Abstract:
An instrumentation system includes a detection apparatus and a data logging apparatus that detect and record various inflow parameters and outflow parameters of the well during the completion phase or other operational phase of the well. The detection apparatus includes instrumentation that is applied to both the inflow into the well and the outflow out of the well and that detects the inflow and outflow parameters. The data logging apparatus captures the output from such instrumentation and records it for analysis. Such analysis can be performed in real time, i.e., as the data is being recorded, and/or can be retrieved at a later time for analysis and for optimization of future wells. A method involves applying the instrumentation system to a well.

Description:
CROSS-REFERENCE TO RELATED APPLICATION 
       [0001]    The instant application claims priority from U.S. Provisional Patent Application Ser. No. 62/289,228, filed Jan. 30, 2016; U.S. Provisional Patent Application Ser. No. 62/327,707 filed Apr. 26, 2016; U.S. Provisional Patent Application Ser. No. 62/420,194 filed Nov. 10, 2016; U.S. Provisional Patent Application Ser. No. 62/420,206 filed Nov. 10, 2016; and U.S. Provisional Patent Application Ser. No. 62/423,954 filed Nov. 18, 2016, the disclosures of which are incorporated herein by reference. 
     
    
     BACKGROUND 
       [0002]    Field 
         [0003]    The disclosed and claimed concept relates generally to an instrumentation system and, more particularly, to an instrumentation system that is usable in conjunction with a well such as a fossil fuel well. 
         [0004]    Related Art 
         [0005]    Numerous types of subterranean wells are known to exist in the relevant art. Such wells typically are employed in order to remove subterranean resources that are in a fluid or fluidized state. Such wells can include, for example, water wells and also can include wells that remove hydrocarbons from subterranean locations, such as petroleum wells. Other wells remove materials that would be in a gaseous state at atmospheric pressure. Some such gas wells involve a reservoir that includes a pocket of, for instance, natural gas and/or other substances that can include other hydrocarbons, and the pocket is tapped in order to cause the materials in the pocket to be brought to the surface for use. Another such gas well implementation is one in which the hydrocarbons are locked within a shale matrix and must be subjected to a hydraulic fracturing operation in order to free the hydrocarbons for removal to the surface. 
         [0006]    Such a hydraulic fracturing operation typically involves the drilling of a hole into the surface of the earth and the installation of a pair of concentric pipes in the hole that can be said to include an outer pipe and an inner pipe, wherein an annular region is formed between the inner and outer pipes. The hydraulic fracturing operation further includes the installation of a number of plugs at various vertical locations within the inner pipe. As employed herein, the expression “a number of” and variations thereof shall refer broadly to any non-zero quantity, including a quantity of one. As each successive plug is installed, the region of the earth vertically below the plug is subjected to a hydraulic fracturing operation that involves a pressurized fluid and a proppant such as sand or other material in a known fashion. After all of the hydraulic fracturing operations are performed in the hole, the plugs typically are removed in what is generally known as a completion phase. 
         [0007]    In the completion phase, a drill bit having a turbomachinery motor is received in the inner pipe. A fluid at a high pressure and a high velocity, such as water with polymers and other additives, is pumped into the inner pipe in order to operate the turbomachine in order to power the drill bit, and the drill bit thus drills through the various plugs. The fluid is generally removed from the well by causing it to flow through the annular region between the inner and outer pipes back to the surface whereby it can carry parts of the plugs and may additionally carry other materials such as dirt and hydrocarbons. The returned fluid typically is caused to be received in a number of reclamation tanks, after which it is reconditioned as needed and pumped back into the inner pipe in order to continue to power the drill bit. The system employed a pressure pumper to pump the fluid into the well and to power the turbomachine motor that operates the drill bit. However, the system typically also includes a choke on the outward-flowing fluid path that is adjusted in order to maintain a certain downhole pressure and that serves as counterbalancing pressure to the pressure provided by the pressure pumper to the inward flow of fluid. 
         [0008]    While such completion operations have been generally effective for their intended purposes, they have not been without limitation. A strap stick or other such manual tool was typically received in the reclamation tank, and the change in height of the fluid in the reclamation tank typically was visually observed. If the fluid level in the reclamation tank was observed to be increasing, a command typically was issued to reduce the velocity of the pressure pumper that was pumping the fluid into the well or to narrow the setting on the choke, or both. On the other hand, if the level of the fluid in the reclamation tank was seen to be dropping, the pressure pumper typically may have been instructed to increase its speed, or the setting on the choke was widened. This was typically done in order to achieve a volumetrically balanced type of flow into and out of the well. Depending upon the state of the pressure pumper and the state of the choke, the well could be in an overbalanced state wherein material was flowing from the pipes and into the reservoir, which is undesirable. Likewise, the well could alternatively be in an underbalanced state wherein material is flowing from the reservoir into the pipe and flowing out of the well and into the reclamation tanks, by way of example. The overbalanced and underbalanced states are both undesirable. Other such undesirable conditions can exist in the well during the completion phase. While such manual measurement tools such as the strap stick were employed, along with other such manual measuring tools such as the use of stopwatches and the manual counting of pump cycles, such manual measurement devices provided at most only an incomplete view of the operational state of the well. Improvements thus would be desirable. 
       SUMMARY 
       [0009]    These and other shortcoming are addressed by an improved instrumentation system and method in accordance with the disclosed and claimed concept. The instrumentation system includes a detection apparatus and a data logging apparatus that detect and record various inflow parameters and outflow parameters of the well during the completion phase or other operational phase of the well. The detection apparatus includes instrumentation that is applied to both the inflow into the well and the outflow out of the well and that detects the inflow and outflow parameters. The data logging apparatus captures the output from such instrumentation and records it for analysis. Such analysis can be performed in real time, i.e., as the data is being recorded, and/or can be retrieved at a later time for analysis and for optimization of future wells. 
         [0010]    Accordingly, an aspect of the disclosed and claimed concept is to provide an instrumentation system for a well that provides instrumentation on both an inward flow into the well and an outward flow out of the well, and that can record and retain such data. 
         [0011]    Another aspect of the disclosed and claimed concept is to provide such an instrumentation system wherein the stored data can be retrieved for real time analysis or can be retrieved later for other purposes such as optimization of future wells, and for other purposes. 
         [0012]    Accordingly, an aspect of the disclosed and claimed concept is to provide an improved instrumentation system structured to be used in conjunction with a well that is formed in a surface, the well having a fluid inflow channel through which an inward flow of fluid can be caused to travel in a direction generally from the surface into the well, the well further having a fluid outflow channel through which an outward flow of fluid can be caused to travel in a direction generally outward from the well to the surface. The instrumentation system can be generally stated as including a detection apparatus that can be generally stated as including an inlet instrumentation package and an outlet instrumentation package, the inlet instrumentation package can be generally stated as including a plurality of sensing elements, each sensing element of the plurality of sensing elements being structured to detect an inflow parameter of the inward flow and to generate an inflow data signal based at least in part upon the inflow parameter, the outlet instrumentation package can be generally stated as including a plurality of other sensing elements, each other sensing element of the plurality of other sensing elements being structured to detect an outflow parameter of the outward flow and to generate an outflow data signal based at least in part upon the outflow parameter, and a data logging apparatus that can be generally stated as including a communication system and a processor apparatus, the communication system being structured to receive the inflow data signals and the outflow data signals, the processor apparatus can be generally stated as including a processor and a storage, the processor being structured to receive the inflow data signals and the outflow data signals from the communication system, the processor being further structured to store at least some of the inflow data signals and the outflow data signals in the storage. 
         [0013]    Another aspect of the disclosed and claimed concept is to provide an improved method of detecting a plurality of operational parameters of a well that is formed in a surface, the well having a fluid inflow channel through which an inward flow of fluid is caused to travel in a direction generally from the surface into the well, the well further having a fluid outflow channel through which an outward flow of fluid is caused to travel in a direction generally outward from the well to the surface. The method can be generally stated as including applying to the well an instrumentation system that can be generally stated as including a detection apparatus can be generally stated as including an inlet instrumentation package and an outlet instrumentation package, the inlet instrumentation package can be generally stated as including a plurality of sensing elements, each sensing element of the plurality of sensing elements detecting an inflow parameter of the inward flow and generating an inflow data signal based at least in part upon the inflow parameter, the outlet instrumentation package can be generally stated as including a plurality of other sensing elements, each other sensing element of the plurality of other sensing elements detecting an outflow parameter of the outward flow and generating an outflow data signal based at least in part upon the outflow parameter, and a data logging apparatus that can be generally stated as including a communication system and a processor apparatus, the communication system receiving the inflow data signals and the outflow data signals, the processor apparatus can be generally stated as including a processor and a storage, the processor receiving the inflow data signals and the outflow data signals from the communication system, the processor storing at least some of the inflow data signals and the outflow data signals in the storage. 
     
    
     
       DRAWINGS 
         [0014]    A further understanding of the disclosed and claimed concept can be gained from the following Description when read in conjunction with the accompanying drawings in which: 
           [0015]      FIG. 1  is a schematic depiction of an improved instrumentation system in accordance with the disclosed and claimed concept; and 
           [0016]      FIG. 2  is a detailed depiction of a detection apparatus of the instrumentation system of  FIG. 1 . 
       
    
    
       [0017]    Similar numerals refer to similar parts through the specification. 
       DESCRIPTION 
       [0018]    An improved instrumentation system  4  in accordance with the disclosed and claimed concept is depicted generally in  FIGS. 1 and 2 . The instrumentation system is usable in conjunction with a well  6  which, in the depicted exemplary embodiment, is a fossil fuel well and, more particularly, it is a shale gas well. It is understood that other types of wells, including those that do not involve fossil fuels, can have the instrumentation system  4  applied thereto without limitation. The instrumentation system  4  is depicted in  FIG. 1  as being in communication with a Christmas tree  8  that is situated atop the well  6  and which performs control functions and other functions of the type that are generally known in the relevant art. As can be understood from  FIG. 1 , the well  6  is formed in a surface  10  of the earth and is usable to cause materials from within the earth to be brought to the surface  10  for extraction, use, etc. 
         [0019]    The Christmas tree  8  is part of a flow circuit  12  that is depicted generally in  FIG. 2  and which is situated generally above and upon the surface  10 . The well  6  itself includes a pair of concentric pipes that extend below the surface  10  and that form a fluid inflow channel  14  within the inner pipe and a fluid outflow channel  16  in the annular region between the inner pipe and the outer pipe. During certain operations involving the well  6 , an inward flow of fluid  18  flows into the Christmas tree  8  and thereafter into the fluid inflow channel  14  and flows in a direction generally from the surface  10  downward into the well  6 . Likewise, an outward flow of fluid  20  is caused to flow in the fluid outflow channel  16  in a direction generally upward from the well  6  toward and out of the surface  10 . 
         [0020]    The circulation fluid that is provided as the inward flow of fluid  18  and that is returned as the outward flow of fluid  20  typically is fowled primarily of water and known polymer materials that facilitate flow of the fluid into the well  6  and that promote similar flow out of the well  6  carrying particles of plugs that have been installed within the well  6  and subsequently drilled out using a drill bit. As such, the outward flow of fluid typically includes the water infused with polymers (along with other additives) and further carries with it particles of drilled-out plugs and may additionally carry with it hydrocarbons and proppant material of a type that is known in the relevant art. 
         [0021]    As can be understood from  FIG. 1 , the instrumentation system  4  can be said to include a detection apparatus  22  and a data logging apparatus  24  that are in communication with one another. More particularly, and as will be set forth in greater detail below, the detection apparatus  22  detects certain parameters of the inward and outward flows of fluid  18  and  20  and communicates data signals representative of such parameters to the data logging apparatus  24 . It is understood that any type of data connection between the detection apparatus  22  and the data logging apparatus  24  can be used without limitation. While  FIG. 1  depicts a wired connection between the detection apparatus  22  and the data logging apparatus  24 , it is understood that any type of wireless or other type of data communication systems therebetween can be employed without limitation. 
         [0022]    The detection apparatus  22  can be said to include an inlet instrumentation package  26  and an outlet instrumentation package  28 . The inlet instrumentation package  26  includes a plurality of instruments that are in communication with the inward flow of fluid  18 , meaning that they are in physical proximity to the inward flow of fluid  18  or are in fluid communication with the inward flow of fluid  18  depending upon the needs of the various instruments. In a similar fashion, the outlet instrumentation package  28  is in communication with the outward flow of fluid  20 , and such communication may be the state of being in proximity with or in fluid communication with the outward flow of fluid  20  depending upon the needs of the particular instruments that make up the outlet instrumentation package  28 . 
         [0023]    More specifically, and as can be seen in  FIG. 2 , the flow circuit  12  includes an inflow leg  30  that brings the circulation fluid to the Christmas tree  8  for flow into the fluid inflow channel  14 . The flow circuit  12  further includes an outflow leg  32  that carries the circulation fluid away from the Christmas tree  8  after flowing out of the fluid outflow channel  16 . The inlet instrumentation package  26  is situated on or in proximity to the inflow leg  30 , and the outlet instrumentation package  28  likewise is situated on or in proximity to the outflow leg  32 . 
         [0024]    As can further be seen in  FIG. 2 , the outflow leg  32  can be said to include a set of of outflow piping  34  that is connected between the Christmas tree  8  and a set reclamation tanks  36  and which receives the circulation fluid. The reclamation tanks  36  penult the settling of certain particulate materials and the venting of certain volatile materials and serve other purposes that are known in the relevant art. A transfer pump  38  pumps the circulation fluid from the reclamation tanks  36  through a filtration system  40  and into a water tank farm  42  where the circulation fluid is stored. A delivery pump  44  then pumps the circulation fluid from the water tank farm  42  into a mixing pit  46  where additional polymer materials and other materials can be added to the circulation fluid to replenish anything that may have been lost either downhole or otherwise. It is noted that within the outflow leg  32 , a choke  49  is situated upstream of a separator  48 . The separator  48  is connected with a flare  50  that ignites volatile gaseous material that may be of hydrocarbon content, for example, and that may have been carried out of the well  6  as part of the outward flow of fluid  20 . 
         [0025]    As can further be seen in  FIG. 2 , the inflow leg  30  can be said to include a set of inflow piping  52  and a pressurizing pump  54  that draws the circulation fluid from within the mixing pit  46 . The pressuring pump  54  then pumps the circulation fluid toward a service rig  56  and thereafter into the Christmas tree  8  and into the fluid inflow channel  14 . It is understood that the exemplary depiction of the flow circuit  12  is not intended to be limiting in any fashion. 
         [0026]    The inlet instrumentation package  26  can be said to include a plurality of inflow instruments  58  that are described in greater detail below. The inflow instruments  58  can be mounted directly to the inflow leg  30  as individual instruments in a fashion that is suited to the operational needs of the various inflow instruments  58 . Alternatively, the inflow instruments  58  can be mounted to a housing having a fluid inlet and a fluid outlet that can be placed in fluid communication with the inflow leg  30  without departing from the spirit of the instant disclosure. 
         [0027]    The inflow instruments  58  in the depicted exemplary embodiment include a temperature sensor  60 , a pressure sensor  62 , a volumetric flow meter  64 , and a viscometer  66 . The exemplary temperature sensor  60  in the depicted exemplary embodiment is placed directly in contact with the fluid flow within the inflow leg  30  and can be (please provide an exemplary model number, manufacturer, and manufacturer location), although other temperature sensors can be employed without departing from the spirit of the present concept. The pressure sensor  62  is likewise placed in fluid communication with the inflow leg  30  and can be (please provide an exemplary model number, manufacturer, and manufacturer location) or other appropriate pressure sensor. 
         [0028]    The volumetric flow meter  64  can be any of a wide variety of flow meters and particularly may include an ultrasonic flow meter, of which numerous types are known to exist. An ultrasonic flow meter need not necessarily be directly in fluid communication with the inflow leg  30  and rather need only be within a predetermined proximity of the inflow leg  30  in order to detect the flow rate of the fluid within the inflow leg  30 . Since the volumetric flow meter  64  is on what can be termed the “clean” side of the flow circuit  12 , i.e., on the inflow leg  30 , an appropriate ultrasonic volumetric flow meter would be a transit time meter such as (please provide an exemplary model number, manufacturer, and manufacturer location), although other types of flow meters can be employed without limitation. 
         [0029]    The viscometer  66  is depicted as being situated between the mixing pit  46  and the pressurizing pump  54  and is situated within such flow, i.e., in fluid communication therewith. The viscometer  66  can, for example, be (please provide an exemplary model number, manufacturer, and manufacturer location), although other viscometers can be employed without departing from the spirit of the present disclosure. 
         [0030]    The outlet instrumentation package  28  can likewise be said to include a plurality of outflow instruments  66  that are placed in communication with the outward flow of fluid  20 , meaning that they are placed either in proximity to the outflow leg  32  or in fluid communication with the outward flow of fluid  20  within the outward flow leg  32 . It is noted that the inflow instruments  58  and the outflow instruments  68  are preferably placed at least ten pipe diameters from an upstream flow change such as an elbow or the like, and are further preferably placed at least five pipe diameters from a downstream flow change such as an elbow, etc. 
         [0031]    The outflow instruments  68  include a temperature sensor  70  and a pressure sensor  72  that may be similar to the temperature sensor  60  and the pressure sensor  62 , although other instrumentation can be employed depending upon the needs of the particular application. The outflow instruments  68  further include a volumetric flow meter  74  which may or may not be similar to the volumetric flow meter  64 . Inasmuch as the volumetric flow meter  74  can be said to be on what can be termed the “dirty” side of the flow circuit  12 , the volumetric flow meter  74  may advantageously employ a Doppler sensing system that relies upon particulate material that is carried within the outward flow of fluid  20  in order to measure the volumetric flow rate. Further advantageously, the volumetric flow meter  74  may be of a hybrid variety that employs not only the Doppler technology but may additionally employ transit time ultrasonic technology and can switch between the two depending upon the amount of particulate material within the outward flow of material  20  at any given time. The volumetric flow meter  74  may be (please provide an exemplary model number, manufacturer, and manufacturer location), although other appropriate volumetric flow meters can be employed without departing from the spirit of the present disclosure. 
         [0032]    The outflow instruments  68  further include a viscometer  66  that is situated in the flow of circulation fluid and is disposed immediately prior to the mixing pit  46 . The viscometer  66  thus measures the viscosity of the circulation fluid immediately before it reaches the mixing pit  46 . Inasmuch as the viscometer  76  measures the viscosity of the circulation fluid immediately after it leaves the mixing pit  46 , the viscosity values that are output by the viscometers  66  and  76  enable appropriate materials, such as polymer materials and other known materials, to be added to the mixing pit  46  in order to achieve a desirable mixture, as measured by its viscosity, on the circulation fluid leaving the mixing pit  46 . 
         [0033]    The outflow instruments  68  further include a mass flow meter  78  that may be a Coriolis mass flow meter or an electromagnetic mass flow meter, by way of example and without limitation. If the mass flow meter  78  is a Coriolis flow meter, it desirably will be positioned in a vertical orientation such that particulate matter that may be carried in the outward flow of fluid  20  does not become trapped within the Coriolis flow meter during operation or after periodic shutdowns of the flow circuit  12 . The mass flow meter  78  may be (please provide an exemplary model number, manufacturer, and manufacturer location), although other appropriate mass flow meters can be employed without departing from the spirit of the present concept. 
         [0034]    The inflow instruments  58  and the outflow instruments  68  are configured to detect parameters of the inward flow of fluid  18  and the outward flow of fluid  20 , respectively, and such data is communicated as a series of data signals from the detection apparatus  22  to the data logging apparatus  24 . For example, the temperature sensor  60  detects as an inflow parameter of the inward flow of fluid  18  a temperature of the inward flow of fluid  18 . The temperature sensor  60  then generates an inflow data signal that is representative of or is based at least in part upon the detected temperature. The inflow data signal is then communicated to the data logging apparatus  24 . In a like fashion, the pressure sensor  62  detects as an inflow parameter the pressure of the inward flow of fluid  18  and generates an inflow data signal that is representative of or is based at least in part upon the detected pressure. Likewise, the volumetric flow meter  64  detects as an inflow parameter the volumetric flow rates of the inward flow of fluid  18  and generates an inflow data signal that is representative of or is based at least in part upon the detected volumetric flow rate of the inward flow of fluid  18 . Similarly, the viscometer  66  detects as the inflow parameter a viscosity of the inward flow of fluid  18  at the location between the mixing pit  46  and the pressurizing pump  54 . The viscometer  66  then generates as an inflow data signal a signal that is representative of or is based at least in part upon the detected viscosity of the inward flow of fluid  18  at such location. All such inflow data signals are communicated to the data logging apparatus  24 . 
         [0035]    In a like fashion, the outflow instruments  68  each detect an outflow parameter in the outward flow of fluid  20  and generate an outflow data signal that is representative of the detected outflow parameter or that is at least based in part upon the detected outflow parameter. For instance, the temperature sensor  70  detects as an outflow parameter the temperature of the outward flow of fluid  20  and generates an outflow data signal that is representative of or is based at least in part upon the detected temperature. The pressure sensor  72  likewise detects as an outflow parameter a pressure of the outward flow of fluid  20  and generates an outflow data signal that is representative of or is based at least in part upon the detected pressure. The volumetric flow meter  74  detects as an outflow parameter the volumetric flow rate of the outward flow of fluid  20  and generates an outflow data signal that is representative of the volumetric flow rate or is based at least in part upon the detected volumetric flow rate. The viscometer  76  detects as an outflow parameter a viscosity of the outward flow of fluid  20  at the indicated location and generates an outflow data signal that is representative of the detected viscosity or is based at least in part upon the detected viscosity. Likewise, the mass flow meter  78  detects as an outflow parameter a mass flow rate of the outward flow of fluid  20  and generates an outflow data signal that is representative of or is based at least in part upon the detected mass flow rate. The outflow data signals are then communicated to the data logging apparatus  24   
         [0036]    It is noted that the various inflow data signals and outflow data signals are, in the depicted exemplary embodiment, communicated in real time to the data logging apparatus  24 . In other embodiments, some storage of data and burst communication of such data can be employed depending upon the needs of the particular application. 
         [0037]    As suggested above, a wired connection exists between the detection apparatus  22  and the data logging apparatus  24 , which may be in the form of wires that extend between each of the inflow instruments  58  and the data logging apparatus  24  and that may additionally include wires that extend between the outflow instruments  68  and the data logging apparatus  24 . In other embodiments, one or more of the inflow instruments  58  or the outflow instruments  68  or both can include a wireless data communication link that enables the inflow or outflow data signals or both to be wirelessly communicated directly from the instrument to the data logging apparatus  24  without departing from the spirit of the present concept. 
         [0038]    As can be understood from  FIG. 1 , the data logging apparatus  24  can be said to include a communications systems  80  that receives the inflow data signals and the outflow data signals from the detection apparatus  22 . The data logging apparatus  24  further includes a processor apparatus  82  that receives the inflow and outflow data signals from the communications system  80  and stores them, potentially with additional processing being involved. The communications system  80  includes a wireless transmitter  84  that wirelessly transmits the inflow and outflow data signals to the processor apparatus  82 . 
         [0039]    In the depicted exemplary embodiment, the processor apparatus  82  includes a processor  86 , a storage  88 , and a wireless receiver  90 . The processor  86  can be any of a wide variety of processors, such as microprocessors and the like, without limitation, that perform data processing operations. The storage  88  can be any of a wide variety of electronic storage media such as RAM, ROM, EPROM, FLASH, and the like without limitation, and serves as a central storage and memory area on the processor apparatus  82  that interfaces with the processor  86 . The storage  88  has a number of routines  92  stored therein that are executable on the processor  86  to cause the processor  86  and the data logging apparatus  24  to perform certain desirable operations. For example, the operations can include the processing of the inflow and outflow data signals and the storing in the storage of a set of operational data  94  that can be retrieved and viewed in real time or that can be retrieved at a later date for other purposes. 
         [0040]    The wireless receiver  90  is configured to receive the inflow and outflow data signals from the wireless transmitter  84 . In this regard, the depicted exemplary embodiment shows an external antenna  96  that receives the data signals from the wireless transmitter  84  and communicates the data signals to the wireless receiver  90 . The exemplary external antenna  96  may be representative of a cellular data communication network or can be a satellite-based communication network or other type of communication network. Alternatively, the wireless transmitter  84  and the wireless receiver  90  can communicate directly with one another without resort to the external antenna  96 , and such communication can be wired or wireless. The wireless transmitter  84  and the wireless receiver  90  may be in the form of wireless transceivers that can both transmit and receive data, although this need not necessarily be the case. 
         [0041]    As noted above, the operational data  94  can be viewed in real time through access to the operational data  94  via computers, laptops, smartphones, and the like without limitation. Alternatively, the data can be saved and reviewed at a later time for purposes such as optimizing future wells. 
         [0042]    When viewed in real time, the various inflow and outflow parameters are useful to a technician for various purposes. For example, the parameters can be employed to avoid an overbalanced system and to likewise avoid an underbalanced system by employing the data to determine how to adjust the pressurizing pump  54  and the choke  49 . 
         [0043]    Similarly, the technician may employ the operational data  94  in real time to determine the existence of a decrease in pressure in the outward flow of fluid  20  with a corresponding increase in flow rate in the outward flow of fluid  20  and may determine that a gas pocket or “kick” is imminent. In such a situation, the technician may again take steps to adjust the choke  49  or the pressurizing pump  54  or both in order to avoid the formation of such a gas pocket. 
         [0044]    Furthermore, the operational data  94  may be reviewed in real time in order to maintain a desired flow state, which may be a state that has a balanced volumetric flow in the inward flow of fluid  18  and the outward flow of fluid  20  or other appropriate flow state. Previously, such wells had never been instrumented, and the provision of such an instrumentation system  4  by the inventors enables adjustments of the well  6  and of the flow circuit  12  in a fashion that increases efficiency, maximizes flow, and maximizes overall production. Other advantages will be apparent. 
         [0045]    It is further noted that an advantageous method of detecting a plurality of parameters of the well  6  is disclosed herein. The advantageous method including applying the instrumentation system  4  to the well  6  and recording the data that is generated thereby. 
         [0046]    While specific embodiments of the disclosed concept have been described in detail, it will be appreciated by those skilled in the art that various modifications and alternatives to those details could be developed in light of the overall teachings of the disclosure. Accordingly, the particular arrangements disclosed are meant to be illustrative only and not limiting as to the scope of the disclosed concept which is to be given the full breadth of the claims appended and any and all equivalents thereof.