Patent Publication Number: US-2023133939-A1

Title: Systems And Methods For Production And Reservoir Monitoring

Description:
BACKGROUND 
     Oilfield operators drill boreholes into subsurface reservoirs to recover oil and other hydrocarbons. If the reservoir has been partially drained or if the oil is particularly viscous, an oilfield operator will often inject fluids (e.g., water, steam, chemicals, gas, etc.) into the reservoir via. One or more injection wells to encourage the hydrocarbons to migrate toward the production well to be produced to the surface. Such operations are known as enhanced oil recovery (EOR) operations and infecting such fluids is often referred to as “flooding.” 
     Flooding can be tailored with varying fluid mixtures, flow rates/pressures, and injection sites, but may nevertheless be difficult to control due to inhomogeneity in the structure of the subsurface formations. The interface between the reservoir fluid and the injected fluid, often termed the “flood front” or the “waterflood front,” may develop protrusions and irregularities that may reach the production well before the bulk of the residual oil has been flushed from the reservoir. Proper management of the fluid front is essential for optimal recovery of oil and profitability of the water flooding operation. Improper management can create permanent, irreparable damage to well fields that can trap oil so that subsequent water flooding becomes futile. 
     To properly manage the fluid front, personnel may monitor the phase of fluids that are recovered from one or more boreholes. Additionally, one or more systems may be utilized to measure resistivity of the formation to identify movement of the fluid front. Current methods and systems monitoring the type of fluid flow in completions requires wireline- or coiled-tubing-conveyed production logging tools (e.g., fluid capacitance logging). These tools partially obstruct the flow in the production tubing and limits the capability of continuous monitoring of fluid flow properties. A less invasive system and method of monitoring fluid flow within production tubing and across a formation is needed. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       These drawings illustrate certain aspects of some of the embodiments of the present disclosure, and should not be used to limit or define the disclosure; 
         FIG.  1    is an example of a liner hanger disposed in a wellbore; 
         FIG.  2    is a cross-sectional view of a liner hanger system disposed in a wellbore; 
         FIGS.  3 A and  3 B  illustrate a slotted liner hanger; 
         FIG.  4    illustrates an electrical capacitance tomography (ECT) system disposed on a liner hanger. 
         FIG.  5    is a map of a sensing domain. 
         FIG.  6 A  is a map showing conductivity in the sensing domain; 
         FIG.  6 B  is a map showing permittivity in the sensing domain; 
         FIG.  7    is an example of a formation monitoring operation; 
         FIG.  8    is another example of the formation monitoring operation; 
         FIG.  9    is another example of the formation monitoring operation; 
         FIG.  10    is a workflow for production operations; and 
         FIG.  11    is a workflow for formation monitoring operations. 
     
    
    
     DETAILED DESCRIPTION 
     This disclosure presents systems and methods that utilize an electrical capacitance tomography (ECT) system to monitor production operations and formation monitoring operations simultaneously in accordance with one or more embodiments. As discussed below, the ECT system may perform as a dual monitoring system for simultaneous monitoring of production and formation fluids in open-hole completions. Production monitoring can be achieved by ECT sensors (e.g., electrodes) deployed around non-conducting sections of the production conduit. The ECT sensors may operate in the MHz range (i.e., 1 MHz to 1000 MHz) to provide time-lapse cross-sectional maps of the fluid flowing through the conduit. The same electrodes may be simultaneously excited with low frequency current, in the kHz range, for deep formation monitoring around the borehole. The ECT system may be disposed on a casing string or liner hanger system. 
       FIG.  1    illustrates an example of an expandable liner hanger system  100 . In expandable liner hanger system  100 , a casing string  102  has been installed and cemented within a wellbore  104 . An expandable liner hanger  108  may be hung, extending downhole from a lower end of casing string  102 . An annulus  106  may be created between casing string  102  and a work string  110 . In embodiments, an expandable liner hanger  108  may support additional wellbore casing, operational tubulars or tubing strings, completion strings, downhole tools, etc., for positioning at greater depths. 
     As used herein, the terms “liner,” “casing,” and “tubular” are used generally to describe tubular wellbore items, used for various purposes in wellbore operations. Liners, casings, and tubulars may be made from various materials (metal, plastic, composite, etc.), can be expanded or unexpanded as part of an installation procedure, and may be segmented or continuous. It is not necessary for a liner or casing to be cemented into position. Any type of liner, casing, or tubular may be used in keeping with the principles of the present disclosure. 
     As further illustrated in  FIG.  1   , expandable liner hanger  108  may be sealed and secured at an upper end of casing string  102 . Alternatively, expandable liner hanger  108  may be sealed and secured above a window (not shown) formed through a sidewall of casing string  102 , with expandable liner hanger  108  extending outwardly through the window into a branch or lateral wellbore. Without limitation, many different configurations and relative positions of casing string  102  and expandable liner hanger  108  may be possible. 
     In examples, as also shown in  FIG.  1   , a setting tool  112  may be connected proximate expandable liner hanger  108  on work string  110 . Work string  110  may convey setting tool  112  and expandable liner hanger  108  into wellbore  104 , conduct fluid pressure and flow, transmit torque, tensile and compressive force, etc. Setting tool  112  may facilitate conveyance and installation of expandable liner hanger  108 , in part by using the torque, tensile and compressive forces, fluid pressure and flow, etc., as delivered by work string  110 . 
     In  FIG.  1   , expandable liner hanger  108  is illustrated with a plurality of anchoring ridges  116  positioned on and attached to expandable liner hanger  108 . In examples, when expandable liner hanger  108  may be expanded, such as with an expansion cone, discussed below, into anchoring and sealing engagement with casing string  102 , the plurality of anchoring ridges  116  engage the interior of casing string  102 . It should be noted that in examples rubber elements may be used in conjunction with anchoring ridges  116 . However, in a geothermal well, expandable liner hanger  108  may experience swings in temperature, specifically, increases in temperature during geothermal well operations which may be detrimental to maintaining contact between expandable liner hanger  108  and casing string  102 . This may be due to fluid expansion exerting a force on expandable liner hanger  108 . For example, the body of expandable liner hanger  108  and anchoring ridges  116  may confine and trap fluid against casing string  102 . As temperatures fluctuate and rise in a geothermal well, the fluid may expand, which may push against casing string  102 , expandable liner hanger  108 , and anchoring ridges  116 . This may in turn lead anchoring ridges  116  dislodging from casing string  102  and the ultimate failure of expandable liner hanger  108 . 
       FIG.  2    depicts a cross-sectional view of expandable liner hanger  108  and anchoring ridges  116 . Without limitation, anchoring ridges  116  may be metal spikes. The metal spikes may be made of any suitable steel grade, aluminum, any other ductile material, and a combination thereof. In certain implementations, the spikes may be made from a combination of one or more of the recited materials. In certain embodiments, anchoring ridges  116  may be made from AISI4140 steel or AISI4340 steel. In examples, each anchoring ridge  116  may be a circular ring that extends along an outer perimeter of expandable liner hanger  108  at a desired axial location. However, the present disclosure is not limited to this particular configuration of anchoring ridges  116 . For instance, in certain embodiments, anchoring ridges  116  may extend along an axial direction of expandable liner hanger  108 . Moreover, in certain implementations, different anchoring ridges  116  may have different surface geometries without departing from the scope of the present disclosure. Specifically, a first spike may extend along an outer perimeter of expandable liner hanger  108  at a first axial position along expandable liner hanger  108  and a second spike may extend along an outer perimeter of expandable liner hanger  108  at a second axial position along expandable liner hanger  108 . 
     In examples, anchoring ridges  116  may be formed using any suitable methods known to those of ordinary skill in the art. For instance, in certain implementations, anchoring ridges  116  may be formed by machining the body of expandable liner hanger  108 . However, the present disclosure is not limited to machined spikes. Without limitation, any suitable methods known to one of ordinary skill in the art may be used to form anchoring ridges  116 . For instance, in examples, anchoring ridges  116  may be formed as a separate structure that may be coupled to expandable liner hanger  108  using any suitable coupling mechanisms known to one of ordinary skill in the art. Moreover, any number of anchoring ridges  116  may be formed along the axial direction of expandable liner hanger  108 . The number of anchoring ridges  116  formed along the axial direction of expandable liner hanger  108  may depend upon a number of factors such as, for example, the anchor load that is desired to be reached. 
     Accordingly, each of anchoring ridges  116  provide a metal-to-metal seal between expandable liner hanger  108  and casing string  102 . In examples, anchoring ridges  116  may have a flat top portion  200 . The use of anchoring ridges  116  with a flat top portion  200  as opposed to pointed spikes or threads may be beneficial because flat anchoring ridges  116  may be less sensitive to casing variations and have a higher load capacity than pointed spikes. Anchoring ridges  116  may be symmetrically aligned such that an angle θ is the same on both sides of each anchoring ridges  116  as shown in  FIG.  2   . However, in examples, the angle θ may be different on the opposing sides of anchoring ridges  116  without departing from the scope of the present disclosure. The angle θ is referred to herein as the “spike angle.” In examples, the spike angle ( 0 ) is selected such that after expansion, anchoring ridges  116  remain substantially normal to expandable liner hanger  108  body. For instance, in certain implementations, the spike angle ( 0 ) may be selected to be in a range of from approximately 30° to approximately 70°. 
     Moreover, as shown in  FIG.  2   , the dimension δ denotes the width of flat portion  200  of anchoring ridges  116  and is referred to herein as the spike width (δ). The spike width (δ) may be selected as desired such that expandable liner hanger  108  may expand without significant increase in expansion pressure while maintaining optimum contact area between anchoring ridges  116  and casing string  102 . Specifically, as anchoring ridges  116  are expanded, flat portion  200  of the spike interfaces with the inner surface of casing string  102  and may eventually couple expandable liner hanger  108  to casing string  102 . As shown in  FIG.  2   , the spacing between the anchoring ridges  116  along the length of expandable liner hanger  108  is denoted as “L”. The distance between the spikes (L) may be configured such that the deformation zones in casing string  102  induced by the anchoring ridges  116  may be isolated. The distance (L) may be selected to maximize the hanging capacity per spike. The term “hanging capacity” as used herein refers to the maximum downward load (anchor load) a hanger can carry without inducing an appreciable relative motion between the expandable liner hanger  108  and casing string  102  after the hanger is set in the casing. Accordingly, in certain implementations, it may not be desirable for the distance between the spikes (L) to fall below a certain threshold value. For instance, in examples, it may not be desirable for the distance between the spikes (L) to be less than three times the thickness of casing string  102 . Accordingly, the distance (L) between anchoring ridges  116  has an optimum value which is dependent upon a number of factors including, but not limited to, the outer diameter of the hanger (hanger OD), the hanger wall thickness, the inner diameter of the casing (casing ID) and the casing wall thickness. Moreover, the available length of expandable liner hanger  108  may limit the number of anchoring ridges  116  that may be placed thereon. Beyond this optimum value an increase in the distance (L) may no longer improve the hanging capacity per anchoring ridges  116 . 
     The height (H) of anchoring ridges  116  (and their resulting outer diameter (OD)) may be selected so that it is between an upper and a lower boundary. The upper spike height boundary may be selected as a function of the amount of flow area that is desired around expandable liner hanger. In contrast, the lower spike height boundary may be selected as a function of the distance desired between expandable liner hanger  108  and casing string  102 . Moreover, if the spike height is too large, it may destroy downhole equipment as it expands and if the spike height is too low, it wouldn&#39;t be able to support a liner as required. Configuration of the height (H) may cause a significant deformation of anchoring ridges  116  and an appreciable localized plastic deformation of the casing. Once anchoring ridges  116  of expandable liner hanger  108  are expanded, anchoring ridges  116  and the inner diameter of casing string  102  form multiple metal-to-metal seals. Accordingly, anchoring ridges  116  of expandable liner hanger  108  provide mechanical support for expandable liner hanger  108 . 
       FIG.  3 A  illustrates expandable liner hanger  108  attached to casing string  102  through one or more anchoring ridges  116 . Casing string  102  may be cemented with cement  300  to subterranean formation  302 . As further illustrated, liner hanger  108  may be disposed in open hole  304 , which may be identified as an open-hole completion. In such operations, liner hanger  108  may be slotted with one or more slots  306  (i.e., perforations) disposed in liner hanger  108 . One or more slots  306  may allow for formation fluids to pass from subterranean formation  302 , through liner hanger  108  and to the surface through casing string  102 . It should be noted that slots  306  may be any suitable size, length, and/or width. Additionally, slots  306  may be disposed on liner hanger  108  in any suitable arrangement and/or order. 
     During production operations, personnel may want to know and identify the type of formation fluid that may be moving through liner hanger  108  and casing string  102  as the formation fluid moves to the surface through casing string  102 . Methods and systems discussed bel may utilize electrical capacitance tomography (ECT) to determine the type of formation fluid moving through liner hanger  108  from subterranean formation  302  (e.g., referring to  FIG.  3 A ). ECT is a non-invasive imaging technique and system that may produce imaging (frame) rates in the hundreds of frames-per-second, thus enabling high-speed real-time measurements of fast reactions and physical flow processes. 
       FIG.  4    illustrates an operation in which an ECT system  400  may be utilized. As illustrated ECT system  400  may be disposed on liner hanger  108 , however, in other examples, ECT system  400  may be disposed on production tubing and/or casing string  102  and operate with the methods and systems discussed below. In examples with production tubing, production tubing may be disposed within liner hanger  108  and/or casing string  102 . Additionally, production tubing may be disposed in open hole  304  (e.g., referring to  FIG.  3   ) without liner hanger  108 . ECT system  400  may comprise an array of electrodes  402  disposed circumferentially around liner hanger  108 . Each electrode  402  may inject current into a sensing domain through capacitive coupling. A sensing domain is defined as the area in which current is injected to identify a property of a formation fluid  412  or the formation itself. In examples, the sensing domain may be within liner hanger  108  or outside of liner hanger  108  in subterranean formation  302 . Mutual impedance measurements may be taken across each electrode pair, and the resulting array of measurements is processed to reconstruct cross-sectional or volumetric conductivity and permittivity maps. With continue reference to  FIG.  4   , one or more electrodes  402  may be disposed on an outer surface of non-conductive section  404 . Non-conductive section  404  is a part of liner hanger  108  or disposed on liner hanger  108 . Non-conductive section  404  may be made of any suitable maters, such as, but not limited to, fiberglass, resin, ceramic, PEEK, etc. Disposing one or more electrodes  402  on non-conductive section  404  may prevent coupling between each electrode  402  during measurement operations. If electrodes  402  are disposed directly to a conductive part of liner hanger  108 , coupling may occur. Coupling is when current transmitted from an electrode moves directly to an adjacent electrode  402  disposed on liner hanger  108  or acquisition unit  408 , discussed below, without moving through subterranean formation  302 . This may skew measurements and may lead to an inability to determine formation fluids  412  moving through sensing domain  504  (e.g., referring to  FIG.  5   ). Removing coupling may allow capacitance tomography of production flow through the section of liner hanger  108  in which non-conductive section  404  is disposed. Capacitance tomography may be found by processing measurements taken by acquisition units  408 , discussed below. Processing may be performed by information handling system  406 . 
     Information handling system  406  may include any instrumentality or aggregate of instrumentalities operable to compute, estimate, classify, process, transmit, receive, retrieve, originate, switch, store, display, manifest, detect, record, reproduce, handle, or utilize any form of information, intelligence, or data for business, scientific, control, or other purposes. For example, an information handling system  406  may be a processing unit  414 , a network storage device, or any other suitable device and may vary in size, shape, performance, functionality, and price. Information handling system  406  may include random access memory (RAM), one or more processing resources such as a central processing unit (CPU) or hardware or software control logic, ROM, and/or other types of nonvolatile memory. Additional components of the information handling system  406  may include one or more disk drives, one or more network ports for communication with external devices as well as an input device  416  (e.g., keyboard, mouse, etc.) and video display  418 . Information handling system  406  may also include one or more buses operable to transmit communications between the various hardware components. 
     Alternatively, systems and methods of the present disclosure may be implemented, at least in part, with non-transitory computer-readable media  420 . Non-transitory computer-readable media  140  may include any instrumentality or aggregation of instrumentalities that may retain data and/or instructions for a period of time. Non-transitory computer-readable media  140  may include, for example, storage media such as a direct access storage device (e.g., a hard disk drive or floppy disk drive), a sequential access storage device (e.g., a tape disk drive), compact disk, CD-ROM, DVD, RAM, ROM, electrically erasable programmable read-only memory (EEPROM), and/or flash memory; as well as communications media such as wires, optical fibers, microwaves, radio waves, and other electromagnetic and/or optical carriers; and/or any combination of the foregoing. 
     Additionally, as illustrated, information handling system  406  may be connected to one or more acquisition units  408  through a communication line  410 . Acquisition units  408  may be permanently disposed downhole and may be connected to one or more electrodes  402  by any wired or wireless devices. During operations, acquisition units  408  may sequentially excite electrode pairs  402  disposed on liner hanger  108  with current and measure voltage across each electrode  402 . Generally, one acquisition unit  408  may be utilized for each is needed for an electrode station  702 , discussed below (e.g., referring to  FIG.  7   ). Measurements recorded by acquisition units  408  are communicated to information handling system  406 , which may be disposed at surface or in wellbore  104  (e.g., referring to  FIG.  1   ), through communication line  210 , which may be a fiber optic cable, wired cable, wirelines cable, and/or the like. 
       FIG.  5    illustrates a top-down view of liner hanger  108 . Specifically, a cut away view of liner hanger  108  at a location on liner hanger  108  in which non-conductive material  404  is disposed as part of liner hanger  108 . Additionally, one or more electrodes  402  for ECT system  400  are disposed on and/or in non-conductive material  404 . During operations, one or more electrodes  402  may operate to determine any number of fluids within sensing domain  504 . Measurements taken by one or more electrodes  402  may include electrical properties of the fluids within sensing domain  504 . Measurements may be processed and analyzed by information handling system  406  using the methods and systems described above. In this example, without limitation, there is a first fluid  500  and a second fluid  502  within sensing domain  504 . This may be performed by injecting a current in the MHz range through first fluid  500  and second fluid  502  using one or more electrodes  402 .  FIGS.  6 A and  6 B  illustrate measurements taken from ECT system  400  (i.e., referring to  FIG.  4   ). Specifically,  FIG.  6 A  is a cross-sectional map of measured conductivity and  FIG.  6 B  is a cross-sectional map of permittivity. These maps may be created on information handling system  406 , utilizing measurements taken by ECT system  400  and transmitted to information handling system  406  using the methods and systems described above. Using the measurements in  FIGS.  6 A and  6 B , the phase of measured formation fluids may be identified. 
       FIG.  7    illustrates an example where ECT system  400  may be utilized for monitoring of subterranean formation  302 . For  FIGS.  7 - 9   , sensing domain  504  is subterranean formation  302 . As illustrated, one or more electrode stations  702 , which include one or more electrodes  402 , disposed on non-conductive material  404  of liner hanger  108  may inject current  706  as a monopole excitation into subterranean formation  302 . Thus, all electrodes  402  may inject current  706  through subterranean formation  302  to a common current return  700  that is connected to information handling system  406  by a communication line  410 . It should be noted that current  706  injected into subterranean formation  302  may be in a frequency range of 0.1 Hz to 1 MHz. In examples, common current return  700  may be disposed in the surface. During measurement operations, as current  706  flows through subterranean formation  302  to common current return  700 , acquisition unit  408  may measure voltage by measuring a potential difference using a voltage reference. The potential difference may be measured between each electrode station  702  and potential reference point  704 . Additionally, acquisition unit  408  communicates measured voltage to the information handling system  406 . Thus, information handling system  406  may process the measured voltage to determine the resistivity distribution of the formation and the distance to a flood front. 
       FIG.  8    illustrates another example of an operation that utilizes ECT system  400  for formation monitoring. In the illustrated example, electrode stations  702  may emit current  7060  as a dipole excitation, where current  706  is injected into subterranean formation  302  from one electrode station  702  and returns to another electrode station  702 . In examples, the spacing between each electrode station  702  may determine the depth of current  706  penetration into subterranean formation  302 . For example, a distance of about ten feet (about 3 meters) between electrodes stations  702  may render current penetration of about ten feet (about 3 meters) into subterranean formation  302 . Additionally, information handling system  406  communicates simultaneously with one or more acquisition units  408  through one or more communication lines  410 . Thus, information handling system  406  may determine which electrode station  702  is operating at any point in time and where current  706  may originate from.  FIG.  9    illustrates an embodiment of  FIG.  8    in which a plurality of electrode stations  702  are daisy chained together. This may allow for multiplexing of the plurality of electrode stations  702  by information handling system  406  to cover an extended length of monitoring subterranean formation  302 . 
       FIG.  10    illustrates workflow  1000  for production operations that may be monitored by ECT system  400  (e.g., referring to  FIG.  4   ). During production operations, workflow  1000  may begin with block  1002 . In block  1002 , one or more currents may be injected by one or more electrodes  402  into a sensing domain, disposed within liner hanger  108  (e.g., referring to  FIG.  4   ). In block  1004 , a voltage (impedance) is measured across pairs of electrodes  402 . The measurements are transferred to information handling system  406  (e.g., referring to  FIG.  4   ). In block  1006 , the measurements may be processed by information handling system  406  to reconstruct a cross-sectional conductivity and permittivity map of the flow of formation fluid through the sensing domain at any time during production operations. In block  1008 , the phase of formation fluids in the sensing domain are determined utilizing the reconstructed maps of conductivity and permittivity. 
       FIG.  11    illustrates workflow  1100  for operations to monitor subterranean formation  302  (e.g., referring to  FIG.  3   ). During monitoring operations, workflow  1100  may begin with block  1102 . In block  1102 , one or more currents may be injected by one or more electrodes  402  into a sensing domain, which is subterranean formation  302 . In block  1104 , a voltage (impedance) is measured across pairs of electrodes  402 , which may be disposed at separate electrode stations  702  (e.g., referring to  FIG.  7   ). The measurements are transferred to information handling system  406  (e.g., referring to  FIG.  4   ). In block  1106 , the measurements may be processed by information handling system  406  to reconstruct resistivity logs that may be used as measurements of formation surrounding liner hanger  108 . In block  1108 , reservoir properties may be determined, such as distance to a waterflood front, utilizing the resistivity logs. 
     Generally, the electrical capacitance tomography (ECT) system and methods of operation discussed above is an improvement over current technology in that the ECT system and methods may be installed and operated at a relatively low cost compared to other imaging technologies, such as MRI or X-ray tomography. The methods described above may be performed simultaneously, which may allow for the same electrodes for capacitive tomography to be utilized for identifying production flow and further allow for galvanic sensing of formation fluids. Additionally, the ECT system is disposed on a non-conductive sections to production tubing or liner hangers to allow capacitance tomography of production flow. ECT improvement over current technology also encompass methods and systems that perform simultaneous use of the same electrodes on non-conductive section of liner hanger for capacitive tomography of production flow and galvanic sensing of formation fluids. 
     The preceding description provides various embodiments of systems and methods of use which may contain different method steps and alternative combinations of components. It should be understood that, although individual embodiments may be discussed herein, the present disclosure covers all combinations of the disclosed embodiments, including, without limitation, the different component combinations, method step combinations, and properties of the system. 
     Statement 1. A system may comprise at least one electrode station that is disposed on a non-conductive material, wherein the non-conductive material is at least a part of a conduit, and at least two electrodes coupled to the at least one electrode station, wherein the at least two electrodes are configured to inject a current into a sensing domain. The system may further comprise at least one acquisition unit that is configured to measure a voltage across the two electrodes of the at least one electrode station, and an information handling system connected to the at least one acquisition unit and configured to identify one or more electrical properties of the sensing domain from the measured voltage. 
     Statement 2. The system of statement 1, wherein the conduit is a production tubing disposed inside an outer casing. 
     Statement 3. The system of statements 1 or 2, wherein the conduit is a production tubing or a liner hanger disposed inside an open-hole section of a wellbore. 
     Statement 4. The system in statement 3, wherein the production tubing or the liner hanger have one or more perforations or one or more slots. 
     Statement 5. The system of any preceding statements 1, 2, or 3, wherein the non-conductive material is fiberglass. 
     Statement 6. The system of any preceding statements 1-3, or 5, wherein the at least two electrodes are disposed circumferentially on an outer surface of the non-conductive material. 
     Statement 7. The system any preceding statements 1-3, 5, or 6, wherein the sensing domain is inside the conduit, the current is in a range from 1 MHz to 1000 MHz, and the current is capacitively coupled through the non-conductive material and one or more fluids within the sensing domain to the at least two electrodes. 
     Statement 8. The system any preceding statements 1-3, or 5-7, wherein the information handling system is further configured to reconstruct a cross-sectional conductivity and a cross-sectional permittivity of the sensing domain. 
     Statement 9. The system of statement 8, wherein the information handling system is further configured to identifying one or more phases of a formation fluid in the sensing domain utilizing the cross-sectional conductivity or the cross-sectional permittivity. 
     Statement 10. The system any preceding statements 1-3 or 5-8, wherein the information handling system is disposed at surface and a fiber optic cable connect the information handling system to the at least one acquisition unit. 
     Statement 11. The system any preceding statements 1-3, 5-8, or 10, wherein the sensing domain is disposed in a subterranean formation, and the current flows through the subterranean formation surrounding the at least one electrode station to a current return, and the voltage is measured relative to a voltage reference. 
     Statement 12. The system of statement 11, wherein the current is in a frequency range of 0.1 Hz to 1 MHz, and is coupled conductively or capacitively into the subterranean formation. 
     Statement 13. The system of statement 11, wherein the information handling system is further configured to identify a resistivity of the subterranean formation from the current and the voltage. 
     Statement 14. The system of statement 11, wherein the current is injected simultaneously into two or more sensing domains and the at least one acquisition until is configured to use frequency division multiplexing to separate one or more responses within the two or more sensing domains. 
     Statement 15. The system of statement 11, wherein the acquisition unit is configured to measure a potential difference of the current flowing between a first electrode station and a second electrode station and the information handling system is further configured to identifying a formation resistivity from the potential difference. 
     Statement 16. The system of statement 11, wherein each electrode stations is separated from another electrode station by one or more distances. 
     Statement 17. A method may comprise injecting a current into a sensing domain with at least two electrodes disposed on at least one electrode station, measuring a voltage across the at least two electrodes at the at least one electrode station using an acquisition unit, and sending the measured voltage to an information handling system connected to the acquisition unit by at least one communication line. 
     Statement 18. The method of statement 17, further comprising constructing a cross-sectional conductivity and a cross-sectional permittivity of the sensing domain with the measured voltage using the information handling system. 
     Statement 19. The method of statement 18, further comprising identifying one or more phases of a formation fluid in the sensing domain utilizing the cross-sectional conductivity or the cross-sectional permittivity. 
     Statement 20. The method of statements 17 or 18, further comprising injecting the current into two or more sensing domains simultaneously with the at least two electrodes. 
     It should be understood that the compositions and methods are described in terms of “comprising,” “containing,” or “including” various components or steps, the compositions and methods can also “consist essentially of” or “consist of” the various components and steps. Moreover, the indefinite articles “a” or “an,” as used in the claims, are defined herein to mean one or more than one of the elements that it introduces. 
     Therefore, the present embodiments are well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. The particular embodiments disclosed above are illustrative only, as the present disclosure may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Although individual embodiments are discussed, the disclosure covers all combinations of all those embodiments. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. Also, the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee. It is therefore evident that the particular illustrative embodiments disclosed above may be altered or modified and all such variations are considered within the scope and spirit of the present disclosure. If there is any conflict in the usages of a word or term in this specification and one or more patent(s) or other documents that may be incorporated herein by reference, the definitions that are consistent with this specification should be adopted.