Abstract: Quality factors associated with formation pressure measurements at various depths in the geologic formation are determined based on one or more well logs of formation properties in a geologic formation. A formation testing tool with two or more probes is positioned in a borehole of the geologic formation based on the quality factors. The two or more probes in the borehole perform respective formation pressure measurements, where each formation pressure measurement is performed at a different depth. The formation pressure measurements and the given distance between the two or more probes indicate a formation pressure gradient.

Abstract: Based upon a measured first resistance, a first delta curve is selected. Based upon a measured second resistance, a second delta curve is selected. A first fuel valve position (FVP) is received from a first position sensor, and the first FVP is applied to the first delta curve to obtain a first offset. A second FVP is received from a second position sensor, and the second FVP is applied to the second delta curve to obtain a second offset. The first offset is applied to the first measured FVP to obtain the first compensated FVP and the second offset is applied to the second measured FVP to obtain the second compensated FVP. The first compensated FVP and the second compensated FVP are correlated to obtain a final compensated FVP, which is applied to a desired fuel valve position to obtain a final fuel valve position.

Abstract: A method comprises determining an adaptive fluid predictive model calibrated with a plurality of types of sensor data, wherein the plurality of types of sensor responses comprise a first type of sensor response associated with a synthetic parameter space and a second type of sensor response associated with a tool parameter space. The method comprises applying the adaptive fluid predictive model to one or more fluid samples from field measurements obtained from a tool deployed in a wellbore formed in a subterranean formation and determining a value of a fluid answer product prediction with the applied adaptive fluid predictive model. The method comprises facilitating a wellbore operation with the tool based on the value of the fluid answer product prediction.

Abstract: A formation tester tool assembly includes a seal member mounted on rigid stabilizer that contacts a borehole wall separately from the seal member, so that seal exposure to a stabilization load that presses the tool against the borehole wall is limited or reduced by contact engagement of the stabilizer with the borehole wall. The stabilizer is provided by a hydraulically actuated probe piston reciprocally movable relative to a tool body on which it is mounted. The seal member is in some embodiments movable relative to the probe piston, for example being configured for hydraulic actuation to sealingly engage the borehole wall while the tool body is stabilized by action of the probe piston.

Abstract: An actuator including a housing defining a volume changeable chamber therein, the volume changeable chamber being divided into a first volume changeable subchamber, a second volume changeable subchamber, a separator disposed between the first volume changeable subchamber and the second volume changeable subchamber, the separator initially preventing mixing of substances in the first volume changeable subchamber and in the second volume changeable subchamber and at a selected time allowing fluid movement between the first and second volume changeable subchamber. A method for actuating a tool including triggering a separator between a first volume changeable subchamber having a first substance therein and a second volume changeable subchamber having a second substance therein within a housing containing the first volume changeable subchamber and the second volume changeable subchamber. A borehole system including a borehole in a subsurface formation, and an actuator disposed in the borehole.

Abstract: A technique facilitates control over the positioning of a well tool in a wellbore or other type of borehole. A well tool is combined with a centralizer system. The centralizer system has a plurality of extension members which are oriented to extend outwardly, e.g. radially outwardly, from the well tool. The extension members of the plurality of extension members are controllable to enable controlled positioning of the well tool within the borehole. The extension members may be actuated to centralize the well tool along a desired borehole axis.

Abstract: Automated systems are disclosed that enable the rapid provision of fluids to downhole isolation tools. This is achieved by automatically optimizing the use of power available downhole by providing a high flowrate when pressure demand is low and a lower flowrate when pressure demand is high. Methods are disclosed which utilize the apparatus in a bottom hole assembly during downhole operations for isolating segments of a borehole.

Abstract: A method may comprise positioning a downhole fluid sampling tool into a wellbore; performing a pressure test operation within the wellbore; performing a pumpout operation within the wellbore; identifying one or more formation parameters at least in part from the at least one pressure test operation or the at least one pumpout operation; building a correlation model that relates a pumpout trend to the one or more formation parameters; determining a time when the downhole fluid sampling tool takes a clean fluid sample utilizing at least the correlation model; and acquiring the clean fluid sample with the downhole fluid sampling tool from the wellbore. Additionally, a system may comprise a downhole fluid sampling tool configured to: perform a pressure test operation within a wellbore; and perform a pumpout operation within the wellbore.

Abstract: A system, apparatus, and method for determining intact versus fractured rock zones based on performance monitoring of an electric drilling machine when drilling a blasthole. The determination can be based on a calculation of compensated blastability index (“CBI”) values using transformed performance monitoring data collected in real-time as the drilling machine drills the blasthole.

Abstract: A fluid sampling tool and method for fluid sampling in an ultra-tight or tight formation. The tool may include a packer assembly that includes one or more inflatable packers and one or more exhaust ports, a multi-chamber section that includes one or more sample chambers, and at least two storage sections that each contain a storage tank, wherein each storage tank holds a stimulation fluid. A method for performing a stimulation operation that includes disposing a fluid sampling tool into a well, moving the fluid sampling tool to a zone of interest, and isolating the zone of interest with a packer assembly on the fluid sampling tool. The method may further include performing a first pressure draw down and a first pressure build up, performing an injectivity test, and performing a sampling process.

Abstract: An extendable downhole tool including a first extendable probe, a second extendable probe and a pressure system configured to apply pressure to the first extendable probe and the second extendable probe. The pressure system also include an extension valve configured to pass fluid pressure to an inner surface of a first piston and a second piston and a retracting valve configured to pass the fluid pressure to an outer surface of the first piston and the second piston. An area ratio of the first piston may be greater than an area ratio of the second piston. The extendable downhole tool may also include a screen and a screen scraper associated with one or more of the first extendable probe and the second extendable probe.

Abstract: A formation sampling tool including a plurality of ferrofluidic seals for sealing the formation sampling tool against a wellbore wall of a wellbore, each adjacent pair of the plurality of ferrofluidic seals defining a formation fluid inflow section through which formation fluid enters the formation sampling tool via fluid inflow lines, wherein a first ferrofluidic seal of the plurality of ferrofluidic seals is distal a drill bit, and wherein a last ferrofluidic seal of the plurality of ferrofluidic seals is proximate the drill bit; a formation fluid sampling line, wherein the formation fluid sampling line is in fluid communication with the one or more fluid inflow lines; one or more sensors in fluid communication with the one or more fluid inflow lines and/or the formation fluid sampling line; and a pump configured to pump formation fluid into the formation sampling tool via each of the formation fluid inflow sections.

Abstract: A system for processing samples from a body of fluid. The system includes one or more sample bottles for acquiring a sample from the body of fluid. Each sample bottle initially retains a pre-filling fluid. Each sample bottle includes a fluidic inlet port and a bottle outlet port. Each sample bottle has an inlet check valve coupled to the fluidic inlet port, the inlet check valve configured to allow fluid from the body of fluid into a sample bottle via the fluidic inlet port when the pressure difference between the body of fluid and fluid within the sample bottle reaches a threshold. The system further includes at least one pump, the bottle outlet port of each sample bottle selectively coupled to the at least one pump via a different control valve. The at least one pump is configured, in a first configuration, to remove prefilling fluid from each selected sample bottle such that, for each selected sample bottle, the pressure difference threshold is reached and a sample from the body of fluid is acquired.

Abstract: A protective tubular is run downhole into a wellbore in a subterranean formation. A non-metallic tubular is disposed within the protective tubular. The non-metallic tubular includes an adapter. The adapter includes a spring-loaded latch, a ball seat, a shear pin, and a ball catcher. While intact, the shear pin holds a position of the non-metallic tubular relative to the protective tubular. A ball is used to shear the shear pin of the adapter, thereby allowing the non-metallic tubular to move relative to the protective tubular. Pressure is applied to the ball to move the non-metallic tubular relative to the protective tubular. The non-metallic tubular is coupled to the protective tubular using the spring-loaded latch of the adapter. Pressure is applied to the ball to shear the ball seat of the adapter. A fluid is flowed into the non-metallic tubular through an opening defined by the adapter.

Abstract: An example logging tool includes an injection system, a detection system, and an electric control and processing system. The injection system includes a gas source, and is configured to inject a first gas from the gas source into a region of a subterranean formation. The detection system includes a gas detection chamber and one or more sensors disposed in the gas detection chamber, and is configured to receive, in the gas detection chamber, a sample from the region of the subterranean formation, and generate, using the one or more sensors, sensor measurements of the sample, The electronic control and processing system includes one or more processors, and is configured to determine one or more characteristics of the subterranean formation based on the sensor measurements.

Abstract: Systems and methods are described to determine a prioritization schedule for samples handled by a system with multiple remote sampling systems. A system embodiment includes, but is not limited to, an analysis system at a first location; one or more remote sampling systems at remote from the first location, the one or more remote sampling systems configured to receive a liquid segment and transfer a liquid sample to the analysis system via a transfer line; and a controller communicatively coupled with the analysis system and the one or more remote sampling systems, the controller configured to assign a priority value to a sample for analysis by the analysis system and to manage a queue of samples received from at the one or more remote sampling systems on the basis of the assigned priority value.

Abstract: A downhole sample extractor includes a sample container chamber that holds a sample container containing a downhole sample. The downhole sample extractor also includes a sample extraction chamber having an internal chamber that is partially filled with a carrier solution, wherein the downhole sample is mixed with the carrier solution in the internal chamber of the extraction container. The downhole sample extractor further includes a first piston that, when actuated, inserts the sample container into the internal chamber of the sample extraction chamber.

Abstract: A formation tester tool assembly includes a seal member mounted on rigid stabilizer that contacts a borehole wall separately from the seal member, so that seal exposure to a stabilization load that presses the tool against the borehole wall is limited or reduced by contact engagement of the stabilizer with the borehole wall. The stabilizer is provided by a hydraulically actuated probe piston reciprocally movable relative to a tool body on which it is mounted. The seal member is in some embodiments movable relative to the probe piston, for example being configured for hydraulic actuation to sealingly engage the borehole wall while the tool body is stabilized by action of the probe piston.

Abstract: Quality factors associated with formation pressure measurements at various depths in the geologic formation are determined based on one or more well logs of formation properties in a geologic formation. A formation testing tool with two or more probes is positioned in a borehole of the geologic formation based on the quality factors. The two or more probes in the borehole perform respective formation pressure measurements, where each formation pressure measurement is performed at a different depth. The formation pressure measurements and the given distance between the two or more probes indicate a formation pressure gradient.

Abstract: A protective tubular is run downhole into a wellbore in a subterranean formation. A non-metallic tubular is disposed within the protective tubular. The non-metallic tubular includes an adapter. The adapter includes a spring-loaded latch, a ball seat, a shear pin, and a ball catcher. While intact, the shear pin holds a position of the non-metallic tubular relative to the protective tubular. A ball is used to shear the shear pin of the adapter, thereby allowing the non-metallic tubular to move relative to the protective tubular. Pressure is applied to the ball to move the non-metallic tubular relative to the protective tubular. The non-metallic tubular is coupled to the protective tubular using the spring-loaded latch of the adapter. Pressure is applied to the ball to shear the ball seat of the adapter. A fluid is flowed into the non-metallic tubular through an opening defined by the adapter.

Abstract: A double-walled drill pipe includes an outer drill pipe, an inner drill pipe and a drill pipe sealing apparatus. The outer drill pipe includes an axial through hole and a wall surface through hole, and the wall surface through hole is disposed in a wall surface of the outer drill pipe to connect the outside of the double-walled drill pipe and the axial through hole. The inner drill pipe is rotatably disposed in the axial through hole, and includes a fluid guiding hole connected to the wall surface through hole. The drill pipe sealing apparatus is disposed between the outer drill pipe and the inner drill pipe. The drill pipe sealing apparatus is axially located between a driving end and a connecting port of the wall surface through hole connected to the axial through hole. A drilling machine including the double-walled drill pipe is also provided.

Abstract: System and methods for customizing fracturing fluids downhole for real-time optimization of micro-fracturing operations are provided. Downhole operating conditions are monitored during a micro-fracturing operation along a portion of a wellbore within a subterranean formation, based on downhole measurements collected by sensors of a downhole formation tester. Injection parameters for a fracturing fluid to be injected from a bulk storage chamber of the downhole formation tester into the subterranean formation are determined based on the downhole operating conditions. Signals for customizing the fracturing fluid using one or more fluid additives stored within corresponding fluid storage chambers of the downhole formation tester are transmitted to a controller of the downhole formation tester, based on the injection parameters.

Abstract: A siphon pump chimney can be used in a mini-drillstem test to increase formation fluid flow rates. A formation tester can be coupled to a siphon pump chimney via a wet connect assembly to transfer formation fluid from a fluid-bearing formation. The siphon pump chimney can receive the formation fluid through the wet connect and disperse the formation fluid into a drill pipe that is flowing drilling fluid. The siphon pump chimney can include check valves to prevent the drilling fluid from entering the siphon pump chimney. The siphon pump chimney can be configured to have a variable height that can reduce pressure within the siphon pump chimney to a pressure value that can be close to or less than the formation pressure, which can allow a pump to operate at high flow rates or be bypassed in a free flow configuration.

Abstract: An apparatus for performing a well test operation includes a tubular member having a surge chamber and a valve that can control fluid flow from a well into the surge chamber during the well test operation. The apparatus can also include a flow control device, in addition to the valve, for further controlling fluid flow into the surge chamber from the well. Flow rate and pressure data can be measured during the well test operation and used to estimate reservoir properties. Various other systems, devices, and methods are also disclosed.

Abstract: A focused sampling method comprising: allocating fluid flow from a guard zone through a guard line and from a sample zone through a sample line, the guard zone being positioned at least partially concentrically about the sample zone and the guard zone, and the sample zone being in fluid communication with a formation; pumping, via a common line, a combined fluid flow from the formation through to a discard line for a pre-sampling time period, the combined flow comprising the fluid flow allocated from the guard zone into the guard line and the fluid flow allocated from the sample zone into the sample line; subsequent the pre-sampling time period, discontinuing flow from the guard line into the common line, such that the combined flow comprises only the fluid flow from the sample line; and introducing the combined flow comprising the fluid flow from the sample line into a sample chamber.

Abstract: Cementing plugs and methods of forming cementing plugs containing a plurality of objects are disclosed. In some implementations, the cementing plug includes a body having a plurality of objects dispersed within the body. One or more of the objects may protrude from a surface of the body of the cementing plug. In some implementations, the plurality of objects may be irregularly-shaped, uniformly-shaped, or a combination of irregularly-shaped and uniformly-shaped. The plurality of objects may be randomly distributed in the body of the cementing plug or uniformly arranged in the body of the cementing plug. In some implementations, a portion of the plurality of objects may be uniformly arranged and another portion of the plurality of objects may be randomly distributed in the body of the cementing plug.

Abstract: A sampling-by-pushing system includes a setting-by-pushing mechanism and a centralizing device. The setting-by-pushing mechanism is connected with the centralizing device through a connecting pipe, and is configured to be set and sealed in a borehole. The centralizing device includes a base body and a retractable support arm arranged on the base body. The support arm is configured to be in contact with the wall of the borehole so as to position the setting-by-pushing mechanism in the center of the borehole.

Abstract: Shaped charge slitting devices for control line disruption in a hydrocarbon well and related methods for sealing the hydrocarbon well. The shaped charge slitting devices include a plurality of shaped charges. Each shaped charge is configured to, upon actuation, transform a corresponding liner into a high-speed sheet portion, which is configured to form a circumferential slit within production tubing, and a low-speed slug portion, which is configured to at least partially seal the circumferential slit. The methods include positioning a shaped charge slitting device within a selected region of a tubing conduit, actuating the shaped charge slitting device to form a plurality of circumferential slits within the production tubing and also to sever a control line, pumping a sealing material into an annular space via a sealing material injection opening that extends between the tubing conduit and the annular space, and curing the sealing material to form a fluid seal.

Abstract: Method of optimizing well placement in an unconventional reservoir, by obtaining a plurality of produced oil, produced water and produced gas samples from an unconventional reservoir over a period of time, and obtaining a plurality of rock samples from the reservoir. Each of those plurality of samples is chemically fingerprinted, as well as assigned time and location identifiers. This data is then used to generate a plurality of reservoir maps over time and those maps then used to optimizing well placement in the reservoir.

Abstract: A formation-tester tool may be positioned downhole in an openhole wellbore. The formation-tester tool may suspend proppant in fracturing fluid located in a chamber of the formation-tester tool. The formation-tester tool may generate a test fracture in an uncased wall of an area of interest of a subterranean formation adjacent to the openhole wellbore and inject the fracturing fluid and the proppant toward the uncased wall and into the test fracture. The formation-tester tool may retrieve a fluid sample from a reservoir within the area of interest of the subterranean formation by creating a drawdown pressure in the test fracture.

Abstract: A well tool assembly can include a well screen configured to filter fluid flow between an interior and an exterior of a tubular string, and an outflow control section that permits the fluid flow in an outward direction and prevents the fluid flow in an inward direction, the outflow control section including at least two outflow control valves arranged in series. A method can include installing a well tool assembly including a well screen, flowing a fluid from an exterior to an interior of a tubular string through the well screen and an inflow control valve of the well tool assembly, and flowing another fluid from the interior to the exterior of the tubular string through the well screen and at least one outflow control valve of the well tool assembly.

Abstract: Disclosed is a downhole tool comprising a fast hybrid telemetry module, and electronics module, and an acoustic flow meter tool module. Suitably, the fast hybrid telemetry module, the electronics module, and the acoustic flow meter tool module are assembled in series. Initially, the acoustic flow meter tool module is preferably provided for regular measurement of fluid temperature, fluid velocity, and fluid density in downhole oilfield production applications. Preferably, the electronics module is provided for data processing and self-compensation of the acoustic flow meter tool module (i.e., automated adjustment of acoustic wave energy and signal conditioning settings to perform flow rate measurements in a wide range of well bore conditions). Finally, the fast hybrid telemetry module is configured for bidirectional data transmission between the downhole tool and a surface data acquisition and monitoring station.

Abstract: An integrated monitoring system for radiological surveillance of groundwater and an operation method thereof are disclosed.

Abstract: Methods and systems for delivering EOR substances and determining their efficiency in real time, or near real time, are disclosed. The systems and methods of the present disclosure are especially important in determining petrophysical information about the reservoir as well as the in-situ effect of substances on enhanced oil recovery.

Abstract: A well testing tool mounted on a drill string is positioned within a zone of interest in a wellbore. An RFID tag with a density between 400 and 500 pounds per square foot is dropped through the drill string to activate the well testing tool. An uphole packer positioned at an uphole end of the well testing tool and a downhole packer positioned at a downhole end of the well testing tool are expanded to isolate a portion of the zone of interest between the expanded uphole packer and the expanded downhole packer. A three-way valve positioned between the uphole packer and the downhole packer is adjusted to allow fluid to flow from the isolated portion of the zone of interest into the drill string. One or more sensors within the well testing tool are activated.

Abstract: A coreflood method that treats a consolidated porous medium, e.g., as a bundle of capillaries of various sizes as a surfactant alternating gas (SAG) method of foam injection. An electrical resistivity tool is used to monitor and measure in-situ changes in water and gas saturation while a high-resolution pressure transducer measures the pressure drop across the sample. A consolidated rock sample pre-saturated with a surfactant solution is injected with a small slug of gas and then a surfactant solution is injected until a steady state flow is observed. Graphical analysis of the saturation and pressure profile in each cycle allows the estimation of water saturation, saturation of the mobile and trapped fractions, and a corresponding pressure drop. Similarly, graphical analysis of the saturation and pressure profile in multiple SAG cycles generates a data set as a function of pore size, water saturation, and capillary pressure.

Abstract: Provided is a tool-body that arranges ultrasonic and electrical capacitance sensors at close distances to the casing wall of the wellbore such that properties of thickness, flow velocity, acoustic impedance and the dielectric constant of the liquid layer are measured at a number of circumferential locations inside the casing of the wellbore. These measured values may then be combined to derive the average flow rate of the layer and also used to identify whether the liquid is water or condensate/oil, or a mixture of the two with a certain water-in-liquid ratio. Combined with a gas flow rate and a liquid droplets concentration measurement, the total liquid flow rate and liquid type can be derived.

Abstract: A downhole tool is operated to pump fluid from a subterranean formation while obtaining fluid property measurements pertaining to the pumped fluid. The downhole tool is in communication with surface equipment located at the wellsite surface. The downhole tool and/or surface equipment is operated to estimate a first linear, exponential, logarithmic, and/or other relationship between compressibility and pressure of the pumped fluid based on the fluid property measurements. The downhole tool and/or surface equipment may also be operated to estimate a second linear, exponential, logarithmic, and/or other relationship between formation volume factor and pressure of the pumped fluid based on the first relationship. The downhole tool and/or surface equipment may also be operated to measure and correct optical density of the pumped fluid based on the first relationship.

Abstract: A method includes automatically creating one or more test schedules for a well test of one or more wells in an oil or gas production environment. The method also includes automatically creating one or more test frames for use in generation of the well test. The method further includes, following execution of the test frame, automatically validating one or more test records generated during the one or more test frames. In addition, the method includes automatically creating the well test for determining one or more well characteristics.

Abstract: Systems and methods for subterranean formation testing. A method may include: lowering a formation testing tool into a subterranean formation, wherein the formation testing tool may include memory, a pump, a formation probe, at least two sample chambers, wherein the at least two sample chambers may include probes to measure pressure and temperature; extracting a fluid from the subterranean formation with the pump and the formation probe; flowing the fluid into the at least two sample chambers with the pump; storing pressure and temperature data of the fluid in the memory; and removing the at least two sample chambers from the formation testing tool.

Abstract: An Automatic Pulse Tracer Velocimeter (APTV) including arc-type APTVs and cross-type APTVs along with a field station and a master station capable of wireless communication with a remote computing devices. The APTV measures flow velocity in a flowable medium by injecting a small amount of a conductive tracer solution into a water column. Following injection, a plurality of wire detector pairs positioned downstream of the injection point are programmed to continuously make conductivity measurements at pre-determined time intervals. A tracer curve of the conductivity measurements over time is created and used to obtain velocity measurements.

Abstract: A filter device housed within a body component. The filter device can include an outer filter and an inner filter positioned coaxially within the outer filter. The outer and inner filters may be composed of a material having mesh, slots, holes, or any other openings being of a sufficient size and shape to restrict passage of items of a predetermined size or larger. Formed between the inner and outer filters is a first annular space into which fluid that is provided down the drill string may enter. The filter device may also include a valve within the internal bore which regulates passage of wellbore fluid provided to the drill string, or for a wireline or slickline, to pass through the filter device in order to access other components of the drill string downhole from the filter device.

Abstract: An innovative apparatus and computer implemented methods to obtain values for a set of scalars corresponding to each force and displacement, which may be obtained from acoustical signals captured by sensors of a drill bit while drilling, in a material of known mechanical properties, such as a cement from casing the well, such that the application and use of the scalars in relation to measurements of the mechanics while drilling, such as the acceleration of the bit and motion of the bit captured by sensors such as accelerometers, allow for absolute values of mechanical rock properties to be obtained in rock formations, being drilled through, with otherwise unknown mechanical properties prior to drilling.

Abstract: A method for detecting pad construction and/or drilling and/or for hydraulic fracturing of at least one hydrocarbon well, comprising the steps of: selecting at least one specified well location, obtaining at least one time series of top view images of the specified well location, in which each top view image has a date corresponding to a day of acquisition of the top view image, processing the time series of top view images to detect at least one top view image showing the apparition of a well pad and/or showing drilling activity and/or showing fracturing activity, exporting the date corresponding to the acquisition day of the top view image showing the apparition of the well pad and/or drilling activity and/or fracturing activity, providing, based on export date, an information of pad construction date and/or drilling starting date and/or fracturing starting date and/or a full production forecast for the specified well location.

Abstract: A sampling tool includes a tubular member and a sampling piston positioned within the tubular member. The sampling piston has a bore formed axially-therethrough. A secondary piston is positioned within the bore of the sampling piston. A check valve assembly is positioned at least partially within the tubular member. The secondary piston and the check valve assembly move together with respect to the tubular member.

Abstract: A laboratory device to measure horizontal displacement of soil around a region treated by vacuum preloading includes a box injected with dredger fill. A vertical drainage board and a vacuum pumping tube are buried within soil in the treatment region in connection with a vacuum degree detector and a vacuum pump. A seal membrane covers soil in the treatment region. A loading device is above the seal membrane. Transverse tubes are inserted into a side of the box and in surrounding soil of the treatment region. An annular sensing source, which moves together with the soil and which is movable along the transverse tubes, sleeved on the transverse tubes. Each transverse tube is provided with a sensing instrument, and the sensing instrument is connected with a sensor is inserted into the transverse tube. The different positions of the sensing source at different moments of time are determined.

Abstract: A method for determining a volume of a constituent(s) in a geological formation may include generating an equation of state based upon log measurements for the geological formation, with the equation of state providing a correlation between the log measurements, determining a quality factor for the equation of state, and for each of a plurality of different constituents expected to be in the formation, determining a constituent compliance factor for each of the constituents. The method may further include determining an uncertainty for each constituent compliance factor, determining a likelihood that each constituent is present in the formation based upon the quality factor, the constituent compliance factor for the constituent, and the uncertainty for the constituent compliance factor, generating a volumetric model based upon the log measurements and the determined likelihoods of the constituents in the formation, and determining the volume of the constituent(s) based upon the volumetric model.

Abstract: Systems, methods and devices for analyzing a sample of fluid extracted from a hydrocarbon-producing geological formation to detect a quantitative amount of hydrogen sulfide or disclosed. The systems methods and devices involve including a scavenger within a sample compartment to react with the hydrogen sulfide therein. The concentration of hydrogen sulfide in the sample may be derived as a function of the amount of scavenger remaining in the sample after reaction with hydrogen sulfide, an amount of byproduct of a reaction between the scavenger and the hydrogen sulfide, or an amount of hydrogen sulfide as measured following a secondary reaction that releases the hydrogen sulfide from the scavenger.

Abstract: A downhole tool, surface equipment, and/or remote equipment are utilized to obtain data associated with a subterranean hydrocarbon reservoir, fluid contained therein, and/or fluid obtained therefrom. At least one condition indicating that a density inversion exists in the fluid contained in the reservoir is identified from the data. Molecular sizes of fluid components contained within the reservoir are estimated from the data. A model of the density inversion is generated based on the data and molecular sizes. The density inversion model is utilized to estimate the density inversion amount and depth and time elapsed since the density inversion began to form within the reservoir. A model of a gravity-induced current of the density inversion is generated based on the data and the density inversion amount, depth, and elapsed time.

Abstract: A technique facilitates mechanical operation of components, e.g. valves, without utilizing electronics at the components or control lines routed to the components. An actuation control system is fully mechanical in the sense that it is constructed to mechanically shift to different control positions via pressure input, such as pressure input supplied along a wellbore annulus. The actuation control system utilizes a spool valve coupled with a pilot control circuit which establishes a reference pressure that can be used in shifting the spool valve to different operational positions.