Abstract: An exemplary method of the present disclosure includes causing, by a processing system proximate to the wellbore, injection of the lift gas into the wellbore at a first gas injection rate; obtaining, by the processing system, a first indication of a parameter associated with the wellbore, an arrival of a first fluid at a wellhead associated with the wellbore, or a composition of the first fluid; determining, by the processing system and based on the first indication, at least one of: a second gas injection rate of the intermittent gas lift system, a first period to inject the lift gas with the intermittent gas lift system, or a second period, subsequent to the first period, with no injection of the lift gas by the intermittent gas lift system; and operating, by the processing system, the intermittent gas lift system according to the determination.

Abstract: A well telemetry system supplies power to downhole sensor nodes employed for obtaining telemetry data in oil wells. The nodes are held in the cement that lines the well and surround the casing. At the surface, an AC power unit is connected to the casing and geological structure that surrounds the cement. Power to nodes is supplied using an AC resonant circuit that generates standing waves of electrical power on the casing. Power from the standing waves is delivered to the nodes which are located at antinodes of the standing wave. The nodes are held in cement that surround the casing, with one of their two electrodes connected to the casing and the other connected to the cement or to geological structure.

Abstract: A technique includes inducing a distributed temperature change along a portion of a wellbore and measuring a time varying temperature along the portion of the wellbore due to the induced change. The technique includes determining a distributed flow rate in the portion based at least in part on the measured time varying temperature before the temperature reaches equilibrium.

Abstract: An example system includes a casing for insertion into a wellbore that includes one or more inflow control devices (ICDs). The ICDs may be disposed along the casing string to control the inflow of water into the wellbore. The system may include one or more controllers, each of which may be associated with an ICD. The controllers may be configured to receive a radio frequency identification (RFID) and to determine whether the associated ICD is a target for the RFID. A target ICD may be an ICD associated with a water cut zone. If the ICD is the target for the RFID, the controller is configured to control the ICD to open or close, thereby controlling the inflow of water. If the ICD is not the target for the RFID, the controller is configured to repeat the RFID.

Abstract: An optical wireless rotary joint can include a first optical device and a second optical device. The first optical device can be coupled to a rotatable component for rotating with the rotatable component. The second optical device can be physically separated from the first optical device. The second optical device can be coupled to a stationary component for communicating data with the first optical device using an optical signal. The first optical device or the second optical device can include an optical transmitter for transmitting the optical signal based on the data. The other of the first optical device or the second optical device can include an optical receiver for generating a new signal in response to detecting the optical signal transmitted by the optical transmitter.

Abstract: Fracturing a reservoir includes providing a pad fluid to the reservoir via a wellbore in a well to create fractures in the reservoir, providing a fracturing fluid to the fractures via the wellbore, providing a geopolymer precursor fluid to the fractures via the wellbore, shutting in the wellbore at a wellbore pressure, thereby allowing the geopolymer precursor fluid to harden and form geopolymer proppant pillars in the fractures. Providing the geopolymer precursor fluid to the fractures includes pulsing quantities of the geopolymer precursor fluid into a continuous flow of the fracturing fluid or alternately pulsing quantities of the geopolymer precursor fluid and the fracturing fluid. An elapsed time between pulsing the quantities of the geopolymer precursor fluid is between 2 seconds and 20 minutes.

Abstract: This disclosure provides a method and device for detecting the damage rate of an inner coating of a downhole oil casing. The method includes filling the oil casing with electrolyte, obtaining the well depth-detection current on a discharge electrode in a process of moving the discharge electrode from one end of the oil casing to the other end of the oil casing, and determining a well depth-damage rate state of the inner coating of the oil casing according to the well depth-detection current. This application can realize quantitative judgment for the damage rate of an inner coating of a downhole oil casing, resulting in rapid in detection speed, convenient and safe in operation, and low detection cost.

Abstract: In some aspects, a method includes imaging a casing, completed wellbore, or open wellbore. An integrity problem is with the casing, completed wellbore, or open wellbore is determined based on the imaging. A placement zone for a filler, a filler amount, and filler parameters for the integrity problem is determined. The filler in the filler amount is injected in the placement zone. The filler is solidified at the placement zone.

Abstract: The invention provides a method for efficiently adjusting existing landfill gas well head control devices in a manner which reduces the overall air migration into the landfill's gas collection systems in a short period of time. The method also provides for mapping out hydrogen sulfide concentration areas of landfills; allowing for efficient evaluation and selective reduction of hydrogen sulfide.

Abstract: A method of inhibiting corrosion of metal during acid stimulation of an oil and gas well, whereby the oil and gas well is treated with an acidic treatment fluid that includes 10 to 28 wt. % of an acid, based on a total weight of the acidic treatment fluid, and 0.01 to 5% of a pyrazine corrosion inhibitor by weight per total volume of the acidic treatment fluid, wherein the pyrazine corrosion inhibitor is 2,3-pyrazine dicarboxylic acid, pyrazine-2-carboxamide, 2-methoxy-3-(1-methylpropyl) pyrazine, or combinations thereof.

Abstract: A system for controlling flow in a wellbore can include a down-hole control module that is hydraulically coupled to multiple components of the system. The control module can include a computer, which can be preprogrammed to operate the various components in a particular sequence, and communicate confirmation or error signals to a surface location. The control module can also include a micro-hydraulic motor and pump that can that can be instructed by the computer to selectively deliver hydraulic fluid to one or more of the components of the system. The system can include isolation members such as packers, hydraulic pressure maintenance devices (PMDs), hydraulic sheer joints, inflow control devices or valves (ICDs or ICVs) and a three-position valve that can be actuated by the control module without necessitating communication with a surface location.

Abstract: A method of producing fluids from a geological structure includes receiving field information associated with producing wells of a field; deriving a field specific model based on the field information, the field specific model including a proximity depletion synthetic variable and a fraction hit synthetic variable; identifying a proposed location based on the application of field management engine to the field specific model, the field management engine projecting a decrease in production from wells proximal to the location and projecting an improvement in a production objective; and drilling a well at the proposed location.

Abstract: A wellhead system includes a tubing or casing hanger to be installed in a wellhead, the tubing or casing hanger including an outer surface including a landing profile configured to engage a mating landing profile of the wellhead, a landing sensor configured to transmit a signal indicating contact between the landing profile of the tubing or casing hanger and the landing profile of the wellhead, and a processor configured to receive the signal transmitted by the landing sensor.

Abstract: A system and method for logging in a wellbore where sensor assemblies on a logging tool are deployed and landed in the wellbore. After the sensor assemblies are landed in the wellbore and released from the logging tool, the logging tool is pulled uphole. Moving the logging tool uphole from where the sensor assemblies are landed, reduces interference of the logging tool with measurements obtained with the sensor assemblies. The sensor assemblies include sensors for detecting fluid flow, pressure, temperature, fluid density, formation resistivity, and which can be mechanical, optical, acoustic, or electromagnetic.

Abstract: Gravity surveys of subterranean formations may be based on the simultaneous measurement of gravity and its derivatives to produce a higher resolution formation map or wellbore log.

Abstract: Example systems and methods are described for performing multilateral well sensing in a downhole environment. In an example system, a cased parent wellbore and a cased lateral wellbore intersect at a lateral junction. A sensor is deployed within the cased lateral wellbore that communicably couples to a transmitter module, wherein the transmitter module is deployed within the cased lateral wellbore downhole of the lateral junction and configured to generate acoustic signals. An optical fiber cable is deployed within the cased parent wellbore and configured to receive acoustic signals transmitted by the transmitter module in the cased lateral wellbore.

Abstract: Hydraulic fracturing of a geological formation is performed by injection of a proppant mixture into the geological formation to form fractures in the geological formation. The proppant mixture includes at least a liquid, proppant, and proppant additive particles. The hydraulic fracturing results in a presence of the proppant additive particles within the formed fractures, wherein the proppant additive particles are configured with a first complex conductivity that is measurably different than a second complex conductivity exhibited by materials comprising the geological formation. The formed fractures can then be imaged and mapped in the geological formation with electromagnetic energy at one or more frequencies in a manner so that the proppant additive particles function as a contrast agent due to the first complex conductivity of the proppant additive particles being measurably different from the second complex conductivity.

Abstract: A system for controlling flow in a wellbore can include a down-hole control module that is hydraulically coupled to multiple components of the system. The control module can include a computer, which can be preprogrammed to operate the various components in a particular sequence, and communicate confirmation or error signals to a surface location. The control module can also include a micro-hydraulic motor and pump that can that can be instructed by the computer to selectively deliver hydraulic fluid to one or more of the components of the system. The system can include isolation members such as packers, hydraulic pressure maintenance devices (PMDs), hydraulic shear joints, inflow control devices or valves (ICDs or ICVs) and a three-position valve that can be actuated by the control module without necessitating communication with a surface location.

Abstract: A method including positioning a downhole acquisition tool in a wellbore in a geological formation; performing a pretest sequence to gather at least one of pressure or mobility information based on downhole acquisition from a sample line, a guard line, or both while the downhole acquisition tool is within the wellbore. The pretest sequence includes controlling a valve assembly to a first valve configuration that may allow the fluid to flow into the downhole tool via one or more flowlines toward a pretest system. The one or more flowlines include the sample line only, the guard line only, or both the sample line and the guard line; and drawing in the fluid through the one or more flowlines. The method also includes controlling the valve assembly to a second valve configuration. The second valve configuration is different from the first valve configuration and may block the one or more flowlines from drawing in the fluid.

Abstract: A wellbore formation system includes a downhole cutting tool having a body and at least one cutting element. A sensor is coupled to the downhole cutting tool, and the sensor includes a transmitter configured to transmit a signal prior to wear on a portion of the downhole cutting tool reaching a first amount. The sensor ceases transmission of the signal when the wear on the portion of the downhole cutting tool reaches the first amount.

Abstract: A method for completing a well includes receiving completion parameters associated with wells within a field. The completion parameters including casing parameters, perforation parameters, and fracking parameters. The method further includes determining a field-specific model utilizing the completion parameters and prescribing a completion recipe using a completion analysis engine applied to the field-specific model. The completion recipe includes prescribed perforation parameters and prescribed fracking parameters. The completion analysis engine includes a neural network derived from the field-specific model or regression of a correlation of features in the field-specific model. The method also includes completing the well in accordance with the completion recipe including performing perforation in accordance with the perforation parameters and fracking in accordance with the fracking parameters.

Abstract: A technique facilitates use of acoustic measurements to enable geo-steering during a well operation. A steerable well string is provided with acoustic systems used to collect data which is then processed to determine geo-steering inputs. In some applications, the well string may comprise a coiled tubing drilling tool. The coiled tubing drilling tool or other well string tool is combined with an azimuthally distributed pitch-catch micro-sonic sensor system and an azimuthally distributed ultrasonic pulse-echo transducer system. Data from these two systems is provided to a processing system which processes the data to determine, for example, real-time, geo-steering inputs. These inputs may then be used to more effectively steer the coiled tubing drilling tool or other well string tool.

Abstract: The disclosed embodiments include methods and networks to determine a boundary of a cement mixture. In one embodiment, the method includes detecting first acoustic signals transmitted from at least one of a first plurality of acoustic tags that are mixed with cement slurry, where the cement slurry is deposited in a first section of a wellbore in an annulus between a casing and the first section of the wellbore. The method also includes determining a location of a first boundary of the cement slurry based on the first acoustic signals.

Abstract: A bottom hole assembly includes a single wire bus, a legacy sensor coupled to the single wire bus, and at least one high frequency communication sensor coupled to the single wire bus. The high frequency communication sensor injects a high frequency signal alternating between high frequency synchronization pulses and high frequency data signals onto the single wire bus. A first high frequency pass filter coupled between the at least one high frequency communication sensor and the single wire bus is also included. The high frequency pass filter passes the high frequency signal to the single wire bus from the high frequency communication sensor. The bottom hole assembly includes a first high frequency blocking filter coupled between the legacy sensor and the single wire bus. The high frequency blocking filter blocks the high frequency signal from the high frequency communication sensor from disturbing a legacy signal at the legacy sensor.

Abstract: A system and method is provided for enhancing hydrocarbon production. The method and system involve geochemistry analysis and include multiply substituted isotopologue and position specific isotope geochemistry for at least one hydrocarbon compound of interest associated with free gas and sorbed gas. The method and system involve using clumped isotope and position specific isotope signatures to enhance monitoring of well and stimulation performance.

Abstract: The invention relates to a pipe (2) including: —a tubular element (3) defining an inner longitudinal passage (5); —a protective element (6) attached onto the outer surface of the tubular element (3) and extending longitudinally in relation to the tubular element (3), the protective element (6) and the tubular element (3) defining a longitudinal receiving passage (9); and —a detection element (12) that is detectable with a detection device. The detection element (12) is linear and includes an electrically conductive core (13) and an electrically insulating sheath (14) that covers the electrically conductive core (13). The detection element (12) extends longitudinally into the receiving passage (9) and is movably mounted longitudinally in relation to the tubular element (3) and the protective element (6).

Abstract: A cartridge with a permeable material configured to be positioned within a frac sleeve, wherein the permeable material is or includes a tracer.

Abstract: Embodiments are directed to automatically detecting an event in a production curve, generating a production estimate using a quantile regression and to performing a probabilistic decline curve analysis. In one scenario, a computer system identifies a candidate break point in a production decline curve which represents a decline in material production at a well. The computer system identifies one trend for the production decline curve occurring before the candidate break point and identifies a second trend for the production decline curve occurring after the candidate break point. The computer system calculates the difference between the first material production decline estimate and the second material production decline estimate and identifies the candidate break points where the difference between the first material production decline estimate and the second material production decline estimate is beyond a threshold value.

Abstract: Systems and methods for detection of downhole tubulars.

Abstract: A system includes an annular wellhead housing and an indicator assembly. The annular wellhead housing includes a shoulder and a first passage extending radially through the wellhead housing from an exterior surface of the wellhead housing to an interior surface of the wellhead housing. The indicator assembly is configured to extend through the passage, wherein the indicator assembly, when actuated, is configured to indicate whether a hanger disposed within the wellhead housing has landed on the shoulder.

Abstract: A method of measuring temperatures, includes disposing a carrier in a borehole in an earth formation, the carrier having an optical fiber connected thereto, interrogating the optical fiber with a pulsed optical signal generated by a distributed temperature sensing (DTS) assembly, the pulsed optical signal having a first frequency, and receiving first reflected signals from the optical fiber, estimating an absolute temperature from the reflected signals, interrogating the optical fiber with an at least partially coherent optical signal from a phase sensitive optical time domain reflectometry (?-OTDR) assembly, the at least partially coherent optical signal having a second frequency, and receiving second reflected signals from multiple scattering locations in the optical fiber; estimating a phase difference between the reflected signals, and estimating a temperature change based on the phase difference, and combining the absolute temperature and the temperature change to generate a temperature profile at a loca

Abstract: Included are well systems and methods for use in subterranean formations. An example well system comprises a water front sensor operable to sense a water front, wherein the water front sensor comprises a water front sensor signal transmitter and a water front sensor signal receiver. The example well system further comprises an electronic inflow control device, wherein the electronic inflow control device comprises a flow regulator in fluidic communication with an inlet of the electronic inflow control device and adjustable to provide a flow resistance to a fluid flowing through the electronic inflow control device, and a controller configured to actuate the flow regulator to change the flow resistance through the electronic inflow control device.

Abstract: A downhole system in which an agile light source is used to simulate an integrated optical element to measure one or more characteristics of a fluid in a wellbore.

Abstract: A method of controlling at least one of a flow rate or pressure of an injected fluid includes receiving a measured value indicative of the at least one of the flow rate or the pressure of the injected fluid, and determining a control mode for controlling the at least one of the flow rate or the pressure. The method further includes controlling the at least one of the flow rate or the pressure of the injected fluid according to the selected control mode including: determining a command signal to be communicated to a field device, and communicating the command signal to the field device.

Abstract: Provided in this disclosure, in part, are methods, compositions, and systems for degrading organic matter, such as kerogen, in a subterranean formation. Further, these methods, compositions, and systems allow for increased hydraulic fracturing efficiencies in subterranean formations, such as unconventional rock reservoirs. Also provided in this disclosure is a method of treating kerogen in a subterranean formation including placing in the subterranean formation a composition that includes a first oxidizer including a persulfate and a second oxidizer including a bromate.

Abstract: Techniques and apparatus are provided for improved diagnostics of downhole dynamometer data for control and troubleshooting of reciprocating rod lift systems. A method for pump fillage determination for a reciprocating rod lift system is provided. The method generally includes measuring downhole data during a pump cycle, wherein the downhole data comprises a first plurality of data points associated with an upstroke of the pump cycle and a second plurality of data points associated with a downstroke of the pump cycle, each data point comprising a rod position value and an associated rod load value; converting the data points to non-dimensional data points, calculating non-dimensional slope values between non-dimensional data points; and determining pump fillage based, at least part, on the calculated non-dimensional slope values.

Abstract: A modular top drive system for construction of a wellbore includes an alignment assembly configured to align a tool with a top drive unit to facilitate automatic tool installation during rig up.

Abstract: A system and method for detection of coking in a fuel. The system including a fuel system for delivery of fuel, a fuel contamination sensor having a contamination detection sensor with input and output transducers immersed in the fuel, a controller in operable communication with the fuel contamination sensor, the controller configured to execute a method for detection of coking in fuel. The method including generating an excitation signal for the contamination detection sensor, receiving at a controller operably connected to the contamination detection sensor, a sensor output signal from the output transducer, comparing the sensor output signal with the excitation signal, diagnosing a condition of the fuel based on a the comparing, and indicating a condition of coking based on the diagnosing. The system also includes an enunciator to indicate the detection of coking in the fuel.

Abstract: Systems and methods for reducing unwanted water and/or gas intrusion into a hydrocarbon production wellbore. The system includes a treatment injection tool for injecting a treatment agent into portions of the formation surrounding the wellbore and a tunneling tool for forming one or more tunnels within the formation. Sensors provide real-time information about wellbore parameters during treatment so that wellbore analysis can be conducted.

Abstract: Methods and apparatus of pressure activated completion tools for hydraulic fracturing and related processes are provided. In some embodiments, the hydraulic fracturing apparatuses for accessing a subterranean formations can include a tubular body to be fluidly connected in-line with a completion string, the tubular body having at least one burst port configured to receive burst inserts (burst plugs), and a movable inner sleeve that can slide along the inside of the tubular body when exposed to hydraulic pressure from a first position to a second position. The tubular body can also have flow-port(s) that are blocked when the movable inner sleeve is in the first position and opened when the movable inner sleeve slides to the second position.

Abstract: This invention is a method of developing a sedimentary basin containing hydrocarbons, by using basin simulation. Starting with gridded representations representative of a basin for each time step of a simulation, for each time step and in each cell of the gridded representation the following steps are performed. First a determination of at least one amount of biogenic gas produced in the cell for the time step is preformed followed by determining at least one amount of biogenic gas dissolved in water present in the cell at the time step, and determining therefrom an amount of free biogenic gas in the cell at the time step; then, accounting for advective transport of the quantity of biogenic gas dissolved in the water of the cell at the time step.

Abstract: Monitoring one or more items of equipment associated with a borehole or other conduit. A sensor system includes a vibration sensor for sensing vibrations at one or more sensor locations associated with one or more items of the equipment and/or the borehole or other conduit. A processing system processes the sensor information to determine a characteristic of the operation of the one or more items of equipment and/or the borehole or other conduit.

Abstract: A chemical probe composition comprising a base fluid and a chemical probe, wherein the chemical probe is capable of reacting with hydrogen sulfide to form a fluorophore and associated methods and systems.

Abstract: A method and apparatus that includes positioning a completion string that has an internal passageway and that has an external surface that at least partially defines an external region within a wellbore; isolating a zone of the external region from a wellbore hydrostatic pressure; measuring a pressure within the external region of the isolated zone; determining whether the pressure within the external region of the isolated zone is within a predetermined pressure range; and operating a valve that controls a flow of a fluid through a flow path from the internal region to the external region of the isolated zone when the pressure within the external region is outside of the predetermined pressure range.

Abstract: A multilateral production control method includes casing a first borehole with a casing tubular having at least one transmission crossover arrangement, each transmission crossover arrangement having an adapter in communication with a coil antenna that encircles the casing tubular. The method also includes completing a second borehole with an inflow control device. The method also includes deploying, inside the casing tubular, a conductive path that extends from a surface interface to the at least one transmission crossover arrangement. The method also includes communicating between the surface interface and the inflow control device using the at least one transmission crossover arrangement.

Abstract: An automated system for assessing pumpoff risk can be used to warn operators and/or control machinery in order to avoid pumpoff. Pumpoff risk is assessed through the use and/or comparison of one or more models of pumpoff risk. These models can include a sand build up model (e.g., to determine the threshold buildup size where pumpoff risk is too great), a line speed increase model (e.g., to determine the maximum flow rate allowable given a maximum support line feed rate), a residual error comparison model (e.g., to compare the deviation of predicted tension from actual tension), and a statistical analysis model (e.g., to determine likelihood of pumpoff given statistical probability of each of a multitude of possible scenarios).

Abstract: A technique facilitates communication of signals in a downhole environment. According to an embodiment, the system comprises an antenna which may be combined with a well component for communicating signals along a wellbore. The antenna comprises wire which is coated with a suitable material, such as amorphous polyetheretherketone (PEEK), and wet wound into a coil. A plurality of protective elements may be combined with the wire, e.g. sleeves may be placed over portions of the wire to protect the wire. Layers of tape also may be wrapped around coil to enhance durability of the antenna.

Abstract: A coiled tubing injector head unit includes a first bearing carrier and a second bearing carrier attached to a frame of the injector head unit that support an input drive shaft extending between the first and second bearing carriers, a sprocket shaft coupled to the input drive shaft that supports a pair of continuous parallel drive chains that revolve in a common plane and have opposed, elongated parallel runs spaced apart to form a path for engaging tubing passing there through, and a hydraulic motor attached to the frame opposite the first bearing carrier, and a gearbox attached to the frame opposite the second bearing carrier, wherein the input drive shaft is operatively connected to and extends between, but is not supported by, the hydraulic motor and the gearbox.

Abstract: Optical analysis devices may be configured for optically interacting a material of interest with a chemical filter and a detector that together are configured to detect a characteristic of the material of interest, wherein optically interacting the material of interest with the chemical filter comprises absorbing, by the chemical filter, at least a portion of an electromagnetic radiation having optically interacted with the material of interest. Relative to cementing operations, such optical analysis devices may be useful in identifying fluids, analyzing compositions of cement slurries, investigating the status of a reaction occurring in a cement slurry, detecting and/or monitoring corrosion of a set cement, and the like.

Abstract: An apparatus for sensing acoustic waves below a surface of the earth includes an optical fiber disposed below the surface of the earth and having a series of sensing units along the optical fiber with each sensing unit having three or more reflectors and an optical interrogator in optical communication with the optical fiber. The reflectors in each sensing unit are positioned to provide a linearized response that approximates a sawtooth wave better than a sinusoidal wave to sense the acoustic waves in a desired dynamic range. The optical interrogator is configured to transmit an input light signal into the optical fiber and receive a reflected light signal from the optical fiber due to the input light signal in order to measure a strain on each sensing unit due to interaction with the acoustic waves and to determine a location of the sensing unit corresponding to the sensed strain.