Abstract: A downhole pump assembly for pumping production fluid to a surface of a well. The downhole pump assembly includes a fluid pump that is operable to pump the production fluid to the surface. An optical computing device having at least one integrated computational element and at least one detector. The at least one integrated computational element is configured to optically interact with the production fluid proximate the fluid pump and is configured to generate optically interacted light. The at least one detector is arranged to receive the optically interacted light and to generate an output signal corresponding to a characteristic of the production fluid.

Abstract: A subterranean tool that is self contained for actuation can be run into a desired location on an automatic set mode controlled by a timer. If a problem develops in getting the tool to the desired location in time a magnetic field created by permanent or electro-magnets can be brought to bear on the tool to stop the timer before the tool actuates. Once the tool is subsequently positioned at the desired location another magnetic field can be brought to bear near the tool to set it. Alternatively, the tool can be run to the desired location without activation with the timer and then the magnetic field can be brought to the tool to set it. The magnetic field can be lowered to the tool with wireline or can be dropped or pumped past the tool to actuate the tool. Optionally the field can be generated from within an object that ultimately lands on a seat to provide a backup way to set the tool using tubing pressure.

Abstract: A plunger lift control system for improving the output efficiency of an oil or gas well by a real-time reporting arrangement, the system comprising: a tubing string having an upper end and a lower end, the tubing string arranged within a well casing for receiving a plunger traveling therethrough, a plunger having a sound generating function therewith, so as to transmit a real-time lower-end location signal from the plunger to a signal sensor and processor arranged in communication with a system controller arranged at the upper end of the tubing.

Abstract: A method of geothermal energy production can include injecting water into a formation, and then automatically decreasing resistance to flow through at least one valve in response to the water changing phase in the formation. A geothermal well system can include a tubular string disposed in a production wellbore, the tubular string including at least one valve, water which flows from an injection wellbore into a formation surrounding the wellbore, and then flows from the formation into the production wellbore as steam, and resistance to flow through the valve decreasing automatically in response to presence of the steam in the production wellbore. Another method of geothermal energy production can include injecting water into a formation from an injection wellbore, the water changing phase in the formation, and then automatically decreasing resistance to fluid flow through at least one valve in response to presence of steam in a production wellbore.

Abstract: A downhole steam generation apparatus and method of use are provided. The apparatus may include an injection section, a combustion section, and an evaporation section. The injection section may include a housing, injector elements, and injector plate. The combustion section may include a liner having channels disposed therethrough. The evaporation section may include conduits in fluid communication with the channels and the combustion chamber, and a nozzle operable to inject a fluid from the channels to the combustion chamber in droplet form. A method of use may include supplying fuel, oxidant, and fluid to the apparatus; combusting fuel and oxidant in a chamber while flowing the fluid through a plurality of channels disposed through a liner, thereby heating the fluid and cooling the liner; and injecting droplets of the heated fluid into the chamber and evaporating the droplets by combustion of the fuel and the oxidant to produce steam.

Abstract: A wellbore machining device is proposed for machining a tubular component of a wellbore. The device includes a control unit at the surface level of the wellbore and a down-hole tool unit connected to the control unit through a wire line. The tool unit includes an elongated guide member, a tool member movably supported on the guide member with respect to at least three axes of motion and a plurality of actuators controlled by the control unit and adapted to move the tool member with respect to the axes of motion. The tool unit further includes two anchor members each mounted to an axial end of the guide member and adapted to releasably clamp the tool unit to the tubular component. The control unit and the tool unit form a computer numerical control device (CNC device) wherein the actuators are electric servo motors controlling an actual position of the tool member with respect to a path and/or a sequence of desired position defined by the control unit.

Abstract: The present disclosure describes a system, method and computer readable medium capable of dynamically managing a hydrocarbon recovery operation. The hydrocarbon recovery operation may utilize an injection well and a production well. Proportional integral derivative controller(s) may be utilized to control injection processes (for the injection well) and/or production processes (for the production well) using temperature and/or pressure data obtained from the formation. One or more production tubulars may be equipped with inflow control devices capable of controlling the flow of hydrocarbons from the formation into the production well. In one embodiment, the PID controller(s) may adjust the positioning of the injection tubing strings and/or production tubulars within their respective wells. A graphic user interface may be provided to allow users to adjust and/or customize recovery operation parameters.

Abstract: A method and system for monitoring and controlling an injection operation is disclosed. A plurality of distributed fiber optic sensors is located in a production well. Fluid is injected into an injection well spaced apart from the production well. A parameter of a formation between the production well and the injection well is determined from measurements from the formation obtained using the fiber optic sensors. At least one of an injection of fluid into the injection well and a flow into the production well is controlled in response to the determined parameter.

Abstract: A system for controlling functions of a subsea structure, such as a blowout preventer, has a plurality of actuators respectively affixed to a plurality of controls of the subsea structure, and an acoustic signal generator positioned remotely from the plurality of actuators. Each of the plurality of actuators has a transponder connected thereto. The acoustic signal generator produces an acoustic signal so as to actuate at least one of the plurality of actuators. Each of the actuators is an electrically-powered torque wrench having a battery affixed there to so as to supply power thereto. An induction generator can transmit an electromagnetic wave along the tubing associated with the blowout preventer so as to recharge the batteries of the torque wrenches.

Abstract: A landfill well control system includes a mobile hand-held device provided with a software monitoring application including a table having data related to determination of a desired methane gas output flow rate. A landfill gas (LFG) wellhead gas control valve includes: an electronically controlled, powered flow control device actuator; a flow measurement element producing differential pressures proportional to a gas flow rate; a pressure sensor/transducer; and a microprocessor having control logic capability and the ability to communicate via a local wireless signal to the mobile hand-held device. The powered flow control device actuator using data from the table of the mobile hand-held device or remotely stored data provides automatic valve positioning.

Abstract: A fluid level control mechanism comprising a reservoir assembly, a flow line assembly, and a resilient force assembly. The flow line assembly has a main flow line capable of passing a fluid, a diverter flow line, and a diverter valve. The diverter valve is connected to a lower end plate of the reservoir assembly via a lever arm, such that the reservoir assembly is capable of sliding along the length of the main flow line in response to a fluid level. Downward movement of the reservoir assembly opens the diverter valve and upward movement of the reservoir assembly closes the diverter valve. The resilient force assembly is attached to the main flow line and the reservoir assembly and is capable of exerting a vertical force against the reservoir assembly to close the diverter valve.

Abstract: A system and a method for the artificial pneumatic production of oil and gas which is self-supplied is provided. The well's originating gas separates in a skid of separation of oil and after gas is rectified, gas is injected again into the well; the gas injection is made to a pressure enough to lift the oil-gas mixture inside the well. The excess of gas is exhausted toward the closer processing station.

Abstract: Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density. A fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. The diverter can control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve. The fluid diverter can move in response to density change in the fluid to affect fluid flow patterns in a tubular, the change in flow pattern operating a valve assembly.

Abstract: Some embodiments include a heavy-oil-based hydrocarbons effluent production installation for the production of hydrocarbons from at least one well. The installation includes an effluent-lightening fluid injection system at the bottom of the well, an effluent-evacuation pump, a plurality of sensors that measure physical units relating to the installation, and an automated device suitable for optimizing the lightening-fluid injection flow-rate and for regulating the pump speed. The automated device regulates the pump speed according to the physical units and a predetermined target production value. The speed of the pump and the physical units are within a predetermined range of values. some embodiments include a hydrocarbons production method in such an installation. Some embodiments make it possible to ensure a minimum consumption of lightening fluid, while ensuring good operation of the pump and good productivity of the well.

Abstract: Systems and methods are provided for supervising the control of wells in a grouping of wells, or “well pads,” in a subterranean hydrocarbon reservoir so as to coordinate operation of the well pad. By coordinating operation of the well pad, hydrocarbon production for the well pad can be optimized. An exemplary method includes the steps of generating a plurality of requests to control individual wells of the well grouping, queuing the requests, and authorizing the requests based on one or more criteria associated with the well grouping so as to coordinate operation of the well grouping.

Abstract: A method and apparatus for operating a plunger lift system in a well is provided. The methods can include: opening a control valve and allowing a plunger to rise to a top of the well; determining an actual rise time of the plunger based on a time it takes the plunger to rise to the top of the well; using actual rise time of the plunger and a target rise time calculating adjustments to the afterflow time or close time; and allowing the afterflow time to pass before closing the control valve and keeping the valve closed for the close time. The methods are repeated, each time calculating a new adjusted afterflow time or adjusted close time to incrementally alter these times to improve the operation of the plunger lift system.

Abstract: Vibration of an electric submersible pump assembly is monitored to produce a vibration spectrum. The vibration spectrum is compared to a known vibration signature for a pump condition that precedes gas lock. The pump condition is at least one of an impeller rotating stall condition, a diffuser stall condition, a pre-surge condition, and percentage of free gas within the wellbore fluid. Operation of the pump is then adjusted in response to the similarity of the vibration spectrum to the vibration signature for the pump condition to prevent impending gas lock.

Abstract: A method of performing an oilfield operation about a wellbore penetrating a subterranean formation are provided. The method involves performing a fracture operation by generating fractures about the wellbore. The fractures define a hydraulic fracture network (HFN) about the wellbore. The method also involves generating a discrete fracture network (DFN) about the wellbore by extrapolating fracture data from the HFN. The DFN includes fracture branches with intersections therebetween and matrix blocks. The method also involves generating a depth of drainage through the DFN, defining production parameter(s), and performing a production operation to produce fluids from the subterranean formation based on the depth of drainage and the production parameter(s). The production operation may involve generating a flow rate through the DFN, generating a pressure profile of the DFN for an initial time based on the flow rate, and generating a production rate based on the pressure profile.

Abstract: A method can include providing a motor that includes a housing, axially aligned stationary electromagnets disposed in the housing, an aperture defined by the axially aligned stationary electromagnets, movable axially aligned permanent magnets disposed in the aperture and a connector shaft connected at an end of the movable axially aligned permanent magnets; disposing the motor and a rod pump in a well; controlling operation of the motor to linearly reciprocate the axially aligned movable permanent magnets and the connector shaft; pumping fluid from the well via the rod pump responsive to the linear reciprocation of the axially aligned movable permanent magnets and the connector shaft; and substantially blocking the pumped fluid from flowing through the aperture defined by the axially aligned stationary electromagnets of the motor. Various other apparatuses, systems, methods, etc., are also disclosed.

Abstract: A system, method and apparatus for operating a laser at a downhole location is disclosed. A gas is configured to receive an output of a laser and to absorb a selected wavelength of the laser corresponding to a selected spectral line of the gas. A pressure device reduces broadening of the selected spectral line related to a temperature at the downhole location. A photodetector receives light from the gas chamber and provides a measurement related to the received light. A processor alters an operating parameter of the laser using the obtained measurement to operate the laser.

Abstract: An apparatus and method of measuring a parameter characteristic of a rock formation in an oil well is provided with a device for generating a sensing field within a volume of the rock formation and a device for causing a flow through the volume in the presence of the sensing field, further including sensors responsive to changes in the volume, wherein a sensor response is indicative of the amounts of fluid, particularly hydrocarbon and water saturations and irreducible hydrocarbon and water saturations. Measurements can be made before the flow affects the measuring volume and after onset of the flow through the measuring volume.

Abstract: A completion assembly for operation in a subterranean well having multiple production zones. The completion assembly includes a lower completion assembly operably positionable in the well. The lower completion assembly includes first and second zonal isolation subassemblies. An upper completion assembly is operably positionable at least partially within the lower completion assembly to establish fluid communication between first and second fluid flow control modules, respectively, with the first and second zonal isolation subassemblies. A first communication medium having a connection between the upper and lower completion assemblies extends through the first and second zonal isolation subassemblies. A second communication medium is operably associated with the first and second fluid flow control modules. Data obtained by monitoring fluid from the production zones is carried by the first and second communication media and is used to control production through the first and second fluid flow control modules.

Abstract: A prog analysis and execution system and method. The system includes a computer control system, an interface engine in communication with the computer control system, the interface engine being configured to receive prog information, and an action item development engine in communication with the control system, the action item development engine being configured to analyze received prog information and to determine corresponding action items. The system further includes a sensor engine in communication with the computer control system, the sensor engine being configured to receive input from at least one sensor for use in controlling a well drilling operation, and an operational equipment engine in communication with the computer control system, the operational equipment engine being configured to receive input from the computer control system and to control the well drilling operation in accordance with the determined action items in the prog.

Abstract: Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density. A fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. The diverter can control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve. The fluid diverter can move in response to a change in the fluid to affect fluid flow patterns in a tubular, the change in flow pattern operating a valve assembly.

Abstract: A method and system for managing one or more hydrocarbon producing well sites is provided. The well site includes a hydrocarbon material flow passing through a pipe. The system includes a clamp-on flow meter and a control station. The clamp-on flow meter is operable to produce output indicative of at least one characteristic of the hydrocarbon material flowing through the pipe at the well site. The control station is separately located from the well site. The control station includes at least one processor adapted to receive the output from the clamp-on flow meter. The processor is adapted to determine one or more characteristics of the hydrocarbon material flow at each well site using a flow compositional model.

Abstract: A system and method for controlling an advancing water front in a reservoir toward a wellbore is provided. The system has a production control unit. The production control unit has a reservoir unit for producing a reservoir model and a production path unit for producing a production path model that determines at least one pressure parameter about the wellbore during a life of the wellbore. The production control unit has a production optimizer unit for producing a well plan that optimizes a function of the wellsite. The production control unit may be for controlling an advancing fluid front in the reservoir with at least one control device, and wherein a production path is constructed based on the well plan.

Abstract: A system for attaining and maintaining a pre-determined fluid level in a petroleum-producing well having a pump, such as a progressive-cavity pump, and a pump motor having a variable-frequency drive control using two sensors: a pump pressure sensor located at the pump depth and a casing pressure sensor located at the casinghead of the well. A programmable computer is connected to the first and second pressure sensors and the motor speed control so that the programmable computer controls the operation of the pump motor to attain and maintain a target fluid level in the well over a predetermined time interval for reaching the target fluid level in the well. The programmable computer computes an error signal to control a variable frequency drive motor, where the error signal is computed periodically from the difference between in the actual fluid level in the well and the target fluid level in the well according to a rate reference curve.

Abstract: A wellbore servicing tool comprising a housing comprising ports, a triggering system, a first sliding sleeve transitional from a first position to a second position, and a second sliding sleeve transitional from a first position to a second position, wherein, when in the first position, the first sliding sleeve retains the second sliding sleeve in the first position, wherein, when in the first position, the second sliding sleeve prevents a route of fluid communication via the one or more ports of the housing and, when is in the second position, the second sliding sleeve allows fluid communication via the ports, and wherein the triggering system is configured to allow the first sliding sleeve to transition from the first position to the second position responsive to recognition of a predetermined signal comprising a predetermined pressure signal, a predetermined temperature signal, a predetermined flow-rate signal, or combinations thereof.

Abstract: A system for use with a well having multiple zones can include multiple well screens which filter fluid flowing between a completion string and respective ones of the zones, at least one optical waveguide which senses at least one property of the fluid as it flows between the completion string and at least one of the zones, multiple flow control devices which variably restrict flow of the fluid through respective ones of the well screens, and multiple pressure sensors which sense pressure of the fluid which flows through respective ones of the well screens. A completion string for use in a subterranean well can include at least one well screen, at least one flow control device which selectively prevents and permits substantially unrestricted flow through the well screen, and at least one other flow control device which is remotely operable, and which variably restricts flow through the well screen.

Abstract: A system for use with a well having multiple zones can include multiple well screens which filter fluid flowing between a completion string and respective ones of the zones, at least one optical waveguide which senses at least one property of the fluid as it flows between the completion string and at least one of the zones, multiple flow control devices which variably restrict flow of the fluid through respective ones of the well screens, and multiple pressure sensors which sense pressure of the fluid which flows through respective ones of the well screens. A completion string for use in a subterranean well can include at least one well screen, at least one flow control device which selectively prevents and permits substantially unrestricted flow through the well screen, and at least one other flow control device which is remotely operable, and which variably restricts flow through the well screen.

Abstract: A method and system to aid and/or train well control personnel by measuring the actual hydraulic delay and pressure attenuation of operator choke changes during well control operations or simulations. This provides the choke operator with an anticipated drillpipe pressure as soon as the choke is adjusted, accounting for hydraulic delay, pressure attenuation and prior choke adjustments that are currently travelling through the wellbore as well as reflections of the transient pressure waves against the pumps and choke. The technique that is described utilizes only three inputs, and works without knowledge of or inputting data such as well depth, pipe and hole geometry, mud properties, temperature, water depth, land, offshore platform or floating (subsea BOP's) drilling rigs.

Abstract: An acoustic signal is recorded at least once, the signal being a response of a wellbore-reservoir system onto acoustic impulses of pressure. A source of the pressure impulses is an electric submersible pump located inside the wellbore. The acoustic signal is recorded at least once by at least one sensor placed in a bottomhole chamber of the wellbore, the sensor measuring at least one physical parameter of the wellbore-reservoir system, which characterizes a process of propagation of the acoustic signal in the wellbore. A mathematical model of propagation of acoustic signals in the bottomhole chamber is created and data obtained by means of modeling are compared with data obtained by means of registering of the acoustic signals.

Abstract: A fluid regulator characterization system can characterize the flow of a fluid regulator that results in response to a received control signal. The fluid regulator characterization system can use the characterization to achieve a linear fluid regulator flow gain over a full operating range (e.g., zero percent travel to one hundred percent travel) for the fluid regulator relative to the received control signal. A linear fluid regulator flow gain can improve process control and reduce process variability.

Abstract: An apparatus for pumping a downhole fluid includes: a carrier configured to be conveyed through a borehole penetrating the earth; a pump disposed at the carrier and configured to pump the downhole fluid; a multi-phase electric motor coupled to the pump and configured to receive multi-phase electrical energy from a power source in order to operate the pump, the multi-phase electrical motor having multiple windings; and a switch configured to connect the multiple windings in a configuration selected from a plurality of configurations that includes (i) a first configuration where one terminal of each winding of the multiple windings is uniquely connected to one terminal of another winding and (ii) a second configuration where one terminal of each winding of the multiple windings is commonly connected to one terminal of each of the other windings.

Abstract: Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density or viscosity. A fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. The diverter is operable to control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve.

Abstract: Systems and methods in which output power that would conventionally be provided by surface equipment to drive downhole equipment, is transformed to increase the voltage before transmitting the power over a power cable to downhole equipment. The downhole equipment includes a step-down transformer that receives power from the power cable at a voltage which is too high to drive the motor or other downhole equipment and reduces the voltage to a level that is suitable for use by the downhole equipment. The step-down transformer may utilize toroidal transformers that are positioned around other components of the system, such as the shaft that couples a motor to an electric submersible pump. The step-down transformer may be configured as a modular unit that can be inserted between components (e.g. motor and seal) that are manufactured using conventional designs.

Abstract: Systems and methods for monitoring a wellbore and actuating a downhole device include a body adapted for insertion into the wellbore that contains a processor, data storage, and sensors that detect a pressure, temperature, and acceleration associated with the body. Computer instructions are usable to receive and store preselected parameters, which include pressure, temperature, and acceleration ranges, and to compare measured values to these ranges for forming a determination usable to initiate actuation of a downhole tool. Additional parameters, such as temporal parameters, can be used to allow, cease, reset, or prevent actuation of the downhole tool.

Abstract: Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density or viscosity. A fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. The diverter is operable to control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve.

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: An apparatus includes an impervious body, a sealing element, an energy source, and a trigger. The impervious body is configured to prevent passage of fluid therethrough. The sealing element is disposed about the impervious body. The energy source is operationally connected to the sealing element. The trigger is configured to transfer energy from the energy source to the sealing element. The trigger is activated, at least in part, by receiving a signal transmitted through the impervious body.

Abstract: A completion system and method adapted for use in wells having long lateral boreholes includes a mast assembly, a pipe handling mechanism, a pipe arm, a pipe tub, a pump/pit combination skid, a rig carrier, and a control system. The control system can be used to automate operations of the completion system to facilitate rapid and safe make-up and breaking of tubular connections.

Abstract: A method for reducing the extent of treatment required for groundwater comprises the steps of (A) determining one of groundwater (1) flow, and (2) chemistry within at least one of a plurality of fluid zones within a subsurface well having a primary pump positioned at least partially therein; (B) modifying fluid dynamics within the subsurface well based on at least one of the groundwater flow and chemistry; (C) selectively extracting groundwater from at least one of the plurality of fluid zones with the primary pump; and (D) removing one or more contaminants from the groundwater with a fluid treatment system. Additionally, the step of determining can include the use of miniaturized technologies, such as miniaturized flow profiling technologies, miniaturized water sampling technologies and miniaturized sensors.

Abstract: Fluid distribution determination and optimization using real time temperature measurements. A method of determining fluid or flow rate distribution along a wellbore includes the steps of: monitoring a temperature distribution along the wellbore in real time; and determining in real time the fluid or flow rate distribution along the wellbore using the temperature distribution. A method of optimizing fluid or flow rate distribution includes the steps of: predicting in real time the fluid or flow rate distribution along the wellbore; comparing the predicted fluid or flow rate distribution to a desired fluid or flow rate distribution; and modifying aspects of a wellbore operation in real time as needed to minimize any deviations between the predicted and desired fluid or flow rate distributions.

Abstract: A method for performing an oilfield operation of an oilfield having a subterranean formation. The method includes collecting oilfield data and deploying a first plug-in including a first oilfield technology functionality into an oilfield hosting application. The method further includes performing an oilfield analysis on the collected oilfield data in the oilfield hosting application using the first oilfield technology functionality of the first plug-in to generate an oilfield output and adjusting an oilfield operation based on the oilfield output.

Abstract: This invention provides for an apparatus that controls a liquid level down-hole of a hydrocarbon producing well by physically monitoring the liquid level down-hole having a down-hole liquid level measurer and a signal device connected to the liquid level measurer that causes a pump to adjust its current liquid output based on the liquid level down-hole as measured by the down-hole liquid level measurer.

Abstract: A method and apparatus for controlling the operation of a well which is not flowing or in which fluid is pumped or injected into the well utilising a downhole located pressure monitoring device which is operative to monitor a characteristic pressure profile of the well, and to respond and generate a triggering output when a significant deviation to the pressure profile is introduced into the well as a control signal to the monitoring device by comparing two separate pressure profiles within a certain time span, the device only generating a triggering output when the same pressure profile is monitored twice within the time span; and an actuator which is initiated into operation to control any required operation of the well when the monitoring device responds to the control signal and generates the triggering output.

Abstract: One or more methods, systems and computer readable mediums are utilized to provide treatment of a subterranean formation that contains solid organic matter, such as oil shale, tar sands, and/or coal formation. The treatment of the formation includes heating a treatment interval within the subterranean formation with one or more electrical in situ heaters. Available power, or other production resources, for the electrical heaters are determined at regular, predetermined intervals. Heating rates of the one or more electrical heaters are selectively controlled based on the determined available power at each regular, predetermined interval and based on an optimization model that outputs optimal heating rates for each of the electrical heaters at the determined available power.

Abstract: A valve (30) for a production liner (12) in connection with the extraction of oil and gas, arranged to automatically shut of the flow of fluid into the production liner (12) in the event of a gas break-through, whereby the valve (30) comprises a valve seating (32) containing at least one central inflow channel (34) and one or more outflow channels (36, 38) from the valve (30). The valve (30) is constructed with a curved design equal to the shape of the outer diameter of the production liner (12), and is placed on the outside of the production liner (12), and in that a rectangular shut off disk (40) with the same curving is arranged in the valve (30), in the flowing path of the liquid flow, to cause a high velocity flow over the shut off disk's surface (40a) against the valve seat (32), wherein the shut off disk (40) is adapted to seal against said valve seat (32) dependant on the differential pressure being produced by the viscosity of the passing flow.

Abstract: A method, apparatus, and program product facilitate the automation of an oil & gas process, e.g., a drilling process, through the use of a dynamic phase machine incorporating multiple autonomous agents. The agents may be registered after deployment of the dynamic phase machine to dynamically extend the dynamic phase machine and modify an oil & gas process implemented thereby.

Abstract: A method and apparatus for controlling the operation of a well involves locating a pressure monitoring device downhole and arranging it to be operative: to monitor a characteristic pressure profile of a well during a certain time span controlled by a downhole clock associated with the device; to monitor the temperature downhole in the region of the clock; to calibrate a time reading of the downhole clock with reference to the monitored temperature to correct for drift between the clock time and real time resulting from the downhole elevated temperature; and to respond and generate a triggering output when a significant deviation to the pressure profile is introduced into the well as a control signal to the monitoring device, by comparing two separate pressure profiles within the time span, the device only generating the triggering output when the same pressure profile is monitored twice within the time span.