Abstract: An unloading plunger having an internal chamber to hold compressed gas and a timer-operated valve to release the compressed gas through a gas jetting port as a jetting force for ascent of the unloading plunger in a wellbore to unload liquid from a well. The ascending of the unloading plunger may be via a combined motive force of wellbore pressure provided by formation pressure plus the jetting force provided by ejecting the compressed gas from the unloading plunger.

Abstract: An unloading plunger having a chamber for compressed gas and a method for unloading liquid from a wellbore via ascending of the unloading plunger including ascending via formation pressure the unloading plunger from the bottom portion of the wellbore to a rest position at a wellhead and releasing compressed gas from the chamber into the wellbore during the ascending to decrease hydrostatic pressure of liquid in the wellbore above the unloading plunger.

Abstract: In some examples, a downhole torque measurement tool comprises a first surface of a structure and a second surface of the structure. The second surface is facing the first surface, and a shear stress sensor is positioned on the first surface. A flexible coupling is positioned between the shear stress sensor and the second surface, and the flexible coupling is coupled to the first and second surfaces.

Abstract: A multi-stage flow sub usable in wellbore operations provides for flow of fluid from a tool string to a wellbore annulus, and may provide for one or more of controlling wellbore pressure during a tool operation, or preventing stripping of wet string. The multi-stage flow sub may include a housing having an axial bore and at least one flow passage. A sleeve within the housing may have an axial bore, a shoulder acting as a ball seat, and first and second axially offset flow passages. A first burst disc may be in fluid communication with the first flow passage, and a second burst disc may be in fluid communication with the second flow passage, the second burst disc having a higher burst pressure than the first burst disc.

Abstract: A core barrel head assembly having at least one electronic instrument that is configured to obtain orientation data; a power source; and a communication means to receive and/or transmit orientation data for use in a core sample down hole surveying and sample orientation system that is configured to provide an indication of the orientation of a core sample relative to a body of material from which the core has been extracted, and also to a method of core sample orientation identification.

Abstract: A fluid container reloading tool for a downhole fluid sampling tool is described. The reloading tool includes an elongated cylindrical body. The body may include a bottom opening sized to engage with a fluid sampling tool deployed within a borehole. A cache of empty fluid containers may be included within the body. A piston may be coupled to at least one of the fluid containers in the cache of fluid containers. The piston may be used to transfer the cache of fluid containers into the fluid sampling tool. The reloading tool may also include a pump in fluid communication with the piston.

Abstract: A method for drill pipe tallying includes detecting that a drill bit (14) has tripped in through a rig floor and monitoring movement of a drawworks (6) that supports the drill bit and a length of drill pipe. If a tag interrogating device does not detect a wireless tag (26) associated with a set of slips, the method includes counting the movement of the drawworks toward a drill pipe tally. If a tag interrogating device detects a wireless tag associated with a set of slips, the method includes not counting the movement of the drawworks toward the drill pipe tally. The tag interrogating device is positioned at a fixed location relative to the rig floor.

Abstract: An apparatus includes a counter for tracking and communicating a number of plug drops through a longitudinal bore; a plug element adapted to be dropped into the longitudinal bore; and a valve defining a plug seat to be disposed within the longitudinal bore to catch the plug element when the plug element is dropped and when the number of plug drops as communicated by the counter exceeds a predetermined number. A method, includes: dropping a plurality of plugs down a longitudinal bore in which a plurality of plug seats are disposed; counting the number of plug drops from within the longitudinal bore; and catching one of the plugs at a preselected one of the plug seats when the number of plug drops exceeds a predetermined number.

Abstract: A system, method and apparatus for controlling a downhole operation is disclosed. A tool is operated to perform the downhole operation at a selected downhole location using a first value of an operation parameter of the tool. A magnetostrictive probe is used to determine a temperature profile along a section of a wellbore related to the operation being performed using the first value of the operation parameter. At least one temperature of the temperature profile is compared to a selected threshold. The operation parameter is altered to a second value based on the comparison of the temperature profile to the selected threshold.

Abstract: In one example of a rotationally independent wellbore ranging system, a housing attached to a rotary component is positioned in a first wellbore and remains substantially stationary relative to the first wellbore when the rotary component rotates in the first wellbore. Multiple sensors affixed to the housing are operable to receive multiple ranging signals from a second wellbore while the rotary component rotates in the first wellbore, and provide the multiple ranging signals to a processor to determine a position of the first wellbore relative to the second wellbore.

Abstract: Systems and methods for artificial lift via a downhole positive displacement pump are disclosed herein. The methods include methods of removing a wellbore liquid from a wellbore that extends within a subterranean formation and/or methods of locating the downhole positive displacement pump within the wellbore. The systems include hydrocarbon wells that include the wellbore, a casing, a rotary electric motor, the downhole positive displacement pump, and a liquid discharge conduit, and the systems may be utilized with and/or configured to perform the methods.

Abstract: According to aspects of the present disclosure, a magnetic ranging system is described herein. The magnetic ranging system may comprise a downhole apparatus tool (350) that is sized to couple to a drill string (375). The downhole apparatus (350) may be included, for example, near-bit within the bottom assembly (BHA). A transmitter (302) and a receiver (304) may be coupled to the downhole apparatus (350). The system may also comprise a power management system (308) coupled to the downhole apparatus (350). In certain embodiments, the power management system (308) may selectively provide power to the transmitter (302) from a first power source (316) or a second power source (318) based, at least in part, on an estimated distance to a target well.

Abstract: A system of couplings and method of use of the couplings to locate a downhole tool connected to coiled tubing, such as a bottom hole assembly, within a selected segment of a casing string. The selected segment of casing may be a ported collar or ported housing that permits the treatment and/or stimulation of the adjacent well formation. The system of couplings may be two, three, or four couplings spaced apart at predetermined lengths. The predetermined lengths may be shorter than typical lengths of casing segments. The distance between the first and second coupling may be substantially identical to the distance between the third and fourth coupling. The use of distances between the couplings that are shorter than the length of conventional casing segments may provide surface indicators as to the location of the bottom hole assembly with a higher confidence than relying on a traditional tally sheet.

Abstract: A counter assembly including an actuatable component. A counter component is disposed with the actuatable component and initially in a first position relative the actuatable component and movable with respect to the actuatable component. A lock member is engaged in a track formed between the actuatable component and the counter component. The lock member is operatively arranged for enabling relative movement between the actuatable component and the lock member in a first direction only and between the counter component and the lock member in a second direction only. At least one iteration of travel of the counter component to a second position relative the actuatable component and back to the first position progresses the lock member incrementally along the track. The actuatable component is immovably locked to the counter component by the lock member when the lock member has reached an end of the track.

Abstract: A time actuated element includes a mandrel, a housing coupled to the mandrel, the housing defining a fluid expansion chamber. A piston is positioned within the fluid expansion chamber. A thermally expanding fluid is positioned within the fluid expansion chamber. An end ring coupled to the piston slides along the mandrel in response to a sliding of the piston. A packer having a first end and a second end, the first end adapted to slide along the mandrel in response to a sliding of the end ring, and the second end fixedly coupled to the mandrel, so that a sliding of the first end of the packer toward the second end causes the packer element to decrease in length and increase in radius.

Abstract: A pressure gauge system and a method for in-situ determination of a wellbore formation pressure through a layer of cement, where the pressure gauge system comprises: a housing arranged to be permanently installed in the cement on the outside of a wellbore casing, wherein said housing comprises a pressure sensor with an output pressure signal, wherein: the pressure gauge system further comprises: a first temperature sensor with a first temperature signal, a second temperature sensor with a second temperature signal; and a computer implemented compensation means arranged to receive the pressure signal, the first and second temperature signals, and calculate a temperature compensated output pressure signal.

Abstract: An improved cementing tool is presented which allows for relatively easy removal and insertion of the tool through the use of non-threaded low-torque connections. The cementing tool uses a combination of threaded connections and non-threaded, low-torque connections configured to create a stack of components including plug launchers, ball launchers and plug launch indicator/counters. Use of non-threaded low-torque connections allows for breaking down the tool by hand, requiring no special torquing equipment.

Abstract: A tubular closure assembly responsive to speed or velocity of an object. The tubular closure assembly includes at least one sensor in operable communication with an interior of a tubular. The at least one sensor sensing an object passing a first point and then a second point within the tubular. A processor receiving an output from the at least one sensor and calculating speed of the object from the first point to the second point. A control panel receiving information from the processor and a closure system movable between an open condition and a closed condition. Activatable to the closed condition by the control panel in response to the object moving from the first point to the second point at speed faster than a preset value or at a velocity outside a preset range. Also included is a method of closing a tubular of a borehole.

Abstract: A method and apparatus for measuring formation properties comprising coiled tubing fitted with a bottom hole assembly, wherein said bottom hole assembly comprises means to measure formation fluid properties, means to transmit said formation fluid properties to a surface monitoring system, means to isolate a section of a wellbore, and means to control the flow of fluid entering said coiled tubing.

Abstract: Systems, computer readable medium, program code, and methods for monitoring and managing a plurality of marine riser assets are provided. An example of a system includes a computer and a computer readable medium containing a program code of instructions that when executed by the computer, cause the computer to perform operations for tracking the subsea deployment and retrieval of each of a plurality of riser joints. The operations can include receiving riser joint identification data from a riser joint identification indicator connected to the respective riser joint during the operational deployment thereof, and identifying the respective riser joint being operationally deployed to thereby track the deployment thereof. The operations can also include receiving riser joint identification data from the riser identification indicator of the respective riser joint during retrieval thereof, and identifying the respective one or more riser joints being retrieved to thereby track the retrieval thereof.

Abstract: Optical analysis systems may be useful in detecting microannulus formation in a wellbore casing and remediating a microannulus. In some instances, a system may include a cement sheath disposed about and in contact with at least a portion of an exterior surface of a casing; and at least one optical computing device arranged coupled to the casing, the at least one optical computing device having at least one integrated computational element configured to optically interact with a material of interest and thereby generate optically interacted light, and at least one detector arranged to receive the optically interacted light and generate an output signal corresponding to a characteristic of the material of interest, the material of interest comprising at least one selected from the group consisting of the cement sheath, a displacement composition disposed between the cement sheath and the exterior surface of the casing, and any combination thereof.

Abstract: This application is directed to a probe used for measuring groundwater characteristics such as temperature and conductivity, and for collecting a groundwater sample. The probe also has a shielding device that allows the probe to be driven into a hard underwater surface without damaging the probe. A deployment rig for accurately placing the probe into the underwater surface is also disclosed. The application is further directed to a method for placing a probe and measuring groundwater characteristics. An external screen membrane used with the probe allows accurate groundwater characteristic measurement by filtering particulate matter. The probe and external screen membrane allow for in situ measurement and monitoring.

Abstract: A plunger lift system of an oil or gas well and method of use is described. The plunger lift system includes a plunger, a sensor, a flow valve assembly, and a controller. The plunger is positioned within the tube string and travels up and down the string in response to the opening and/or closing of the flow valve assembly. The sensor is connected to the tube string and detects vibrations generated by impacts created by the plunger temporarily catching on gaps in the tube string. The sensor generates a sensor signal in response to the impacts of the plunger which are used by the controller to determine the velocity of the plunger within the tube string. If the velocity of the plunger exceeds a preselected maximum velocity, the controller selectively opens or closes the flow valve assembly to reduce the velocity of the plunger.

Abstract: A fiber optic sensing tool assembly is deployed in a wellbore that penetrates a hydrocarbon-bearing formation of interest to measure fluid composition and other fluid characteristics. This measurement is implemented by deploying the tool in a region in which there is substantially no fluid flow and by heating the tool through an optical delivery system. Parameters of the fluid are monitored as a function of the heating of the tool to derive information that is indicative of fluid composition and other fluid characteristics.

Abstract: Disclosed are systems and method for servicing a wellbore and otherwise triggering a downhole tool. One method includes arranging an assembly within a lubricator coupled to a tree, the assembly including at least one downhole tool and a signal receiver subassembly, communicating a signal to the signal receiver subassembly while the assembly is arranged within the lubricator, the signal being configured to activate a timer communicably coupled to the signal receiver subassembly, introducing the assembly into the wellbore and advancing the assembly until reaching a target depth, and transmitting a trigger signal with the signal receiver subassembly to the at least one downhole tool and thereby actuating the at least one downhole tool.

Abstract: A method for communicating a signal to an instrument in a wellbore includes axially accelerating the instrument in a preselected pattern of acceleration. The predetermined pattern corresponds to the signal to be communicated. The axial acceleration of the instrument is detected, and the signal is decoded from the detected axial acceleration. A signal detection system for an instrument in a wellbore includes an accelerometer oriented along a longitudinal axis of the instrument and means for comparing measurements made by the accelerometer to at least one predetermined pattern.

Abstract: Device comprising equipment for measuring parameters of a drilling or coring operation by means of a drillbit fixed to the end of a drill string, measurement equipment (7) being housed in a chamber (5) made in a coupling (1, 18) that is designed to be interposed between two drill string pipes or between the drillbit and a drill string pipe, or to constitute an adapter (18) for a cutting head (15) of the drillbit of a drill string.

Abstract: A plug counter including a housing sized to receive and pass plugs. A helix sleeve rotatably positioned relative to the housing. The helix sleeve including a helical track having a plurality of consecutive turns. A key positionable relative to the helical track and responsive to movement of the helix sleeve in a first rotational direction, wherein the key prevents further movement of the helix sleeve in the first rotational direction after a selected number of plugs pass through the plug counter.

Abstract: A tool assembly is provided that includes an actuatable tool such as a valve or a setting tool. And includes a location device that senses the location of the tool assembly within a tubular body based on a physical signature. The tool assembly also includes an on-board controller configured to send an activation signal to the actuatable tool when the location device has recognized a selected location of the tool based on the physical signature. The actuatable tool, the location device, and the on-board controller are together dimensioned and arranged to be deployed in the wellbore as an autonomous unit.

Abstract: Methods, systems, and program product for monitoring and managing a plurality of marine riser assets are provided. An example of a method includes tracking the subsea deployment and retrieval of each of a plurality of riser joints. This can include deploying the plurality of riser joints from a vessel to form an operationally deployed marine riser string, reading riser joint identification data from a riser joint identification indicator connected to the respective riser joint during the operational deployment thereof, and identifying the respective riser joint being operationally deployed to thereby track the deployment thereof. The method can also include retrieving one or more of the operationally deployed riser joints, reading riser joint identification data from the riser identification indicator of the respective riser joint during retrieval thereof, identifying the respective one or more riser joints being retrieved to thereby track the retrieval thereof.

Abstract: A method for determining depth in a wellbore uses inertial navigation in conjunction with a database having one or more measured parameters correlated with depth. The measured parameter may be the lengths of stands forming a drill string, prior survey data relating to a naturally occurring feature such as formation lithology, or data relating to a human made feature such as collars in a casing string. The downhole processor may use accelerometer measurements to calculate a measured depth of a BHA and access the database to retrieve a predicted depth that corresponds with one or more sensor measurements (e.g., motion indicating the addition of a stand to a drill string). Thereafter, if the downhole processor determines that the predicted depth is in agreement with the calculated depth, the processor stores the predicted depth and/or associates the predicted depth with directional surveys taken along the wellbore.

Abstract: An automatically controlled methanol injection system for oil and gas production streams including an electric methanol injection pump and a temperature sensor and switch, the sensor and switch adapted to automatically adjust the injection of methanol as a function of sensed temperature.

Abstract: An actuation dart for actuating a target tool in a tubing string, the actuation dart includes: a body conveyable through the tubing string to reach the target tool; a control module configured to respond to contact with at least one downhole tool in the tubing string to locate the target tool; and an actuation mechanism for actuating the target tool when it is located.

Abstract: A mechanical counting device for actuating a plurality of output devices, the device comprising: linear indexing means adapted to count a plurality of actuating signals and to cause actuation of the output devices when a predetermined number of actuating signals for each output device has been received, wherein the mechanical counting device is adapted to cause actuation of a particular device when a different predetermined number of actuating signals has been received such that the output devices are sequentially actuable.

Abstract: A control line space out tool for use in identifying the length of control line required to extend between proximal and distal locations in a wellbore is described, the control line space out tool comprises a body having a locator for locating the tool at a proximal location within a wellbore and a passage though which a control line may pass to extend to a distal location, a grip for locking onto a control line, and an actuator for operating the grip to lock onto the control line to thereby indicate the length of control line required to extend between said locations. A method of determining a length of control line required to extend between proximal and distal locations within a wellbore is also described.

Abstract: A method for estimating a depth from which cuttings have been recovered from a well may include varying a parameter of one or more marking agents added into a drilling fluid circulated into the well and recovering the cuttings from the well. The depth may be estimated by estimating a value associated with the marking agent that marks the cuttings. A system for estimating a depth from which cuttings have been recovered from a well includes at least one marking agent configured to mark the cuttings and a marking agent dispensing device configured to add the at least one marking agent into a drilling fluid circulated into the well. The marking agent dispensing device may be further configured to vary a parameter of the at least one marking agent.

Abstract: A casing annulus is remediated by inserting a hose into a casing annulus, the hose having a nozzle on its lower end. An acoustic signal is directed into the annulus. A sensor in the hose receives the acoustic signal and transmits data from the sensor to the surface. The data represents the acoustic signal arrival time to the sensor, and an analyzer estimates the sensor depth based on the data. The hose is inserted from a reel into a wellhead above the annulus. An electrical transducer mechanically coupled to the hose creates the acoustic signal. The signal is propagated along the hose and transferred to the fluid in the annulus, where it then propagates further into the annulus. The transducer can be installed on a hose roller along which the hose is fed into the wellhead.

Abstract: A system and method for cracking, hydrogenating and extracting oil from underground deposits is presented. A method includes injecting a mixture of oxygen, steam and oil into an injection well to upgrade oil in an oil deposit below ground to decrease the viscosity of the oil to product upgraded oil. The upgraded oil is extracted with a production well to bring upgraded oil aboveground. The method monitors at least one characteristic of the upgraded oil to determine when the at least on characteristic exceed a threshold. The mixture of oxygen, steam and oil is adjusted when the at least one characteristic exceeds the threshold value so that the mixture of oxygen, steam and oil does not exceed the threshold.

Abstract: Methods and devices are provided for accurately determining depths of certain structures in downhole strings. Locator tools comprise a shaft and a plurality of locator springs longitudinally mounted on the shaft. The locator springs are biased to expand and are configured to compress to allow the tool to traverse past restrictions in the downhole string. Each locator spring includes a locating pad that allows it to engage with an internal locating notch in the downhole string. The internal locating notch is sized to mate with the locator tool, i.e., to allow the locator springs to engage the internal locating notch. In this way, the depth of internal locating notches may be determined precisely and accurately by sensing engagement of the tool with the internal locating notch. Advantages of certain embodiments include more accurate depth determination, repeatable engagements of the tool, and reduced false engagements.

Abstract: A measurement system is provided that includes an integrated optics unit which measures at least one variable of the movement of a conveyance system relative to an oil well during an oil well operation, wherein the at least one variable is a direction of motion, a speed of movement, or a length of movement of the conveyance system.

Abstract: A method for determining depth in a wellbore uses inertial navigation in conjunction with a database having one or more measured parameters correlated with depth. The measured parameter may be the lengths of stands forming a drill string, prior survey data relating to a naturally occurring feature such as formation lithology, or data relating to a human made feature such as collars in a casing string. The downhole processor may use accelerometer measurements to calculate a measured depth of a BHA and access the database to retrieve a predicted depth that corresponds with one or more sensor measurements (e.g., motion indicating the addition of a stand to a drill string). Thereafter, if the downhole processor determines that the predicted depth is in agreement with the calculated depth, the processor stores the predicted depth and/or associates the predicted depth with directional surveys taken along the wellbore.

Abstract: An indicator comprising a band having a first radial dimension; one or more protectors having a greater radial dimension and disposed sufficiently proximate the band to substantially avoid wear of the band during running of the indicator and method.

Abstract: A method for breaking a fracturing fluid includes identifying application parameter(s) including a subterranean formation temperature, and determining an acid precursor concentration in response to the application parameter(s). The method further includes providing a treatment fluid including a carrier fluid, a metallic peroxide breaker, and an amount of an acid precursor according to the acid precursor concentration, and treating the subterranean formation with the treatment fluid. The application parameter(s) may further include a flowback wait time, a composition of the metallic peroxide breaker, a gel loading of the carrier fluid, and/or a permeability of the subterranean formation. The metallic peroxide breaker may include an alkaline peroxide and/or a zinc peroxide. The acid precursor may include polylactic acid and/or polyglycolic acid.

Abstract: A method and apparatus for the decomposition of hydrogen peroxide, particularly for use as a hydrocarbon well bore and pipeline cleaning and maintenance aid. The apparatus includes a decomposition engine having an inlet manifold extending centrally within the housing and having means for passage of hydrogen peroxide through the manifold wall through a catalyst stack. The decomposition products produced are directed through an exit venturi. The decomposition products are passed through a piping system which allow the selective venting or introduction of the products into a facility to be cleared. Control means are coupled to the engine and valving to allow for the selective adjustment of temperature and or pressure of the decomposition products, as well as the introduction and diversion of the blend into the facility.

Abstract: Generally, the subject matter disclosed herein is directed to devices and methods for energizing and detecting a wave-energizable apparatus on an item movable with respect to a working surface of a drilling rig. One illustrative device disclosed herein includes at least one mat adapted to be positioned on a working surface of a drilling rig and a plurality of spaced-apart energizing apparatuses operatively coupled to the at least one mat. Additionally, each of the plurality of spaced apart energizing apparatuses of the disclosed device is adapted to energize a wave-energizable apparatus attached to an item that is movable adjacent to the mat and relative to the working surface.

Abstract: An apparatus, capable of being conveyed on wireline, for continuous downhole injection of foaming agent(s) and/or beneficial chemical(s), comprising a reservoir and means for dispensing foaming agent(s) and/or beneficial chemical(s) from the reservoir of such apparatus and into the surrounding wellbore environment.

Abstract: A process and system for release and recovery of methane from subterranean methane hydrate deposits in which heated CO2 is used to displace methane from the methane hydrate deposits and a portion of the displaced methane is routed to a combustion device proximate the deposit for combustion in-situ, generating heated CO2 which is introduced into the deposit, displacing additional methane, a portion of which is routed to the combustion device, thereby providing a substantially self-sustaining process. Portions of the displace methane not routed to the combustion device are captured for use elsewhere.

Abstract: A method includes identifying application parameter(s) including a subterranean formation temperature, determining a breaker particle size in response to the application parameter(s), providing a treatment fluid including a carrier fluid and a granular breaker sized according to the breaker particle size, and treating the subterranean formation with the treatment fluid. The granular breaker is a metallic peroxide which may be an alkaline peroxide and/or zinc peroxide. The application parameter(s) may further include a flowback wait time, a composition of the metallic peroxide, a gel loading of the carrier fluid, and a permeability of the subterranean formation. The breaker particle size may include a breaker large particle size that is not greater than 25% larger than a breaker small particle size. At least 90% of the breaker particles may be sized between the breaker small particle size and the breaker large particle size.

Abstract: A method comprising: estimating a change in a characteristic of a subterranean formation into which a fluid has been injected via a well extending into the subterranean formation; building a multi-dimensional model balancing mass of the injected fluid, wherein the model is based on the estimated characteristic change; utilizing the model to determine the sensitivity of a borehole gravity tool in the well; measuring gravity with the borehole gravity tool at a plurality of stations along the well; and utilizing the model and the gravity measurements to locate the injected fluid in the subterranean formation.

Abstract: The present disclosure is directed to a system and method for stimulating subterranean zones. In some implementations, a method for stimulating a subterranean zone includes pumping stimulation fluid through a tubing string in a wellbore during a stimulation process. The tubing string includes a plurality of sleeves with each associated with a different treatment zone of the subterranean zone. A time for each of a plurality of different sealers entering the tubing string is detected. Each of the plurality of different sealers is associated with a different one of the plurality of sleeves. A location of the plurality of different sealers in the tubing string is substantially determined based, at least in part, on the associated entry time.