Patent Publication Number: US-8528635-B2

Title: Tool to determine formation fluid movement

Description:
BACKGROUND OF THE DISCLOSURE 
     Wells are generally drilled into the ground or ocean bed to recover natural deposits of oil and gas, as well as other desirable materials that are trapped in geological formations in the Earth&#39;s crust. Wells are typically drilled using a drill bit attached to the lower end of a “drill string.” Drilling fluid, or mud, is typically pumped down through the drill string to the drill bit. The drilling fluid lubricates and cools the bit, and may additionally carry drill cuttings from the borehole back to the surface. 
     In various oil and gas exploration operations, it may be beneficial to have information about the subsurface formations that are penetrated by a borehole. For example, certain formation evaluation schemes include measurement and analysis of the formation pressure and permeability. These measurements may be essential to predicting the production capacity and production lifetime of the subsurface formation. 
     Reservoir well production and testing may involve drilling into the subsurface formation and the monitoring of various subsurface formation parameters. When drilling and monitoring, downhole tools having electric, mechanic, and/or hydraulic powered devices may be used. In some implementations, pump systems may be used to draw and pump formation fluid from subsurface formations. A downhole string (e.g., a drill string, coiled tubing, slickline, wireline, etc.) may include one or more pump systems depending on the operations to be performed using the downhole string, or the string may have fluids pumped therein from a surface of the formation. 
     In a downhole flow analysis environment, the naturally occurring hydrocarbon fluids may include dry natural gas, wet gas, condensate, light oil, black oil, heavy oil, and heavy viscous tar. In addition, water and synthetic fluids, such as oils used within drilling muds, and fluids used in formation fracturing jobs, may also be present within the downhole environment. 
     As the economic value of a hydrocarbon reserve, the method of production, the efficiency of recovery, the design of production equipment, in addition to a number of other factors, all depend upon a number of flow parameters, such as physical properties, phase behavior and flow rates of the fluid, it is important that the flow parameters be determined accurately. As such, it may be valuable to determine the movement of fluid when present within a formation, for example, to assist in determining the value of a hydrocarbon reserve and formation, or at least a portion thereof. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       The present disclosure is best understood from the following detailed description when read with the accompanying figures. It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale. In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion. 
         FIG. 1  is a side view of apparatus according to one or more aspects of the present disclosure. 
         FIG. 2  is a side view of apparatus according to one or more aspects of the present disclosure. 
         FIG. 3  is a schematic view of apparatus according to one or more aspects of the present disclosure. 
         FIG. 4  is a side view of apparatus according to one or more aspects of the present disclosure. 
         FIG. 5  is a side view of apparatus according to one or more aspects of the present disclosure. 
         FIG. 6  is a side view of apparatus according to one or more aspects of the present disclosure. 
         FIG. 7  is a schematic view of apparatus according to one or more aspects of the present disclosure. 
         FIG. 8  is a schematic view of apparatus according to one or more aspects of the present disclosure. 
     
    
    
     DETAILED DESCRIPTION 
     It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments. Specific examples of components and arrangements are described below to simplify the present disclosure. These are, of course, merely examples and are not intended to be limiting. In addition, the present disclosure may repeat reference numerals and/or letters in the various examples. This repetition is for the purpose of simplicity and clarity and does not in itself dictate a relationship between the various embodiments and/or configurations discussed. Moreover, by forming a first feature over or on a second feature in the description that follows may include embodiments in which the first and second features are formed in direct contact, and may also include embodiments in which additional features may be formed interposing the first and second features, such that the first and second features may not be in direct contact. 
     Referring now to  FIG. 1 , illustrated is a side view of a wellsite  100  having a drilling rig  110  with a drill string  112  suspended therefrom in accordance with one or more aspects of the present disclosure. The wellsite  100  shown, or one similar thereto, may be used within onshore and/or offshore locations. As shown, a borehole  114  may be formed within a subsurface formation F, such as by using rotary drilling, or any other method known in the art. As such, aspects of the present disclosure may be used within a wellsite, similar to the one as shown in  FIG. 1  (discussed more below). Those having ordinary skill in the art will appreciate that the present disclosure may be used within other wellsites or drilling operations, such as within a directional drilling application, without departing from the scope of the present disclosure. 
     Continuing with  FIG. 1 , the drill string  112  may suspend from the drilling rig  110  into the borehole  114 . The drill string  112  may include a bottom hole assembly  118  and a drill bit  116 , in which the drill bit  116  may be disposed at an end of the drill string  112 . The surface of the wellsite  100  may have the drilling rig  110  positioned over the borehole  114 , and the drilling rig  110  may include a rotary table  120 , a kelly  122 , a traveling block or hook  124 , and may additionally include a rotary swivel  126 . The rotary swivel  126  may be suspended from the drilling rig  110  through the hook  124 , and the kelly  122  may be connected to the rotary swivel  126  such that the kelly  122  may rotate with respect to the rotary swivel. 
     An upper end of the drill string  112  may be connected to the kelly  122 , such as by threadingly connecting the drill string  112  to the kelly  122 , and the rotary table  120  may rotate the kelly  122 , thereby rotating the drill string  112  connected thereto. As such, the drill string  112  may be able to rotate with respect to the hook  124 . Those having ordinary skill in the art, however, will appreciate that though a rotary drilling system is shown in  FIG. 1 , other drilling systems may be used without departing from the scope of the present disclosure. For example, a top-drive (also known as a “power swivel”) system may be used in accordance with the present disclosure. In such a top-drive system, the hook  124 , swivel  126 , and kelly  122  are replaced by a drive motor (electric or hydraulic) that may apply rotary torque and axial load directly to drill string  112 . 
     The wellsite  100  may further include drilling fluid  128  (also known as drilling “mud”) stored in a pit  130 . The pit  130  may be formed adjacent to the wellsite  100 , as shown, in which a pump  132  may be used to pump the drilling fluid  128  into the wellbore  114 . The pump  132  may pump and deliver the drilling fluid  128  into and through a port of the rotary swivel  126 , thereby enabling the drilling fluid  128  to flow into and downwardly through the drill string  112 , the flow of the drilling fluid  128  indicated generally by direction arrow  134 . This drilling fluid  128  may then exit the drill string  112  through one or more ports disposed within and/or fluidly connected to the drill string  112 . For example, the drilling fluid  128  may exit the drill string  112  through one or more ports formed within the drill bit  116 . 
     The drilling fluid  128  may flow back upwardly through the borehole  114 , such as through an annulus  136  formed between the exterior of the drill string  112  and the interior of the borehole  114 , the flow of the drilling fluid  128  indicated generally by direction arrow  138 . With the drilling fluid  128  following the flow pattern of direction arrows  134  and  138 , the drilling fluid  128  may be able to lubricate the drill string  112  and the drill bit  116 , and/or may be able to carry formation cuttings formed by the drill bit  116  (or formed by any other drilling components disposed within the borehole  114 ) back to the surface of the wellsite  100 . This drilling fluid  128  may be filtered and cleaned and/or returned back to the pit  130  for recirculation within the borehole  114 . 
     Though not shown, the drill string  112  may include one or more stabilizing collars. A stabilizing collar may be disposed within and/or connected to the drill string  112 , in which the stabilizing collar may be used to engage and apply a force against the wall of the borehole  114 . This may enable the stabilizing collar to prevent the drill string  112  from deviating from the desired direction for the borehole  114 . For example, during drilling, the drill string  112  may “wobble” within the borehole  114 , thereby enabling the drill string  112  to deviate from the desired direction of the borehole  114 . This wobble may also be detrimental to the drill string  112 , components disposed therein, and the drill bit  116  connected thereto. However, a stabilizing collar may be used to minimize, if not overcome altogether, the wobble action of the drill string  112 , thereby possibly increasing the efficiency of the drilling performed at the wellsite  100  and/or increasing the overall life of the components at the wellsite  100 . 
     As discussed above, the drill string  112  may include a bottom hole assembly  118 , such as by having the bottom hole assembly  118  disposed adjacent to the drill bit  116  within the drill string  112 . The bottom hole assembly  118  may include one or more components included therein, such as components to measure, process, and store information. The bottom hole assembly  118  may include components to communicate and relay information to the surface of the wellsite. 
     In  FIG. 1 , the bottom hole assembly  118  may include one or more logging-while-drilling (“LWD”) tools  140  and/or one or more measuring-while-drilling (“MWD”) tools  142 . The bottom hole assembly  118  may also include a steering-while-drilling system (e.g., a rotary-steerable system) and motor  144 , in which the rotary-steerable system and motor  144  may be coupled to the drill bit  116 . 
     The LWD tool  140  shown in  FIG. 1  may include a thick-walled housing, commonly referred to as a drill collar, and may include one or more of a number of logging tools known in the art. Thus, the LWD tool  140  may be capable of measuring, processing, and/or storing information therein, as well as capabilities for communicating with equipment disposed at the surface of the wellsite  100 . 
     The MWD tool  142  may also include a housing (e.g., drill collar), and may include one or more of a number of measuring tools known in the art, such as tools used to measure characteristics of the drill string  112  and/or the drill bit  116 . The MWD tool  142  may also include an apparatus for generating and distributing power within the bottom hole assembly  118 . For example, a mud turbine generator powered by flowing drilling fluid therethrough may be disposed within the MWD tool  142 . Alternatively, other power generating sources and/or power storing sources (e.g., a battery) may be disposed within the MWD tool  142  to provide power within the bottom hole assembly  118 . The MWD tool  142  may include one or more of the following measuring tools: a weight-on-bit measuring device, a torque measuring device, a vibration measuring device, a shock measuring device, a stick slip measuring device, a direction measuring device, an inclination measuring device, and/or any other device known in the art used within an MWD tool. 
     Referring now to  FIG. 2 , illustrated is a side view of a tool  200  in accordance with one or more aspects of the present disclosure. The tool  200  may be connected to and/or included within a drill string  202 , in which the tool  200  may be disposed within a borehole  204  formed within a subsurface formation F. As such, the tool  200  may be included and used within a bottom hole assembly, as described above. 
     Particularly, the tool  200  may include a sampling-while drilling (“SWD”) tool, such as that described within U.S. Pat. No. 7,114,562, filed on Nov. 24, 2003, entitled “Apparatus and Method for Acquiring Information While Drilling,” and incorporated herein by reference in its entirety. The tool  200  may include a probe  210  to hydraulically establish communication with the formation F and draw formation fluid  212  into the tool  200 . 
     The tool  200  may also include a stabilizer blade  214  and/or one or more pistons  216 . The probe  210  may be disposed on the stabilizer blade  214  and extend therefrom to engage the wall of the borehole  204 . The pistons, if present, may also extend from the tool  200  to assist probe  210  in engaging with the wall of the borehole  204 . In alternative configurations, though, the probe  210  may not necessarily engage the wall of the borehole  204  when drawing fluid. 
     Fluid  212  drawn into the tool  200  may be measured to determine one or more parameters of the formation F, such as pressure and/or pretest parameters of the formation F. Additionally, the tool  200  may include one or more devices, such as sample chambers or sample bottles, that may be used to collect formation fluid samples. These formation fluid samples may be retrieved back at the surface with the tool  200 . Alternatively, rather than collecting formation fluid samples, the formation fluid  212  received within the tool  200  may be circulated back out into the formation F and/or borehole  204 . A pumping system may be included within the tool  200  to pump the formation fluid  212  circulating within the tool  200 . For example, the pumping system may be used to pump formation fluid  212  from the probe  210  to the sample bottles and/or back into the formation F. Alternatively still, rather than collecting formation fluid samples, a tool in accordance with the present disclosure may be used to collect samples from the formation F, such as one or more coring samples from the wall of the borehole  204 . 
     Referring now to  FIG. 3 , illustrated is a schematic view of a tool  300  in accordance with one or more aspects of the present disclosure. The tool  300  may be connected to and/or included within a bottom hole assembly, in which the tool  300  may be disposed within a borehole  304  formed within a subsurface formation F. 
     The tool  300  may be a pressure LWD tool used to measure one or more downhole pressures, including annular pressure, formation pressure, and pore pressure, before, during, and/or after a drilling operation. Those having ordinary skill in the art will appreciate that other pressure LWD tools may also be utilized in accordance with the present disclosure, such as that described within U.S. Pat. No. 6,986,282, filed on Feb. 18, 2003, entitled “Method and Apparatus for Determining Downhole Pressures During a Drilling Operation,” and incorporated herein by reference. 
     As shown, the tool  300  may be formed as a modified stabilizer collar  310 , similar to a stabilizer collar as described above, and may have a passage  312  formed therethrough for drilling fluid. The flow of the drilling fluid through the tool  300  may create an internal pressure P 1 , and the exterior of the tool  300  may be exposed to an annular pressure P A  of the surrounding borehole  304  and formation F. A differential pressure P δ  formed between the internal pressure P 1  and the annular pressure P A  may then be used to activate one or more pressure devices  316  included within the tool  300 . 
     The tool  300  may include two pressure measuring devices  316 A and  316 B that may be disposed on stabilizer blades  318  formed on the stabilizer collar  310 . The pressure measuring device  316 A may be used to measure the annular pressure P A  in the borehole  304 , and/or may be used to measure the pressure of the formation F when positioned in engagement with a wall  306  of the borehole  304 . As shown in  FIG. 3 , the pressure measuring device  316 A is not in engagement with the borehole wall  306 , thereby enabling the pressure measuring device  316 A to measure the annular pressure P A , if desired. However, when the pressure measuring device  316 A is moved into engagement with the borehole wall  306 , the pressure measuring device  316 A may be used to measure pore pressure of the formation F. 
     As also shown in  FIG. 3 , the pressure measuring device  316 B may be extendable from the stabilizer blade  318 , such as by using a hydraulic control disposed within the tool  300 . When extended from the stabilizer blade  318 , the pressure measuring device  316 B may establish sealing engagement with the wall  306  of the borehole  304  and/or a mudcake  308  of the borehole  304 . This may enable the pressure measuring device  316 B to take measurements of the formation F also. Other controllers and circuitry, not shown, may be used to couple the pressure measuring devices  316  and/or other components of the tool  300  to a processor and/or a controller. This processor and/or controller may then be used to communicate the measurements from the tool  300  to other tools within a bottom hole assembly or to the surface of a wellsite. A pumping system may be included within the tool  300 , such as including the pumping system within one or more of the pressure devices  316  for activation and/or movement of the pressure devices  316 . 
     Referring now to  FIG. 4 , illustrated is a side view of a tool  400  in accordance with one or more aspects of the present disclosure. As shown, the tool  400  may be a “wireline” tool, in which the tool  400  may be suspended within a borehole  404  formed within a subsurface formation F. The tool  400  may be suspended from an end of a multi-conductor cable  406  located at the surface of the formation F, such as by having the multi-conductor cable  406  spooled around a winch (not shown) disposed on the surface of the formation F. The multi-conductor cable  406  is then couples the tool  400  with an electronics and processing system  408  disposed on the surface. 
     The tool  400  may have an elongated body  410  that includes a formation tester  412  disposed therein. The formation tester  412  may include an extendable probe  414  and an extendable anchoring member  416 , in which the probe  414  and anchoring member  416  may be disposed on opposite sides of the body  410 . One or more other components  418 , such as a measuring device, may also be included within the tool  400 . 
     The probe  414  may be included within the tool  400  such that the probe  414  may be able to extend from the body  410  and then selectively seal off and/or isolate selected portions of the wall of the borehole  404 . This may enable the probe  414  to establish pressure and/or fluid communication with the formation F to draw fluid samples from the formation F. The tool  400  may also include a fluid analysis tester  420  that is in fluid communication with the probe  414 , thereby enabling the fluid analysis tester  420  to measure one or more properties of the fluid. The fluid from the probe  414  may also be sent to one or more sample chambers or bottles  422 , which may receive and retain fluids obtained from the formation F for subsequent testing after being received at the surface. The fluid from the probe  414  may also be sent back out into the borehole  404  or formation F. 
     Referring now to  FIG. 5 , illustrated is a side view of another tool  500  in accordance with one or more aspects of the present disclosure. Similar to  FIG. 4 , the tool  500  may be suspended within a borehole  504  formed within a subsurface formation F using a multi-conductor cable  506 . The multi-conductor cable  506  may be supported by a drilling rig  502 . 
     As shown, the tool  500  may include one or more packers  508  that may be configured to inflate, thereby selectively sealing off a portion of the borehole  504  for the tool  500 . To test the formation F, the tool  500  may include one or more probes  510 , and the tool  500  may also include one or more outlets  512  that may be used to inject fluids within the sealed portion established by the packers  508  between the tool  500  and the formation F. 
     Referring now to  FIG. 6 , illustrated is a side view of a wellsite  600  having a drilling rig  610  in accordance with one or more aspects of the present disclosure. A borehole  614  may be formed within a subsurface formation F, such as by using a drilling assembly, or any other method known in the art. A wired pipe string  612  may be suspended from the drilling rig  610 . The wired pipe string  612  may be extended into the borehole  614  by threadably coupling multiple segments  620  (i.e., joints) of wired drill pipe together in an end-to-end fashion. The wired drill pipe segments  620  may be similar to that as described within U.S. Pat. No. 6,641,434, filed on May 31, 2002, entitled “Wired Pipe Joint with Current-Loop Inductive Couplers,” and incorporated herein by reference. 
     Wired drill pipe may be structurally similar to that of typical drill pipe, however the wired drill pipe may additionally include a cable installed therein to enable communication through the wired drill pipe. The cable installed within the wired drill pipe may be any type of cable capable of transmitting data and/or signals therethrough, such an electrically conductive wire, a coaxial cable, an optical fiber cable, and or any other cable known in the art. The wired drill pipe may include having a form of signal coupling, such as having inductive coupling, to communicate data and/or signals between adjacent pipe segments assembled together. 
     The wired pipe string  612  may include one or more tools  622  and/or instruments disposed within the pipe string  612 . For example, as shown in  FIG. 6 , a string of multiple borehole tools  622  may be coupled to a lower end of the wired pipe string  612 . The tools  622  may include one or more tools used within wireline applications, may include one or more LWD tools, may include one or more formation evaluation or sampling tools, and/or may include any other tools capable of measuring a characteristic of the formation F. 
     The tools  622  may be connected to the wired pipe string  612  during drilling the borehole  614 , or, if desired, the tools  622  may be installed after drilling the borehole  614 . If installed after drilling the borehole  614 , the wired pipe string  612  may be brought to the surface to install the tools  622 , or, alternatively, the tools  622  may be connected or positioned within the wired pipe string  612  using other methods, such as by pumping or otherwise moving the tools  622  down the wired pipe string  612  while still within the borehole  614 . The tools  622  may then be positioned within the borehole  614 , as desired, through the selective movement of the wired pipe string  612 , in which the tools  622  may gather measurements and data. These measurements and data from the tools  622  may then be transmitted to the surface of the borehole  614  using the cable within the wired drill pipe  612 . 
     An apparatus, a system, and one or more methods of using an apparatus and a system, in accordance with the present disclosure, may be included within the tools and/or devices shown in  FIGS. 1-6 , in addition to being included within other tools and/or devices that may be disposed within a formation. The apparatus, thus, may be used to determine fluid movement in a formation. For example, the apparatus, or a system incorporating the apparatus or elements of the apparatus, may be used to pump fluid into a formation, such as a fluid having a tracer element, in which the apparatus may be used to determine the movement of the fluid within the formation. Based upon this movement of the fluid within the formation, one or more properties and/or characteristics of the formation may be determined. For example, the mobility of the fluid within the formation may be determined based upon the movement of the fluid within the formation. 
     An apparatus in accordance with the present disclosure may include, at least, a first packer configured to selectively engage a wall of a borehole of a formation. For example, a borehole may be formed within a formation, in which the first packer may be used to engage a wall of the borehole, such as by sealingly engage the wall of the borehole. The system may further include an outlet disposed adjacent to the first packer, in which the outlet may be configured to have a first fluid pumped therefrom into the formation. In addition to having a first fluid pumped therefrom, the outlet may additionally be configured to have a second fluid pumped therefrom into the formation. When having the first fluid and the second fluid pumped into the formation, the outlet may alternate between having the first fluid pumped therefrom and having the second fluid pumped therefrom, or the outlet may have the first fluid and the second fluid pumped simultaneously therefrom. At one moment, the first fluid may be pumped from the outlet of the apparatus, in which the second fluid may then, in addition or in alternative, be pumped from the outlet of the apparatus. 
     Additionally, the apparatus may have a detecting tool included therewith, in which the detecting tool may be configured to detect the first fluid within the formation. For example, the detecting tool may be disposed adjacent to the first packer of the apparatus, in which the first fluid pumped from the outlet of the apparatus may be detected by the detecting tool of the apparatus. The detecting tool may be an inducting tool. As such, the induction tool may be used to detect the first fluid within the formation, such as by having the induction tool measure a resistivity of the first fluid within the formation. 
     The first fluid may have a tracer element included therewith or disposed therein. When the detecting tool is used to detect the first fluid within the formation, the detecting tool may detect the tracer element of the first fluid. Accordingly, the first fluid may be brine, in which the detecting tool may be used to detect the resistivity of the brine within the formation. The second fluid may be water, for example. 
     Referring now to  FIG. 7 , illustrated is a schematic view of an apparatus  701  in accordance with one or more aspects of the present disclosure. The apparatus  701  may include a housing  703 , such as a generally cylindrical shaped housing, in which the housing  703  may have an axis extending therethrough. As shown, the apparatus  701  may be disposed downhole into a borehole  711  formed within a formation F. As such, and as discussed further below, the apparatus  701  may be used to determine fluid movement in the formation F. 
     As shown, the apparatus  701  may include one or more packers  705 , in which the packers  705  may be used to selectively engage a wall  713  of the borehole  711  of the formation F. For example, the apparatus  701  includes a first packer  705 A and a second packer  705 B, in which each of the packers  705 A and  705 B may be used to selectively engage the wall  713  of the borehole  711 . Particularly, the packers  705  may be used to sealingly engage the wall  713  of the borehole  711 , thereby preventing fluid from flowing across the surfaces between the wall  713  of the borehole  711  and the packers  705 . As shown, as the packers  705  may be used to selectively engage the wall  713  of the borehole  711 , such as when desired, the packers  705  may be activated, when desired, to engage the wall  713  of the borehole  711 . One or more of the packers  705  may be inflatable, in which the packers  705  may then be inflated when desired to have the packers  705  engage the wall  713  of the borehole  711 . Those having ordinary skill in the art will appreciate, however, that other structures and/or mechanisms may be used for the packers of the present disclosure such that the packers selectively engage the wall of the borehole. 
     The apparatus  701  may include one or more outlets included therein, in which the outlets may be used to have fluid pumped therefrom. For example, as shown, the apparatus  701  may include one or more outlets  707 , such as by having one or more probes, disposed adjacent to one or more of the packers  705 , in which the outlets  707  may be used to have a fluid pumped therefrom, such as to have fluid pumped into the formation F. As the apparatus  701  may include two packers  705 A and  705 B, the outlets  707  may be formed within the apparatus  701  and adjacent to the packers  705 A and  705 B such that the outlets  707  are disposed between the packers  705 A and  705 B. As such, as the outlets  707  have fluid pumped therefrom, the fluid may be pumped from the apparatus  707  through the outlets  707 , in which the fluid may enter the borehole  711 . As the packers  705  may be used to engage the wall  713  of the borehole  711 , such as by sealingly engaging the wall  713  of the borehole  711 , fluid may be prevented from moving across the packers  705 . Fluid may enter the formation F as pressure increases from having fluid pumped out through the outlets  707 . 
     The one or more outlets  707  may be used to have at least one fluid pumped therefrom and into the formation F. The outlets  707  may be used to have a first fluid and a second fluid pumped therefrom. For example, apparatus  701  may include one or more containers  721  formed therein, in which fluids may be disposed within the containers  721  of the apparatus  701 . The containers  721  may be fluidly coupled to the outlets  707  such that fluid disposed within the containers  721  may be pumped from the containers  721  and through the outlets  707 . 
     In  FIG. 7 , the apparatus  701  may include a first container  721 A and a second container  721 B, in which a first fluid  723 A may be disposed within the first container  721 A and a second fluid  723 B may be disposed within the second container  721 B. The containers  721 A and  721 B may be fluidly coupled to the outlets  707 , such as by having one or more flowlines  725  within the apparatus  701  that fluidly couple the containers  721 A and  721 B to the outlets  707 . The fluids  723 A and  723 B disposed within the containers  721 A and  721 B may be pumped from the containers  721 A and  721 B and through the outlets  707 . 
     As shown, the apparatus  701  may include one or more pumps  727  included therewith, in which the pumps  727  may be used to pump the fluid  723  through the outlets  707 . For example, as shown, the apparatus  701  may include a pump  727  fluidly coupled to the flowline  725  between the containers  721 A and  721 B and the outlets  707 , thereby enabling fluid  723  to be pumped through the outlets  707 . Those having ordinary skill in the art will appreciate that the pump in accordance with the present disclosure may be a hydraulic pump, an electric pump, and/or any other pump known in the art. 
     As discussed above, the outlets  707  may be used to have the first fluid  723 A and  723 B pumped therefrom and into the formation F. When having fluid pumped therefrom, the apparatus  701  may be used to selectively pump the first fluid  723 A and/or the second fluid  723 B through the outlets  707 . For example, as shown, one or more valves  729  may be included within the apparatus  701 , in which the valves  729  may be selectively opened and closed to selectively pump the first fluid  723 A and/or the second fluid  723 B through the outlets  707 . Accordingly, a first valve  729 A may be fluidly coupled to the first container  721 A, in which the first valve  729 A may be selectively opened and closed to have the first fluid  723 A pumped from the first container  721 A and through the outlets  707 , and a second valve  729 B may be fluidly coupled to the second container  721 B, in which the second valve  729 B may be selectively opened and closed to have the second fluid  723 B pumped from the second container  721 B and through the outlets  707 . 
     As mentioned, when having fluid pumped from the outlets  707 , the apparatus  701  may be used to selectively pump the first fluid  723 A and/or the second fluid  723 B through the outlets  707 . As such, in one arrangement, the outlets  707  may alternate between having the first fluid  723 A pumped therefrom and having the second fluid  723 B pumped therefrom. In another arrangement, when having fluid pumped therefrom, the outlets  707  may have the first fluid  723 A and the second fluid  723 B simultaneously pumped therefrom. The fluids  723 A and  723 B may be pumped through the outlets  707  to have a desired ratio of the first fluid  723 A pumped through the outlets  707  to the second fluid  723 B pumped through the outlets  707 . The first fluid  723 A may be pumped from the one or more outlets  707  of the apparatus  701 , in which the second fluid  723 B may then, in addition or in alternative, be pumped from the outlets  707  of the apparatus  701 . Accordingly, the valves  729 A and  729 B may be selectively operated (e.g., opened and closed), as desired, to have the first fluid  723 A and/or the second fluid  723 B pumped through the outlets  707 . 
     Referring still to  FIG. 7 , the apparatus  701  may include a detecting tool  731 , such as by having a detecting tool  731  disposed therein and/or included therewith. The detecting tool  731  may be used to detect one or more fluids within the formation F. For example, as discussed above, the apparatus  701  may be used to pump the first fluid  723 A and the second fluid  723 B into the formation F. As such, the detecting tool  731  may be used to detect at least one of the fluids  723 A and  723 B in the formation F. When only one fluid is pumped into the formation F, the detecting tool  731  may be used to detect the one fluid pumped into the formation F. 
     In addition to the detecting tool  731  being used to detect the first fluid  723 A within the formation F, the detecting tool  731  may be used to measure one or more properties of the first fluid  723 A pumped within the formation F. For example, the detecting tool  731  may be used to detect/measure a property of the first fluid  731 , such as a density, viscosity, temperature, pressure, resistivity, gas content, and/or any other property of the first fluid  731  pumped into the formation F. 
     The detecting tool  731  may include an induction tool, in which the induction tool may be used to measure a resistivity of first fluid disposed within the formation. For example, the Rt Scanner triaxial induction tool, provided by Schlumberger, may be used as an induction tool in accordance with the present disclosure, in which the induction tool may be used to measure resistivity within a formation at different depths-of-investigation in three orthogonal directions (i.e., x, y, and z directions). A transmitter may be included within the induction tool, in which the transmitter may transmit energy, such as electromagnetic energy, into the formation in up to three orthogonal directions. The induction tool may include one or more receivers, such as a main receiver and a balancing receiver, to receive and measure the effects of the energy transmitted into the formation. The induction tool may be used to measure the resistivity within the formation at various ranges and depths-of-investigation. 
     In accordance with the present disclosure, one or more of the fluids pumped into the formation may include one or more tracer elements therein. By having a tracer element therein, the detecting tool may be used to detect the tracer element within the fluid. In addition, when the detecting tool is used to measure one or more properties of the fluid, the detecting tool may be used to measure the quantity and/or location of the tracer element within the fluid. If the detecting tool is an induction tool, one or more of the fluids pumped into the formation may include a tracer element to increase and/or decrease the resistivity detected/measured within the formation. 
     For example, the first fluid pumped into the formation may have a relatively high-salinity content, such as brine (and/or any other relatively high-salinity fluid or material), in which the brine may alter the resistivity of the formation by being pumped therein. Particularly, by pumping a relatively high-salinity content fluid, such as brine, into the formation, the resistivity within the formation may decrease. When a relatively high-salinity content fluid is pumped into the formation as a first fluid, a relatively low-salinity content fluid, such as water, may also be pumped into the formation, such as water being used as the second fluid. The first fluid pumped into the formation may be contrasted by the second fluid pumped into the formation, thereby providing a variable response of the measured resistivity within the formation by the induction tool based upon the amount and locations of the fluids pumped into the formation. 
     Accordingly, an apparatus in accordance with the present disclosure may be used to determine a movement of fluid within a formation, and thereby determine one or more properties and/or characteristics of the formation based upon the movement of the fluid. For example, fluid may be pumped into the formation by the apparatus, such as a first fluid having a tracer element therein, in which the fluid may be observed (e.g., detected and/or measured) as the fluid travels through the formation. Particularly, as the first fluid is pumped into the formation, the detecting element may be used to detect the first fluid within the formation, and the movement of the first fluid within the formation may be determined based upon the detection of the first fluid with the detecting tool. When an induction tool is used as the detecting tool, brine, for example, may then be pumped into the formation, and the resistivity may be measured by the induction tool, as the brine, when traveling through the formation, may be used to selectively decrease the resistivity measured within the formation by the induction tool. 
     Based upon the determined movement of the fluid within the formation, one or more properties and/or characteristics of the formation may be determined. For example, the porosity of a formation may be determined based upon the movement of the detected fluid within the formation, the density of a formation may be determined based upon the movement of the detected fluid within the formation, in addition to many other properties and/or characteristics may be determined based upon the movement of the detected fluid within the formation. This may enable one to determine a shape, configuration, and/or fluid mobility for a formation, such as determine horizontal and/or vertical boundaries within a formation, in addition to other discontinuities present within the formation. 
     As discussed above, multiple fluids may be pumped into the formation using an apparatus in accordance with the present disclosure. As such, in addition to pumping a first fluid into the formation, the apparatus may be used to pump a second fluid (and/or three or more fluids) into the formation. The apparatus may alternate between having the first fluid pumped therefrom and having the second fluid pumped therefrom. The apparatus may be used to pump the first fluid into the formation for a selected amount of time, and then the apparatus may be used to pump the second fluid into the formation for a selected amount of time. For example, the first fluid and/or the second fluid may be pumped into the formation for a time interval, such as a predetermined or preselected time interval. Particularly, the apparatus may be used to pump the first fluid having the tracer element therein into the formation for a selected amount of time, and then may be used to pump the second fluid not having a tracer element therein into the formation for a selected amount of time. 
     By alternating between pumping the first fluid into the formation and pumping the second fluid into the formation, the movement of the fluids within the formation may be more easily obtained. For example, when only pumping and detecting the first fluid within the formation, only a single “wave” of the first fluid may be detected by the detecting tool as the first fluid propagates and travels through the formation. However, by alternating between pumping and detecting the first fluid and the second fluid within the formation, multiple “waves” of the first fluid may be detected by the detecting tool as the first fluid propagates and travels through the formation. 
     For example, when pumping brine as the first fluid into the formation and using an induction tool to measure the resistivity within the formation, and thereby detect the first fluid in the formation based upon the resistivity, the induction tool may be able to detect the multiple waves of brine within the formation as the apparatus alternates between pumping brine into the formation and pumping the second fluid, such as water, into the formation. Accordingly, this may enable one to more easily determine the movement of the first fluid within the formation based upon the detection of the first fluid (e.g., brine) within the formation. By alternating the pumping of the first fluid and the second fluid within the formation, this may provide one with more information to determine one or more properties and/or characteristics of the formation, such as horizontal and/or vertical boundaries within a formation, in addition to other discontinuities present within the formation. 
     When alternating between pumping the first fluid into the formation and pumping the second fluid into the formation, the first fluid and the second fluid may be pumped into the formation using a pre-determined sequence. For example, a sequence may be pre-determined such that the first fluid may be pumped into the formation for a pre-determined time and/or for a pre-determined amount and the second fluid may also be pumped into the formation for a pre-determined time and/or for a pre-determined amount. Accordingly, the first fluid and the second fluid may be pumped into the formation using a binary sequence and then detected using the detecting tool. The fluids may be pumped into the formation using a pseudo-random binary sequence, such as using one or more “M-Sequences” when pumping the fluids into the formation. Using one or more particular sequences, such as a M-Sequences, the signal-to-noise ratio may be improved by reducing the amount of noise received by the detection tool. An example of one or more sequences that may be used in accordance with the present disclosure is also described within U.S. Patent Application No. 2007/0061093, filed on Aug. 28, 2006, entitled “Time-Of-Flight Stochastic Correlation Measurements,” which is assigned to the assignee of the present disclosure, and is incorporated herein by reference in its entirety. 
     In addition to alternating between pumping the first fluid into the formation and pumping the second fluid into the formation, the apparatus may be used to simultaneously pump the first fluid and the second fluid into the formation. The first and the second fluids may be pumped from the apparatus to have a desired ratio of the first fluid to the second fluid. Accordingly, at one moment, the first fluid may be pumped from the outlet of the apparatus, in which the second fluid may then, in addition or in alternative, be pumped from the outlet of the apparatus. 
     As discussed above, the present disclosure may contemplate having a predetermined time interval for pumping a first fluid and/or a second fluid within a formation. Those having ordinary skill in the art will appreciate that the present disclosure contemplates varying one or more characteristics and/or properties of a fluid that is pumped within a formation. For example, the present disclosure may use a preselected and/or predetermined time interval when pumping the fluid, may use a preselected and/or predetermined pressure when pumping the fluid, may use a preselected and/or predetermined volume when pumping the fluid, may use a preselected and/or predetermined fluid flow when pumping the fluid, may use a preselected and/or predetermined fluid composition when pumping the fluid, and/or may use other preselected and/or predetermined characteristics when pumping the fluid. One or more of these characteristics of the fluid may vary with time when being pump into the formation. For example, the pressure, volume, fluid flow, fluid composition, and/or other characteristics may vary with time as being pumped into the formation. 
     Accordingly, a detecting tool may be used to detect one or more of the characteristics of the fluid when pumped into the formation. For example, as the fluid pumped into the formation interacts with the formation, the detecting tool may be used to detect one or more characteristics of the formation, in which one or more characteristics of the fluid may be predetermined and/or varied to enable the detecting tool to detect one or more characteristics of the formation. A method of the present disclosure, as such, may include the fluid pumped into the formation interacting with the formation, the pumped fluid then being used to produce a signal (e.g., convolution) that may be detected by the detecting device, in which the detecting device may be used to process (e.g., deconvolution) the signal of the fluid to determine characteristics of the formation. 
     Those having ordinary skill in the art will appreciate that an apparatus and/or a system in accordance with the present disclosure may have other structures and/or arrangements as compared to that shown in  FIG. 7 . For example, as shown in  FIG. 7 , the apparatus  701  includes the first container  721 A having the first fluid  723 A contained therein and the second container  721 B having the second fluid  723 B contained therein. However, instead of having the first fluid  723 A and/or the second fluid  723 B disposed within the apparatus  701 , one or more of the fluids may be pumped from the surface of the formation F and through the apparatus  701 . The outlet  707  may be used to pump the first fluid  723 A and the second fluid  723 B therefrom, in which the first fluid  723 A may be pumped through the apparatus  701  from the surface and the second fluid  723 B may be pumped from a container disposed within the apparatus  701 . Rather than by having all of the elements included within one apparatus, the elements of the apparatus shown in  FIG. 7  may be distributed amongst multiple apparatuses within a system. For example, the detecting tool may be included within one apparatus that may be disposed downhole, and the inflatable packers and/or outlets for pumping fluid into the formation may be included within another apparatus that may be disposed downhole. 
     As discussed above, one or more of the fluids used in accordance with the present disclosure may include a tracer element, in which the detecting tool may be used to detect the tracer element within the fluid. As discussed above, one of the fluids used may be brine, in which an induction tool, being used as the detecting tool, may be used to detect the resistivity of the brine within the formation. However, those having ordinary skill in the art will appreciate that the present disclosure is not so limited, as other tracer elements and fluids may be used without departing from the scope of the present disclosure. 
     For example, the tracer element may be a radioactive element, in which the radioactive element may be detected by a detecting tool within the formation. Other tracer elements and/or other fluids may be used, in which the detecting tool may be used to detect one or more properties and/or characteristics of the fluid within the formation, such as by detecting and/or measuring viscosity, temperature, pressure, gas content (e.g., gas volume and/or gas type within the formation). A detecting tool may be able to detect, such as by measuring and/or detecting, one or more properties of a fluid having a particular chemical composition, having a dye disposed therein, having a mixture of various fluids (e.g., oil and water mixture), and/or having a mixture of phases therein (e.g., solid, gas, and/or liquid). As such, each of these properties, characteristics, and/or elements, in addition to other properties, characteristics, or elements, may be used by a detecting tool to detect a fluid within a formation. Accordingly, depending on the tracer element used within the fluid within an apparatus of the present disclosure, an appropriate detecting tool for measuring the tracer element may also be used within an apparatus of the present disclosure. For example, when the tracer element is a radioactive element, a radioactive element detecting tool may correspondingly be used. 
     Additionally or alternatively, the fluid pumped into the formation may chemically react and/or interact with the formation, such as by having one or more properties and/or characteristics of the fluid and/or the formation change when the fluid is pumped into the formation. As fluid is pumped into the formation, the properties of the fluid and/or the formation, such as the chemical properties of the fluid, may change as the fluid interacts with the formation. For example, if the fluid pumped into the formation is a doping material, a nuclear magnetic resonance (NMR) detecting tool may be used to detect and/or measure the response of hydrogen nuclei on the surface of rocks within the formation. This response of the hydrogen nuclei with the rocks of the formation may also change over time, which may be detected by the NMR detecting tool. Additionally, fluid may also be pumped into the formation to interact with fluid already present within the formation. For example, brine may be present within the formation, in which fluid may be pumped into the formation to interact with the brine to change the conductivity of the fluid within the formation, which may be detected by an induction tool disposed within a borehole within the formation. 
     Aspects of the present disclosure, such as detecting a fluid within a formation, determining a movement of the fluid within the formation, and determining one of a property and a characteristic of the formation, may be implemented on any type of computer regardless of the platform being used. For example, as shown in  FIG. 8 , a networked computer system  810  that may be used within the present disclosure may include a processor  820 , associated memory  830 , a storage device  840 , and numerous other elements and functionalities typical of today&#39;s computers (not shown). The networked computer system  810  may also include input means, such as a keyboard  850  and a mouse  860 , and output means, such as a monitor  870 . The networked computer system  810  is connected to a local area network (LAN) or a wide area network (e.g., the Internet) (not shown) via a network interface connection (not shown). Those skilled in the art will appreciate that these input and output means may take many other forms. Additionally, the computer system may not be connected to a network. Those skilled in the art will appreciate that one or more elements of aforementioned computer  810  may be located at a remote location and connected to the other elements over a network. A computer system, such as the networked computer system  810 , and/or any other computer system known in the art may be used, such as by having a computer system coupled to and/or included within an apparatus of the present disclosure. 
     The present disclosure may provide for one or more of the following advantages. An apparatus, a system, and/or a method in accordance with the present disclosure may be included within one or more of the tools and/or devices shown in  FIGS. 1-6 , in addition to being included within other tools and/or devices that may be disposed downhole within a formation. An apparatus, a system, and/or a method in accordance with the present disclosure may be able to determine fluid movement within a formation. This may enable one or more properties and/or characteristics of the formation to be determined based upon the movement of the fluid within the formation. 
     In view of all of the above and the figures, those skilled in the art should readily recognize that the present disclosure introduces an apparatus comprising: a first packer configured to selectively engage a wall of a borehole extending into a subterranean formation; a detecting tool disposed adjacent to the first packer; and an outlet disposed adjacent to the first packer; wherein the outlet is configured to have a first fluid and a second fluid pumped therefrom and into the formation; and wherein the detecting tool is configured to detect the first fluid pumped into the formation. The apparatus may further comprise a second packer configured to selectively engage the borehole wall, wherein the outlet is disposed between the first and second packers. The first fluid may comprise a tracer element, and the detecting tool may be configured to detect the tracer element of the first fluid. The outlet may be configured to alternate between pumping the first fluid and the second fluid therefrom and into the formation. The apparatus may further comprise: a first container fluidly coupled to the outlet, wherein at least a portion of the first fluid is disposed within the first container; and a first valve fluidly coupled between the first container and the outlet. The apparatus may further comprise: a second container fluidly coupled to the outlet, wherein at least a portion of the second fluid is disposed within the second container; and a second valve fluidly coupled between the second container and the outlet. The apparatus may further comprise at least one pump fluidly coupled between the outlet and at least one of the first container and the second container. The first fluid may comprise brine, and the second fluid may comprise water. The detecting tool may comprise an induction tool. The induction tool may be configured to measure a resistivity of the first fluid within the formation. 
     The present disclosure also introduces a method comprising: disposing a detecting tool into a borehole formed within a formation; pumping a first fluid into the formation; and detecting the first fluid within the formation with the detecting tool. The method may further comprise determining a movement of the first fluid within the formation based upon the detection of the first fluid within the formation. The method may further comprise determining one of a property and a characteristic of the formation based upon the determined movement. Detecting the first fluid within the formation with the detecting tool may comprise measuring a property of the first fluid within the formation with the detecting tool. The detecting tool may comprise an induction tool, and measuring the property of the first fluid within the formation with the detecting tool may comprise measuring a resistivity of the first fluid within the formation with the induction tool. The first fluid may comprise a tracer element, and the detecting the first fluid within the formation with the detecting tool may comprises detecting the tracer element of the first fluid within the formation with the detecting tool. The method may further comprise pumping a second fluid into the formation. The method may further comprise alternating between pumping the first fluid into the formation and pumping the second fluid into the formation. Alternating between pumping the first fluid and the second fluid may be performed using a pre-determined sequence. The method may further comprise engaging a wall of the borehole with a first packer, wherein the first fluid is pumped from an outlet disposed adjacent to the first packer. The method may further comprise engaging the wall of the borehole with a second packer, wherein the outlet is disposed between the first packer and the second packer. The method may further comprise outputting the one of the property and the characteristic of the formation, wherein the outputting comprises at least one of: graphically displaying the one of the property and the characteristic of the formation; printing the one of the property and the characteristic of the formation; and storing or transferring to computer readable media the one of the property and the characteristic of the formation. 
     The foregoing outlines feature several embodiments so that those skilled in the art may better understand the aspects of the present disclosure. Those skilled in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structures for carrying out the same purposes and/or achieving the same advantages of the embodiments introduced herein. Those skilled in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the present disclosure, and that they may make various changes, substitutions and alterations herein without departing from the spirit and scope of the present disclosure. 
     The Abstract at the end of this disclosure is provided to comply with 37 C.F.R. §1.72(b) to allow the reader to quickly ascertain the nature of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.