Abstract: The present invention relates to device for increasing the production flow in a production tubing, comprising at least one inlet for adding a fluid medium and means to provide the added fluid at an angle ? between 90 and zero degrees with a longitudinal axis of the tubing. This effect is further enhanced by means for rotating the added fluid medium. A method for increasing the production flow in a production tubing is also disclosed.

Abstract: Embodiments of the present invention provide systems and methods for downhole sampling or sensing of clean samples of component fluids of a multi-fluid mixture. More specifically, but not by way of limitation, embodiments of the present invention provide for, amongst other things, separating downhole multi-fluid mixtures into an oil-based fluid, a water-based fluid and/or the like and sampling and/or sensing of the clean separated fluids. Such sampling or sensing may be provided by a downhole tool in accordance with some embodiments of the present invention and the downhole tool may be used for production logging, formation testing and/or the like.

Abstract: A control system for a plurality of devices including a plurality of devices in at least one group. A first control line is in operable communication with the plurality of devices. A second control line in operable communication with the at least one group. A step-advance mechanism is in operable communication with each of the plurality of the devices, each mechanism being distinct from each other mechanism within the group of devices. Further disclosed herein is a method for reducing the number of control lines needed to control a plurality of downhole devices including supplying a first control line in operable communication with a plurality of devices including at least one group of devices and supplying a second control line in operable communication with the at least one group.

Abstract: High productivity core drilling systems are described. The system includes a drill string, an inner core barrel assembly, an outer core barrel assembly, and a retrieval tool that connects the inner core barrel assembly to a wireline cable and hoist. The drill string comprises multiple variable geometry drill rods. The inner core barrel assembly comprises a non-dragging latching mechanism, such as a fluid-driven latching mechanism that contains a detent mechanism that retains the latches in either an engaged or a retracted position. The inner core barrel assembly also comprised high efficiency fluid porting. Accordingly, the drilling system significantly increases productivity and efficiency in core drilling operations by reducing the time required for the inner core barrel assembly to travel through the drill string. Other embodiments are also described.

Abstract: In some embodiments a method of shifting a downhole-located device between positions with an actuator includes inserting the actuator into the well, engaging the actuator with the shiftable device and actuating the actuator to shift the shiftable device between positions.

Abstract: A technique is employed to shift a well tool located in a wellbore. A shifting tool is moved downhole into proximity with a well tool that is to be shifted. The shifting tool comprises one or more engagement members that enable engagement with any of a variety of well tools having a variety of sizes. A sensor system provides an indication as to when the shifting tool is moved into proximity with a specific well tool.

Abstract: A system that is usable with a well may include a piston, a primary control subsystem and an override subsystem. The piston actuates the downhole tool, and the primary control subsystem may be connected to at least one hydraulic line in order to move the piston in response to pressure that is communicated to the tool via the hydraulic line(s). The override subsystem may be connected to the hydraulic line(s) to override the primary control subsystem and move the piston in response to pressure communicated to the tool via the hydraulic line(s).

Abstract: An activating device is mounted in a drill string to control the activation and deactivation of an enlargement tool used for enlarging a bore hole. In order to assemble the activating device, pistons are mounted in passages and spline bars, in which plates are screwed, are then slid along T-slots of the body, through apertures of the pistons. In order to deploy the pistons and cutters, pressurized drilling fluid is applied to the inner faces of the pistons. When a pre-determined pressure level is reached, screws break and the pistons move from the inward position to the outwardly deployed position.

Abstract: A method for performing a wellbore-related activity may include positioning a sealing device along the wellbore; conveying a work string into the wellbore; using the work string to perform the activity; extracting the work string out of the wellbore; and shifting the sealing device to a closed position to seal a bore of the wellbore using a portion of the work string. A device that selectively seals or occludes a wellbore tubular may include a sealing device having a first and a second sealing element that seal a bore of the wellbore tubular. The first and second sealing elements may support a pressure applied in different directions. Pulling an engagement sleeve with the work string in an uphole direction may fold the first and second sealing elements into the closed position. The bore may be unsealed by applying a pressure cycle to shift the sealing device.

Abstract: A pump jack system for reciprocating a pump rod string is made up of a base frame and piston drive cylinders mounted on the base frame with the upper end of the pump rod connected to the cylinder assemblies, the cylinder assemblies being operated in unison by a fluid control circuit communicating with inner and outer concentric fluid passages, and the pump rod string is counterbalanced by a fluid circuit which supplies pressure in an upward direction to each of the pistons on each upstroke and substantially reduces the pressure on each downstroke, the fluid circuit being selected from an inert gas alone or an inert gas pressurizing a hydraulic fluid. The fluid control circuit includes a directional control valve and timer, along with a fluid dampener, which is automatically responsive to dampen pressure surges and acceleration shocks at the beginning of each upstroke and downstroke.

Abstract: A tool that is usable in a well and may include an operator, a switch, a resilient device and an indexer. The switch may be configured to selectively communicate a first force to the operator, thereby actuating the tool. The resilient device may exert a second force. The indexer may cycle through a sequence of positions in response to alternating between the second force and a third force. The sequence includes a predetermined position configured to actuate the switch, thereby communicating the first force to the operator to actuate the tool.

Abstract: A zone isolation assembly for a fluid monitoring system in an existing subsurface well includes a fluid receiving pipe, a docking receiver, a docking apparatus and a first sealer. The fluid receiving pipe includes a pipe interior and a fluid inlet structure. The fluid receiving pipe receives a fluid through the fluid inlet structure into the pipe interior. The docking receiver is connected to the fluid receiving pipe. The docking apparatus moves between (i) a docked position wherein the docking apparatus is docked with the docking receiver, and (ii) an undocked position wherein the docking apparatus is undocked with the docking receiver. The first sealer is spaced apart from the docking apparatus. In certain embodiments, the first sealer selectively forms a fluid-tight seal between the fluid receiving pipe and the casing to divide the fluid zone into a first zone and a spaced apart second zone.

Abstract: A wellhead hydraulic drive unit to operate various styles of downhole pumps, including a hydraulic cylinder having a piston positioned therein for reciprocation within the cylinder; hydraulic fluid supply conduits contained within the hydraulic cylinder and fluidly communicative with the piston such that hydraulic fluid flowing through the hydraulic fluid supply conduits produces reciprocation of the piston within the hydraulic cylinder, a ram within the cylinder and operably connected to the piston, the ram having a bore; and production tubing inserted through the bore of the ram for enabling well fluid to be discharged from the well, wherein the hydraulic fluid supply conduits are radially offset from a longitudinal axis of the cylinder and the ram is oppositely radially offset from the longitudinal axis of the cylinder.

Abstract: A fluid loss valve is disposed in a wash pipe in a gravel packing assembly. It is preferably held open initially and when in the process it is time for the valve to be able to go closed a pulling force is applied that creates relative movement to either close the valve or allow it to close without release of the assembly when under tension. This allows a surface signal that the valve is to be released for closure. The tension is relieved before string movement with the valve can occur. This can happen by slacking off before picking up again or through other time delay features that allow the tension to be removed and a lock to collapse before a lift force is applied for subsequent gravel packing operations. The valve in its closed position acts to eliminate fluid loss when excess gravel is reversed out.

Abstract: A technique provides a system and method to verify attachment of a fishing tool with a downhole well tool. The fishing tool comprises a latching mechanism that latches onto the well tool to be retrieved. The fishing tool also comprises a detection device to verify connection of the latching mechanism. The detection device provides a signal uphole to verify attachment to the well tool.

Abstract: Methods and apparatus for driving a positive displacement pump disposed within a wellbore are disclosed herein. Embodiments of the present invention provide a drive mechanism for driving the downhole positive displacement pump. In embodiments of the present invention, the positive displacement pump is hydraulically driven and mechanically counterbalanced. The drive mechanism may be mechanically or electrically controlled, or may be controlled by a combination of mechanical and electrical controls.

Abstract: A chemical injection system includes a TRSV; a communication nipple in operable communication with the TRSV and positioned relative to the TRSV to be downhole of a flapper closure mechanism thereof when installed in a wellbore; a chemical injection line in fluid communication with the communication nipple; and a capillary sleeve receivable at the communication nipple and configured to sealingly convey fluid from the communication nipple to a remote location without affecting operation of the TRSV and method.

Abstract: A method and associated system for setting downhole control pressure. A method of setting a downhole control pressure includes the steps of: installing a pressure control system with a pressure source; connecting a proximal end of a line to the pressure source and a distal end to a well tool; and calibrating the system by applying an overshoot pressure to the proximal end, then sensing a settled pressure in the proximal end resulting from the overshoot pressure, and determining a mathematical relationship between the overshoot and settled pressures. A system for setting a downhole control pressure includes a pressure source, a pressure limiter and an interface for applying pressure to a proximal end of a control line and a well tool connected to a distal end of the control line.

Abstract: A remotely operable wellbore valve system includes a valve configured to be coupled to a wellbore conduit and to selectively close the conduit. The valve is disposed in a valve body configured to open an existing wellbore valve by longitudinal motion therethrough and to sealingly engage an interior of the existing wellbore valve. The system includes a valve actuator and a signal receiver in communication with the valve actuator. The signal receiver is configured to detect command signals transmitted from the Earth's surface and to cause the actuator to operate the valve in response to the detected command signals.

Abstract: A single line control module for well tool actuation. A well tool control system includes an actuator, a control module for controlling pressure applied to the actuator, and a single line extending between the control module and a remote location, elevated pressure being applied to the line and exhausted from the line at the remote location to operate the actuator. Another well tool control system includes an actuator having first and second chambers, a line for applying elevated pressure to the actuator to operate the actuator, and a control module including an accumulator, and a valve. The valve has a first position in which the line is connected to the first chamber and the accumulator is connected to the second chamber, and a second position in which the line is connected to the second chamber and the accumulator is connected to the first chamber.

Abstract: A kickover tool for placing and extracting a valve in a mandrel having a hydraulic piston, a kickover arm portion mechanically connected to the hydraulic piston, the kickover arm portion being actuated by application of pressure to the piston. Upon full stoke of the piston, pressure is relieved, and measurement of the pressure relief can be used to indicate proper placement in a side pocket mandrel.

Abstract: A kickover tool for placing and extracting a valve in a mandrel having a tool body extending in a longitudinal direction and having a hydraulic piston chamber therein; a hydraulic piston located inside the hydraulic piston chamber; a kickover arm portion mechanically connected to the hydraulic piston, the kickover arm portion comprising a kickover arm having a tool portion; the kickover arm has a non-kicked-over position where the kickover arm is substantially coaxial with the longitudinal direction and a kicked-over position where the kickover arm is substantially non-coaxial with the longitudinal direction; wherein the kickover arm moves to the kicked-over position upon extension of the hydraulic piston.

Abstract: A system for cleaning compressors (1) that are situated at a difficultly accessible location, e.g., on or near the seabed or downhole in a well bore, comprises a cleaning liquid line (8) extending between a readily accessible liquid source and the compressor. The liquid source may be a line (7) for supplying hydrate inhibitor, anti foam chemicals, barrier liquid, demulsifier or other types of chemicals to a subsea production or processing activity. Alteratively, the liquid source can be an accumulator tank (13) situated in the vicinity of the compressor.

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 pump jack system for reciprocating a pump rod string is made up of a base frame and piston drive cylinders mounted on the base frame with the upper end of the pump rod connected to the cylinder assemblies, the cylinder assemblies being operated in unison by a fluid control circuit communicating with inner and outer concentric fluid passages, and the pump rod string is counterbalanced by a fluid circuit which supplies pressure in an upward direction to each of the pistons on each upstroke and substantially reduces the pressure on each downstroke, the fluid circuit being selected from an inert gas alone or an inert gas pressurizing a hydraulic fluid.

Abstract: A system for communicating information in a borehole between tool assemblies in a tool string includes receiving an information signal and separating a first signal that may be a power and low speed signal. A second signal is separated and demodulated from the information signal. The first signal and second signal are transmit to electronic devices that process data from an earth formation. After the first and second signals are transmit to one or more electronic devices, the signals are modulated and/or filtered and then combined into the information signal. The first signal is at one frequency and the second signal is at a different frequency. The apparatus includes a main signal line that couples to a second signal line and third signal line in the tool assembly.

Abstract: A single or multi-bowl wellhead may be positioned in a diverter housing over the wellbore. Protrusions on the wellhead may be installed after the diverter housing is removed. The wellhead accommodates the direct connection of hydraulic lines to a hanger seated therein. An overshot running tool protects the wellhead during placement and certain operations.

Abstract: A method of constructing a well comprising a borehole drilled through underground formations, comprises: positioning at least one device on the outside of the tubular string (e.g. a drill string or casing string), the device being operable to move between first and second configurations; positioning a tubular string in the borehole with the device positioned in the annular space between the tubular string and the borehole wall in its first configuration so as to interact with the tubular string and the borehole while allowing borehole fluid to flow along the annular space and around the device; and operating the device so as to move it from its first configuration to expand into its second configuration in which it substantially fills at least part of the annular space so as to inhibit flow of fluids along the borehole in the space.

Abstract: Well jet device comprises a packer on a pipe string, with a central channel and a jet pump, comprising channels for supplying a working medium to a nozzle and supplying a medium pumped from the well. A diffuser output connects to the annular space and the nozzle connects to the pipe string internal cavity on the side of the input thereof through the channels. The body has a movable steady bush, spring-loaded working medium flow switch. Steady bush bypass holes and mounting seat for mounting a sealing unit provided with a hole for passing a logging cable or for arranging a depression insert provided with autonomous instruments and a return valve are provided. The sleeve, in the top position, closes the channels and, in lower position, the top end face is positioned under the input into the channel. The bypass holes are connected to the input into the channel.

Abstract: A hybrid process control system including electrical transmission of power to a sub-sea hydraulic power unit, which in turn provides hydraulic power for control of hydraulic actuators. A circulation system using small bore tubing in the umbilical cord in combination with a traditional topside hydraulic power unit provides for active control of hydraulic fluid quality with respect to contamination caused by the sub-sea hydraulic actuators, especially process gas from down hole safety valves. Thus, a more economical power transmission is achieved without reduction of fluid quality, which is essential to system integrity and reliability. Also, a significant enhancement of power transmission without a dramatic increase in the size of hydraulic supply and return lines is achieved. Fluid environmental issues are reduced to a negligible aspect.

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: An example of a method for cementing a casing within an earthen formation includes the steps of providing a gripping mechanism connected to a cementing assembly and a top drive; gripping the casing with the gripping mechanism; sealingly engaging the casing with a seal member; moving the casing to a position within the formation; and cementing the casing within the formation while maintaining a gripping and sealing engagement of the casing. The step of cementing may also include the step of remotely releasing a plug into the casing from the cementing assembly.

Abstract: A communication tool apparatus is described which is adapted to provide selective communication of control fluid through a downhole tool, such as a safety valve. The downhole safety valve is a tubing retrievable subsurface safety valve (“TRSSSV”). The communication tool may be run downhole and within the TRSSSV. Once within the TRSSSV, the communication tool apparatus activates a cutting device within the TRSSSV such that communication of control fluid through the TRSSSV is possible. A replacement safety valve run on a wireline may then be inserted into the TRSSSV and be operated via the control fluid line, as a new communication path created by the communication tool described herein. A method of using the communication tool apparatus is also described.

Abstract: In one aspect, an apparatus for use in a wellbore is provided that may include: a tool configured to be conveyed into the wellbore by a conveying member; and an electro-active polymer device (“EAP device”) configured to connect the tool to the conveying member when the EAP device is in a first mode or position and disconnect the tool from the conveying member when the EAP device is in a second mode or position. In another aspect, a method for releasing a tool in a wellbore is provided which includes: releasably connecting an EAP device to a conveying member and the tool; conveying the tool in the wellbore with the conveying member; and electrically activating the EAP device to release the tool from the conveying member in the wellbore.

Abstract: The method for rapid installation of smaller diameter pressure control device usable on blow out preventors, by installing a threaded profile flange with a bell nipple upon a BOP, installing a test plug in the base of the BOP or base of a stack of BOPs, installing a test plug into the threaded profile of flange, performing a pressure test on the flange and all sealing aspects of the BOP, depressurizing the flange and removing the test plug, installing a thread protector between the flange and the bore of the BOP, initiating drilling operations, and upon indication of the need for wireline or other small bore type operations, adapting the existing BOP to smaller working diameter pressure control device, removing the thread protector and installing a high pressure assembly to facilitate the small bore well operations.

Abstract: A system and method are provided for direct connecting downhole control hydraulics through an oil field hanger, where the hanger is coupled to a wellhead, to hydraulic lines extending outside the wellhead. Further, the direct connection allows hydraulic system integrity with reduced contamination and leakage. Hydraulic tool ports, formed on the hanger, are coupled with hydraulic lines extending downward to a hydraulic tool. Side ports, formed in the hanger, are fluidicly coupled to the hydraulic tool ports. Hydraulic lines extending outside the wellhead are directly coupled with the side ports by accessing the side ports through access openings in the wellhead when the ports are aligned with the access openings. The system can still maintain pressure within internal spaces of the wellhead after the connection by sealing the access openings with flanges, where the hydraulic lines extend through openings in the flanges that are also sealed around the lines.

Abstract: A system is provided for expanding a tubular element extending into a wellbore formed in an earth formation. The system includes an expander arranged to expand the tubular element by virtue of axial movement of the expander through the tubular element, an activating system for inducing the expander to move through the tubular element, the activating system including at least one activating tool, and a control system for controlling the activating system, including a remote control unit and for each activating tool a respective controller. The remote control unit is arranged to transmit an acoustic signal to an acoustic conductor selected from the tubular element and another elongate member extending into the borehole, each controller being arranged to receive the acoustic signal from the acoustic conductor and to control the corresponding activating tool upon receipt of the acoustic signal.

Abstract: A formation evaluation system and method. A formation evaluation system includes an assembly interconnected as part of a tubular string and displaceable to multiple positions proximate each of multiple zones intersected by a wellbore. The assembly includes at least one formation evaluation instrument for determining a characteristic of formation fluid, and a pump which draws the fluid into the assembly. A method of evaluating multiple subterranean zones during a single trip into a wellbore includes the steps of: interconnecting a formation evaluation assembly in a coiled tubing string; for each of the multiple zones, displacing the formation evaluation assembly to a position proximate the respective zone, receiving formation fluid from the respective zone into the formation evaluation assembly, and determining at least one characteristic of the formation fluid; and performing the multiple displacing, receiving and determining steps during the single trip of the coiled tubing string into the wellbore.

Abstract: An electromagnetic ram for use in artificially lifting fluid from a well and in particular an oil well. The disclosure also teaches a method and system employing the ram. The use obviates existing systems used today in terms of cost, environmental concerns, optimized mechanical efficiencies and maximizing overall production of wells on a case by case basis.

Abstract: An integrated well access assembly. The assembly may be a coiled tubing unit with integrated pumping capability. However, other types of assemblies for oilfield operations may be employed. Regardless, the assembly may include a single prime mover to operate multiple pumps from a single trailer platform. This may be achieved by replacement of a conventional crankshaft driven pump or other significantly massive pump with a smaller hydraulic pump of sufficient pumping capacity. This replacement allows for a reduction in the amount of capital equipment required at the oilfield for a given operation. Thus, in turn, manpower and other maintenance expenses may similarly be reduced for the operation.

Abstract: Embodiments of the present invention provide systems and methods for downhole sampling or sensing of clean samples of component fluids of a multi-fluid mixture. More specifically, but not by way of limitation, embodiments of the present invention provide for, amongst other things, separating downhole multi-fluid mixtures into an oil-based fluid, a water-based fluid and/or the like and sampling and/or sensing of the clean separated fluids. Such sampling or sensing may be provided by a downhole tool in accordance with some embodiments of the present invention and the downhole tool may be used for production logging, formation testing and/or the like.

Abstract: A pump jack system for reciprocating a pump rod string is made up of a base frame and piston drive cylinders mounted on the base frame with the upper end of the pump rod connected to the cylinder assemblies, the cylinder assemblies being operated in unison by a fluid control circuit communicating with inner and outer concentric fluid passages, and the pump rod string is counterbalanced by a fluid circuit which supplies pressure in an upward direction to each of the pistons on each upstroke and substantially reduces the pressure on each downstroke, the fluid circuit being selected from an inert gas alone or an inert gas pressurizing a hydraulic fluid.

Abstract: A pump jack system for reciprocating a pump rod string is made up of a base frame and piston drive cylinders mounted on the base frame with the upper end of the pump rod connected to the cylinder assemblies, the cylinder assemblies being operated in unison by a fluid control circuit communicating with inner and outer concentric fluid passages, and the pump rod string is counterbalanced by a fluid circuit which supplies pressure in an upward direction to each of the pistons on each upstroke and substantially reduces the pressure on each downstroke, the fluid circuit being selected from an inert gas alone or an inert gas pressurizing a hydraulic fluid. The fluid control circuit includes a directional control valve and timer, along with a fluid dampener, which is automatically responsive to dampen pressure surges and acceleration shocks at the beginning of each upstroke and downstroke.

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.

Abstract: The method for rapid installation of a smaller diameter pressure control device usable on an annular BOP or any type of BOP. The step are first installing a flange with a threaded profile upon an annular BOP. Next, install a bell nipple on the flange, then install a first test plug in the base of the BOP or the base of the stack of BOPs. Then install a second test plug into the threaded profile of flange. Perform a pressure test on the flange and all sealing aspects of the annular BOP; depressurizing the flange and removing the test plug. Install a thread protector between flange and the bore of the annular BOP. Next initiate drilling operations; and upon indication of the need for wireline operations, or adapting the existing BOP to smaller working diameter pressure control device, remove the thread protector and install a high pressure assembly.

Abstract: This invention provides a method for controlling production operations using fiber optic devices. An optical fiber carrying fiber-optic sensors is deployed downhole to provide information about downhole conditions. Parameters related to the chemicals being used for surface treatments are measured in real time and on-line, and these measured parameters are used to control the dosage of chemicals into the surface treatment system. The information is also used to control downhole devices that may be a packer, choke, sliding sleeve, perforating device, flow control valve, completion device, an anchor or any other device. Provision is also made for control of secondary recovery operations online using the downhole sensors to monitor the reservoir conditions. The present invention also provides a method of generating motive power in a wellbore utilizing optical energy. This can be done directly or indirectly, e.g., by first producing electrical energy that is then converted to another form of energy.

Abstract: A system and method is provided for integrated control of multiple well tools. Predetermined pressure levels are utilized in independently actuating specific well tools from a plurality of well tools. The number of well tools independently controlled may be greater than the number of fluid control lines that cooperate with the well tools to control tool actuation.

Abstract: The present invention provides a high-speed communication and data link between a downhole tool and a surface computer. The present invention provides a plurality of busses inside of the downhole tool for providing multiple data paths between a down hole tool memory or device and a surface computer. The present invention enables high-speed dumping of memory from the downhole tool to a surface computer. The invention also provides a web server inside of the downhole tool.

Abstract: This invention provides a method for controlling production operations using fiber optic devices. An optical fiber carrying fiber-optic sensors is deployed downhole to provide information about downhole conditions. Parameters related to the chemicals being used for surface treatments are measured in real time and on-line, and these measured parameters are used to control the dosage of chemicals into the surface treatment system. The information is also used to control downhole devices that may be a packer, choke, sliding sleeve, perforating device, flow control valve, completion device, an anchor or any other device. Provision is also made for control of secondary recovery operations online using the downhole sensors to monitor the reservoir conditions. The present invention also provides a method of generating motive power in a wellbore utilizing optical energy. This can be done directly or indirectly, e.g., by first producing electrical energy that is then converted to another form of energy.

Abstract: A casing sensor and methods for sensing using a casing sensor are disclosed. The casing sensor includes a casing shoe and a sensor coupled to the casing shoe. A casing data relay includes a downhole receiver coupled to a well casing and a transmitter coupled to the receiver. The casing sensor may be coupled to the transmitter. A drill string actuator may be controllable through the downhole receiver.