Patent Publication Number: US-10309215-B2

Title: Casing segment having at least one transmission crossover arrangement

Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
     The present application is a National Stage of International PCT App. PCT/US2015/027378, titled “Casing Segment Having at Least One Transmission Crossover Arrangement”, filed Apr. 23, 2015 by Michael S. Bittar et al., which claims the benefit of U.S. Prov. Pat. App. 61/987,450, titled “Inductive Transmission Crossover Unit”, filed May 1, 2014 by Michael S. Bittar et al., and U.S. Prov. Pat. App. 61/987,449, titled “Electrode-Based Transmission Crossover Unit”, filed May 1, 2014 by Michael S. Bittar et al. The above-noted applications are hereby incorporated herein by reference in their entirety. 
    
    
     BACKGROUND 
     Oilfield operating companies seek to maximize the profitability of their reservoirs. Typically, this goal can be stated in terms of maximizing the percentage of extracted hydrocarbons subject to certain cost constraints. A number of recovery techniques have been developed for improving hydrocarbon extraction. For example, many companies employ flooding techniques, injecting a gas or a fluid into a reservoir to displace the hydrocarbons and sweep them to a producing well. As another example, some heavy hydrocarbons are most effectively produced using a steam-assisted gravity drainage technique, where steam is employed to reduce the hydrocarbons&#39; viscosity. 
     Such recovery techniques create a fluid front between the injected fluid and the fluid being displaced. The position of the fluid front is a key parameter for the control and optimization of these recovery techniques, yet it is usually difficult to track due to the absence of feasible and suitably effective monitoring systems and methods. Where the use of seismic surveys, monitoring wells and/or wireline logging tools is infeasible, operators may be forced to rely on computer simulations to estimate the position of the fluid front, with commensurately large uncertainties. Suboptimal operations related to inter-well spacing, inter-well monitoring, and/or multi-lateral production control increases the likelihood of premature breakthrough where one part of the fluid front reaches the producing well before the rest of the front has properly swept the reservoir volume. Such premature breakthrough creates a low-resistance path for the injected fluid to follow and deprives the rest of the system of the power it needs to function. 
    
    
     
       DESCRIPTION OF THE DRAWINGS 
       Accordingly, there are disclosed in the drawings and the following description a casing segment with at least one transmission crossover arrangement and related methods and systems for guided drilling, interwell tomography, and/or multi-lateral production control. In the drawings: 
         FIG. 1  is a block diagram showing features of an illustrative casing segment configuration involving at least one crossover transmission arrangement. 
         FIG. 2  is a schematic depiction of an illustrative system employing a casing segment with at least one transmission crossover arrangement. 
         FIG. 3  is a schematic depiction of an interwell tomography system employing casing segments with transmission crossover arrangements. 
         FIG. 4A  is a cutaway view showing a downhole scenario involving a transmission crossover arrangement with an inductive adapter. 
         FIG. 4B  is a cutaway view showing a downhole scenario involving a transmission crossover arrangement with an electrode-based adapter. 
         FIGS. 4C and 4D  are cross-sectional views of alternative electrode coupling configurations. 
         FIG. 5  shows a guided drilling system employing casing segments with transmission crossover arrangements. 
         FIG. 6A  shows a cased multi-lateral control system employing a casing segment with a transmission crossover arrangement. 
         FIG. 6B  shows an open-hole multi-lateral control system employing a casing segment with a transmission crossover arrangement. 
         FIGS. 7A and 7B  show illustrative geometrical inversion parameters. 
         FIG. 7C  shows multi-well monitoring of a fluid front. 
         FIG. 8  shows an illustrative multilateral well configuration. 
         FIG. 9A  is a flow diagram of an illustrative interwell tomography method. 
         FIG. 9B  is a flow diagram of an illustrative guided drilling method. 
         FIG. 9C  is a flow diagram of an illustrative multilateral control method. 
     
    
    
     It should be understood, however, that the specific embodiments given in the drawings and detailed description thereto do not limit the disclosure. On the contrary, they provide the foundation for one of ordinary skill to discern the alternative forms, equivalents, and modifications that are encompassed together with one or more of the given embodiments in the scope of the appended claims. 
     DETAILED DESCRIPTION 
     Disclosed herein are casing segment embodiments with at least one transmission crossover arrangement. As used herein, the term “casing segment” or “casing tubular” refer to any structure (e.g., a tubular) used to line the wall of any section of a borehole, either in a main borehole or in a lateral branch. Casing segments may vary with regard to material, thickness, inner diameter, outer diameter, grade, and/or end connectors, and various casing segment types are known in the industry such as conductor casing, surface casing, intermediate casing, production casing, liner, and liner tieback casing. Casing segments are often joined or coupled together to form a casing string that protects the integrity of an entire borehole or at least part of a borehole. While some casing strings extend to earth&#39;s surface, other casing strings (e.g., liners) hang from another casing string. 
     The term “coupled” or “coupled to” herein refers to a direct or indirect connection between two or more components. Without limitation, the direct or indirect connection may be mechanical, electrical, magnetic, and/or chemical in nature. For example, if a first component couples to a second component, that connection may be through a direct electrical connection, through an indirect electrical connection via other components and connections, through a direct physical connection, or through an indirect physical connection via other components and connections in various embodiments. Further, it should be appreciated that coupling two components may result in only one type of connection (mechanical, electrical, magnetic, or chemical) or in multiple types of connections (mechanical, electrical, magnetic, and/or chemical). 
     As used herein, the term “transmission crossover arrangement” corresponds to at least one coil antenna external to the casing tubular and in communication with an adapter. As an option, a control unit may be included with or assigned to each transmission crossover arrangement to support various operations involving controlled transmission, receipt, and/or storage of electromagnetic (EM) signals or sensor data. Thus, the phrase “in communication with” may refer to a direct coupling between the at least one coil antenna and the adapter, or an indirect coupling (e.g., control unit components may be positioned between the at least one coil antenna and the adapter). With an indirect coupling between the at least one coil antenna and the adapter, conveyance of power and/or communications between the at least one coil antenna, control unit components, and the adapter can be immediate or delayed as desired. In operation, each transmission crossover arrangement enables power or communications to be conveyed (immediately or in a delayed manner) from a respective casing segment&#39;s interior to its exterior or vice versa. 
     To enable downhole operations, a transmission crossover arrangement is permanently or temporarily coupled to a conductive path that extends to earth&#39;s surface. For example, the conductive path may couple to a transmission crossover arrangement&#39;s adapter at one end and to a surface interface at the other end. As used herein, the term “surface interface” corresponds to one or more components at earth&#39;s surface that provide power and/or telemetry for downhole operations. Example components of a surface interface include one or more power supplies, transmitter circuitry, receiver circuitry, data storage components, transducers, analog-to-digital converters, and digital-to-analog converters. The surface interface may be coupled to or includes a computer system that provides instructions for surface interface components, transmission crossover arrangements, and/or downhole tools. 
     In at least some embodiments, the adapter for a given transmission crossover arrangement corresponds to an inductive adapter that couples to a conductive path coil inductively, where the conductive path extends between an interior of the casing tubular and earth&#39;s surface (e.g., to a surface interface). In other embodiments, the adapter corresponds to an electrode-based adapter that couples to conductive path electrodes capacitively or galvanically, where the conductive path extends between the interior of the casing tubular and earth&#39;s surface. As an example, one or more of such conductive paths may be deployed downhole by attaching a cable to an inner tubular and lowering the inner tubular to a position at or near a transmission crossover arrangement&#39;s adapter. Alternatively, one or more of such conductive paths may be deployed downhole by lowering a wireline service tool to a position at or near a transmission crossover arrangement&#39;s adapter. 
     For inductive coupling, the conductive path includes an inductive coil that, when sufficiently close to the inductive adapter of a transmission crossover arrangement, enables power or communications to be conveyed between earth&#39;s surface and the respective transmission crossover arrangement. For electrode-based coupling, the conductive path includes one or more electrodes that, when galvanic or capacitive contact occurs between the conductive path&#39;s electrode(s) and an electrode-based adapter of a transmission crossover arrangement, enable power or communications to be conveyed between the conductive path and the transmission crossover arrangement. Such coupling between inductive coils or electrodes corresponding to a conductive path and a transmission crossover arrangement may be scaled as needed. Thus, it should be appreciated that each casing segment may include one transmission crossover arrangement or multiple transmission crossover arrangements. Further, a downhole casing string may include multiple casing segments that each employ at least one transmission crossover arrangement. Further, a conductive path may be arranged to couple to a single transmission crossover arrangement or to multiple transmission crossover arrangements at a time. Further, multiple conductive paths may be employed, where each conductive path may be permanently installed or moveable. If moveable, each conductive path may support coupling to one transmission crossover arrangement at a time or a set of transmission crossover arrangements at a time. Each transmission crossover arrangement that is coupled to a conductive path as described herein, regardless of whether such coupling is temporary or permanent, may be termed a transmission crossover unit or module. In other words, a transmission crossover unit or module includes a casing segment with a transmission crossover arrangement as well as inner conductive path components needed to convey power or communications to or from earth&#39;s surface. 
     Each transmission crossover arrangement may also include other features including a control unit with an energy storage device, a data storage device, interior sensors, exterior sensors, and/or control circuitry. Such features can facilitate transmitting or receiving signals, where multiple signals can be uniquely identified (e.g., using addressing, multiplexing, and/or modulation schemes). Further, interior or exterior sensor data can be useful for tracking downhole fluid properties and/or properties of the ambient environment (e.g., temperature, acoustic activity, seismic activity, etc.). With an energy storage device, a casing segment with at least one transmission crossover arrangement can perform signal transmission, signal reception, sensing, and data storage operations even if a conductive path to earth&#39;s surface is not currently available. When a conductive path temporarily couples to a given transmission crossover arrangement, stored data collected during ongoing or periodic operations (e.g., such operations may be performed before, during, or after temporary conductive path coupling) can be conveyed to earth&#39;s surface and/or an energy storage device can be recharged to enable ongoing or periodic operations even after the conductive path is no longer available. 
     As described herein, a casing segment employing at least one transmission crossover arrangement may be part of a system used to perform guided drilling operations, interwell tomography operations, and/or multi-lateral control operations.  FIG. 1  is a block diagram showing features of an illustrative casing segment configuration  20  involving at least one transmission crossover arrangement. As shown, the casing segment configuration  20  includes a transmission crossover arrangement with at least one external coil antenna and at least one internal adapter. Options for the at least one external antenna include tilted antennas and multi-component antennas. Meanwhile, options for the at least one internal adapter include an inductive adapter and an electrode-based adapter. The electrode-based adapter may support capacitive coupling and/or galvanic coupling. If an inductive adapter is used, the corresponding inductive coil may be internal to and insulated from the casing segment. Alternatively, the inductive adapter may correspond to an inductive coil that wraps around an exterior of the casing segment or an exterior recess of the casing segment, where the casing segment includes nonconductive windows to allow electromagnetic energy to be transferred from a conductive path inside the casing segment to the inductive adapter. In some embodiments, transmission crossover arrangement components may be set in a recess of a casing tubular and/or covered with protective material. 
     Other features of the casing segment configuration  20  include an energy storage device, a data storage device, sensors, a control unit and/or control circuitry. In some embodiments, one or more of these other features are optionally employed to facilitate transmitting or receiving signals, where multiple signals can be uniquely identified (e.g., using addressing, multiplexing, and/or modulation schemes). Further, interior or exterior sensor data can be useful for tracking downhole fluid properties and/or properties of the ambient environment (e.g., temperature, acoustic activity, seismic activity, etc.). With an energy storage device, a casing segment with at least one transmission crossover arrangement can perform signal transmission, signal reception, sensing, and data storage operations even if a conductive path to earth&#39;s surface is not currently available. When a conductive path temporarily couples to a given transmission crossover arrangement, stored data collected during ongoing or periodic operations (e.g., such operations may be performed before, during, or after temporary conductive path coupling) can be conveyed to earth&#39;s surface and/or an energy storage device can be recharged to enable ongoing or periodic operations even after the conductive path is no longer available. An example energy storage device includes a rechargeable battery. An example data storage device includes a non-volatile memory. Example sensors include temperature sensors, pressure sensors, acoustic sensors, seismic sensors, and/or other sensors. In at least some embodiments, optical fibers are used for sensing ambient parameters such as temperature, pressure, or acoustic activity. 
     Further, an example control unit may correspond to a processor or other programmable logic that can execute stored instructions. As desired, new or updated instructions can be provided to the processor or other programmable logic. With the instructions, the control unit is able to employ addressing schemes, modulation schemes, demodulation schemes, multiplexing schemes, and/or demultiplexing schemes to enable unique identification of transmitted or received signals. Such signals may be conveyed between earth&#39;s surface and one or more transmission crossover arrangements, between different transmission crossover arrangements, and/or between one or more transmission crossover arrangements and downhole equipment (e.g., an in-flow control device as described herein). Example control circuitry includes drivers and receivers that facilitate signal transmission operations and signal reception operations. 
     In at least some embodiments, a casing segment with some or all of the features of configuration  20  is employed along a casing string to perform operations such as interwell tomography operations, guided drilling operations (ranging), multi-lateral in-flow control device (ICD) monitoring or control operations, and/or other operations.  FIG. 2  is a schematic depiction of an illustrative system  10  employing a casing segment  21 A with a transmission crossover arrangement  22 . As represented in  FIG. 2 , the casing segment  21 A is part of a casing string  11  deployed in a borehole  12  that extends through various formation layers  14 A- 14 C. The well  12  can be drilled and cased using known techniques. In one embodiment, the casing string  11  may have multiple casing segments  21  connected together, for example, using couplers  18 . Different casing string embodiments are possible, where the number and/or the characteristics of casing segments  21  may vary. Further, the manner in which casing segments  21  couple together to form a casing string  11  may vary as is known in the art. While the casing string  11  and casing segment  21 A are shown to have a vertical orientation in  FIG. 2 , it should be appreciated that casing segments, such as segment  21 A, could have another orientation. Further, multiple casing segments, each with its own transmission crossover arrangement  22 , may be employed along a casing string such as casing string  11 . In such case, the spacing between and/or orientation of different casing segments having a transmission crossover arrangement may be the same or may vary. 
     In accordance with at least some embodiments, the transmission crossover arrangement  22  of casing segment  21 A includes adapter  24 , coil antenna  26 , and control unit  28 . The adapter  24 , for example, corresponds to an inductive adapter or electrode-based adapter that is accessible along an interior of casing segment  21 A to enable coupling to a conductive path  30  that runs along the interior of the casing string  11 . Further, the conductive path  30  may include a conductive path adapter  32  that is compatible with adapter  24 . Together, the transmission crossover arrangement  22  of casing segment  21 A and the conductive path adapter  32  may be considered to be a transmission crossover unit or module that is temporarily available or permanently deployed. 
     The coil antenna  26  may be used to send signals  42  to and/or receive signals  44  from a downhole tool  52  in another borehole  50 . The downhole tool  52  may correspond to another casing segment with an transmission crossover arrangement, an in-flow control device (ICD), a wireline tool, logging-while-drilling (LWD) tool, a bottomhole assembly, or other downhole tool. Example operations (represented in operations block  45 ) involving the coil antenna  26  sending signals  42  to and/or receiving signals  44  from downhole tool  52  include interwell tomography, guided drilling, and/or multi-lateral ICD monitoring or control. To perform such operations, the downhole tool  52  may include an antenna  54  and control unit  56  (which may or may not be part of another transmission crossover arrangement). Further, in some embodiments, a conductive path  58  may be optionally provided to enable more direct conveyance of power/communications between earth&#39;s surface and the downhole tool  52 . Alternatively, the downhole tool  52  sends signals  44  to and/or receives signals  42  from the transmission crossover arrangement  22  without having separate conductive path  58 . In such case, power/communications between earth&#39;s surface and the downhole tool  52  is conveyed via the transmission crossover arrangement  22  and conductive path  30 . Further, the transmission crossover arrangement  22  may perform the task of selecting or filtering information to be provided to earth&#39;s surface from the downhole tool  52 , and/or of selecting or filtering information to be provided from earth&#39;s surface to the downhole tool  52 . 
     The control unit  28  may include an energy storage device, a processing unit, a data storage device, sensors, and/or control circuitry. The function of the control unit  28  may vary for different embodiments. Further, in some embodiments, the control unit  28  may be omitted. Example features provided by the control unit include directing periodic or ongoing transmissions of signals  42  and/or directing periodic or ongoing reception of signals  44 . Further, the control unit  28  may employ an addressing scheme, a multiplexing scheme, and/or a modulation scheme to enable unique identification of multiple signals  42  or  44  (note: there may be multiple transmission crossover arrangements  22  and/or multiple downhole tools  52  within range of each other). Such schemes may involve transmitter circuitry, receiver circuitry, a processing unit, and/or a data storage device with instructions executable by the processing unit. Further, interior or exterior sensors may track downhole fluid properties and/or properties of the ambient environment (e.g., temperature, acoustic activity, seismic activity, etc.). With an energy storage device, the control unit  28  can direct signal transmission, signal reception, sensing, and data storage operations even if a conductive path to earth&#39;s surface is not currently available. When a conductive path temporarily couples to the transmission crossover arrangement  22 , the control unit  28  may direct the process of conveying stored data collected during ongoing or periodic operations (e.g., such operations may be performed before, during, or after a temporary conductive path coupling) to earth&#39;s surface and/or may direct recharging of the energy storage device. An example energy storage device includes a rechargeable battery. An example data storage device includes a non-volatile memory. Example sensors include temperature sensors, pressure sensors, acoustic sensors, seismic sensors, and/or other sensors. In at least some embodiments, optical fibers are used for sensing ambient parameters such as temperature, pressure, or acoustic activity. 
     At earth&#39;s surface, a surface interface  59  provides power and/or telemetry for downhole operations involving the transmission crossover arrangement  22 . Example components for the surface interface  59  include one or more power supplies, transmitter circuitry, receiver circuitry, data storage components, transducers, analog-to-digital converters, digital-to-analog converters. The surface interface  59  may be coupled to or includes a computer system  60  that provides instructions for surface interface components, the transmission crossover arrangement  22 , and/or downhole tool  52 . Further, the computer system  60  may process information received from the transmission crossover arrangement  22  and/or the downhole tool  52 . In different scenarios, the computer system  60  may direct the operations of and/or receive measurements from the transmission crossover arrangement  22  and/or the downhole tool  52 . The computer system  60  may also display related information and/or control options to an operator. The interaction of the computer system  60  with the transmission crossover arrangement  22  and/or the downhole tool  52  may be automated and/or subject to user-input. 
     In at least some embodiments, the computer system  60  includes a processing unit  62  that displays logging/control options and/or results by executing software or instructions obtained from a local or remote non-transitory computer-readable medium  68 . The computer system  60  also may include input device(s)  66  (e.g., a keyboard, mouse, touchpad, etc.) and output device(s)  64  (e.g., a monitor, printer, etc.). Such input device(s)  66  and/or output device(s)  64  provide a user interface that enables an operator to interact with components of the transmission crossover arrangement  22 , the downhole tool  52 , and/or software executed by the processing unit  62 . 
     For interwell tomography, the information conveyed from computer system  60  to the transmission crossover arrangement  22  or downhole tool  52  may correspond to interwell tomography instructions or signals. Meanwhile, the information conveyed from the transmission crossover arrangement  22  or downhole tool  52  to the computer  60  may correspond to interwell tomography measurements or acknowledgment signals. For guided drilling, the information conveyed from the computer system  60  to the transmission crossover arrangement  22  or downhole tool  52  may correspond ranging or drilling instructions or signals. Meanwhile, the information conveyed from the transmission crossover arrangement  22  or downhole tool  52  to the computer system  60  may correspond to ranging or guided drilling measurements or acknowledgment signals. For multi-lateral monitoring/control operations, the information conveyed from the computer system  60  to the transmission crossover arrangement  22  or downhole tool  52  may correspond ICD instructions or interrogations. Meanwhile, the information conveyed from the transmission crossover arrangement  22  or downhole tool  52  to the computer  60  may correspond to ICD measurements or acknowledgment signals. 
       FIG. 3  is a schematic depiction of an interwell tomography system. In  FIG. 3 , the interwell tomography area corresponds to at least some of the downhole area or volume between injection well  8  and production well  9 . Note: it should be appreciated that interwell tomography can be performed between the same well type or different well types (monitoring wells, production wells, injection wells) and that production wells can operate as injection wells and vice versa. In  FIG. 3 , the production well  8  includes a casing string  1  lB having a casing segment  21 B with transmission crossover arrangement  22 B. Similarly, injection well  9  includes a casing string  11 C having a casing segment  21 C with transmission crossover arrangement  22 C. The casing strings  11 B and  11 C are deployed in boreholes  12 B and  12 C that pass through different formation layers  14 A- 14 C of the earth. Along the casing strings  11 B and  11 C, respective perforations  19 B and  19 B enable fluid injection  48  by casing string  11 C and fluid production  46  by casing string  11 B. 
     In operation, the transmission crossover arrangements  22 B and  22 C are used to collect interwell tomography information that can be used to characterize at least some of the downhole area or volume between injection well  8  and production well  9  and/or to reduce the occurrence of premature breakthrough (where one part of the fluid front  49  reaches the producing well  9  before the rest of the front  49  has properly swept the reservoir volume). The specific features of transmission crossover arrangements  22 B and  22 C was previously described for the transmission crossover arrangements  22  of  FIG. 2  and will not be repeated. 
     In  FIG. 3 , two different conductive path options  30 A and  30 B along the interiors of casing strings  11 B and  11 C are represented using cut-out views  70 A and  70 B. The conductive path  30 A interior to casing string  11 B corresponds at least in part to a cable  74  attached (e.g., using bands  76 ) to an inner tubular  72  (e.g., a production string) deployed within the casing string  11 B. In at least some embodiments, the cable  74  and inner tubular  72  extend between earth&#39;s surface and the transmission crossover arrangement  22 B, where a conductive path adapter  32  enables coupling between the conductive path  30 A and the adapter  24  of transmission crossover arrangement  22 B. The coupling may be inductive or electrode-based as described herein. Further, the cable  74  may exit a wellhead  80  at earth&#39;s surface and connect to a surface interface  84  to enable conveyance of power/communications between earth&#39;s surface and the transmission crossover arrangement  22 B. 
     Meanwhile, the conductive path  30 B interior to casing string  11 C corresponds at least in part to a wireline service tool  31  that is lowered or raised within casing string  11 C using wireline  92 . Herein, the term “wireline”, when not otherwise qualified, is used to refer to a flexible or stiff cable that can carry electrical current on an insulated conductor that may be armored with a wire braid or thin metal tubing having insufficient compressive strength for the cable to be pushed for any significant distance. In some cases, a stiff wireline may be rigid enough for pushing a tool along a deviated, horizontal, or ascending borehole. In practice, stiff wireline may take the form of a flexible cable strapped or otherwise attached to a tubular, though other embodiments are possible. 
     In at least some embodiments, the wireline  92  may extend from a reel (not shown) and is guided by wireline guides  94 A,  94 B of a rig or platform  90  at earth&#39;s surface. The wireline  92  may further extend to a surface interface (e.g., interface  84  or computer system  60 ) to enable conveyance of power/communications between earth&#39;s surface and transmission crossover arrangement  22 C. When the wireline service tool  31  is at or near the transmission crossover arrangement  22 C, a conductive path adapter  32  provided with the wireline service tool  31  enables coupling between the conductive path  30 B and the adapter  24  of transmission crossover arrangement  22 C. The coupling may be inductive or electrode-based as described herein. 
     Though  FIG. 3  shows vertical wells, the interwell tomography principles described herein also apply to horizontal and deviated wells. They may also apply where the injected fluid does not act as a drive fluid. For example, in a steam-assisted gravity drainage (SAGD) operation, in an injection well circulates and injects steam into a surrounding formation. As the thermal energy from the steam reduces the viscosity of the heavy oil in the formation, the heavy oil (and steam condensate) is drawn downward by gravity to a producing well drilled parallel and from about 5-20 ft lower. In this manner, the steam forms an expanding “steam chamber” that delivers thermal energy to more and more heavy oil. The chamber primarily grows in an upward direction, but there is a front that gradually moves downward towards the producing well. Excessive injection rates will drive the front prematurely to the producing well, creating an unwanted flow path that severely reduces the operation&#39;s efficiency. Either or both of the wells may be equipped with external antenna modules to map the distribution of formation properties and thereby track the distance of the front. (The front is detectable because injected steam has different resistive and dielectric properties than the formation and the heavy oil.) 
     Often companies will drill additional wells in the field for the sole purpose of monitoring the distribution of reservoir fluids and predicting front arrivals at the producing wells. In the system of  FIG. 3 , additional wells and well interfaces may be included in the coordinated operation of the field and the interwell tomography system. The additional wells may be single-purpose wells (i.e., only for injection, production, or monitoring), or they may serve multiple purposes, some of which may change over time (e.g., changing from a producing well to an injection well or vice versa). 
     During interwell tomography operations, transmission crossover arrangements  22 B and  22 C may be used along or may be used in combination with other components such as spaced-apart electrodes that create or detect EM signals, wire coils that create or detect EM signals, and/or magnetometers or other EM sensors to detect EM signals. In at least some embodiments, different coil antennas  26  of the respective transmission crossover arrangements  22 B and  22 C transmit EM signals while other coil antennas  26  obtain responsive measurements. In some embodiments, it is contemplated that different coil antennas  26  of the transmission crossover arrangements  22 B and  22 C are suitable only for transmitting while others are suitable only for receiving. Meanwhile, in other embodiments, it is contemplated that different coil antennas  26  of the transmission crossover arrangements  22 B and  22 C can perform both transmitting and receiving. In at least some embodiments, coil antennas  26  of the transmission crossover arrangements  22 B and  22 C perform interwell tomography operations by transmitting or receiving arbitrary waveforms, including transient (e.g., pulse) waveforms, periodic waveforms, and harmonic waveforms. Further, coil antennas  26  of the transmission crossover arrangements  22 B and  22 C may perform interwell tomography operations by measuring natural EM fields including magnetotelluric and spontaneous potential fields. Without limitation, suitable EM signal frequencies for interwell tomography include the range from 1 Hz to 10 kHz. In this frequency range, the modules may be expected to detect signals at transducer spacings of up to about 200 feet, though of course this varies with transmitted signal strength and formation conductivity. Lower (below 1 Hz) signal frequencies may be suitable where magnetotelluric or spontaneous potential field monitoring is employed. Higher signal frequencies may also be suitable for some applications, including frequencies as high as 500 kHz, 2 MHz, or more. 
     In at least some embodiments, the surface interface  84  and/or a computer system (e.g., computer  60 ) obtains and processes EM measurement data, and provides a representative display of the information to a user. Without limitation, such computer systems can take different forms including a tablet computer, laptop computer, desktop computer, and virtual cloud computer. Whichever processor unit embodiment is employed includes software that configures the processor(s) to carry out the necessary processing and to enable the user to view and preferably interact with a display of the resulting information. The processing includes at least compiling a time series of measurements to enable monitoring of the time evolution, but may further include the use of a geometrical model of the reservoir that takes into account the relative positions and configurations of the transducer modules and inverts the measurements to obtain one or more parameters such as fluid front distance, direction, and orientation. Additional parameters may include a resistivity distribution and an estimated water saturation. 
     A computer system such as computer system  60  may further enable the user to adjust the configuration of the transducers, varying such parameters as firing rate of the transmitters, firing sequence of the transmitters, transmit amplitudes, transmit waveforms, transmit frequencies, receive filters, and demodulation techniques. In some contemplated system embodiments, an available computer system further enables the user to adjust injection and/or production rates to optimize production from the reservoir. 
     The interwell tomography scenario of  FIG. 3  is just one example of how casing segments with at least one transmission crossover arrangement can be used. Further, it should be appreciated that different transmission crossover arrangement and conductive path options are possible.  FIG. 4A  is a cutaway view showing a downhole scenario involving a transmission crossover arrangement with an inductive adapter. In  FIG. 4A , the transmission crossover arrangement includes an inductive adapter coil  302  and external coil antenna  156 A. The inductive adapter coil  302  is wound coaxially over one or more windows  304  through the wall of the casing tubular  154 . The illustrated windows  304  are longitudinal slots that may be filled with a nonconductive material. The windows  304  facilitate the passage of electromagnetic energy between the inductive adapter coil  302  and a conductive path coil  306 . 
     The conductive path coil  306  forms part of a conductive path that extends between a surface interface and the inductive adapter coil  302 . In  FIG. 4A , the conductive path includes conductive path coil  306  and a cable  158  with one or more electrical conductors. In at least some embodiments, cable  158  is attached to an inner tubular  112  by straps  132 . Further, the conductive path coil  306  encircles the inner tubular  112 , and a layer of high-permeability material  308  may be placed between the inner tubular  112  and the conductive path coil  306  to reduce the attenuation that might otherwise be caused by the conductive inner tubular  112 . (A similar high-permeability layer  310  may overlie the inductive adapter coil  302  to improve the inductive coupling between the inductive adapter coil  302  and the conductive path coil  306 .) For protection, the conductive path coil  306  may be seated between annular bulkheads  312  or flanges, and sealed beneath a nonconductive cover  314 . A resin or other filler material may be used to fill the gaps beneath the cover  314  to protect the conductive path coil  306  from various effects of the downhole environment including fluids at elevated temperature and pressures. 
     The nonconductive windows  304  and any gaps in recess  316  may also be filled with a resin or other filler material to protect the outer coil  302  from fluids at elevated temperatures and pressures. A sleeve  318  provides mechanical protection for the inductive adapter coil  302 . Depending on the depth of recess  316  and the number and width of windows  304 , it may be desirable to make sleeve  318  from steel or another structurally strong material to assure the structural integrity of the casing tubular. If structural integrity is not a concern, the sleeve may be a composite material. 
     To facilitate alignment of the conductive path coil  306  with the inductive adapter coil  302 , the longitudinal dimension of the inductive adapter coil  302  and slots  304  may be on the order of one to three meters, whereas the longitudinal dimension of the conductive path coil  306  may be on the order of 20 to 40 centimeters. 
     The inductive adapter coil  302  of the transmission crossover arrangement is coupled to a set of one or more external coil antennas  156  ( FIG. 4A  shows only a single external antenna coil  156 A). The external coil antenna(s) encircle the casing tubular  154  and they may be tilted to provide azimuthal sensitivity. A high-permeability layer  320  is positioned between the casing tubular  154  and the external coil antenna  156 A to reduce attenuation that might otherwise be caused by the conductive material of the tubular. For mechanical protection, external coil antenna(s) such as antenna  156 A may be seated in a recess  322  and surrounded by a nonconductive cover  324 . Any gaps in the recess  322  may be filled with a resin or other nonconductive filler material. 
     In certain alternative embodiments where a greater degree of protection is desired for the conductive path coil  306  or the external coil antenna  156 A, the nonconductive covers  314  or  324  may be supplemented or partially replaced with a series of steel bridges across the recess so long as there are windows of nonconductive material between the bridges to permit the passage of electromagnetic energy. The edges of the metal bridges should be generally perpendicular to the plane of the coil. 
     In some embodiments, the external coil antenna  156 A is coupled in series with the inductive adapter coil  302  so that signals are directly communicated between the conductive path coil  306  and the external coil antenna  156 A, whether such signals are being transmitted into the formation or received from the formation. In other embodiments, a control unit  326  mediates the communication. Control unit  326  may include a switch to multiplex the coupling of the inductive adapter coil  302  to selected ones of the external coil antennas. Further, control unit  326  may include a battery, capacitor, or other energy source, and a signal amplifier. The control unit  326  may additionally or alternatively include an analog-to-digital converter and a digital-to-analog converter to digitize and re-transmit signals in either direction. Control unit  326  may still further include a memory for buffering data and a programmable controller that responds to commands received via the inductive adapter coil  302  to provide stored data, to transmit signals on the external coil antenna, and/or to customize the usage of the external antennas. 
       FIG. 4B  is a cutaway view showing a downhole scenario involving a transmission crossover arrangement with an electrode-based adapter. In  FIG. 4B , the electrode-based adapter corresponds to a set of electrodes  330  on an inner wall of the casing tubular  154 . Meanwhile, a set of conductive path electrodes  332  (included as part of the inner conductive path) couple capacitively or galvanically to the inner wall electrodes  330 . As shown by the transverse cross section in  FIG. 4C , there need not be a one-to-one correspondence between the inner wall electrodes  330  and conductive path electrodes  332 . The particular configuration shown in  FIG. 4C  includes three inner wall electrodes  330 A,  330 B,  330 C, each occupying approximately one third of the circumferencial arc size, and two symmetrically arranged conductive path electrodes  332 A,  332 B each occupying approximately one-sixth of the circumferencial arc size. The inclusion of extra inner wall electrodes prevents any one inner wall electrode from simultaneously coupling to both conductive path electrodes, enabling the conductive path to operate efficiently regardless of orientation. If wider conductive path electrodes are desired, the number of inner wall electrodes may be increased still further, though this increases the complexity of the signal transference. 
     The usage of extra inner-wall electrodes may, in at least some instances, mean that signal transference from the conductive path electrodes to the control unit  326  is not trivial. Alternating current (AC) signaling may be employed, and the signals from the three electrodes may be coupled to a two-wire input for the control unit  326  via diodes. Such an approach may be particularly effective for charging an energy storage unit. For communication from the control unit  326  to the conductive path electrodes, a multi-phase (e.g., 3-phase) signaling technique may be employed, driving the inner wall electrodes with signals of different phases (e.g., 120° apart). 
     For capacitive coupling embodiments, nonconductive material may be placed over each conductive path electrode  332 . The inner wall electrodes  330  may be similarly coated. The nonconductive material preferably acts as a passivation layer to protect against corrosion, and where feasible, the passivation layer is kept thin and made from a high-permittivity composition to enhance the capacitive coupling. 
     In contrast to capacitive coupling, galvanic coupling embodiments make conductor-to-conductor contact between the conductive path electrodes and the inner wall electrodes  330 . Resilient supports and scrapers may be employed to clean the electrodes and provide such contact.  FIG. 4D  shows a transverse cross section of a transmission crossover arrangement having an inner lip  340  that catches and guides adapter key(s)  342  into a channel having electrode  344  to contact matching conductive path electrodes  346  on the keys  342 . The keys can be spring biased to press the electrodes together. This configuration supports both galvanic and capacitive coupling techniques, and the one-to-one electrode correspondence simplifies the signal transfer between the conductive path electrodes and the controller  326  or external antennas  156 . 
       FIG. 5  shows an illustrative system employing casing segments with transmission crossover arrangements for guided drilling. Such a system may be employed to drill parallel boreholes suitable for steam assisted gravity drainage (SAGD), intersecting boreholes, or for intersection avoidance in sites having multiple wells. In  FIG. 5 , a first inductive transmission crossover arrangement  402  responds to a first conductive path  404  along on an internal tubular  112 , causing an external antenna  406  of the transmission crossover arrangement  402  to send electromagnetic signals  408 . Additionally or alternatively, external antenna  406  receives electromagnetic signals  410  from the bottomhole assembly (BHA)  452  of a drillstring in a nearby borehole  455 , and communicates the receive signal (or measurements thereof) to the surface via the conductive path  404 . 
       FIG. 5  also shows a second inductive transmission crossover arrangement  412  with an external antenna  416  to transmit electromagnetic signals  418  in response communications conveyed via the conductive path  414  and/or to receive electromagnetic signals  410  and communicate them to the surface via the conductive path  414 . Similar to conductive path  404 , the conductive path  414  is mounted to the internal tubular  112 . In some embodiments, the conductive paths  404  and  414  correspond to one conductive path. However, it should be appreciated that with careful control of the spacing, any number of conductive paths can be provided for communication with a corresponding number of transmission crossover arrangements. 
       FIG. 6A  shows an illustrative system employing casing segments with transmission crossover arrangements to provide multilateral production control. The well in  FIG. 6A  has two, laterally branching, cased boreholes  502 ,  504  extending from the mother borehole  155 . Perforated regions  506  enable formation fluids to enter the lateral boreholes  502 ,  504 , and absent further considerations, flow to the mother borehole  155  and thence to the surface. 
     To control the flow from the lateral boreholes  502 ,  504 , each is provided with an inflow control device (ICD)  510 ,  520 . The ICD&#39;s are equipped with packers  512  that seal the lateral borehole against any flow other than that permitted through inlet  519  by an internal valve. The ICD&#39;s are further equipped with a coaxial antenna  514  through which the ICD receives wireless commands to adjust the internal valve setting. In  FIG. 6A , the coaxial antenna  514  is placed in an inductive coupling relationship with the outer coil  516  of an inductive transmission crossover arrangement that facilitates communication between the coaxial antenna  514  and an external antenna  518 . As with other transmission crossover arrangements described herein, a control unit  517  may mediate the communication. 
     In the mother borehole  155 , one or more transmission crossover arrangements  530  facilitate communication between an external antenna  532  and a conductive path  533 , which extends to a surface interface. The surface interface is thus able to employ the external antenna  532  to send electromagnetic signals  534  to the external antennas  518  of the lateral boreholes (to relay the signals to the ICDs  510 ,  520 ). 
     In some embodiments, the ICDs are battery powered and periodically retrieved for servicing and recharging. Another option may be to recharge an ICD battery by conveying EM energy between at least one transmission crossover arrangement and an ICD. The ICDs may be equipped with various sensors for temperature, pressure, flow rates, and fluid properties, which sensor measurements are communicated via the transmission crossover arrangements and external antennas to the conductive path  533  and thence to the surface interface. A computer processing the sensor measurements may determine the appropriate valve settings and communicate them back to the individual ICDs. 
     A similar multilateral production control system is shown in  FIG. 6B  for open hole laterals. The lateral boreholes are uncased, so the ICDs seal against the borehole walls and regulate flow to ports  552  and  554  in the mother borehole casing  154 . 
     The multilateral systems in  FIGS. 7A and 7B  are simplified for the purposes of explanation. Meanwhile,  FIG. 8  shows a more typical multilateral “fishbone” configuration in which the mother bore  702  is drilled in a mostly vertical fashion until a desired depth is reached, and thereafter steered nearly horizontally along a formation bed. From this nearly horizontal region, lateral “ribs”  704  are drilled horizontally in each direction away from the mother bore in each direction. For SAGD applications, a second such configuration is drilled above or below the first in an essentially parallel arrangement. 
     Returning to  FIGS. 7A and 7B , certain geometrical parameters are defined that are useful for tomographic inversion and fluid front tracking  FIG. 7A  shows a side view of casing  602  extending along a downwardly-directed casing axis (the Z-axis). A fluid front  604  is shown at a distance D from the receiver location. The front  604  need not be parallel to the casing axis, and in fact  FIG. 7A  shows the front at a relative dip angle θ (measured from the positive Z axis).  FIG. 7B  shows an end view of the casing  602 , with an X-axis defining a zero-azimuth, which may be the high-side of the borehole or, for a vertical well, may be North. The azimuth angle cp, or “strike”, of the front  604  is measured counterclockwise from the X-axis. Similarly, the tilt of the external antennas can also be specified in terms a tilt angle (relative dip)  0  and azimuth cp of the antenna axis. 
     When measurements by multiple sets of external antennas from multiple wells are combined, a more complete understanding of the interwell region can be obtained. Time-domain and/or frequency domain electromagnetic signals can be employed to perform accurate real-time inversion for fluid front tracking, or with sufficient data from multiple transducers and arrays, to perform accurate imaging and tomography of the injection region. The measurements can be repeated to obtain time-lapse monitoring of the injection process. In addition, the conductive tubulars used for nearby drillstrings will make those drillstrings detectable via the electromagnetic signals, enabling them to be guided relative to the existing well(s). 
       FIG. 7C  shows an overhead perspective of a field having an injection fluid front  604  propagating outwards from an injection well  606  towards a producing well  602 . Monitoring wells  608 ,  610  may be provided to enable better monitoring of the front in the region intermediate the injection and producing wells. The positions of the wells and the EM transducers, together with the operating parameters such as transmit signal frequencies, can be chosen using optimization via numerical simulations and/or measurements from LWD and wireline tools during the drilling process. The design parameters are chosen to obtain adequate range and resolution with a minimum cost. 
     The use of tilted antennas for acquiring measurements from multi-component transmitter and receiver arrangements enables significantly more accurate tomographic and guidance operations to be performed with fewer sets of antennas. In at least some contemplated embodiments, each set of external antenna includes three tilted coil antennas, each tilted by the same amount, but skewed in different azimuthal directions. The azimuthal directions are preferably spaced 120° apart. The amount of tilt can vary, so long as the angle between the antenna axis and the tool axis is greater than zero. Without limitation, contemplated tilts include 30°, 45° and 54.7°. (The latter tilt makes the three antennas orthogonal to each other.) Such tilted coil antennas have been shown to achieve a large lateral sensitivity. Other suitable tilt angles are possible and within the scope of the present disclosure. 
       FIG. 9A  is a flow diagram of an illustrative interwell tomography method that, after the initial setup steps, may be at least partly carried out by a processor in communication with one or more of the surface interface systems. In block  802 , a crew drills an initial borehole. In block  804 , the crew assembles a casing string with at least one set of transmission crossover arrangements and inserts it in the borehole. Some systems may employ multiple transmission crossover arrangements, each having a respective set of external antennas. The crew may cement the casing string in place for permanent installation. 
     In block  806 , the crew deploys a conductive path (e.g., a cable along an inner tubular or a wireline service tool) inside the casing string. As described herein, inductive coils or electrodes are employed along the conductive path to couple to transmission crossover arrangement adapters along the casing string. According, the conductive path supports the delivery of power and/or telemetry to each transmission crossover arrangement. The positioning of the inner tubular or wireline can be adjusted (to adjust inductive coils or electrodes along the conductive path) until suitable coupling has been achieved with each transmission crossover arrangement adapter. 
     In block  808 , the crew drills one or more additional boreholes, and in block  810  the crew equips each of the additional boreholes with one or more sets of antennas. Such antennas may be external casing antennas as used in the initial borehole, or they make take some other form such as an open hole wireline sonde. Additional antennas may also be deployed at the surface. 
     In block  812 , the processor employs the conductive path and transmission crossover arrangements to acquire measurements of the designated receive antenna responses to signals from each of the designated transmit antennas. The external antennas corresponding to the transmission crossover arrangements can function in either capacity or in both capacities. In addition to some identification of the measurement time and the associated transmit and receive antennas, the signal measurements may include signal strength (e.g., voltage), attenuation, phase, travel time, and/or receive signal waveform. The processor unit optionally triggers the transmitters, but in any event obtains responsive measurements from the receivers. Some systems embodiments may employ transient or ultra-wideband signals. 
     In block  814 , the processor unit performs initial processing to improve the signal-to-noise ratio of the measurements, e.g., by dropping noisy or obviously erroneous measurements, combining measurements to compensate for calibration errors, demodulating or otherwise filtering signal waveforms to screen out-of-band noise, and/or averaging together multiple measurements. 
     In addition, the processor may apply a calibration operation to the measurements. One particular example of a calibration operation determines the ratio of complex voltage or current signals obtained at two different receivers, or equivalently, determines the signal phase differences or amplitude ratios. 
     In block  816 , the processor unit performs an inversion to match the measurements with a synthetic measurements from a tomographic formation model. The model parameters may include a distribution of formation resistivity R and/or permittivity as a function of distance, dip angle, and azimuth from a selected transmitter or receiver. Where a sufficient number of independent measurements are available (e.g. measurements at additional receivers, frequencies, and/or from different wells), the model parameters may include the relative positions and orientations of nearby tubulars such as drillstrings or the casings of different wells. 
     In block  818 , the processor unit provides to a user a display having a representation of the derived model parameter values. The display may include a graphical representation of the resistivity and/or permittivity distribution throughout a two or three dimensional volume. Alternative representations include numeric parameter values, or a two-dimensional log of each parameter value as a function of time. 
     In block  820 , the processor unit combines the current parameter values with past parameter values to derive changes in the resistivity or permittivity distribution, which may indicate the motion of a fluid front. These parameter values may be similarly displayed to the user. 
     In block  822 , the processor unit may automatically adjust a control signal or, in an alternative embodiment, display a control setting recommendation to a user. For example, if a fluid front has approached closer than desired to the producing well, the processor unit may throttle down or recommend throttling down a flow valve to reduce the production rate or the injection rate. Where multiple injection or production zones are available, the system may redistribute the available production and injection capacity with appropriate valve adjustments to keep the front&#39;s approach as uniform as possible. Blocks  812 - 822  are repeated to periodically obtain and process new measurements. 
       FIG. 9B  is a flow diagram of an illustrative guided drilling method. Blocks representing similar operations in the previous method are similarly numbered and not described further here. In block  824 , the additional borehole(s) are drilled with a steerable drillstring that optionally has a bottom hole assembly with antennas to transmit or receive signals from external casing antennas corresponding to at least one transmission crossover arrangement in the initial well. In block  826 , distance or direction measurements are used to triangulate a position and to derive, in combination with previous measurements, a trajectory. The settings adjustment in block  822  represents the steering operations that are undertaken in response to the position and trajectory measurements to steer the drillstring along a desired course relative to the initial borehole. 
     In certain alternative embodiments, the transmission crossover arrangements are employed to generate beacon signals from each of the external casing antennas. The drillstring BHA measures the beacon signals and optionally determines a distance and direction to each beacon, from which a position and desired direction can be derived. In other embodiments, the BHA employs a permanent magnet that rotates to generate an electromagnetic signal that can be sensed by the external casing antennas. In still other embodiments, the external casing antennas merely detect the presence of the conductive drillstring from the changes it causes in the resistivity distribution around the initial well. 
       FIG. 9C  is a flow diagram of an illustrative multilateral control method. Blocks representing similar operations in the previous methods are similarly numbered and not described further here. In block  830 , the crew drills lateral boreholes extending from the mother borehole. In optional block  832 , the crew assembles a lateral casing string with at least one transmission crossover arrangement and inserts it in the lateral borehole. 
     In block  834 , the crew deploys an ICD in each lateral borehole, setting it with one or more packers to secure it in place. Each ICD includes an internal valve that can be adjusted via wireless commands to a coaxial ICD antenna coil. Blocks  830 ,  832 ,  834  preferably precede the deployment of an inner tubular or wireline adapter in block  806 . 
     In block  836 , the processor unit communicates with each ICD via the conductive path and one or more transmission crossover arrangements to establish suitable valve settings. In block  838 , the processor unit collects and processes various sensor measurements optionally including measurements from sensors in the ICDs themselves. In any event, flow rates and fluid compositions at the wellhead should be measured. In block  822 , the processor unit determines whether any adjustments are necessary, and if so, communicates them to the individual ICDs. Blocks  836 ,  838 , and  822  may form a loop that is periodically repeated. 
     Embodiments disclosed herein include: 
     A: A casing segment that comprises a conductive tubular body and at least one transmission crossover arrangement. Each transmission crossover arrangement has an adapter in communication with a coil antenna that encircles an exterior of the tubular body. 
     The embodiment, A, may have one or more of the following additional elements in any combination. Element 1: wherein the adapter comprises an inductive coil arranged along an interior of the tubular body. Element 2: wherein the adapter comprises an inductive coil arranged along an exterior of the tubular body, wherein the tubular body includes one or more nonconductive windows permitting passage of electromagnetic energy to the inductive coil. Element 3: wherein the adapter comprises an inductive coil arranged along an exterior recess of the tubular body, wherein the tubular body includes one or more nonconductive windows permitting passage of electromagnetic energy to the inductive coil. Element 4: wherein the adapter comprises inner wall electrodes coated with a passivation layer. Element 5: wherein the adapter comprises inner wall electrodes positioned in one or more channels along an inner wall of the conductive tubular body. Element 6: wherein the adapter corresponds to a galvanic coupling interface. Element 7: wherein the adapter corresponds to a capacitive coupling interface. Element 8: wherein each transmission crossover arrangement further comprises a control unit, each control unit having circuitry to direct EM transmissions or handle EM measurements acquired by a respective coil antenna. Element 9: wherein each control unit handles EM measurements acquired by a respective coil antenna in accordance with an addressing or modulation scheme that uniquely identifies signals associated with different transmission crossover arrangements. Element 10: wherein each transmission crossover arrangement further comprises an energy storage device. Element 11: wherein the at least one transmission crossover arrangement comprises a plurality of nonparallel external coils and a control unit that selectively operates the plurality of nonparallel external coils to provide multi-component transmission or reception. Element 12: wherein at least one coil antenna corresponding to the at least one transmission crossover arrangement is tilted. Element 13: further comprising at least one sensor along an interior of the tubular body, wherein the at least one sensor is in communication with the at least one transmission crossover arrangement. Element 14: further comprising at least one sensor along an exterior of the tubular body, wherein the at least one sensor is in communication with the at least one transmission crossover arrangement. Element 15: wherein each adapter is inductively coupled to a conductive path coil mounted to an inner tubular string deployed in a borehole. Element 16: wherein each adapter is inductively coupled to a conductive path coil that is part of a wireline service tool deployed in a borehole. Element 17: wherein each adapter galvanically or capacitively couples to a conductive path included with an inner tubular string deployed in a borehole. Element 18: wherein each adapter galvanically or capacitively couples to a conductive path included with a wireline service tool deployed in a borehole. Element 19: wherein the casing segment is deployed in a borehole as part of a casing string, and wherein the at least one transmission crossover arrangement is used to perform interwell tomography operations. Element 20: wherein the casing segment is deployed in a borehole as part of a casing string, and wherein the at least one transmission crossover arrangement is used to perform ranging operations to guide drilling of a new well. Element 21: wherein the casing segment is deployed in a borehole as part of a casing string, and wherein the at least one transmission crossover arrangement is used to transmit control signals to an inflow control device deployed in another borehole. Element 22: wherein the casing segment is deployed in a borehole as part of a casing string, and wherein the at least one transmission crossover arrangement is used to receive sensor measurements from an inflow control device deployed in another borehole. 
     Numerous variations and modifications will become apparent to those skilled in the art once the above disclosure is fully appreciated. For example, the foregoing disclosure focuses on the use of tilted and untilted magnetic dipole antennas, but the disclosed principles are applicable to external casing elements employing other transducer types including multicomponent electric dipoles and further including various magnetic field sensors such as fiberoptic sensors, MEMS sensors, and atomic magnetometers. As another example, the casing tubular need not provide a transmission crossover arrangement for each external element, but rather may have an array of longitudinally-spaced external elements that couple to a shared control unit and/or adapter. Array communications may be provided using an external cable or wireless near field communications. 
     As yet another example, the use of transmission crossover arrangements is not limited to casing, but rather may be employed for any pipe-in-pipe system including those wells employing multiple concentric production tubulars and those drilling systems employing concentric drilling tubulars. Further, it should be appreciated that surface interface components need not be at earth&#39;s surface in order to function. For example, one or more surface interface components may be below earth&#39;s surface and uphole relative to the transmission crossover arrangements being used. In subsea scenarios, surface interface components (or a corresponding unit) may be deployed, for example, along a seabed to provide an interface for transmission crossover arrangements deployed in a well that extends below the seabed. It is intended that, where applicable, the claims be interpreted to embrace all such variations and modifications.