Abstract: Methods of and apparatus for a downhole communication in a well. The well has a metallic structure which includes an insulated metallic, fluid carrying, control line. The method comprises the steps of applying signals to the control line at a first location and extracting the signals from the control line at a second location. There is also provided a downhole communication system for use in a well having a metallic structure. The metallic structure includes an insulated metallic, fluid carrying, control line. The system comprises means for applying signals to the control line at a first location and means for extracting the signals from the control line at a second location. The control line acts as a signal channel. Other methods and apparatus making use of control line carrying no fluid and/or the metallic shielding of cable having insulated metallic shield are also described.

Abstract: A subsea lubricator system is disclosed which includes a lubricator tube adapted to be positioned subsea above a subsea well, a pressure control head adapted to be positioned above the lubricator tube, at least one pressure sensor adapted for sensing at least one of a pressure in the subsea well or an ambient seawater pressure proximate the pressure control head, and at least one pump that is adapted to be positioned subsea to inject a lubricant into the pressure control head at a pressure that is greater than the sensed pressure. A method of operating a subsea lubricator system positioned above a subsea well, the lubricator system including a pressure control head, is also disclosed which includes monitoring at least one of a pressure within the well and an ambient seawater pressure proximate the lubricator system, and injecting a lubricant into the pressure control head at a pressure that is greater than the monitored pressure.

Abstract: A method of treating a subterranean formation is provided utilizing a system for setting downhole control pressure to select and operate hydraulically activated sleeve valves which are disposed on a casing which is cemented into a well bore, and flowing a first treatment fluid which is capable of dissolving cement through the hydraulically activated sleeve valves.

Abstract: An apparatus for controlling fluid flow into a wellbore tubular includes a flow control member that selectively aligns a port with an opening in communication with a flow bore of the wellbore tubular. The flow control member may have an open position wherein the port is aligned with the opening and a closed position wherein the port is misaligned with the opening. The flow control member moves between the open position and closed position in response to a change in drag force applied by a flowing fluid. A biasing element urges the flow control member to the open or the closed position. The apparatus may include a housing receiving the flow control member. The flow control member and the housing may define a flow space that generates a Couette flow that causes the drag force. In embodiments, the flow space may include a hydrophilic and/or water swellable material.

Abstract: The present invention relates to a device for controlling the Blow out preventer (BOP) used in well drilling operations comprising: BOP control unit, master control panel connected to the BOP unit for acquisition of data and processing the said data, comprising an input module, an output module and analog I/P module; a plurality of slave panels connected to master panel through the connecting means comprising input module, output module for controlling the BOP control unit; wherein the said slave panel is a programmable logic controller(PLC) for controlling BOP control unit.

Abstract: A pumping unit is provided with a hydraulic drive unit. The drive includes a hydraulic motor attached to a driven sheave that, through reduction gears, drives a drive shaft and crank arm that causes the pumping unit to pump. The speed of the hydraulic motor is controlled by hydraulic pump in fluid communication with the hydraulic motor. A prime mover drives the hydraulic pump. The speed of the hydraulic pump (and the hydraulic motor by correlation) is controlled by a speed control on the prime mover and/or a flow control valve.

Abstract: A wellbore services manifold trailer comprising a blender connector configured to couple to a blender, a boost pump coupled to the blender connector, a high-pressure pump suction connector coupled to the boost pump and configured to couple to a high-pressure pump, a high-pressure pump discharge connector configured to couple to the high-pressure pump, and a wellhead connector configured to couple to a wellhead is disclosed. A wellbore servicing method comprises receiving a fluid at a first pressure, increasing the pressure of the fluid to a second pressure greater than the first pressure, feeding the fluid to a high-pressure pump at the second pressure, receiving the fluid from the high-pressure pump at a third pressure greater than the second pressure, and feeding the fluid to a wellhead at the third pressure is also disclosed.

Abstract: A device or system for controlling fluid flow in a well includes a flow control element and a water detector. The water detector may actuate the flow control element in response to a measurement of a property of the flowing fluid. The water detector may be a capacitive proximity sensor. The measured property may be a dielectric constant. The flow control element may permit a predetermined amount of fluid flow after being actuated to a closed position. Also, the water detector may measure a property of the fluid flowing after the flow control element is in the closed position. A method for controlling a flow of fluid into a wellbore tubular may include positioning a flow control element along the wellbore tubular; measuring a property of a flowing fluid using a water detector; and actuating the flow control element in response to the measurement.

Abstract: An apparatus for controlling a flow of fluid in a well includes a flow control device and a generator that generates electrical energy in response to a flow of an electrically conductive fluid. The flow control device may include an actuator receiving electrical energy from the generator, and a valve operably coupled to the actuator. The actuator may be configured to operate after a preset value for induced voltage is generated by the generator. The generator may use a pair of electrodes positioned along a flow path of the electrically conductive fluid to generate electrical energy. In one arrangement, one or more elements positioned proximate to the electrodes generate a magnetic field along the flow path of the electrically conductive fluid that causes the electrodes to generate a voltage. In another arrangement, the electrodes create an electrochemical potential in response to contact with the electrically conductive fluid.

Abstract: The invention relates to a method of performing an oilfield operation of an oilfield having at least one wellsite, each wellsite having a wellbore penetrating a subterranean formation for extracting fluid from an underground reservoir therein.

Abstract: A method of downhole characterization of formation fluids is provided. The method includes: estimating a rough value of the bubble point pressure of the formation fluids; depressurizing the formation fluids at a first speed to a certain pressure which is a predetermined value higher than the estimated rough value while the formation fluids are isolated in a portion of the flowline; and depressurizing the isolated fluids at a second speed which is slower than the first speed in order to measure a precise value of the bubble point pressure.

Abstract: A circulation pump for circulating downhole fluids is provided. The circulation pump includes a cylindrical pump housing, a shaft secured in the pump housing extending in a longitudinal direction thereof, an impeller rotating around the shaft in the pump housing, a cylindrical magnetic coupler rotating around the pump housing, the cylindrical magnetic coupler including a magnet, and a motor positioned outside of the pump housing and connected to the magnetic coupler to rotate the magnetic coupler around the pump housing. The impeller is provided with a magnetic piece, which is capable of being magnetically connected with the magnet of the cylindrical magnetic coupler to cause the impeller to rotate around the shaft by rotating the cylindrical magnetic coupler around the pump housing.

Abstract: Systems and methods for the production of hydrocarbons from a wellbore. One or more combination tools can be disposed along a casing string inserted into a wellbore. Each combination tool can contain a body having a bore formed therethrough; a sliding sleeve at least partially disposed in the body; one or more openings disposed about the body at a first end thereof, and a valve assembly and a valve seat assembly at least partially disposed within the bore at a second end thereof. While initially permitting free bidirectional flow of fluids within the casing string, the sliding sleeve within each combination tool can be manipulated to close the valve within the tool, thus permitting pressure testing of the casing string. The sliding sleeve can be further manipulated to open the one or more openings thereby permitting hydraulic fracturing and production of a hydrocarbon zone surrounding the combination tool.

Abstract: A downhole valve assembly including a valve mounted in a tubular body, the valve moveable between an open and closed position. Movement is achieved by a fluid operated valve actuation mechanism located downhole of the valve having a fluid inlet port located uphole of the valve. A method of controlling fluid flow downhole is also described allowing the valve to be moved between the open and closed positions and between closed and open positions.

Abstract: An apparatus for and a method of transmitting signals from the surface of a well to a location downhole in the well utilize a downhole fluid pressure sensor, a signal processing means located downhole in electrical connection with the pressure sensor and a downhole programmable logic unit capable of counting at least two signals received by the downhole pressure sensor. Typically, signals transmitted from the surface comprise a peak in pressure of downhole fluid located in production tubing run into a well bore and these signals are sensed by the downhole fluid pressure sensor. The logic unit outputs a signal to a tool to be actuated if it receives a number of signals within a particular time period, wherein the logic unit actuates the tool by the frequency of signals received rather than the amplitude of the signals received.

Abstract: A motor controller for an electrical submersible pump production system is coupled to a real-time software model using known correlations and algorithms to model the performance of the production system, including the production equipment and the well, and executes separately from any modeling used to compute operating parameters from downhole measurements for use by the motor controller. The real-time software model receives operating parameter measurements from a data acquisition subsystem and compares the measurements with projected operating parameter values according to the model. Differences between measured and projected values are analyzed to identify operating problems or non-optimal operating conditions, with automatic corrections and/or notifications being triggered.

Abstract: This invention relates to a method and apparatus for controlling a gas in a group of gases produced from a reservoir and specifically relates to controlling the amount of methane gas in a group of gases produced from a reservoir.

Abstract: The invention relates to a method for performing an oilfield operation. The method steps include obtaining oilfield data sets associated with oilfield entities, generating a stochastic database from the oilfield data sets based on an artificial neural network of the oilfield data sets, screening the oilfield data sets to identify candidates from the oilfield entities, wherein the screening is based on the stochastic database, performing a detail evaluation of each candidates, selecting an oilfield entity from the candidates based on the detail evaluation, and performing the oilfield operation for the selected oilfield entity.

Abstract: An apparatus operable is a hazardous area for controlling a choke assembly includes an air source, an air purge system in fluid communication with the air source, a remote operating panel receiving data from at least one remotely located wellbore sensor, a local operating panel in electronic communication with the remote operating panel, and an actuator coupled to the assembly to control pressure within the wellbore. The remote operating panel includes an airtight housing in fluid communication with the air purge system, wherein air from the air purge system is circulated through the housing, a plurality of operator controls for manually controlling operation of the pressure control assembly, and a display for visually displaying values of data received from the wellbore sensor.

Abstract: A control system and control method for controlling a modular apparatus for extracting petroleum and/or generating electricity based on subsurface data as well as market prices of electricity and/or petroleum. One or more probes measure subsurface total pressure, partial pressure of carbon dioxide, partial pressure of hydrogen, oil flow rate, gas flow rate, underground temperature, and/or viscosity of the oil. The control system/method controls the apparatus based on the subsurface parameters by controlling an injection module and/or a gas separator module to increase or decrease output of driver gas. The control system/method may also control the injection module and/or the gas separator module to increase (or decrease) output of driver gas when the market price of electricity decreases (or increases) and/or petroleum increases (or decreases).

Abstract: The present invention relates to a method and system for determining multiphase fluid streams flowing from individual wells of a cluster of crude oil, gas and/or other fluid production wells, wherein the fluid streams produced by the individual wells are commingled and routed via a fluid separation assembly into fluid outlet conduits for transportation of at least partly separated streams of crude oil, gas and/or other fluids.

Abstract: A technique facilitates the treatment of a subterranean formation. The technique involves the use of a fluid delivery system that comprises a continuous feedback system. The continuous feedback system utilizes a real time closed loop interpretation technique to instantaneously synchronize and adjust actions at a well site surface relative to measured downhole events. Sensors are used to monitor at least one downhole property in real time. Based on the real time data, the continuous feedback system enables adjustments to be made with respect to the at least one property in a manner designed to influence a downhole event.

Abstract: A microcontroller system for oil and gas wells using a plunger lift device, which responds to the variations in well production and operation. The system requires minimal operator input, and is able to calculate the operational cycles and adjustments to maximize well production and maintain environmental safety using non-linear artificial intelligence processes.

Abstract: A plunger lift apparatus includes wellhead equipment containing a receiver, a conduit extending from the wellhead equipment into a wellbore, and a plunger to be run through the conduit to a downhole location in the wellbore. The plunger includes at least a sensor to measure a downhole parameter, and a plunger is adapted to communicate the measured downhole parameter to the receiver.

Abstract: A gas lift system for use in marginal well and small diameter production tubing is disclosed. The system uses compressed natural (produced) gas to lift formation fluids thereby enhancing produced gas. Incorporated in the system is a plurality of differential pressure control valves which provide the required lift capability for a standard jet pump, located at the bottom of the wellbore, to continue to lift produced fluids. The methods of use are described.

Abstract: Autonomous control of a wellbore tool is provided by programming a memory module of a processor with a database having data relating to a selected parameter of interest; conveying a sensor and the processor along the wellbore; and activating the wellbore tool if the processor determines that a measurement provided by the sensor correlates with the database data. The processor may correlate the sensor measurements with a predetermined pattern associated with the data, a preset value, and/or a preset range of values. Well tool activation may occur when the processor finds: a substantial match between a predetermined pattern and at least one measured value; a present value and at least one measured value, and/or a preset range of values and at least one measured range of values. Also, activating the well tool may occur only if a measurement from a second sensor meets a preset criteria.

Abstract: A method and associated apparatus continuously optimizes reservoir, well and surface network systems by using monitoring data and downhole control devices to continuously change the position of a downhole intelligent control valve (ICV) (12) until a set of characteristics associated with the “actual” monitored data is approximately equal to, or is not significantly different than, a set of characteristics associated with “target” data that is provided by a reservoir simulator (32). A control pulse (18) having a predetermined signature is transmitted downhole thereby changing a position of the ICV. In response, a sensor (14) generates signals representing, “actual” monitoring data. A simulator (32) which models a reservoir layer provides “target” data.

Abstract: Data about operation of a well for extracting a product from the subterranean reservoir and at least one of a characteristic of a subterranean reservoir or operation of a processing and transport system upstream of a point of sale is received. A corrective action can be automatically initiated on at least one of the well or the processing and transport system in response to a difference between the received data and a specified operational objective. An adjustment to a model of the reservoir, the well, and the processing and transporting system can be automatically initiated in response to the received data.

Abstract: An embodiment of a method of controlling a plunger lift system for a well, the plunger lift system having a tubing positioned in a cased well, a plunger in the tubing moveable from the bottom of the tubing to a top of the tubing, a control valve in functional connection with the tubing, a plunger arrival sensor, a tubing pressure sensor, a casing pressure sensor, and a sales line pressure sensor, a controller in operational connection with the control valve and functional connection with the sensors for receiving signals from the sensors, the method including the steps of: defining a threshold value for a trigger event, the trigger event initiating operation of the control valve by the controller; defining event-value conditions upon which adjustment of the trigger event is adjusted; determining, upon a calling-event, if the event-value conditions have been satisfied; and adjusting the trigger event threshold value upon satisfaction of the event-value conditions.

Abstract: A method and apparatus relates to incorporating a magnetic coupling for use in oilfield applications. The magnetic coupling is operatively coupled to an oilfield machine to provide a controlled operational speed. The magnetic coupling may be operatively connected to a motor and a drive shaft where a speed of rotation of the drive shaft is controlled by an operation of the magnetic coupling. The drive shaft is operatively connected to the oilfield machine.

Abstract: A pump monitoring and control system includes a plurality of pumps associated with a well, each of the plurality of pumps including one or more sensors associated therewith, and one or more communication devices linking each of the sensors with a well system controller. The well system controller is configured to process information received from the one or more sensors and control any of the plurality of pumps based on information received from one or more of the plurality of pumps.

Abstract: Systems for assessing health and performance of actuators and sensors in process equipment system. In one example, the equipment system comprises subsystems (preferably physically coupled subsystems), at least some of which are characterizable by transmitted signals. Some of these signals are transformed into a comparable form and compared, so as to identify signals that are outside of operating bounds.

Abstract: Systems, methods, and heaters for treating a subsurface formation are described herein. At least one system for providing power to one or more subsurface heaters is described herein. The system may include an intermittent power source; a transformer coupled to the intermittent power source, and a tap controller coupled to the transformer. The transformer may be configured to transform power from the intermittent power source to power with appropriate operating parameters for the heaters. The tap controller may be configured to monitor and control the transformer so that a constant voltage is provided to the heaters from the transformer regardless of the load of the heaters and the power output provided by the intermittent power source.

Abstract: A method for servicing a well bore comprises connecting a mixing system to the well bore, controlling the mixing system to produce a material mixture with approximately a desired density, and controlling the mixing system to provide the material mixture to the well bore at approximately a desired volumetric flow rate to service the well bore, wherein the controlling to produce approximately a desired density is independent from the controlling to provide approximately a desired volumetric flow rate.

Abstract: The present invention includes a method and system for automated choke control on a hydrocarbon producing well. The method includes sensing parameters such as sand production, well head tubing pressure, flow rate through the well system, and pressure differential between downhole tubing and an adjacent producing formation. The opening size of the choke is automatically changed, without need for human intervention, in response to changes in the sensed parameters to optimize operation of the well system. Ideally, a programmable logic controller is used to determine when the opening size on the choke should be changed. An advisory communication is preferably sent to a remotely located monitoring station advising that the opening size of the choke has been automatically adjusted. A decision is then made whether an operator should go to the well site and manually well test and shake out the well before placing the system on automatic operation again.

Abstract: A method is disclosed for optimal lift resource allocation, which includes optimally allocating lift resource under a total lift resource constraint or a total production constraint, the allocating step including distributing lift resource among all lifted wells in a network so as to maximize a liquid/oil rate at a sink.

Abstract: Methods and apparatus are disclosed for conveying an electrically energized hydraulic pump into a wellbore surrounded by steel casing and thereafter using that hydraulic pump to pump oil, water and gas to the surface of the earth. The apparatus may be used as a well tractor conveyance system to service a perforated steel cased wellbore located in a geological formation that incorporates means to prevent any reverse fluid flow into the geological formation through any perforations in the steel cased wellbore during movement within the wellbore of the tractor conveyance means.

Abstract: Methods and systems for deliquification of fluid loaded, packed wells with sub-surface safety valves (“SSSVs”) utilizing timed and tailored chemical treatments. A flow meter measures the flow rate of the well and an intermitter initiates shut in of the well when a particular flow rate is reached. A chemical treatment is applied and allowed to penetrate the length of the well before production is restarted. Predetermined combinations of chemical treatments and production cycles are utilized based on past experience and well data, and the entire process can be automated through the use of a computer system.

Abstract: A method and system for controlling a producing cycle in a well, during the production cycle, for optimizing production from the well including disrupting fluid in a wellbore with a pulse generator to create a pressure pulse transmitted through the fluid in the wellbore, detecting the pressure pulse created and the pressure pulse reflected from objects located within the wellbore, wherein the objects may include a liquid/gas interface and a producing apparatus such as a plunger, converting the detection of the pressure pulse and the reflected pressure pulses to a signal, computing the signals to determine the well status and controlling production of the fluid from the wellbore based on the well status.

Abstract: A production control system having a series of nested tubular members including at least one axial flow channel and at least two annular flow channels. At least one valve configured and positioned to control flow from each flow channel is provided. A production apparatus having a series of nested tubulars connected to one another such that at least an axial flow channel and at least two annular flow channels are formed. A valve is associated with each flow channel and is configured to independently control flow from each flow channels. A method for controlling commingling of flows from multiple zones. The method includes containing flows from different zones to individual concentric flow channels in a nested tubular arrangement and selectively commingling one or more of the flows by setting at least one valve associated with each channel to a closed position or one of an infinite number of flow positions.

Abstract: The present invention is directed to a method for allocating revenue or taxes to individual fluid streams commingled during an oil and gas production process, the method includes commingling fluid streams to produce a commingled fluid stream; (2) utilizing a process simulation model to predict a phase change of each fluid stream in the commingled fluid stream, wherein the process simulation model predicts the phase change of all the individual fluid streams in the commingled fluid stream the phase change of each individual fluid stream in isolation of the commingled fluid stream, the phase change of all the individual fluid streams in the commingled fluid stream absent a single fluid stream; and (3) determining the difference in phases between the calculated phase change of all the in individual fluid streams in the commingled fluid stream and calculated phase change of all the individual fluid streams in the commingled fluid stream absent a single fluid stream.

Abstract: A method and apparatus for controlling the operation of a flowing or producing well utilising: a downhole located pressure monitoring device which is operative to monitor a characteristic pressure profile of the flowing well, and to respond when a significant deviation to the pressure profile is introduced into the well as a control signal to the monitoring device; 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.

Abstract: A system and method is provided for producing fluid from a subterranean formation. A sensor system is used to monitor bottom hole flowing pressure and formation pressure. The relationship of these pressures is utilized in conjunction with a stability envelope of the formation in optimizing fluid production.

Abstract: Systems and methods for automating the extraction of oil from an oil well, especially low production orphan wells. The system includes an endless loop pump extending into the oil well; a rotational drive motor operably connected to the loop pump; a transfer pump for conveying petroleum product away from the endless loop pump; a microprocessor controller for controlling the rotational drive motor and transfer pump; a number of sensors for sending operational measurements to the microprocessor indicative of the operational characteristics of the rotational drive motor; a collection reservoir for gathering the petroleum product from the endless loop pump; and a liquid level sensor for sending a level measurement to the microprocessor indicative of the level of the petroleum product in the collection reservoir. The system includes a variable sheave-pulley configuration and arrangement as well as complete local and remote system monitoring and reporting.

Abstract: Methods and apparatus are disclosed for conveying an electrically energized progressing cavity pump into a wellbore surrounded by steel casing and thereafter using that progressing cavity pump to pump oil, water and gas to the surface of the earth. The progressing cavity pump self-powers itself into the wellbore by pumping fluid from one side to another side of a lateral hydraulic seal and is thereafter used to provide artificial lift which is particularly useful in extreme-reach lateral wellbores. The apparatus may be suspended on coiled tubing, on any umbilical means, or on a wireline, and may also be used as a conveyance system to convey completion devices into a well. The progressing cavity pump is not subject to gas lock in highly deviated, partially gas-filled wells, and may be used to prevent any reverse fluid flow into formation during deployment in the well.

Abstract: An apparatus and method for operating an electrically powered device in a packer using the piping structure of the well as an electrical conductor for providing power and/or communications. The electrically powered device may comprise an electrically controllable valve, a communications and control module, a modem, a sensor, and/or a tracer injection module.

Abstract: Acoustic telemetry systems and methods with surface noise cancellation. One illustrative embodiment may include an acoustic telemetry system comprising a transmitter configured to generate an acoustic information signal that propagates along a drillstring, and a receiver configured to detect an acoustic receive signal from the drillstring and a noise signal from a surface environment. The receiver operates on the acoustic receive signal and the noise signal to produce a modified signal indicative of the acoustic information signal and having a reduced noise content relative to the acoustic receive signal.

Abstract: The present invention generally relates to an apparatus and method for improving production from a wellbore. In one aspect, a downhole pump for use in a wellbore is provided. The downhole pump includes two or more chambers for the accumulation of formation fluids and a valve assembly for filling and venting gas to and from the two or more chambers. The downhole pump further includes a fluid passageway for connecting the two or more chambers to a production tube. In another aspect, a downhole pump including a chamber for the accumulation of formation fluids is provided. In another aspect, a method for improving production in a wellbore is provided. In yet another aspect, a method for improving production in a steam assisted gravity drainage operation is provided. Additionally, a pump system for use in a wellbore is provided.

Abstract: Devices and methods for control flow of formation fluids respect to one or more selected parameter relating to the wellbore fluid. In one embodiment, a flow control device for controlling fluid flow into the production tubular uses a flow restriction member that is actuated by a character change of the formation fluid, such as liquid to gas or oil to water. The flow restriction member can be sensitive to a change in density of the formation fluid. The flow restriction member is passive, self-regulating and does not need any power source or control signal to control fluid flow. In one embodiment, the flow control device automatically rotates into a predetermined orientation upon being positioned in the wellbore. A seal disposed on the flow control devices expands into sealing engagement with an enclosure after the flow control device assumed the desired predetermined position.

Abstract: A method and system are provided for controlling the production of oil and gas in a well such that the well operates at the edge of gas coning. Thereto the flow rate and/or pressure of the produced well effluents are controlled by a dynamically controlled choke such that continously a limited amount of gas is entrained in the produced crude oil, whereas full gas coning and breakthrough of gas from the gas cap is prevented. The choke may be controlled by a control system which includes an algorithm that takes wellhead temperatures, pressures and choke position as measured variables and which maintains the average bulk velocity of the well effluents at a substantially constant and relatively high level. Optionally, the system also maintains an optimal gas-to-liquid ratio of the well effluents.