Indian Patents. 208617:CONTROLLABLE PRODUCTION WELL PACKER

Title of Invention	CONTROLLABLE PRODUCTION WELL PACKER
Abstract	An apparatus and method for operating an electrically powered devicein 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.

Full Text	This application claims the benefit of the following U.S. Provisional Applications, all of which are hereby incorporated by reference; The current application shares some specification and figures "with the following commonly owned and concurrently filed applications, all of which are hereby incorporated by reference: commonly owned and previously filed applications, all of which are hereby incorporated . by reference: The benefit of 35 U.S.C. § 120 is claimed for all of the above referenced commonly owned applications. The applications referenced in the tables above are referred to herein as the "Related Applications." BACKGROUND OF THE INVENTION Field of the Invention The present invention relates to a controllable production well packer. In one aspect, it relates to a petroleum production well packer comprising an electrically powered device, in which the device may comprise an electrically controllable valve, a communications and control module, a sensor, a modem, a tracer injection module, or any combination thereof Description of tlie Related Art Petroleum wells (e.g., oil and/or gas wells) typically pass through formations containing multiple zones that may produce differing fluids, as well as impermeable zones. The fluid-bearing zones may produce saline or clear water, oil, gas, or a mixture of these components. It is desirable and customary to maintain hydraulic isolation between zones so tliat the fluids produced fi:om each zone may be received separately at the surface. Even if a particular zone is not producing petroleum products, it is usually necessary to ensure that fluids from that zone do not travel to otlier zones using the wellbore as a transport path, and to avoid contamination of the fluids in each zone. The necessary isolation between zones is often provided by packers. A typical hydraulically set production packer of the prior art is schematically shown in FIG. 1. Packers are mechanical devices that close the annulus between the production tubing and the casing, and seal to both. Packers are typically installed at the time of well, completion by attaching them to a tubing string as it is lowered into the well. Thus, during placement, the packer must pass freely within the casing. Once it is in place, a hydraulic actuator (energized and controlled from the surface) operates the sealing mechanism of the packer, which clamps the packer to the casing and effects a fluid-tight seal in the annular space between the tubing and the casing. Packers may provide complete isolation between the annular spaces above and below them, or may be equipped with one or more preset mechanically-actuated valves to control flow past them. When control valves are included, however, their settings can only be altered by mechanically inserting a slick-line tool, which is inconvenient, slow, and relatively costly. Additionally, when there are multiple zones and muhiple packers it is often impossible or impractical to reach the lowermost packers with a slick-line tool. This lack of a fast and inexpensive method for controlling valves in a packer is a constraint on well design and production operations. Conventional packers are known such as described in U.S. Patents 6,148,915, 6,123,148, 3,566,963 and 3,602,305. All references cited herein are incorporated by reference to the maximum extent allowable by law. To the extent a reference may not be fully incorporated herein, it is incorporated by reference for background purposes, and indicative of tlie knowledge of one of ordinary skill in the art. BRIEF SUMMARY OF THE INVENTION Tne problems and needs outlined above are largely solved and met by the present invention. In accordance with one aspect of the present invention, a packer adapted for use in a petroleum well, wherein the packer comprises an electrically powered device, is provided. The electrically powered device may comprise an electrically controllable valve adapted to control fluid communication from one side of the packer to another side of the packer when the packer is operably installed. The electrically powered device may further comprise a communications and control module being electrically connected to the electrically controllable valve, wherein the module comprises a modem adapted to receive control commands encoded within communication signals. The module can be adapted to decode the control commands received by the modem and control the movement of the valve using the control commands when the packer is operably installed. Alternatively, the electrically powered device may comprise a sensor adapted to detect at least one physical characteristic of a surrounding environment and generate data corresponding to the physical characteristic, as well as a modem adapted to receive the data from the sensor and electrically transmit the data in the form of an electrical communication signal. Hence, the electrically powered device can comprise an electrically controllable valve, a sensor, a modem, a communications and control module, a tracer injection module, or any combination thereof In accordance with another aspect of the present invention, a petroleum production well incorporating the packer described above is provided. The petroleum well comprises a piping structure, a source of time-varying current, an electrical return, an induction choke, and the packer. The piping structure of the well comprises an electrically conductive portion extending along at least part of the piping structure. The piping structure can comprise a production tubing string of the well. The source of time-varying current comprises two source terminals. A first of the source terminals is electrically connected to the electrically conductive portion of the piping structure. The electrical return electrically connects between the electrically conductive portion of the piping structure and a second of the source terminals of the time-varying current source. The electrical return can comprise a well casing of the well, part of the packer, another packer, and/or a conductive fluid within the well. The induction choke is located about part of the electrically conductive portion of the piping structure at a location along the piping structure between the electrical connection location for the first source terminal and the electrical connection location for the electrical return, such that a vohage potential is formed between the electrically conductive portion of the piping structure on a source-side of the induction choke, and the electrically conductive portion of the piping structure on an electrical-retm-n-side of the induction choke as well as the electrical return when time-varying current flows through the electrically conductive portion of the pipmg structure. The induction choke can comprise a fenomagnetic material. Also, the induction choke need not be powered when its size, geometry, and magnetic properties can provide sufficient magnetic inductance for developmg tlie voltage potential desired. The electrically powered device of the packer is electrically connected across the voltage potential such that part of the time-varying current is routed through the device due to the induction choke when the time-varying current flpws through the electrically conductive portionof the piping structure. In accordance with yet another aspect of the present invention, a method of producing petroleum products fi:om a petroleum well comprising an electrically powered packer is provided. A conventional petroleum well includes a cased wellbore having a tubmg string positioned within and longitudinally extending within the casing. In a preferred embodiment, a controllable packer is coupled to the tubing to provide a seal of the annular space between the tubing and casing. A valve in the packer (and/or other devices, such as sensors) is powered and controlled frorn the surface. Communication signals and power are sent from the surface using the tubing and casmg as conductors. At least one induction choke is coupled about the tubing downhole to magnetically inliibit alternating current flow through the tubing at a choke. An insulating tubmg joint, another induction choke, or another insulating means between the tubing and casing can be located at the surface above a location where current and communication signals are imparted to the tubmg. Hence, most of the ahemating current is contained between the " downhole choke and the insulating tubing joint, or between the chokes when two chokes are used. The Related Applications describe alternative ways to provide electrical power from the surface to downhole modules, and to establish bidirectional communications for data and commands to be passed between the surface and downhole modules using surface and downhole modems. A preferred embodiment utilizes the production tubing and the well casing as the electrical conduction path between the surface and downhole equipment. The cost reduction and simplification of installation procedures which accrue from obviating the need for elecfrical cables to provide power, sensing, and control functions downhole allow wider deployment of active equipment downhole during production. In the context of downhole packers, the ability to power and communicate with the packer has many advantages. Such a controllable packer in accordance with the present invention may incorporate sensors, with data from the sensors being received in real time at the surface. Similarly, the availability of power downhole, and the ability to pass commands from the surface to the controllable packer, allow electrically motorized mechanical components, such as flow control valves, to be included in packer design, thus increasing theu: flexibiUty in use. Notably, the control of such components in the controllable packer hereof is near real time, allowing packer flow control valves to be opened, closed, adjusted, or throttled constantly to contribute to the management of production. In a preferred embodiment, a surface computer having a master modem can impart a communication signal to the tubing, and the communication signal is received at a slave modem downhole, which is electrically connected to or within the controllable packer. The communication signal can be received by tlie slave modem either directly or indirectly via one or more relay modems. Further, electric power can be input into the tubing string and received downhole to power the operation of sensors or other devices in the controllable packer. Preferably, the casing is used as a conductor for the electrical return. In a preferred embodiment, a controllable valve m tlie packer regulates the fluid communication in the annulus between the casing and tubing. The electrical return path " can be provided along part of the controllable packer, and preferably by the expansion of the expansion slips into contact with the casing. Alternatively, the electrical return path may be via a conductive centralizer around the tubing which is insulated in its contact with the tubing, but is in electrical contact with the casing and electrically connected to the device in the packer. In enhanced forms, the controllable packer includes one or more sensors dowTJiole wluch are preferably in contact with the downhole modem and communicate with the surface computer via the tubing and/or well casing. Such sensors as temperature, pressure, acoustic, valve position, flow rates, and differential pressure gauges can be advantageously used in many situations. The sensors supply measurements to the modem for transmission to the surface or directly to a programmable interface controller operating a downhole device, such as controllable valve for controlling the fluid flow through the packer. In one embodiment, ferromagnetic induction chokes are coupled about the tubing to act as a series impedance to current flow on the tubing. In a preferred form, an upper ferromagnetic choke is placed aroimd the tubmg below the casing"hanger, and the cunent and communication signals are imparted to the tubing below the upper ferromagnetic choke. A lower ferromagnetic choke is placed downhole around the tubing with the controllable packer electrically coupled to the tubing above the lower ferromagnetic choke, although the controllable packer may be mechanically coupled to the tubing below the lower ferromagnetic choke instead. Preferably, a surface computer is coupled via a surface master modem and the tubing to the downhole slave modem of the controllable packer. The surface computer can receive measurements from a variety of sources (e.g., downhole"sensors), measiurements of the oil output ftom the well, and measurements of the compressed gas input to the well in the case of a gas lift well. Using such measurements, the computer can compute desired positions of the controllable valve in the packer, and more particularly, the optknum amount of fluid conmiunication to permit into the annulus inside the casing. Construction of such a petroleum well is designed to be as similar to conventional construction methodology as possible. That is, after casing the well, a packer is typically set to isolate each zone. In a production well, there may be several oil producing zones, water producing zones, impermeable zones, and tliief zones. It is desirable to prevent or permit communication between the zones. For example when implementing the present _ invention, the tubing string is fed through the casmg into communication with the production zone, with controllable packers defining the production zone. As the tubmg .. string is made up at the surface, a lower ferromagnetic choke is placed around one of the conventional tubing strings for positioning above the lowermost controllable packer. In the sections of the tubing strmgs where it is desired, another packer is coupled to the tubing string to isolate zones. Controllable gas lift valves or sensor pods also may be coupled to the tubing as desired by insertion in a side pocket mandrel (tubing conveyed) and corresponding induction chokes as needed. The tubing string is made up to the surface where an upper ferromagnetic induction choke is again placed around the tubing string below the casing hanger. Communication and power leads are then connected to the tubing string below the upper choke. In an enhanced form, an electrically insulating joint is used instead of the upper induction choke. A sensor and communication pod can be incorporated into the controllable packer ofthepre"sentinventionwithoutthenecessityofincluduig a controllable valve or other control device. That is, an electronics module having pressure, temperature or acoustic sensors, power supply, and a modem can Ije incorporated into the packer for communication to the surface computer using the tubing and casing as conductors. BRIEF DESCRIPTION OF THE DRAWTNGS Other objects and advantages of the invention will become apparent upon reading the following detailed description and upon referencing the accompanying drawings, in which: FIG. 1 is a schematic showing a typical packer of the prior art; FIG. 2 is a schematic showmg a petroleum production well in accordance with a prefenred embodiment of the present invention; FIG. 3 is a simplified electrical schematic of the embodiment shown in FIG. 2; and FIG. 4 is an enlarged schematic showing a controllable packer, from FIG. 2, comprismg an electrically controllable valve. DETAILED DESCRIPTION OF THE INVENTION Referring now to the drawings, wherein lijce referencetiumbers are used herein to -designate like elements tliroughout the various views, a preferred embodiment of the present invention is illustrated and further described, and other possible embodiments of the present invention are described. The figures are not necessarily drawn to scale, and in some instances the drawings have been exaggerated and/or simplified m places for illustrative purposes only. One of ordinary skill in the art will appreciate the many possible applications and variations of the present invention based on the following examples of possible embodiments of the present invention, as well as based on those embodiments illustrated and discussed in the Related Applications, which are incorporated by reference herein to the maximum extent allowed by law. As used in the present application, a "piping structure" can be one single pipe, a tubing string, a well casing, apumpiiig rod, a series of interconnected pipes, rods, rails, tnisses, lattices, supports, a branch or.lateral extension of a well, a network of interconnected pipes, or other similar structures known to one of ordinary skill in the art The prefeired embodiment makes use of the invention in the context of a petroleum well.-where the piping structure comprises tubular, metallic, electrically-conductive pipe or tubing strings, but the invention is not so limited. For the present invention, at least a portion of the piping structure needs to be electrically conductive, such electrically conductive portion may be the entire piping structure (e.g., steel pipes, copper pipes) or a longitudmal extending electrically conductive portion combined with a longitudinally extending non-conductive portion. In other words, an electrically conductive piping structure is one that provides an electrical conducting path &om a first portion where a power source is electrically connected to a second portion where a device and/or electrical return is electrically connected. The piping structure will typically be conventional round metal tubing, but the cross-section geometry of the piping structure, or any portion thereof, can vary in shape (e.g., round, rectangular, square, oval) and size (e.g., length, diameter, wall thickness) along any portion of the piping structure. Hence, a piping structure must have an electrically conductive portion extending from a first " portion of the piping structure to a second portion of the piping structure, wherein the first portion is distally spaced from the second portion along the piping structure. Note that the terms "first portion" and "second portion" as used herein are each defined generally to call out a portion, section, or region of a piping structure that may or may not extend along the piping structure, that can be located at any chosen place along the piping structure, and tliat may or may not encompass the most proximate ends of the piping structure. Similarly, in accordance with conventional terminology of oilfield practice, the descriptors "upper", "lower", "uphole" and "downhole" are relative and refer to distance along hole depth &om the surface, which in deviated or horizontal wells may or may not accord with vertical elevation measured with respect to a survey datum. Also note that the term "modem" is used herein to generically refer to any communications device for transmitting and/or receiving electrical communication signals via an electrical conductor (e.g., metal). Hence, the term "modem" as used .• . . herein is not limited to the acronym for a modulator (device that converts a voice or data signal into a form that can be transmitted)/demodulator (a device that recovers an original signal after it has modulated a high frequency carrier). Also, the term "modern" as used herein is not limited to conventional computer modems that convert digital signals to analog signals and vice versa (e.g., to send digital data signals over the analog Public Switched Telephone Network). For example, if a sensor outputs measurements in an analog format, then such measurements may only need to be modulated (e.g., spread spectrum modulation) and transmitted—hence no analog/digital conversion needed. As another example, a relay/slave modem or communication device may only need to identify, filter, amplify, and/or retransmit a signal received. As used in the present application, "wireless" means the absence of a conventional, insulated wire conductor e.g. extending from a downhole device to the surface. Using the tubing and/or casing as a conductor is considered "v^ireless." The term "valve" as used herein generally refers to any device that functions to regulate tlie flow of a fluid. Examples of valves include, but are not limited to, bellows-type gas-lift valves and controllable gas-lifl valves, each of which may be used to regulate the flow of lift gas into a tubing string of a well. The internal workings of valves can vary greatly. . and in tlie present application, it is not intended to limit the valves described to any particular configuration, so long as the valve functions to regulate flow. Some of the various types of flow regulating mechanisms include, but are not limited to, ball valve configurations, needle valve configurations, gate valve configurations, and cage valve configurations. The methods of installation for valves discus.§,ed in the present application can vary widely. The term "electrically controllable valve" as used herein generally refers to a "valve" (as just described) that can be opened, closed, adjusted, altered, or throtded continuously in response to an electrical control signal (e.g., signal from a surface computer or from a dovviihole electronic controller module). The mechanism that actually moves the valve position can comprise, but is not limited to: an electric motor; an electric servo; an electric solenoid; an electric switch; a hydraulic actuator controlled by at least one electrical servo, electrical motor, electrical switch, electric solenoid, or combinations thereof; a pneumatic actuator controlled by at least one electrical servo, electrical motor, electrical switch, electric solerioid, or combinations thereof; or a spring biased device in combination with at least one electrical servo, electrical motor, electrical , switch, electric solenoid, or combinations thereof. An "electrically controllable valve may or may not include a position feedback sensor for providing a feedback signai corresponding to the actual po.sition of the valve. The term "sensor" as used herein refers to any device that detects, determines, monitors, records, or otherwise senses the absolute value of or a change in a physical quantity. A sensor as described herein can be used to measure physical quantities including, but not Hmited to: temperature, pressure (both absolute and differential), flow rate, seismic data, acoustic data, pH level, salinity levels, valve positions, or almost any otlier physical data. FIG. 1 is a schematic showing a conventional hydraulically set production packer 20 of the prior art set within a well casing 22 of a well. The packer 20 of FIG. 1 is threaded to a production tubing string 24. The conventional packer 20 has a tail piece 26 that may terminate with an open or closed end for the lowest packer in the completed well, or the tail piece 26 may be threaded onto tubing (not shown) that passes to lower regions of the well. The conventional packer 20 has a section of slips 28 and a Seal section 30. Both the slips 28 and the seal section 30 can pass freely inside the well casing 22 during placement, and are operated by a hydraulic actuator 32. When the packer 20 is at its final location in the casing 22, the hydraulic actuator 32 is used to exert mechanical forces on the slips 28 and the seals 30 causing them to expand against the casing The slips 28 lock the packer 20 in place by gripping the internal surface of the casing 22 so that the packer cannot be displaced by differential pressure between the spaces above and below the packer. The seal section 30 creates a liquid-tight seal between the spaces above and below the packer 20. The hydraulic actuator 32 is operated using high-pressure oil supplied from the surface (not shown) by a control tube 34. However, the conventional packer 20 does not comprise an electrically powered device. FIG.2 is a schematic showing a petroleum production well 38 in accordance with a preferred embodiment of the present invention. The petroleum production well 38 shown in FIG. 2 is similar to a conventional well in construction, but with the incorporation on of the present invention. In this example, a packer 40 comprising an electrically powered device 42 is placed in the well 38 in the same manner as a conventional packer 20 would be-to separate zones in a formation. In the preferred embodiment, the electrically powered device 42 of the packer 40 comprises an electric controllable valve 44 that acts as a bypass valve, as shown in more detail in FIG. 4 described further below. In a preferred embodiment, the piping structure comprises part of a production tubing string 24, and the electrical return comprises part of a well casing 22. An insulating tubing joint 47 and a ferromagnetic induction choke 48 are used in this preferred embodiment. The insulating joint 47 is incorporated close to the wellhead to electrically insulate the lower sections of tubing 24 from casing 22. Thus, the insulating joint 47 prevents an electrical short-circuit between the lower sections of tubing 24 and casing 22 the tubing hanger 46. The hanger 46 provides mechanical coupling and support of the tubing 24 by transferring the weight load of the tubing 24 to the casing 22. The induction on choke 48 is attached about the tubing string 24 at a second portion 52 downhole above the packer 40. A computer system 56 comprising a master modem 58 and a source of time-varying current 60 is electrically connected to the tubing string 24 below the insulating tubing joint 47 by a first source terminal 61. The first source terminal 61 is insulated from the hanger 46 where it passes through it. A second source terminal 62 is electrically connected to the well casing 22, either directly (as in FIG. 2) or via the hanger 46 (arrangement not shown). In alternative to or in addition to the insulating tubing joint 47, another induction choke (not shown) can be placed about the tubing 24 above the electrical connection location for the first source terminal 61 to the tubing. The time-varying current source 60 provides the current, which carries power and communication signals downhole. The time-varying current is preferably alternating current (AC), but it can also be a varying direct current (DC). The communication signals can be generated by the master modem 58 and embedded within the current produced y the source 60. Preferably, the communication signal is a spread spectrum signal, but other forms of modulation could be used in alternative. The electrically powered device 42 in the packer 40 comprises two device terminals 71, 72, and there can be other device terminals as needed for other embodiments or applications. A first device terminal 71 is electrically connected to the tubing 24 on a source-side 81 of the induction choke 48, which in this case is above the induction choke. Similarly, a second device terminal 72 is electrically connected to the tubing 24 on an electrical-retum-side 82 of the induction choke 48, which in this case is below the induction choke. In this preferred embodiment, the slips 28 of the packer 40 provide the electrical connection between the tubing 24 and the well casing 22. However, as will be clear to one of ordinary skill in the art, the electrical connection between the tubing 24 and the well casing 22 can be accomplished in numerous ways, some of which can be seen in tile Related Applications, including (but not limited to): another packer (conventional or controllable); conductive fluid in the annulus between the tubing and the well casing; a conductive centralizer; or any combination thereof. Hence, an electrical circuit is formed using the tubing 24 and the well casing 22 as conductor to the downhole device 42 within the packer 40. FIG. 3 illustrates a simplified electrical schematic of the electrical circuit formed in the well 38 of FIG. 2. The insulating tubing joint 47 and the induction choke 48 effectively create an isolated section of the tubing string 24 to contain most of the time-varying current between them. Accordingly, a voltage potential develops between the isolated section of tubing 24 and the well casing 22 when AC flows through the tubing string. Likewise, the voltage potential also forms between tubing 24 on the source-side 81 of the induction choke 48 and the tubing 24 on the electrical-retum-side 82 of the _ induction choke 48 when AC flows through the tubing string. In the preferred embodiment, the electrically powered device 42 in the packer-40 is electrically connected-across the voltage potential between the source-side 81 and the electrical-retum-side 82 of the tubing 24. However in alternative, the device 42 can be electrically connected across the voltage potential between the tubing 24 and the casmg 22, or the voltage potential between the tubing 24 and part of the packer 40 (e.g., slips 28), if that part of the packer is electrically contacting the well casing 22. Thus, part of the current that travels through the tubing 24 and casing 22 is routed through the device 42 due to the mduction choke 48. As is made clear by consideration of the electrical equivalent circuit diagram of FIG. 3, centralizers which are installed on the tubing between isolation device 47 and choke 48 must not provide an electrically conductive path between tubing 24 and casing 22. Suhable centralizers may be composed of solid molded or machined plastic, or may be of the bow-spring type provided these are furnished with appropriate insulating elements. Many suitable and alternative design implementations of such centralizers will be clear to those of average skill in tlie art." Other alternative ways to develop an electrical circuit using a piping structure and at least one induction choke are described in the Related Applications, many of which can be applied in conjunction with the present invention to provide power and/or communications to the electrically powered device 42 of the packer 40 and to form other embodiments of the present invention. Turning to FIG. 4, which shows more details of the packer 40 of FIG. 2, it is seen that the controllable packer 40 is similar to the conventional packer 20 (shown in FIG. 1), but vrith the addition of an electrically powered device 42 comprising an electrically controllable valve 44 and a communications and control module 84. The communications and control module 84 is powered from and communicates with the computer system 56 at the surface 54 via the tubing 24 and/or the casing 22. The communications and control module 84 may comprise a modem 86, a power transformer . (not shown), a microprocessor (not shown), and/or other various electronic components (not shown) as needed for an embodiment. The communications and control module 84 receives electrical signals from the computer system 56 at the surface 54 and decodes commands for controlling the electrically controlled valve 44, which acts as a bypass valve. Using the decoded commands, tlie comniunications and control module 84 controls a low current electric motor that actuates the movement of the bypass valve 44. Tlius, die valve 44 can be opened, closed, adjusted, altered, or throttled continuously by the computer system 56 from the surface 54 via the tubing 24 and well casing 22. The bypass valve 44 of FIG. 4 conhols flow through a bypass tube 88, which connects inJet and outlet ports 90, 92 at the bottom and top of the packer 40. The ports 90, 92 commxmicate freely with the annular spaces 94, 96 (between the casing 22 and the tubing 24), above and below the packer 40. The bypass control valve 44 therefore controls fluid exchange between these spaces 94, 96, and this exchange may be altered in real time using commands sent from the computer system 56 and received by the controllable packer 40. The mechanical arrangement of the packer 40 depicted in FIG. 4 is illustrative, and alternative embodiments having other mechanical features providing the same functional needs of a packer (i.e., fluidly isolating and sealing one casing section from another casing section in a well, and in the case of a controllable packer, regulating and controlling fluid flow between these isolated casing sections) are possible and encompassed wdthin the present invention. For instance, the inlet and outlet ports 90, 92 may be exchanged to pass fluids from tlie annular space 94 above the packer 40 to the space 96 below the packer. Also, the communications and control module 84 and the bypass confrol valve 44 may be located in upper portion of the packer 40, above the slips 28. The controllable packer 40 may also comprise sensors (not shown) electrically connected to or within the communication and control module 84, to measure pressures or temperatures in the annuli 94, 96 or within the production tubing 24. Hence, the measurements can be transmitted to the computer system 56 at the surface 54 using the communications and control module 84, providing real time data on downhole conditions. Also the setting and unsetting mechanism of the packer slips may be actuated by one or more motors driven and controlled by power and commands received by module 84. In other possible embodiments of the present invention, the electrically powered device 42 of the packer 40 may comprise: a modem 86; a sensor (not shown); a microprocessor (not sho^wii); a packer valve 44; a tracer injection module (not shown); an . electrically controllable gas-lift valve (e.g., for controlling the flow of gas from the annulus to inside the tubing) (not shown); a tubing valve (e.g.rfor varying tlie flow of a -tubing section, such as an application having muhiple branches or laterals) (not shown); a communications and control module 84; a logic circuit (not shown); a relay modem (not shown); other electronic components as needed (not shown); or any combination thereof Also in other possible embodiments of the present invention, there may be multiple controllable packers and/or multiple induction chokes. In an application where there are multiple controllable packers or additional conventional packers combined with tlie present invention, it may be necessary to electrically insulate some or all of the packers so that a packer does not act as a short between the piping structure (e.g., tubing 24) and the electrical return (e.g., casing 22) where such a short is not desired. Such electrical insulation of a packer may be achieved in various ways apparent tO"One of.";""!, ordinary skill in the art, including (but not limited to): an insulating sleeve^ about the;. . t"..-. . . tubing at the packer location; a rubber or uxethane portion at the radial extent of the .. " packer slips; an insulating coatmg on the tubing at the packer location; forming the slips ;. :."• fi:om non-electrically-conductive materials; other known insulating means; or any combination thereof The present invention also can be applied to other types of wells (other tlian petroleum wells), such as a water well. It will be appreciated by those skilled in the art having the benefit of this disclosure that this invention provides a packer comprising an electrically powered device, as well as a petroleum production well incorporating such a packer. It should be xmderstood that the drawings and detailed description herein are to be regarded in an illustrative rather than a restrictive maimer, and are not intended to limit the invention to the particular fornis and examples disclosed. On the contrary, the invention includes any further modifications, changes, rearrangements, substitutions, alternatives, design choices, and embodiments apparent to those of ordinary skill in the art, without departing from the spirit and scope of this invention, as defined by the following claims. Thus, it is intended that the following claims be interpreted to embrace all such further -s. _ ! " modifications, changes, rearrangements, substitutions, alternatives, design choices, and embodiments. WE CLAIM: 1. A petroleum well assembly for producing petroleum products, comprising: a piping structure (24) comprising an electrically conductive portion extending along at least part of said piping structure; a source of time-varying current electrically connected to said electrically conductive portion of said piping structure (24); an electrical return (22); and a packer comprising an electrically powered device (42); characterized in that an induction choke (48) is installed about part of the electrically conductive portion of the piping structure (24); and that said electrically powered device (42) is electrically cormected to the piping structure at a source side and at an electrical return side of the induction choke (48) such that part of said time-varying current is routed through said device (42) when said time varying current is applied through said electrically conductive portion of said piping structure (24). 2. The petroleum well assembly as claimed in claim 1, wherein said electrically powered device (42) comprises an electrically controllable valve (44) adapted to control fluid communication between one side of said packer (40) and another side of said packer (40) when said packer (40) is operably installed. 3. The petroleum well assembly as claimed in claim 1, wherein said electrically powered device (42) comprises a sensor adapted to measure a physical quantity. 4. The petroleum well assembly as claimed in claim 1, wherein said electrically powered device (42) comprises a modem (86) adapted to send and receive communications along said electrically conductive portion of piping structure (24). 5.The petroleum well assembly as claimed in claim 1, wherein said electrically powered device (42) comprises a chemical injection module adapted to controllably inject a substance into a flow stream. 6. The petroleum well assembly as claimed in claim 1, wherein said electrically powered device (42) comprises an electrically controllable valve adapted to control fluid communication between an exterior and an interior of a production tubing string. 7. The petroleum well assembly as claimed in claim 1, wherein said electrically powered device (42) comprises an electrically controllable valve (44) adapted to control fluid flow within a production tube. 8. The petroleum well assembly as claimed in claim 1, wherein said piping structure (24) comprises a production tubing string (24) of said well (38). 9. The petroleum well assembly as claimed in claim 1, wherein said piping structure comprises a well casing (22) of said well. 10. The petroleum well assembly as claimed in claim 1, wherein said electrical return (22) comprises a well casing (22) of said well. 11. The petroleum well assembly as claimed in claim 1, wherein said electrical return comprises at least a portion of an earthen ground. 12. The petroleum well assembly as claimed in claim 1, comprising a second induction choke, said second induction choke being located about another part of said electrically conductive portion of said piping structure and at a location along said piping structure such that said electrical connection location for said time-varying current source is located between said induction chokes. 13. The petroleum well assembly as claimed in claim 1, comprising a second packer. 14. The petroleum well assembly as claimed in claim 13, wherein said second packer comprises an electrical insulator so that, said electrically conductive portion of said piping structure is not electrically connected to said electrical return at said second packer when said second packer is operably installed. 15. The petroleum well assembly as claimed in claim 13, wherein said second packer is part of said electrical return. 16. The petroleum well assembly as claimed in claim 1, wherein said packer (40) is located on said source-side of said induction choke (48). 17. The petroleum well assembly as claimed in claim 1, wherein said packer (40) is located on said electrical-retum-side of said induction choke (48). 18. A method of operating a petroleum well assembly comprising: providing an electrically powered packer (40) in a petroleum well (38); providing a piping structure (24) in said well (38), said piping structure (24) comprising an electrically conductive portion extending along at least part of said piping structure (24); operably installing said electrically powered packer (40) in said well (38), said electrically powered packer (40) comprising an electrically powered device (42), such that said device (42) is electrically connected to said electrically conductive portion of said piping structure (24) when said well (38) is operable for petroleum production; characterized in that the method comprises: operably installing an induction choke (48) about part of said electrically conductive portion of said piping structure (24); supplying time-varying current to said piping structure (24); routing part of said time-varying current through said electrically powered device (42) using said induction choke (48); and producing petroleum products with said well (38). 19. The method as claimed in claim 18, comprising the steps of: measuring a physical quantity with said electrically powered device (42), wherein said electrically powered device comprises a sensor; and varying a flow of petroleum products in said well (38) based on said measurements. 20. The method as claimed in claim 18, comprising the step of: electrically controlling fluid communication between sections of said well (38) using said packer (40), wherein said electrically powered device (42) comprises an electrically controllable valve (44).

Full Text

This application claims the benefit of the following U.S. Provisional Applications, all of which are hereby incorporated by reference;

The current application shares some specification and figures "with the following commonly owned and concurrently filed applications, all of which are hereby incorporated by reference:

commonly owned and previously filed applications, all of which are hereby incorporated
. by reference:

The benefit of 35 U.S.C. § 120 is claimed for all of the above referenced commonly owned applications. The applications referenced in the tables above are referred to herein as the "Related Applications."
BACKGROUND OF THE INVENTION
Field of the Invention
The present invention relates to a controllable production well packer. In one
aspect, it relates to a petroleum production well packer comprising an electrically powered device, in which the device may comprise an electrically controllable valve, a communications and control module, a sensor, a modem, a tracer injection module, or any combination thereof

Description of tlie Related Art
Petroleum wells (e.g., oil and/or gas wells) typically pass through formations containing multiple zones that may produce differing fluids, as well as impermeable zones. The fluid-bearing zones may produce saline or clear water, oil, gas, or a mixture of these components.
It is desirable and customary to maintain hydraulic isolation between zones so tliat the fluids produced fi:om each zone may be received separately at the surface. Even if a particular zone is not producing petroleum products, it is usually necessary to ensure that fluids from that zone do not travel to otlier zones using the wellbore as a transport path, and to avoid contamination of the fluids in each zone.
The necessary isolation between zones is often provided by packers. A typical hydraulically set production packer of the prior art is schematically shown in FIG. 1. Packers are mechanical devices that close the annulus between the production tubing and the casing, and seal to both. Packers are typically installed at the time of well, completion by attaching them to a tubing string as it is lowered into the well. Thus, during placement, the packer must pass freely within the casing. Once it is in place, a hydraulic actuator (energized and controlled from the surface) operates the sealing mechanism of the packer, which clamps the packer to the casing and effects a fluid-tight seal in the annular space between the tubing and the casing.
Packers may provide complete isolation between the annular spaces above and below them, or may be equipped with one or more preset mechanically-actuated valves to control flow past them. When control valves are included, however, their settings can only be altered by mechanically inserting a slick-line tool, which is inconvenient, slow, and relatively costly. Additionally, when there are multiple zones and muhiple packers it is often impossible or impractical to reach the lowermost packers with a slick-line tool. This lack of a fast and inexpensive method for controlling valves in a packer is a constraint on well design and production operations.
Conventional packers are known such as described in U.S. Patents 6,148,915, 6,123,148, 3,566,963 and 3,602,305.

All references cited herein are incorporated by reference to the maximum extent allowable by law. To the extent a reference may not be fully incorporated herein, it is incorporated by reference for background purposes, and indicative of tlie knowledge of one of ordinary skill in the art.
BRIEF SUMMARY OF THE INVENTION
Tne problems and needs outlined above are largely solved and met by the present invention. In accordance with one aspect of the present invention, a packer adapted for use in a petroleum well, wherein the packer comprises an electrically powered device, is provided. The electrically powered device may comprise an electrically controllable valve adapted to control fluid communication from one side of the packer to another side of the packer when the packer is operably installed. The electrically powered device may further comprise a communications and control module being electrically connected to the electrically controllable valve, wherein the module comprises a modem adapted to receive control commands encoded within communication signals. The module can be adapted to decode the control commands received by the modem and control the movement of the valve using the control commands when the packer is operably installed. Alternatively, the electrically powered device may comprise a sensor adapted to detect at least one physical characteristic of a surrounding environment and generate data corresponding to the physical characteristic, as well as a modem adapted to receive the data from the sensor and electrically transmit the data in the form of an electrical communication signal. Hence, the electrically powered device can comprise an electrically controllable valve, a sensor, a modem, a communications and control module, a tracer injection module, or any combination thereof
In accordance with another aspect of the present invention, a petroleum production well incorporating the packer described above is provided. The petroleum well comprises a piping structure, a source of time-varying current, an electrical return, an induction choke, and the packer. The piping structure of the well comprises an electrically conductive portion extending along at least part of the piping structure. The piping structure can comprise a production tubing string of the well. The source of time-varying current comprises two source terminals. A first of the source terminals is electrically connected to the electrically conductive portion of the piping structure. The

electrical return electrically connects between the electrically conductive portion of the piping structure and a second of the source terminals of the time-varying current source. The electrical return can comprise a well casing of the well, part of the packer, another
packer, and/or a conductive fluid within the well. The induction choke is located about
part of the electrically conductive portion of the piping structure at a location along the
piping structure between the electrical connection location for the first source terminal
and the electrical connection location for the electrical return, such that a vohage
potential is formed between the electrically conductive portion of the piping structure on
a source-side of the induction choke, and the electrically conductive portion of the piping
structure on an electrical-retm-n-side of the induction choke as well as the electrical
return when time-varying current flows through the electrically conductive portion of the
pipmg structure. The induction choke can comprise a fenomagnetic material. Also, the
induction choke need not be powered when its size, geometry, and magnetic properties
can provide sufficient magnetic inductance for developmg tlie voltage potential desired.
The electrically powered device of the packer is electrically connected across the voltage
potential such that part of the time-varying current is routed through the device due to the
induction choke when the time-varying current flpws through the electrically conductive
portionof the piping structure.
In accordance with yet another aspect of the present invention, a method of producing petroleum products fi:om a petroleum well comprising an electrically powered packer is provided.
A conventional petroleum well includes a cased wellbore having a tubmg string positioned within and longitudinally extending within the casing. In a preferred embodiment, a controllable packer is coupled to the tubing to provide a seal of the annular space between the tubing and casing. A valve in the packer (and/or other devices, such as sensors) is powered and controlled frorn the surface. Communication signals and power are sent from the surface using the tubing and casmg as conductors. At least one induction choke is coupled about the tubing downhole to magnetically inliibit alternating current flow through the tubing at a choke. An insulating tubmg joint, another induction choke, or another insulating means between the tubing and casing can be located at the surface above a location where current and communication signals are imparted to the tubmg. Hence, most of the ahemating current is contained between the

" downhole choke and the insulating tubing joint, or between the chokes when two chokes are used.
The Related Applications describe alternative ways to provide electrical power from the surface to downhole modules, and to establish bidirectional communications for data and commands to be passed between the surface and downhole modules using surface and downhole modems. A preferred embodiment utilizes the production tubing and the well casing as the electrical conduction path between the surface and downhole equipment. The cost reduction and simplification of installation procedures which accrue from obviating the need for elecfrical cables to provide power, sensing, and control functions downhole allow wider deployment of active equipment downhole during production.
In the context of downhole packers, the ability to power and communicate with the packer has many advantages. Such a controllable packer in accordance with the present invention may incorporate sensors, with data from the sensors being received in real time at the surface. Similarly, the availability of power downhole, and the ability to pass commands from the surface to the controllable packer, allow electrically motorized mechanical components, such as flow control valves, to be included in packer design, thus increasing theu: flexibiUty in use. Notably, the control of such components in the controllable packer hereof is near real time, allowing packer flow control valves to be opened, closed, adjusted, or throttled constantly to contribute to the management of production.
In a preferred embodiment, a surface computer having a master modem can impart a communication signal to the tubing, and the communication signal is received at a slave modem downhole, which is electrically connected to or within the controllable packer. The communication signal can be received by tlie slave modem either directly or indirectly via one or more relay modems. Further, electric power can be input into the tubing string and received downhole to power the operation of sensors or other devices in the controllable packer. Preferably, the casing is used as a conductor for the electrical return.
In a preferred embodiment, a controllable valve m tlie packer regulates the fluid communication in the annulus between the casing and tubing. The electrical return path

" can be provided along part of the controllable packer, and preferably by the expansion of the expansion slips into contact with the casing. Alternatively, the electrical return path may be via a conductive centralizer around the tubing which is insulated in its contact with the tubing, but is in electrical contact with the casing and electrically connected to
the device in the packer.
In enhanced forms, the controllable packer includes one or more sensors dowTJiole wluch are preferably in contact with the downhole modem and communicate with the surface computer via the tubing and/or well casing. Such sensors as temperature, pressure, acoustic, valve position, flow rates, and differential pressure gauges can be advantageously used in many situations. The sensors supply measurements to the modem for transmission to the surface or directly to a programmable interface controller operating a downhole device, such as controllable valve for controlling the fluid flow through the packer.
In one embodiment, ferromagnetic induction chokes are coupled about the tubing
to act as a series impedance to current flow on the tubing. In a preferred form, an upper
ferromagnetic choke is placed aroimd the tubmg below the casing"hanger, and the cunent
and communication signals are imparted to the tubing below the upper ferromagnetic choke. A lower ferromagnetic choke is placed downhole around the tubing with the controllable packer electrically coupled to the tubing above the lower ferromagnetic choke, although the controllable packer may be mechanically coupled to the tubing below the lower ferromagnetic choke instead.
Preferably, a surface computer is coupled via a surface master modem and the tubing to the downhole slave modem of the controllable packer. The surface computer can receive measurements from a variety of sources (e.g., downhole"sensors), measiurements of the oil output ftom the well, and measurements of the compressed gas input to the well in the case of a gas lift well. Using such measurements, the computer can compute desired positions of the controllable valve in the packer, and more particularly, the optknum amount of fluid conmiunication to permit into the annulus inside the casing.
Construction of such a petroleum well is designed to be as similar to conventional construction methodology as possible. That is, after casing the well, a packer is typically

set to isolate each zone. In a production well, there may be several oil producing zones, water producing zones, impermeable zones, and tliief zones. It is desirable to prevent or permit communication between the zones. For example when implementing the present _ invention, the tubing string is fed through the casmg into communication with the production zone, with controllable packers defining the production zone. As the tubmg .. string is made up at the surface, a lower ferromagnetic choke is placed around one of the conventional tubing strings for positioning above the lowermost controllable packer. In the sections of the tubing strmgs where it is desired, another packer is coupled to the tubing string to isolate zones. Controllable gas lift valves or sensor pods also may be coupled to the tubing as desired by insertion in a side pocket mandrel (tubing conveyed) and corresponding induction chokes as needed. The tubing string is made up to the surface where an upper ferromagnetic induction choke is again placed around the tubing string below the casing hanger. Communication and power leads are then connected to the tubing string below the upper choke. In an enhanced form, an electrically insulating joint is used instead of the upper induction choke.
A sensor and communication pod can be incorporated into the controllable packer
ofthepre"sentinventionwithoutthenecessityofincluduig a controllable valve or other control device. That is, an electronics module having pressure, temperature or acoustic sensors, power supply, and a modem can Ije incorporated into the packer for communication to the surface computer using the tubing and casing as conductors.
BRIEF DESCRIPTION OF THE DRAWTNGS
Other objects and advantages of the invention will become apparent upon reading the following detailed description and upon referencing the accompanying drawings, in which:
FIG. 1 is a schematic showing a typical packer of the prior art;
FIG. 2 is a schematic showmg a petroleum production well in accordance with a prefenred embodiment of the present invention;
FIG. 3 is a simplified electrical schematic of the embodiment shown in FIG. 2; and

FIG. 4 is an enlarged schematic showing a controllable packer, from FIG. 2, comprismg an electrically controllable valve.
DETAILED DESCRIPTION OF THE INVENTION
Referring now to the drawings, wherein lijce referencetiumbers are used herein to -designate like elements tliroughout the various views, a preferred embodiment of the present invention is illustrated and further described, and other possible embodiments of the present invention are described. The figures are not necessarily drawn to scale, and in some instances the drawings have been exaggerated and/or simplified m places for illustrative purposes only. One of ordinary skill in the art will appreciate the many possible applications and variations of the present invention based on the following examples of possible embodiments of the present invention, as well as based on those embodiments illustrated and discussed in the Related Applications, which are incorporated by reference herein to the maximum extent allowed by law.
As used in the present application, a "piping structure" can be one single pipe, a
tubing string, a well casing, apumpiiig rod, a series of interconnected pipes, rods, rails,
tnisses, lattices, supports, a branch or.lateral extension of a well, a network of
interconnected pipes, or other similar structures known to one of ordinary skill in the art The prefeired embodiment makes use of the invention in the context of a petroleum well.-where the piping structure comprises tubular, metallic, electrically-conductive pipe or tubing strings, but the invention is not so limited. For the present invention, at least a portion of the piping structure needs to be electrically conductive, such electrically conductive portion may be the entire piping structure (e.g., steel pipes, copper pipes) or a longitudmal extending electrically conductive portion combined with a longitudinally extending non-conductive portion. In other words, an electrically conductive piping structure is one that provides an electrical conducting path &om a first portion where a power source is electrically connected to a second portion where a device and/or electrical return is electrically connected. The piping structure will typically be conventional round metal tubing, but the cross-section geometry of the piping structure, or any portion thereof, can vary in shape (e.g., round, rectangular, square, oval) and size (e.g., length, diameter, wall thickness) along any portion of the piping structure. Hence, a piping structure must have an electrically conductive portion extending from a first

" portion of the piping structure to a second portion of the piping structure, wherein the first portion is distally spaced from the second portion along the piping structure.
Note that the terms "first portion" and "second portion" as used herein are each defined generally to call out a portion, section, or region of a piping structure that may or may not extend along the piping structure, that can be located at any chosen place along the piping structure, and tliat may or may not encompass the most proximate ends of the piping structure.
Similarly, in accordance with conventional terminology of oilfield practice, the descriptors "upper", "lower", "uphole" and "downhole" are relative and refer to distance along hole depth &om the surface, which in deviated or horizontal wells may or may not accord with vertical elevation measured with respect to a survey datum.
Also note that the term "modem" is used herein to generically refer to any communications device for transmitting and/or receiving electrical communication signals via an electrical conductor (e.g., metal). Hence, the term "modem" as used .• . . herein is not limited to the acronym for a modulator (device that converts a voice or data signal into a form that can be transmitted)/demodulator (a device that recovers an original signal after it has modulated a high frequency carrier). Also, the term "modern" as used herein is not limited to conventional computer modems that convert digital signals to analog signals and vice versa (e.g., to send digital data signals over the analog Public Switched Telephone Network). For example, if a sensor outputs measurements in an analog format, then such measurements may only need to be modulated (e.g., spread spectrum modulation) and transmitted—hence no analog/digital conversion needed. As another example, a relay/slave modem or communication device may only need to identify, filter, amplify, and/or retransmit a signal received.
As used in the present application, "wireless" means the absence of a conventional, insulated wire conductor e.g. extending from a downhole device to the surface. Using the tubing and/or casing as a conductor is considered "v^ireless." The term "valve" as used herein generally refers to any device that functions to regulate tlie flow of a fluid. Examples of valves include, but are not limited to, bellows-type gas-lift valves and controllable gas-lifl valves, each of which may be used to regulate the flow of lift gas into a tubing string of a well. The internal workings of valves can vary greatly.

. and in tlie present application, it is not intended to limit the valves described to any
particular configuration, so long as the valve functions to regulate flow. Some of the
various types of flow regulating mechanisms include, but are not limited to, ball valve
configurations, needle valve configurations, gate valve configurations, and cage valve
configurations. The methods of installation for valves discus.§,ed in the present
application can vary widely.
The term "electrically controllable valve" as used herein generally refers to a
"valve" (as just described) that can be opened, closed, adjusted, altered, or throtded
continuously in response to an electrical control signal (e.g., signal from a surface
computer or from a dovviihole electronic controller module). The mechanism that
actually moves the valve position can comprise, but is not limited to: an electric motor;
an electric servo; an electric solenoid; an electric switch; a hydraulic actuator controlled
by at least one electrical servo, electrical motor, electrical switch, electric solenoid, or
combinations thereof; a pneumatic actuator controlled by at least one electrical servo,
electrical motor, electrical switch, electric solerioid, or combinations thereof; or a spring
biased device in combination with at least one electrical servo, electrical motor, electrical ,
switch, electric solenoid, or combinations thereof. An "electrically controllable valve
may or may not include a position feedback sensor for providing a feedback signai
corresponding to the actual po.sition of the valve.
The term "sensor" as used herein refers to any device that detects, determines, monitors, records, or otherwise senses the absolute value of or a change in a physical quantity. A sensor as described herein can be used to measure physical quantities including, but not Hmited to: temperature, pressure (both absolute and differential), flow rate, seismic data, acoustic data, pH level, salinity levels, valve positions, or almost any otlier physical data.
FIG. 1 is a schematic showing a conventional hydraulically set production packer 20 of the prior art set within a well casing 22 of a well. The packer 20 of FIG. 1 is threaded to a production tubing string 24. The conventional packer 20 has a tail piece 26 that may terminate with an open or closed end for the lowest packer in the completed well, or the tail piece 26 may be threaded onto tubing (not shown) that passes to lower regions of the well. The conventional packer 20 has a section of slips 28 and a Seal

section 30. Both the slips 28 and the seal section 30 can pass freely inside the well casing 22 during placement, and are operated by a hydraulic actuator 32. When the packer 20 is at its final location in the casing 22, the hydraulic actuator 32 is used to exert mechanical forces on the slips 28 and the seals 30 causing them to expand against the casing The slips 28 lock the packer 20 in place by gripping the internal surface of the casing 22 so that the packer cannot be displaced by differential pressure between the spaces above and below the packer. The seal section 30 creates a liquid-tight seal between the spaces above and below the packer 20. The hydraulic actuator 32 is operated using high-pressure oil supplied from the surface (not shown) by a control tube 34. However, the conventional packer 20 does not comprise an electrically powered device.
FIG.2 is a schematic showing a petroleum production well 38 in accordance with a preferred embodiment of the present invention. The petroleum production well 38 shown in FIG. 2 is similar to a conventional well in construction, but with the incorporation on of the present invention. In this example, a packer 40 comprising an electrically powered device 42 is placed in the well 38 in the same manner as a conventional packer 20 would be-to separate zones in a formation. In the preferred embodiment, the electrically powered device 42 of the packer 40 comprises an electric controllable valve 44 that acts as a bypass valve, as shown in more detail in FIG. 4 described further below.
In a preferred embodiment, the piping structure comprises part of a production tubing string 24, and the electrical return comprises part of a well casing 22. An insulating tubing joint 47 and a ferromagnetic induction choke 48 are used in this

preferred embodiment. The insulating joint 47 is incorporated close to the wellhead to electrically insulate the lower sections of tubing 24 from casing 22. Thus, the insulating joint 47 prevents an electrical short-circuit between the lower sections of tubing 24 and casing 22 the tubing hanger 46. The hanger 46 provides mechanical coupling and support of the tubing 24 by transferring the weight load of the tubing 24 to the casing 22. The induction on choke 48 is attached about the tubing string 24 at a second portion 52 downhole above the packer 40. A computer system 56 comprising a master modem 58 and a source of time-varying current 60 is electrically connected to the tubing string 24 below the insulating tubing joint 47 by a first source terminal 61. The first source terminal 61 is insulated from the hanger 46 where it passes through it. A second source terminal 62 is electrically connected to the well casing 22, either directly (as in FIG. 2) or via the hanger 46 (arrangement not shown). In alternative to or in addition to the insulating tubing joint 47, another induction choke (not shown) can be placed about the tubing 24 above the electrical connection location for the first source terminal 61 to the tubing.
The time-varying current source 60 provides the current, which carries power and communication signals downhole. The time-varying current is preferably alternating current (AC), but it can also be a varying direct current (DC). The communication signals can be generated by the master modem 58 and embedded within the current produced y the source 60. Preferably, the communication signal is a spread spectrum signal, but other forms of modulation could be used in alternative.
The electrically powered device 42 in the packer 40 comprises two device terminals 71, 72, and there can be other device terminals as needed for other embodiments or applications. A first device terminal 71 is electrically connected to

the tubing 24 on a source-side 81 of the induction choke 48, which in this case is above the induction choke. Similarly, a second device terminal 72 is electrically connected to the tubing 24 on an electrical-retum-side 82 of the induction choke 48, which in this case is below the induction choke. In this preferred embodiment, the slips 28 of the packer 40 provide the electrical connection between the tubing 24 and the well casing 22. However, as will be clear to one of ordinary skill in the art, the electrical connection between the tubing 24 and the well casing 22 can be accomplished in numerous ways, some of which can be seen in tile Related Applications, including (but not limited to): another packer (conventional or controllable); conductive fluid in the annulus between the tubing and the well casing; a conductive centralizer; or any combination thereof. Hence, an electrical circuit is formed using the tubing 24 and the well casing 22 as conductor to the downhole device 42 within the packer 40.
FIG. 3 illustrates a simplified electrical schematic of the electrical circuit formed in the well 38 of FIG. 2. The insulating tubing joint 47 and the induction choke 48 effectively create an isolated section of the tubing string 24 to contain most of the time-varying current between them. Accordingly, a voltage potential develops between the

isolated section of tubing 24 and the well casing 22 when AC flows through the tubing string. Likewise, the voltage potential also forms between tubing 24 on the source-side 81 of the induction choke 48 and the tubing 24 on the electrical-retum-side 82 of the _ induction choke 48 when AC flows through the tubing string. In the preferred embodiment, the electrically powered device 42 in the packer-40 is electrically connected-across the voltage potential between the source-side 81 and the electrical-retum-side 82 of the tubing 24. However in alternative, the device 42 can be electrically connected across the voltage potential between the tubing 24 and the casmg 22, or the voltage potential between the tubing 24 and part of the packer 40 (e.g., slips 28), if that part of the packer is electrically contacting the well casing 22. Thus, part of the current that travels through the tubing 24 and casing 22 is routed through the device 42 due to the mduction choke 48.
As is made clear by consideration of the electrical equivalent circuit diagram of
FIG. 3, centralizers which are installed on the tubing between isolation device 47 and
choke 48 must not provide an electrically conductive path between tubing 24 and casing
22. Suhable centralizers may be composed of solid molded or machined plastic, or may
be of the bow-spring type provided these are furnished with appropriate insulating
elements. Many suitable and alternative design implementations of such centralizers will be clear to those of average skill in tlie art."
Other alternative ways to develop an electrical circuit using a piping structure and at least one induction choke are described in the Related Applications, many of which can be applied in conjunction with the present invention to provide power and/or communications to the electrically powered device 42 of the packer 40 and to form other embodiments of the present invention.
Turning to FIG. 4, which shows more details of the packer 40 of FIG. 2, it is seen that the controllable packer 40 is similar to the conventional packer 20 (shown in FIG. 1), but vrith the addition of an electrically powered device 42 comprising an electrically controllable valve 44 and a communications and control module 84. The communications and control module 84 is powered from and communicates with the computer system 56 at the surface 54 via the tubing 24 and/or the casing 22. The communications and control module 84 may comprise a modem 86, a power transformer

. (not shown), a microprocessor (not shown), and/or other various electronic components (not shown) as needed for an embodiment. The communications and control module 84 receives electrical signals from the computer system 56 at the surface 54 and decodes commands for controlling the electrically controlled valve 44, which acts as a bypass valve. Using the decoded commands, tlie comniunications and control module 84 controls a low current electric motor that actuates the movement of the bypass valve 44. Tlius, die valve 44 can be opened, closed, adjusted, altered, or throttled continuously by the computer system 56 from the surface 54 via the tubing 24 and well casing 22.
The bypass valve 44 of FIG. 4 conhols flow through a bypass tube 88, which connects inJet and outlet ports 90, 92 at the bottom and top of the packer 40. The ports 90, 92 commxmicate freely with the annular spaces 94, 96 (between the casing 22 and the tubing 24), above and below the packer 40. The bypass control valve 44 therefore controls fluid exchange between these spaces 94, 96, and this exchange may be altered in real time using commands sent from the computer system 56 and received by the controllable packer 40.
The mechanical arrangement of the packer 40 depicted in FIG. 4 is illustrative,
and alternative embodiments having other mechanical features providing the same
functional needs of a packer (i.e., fluidly isolating and sealing one casing section from
another casing section in a well, and in the case of a controllable packer, regulating and controlling fluid flow between these isolated casing sections) are possible and encompassed wdthin the present invention. For instance, the inlet and outlet ports 90, 92 may be exchanged to pass fluids from tlie annular space 94 above the packer 40 to the space 96 below the packer. Also, the communications and control module 84 and the bypass confrol valve 44 may be located in upper portion of the packer 40, above the slips 28. The controllable packer 40 may also comprise sensors (not shown) electrically connected to or within the communication and control module 84, to measure pressures or temperatures in the annuli 94, 96 or within the production tubing 24. Hence, the measurements can be transmitted to the computer system 56 at the surface 54 using the communications and control module 84, providing real time data on downhole conditions. Also the setting and unsetting mechanism of the packer slips may be actuated by one or more motors driven and controlled by power and commands received by module 84.

In other possible embodiments of the present invention, the electrically powered device 42 of the packer 40 may comprise: a modem 86; a sensor (not shown); a microprocessor (not sho^wii); a packer valve 44; a tracer injection module (not shown); an . electrically controllable gas-lift valve (e.g., for controlling the flow of gas from the annulus to inside the tubing) (not shown); a tubing valve (e.g.rfor varying tlie flow of a -tubing section, such as an application having muhiple branches or laterals) (not shown); a communications and control module 84; a logic circuit (not shown); a relay modem (not shown); other electronic components as needed (not shown); or any combination thereof
Also in other possible embodiments of the present invention, there may be
multiple controllable packers and/or multiple induction chokes. In an application where
there are multiple controllable packers or additional conventional packers combined with
tlie present invention, it may be necessary to electrically insulate some or all of the
packers so that a packer does not act as a short between the piping structure (e.g.,
tubing 24) and the electrical return (e.g., casing 22) where such a short is not desired.
Such electrical insulation of a packer may be achieved in various ways apparent tO"One of.";""!,
ordinary skill in the art, including (but not limited to): an insulating sleeve^ about the;. . t"..-. . .
tubing at the packer location; a rubber or uxethane portion at the radial extent of the .. "
packer slips; an insulating coatmg on the tubing at the packer location; forming the slips ;. :."• fi:om non-electrically-conductive materials; other known insulating means; or any combination thereof The present invention also can be applied to other types of wells (other tlian petroleum wells), such as a water well.
It will be appreciated by those skilled in the art having the benefit of this disclosure that this invention provides a packer comprising an electrically powered device, as well as a petroleum production well incorporating such a packer. It should be xmderstood that the drawings and detailed description herein are to be regarded in an illustrative rather than a restrictive maimer, and are not intended to limit the invention to the particular fornis and examples disclosed. On the contrary, the invention includes any further modifications, changes, rearrangements, substitutions, alternatives, design choices, and embodiments apparent to those of ordinary skill in the art, without departing from the spirit and scope of this invention, as defined by the following claims. Thus, it is intended that the following claims be interpreted to embrace all such further
-s. _

! " modifications, changes, rearrangements, substitutions, alternatives, design choices, and
embodiments.

WE CLAIM:
1. A petroleum well assembly for producing petroleum products, comprising:
a piping structure (24) comprising an electrically conductive portion extending along at least part of said piping structure;
a source of time-varying current electrically connected to said electrically conductive portion of said piping structure (24);
an electrical return (22); and
a packer comprising an electrically powered device (42);
characterized in that an induction choke (48) is installed about part of the electrically conductive portion of the piping structure (24); and that said electrically powered device (42) is electrically cormected to the piping structure at a source side and at an electrical return side of the induction choke (48) such that part of said time-varying current is routed through said device (42) when said time varying current is applied through said electrically conductive portion of said piping structure (24).
2. The petroleum well assembly as claimed in claim 1, wherein said electrically powered device (42) comprises an electrically controllable valve (44) adapted to control fluid communication between one side of said packer (40) and another side of said packer (40) when said packer (40) is operably installed.
3. The petroleum well assembly as claimed in claim 1, wherein said electrically powered device (42) comprises a sensor adapted to measure a physical quantity.

4. The petroleum well assembly as claimed in claim 1, wherein said electrically powered device (42) comprises a modem (86) adapted to send and receive communications along said electrically conductive portion of piping structure (24).
5.The petroleum well assembly as claimed in claim 1, wherein said electrically powered device (42) comprises a chemical injection module adapted to controllably inject a substance into a flow stream.
6. The petroleum well assembly as claimed in claim 1, wherein said electrically powered device (42) comprises an electrically controllable valve adapted to control fluid communication between an exterior and an interior of a production tubing string.
7. The petroleum well assembly as claimed in claim 1, wherein said electrically powered device (42) comprises an electrically controllable valve (44) adapted to control fluid flow within a production tube.
8. The petroleum well assembly as claimed in claim 1, wherein said piping structure (24) comprises a production tubing string (24) of said well (38).
9. The petroleum well assembly as claimed in claim 1, wherein said piping structure comprises a well casing (22) of said well.
10. The petroleum well assembly as claimed in claim 1, wherein said electrical
return (22) comprises a well casing (22) of said well.

11. The petroleum well assembly as claimed in claim 1, wherein said electrical return comprises at least a portion of an earthen ground.
12. The petroleum well assembly as claimed in claim 1, comprising a second induction choke, said second induction choke being located about another part of said electrically conductive portion of said piping structure and at a location along said piping structure such that said electrical connection location for said time-varying current source is located between said induction chokes.
13. The petroleum well assembly as claimed in claim 1, comprising a second packer.
14. The petroleum well assembly as claimed in claim 13, wherein said second packer comprises an electrical insulator so that, said electrically conductive portion of said piping structure is not electrically connected to said electrical return at said second packer when said second packer is operably installed.
15. The petroleum well assembly as claimed in claim 13, wherein said second packer is part of said electrical return.
16. The petroleum well assembly as claimed in claim 1, wherein said packer (40) is located on said source-side of said induction choke (48).
17. The petroleum well assembly as claimed in claim 1, wherein said packer (40) is located on said electrical-retum-side of said induction choke (48).

18. A method of operating a petroleum well assembly comprising:
providing an electrically powered packer (40) in a petroleum well (38);
providing a piping structure (24) in said well (38), said piping structure (24)
comprising an electrically conductive portion extending along at least part of said piping structure (24);
operably installing said electrically powered packer (40) in said well (38), said electrically powered packer (40) comprising an electrically powered device (42), such that said device (42) is electrically connected to said electrically conductive portion of said piping structure (24) when said well (38) is operable for petroleum production;
characterized in that the method comprises:
operably installing an induction choke (48) about part of said electrically conductive portion of said piping structure (24);
supplying time-varying current to said piping structure (24);
routing part of said time-varying current through said electrically powered device (42) using said induction choke (48); and
producing petroleum products with said well (38).
19. The method as claimed in claim 18, comprising the steps of:
measuring a physical quantity with said electrically powered device (42),
wherein said electrically powered device comprises a sensor; and
varying a flow of petroleum products in said well (38) based on said measurements.

20. The method as claimed in claim 18, comprising the step of:
electrically controlling fluid communication between sections of said well (38)
using said packer (40), wherein said electrically powered device (42) comprises an
electrically controllable valve (44).

Documents:

in-pct-2002-1388-che abstract.pdf

in-pct-2002-1388-che assignment.pdf

in-pct-2002-1388-che claims duplicate.pdf

in-pct-2002-1388-che claims.pdf

in-pct-2002-1388-che correspondence others.pdf

in-pct-2002-1388-che correspondence po.pdf

in-pct-2002-1388-che description (complete) duplicate.pdf

in-pct-2002-1388-che description (complete).pdf

in-pct-2002-1388-che drawings.pdf

in-pct-2002-1388-che form-1.pdf

in-pct-2002-1388-che form-18.pdf

in-pct-2002-1388-che form-26.pdf

in-pct-2002-1388-che form-3.pdf

in-pct-2002-1388-che form-5.pdf

in-pct-2002-1388-che pct.pdf

in-pct-2002-1388-che petition.pdf

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Patent Number

208617

Indian Patent Application Number

IN/PCT/2002/1388/CHE

PG Journal Number

26/2007

Publication Date

29-Jun-2007

Grant Date

03-Aug-2007

Date of Filing

03-Sep-2002

Name of Patentee

M/S. SHELL INTERNATIONALE RESEARCH MAATSCHAPPIJ B.V

Applicant Address

Carel van Bylandtlaan 30, NL-2596 HR The Hague

Inventors:

#	Inventor's Name	Inventor's Address
1	HIRSCH, John, Michele	1502 Cedarbrook Drive, Houston, Texas 77055
2	SAVAGE, William, Mountjoy	8446 Ariel, Houston, Texas 77074 (US).
3	VINEGAR, Harold, J.	5219 Yarwell, Houston, Texas 77096
4	BURNETT, Robert, Rex	20711 Flagmore Court, Katy, Texes 77450
5	CARL, Frederick, Gordon, Jr	8406 Edgemoor, Houston, Texas 77036

PCT International Classification Number

E21B47/12

PCT International Application Number

PCT/US2001/06984

PCT International Filing date

2001-03-02

PCT Conventions:

#	PCT Application Number	Date of Convention	Priority Country
1	60/186,375	2000-03-20	U.S.A.