless electromagnetic or acoustic receiver. When a signal is received by the wireless receiver to activate the apparatus, a valve or other mechanism maybe activated to release the floating piston and connected control member such that the lower pressure void and differing cross-sectional areas of the container drives and expels fluid out of the apparatus.

Abstract: This invention relates to a collecting device and method for loosening and collecting debris in a well, the collecting device includes a first end portion and a second end portion; a collecting receptacle between the first and second end portions, the collecting receptacle including at least one receptacle section and at least one screen receptacle section and at least one screen receptacle; a motor; and the collecting device, at its first end portion, including a feel pipe; a conveying screw in the feed pipe driven by the motor, the conveying screw being arranged to move the debris in towards the collecting receptacle and a tool at the leading end portion of the conveying screw.

Abstract: An apparatus housing for a cutting system for radially projecting a flow of heated gas to cut from an internal surface through an external surface of a conduit. The cutting system adapted to be positioned within the conduit comprising an igniter, an extension housing, and an apparatus housing. The apparatus housing has a movable sleeve section and a nozzle assembly. The nozzle assembly comprises a conical head with through holes for evenly dispersing the flow of heated gas. A retainer abuts a diverter. The diverter imposes a 90-degree bend in the direction of the flow of the heated gas to cause the flow of heated gas to move the sleeve section away from the apparatus housing to expose a circumferential diverter gap through which the flow of heated gas projects radially to perform the cutting function. A spindle provides structure for the nozzle assembly and maintains the position of the nozzle assembly in the apparatus housing.

Abstract: A subsea wellhead assembly is provided. The subsea wellhead assembly comprises: a conductor; a subsea wellhead; and subsea riser system equipment mounted on the subsea wellhead; wherein the subsea riser system equipment is connected to the conductor such that forces can be transmitted from the subsea riser equipment to the conductor.

Abstract: Components of drilling and production systems with wide flange bodies are provided. In one embodiment, an apparatus includes a component (40, 124, 126, 128) of a wellhead assembly (18) or of a riser (16) of a drilling or production system, the component having a non-tubular main body (42, 130, 140) and a bore (44, 132, 144) extending axially through the main body to allow fluids to flow through the main body via the bore. Rather than having a flanged neck fixedly extending the bore from the main body with a connection flange below or above the main body, the component includes a lateral flange (50, 134, 146, 160) extending outwardly from an exterior surface of the main body such that the lateral flange is positioned alongside the main body. Additional systems, devices, and methods are also disclosed.

Abstract: A system, includes a first sensor configured to monitor a first characteristic of drilling fluid and generate a first indication based on the monitoring. The system also includes a second sensor configured to monitor a second characteristic of drilling fluid and generate a second indication based on the monitoring. The system further includes a processor configured to correlate the first indication with the second indication to generate a baseline value indicative of a characteristic of a well.

Abstract: A wiper dart includes one or more wiper elements disposed about a mandrel, each wiper element comprising a wiper cup that extends radially outward and rearwardly relative to the mandrel, and a nose assembly coupled to the mandrel. A drive element is disposed about the mandrel and includes a shoe and a cup coupled to the shoe. The cup extends radially outward and rearwardly from the shoe and exhibits a maximum diameter less than or equal to a maximum diameter of the one or more wiper elements, and the shoe provides at least one of axial and radial support to the cup.

Abstract: A plug assembly including a sleeve defining a primary channel, and a plug blocking the primary channel. One or more components of the plug assembly may be dissolvable. A pipe system including a pipe, a first plug assembly, a second plug assembly, and a fluid sealed within the pipe between the plug assemblies. At least one of the plug assemblies includes a sleeve defining a primary channel and a plug blocking the primary channel. One or more components of the plug assemblies may be dissolvable. A method for inserting a pipe system into a wellbore, including providing the pipe system, which includes a first plug assembly and a second plug assembly, sealing a fluid between the plug assemblies, inserting the pipe system into the wellbore, and unsealing the plug assemblies. The method may include dissolving one or more components of one or both of the plug assemblies.

Abstract: A backup or extrusion barrier ring assembly has multiple rows of rings in segments that have circumferentially offset slots. The rings are rotationally locked to each other to maintain the circumferential offset of the slots that allow the rings to be more flexible in the setting process. The rings as a unit can be mounted to relatively rotate on a supporting mandrel. The rings are mounted to allow them to move axially during setting either in tandem or axially relatively to each other. The axial run in heights of rings decline from innermost to outermost so that when set the heights approach each other to minimize or eliminate sharp ends against the seal. Alternatively, the height difference can be such as to allow ends to bend over an adjacent end further out radially so that free ends bend toward the surrounding tubular and avoid the seal.

Abstract: Certain embodiments are directed to magnetic rheological packer systems that seal an annulus in a downhole wellbore. In one embodiment, the seal is formed from a two-part epoxy and magnetorheological composition. The epoxy and magnetorheological compositions are allowed to be shaped by a magnetic field provided by one or more magnets exerting a magnetic field to place the packer seal.

Abstract: A plug for plugging wells, and in particular oil and gas wells, is provided. The plug has a plug body formed from an outer metal tube of a reduced thickness. The plug also has reinforcement means, attached to an inner surface of the outer tube, that give the plug a cross-sectional structural strength that is at least equivalent to that of a thicker metal tube. The plug has a central heater receiving void located along the axis of the plug to enable a plug deployment heater to be received therein. Also provided is a plug assembly with a variable cross-sectional area in a plane perpendicular to the plane in which the assembly is deployed during the plugging of underground conduits.

Abstract: Method of plugging a hydrocarbon well by a through-tubing technique are described. The method allows the tubing to be left in place. Only a short (<2 m) section is cut, milled, perforated, ruptured and expanded, or combinations thereof. A blocking device is sent downhole to block a bottom of the plug section, and bismuth alloy pellets dropped onto the blocking device. A heater is deployed to melt the bismuth alloy pellets. Next, the alloy liquid is allowed to cool and solidify. During solidification, the alloy expands and fills the section of well to be plugged or a portion thereof. Once primary and secondary barriers are in place, the well can be closed and the Christmas tree removed. A rock-to-rock plug can be set by removing or partially removing the tubular and outer casing, or just inner casing/tubulars can be removed if the exterior cement and casing are of sufficient quality.

Abstract: A method of plugging a well in a plug and abandonment procedure includes providing a tubing in a wellbore, in a location for a well plug, the tubing is provided with an internal cable section placed inside of the tubing, and forming a plug in the well in said location for the well plug across the width of the tubing and a surrounding wellbore annulus to create a permanent barrier without pulling the tubing from the wellbore. The step of forming the plug includes substantially removing the internal cable section inside the tubing and forming a fluid-tight seal in the tubing where the internal cable section has been removed, for separating, on either side of the seal, first and second fluid volumes of the tubing.

Abstract: A fluid placement tool, comprising: a connecting section at a proximal end of the fluid placement tool for coupling the fluid placement tool to a conveyance; an actuating section coupled to the connecting section, wherein the actuating section comprises a first check valve and a piston, wherein the first check valve is positioned to allow fluid flow through the actuating section and into engagement with the piston; and a fluid containment section, wherein the fluid containment section comprises a fluid reservoir and a second check valve, wherein the fluid reservoir is disposed between the first check valve and the second check valve, wherein the second check valve is position to only allow flow out of the fluid containment section; wherein the actuating section is operable to drive the piston through the fluid reservoir for displacement of a fluid from the fluid reservoir and into a wellbore.

Abstract: This disclosure presents a new tool and methodology to work, in a single-trip system, and create conduits through the casing or tubing to access the annuli, circulate out the annuli contents, accurately deliver the cement required to create the subsequent barrier. The tool and system provided by this disclosure provide a cost effective way of plugging an oil and gas well in a single trip without the need to remove in-place production casing.

Abstract: A rotary steerable tool used for directional drilling include a housing, at least one external director, and at least one valve. The external director is hydraulically movable to an extended condition relative to the housing, and the valve selectively directs pressurized fluid from a first side of the valve to the external director on the valve's second side. A first seal of the valve is selectively orientable about an axis and has an inlet, which communicates with the pressurized fluid from the first side. A second seal of the valve disposed adjacent the first seal has an outlet, which communicates the pressurized fluid to the second side at least when aligned with the inlet. A bearing assembly of the valve is disposed at the axis between the seals and has male and female bearing surfaces, which are angled off the axis and are mated with one another.

Abstract: A fracturing tool is used for hydraulically fracturing multiple stages of a well bore with treatment fluid. The tool includes a tubular housing retaining a longitudinally sliding sleeve which moves between a first position concealing fluid ports in the tubular housing and a second position in which the ports are uncovered. A deformable seat disposed in the sliding sleeve cooperates with an actuating member which is directed downwardly through a fracturing string locating a plurality of tools therein associated with respective stages of an isolated zone to sequentially uncover the fluid ports. Disposed in the fluid ports are burst plugs arranged to open when exposed to a threshold pressure. All uncovered burst plugs of the tools within the isolated zone can thus be sequentially uncovered and then opened when exposed to the threshold pressure to permit the treatment fluid to exit from the housing into the surrounding well bore.

Abstract: A well comprising a pressure activated device exposed to pressure in an annulus above a barrier between an upper tubular and the borehole. An acoustic or electromagnetic (EM) transmitter is coupled to the pressure activated device and configured to transmit a control signal to a respective receiver below the barrier for controlling a valve. In the event of an emergency, certain embodiments allow the pressure in the annulus to be quickly dropped, activating the transmitter to close the valve below the barrier, thus isolating the well below the barrier. A variety of default states may be programmed into the transmitter, such as transmitting a ‘stay-open’ signal to the receiver controlling the valve, which is configured to close if this signal is not received. A further EM or acoustic transmitter may be coupled to the valve to send information from below the barrier to above the barrier, such as pressure data or valve status.

Abstract: A multiple event trigger and actuation system including an actuator having an actuation component, a frangible dome and a pressure shiftable sleeve, a trigger having an incrementally movable stem, a holding configuration operably connected to the stem and configured to allow an incremental movement at a time based upon a pressure cycle and then hold the stem in such incremented position, and a rupture disk, the disk being positioned between a port to a pressure source and a trigger chamber, and a trigger transfer sleeve operatively connected to the shiftable sleeve to cause movement of the shiftable sleeve upon movement of the trigger transfer sleeve.

Abstract: A drain-back check valve assembly includes a body having a passageway with an inlet and an outlet. A bypass port extends from the passageway to an outer surface of the valve body. A main poppet valve assembly is disposed in the passageway and moveable between a closed position which prevents fluid flow from the outlet to the inlet and an open position which allows fluid flow from the inlet to the outlet. The main poppet valve assembly includes a poppet and a spool guide fixed to the poppet. The guide has a sidewall which includes a drain-back port. When the main poppet valve assembly is in the closed position, the drain-back port is aligned with the bypass port. When the main poppet valve assembly is in the opened position, the drain-back port is not aligned with the bypass port.

Abstract: A method for the economic assessment of residual oil zones (“ROZ”), support for the engineering of the design of CO2 enhanced oil recovery (“EOR”) systems associated with production of petroleum from ROZ, support of EOR operations, and subsequent management and monitoring of CO2 sequestered in ROZ is disclosed. This efficient identification and assessment of ROZs significantly increases the geographic footprint and target locations into which CO2 can be injected and ultimately utilized and permanently sequestered in a commercial fashion generating value to partially offset the parasitic costs associated with the capture of anthropogenic CO2. Microbial self limitation (MSL) conditions of an ROZ are exploited for the assessment and management purposes of the ROZ.

Abstract: A subsurface hydrocarbon reservoir is simulated by sequential solution of reservoir and well equations to simulate fluid flow inside the reservoir and well production rates. Sequential solution of reservoir and well equations treats wells as specified bottom hole pressure wells. This avoids solving large matrices resulting from the simultaneous solution of the reservoir and well equations which can be computationally very expensive for large number of unknowns and require special sparse matrix solvers. Such sequential solution involves regular reservoir system solvers complemented by small matrices for the numerical solution of the well bottom hole pressures. The solution is performed on tridiagonal matrices for the adjacent reservoir cells to the well cells at the perforated well intervals; and a vector of the unknown reservoir potentials for the adjacent reservoir cells.

Abstract: A method can include forming a mixture of an explosive and a thermally conductive material; disposing at least a portion of the mixture in a chamber of a capsule; and at least partially sealing the chamber.

Abstract: A method of remanufacturing a fluid end block having a plurality of segments adapted to receive working fluid includes removing at least one damaged segment from the plurality of segments of the fluid end block. The method also includes providing at least one replacement segment at a location of the at least one damaged segment. The method further includes providing a seal between a first surface of the at least one replacement segment and a first surface of at least one adjacent segment of the plurality of segments. The method includes coupling the at least one replacement segment with the at least one adjacent segment to form a remanufactured fluid end block.

Abstract: A method of increasing a stimulated reservoir volume in a hydrocarbon-bearing formation in fluid communication with a wellbore, the method including drilling a plurality of lateral extensions at varying depths in the formation extending from a vertical wellbore using underbalanced coiled tubing drilling; and injecting an exothermic reaction component into the plurality of lateral extensions to create a plurality of fractures extending outwardly from and between the plurality of lateral extensions to create a multilateral fracture network.

Abstract: Remotely actuated screenout relief valves, systems and methods are disclosed herein. The methods include providing a proppant slurry stream that includes proppant to a casing conduit that is defined by a casing string that extends within a subterranean formation. The methods further include detecting an operational parameter that is indicative of a screenout event within the casing conduit. Responsive to the detecting, the methods include providing a flush fluid stream to the casing conduit, opening the remotely actuated screenout relief valve, and displacing the proppant from the casing conduit into the subterranean formation with the flush fluid stream via the remotely actuated screenout relief valve. The methods may further include closing the remotely actuated screenout relief valve. The systems include hydrocarbon wells that include the remotely actuated screenout relief valve and/or hydrocarbon wells that include controllers that are configured to perform at least a portion of the methods.

Abstract: Systems and methods for controlling a drilling rig are disclosed herein. A driller can select between modes: local, human-machine interface (HMI), and automatic. In a local mode a motor operator is instructed to operate a genset for the drilling rig. In a Remote mode the driller can operate the genset directly without the need for a motor operator to start or stop the gensets. In an automatic mode, the genset is controlled according to a well plan including a power consumption schedule.

Abstract: A method for determining a rotational frequency of a positive displacement motor positioned in a downhole portion of a drill string, the method including: providing at least one measurement device for measuring a property of a part of the drill string; providing a processor for processing a signal output by the at least one measurement device; operating the positive displacement motor whilst the part of the drill string is in a non-driven state; receiving the signal at the processor; determining, using the processor, a frequency spectrum of the signal; and determining the rotational frequency of the positive displacement motor by: identifying a peak in the frequency spectrum in a pre-determined frequency range associated with an expected rotational frequency of the positive displacement motor; and/or identifying a peak in the frequency spectrum having a pre-determined peak width associated with an expected rotational frequency of the positive displacement motor.

Abstract: A tubular system includes a side pocket mandrel having at least one side pocket defining a device storage zone. A conductor extends along the tubular system to the side pocket. A stored device is arranged in the device storage zone.

Abstract: Techniques for determining geometries of hydraulic fractures include identifying a data structure that includes data associated with hydraulic fracture identifiers and observed fluid pressures, at least one of the hydraulic fracture identifiers representing a first hydraulic fracture formed from a monitor wellbore into a subsurface rock formation and at least another of the hydraulic fracture identifiers representing a second hydraulic fracture formed from a treatment wellbore into the subsurface rock formation, at least one of the observed fluid pressures includes a pressure change in a fluid in the first hydraulic fracture that is induced by formation of the second hydraulic fracture; performing a single- or multi-objective, non-linear constrained optimization analysis to minimize at least one objective function associated with the observed fluid pressures; and based on minimizing the at least one objective function, determining respective sets of hydraulic fracture geometries associated with at least one o

Abstract: Hydraulic fracturing of subterranean formations has become more complex and detailed as information increases. Methods for calculating and monitoring reservoir pressures during treatment provide unique opportunities to adjust treatments on the fly. Treatments include acid fracturing, fracture acidizing, acid stimulation, propped acid fracture stimulation, hydraulic fracturing, slick water based hydraulic fracturing, foamed based hydraulic fracturing, foam based acid fracturing, foamed based acid diversion, any other physical particulate and fiber based hydraulic fracturing or matrix treatment.

Abstract: Techniques for determining geometries of hydraulic fractures include identifying a data structure that includes data associated with hydraulic fracture identifiers and observed fluid pressures, at least one of the hydraulic fracture identifiers representing a first hydraulic fracture formed from a monitor wellbore into a subsurface rock formation and at least another of the hydraulic fracture identifiers representing a second hydraulic fracture formed from a treatment wellbore into the subsurface rock formation, at least one of the observed fluid pressures includes a pressure change in a fluid in the first hydraulic fracture that is induced by formation of the second hydraulic fracture; performing a single- or multi-objective, non-linear constrained optimization analysis to minimize at least one objective function associated with the observed fluid pressures; and based on minimizing the at least one objective function, determining respective sets of hydraulic fracture geometries associated with at least one o

Abstract: A method of pressure testing a casing system (12) comprising deploying an apparatus (110) with a container (68) formed from drill pipe or production tubing, on a string of drill pipe or production tubing into a well, such that a port (61) thereof is provided in an isolated section of the well. The isolated section of the well has a higher pressure than the pressure of a gas sealed in the container (68). The port (61) is opened and pressure in the isolated section is monitored to assess its integrity. Communication with the apparatus is achieved by wireless means sending pressure data, control signals for controlling the port and/or other data or commands.

Abstract: An embodiment a monitoring and control system that includes an instrumented top sub configured to obtain drilling data.

Abstract: An example method includes connecting a casing liner device to a polished bore receptacle (PBR) of a liner hanger outside of a wellbore. The PBR includes a first connection mechanism. The casing liner device includes second connection mechanism that connects to the first connection mechanism. The casing liner device connected to the PBR is run into the wellbore in tandem.

Abstract: Inversion-based workflows are provided for real-time interpretation of the electromagnetic (EM) look-around and look-ahead measurements. The profile of a look-around zone is determined by interpreting EM measurements of a look-around zone. The profile of the look-around zone characterizes formation dip as well as vertical resistivity or resistivity anisotropy of one or more formation layers of the look-around zone. The profile of a look-ahead zone is determined by interpreting EM measurements of the look-ahead zone. The profile of the look-ahead zone characterizes formation dip as well as horizontal resistivity, vertical resistivity or anisotropy of one or more formation layers of the look-ahead zone. The workflows can also involve interpretation of look-around resistivity measurements to aid in the characterization of the look-around zone.

Abstract: Methods and downhole tools for operation within in a wellbore that extends into a subterranean formation. The operation includes simultaneously causing a change in a first parameter of fluid drawn into the downhole tool from the formation and determining a change in a second parameter of the fluid relative to the change in the first parameter. A third parameter of the fluid is determined based on the first and second parameter changes.