US20020036085A1

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Publication number: US20020036085A1
Application number: US09/769,047
Authority: US
Inventors: Ronald Bass; Harold Vinegar; Robert Burnett; William Savage; Frederick Carl
Original assignee: Individual
Current assignee: Shell USA Inc
Priority date: 2000-01-24
Filing date: 2001-01-24
Publication date: 2002-03-28
Also published as: US20040144530A1; US7055592B2; US20040079524A1

Abstract

An induction choke in a petroleum well where a voltage potential is developed across the choke to power and communicate with devices and sensors in the well. Preferably, the induction choke is a ferromagnetic material and acts as an impedance to a time-varying current, e.g. AC. The petroleum well includes a cased wellbore having a tubing string positioned within and longitudinally extending within the casing. A controllable gas lift valve, sensor, or other device is coupled to the tubing. The valve sensor, or other device is powered and controlled from the surface. Communication signals and power are sent from the surface using the tubing, casing, or liner as the conductor with a casing or earth ground. For example, AC current is directed down a casing or tubing or a lateral where the current encounters a choke. The voltage potential developed across the choke is used to power electronic devices and sensors near the choke. Such induction chokes may be used in many other applications having an elongated conductor such as a pipe, where it is desirable to power or communicate with a valve, sensor, or other device without providing a dedicated power or communications cable.

Description

CROSS-REFERENCES TO RELATED APPLICATIONS

This application claims the benefit of the U.S. Provisional Applications in the following table, all of which are hereby incorporated by reference:[0001]

U.S. PROVISIONAL APPLICATIONS

	Serial
T&K #	Number	Title	Filing Date

TH 1599	60/177,999	Toroidal Choke Inductor	Jan. 24, 2000
		for Wireless Communication
		and Control
TH 1599x	60/186,376	Toroidal Choke Inductor	Mar. 2, 2000
TH 1600	60/178,000	Ferromagnetic Choke in	Jan. 24, 2000
		Wellhead
TH 1600x	60/186,380	Ferromagnetic Choke in	Mar. 2, 2000
		Wellhead
TH 1601	60/186,505	Reservoir Production	Mar. 2, 2000
		Control from Intelligent
		Well Data
TH 1602	60/178,001	Controllable Gas-Lift Well	Jan. 24, 2000
		and Valve
TH 1603	60/177,883	Permanent, Downhole,	Jan. 24, 2000
		Wireless, Two-Way
		Telemetry Backbone Using
		Redundant Repeater, Spread
		Spectrum Arrays
TH 1668	60/177,998	Petroleum Well Having	Jan. 24 2000
		Downhole Sensors,
		Communication, and Power
TH 1669	60/177,997	System and Method for	Jan. 24, 2000
		FluidFlow Optimization
TS6185
	60/181,322	Optimal Predistortion in	Feb. 9, 2000
		Downhole Communications
		System
TH 1671	60/186,504	Tracer Injection in a	Mar. 2, 2000
		Production Well
TH 1672	60/186,379	Oilwell Casing Electrical	Mar. 2, 2000
		Power Pick-Off Points
TH 1673	60/186,394	Controllable Production	Mar. 2, 2000
		Well Packer
TH 1674	60/186,382	Use of Downhole High	Mar. 2, 2000
		Pressure Gas in a Gas Lift
		Well
TH 1675	60/186,503	Wireless Smart Well Casing	Mar. 2, 2000
TH 1677	60/186,527	Method for Downhole Power	Mar. 2, 2000
		Management Using
		Energization from
		Distributed Batteries or
		Capacitors with
		Reconfigurable Discharge
TH 1679	60/186,393	Wireless Downhole Well	Mar. 2, 2000
		Interval Inflow and
		Injection Control
TH 1681	60/186,394	Focused Through-Casing	Mar. 2, 2000
		Resistivity Measurement
TH 1704	60/186,531	Downhole Rotary Hydraulic	Mar. 2, 2000
		Pressure for Valve
		Actuation
TH 1705	60/186,377	Wireless Downhole	Mar. 2, 2000
		Measurement and Control
		For Optimizing Gas Lift
		Well and Field Performance
TH 1722	60/186,381	Controlled Downhole	Mar. 2, 2000
		Chemical Injection
TH 1723	60/186,378	Wireless Power and	Mar. 2, 2000
		Communications Cross-Bar
		Switch

The current application shares some specification and figures with the following commonly owned and concurrently filed applications in the following table, all of which are hereby incorporated by reference:[0002]

COMMONLY OWNED AND CONCURRENTLY

FILED U.S. PATENT APPLICATIONS

T&K #	Ser. No.	Title	Filing Date

TH 1600US	09/_{—————}	Induction Choke for Power	January 24,
		Disribution in Piping	2001
		Structure
TH 1602US	09/_{—————}	Controllable Gas-Lift	January 24,
		Well and Valve	2001
TH 1603US	09/_{—————}	Permanent, Downhole,	January 24,
		Wireless, Two-Way	2001
		Telemetry Backbone Using
		Redundant Repeaters
TH 1668US	09/_{—————}	Petroleum Well Having	January 24,
		Downhole Sensors,	2001
		Communication, and Power
TH 1669US	09/_{—————}	System and Method for	January 24,
		Fluid Flow Optimization	2001

FIELD OF THE INVENTION

The present invention relates to the use of a ferromagnetic choke in a petroleum well where a voltage potential is developed across the choke to power and communicate with devices and sensors in the well.[0003]

DESCRIPTION OF RELATED ART

Several methods have been devised to place Controllable valves and other devices and sensors downhole on the tubing string in a well, but all such known devices typically use an electrical cable along the tubing string to power and communicate with the devices and sensors. It is undesirable and in practice difficult to use a cable along the tubing string either integral with the tubing string or spaced in the annulus between the tubing and the casing because of the number of failure mechanisms present in such a system. Other methods of communicating within a borehole are described in U.S. Pat. Nos. 5,493,288; 5,576,703; 5,574,374; 5,467,083; 5,130,706.[0004]

U.S. Pat. No. 6,070,608 describes a surface controlled gas lift valve for use in oil wells. Methods of actuating the valve include electro-hydraulic, hydraulic, and pneumo-hydraulic. Sensors relay the position of the variable orifice and critical fluid pressures to a panel on the surface. However, when describing how electricity is provided to the downhole sensors and valves, the means of getting the electric power/signal to the valves/sensors is described as an electrical conduit that connects between the valve/sensor downhole and a control panel at the surface. U.S. Pat. No. 6,070,608 does not specifically describe or show the current path from the device downhole to the surface. The electrical conduit is shown in the figures as a standard electrical conduit, i.e., an extended pipe with individual electrically insulated wires protected therein, such that the pipe provides physical protection and the wires therein provide the current path. But such standard electrical conduits can be difficult to route at great depths, around turns for deviated wells, along multiple branches for a well having multiple lateral branches, and/or in parallel with coil production tubing. Hence, there is a need for a system and method of providing power and communications signals to downhole devices without the need for a separate electrical conduit filled with wires and strung along side of production tubing.[0005]

U.S. Pat. No. 4,839,644 describes a method and system for wireless two-way communications in a cased borehole having a tubing string. However, this system describes a downhole toroid antenna for coupling electromagnetic energy in a waveguide TEM mode using the annulus between the casing and the tubing. This toroid antenna uses an electromagnetic wave coupling which requires a substantially nonconductive fluid (such as refined, heavy oil) in the annulus between the casing and the tubing and a toroidal cavity and wellhead insulators. Therefore, the method and system described in U.S. Pat. No. 4,839,644 is expensive, has problems with brine leakage into the casing, and is difficult to use as a scheme for downhole two-way communication.[0006]

Other downhole communication schemes such as mud pulse telemetry (U.S. Pat. Nos. 4,648,471; 5,887,657 have shown successful communication at low data rates but are of limited usefulness as a communication scheme where high data rates are required or it is undesirable to have complex, mud pulse telemetry equipment downhole. Still other downhole communication methods have been attempted, see U.S. Pat. Nos. 5,467,083; 4,739,325; 4,578,675; 5,883,516; and 4,468,665 as well as downhole permanent sensors and control systems: U.S. Pat. Nos. 5,730,219; 5,662,165; 4,972,704; 5,941,307; 5,934,371; 5,278,758; 5,134,285; 5,001,675; 5,730,219; 5,662,165.[0007]

It would, therefore, be a significant advance in the operation of petroleum wells if the tubing, casing, liners and other conductors installed in the well could be used for the communication and power conductors to control and operate devices and sensors downhole in a petroleum well.[0008]

Induction chokes have been used in connection with sensitive instrumentation to protect against surges and stray voltage. For example, most personal computers have some sort of choke incorporated into its AC power cord and video signal cable for such protection. Such protection chokes work well for their intended purpose, but do not operate to define a power or communication circuit.[0009]

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 the knowledge of one of ordinary skill in the art.[0010]

SUMMARY OF THE INVENTION

The problems outlined above are largely solved and met by a petroleum well having one or more ferromagnetic chokes in accordance with the present invention. Broadly speaking, the petroleum well includes a cased wellbore having a tubing string positioned within and longitudinally extending within the casing. A controllable valve, sensor, or other device is coupled to the tubing. The valve sensor, or other device is powered and controlled from the surface. Communication signals and power are sent from the surface using the tubing, casing, or liner as the conductor. For example, AC current may be directed down the tubing to a point where the current encounters a choke. The voltage potential developed across the choke is used to power communication modems, valves, electronic devices and sensors near the choke.[0011]

In more detail, a surface computer includes a modem with an AC signal imparted to a conductive conduit, such as the tubing or casing. The AC signal develops a potential across a choke and a power supply creates DC voltage to power a connected controllable valve, sensor, or other device. Preferably, the casing or liner terminates at earth and is used as the ground return conductor, although an independent ground wire may be used. In a preferred embodiment, the powered device comprises a controllable valve that regulates passage of gas between the annulus and the interior of the tubing.[0012]

In enhanced forms, the petroleum well includes one or more sensors downhole which are preferably in contact with the downhole power and communications module and communicate with the surface computer. Such sensors as temperature, pressure, acoustic, valve position, flow rates, and differential pressure gauges are 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 gas flow through the valve.[0013]

Such ferromagnetic chokes are coupled to a conductor (tubing, casing, liner, etc.) to act as a series impedance to current flow. In one form, a ferromagnetic choke is placed around the tubing or casing downhole and the AC used for power and communication signal is imparted to the tubing, casing or liner near the surface. The downhole choke around the tubing, casing or liner develops a potential used to power and communicate with a controllable valve or sensor.[0014]

In another form, a surface computer is coupled via a surface master modem and the tubing or casing to a plurality of laterals, each having a downhole slave modem to operate a controllable valve in a lateral. The surface computer can receive measurements from a variety of sources, such as the downhole sensors, measurements of the oil output, and measurements of the fluid flow in each lateral. Using such measurements, the computer can compute an optimum position of each controllable valve, more particularly, the optimum amount or composition of fluid production from each lateral. Additional enhancements are possible, such as controlling the amount of compressed gas input into the well at the surface, controlling a surfactant injection system, and receiving production and operation measurements from a variety of other wells in the same field to optimize the production of the field.[0015]

Construction of such a petroleum well is designed to be as similar to conventional construction methodology as possible. That is, the well completion process comprises cementing a casing or liner within the borehole, placing production tubing within the casing or liner and generally concentric with such casing or liner, and placing a packer above the production zone to control fluid passage in the annulus between the tubing and the casing or liner. The completed well includes a choke concentric with the tubing, casing or liner. After cementing the well the casing is partially isolated from the earth. The tubing string passes through the casing and packer and communicates with the production zone. In the section of the tubing string near the choke, sensors or operating devices are coupled to the string. With such configuration a controllable gas lift valve or sensor pod may be directly permanently coupled to the tubing (i.e. “tubing conveyed”). Alternatively, , a controllable gas lift valve or sensor pod may be inserted in a side pocket mandrel. A power and communications module uses the voltage potential developed across the choke to power the valve and sensors.[0016]

A sensor and communication pod can be inserted without the necessity of including a controllable gas lift valve or other control device. That is, an electronics module having pressure, temperature or acoustic sensors, power supply, and a modem is inserted into a side pocket mandrel for communication to the surface computer using the tubing and casing conductors. Alternatively, such electronics modules may be mounted directly on the tubing and not be configured to be wireline replaceable. If directly mounted to the tubing an electronic module or a device may only be replaced by pulling the entire tubing string. In another form, an insulated tubing section near the wellhead may be used to ensure electrical isolation.[0017]

In one broad aspect, the present invention relates to a current impedance device, particularly useful in petroleum wells, comprising a cylindrical choke of ferromagnetic material having an annular bore extending longitudinally therein and adapted for receiving petroleum well cylindrical conductor therein. Many modifications are, of course possible, with such ferromagnetic chokes being applicable to casing, tubing, liners, and headers and other conductors used downhole in a petroleum well.[0018]

BRIEF DESCRIPTION OF THE DRAWINGS

Other objects and advantages of the invention will become apparent upon reading the following detailed description and upon referencing the accompanying drawings, in which:[0019]

FIG. 1 is a schematic of a petroleum well illustrating the general disposition of the major elements of the present invention in relation to the major elements of a conventional well;[0020]

FIG. 4[0023]ais related to FIG. 2, and shows the overall assembly of one of the chokes of FIG. 1;

FIG. 4[0024]bis related to FIG. 4a,and shows in detail the components used in the construction of the choke assembly of FIG. 4a;

FIG. 5[0025]ais an axial cross-section of a choke showing variables used in the design analysis of a choke disposed between tubing and casing;

FIG. 5[0026]bis a radial cross-section of a choke showing variables used in the design analysis of a choke disposed between tubing and casing;

FIG. 5[0027]cis an axial cross-section of a choke showing variables used in the design analysis of a choke external to both tubing and casing;

FIG. 5[0028]dis a radial cross-section of a choke showing variables used in the design analysis of a choke external to both tubing and casing;

FIG. 6 is a schematic of a multilateral petroleum well incorporating electrical chokes of the present invention;[0029]

FIG. 7[0030]ais a schematic of a petroleum well illustrating downhole equipment power and communications connections in electrical series;

FIG. 7[0031]bis a schematic of a petroleum well illustrating downhole equipment power and communications connections in electrical parallel;

FIG. 7[0032]cis a schematic of a switching circuit enabling reconfiguration of downhole power and communications connections;

FIG. 8 is a schematic of a petroleum well illustrating the control of power and communications zones by the use of chokes of the present invention;[0033]

FIG. 9 shows a system in accordance with another embodiment of the present invention, in which chokes are disposed external to the well casing;[0034]

FIG. 10 shows a system in accordance with another embodiment of the present invention, in which a single choke is disposed to direct power into a lateral;[0035]

FIG. 11 shows a system in accordance with another embodiment of the present invention, in which two chokes are disposed to direct power into a lateral;[0036]

FIG. 12 shows a system in accordance with another embodiment of the present invention, in which chokes are disposed on a pump rod;[0037]

FIG. 13 is alternative embodiment to FIG. 12; and[0038]

FIG. 14 is a schematic showing the use of chokes to provide electrical power and communications between a central field facility and individual well heads using collection lines as the transmission path.[0039]

DESCRIPTION OF PREFERRED EMBODIMENTS

Referring now to the drawings, wherein like reference numbers are used to designate like elements throughout the various views, several embodiments of the present invention are further described. The figures are not necessarily drawn to scale, and in some instances the drawings have been exaggerated or simplified 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.[0040]

The terms “first end” and “second end” as used herein are defined generally to call out a side or portion of a piping structure, which may or may not encompass the most proximate locations, as well as intermediate locations along a called out side or portion of the piping structure. Similarly, in accordance with conventional terminology of oilfield practice, the descriptors “upper”, “lower”, “uphole” and “downhole” refer to distance along hole depth from the surface, which in deviated wells may or may not accord with absolute vertical placement measured with reference to the ground surface.[0041]

FIG. 1 shows a system defining an electrical circuit for providing power and/or communications in a well or borehole via a piping structure by using one or more unpowered induction chokes in accordance with a first embodiment of the present invention. The system of the first embodiment comprises an electrically[0042]

resistive device

146, anunpowered induction choke32, an electricallyconductive piping structure34, a well casing36, a source of time-varying current38, and adevice pod40.

A piping structure can be one single pipe, a tubing string, a well casing, a pumping rod, a series of interconnected pipes or rods, a branch or lateral extension of a well, or a network of interconnected pipes. 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 longitudinal extending electrically conductive portion combined with a longitudinally extending non-conductive or partially resistive portion. In other words, an electrically conductive piping structure is one that provides an electrical conducting path from a first end where a power source is electrically connected to a second end 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.[0043]

In the first embodiment shown in FIG. 1, the piping structure comprises a[0044]

production tubing string

34 for a well, which is typically steel tubing. The system has an electrical impedingdevice146 located about thetubing34 along afirst end41 near the surface.Device146 may consist of an electrically insulating joint as shown in FIG. 1, or an unpowered choke of the present invention. Alower choke32 is located about the tubing along asecond end42 downhole within the well. The source of time-varying current38 is electrically connected to thetubing34 between the impeding

devices

30,32. The time-varying current can be alternating current (AC) or a varying direct current (DC), but AC is typically more practical in use. AC power and communications signals from thesource38 are connected byconductor44 to thetubing34 via an insulatingfeedthrough76. Thedevice40 comprises two

terminals

51,52. A device terminal is defined generally as an electrical connection point for a device, which may include but is not limited to: a wire, a device enclosure, a prong, a pin, a contact pad, a solder point, a female receptacle, a shaft, or any combination thereof. Afirst device terminal51 is electrically connected to thetubing34 downhole between the connection location for the source of current38 and thelower choke32.

A[0045]

second device terminal

52 is also electrically connected to thetubing34, but at a location on the opposite side of thelower choke32 relative to the electrical connection location for thefirst device terminal51. As described further below with equations, a voltage potential exists across thechoke32 when a time-varying current flows through the tubing. Hence, thedevice40 is electrically connected across the voltage potential on the tubing developed by thechoke32 when AC flows in thetubing34, which provides current flow through thedevice40.

[0046]

Device

146 may consist of an electrically insulating joint hanger, or a choke in accordance with the present invention. While electrically insulating joint hangers provide true electrical isolation, they must sustain significant mechanical loads on insulating materials such as plastics or ceramics, and are therefore subject to damage from those loads. Chokes cannot provide complete isolation, but are able to sustain high mechanical loads since they are constructed such that all the load-bearing elements are composed of metal.

At least a portion of the[0047]

well casing

36 is electrically conductive. The electrically conductive portion of thewell casing36 is electrically connected to the tubing34 (e.g., viaconductive fluid82 and/or packer56) and the source of current38. Hence, the electrically conductive portion of the well casing36 acts as part of an electrical return to complete the electrical circuit.

Where centralizers are used to control the position of the[0048]

tubing

34 relative to thecasing36, such centralizers which are disposed between

devices

30 and32 must not be electrically conductive. Suitable centralizers are typically composed of molded or machined plastic.

Therefore, the electrical circuit is formed by the system of the first embodiment, wherein the time-varying current (e.g., AC) can flow from the[0049]

power source

38 to thetubing34, along thetubing34 between thedevice146 and thechoke32, through thedevice40 to thetubing34 below thelower choke32, to thecasing36 via thepacker56 and/or theconductive fluid82, and along the well casing36 to thesource38 to complete the electrical circuit. Thus, thedownhole device40 can receive power, as well as send/receive communication signals, using thetubing34 between the upper and

lower devices

146,32 as one of the primary conductors and as a power and/or communications path.

In the application of the first embodiment shown in FIG. 1, the gas-lift oil well extends from the[0050]

surface

64 through a borehole and extends into aproduction zone66 downhole. Aproduction platform68 is schematically illustrated above thesurface64. Ahanger54 supports theproduction tubing string34 from thewell casing36. Thecasing36 is conventional, i.e., it is typically metal tubing held in place by injectingcement70 between the casing and the earth in the borehole during well completion. Similarly thetubing string34 is generally conventional comprising a plurality of elongated tubular metal production pipe sections joined by threaded couplings (not shown) at each end of each tubing section.

A[0051]

gas input throttle

74 is employed to permit the input of compressed gas into thetubing34 via one or more valves contained withinpod40 for lifting oil during production. Schematically illustrated is a computer system andpower source38 at thesurface64 with power and communication feeds44 passing through electrically isolatingpressure seal76 and usingreturn connection78, which is electrically connected to thecasing36. The degree of opening of gas lift valve may be controlled by means of setpoint commands sent by communication from the surface modem to the downhole modem and interpreted by a downhole control interface for the motor of the gas lift valve. Sensor readings from the downhole pod may either be processed locally within the pod to provide autonomous control, or the sensor readings may be conveyed to the surface by means of the communications between the downhole and surface modems, for analysis at the surface.

The[0052]

choke

32 is unpowered and made from a material having a high magnetic permeability (e.g., a relative permeability of 1000 to 150,000), such as a ferromagnetic metal alloy or a ferrite. Thechoke32 is electrically insulated from thetubing34 and acts to create a reactive impedance to AC flow in the tubing. In the case where theupper device146 is a choke (rather than an electrically insulating joint), its action and construction is essentially the same as thelower choke32. The choke32 (and146 in the case where it is a choke) are mounted concentric and external to thetubing34 and are typically coated with shrink-wrap plastic to provide electrical insulation, and may additionally be enclosed within an epoxy or other structurally equivalent shell (not shown) to withstand rough handling and corrosive conditions. As described in the mathematical analysis below, the size and material of chokes can be chosen to achieve a desired series impedance value. FIG. 2 illustrates in greater detail the preferred embodiment of the invention outlined in FIG. 1 as it is applied to a gas-lift oil well. FIG. 2 illustrates such a well consisting ofcasing36 extending from the surface and containingproduction tubing34. At the well head the upper portion of the production tubing is electrically isolated from the lower portion by means of an electrically insulatingjoint hanger146. At depth within the well the annular space betweencasing36 andtubing34 containscompletion fluid82, and an electricallyconductive packer56 which hydraulically isolates the completion fluid from theproduction zone66. Fluids from theproduction zone66 are conveyed to the surface by passage through theproduction tubing34. In FIG. 2 the disposition of twochokes32 are shown at depth within the well, each of which is used to powerelectrical pods40. These pods implement any combination of communication, measurement and control functions to assist well production operations.

Referring still to FIG. 2, the general disposition of surface equipment is illustrated, consisting of an[0053]

AC power source

48, a 1:10power transformer86, and amodem39. One output side of the surface power transformer and modem circuits are connected by means ofconductor44 through a pressure sealedelectrical isolation feedthrough76 to the production tubing section below the electrically isolating hanger. The other output sides of the power transformer and the surface master modem circuits are electrically connected to the well casing.

FIG. 2 shows each pod being used to power and control a motorized[0054]

gas lift valve

24. For this purpose a suitable implementation of the pod consists of apower transformer111 with a winding ratio such that 2 Volts on the tubing side creates 15 Volts on the electronics module side (and vice versa), and a main printed circuit board (PCB)112 having amodem122 and other electrical components to power and control the motorizedgas lift valve24. The downhole modems within the pods communicate with the modem at the surface, and possibly with each other, allowing data to be transferred from each pod to the surface or between pods, and instructions to be passed from the surface to control each gas lift valve. Each modem is individually addressable, and each control or sensor device within each pod is individually addressable.

While FIG. 2 illustrates the case where two downhole modules are operated in the well, it will be readily apparent that the same principle may be used to provide an arbitrary number of downhole modules. This is useful in an application where a[0055]

conductive completion fluid

82 is present in the annulus before unloading a gas-lift well. Each choke will not work sufficiently to develop a voltage potential at its respective device when the choke is submerged in conductive fluid, but as the conductive fluid is progressively removed during the unloading process, each device can receive power and/or communications (thus being controllable) when the respective choke is no longer submerged in conductive fluid. Hence, as the conductive fluid level drops during unloading, the devices sequentially become controllable, which aids in achieving a more controlled unloading procedure.

Referring to FIG. 3, the electrical equivalent circuit of the power and communications path of FIG. 2 may be analyzed. The casing and tubing form the major transmission paths for both the power and communication signals. The casing is represented by the[0056]

conductor

101. The tubing is represented byconductor102.Resistor218 represents the combined distributed resistance offered by casing and tubing, and is typically of the order of 1 Ohm. The choke impedances are represented byinductors32. At the frequency of the AC power the reactive impedance offered by each choke is of the order of 2 Ohms.

Referring still to FIG. 3, the[0057]

surface modem ensemble

39 is represented byresistor212 for its receiver, and anAC source214 for its transmitter. AC power input at the surface is represented byAC source216. The downhole electronic pods associated with each choke are represented by power converter andmodem ensembles122, composed ofresistors106 for the power converters and modem receivers, andAC sources108 for the modem transmitters. The circuit is completed by themetal packer56 which has a negligibly small electrical impedance.

It is seen from FIGS. 2 and 3 that the downhole pods are powered by the AC voltage developed on the tubing by each choke, caused by the back-EMF created by the passage of current along the tubing which passes through the choke. The chokes are designed to develop about 2 Volts from the AC which passes through them, and this AC is converted to DC in the power conditioning circuit which is coupled through the power supply input transformer, following standard practice for such AC-to-DC power conversion and conditioning circuits. This DC power is typically supplied to the pod sensors, modem, and control circuits at about 15 Volts, and of the order of 10 Watts is typically available to power these downhole sub-systems.[0058]

Referring to FIG. 4[0059]a,the construction of a suitable choke may be described. A choke for a given application may be divided into multiple sub-sections along its length (L). In other words, stacking multiple sub-sections ofchokes134 together along thechoke axis60, as shown in FIGS. 4aand4b,provides the same effect as have one large choke of length (L).Multiple sub-sections134 stacked on top of one another act as a series of impedances, which added together provide the same total impedance as a single choke having the same total length of ferromagnetic material as the aggregated sub-sections.

Referring to FIG. 4[0060]b, the details of a suitable choke assembly are illustrated, though it will be clear to one familiar with the art that alternative designs are feasible. Thetubing section34 is composed of type 316 stainless steel and typically has an outer diameter of 3.5 inches and a length of 10 feet. Each end of theproduction tubing section34 is furnished with New VAM male threads by which mating sections of conventional production tubing are attached. (New VAM is a registered Trademark of Vallourec Mannesman Oil & Gas France, and defines a thread form suitable for this purpose). At the upper and lower extremities of the choke section are weldingcollars50 with internal diameter 3.55 inches, length 2 inches, and wall thickness one quarter of an inch. The section oftubing34 between the welding collars is covered with PTFE heat-shrink tubing20 of 0.020 inches wall thickness, and thustubing20 lies between theproduction tubing section34 and the internal walls of all thechoke sub-sections134. Each end of the choke assembly is furnished with a machinedplastic centralizer114. A suitable machinable plastic is polyetheretherketone (PEEK) which is a commodity material available from many commercial sources.

Choke[0061]

sub-sections

134 are formed by winding about 60 sheet laminations of a high-permeability ferromagnetic alloy such as Permalloy (Permalloy is a registered Trademark, of Western Electric Company). Permalloy is a nickel/iron alloy with a nickel content in the range 35% to 90% and is available as a commodity material from many commercial sources. A suitable alloy is composed of 86% nickel/14% iron, and the laminations are 0.014 inches thick and 2.35 inches wide such that the final dimensions of each choke section are 3.6 inches internal diameter, 5.45 inches external diameter, and 2.35 inches in the direction of thechoke axis60. The laminating material is coated with a non-conductive material such that adjacent laminations are electrically isolated from each other, as in standard transformer construction practice. Fifteen such choke sections are stacked to form a total choke assembly suitable for usual power frequencies, 50 or 60 Hertz. At power frequencies up to a few hundred Hertz, the laminated ferromagnetic alloy construction can be used for the choke sections, as in standard transformer design practice, and as described above. Lamination is required to reduce eddy current losses which would otherwise degrade the effectiveness of the choke. For material with absolute magnetic permeability of 50,000 operating at 60 Hertz the required lamination thickness for 2 skin depths is 0.8-millimeters (0.031 inches), which is realistic and practical.

Between each choke section is a polytetrafluoroethylene (PTFE)[0062]

washer

136 with internal diameter 3.6 inches, external diameter 5.45 inches, and thickness 0.030 inches. After all the chokes are threaded onto the tubing, the entire section of chokes is covered withPTFE heatshrink tubing138 having 0.020 inches wall thickness. Thestainless steel rod51 is 0.125 inches diameter covered with polyethylene (PE) heat-shrink tubing and extends along the length of the completed choke assembly. It is attached to theupper welding collar50 and passes through holes in thecentralizers114. Its lower end is electrically connected to the input of the electrical pod which is below the choke assembly.

The impedance offered by the choke is a critical implementation issue, since this determines what proportion of total power supplied to the pipe will be lost to leakage through the choke, and what proportion will be available to power and communicate with the devices installed in the isolated section of the pipe. Since the impedance presented by an inductor increases with frequency, the AC power frequency is used in both the theoretical analysis and the testing of alternative choke configurations, as this is normally equal to or lower than the communication frequencies.[0063]

FIGS. 5[0064]a-dindicate the parameters used in the choke design analysis. FIGS. 5aand5billustrate the case where the choke is placed within theannulus58 between thetubing34 and thecasing36. FIGS. 5cand5dillustrate an alternative case where the choke is placed outside thecasing36. The basis for the analysis is the same in both cases, but it is important to realize that the electrical current value (I) used in the design analysis is the net current linked by the choke. In the case where the choke is disposed in the annulus58 (FIGS. 5aandb), the current is that on the tubing alone. When the choke is disposed external to the casing (FIGS. 5cand5d), the current is the vector sum of the separate currents on the casing and tubing. Thus if these currents were to be equal but opposite in phase there would be no net choking effect with the configuration shown in FIGS. 5cand5d.

The defining variables and a self-consistent set of physical units are:[0065]

L=length of choke, meters;[0066]

a=choke inner radius, meters;[0067]

b=choke outer radius, meters;[0068]

r=distance from choke axis, meters;[0069]

I=r.m.s. net current through choked section, Amperes;[0070]

ω angular frequency of leakage current, radians per second;[0071]

absolute magnetic permeability of choke material at radius r, equal to the absolute permeability of free space (4π×10[0072]⁻⁷Henrys per meter) multiplied by the relative permeability of the magnetic material of the choke.

By definition, ω=2πf where f=frequency in Hertz.[0073]

At a distance r from the current I, the r.m.s. free space magnetic field H, in Henries per meter, is given by:[0074]

H=I/r

The field H is circularly symmetric about the choke axis, and can be visualized as magnetic lines of force forming circles around that axis.[0075]

For a point within the choke material, the r.m.s. magnetic field B, in Teslas, is given by:[0076]

B=H =μI/2πr

The r.m.s. magnetic flux F contained within the choke body, in Webers, is given by:[0077]

F=∫B dS

where S is the cross-sectional area of the choke in square meters as shown in FIGS. 5[0078]aand5cand the integration is over the area S. Performing the integration from the inner radius of the choke (a), to the outer radius of the choke (b), over the length of the choke (L), we obtain:

F=μLI ln(b/a)/2π

where ln is the natural logarithm function.[0079]

The voltage generated by the flux F, ln Volts, is given by:[0080]

V=ωF=2πf F=μLIf ln (b/a)

Note that the back-e.m.f. (V) is directly proportional to the length (L) of the choke for constant values of (a) and (b), the choke element internal and external radii. Thus by altering the length of the choke, any desired back-e.m.f. can be generated for a given current.[0081]

Inserting representative values:[0082]

μ=50,000×(4π×10⁻⁷), L=1 meter, I=10 Amperes, f=60 Hertz,

a=0.045 meters (3.6 inch inner diameter), b=0.068 meters (5.45 inch external diameter):[0083]

then the back−e.m.f. developed V=2.6 Volts[0084]

showing that such a choke is effective in developing the required downhole voltage, and does so when realistic and safe currents and voltages are impressed upon the tubing and transmitted from the well head to downhole equipment.[0085]

FIG. 6 shows a petroleum well application of a second embodiment in accordance with the present invention for a multilateral completion. The second embodiment is similar to the first embodiment in that the piping structure comprises the[0086]

production tubing

34 but the electrical return comprises theearth72 and thecasing36. Themain borehole87 branches into fourlaterals88. Thesource38 comprises a computer system having an AC power source and a modem. As long as a time-varying current is output to the electrical circuit, thesource38 may comprise any variety of electronic components, including but not limited to: a computer system, a modem, a power supply, a software program for analyzing data, a software program for controlling downhole devices, or any combination thereof. Thesource38 is electrically connected at afirst end41 of themain borehole87 between an upper choke or insulating tubing joint30 and alower choke32. Thelower choke32 is located at the downhole end of themain borehole87, below the branch points of the laterals. Thelower choke32 routes the current flowing in thetubing34 of themain borehole87 into thetubing34 in thebranches88. Anadditional choke31 is located within each lateral branch88 (details of only two branches shown). Current is directed through adevice40 and across the voltage potential formed at eachchoke31 within eachlateral branch88. As shown in FIG. 6, thetubing34 is electrically connected to theearthen ground72 at various places to complete the circuit stemming from each choke (30,31,32).

Each[0087]

device

40 comprises acontrol module110,sensors120, amodem122, anelectric motor124, and an electricallycontrollable valve126. Thecontrol module110 receives power and/or communications from thetubing34, which it uses to provide power, control, and communications for thesensors120,modem122, andelectric motor124. Thecontrol module110 can contain various logic structures for closed loop control of thevalve126 based on measurements taken by thesensors120. In this example, there is a pressure sensor, a temperature sensor, and a flow sensor. However, other types ofsensors120 can also be used or substituted (e.g., acoustic sensor, chemical composition sensor). Themodem122 in thedevice40 can send data from thesensors120 to the computer system at thesurface64. Also, themodem122 can receive control signals from the computer system via the modem in thesource38. Thecontrol module110 provides power and control for theelectric motor124, which is capable of operating with low current. Theelectric motor124 is used to open, close, or adjust thevalve126. Eachcontrol module110 for eachlateral branch88 can be separately addressable, eachsensor120 can be separately monitored, and eachvalve126 can be independently operated. Hence, using a system incorporating the third embodiment, eachvalve126 in eachlateral branch88 can be electrically controlled to manage the fluid flow from each lateral.

ALTERNATIVE EMBODIMENTS

It will be clear to those skilled in the art that the effect of the chokes in offering an impedance to AC current flow can be exploited in a variety of ways as alternative embodiments for the provision and distribution of power along the metal structures of wells.[0088]

FIGS. 7[0089]aand7billustrate an alternative configuration for the power supply and communications circuits which would be used in cases where a plurality ofdownhole pods40 are needed. It will be apparent that the configuration of FIG. 7ais based on the basic configuration illustrated in FIGS. 1 and 2. The power and communications connections from eachpod40 have an associatedchoke31, and the power and communication AC signals are in series as shown in the equivalent circuit illustrated in FIG. 3. FIG. 7bshows an alternative configuration where the tubing between uphole choke or insulating tubing joint30,anddownhole choke32, is a common power supply and communications connection for all thepods40 between

devices

30 and32. The power and communications signal return connections are all made to the casing using a slidingcontactor52 between each pod and thecasing36. Thus the power and communications connections are in this case in electrical parallel, as contrasted with the series connections of FIG. 7a.The parallel configuration of FIG. 7bhas the advantage that the voltages needed to supply power to a plurality of downhole pods are not additive, and thus the applied voltage atconnector44, needed to operate a plurality of pods, will not exceed a safety limit, typically taken as 24 Volts. The parallel configuration has the disadvantage that the theannulus58 must be cleared ofconductive fluids82 to a level below thelowermost choke32 as shown in FIG. 7b.

A combination of the configurations of FIGS. 7[0090]aand7bis possible, and a system that provides dynamic switching between the embodiments of FIGS. 7aand7bis shown in FIG. 7c.As shown in the figure, the input to the pod powersupply input transformer111 is connected through two

switches

104 and105. The settings of these switches are controlled by commands sent from the surface and received by the modem of the pod. The switches allow power routing within the pod to be reconfigured. With the

switches

104 and105 set as indicated in FIG. 7c,thetransformer111 is powered from the potential developed on tubing section above and belowchoke32. This state thus corresponds to the series connection for a pod as illustrated in FIG. 7a.Whenswitch105 is set to to its other state, power is routed to theinput transformer111 from thetubing section34 above thechoke32, but is returned to thecasing36 throughswitch105 and the slidingcontactor connection52 to thecasing36. This corresponds to the parallel power configuration of FIG. 7b.

Switch

104 is optional but is desirable in certain applications, since it allows current to flow around thechoke32 when the switch is closed, and therefore in this state the choke ceases to impede current flow intubing34, and thus allows this current to flow without impediment to devices lower in the well.

The ability to reconfigure power routing to multiple downhole pods as shown in FIG. 7[0091]cmay be applied, for instance, to the unloading of a gas lift well where the casing/tubing annulus58 is filled with conductive fluid at the start of unloading. In this case, each downhole pod controls a gas lift valve as illustrated in FIG. 2. Initially all the pods are set to the series power configuration. As the unloading proceeds the conductive fluid level is driven past each pod, which then becomes powered and controllable. When the conductive fluid level has fallen below a pod itsswitch105 may be set to the parallel power configuration. When the fluid level has passed the next pod in sequence downhole,switch104 may be configured to remove the current impeding effect of the upper pod choke, and both pods then draw power from the potential on the tubing developed by the action of the lower pod choke. By this method, as the unloading sequence progresses, the pods are progressively switched to parallel connection, and the voltage required to be applied at the wellhead may be kept low, which is desirable for the safety of personnel.

FIG. 8 shows an alternative embodiment of the present invention, allowing power to be applied selectively to separate zones within a well, where each zone may contain one or more downhole pods. As an example, FIG. 8 illustrates a gas lift well with a plurality of[0092]

chokes

30,31,32, and associateddownhole pods40. As shown in the choke design analysis already described by reference to FIGS. 5a-d,the effect of the choke in impeding AC flow is dependent linearly on the frequency of the AC and the length dimension of the choke (L), all other parameters being held equal. In the well of FIG. 8, chokes30 and32 are designed and constructed to impede current flow at low frequencies, forinstance 60 Hertz, and chokes31 are designed to effectively impede current flow only at a significantly higher frequency, for instance 400 Hertz. Following the example given in the design analysis, this may be accomplished by using 15 choke subsections (132 of FIG. 4b) for

chokes

30 and32, but only 3 such choke subsections forchokes31. With such a disposition of choke sizes, 60 Hertz AC supplied from thesurface equipment38 will energize only the lowest pod associated withchoke32, sincechokes30 will develop insufficient voltage on their associated tubing sections to energize their associated pods. When the AC applied bysurface equipment38 is at 400 Hertz, all the pods will be energized, since all of the chokes are able to develop sufficient potential on their associated tubing section to activate their associated pods. In the case of the gas lift well of FIG. 8 this may aid in the transition from the unloading process to the production process. Since all the gas lift valves are used during the unloading sequence, the AC supplied at the wellhead is 400 Hertz during unloading. Only the lowermost valve, associated withchoke32, is needed during production, so when the unloading has been completed the AC power frequency may be switched to 60 Hertz, so that only the lowermost pod and valve are powered.

There exists a constraint on this zone power selection method. Pods lower in the well must respond to lower applied AC frequency, and pods higher in the well must respond to higher AC frequency, so that the AC impeding effect of the upper chokes does not significantly prevent power from flowing to the lower chokes.[0093]

FIG. 9 shows a petroleum well application in accordance with another embodiment of the present invention, where the chokes are external to the casing. In this embodiment, the piping structure used to carry the electrical current for the[0094]

downhole device

40 comprises thecasing36, which is a conductive metal tubing in this case, and the electrical return comprises theearthen ground72. Thus, in this embodiment, the

chokes

30,32 are located about thecasing36 rather than being located only about thetubing34 as in the embodiments described previously. In this embodiment, the current flows from thepower source38 to thecasing36 below theupper choke30, along thecasing36 to a first device terminal51 (due to the upper choke30), through the device40 (due to a voltage potential developed across the lower choke32) to theearth ground72 via thecasing36 below thelower choke32, and back to thesource38 via the earthen ground72 (and vice versa because AC).

In the choke design analysis previously described with reference to FIGS. 5[0095]c-d,current in both thecasing36 and thetubing34 is impeded by a choke such as30 or32 of FIG. 9 since currents on both the casing and the tubing link the choke. The tubing cannot be used as the current return path for power applied to the casing since the magnetic fields from the supply and return currents would balance within the chokes, which would become ineffective. It is for this reason that that theground return path72 is necessary.

The potential developed on the casing across the[0096]

choke

32 is connected by

electrical conductors

51 and52 to power and communicate with aninstrument pod40 located external to the casing.

Chokes

30,32, and theinstrument pod40, are set in the well with the casing and before thecement70 is injected. As in the previous embodiments theinstrument pod40 may provide bidirectional communication through a modem to return data to the surface from sensors to measure conditions such as formation pressure, temperature, acoustic signals etc connected topod40, and to accept control commands from the surface.

FIG. 10 shows a petroleum well application in accordance with another embodiment of the present invention This embodiment provides a means to divert power and/or communications signals into the casing or liner of a lateral. Power and/or communications signals are conveyed on the casing of the main well bore using the same disposition of surface equipment as in FIG. 9. The main well bore is furnished with upper and[0097]

lower packers

56.Choke32 is external to themain wellbore casing36. The electrical potential developed in the casing bychoke32 acts to divert current and/or communications signals from the main wellbore casing36 onto the casing or liner of the lateral88. By this means power is made available topods40 external to the lateral casing or liner using the same method as the downhole pod illustrated in FIG. 9.

FIG. 11 shows a petroleum well application in accordance with another embodiment of the present invention. This embodiment provides an alternative means to route power and/or communications signals to the casing or liner of a lateral[0098]88. Power and/or communications signals are supplied from the source at the surface through anarmored cable140. Thecable140 is set within thecement70 between thecasing36 and theearth72, and it is routed outside of anupper choke30. In this example, theupper choke30 is at thesecond end42 of themain borehole87 just above thelateral branch88. However,upper choke30 may be placed anywhere along thecasing36 between the surface and thebranch point70 of the lateral88. Anupper packer142 in themain borehole87 is located between theupper choke30 and thelateral branch88, and theupper packer142 electrically connects thetubing34 andcasing36. Thetubing34 andcasing36 above theupper choke30 electrically lead back to theearthen ground72. Because thecable140 is electrically connected to thecasing36 below theupper packer142 and theupper choke30, the current travels in the same direction at any given time within both thetubing34 andcasing36 at theupper choke30. Hence, theupper choke30 impedes current from flowing through thetubing34 andcasing36 at the upper choke. Similarly, alower packer144 in themain borehole87 is located between thelateral branch88 and alower choke32, and thelower packer144 electrically connects thetubing34 to thecasing36. Thetubing34 andcasing36 also electrically lead to theearthen ground72 below thelower choke32. Hence, thelower choke32 impedes current from flowing through thetubing34 andcasing36 at the lower choke. Thus, AC flowing through thecable140 is routed into thetubing34 andcasing36 within thelateral branch88. By this means power is made available to a pod external to the lateral casing or liner using the same method as the downhole pod illustrated in FIG. 9.

Many of the examples described thus far have focused on gas lift petroleum wells. However, a rod pumping artificial lift or “sucker rod” oil well may also incorporate the present invention. FIGS. 12 and 13 show a petroleum well in accordance with another embodiment of the present invention. In this embodiment, the piping structure for carrying current to a[0099]

device

40 downhole comprises apumping rod100 of a rod pumping artificial lift oil well, and the return is on thecasing36. If rod guides are required to prevent therod100 from touching the casing, they must be electrically insulating.

FIG. 14 illustrates an embodiment using the methods of the present invention in the case where it is desired to locate the surface power and communications equipment at a distance from the well head. The power and communications elements located at the[0100]

central field facility

201 comprisecollector tubing234, achoke230, an AC power source248, the modem receiver represented by itsinput impedance212, and the modem transmitter represented by itsAC generator214. One side of the power and modem elements is connected to ground72, and the other side is connected to thecollector tubing234.

Referring still to FIG. 14, the[0101]

collector tubing

234 extends from thecentral facility201 to thewellhead location202. At the wellhead the collector tubing is furnished withchoke230, and anelectrical cable240 carries the power and communications AC through the insulatingfeedthrough276 to the production tubing below the well upper choke. By this means the power and communications ACs are not required to pass over the section of production tubing where it passes into the well. In standard well construction practice this section of thetubing234 is electrically connected to thecasing236 at the point where it passes through thetubing hanger254, and in this case the separateelectrical connection240 is required. If non-standard construction practice is acceptable, then the use of electrically isolating tubing joints and feedthroughs may eliminate the need for theseparate conductor240 and its associated chokes.

At[0102]

depth

203 in the well, theproduction tubing234 is furnished with achoke232 and anelectrical pod210. These function as described in reference to FIGS.1 and2, with the return connection from the downhole equipment being effected by thedownhole ground connection72.

Even though many of the examples discussed herein are applications of the present invention in petroleum wells, the present invention also can be applied to other types of wells, including but not limited to: water wells and natural gas wells.[0103]

Also in a possible embodiment (not shown) of the present invention, the piping structures of two adjacent wells can be used to form a current loop for the electrical circuit. For example, a second end of a piping structure of a first well may be electrically connected (e.g., via a wire, conductive fluid, and/or the earth) to a second end of a piping structure of a second well adjacent to the first well, and a first end of the piping structure of the first well is electrically connected to a first terminal of a power source and a first end of the piping structure of the second well is electrically connected to a second terminal of the source, such that the electrical circuit is formed by using the piping structures of both wells. Hence, one of the piping structures will act as an electrical return. In another possible embodiment (not shown), two piping structures of a same well (e.g., two adjacent lateral branches) can be used to form a current loop for an electrical circuit. For example, the piping structure can be a first lateral branch and the electrical return can be a second lateral branch.[0104]

One skilled in the art will see that the present invention can be applied in many areas where there is a need to provide power and/or communication within a borehole, well, or any other area that is difficult to access. As discussed above, a production tubing string, as used in oil fields for withdrawing oil from a reservoir, is an example of a well with limited access downhole. Another example is the use of the present invention to provide power and/or communications to a device within a borehole of a machine part, where access within the borehole is limited. For example, when looking for cracks in a steam turbine using nondestructive testing techniques (e.g., ultrasonics, eddy current), there is often a need to provide power and communications to a sensor deep within a borehole of the steam turbine rotor that may be three to six inches in diameter and thirty feet long. The piping structure can comprise a rod or tube that physically supports the sensor, and the electrical return can comprise the machine part being inspected. Hence, the use of the present invention can provide a system and method of providing power and communications to a sensor deep within the borehole where access is limited.[0105]

Also, one skilled in the art will see that the present invention can be applied in many areas where there is an already existing conductive piping structure and a need to route power and/or communications in a same or similar path as the piping structure. A water sprinkler system or network in a building for extinguishing fires is an example of a piping structure that may be already existing and having a same or similar path as that desired for routing power and/or communications. In such case another piping structure or another portion of the same piping structure may be used as the electrical return. The steel structure of a building may be used as an electrically conductive structure and/or electrical return for transmitting power and/or communications in accordance with the present invention. The steel reinforcing bar in a concrete dam or a street pavement may be used as an electrically conductive structure and/or electrical return for transmitting power and/or communications in accordance with the present invention. The transmission lines and network of piping between wells or across large stretches of land may be used as a piping structure and/or electrical return for transmitting power and/or communications in accordance with the present invention. Surface refinery production pipe networks may be used as a piping structure and/or electrical return for transmitting power and/or communications in accordance with the present invention. Thus, there are numerous applications of the present invention in many different areas or fields of use.[0106]

It will be appreciated by those skilled in the art having the benefit of this disclosure that this invention provides a system that uses at least one unpowered induction choke to form an electrical circuit in a piping structure. It will also be appreciated by those skilled in the art having the benefit of this disclosure that this invention provides a system for providing power and/or communications to a device downhole in a borehole of a well using an electrical circuit formed in a piping structure by using at least one unpowered induction choke. It should be understood that the drawings and detailed description herein are to be regarded in an illustrative rather than a restrictive manner, and are not intended to limit the invention to the particular forms 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 modifications, changes, rearrangements, substitutions, alternatives, design choices, and embodiments.[0107]