Patent Publication Number: US-2013239673-A1

Title: Systems and Methods for Collecting One or More Measurements in a Borehole

Description:
BACKGROUND OF THE DISCLOSURE 
     A wellbore or borehole (hereinafter “borehole”) is generally drilled into the ground to recover natural deposits of hydrocarbons and/or other desirable materials trapped in a subsurface geological formation (hereinafter “formation”) in the Earth&#39;s crust. The borehole is drilled to penetrate the formation in the Earth&#39;s crust that contains the trapped hydrocarbons and/or other materials. As a result, the trapped hydrocarbons and/or materials are released from the formation and/or recovered via the borehole. 
     Traditionally, downhole components, such as tools, electronics, sensors and/or devices are positioned within the borehole to collect one or more measurements associated with the borehole, the formation and/or the like. One or more of the downhole components are typically housed in one or more drill collars and/or tools which may be located within a drill string or in a bottom hole assembly (hereinafter “the BHA”) of the drill string. For example, the downhole components housed in drill collars located within the borehole may collect one or more measurements associated with one or more characteristics and/or properties, for example, relating to a drill bit mounted to the BHA, the drill string, the BHA, the borehole, the formation surrounding the borehole and/or the like. 
     However, traditional drill collars are made of one or more conductive or metallic materials that interfere or degrade with the measurements being collected by downhole components housed within the drill collars. Often, the drill collars are slotted metallic collars which negatively affect or degrade measurements collected by the downhole components housed within the drill collars. Sometimes, the downhole components have sensors that must be protected with a shield which typically is made of metallic material and negatively affects measurements being collected by the sensors. For example, a downhole tool may be housed within a drill collar made of steel which may interfere with and/or prevent the downhole tool from collecting necessary measurements, such as, for example, electromagnetic wave measurements, gamma ray radiation measurements and/or the like. As a result, the downhole tool, housed in the conductive steel drill collar, may not be able to accurately and/or efficiently collect the necessary measurements associated with the characteristics and/or properties of the drill bit, the drill string, the BHA, the borehole and/or the formation. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         FIG. 1  illustrates a diagram of a wellsite system in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 2  illustrates a diagram of a drill string system in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 3  illustrates a side view of a composite shield protecting a downhole component in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 4  illustrates a side view of a half-shell composite shield protecting a downhole component in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 5  illustrates a perspective view of a composite shield in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 6  illustrates a perspective view of a half-shell composite shield in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 7  illustrates a perspective view of a composite shield in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 8  illustrates a perspective view of a half-shell composite shield in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 9  illustrates a diagram of a composite drill collar incorporated into a bottom hole assembly in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 10  illustrates a diagram of a system having inner coils of a mandrel located inside outer coils of a composite drill collar in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 11  illustrates a diagram of a system having inner coils of a mandrel located inside outer coils of a composite drill collar in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 12  illustrates a diagram of a system having inner coils of a mandrel located between two sets of outer coils of a composite drill collar in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 13  illustrates a diagram of a system having inner coils of a mandrel inside outer coils of a composite drill collar with a sensor in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 14  illustrates a diagram of a drill string having composite short pipes in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 15  illustrates a diagram of piezoelectric strips for composite short pipes in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 16  illustrates a diagram of a composite housing for downhole components in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 17  illustrates a diagram of a flow line connection formed by composite housings in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 18  illustrates a diagram of a flow line connection formed by composite housings in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 19  illustrates a diagram of a composite acoustic attenuator in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 20  illustrates a diagram of a composite acoustic attenuator in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 21  illustrates a diagram of a composite acoustic attenuator in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 22  illustrates a diagram of a composite drill collar having isolated electrodes in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
         FIG. 23  illustrates a diagram of a wellsite system and target well in accordance with embodiments of the present invention and which can be used in practicing embodiments of the method of the present invention. 
     
    
    
     EMBODIMENTS 
     Referring now to the drawings wherein like numerals refer to like parts,  FIG. 1  illustrates a wellsite system  10 , which may be onshore or offshore, in which the present systems and methods for collecting one or more measurements in a borehole  12  may be employed. The borehole  12  is formed in subsurface formations  14  by rotary drilling in a manner that is well known. Embodiments of the invention may be used with vertical, horizontal and/or directional drilling. 
     The wellsite system  10  may include a drill string  16  suspended within the borehole  12 . For example, the drill string  16  may be a wireline logging tool string and/or may include one or more drill pipes  17 . The wellsite system  10  is used as an example system in which the invention may be incorporated, but a person having ordinary skill in the art will understand that the invention may be used in any downhole application, such as logging, formation evaluation, drilling, sampling, reservoir testing, completions, or abandonment of the borehole  12 . A bottom hole assembly  18  (hereinafter “BHA  18 ”) and a drill bit  20  may be coupled to and/or connected to a lower end of the drill string  16  below drill pipes  17 . Rotation of the drill bit  20  and/or the drill string  16  may move the drill string  16  and BHA  18  through the borehole  12 . It should be understood that drill string  16  may include any number of drill pipes  17  as known to one of ordinary skill in the art. 
     The BHA  18  of the drill string  16  may include one or more downhole components  22 ,  24 ,  26 ,  28 ,  30 ,  32  (hereinafter “the downhole components  22 ,  32 ” for simplicity) for collecting one or more measurements relating to one or more characteristics and/or properties associated with the borehole  12 , the formation  14 , the drill string  16 , the BHA  18  and/or the drill bit  20 . It should be understood that the BHA  18  may include any number of downhole components as known to one of ordinary skill in the art. 
     The downhole components  22 ,  32  may be a tool, a power source, a coil, an antenna, an electrode, a sensor, or another downhole component of the drill string  16  as known to one of ordinary skill in the art. For example, the downhole components  22 ,  32  may be tools, sensors, or other devices for collecting one or more measurements relating to one or more characteristics and/or properties associated with the formation  14 , the drill string  16 , the BHA  18 , the drill bit  20  and/or the borehole  12 . The downhole components  22 ,  32  may each be housed in a drill collar, as is known in the art, and/or may contain one or a plurality of known types of telemetry, survey or measurement tools, such as, logging-while-drilling tools (hereinafter “LWD tools”), measuring-while-drilling tools (hereinafter “MWD tools”), near-bit tools, on-bit tools, and/or wireline configurable tools (hereinafter “wireline tools”). In embodiments, the one or more drill collars may be an individual component of the BHA  18  and/or may be incorporated into one or more LWD tools and/or MWD tools which may be included in the BHA  18 . 
     The LWD tools may include capabilities for measuring, processing, and storing information, as well as for communicating with surface equipment. Additionally, the LWD tools may include one or more of the following types of logging devices that measure formation characteristics and/or properties: a resistivity measuring device; a directional resistivity measuring device; a sonic measuring device; a nuclear measuring device; a nuclear magnetic resonance measuring device; a pressure measuring device; a seismic measuring device; an imaging device; a formation sampling device; a natural gamma ray device; a density and photoelectric index device; a neutron porosity device; and a borehole caliper device. It should be understood that the downhole components  22 ,  32  may be any LWD tool as known to one or ordinary skill in the skill. 
     The MWD tools may include one or more devices and/or sensors for measuring characteristics and/or properties of the borehole  12 , the formation  14 , the drill string  16 , the BHA  18  and/or the drill bit  20 . The MWD tools may include one or more of the following types of measuring devices: 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; a natural gamma ray device; a directional survey device; a tool face device; a borehole pressure device; and a temperature device. The MWD tools may detect, collect and/or log data and/or information about the conditions at the drill bit  20 , around the formation  14 , at a front of the drill string  16  and/or at a distance around the drill string  16 . It should be understood that the downhole components  22 ,  32  may be any MWD tool as known to one of ordinary skill in the art. 
     The wireline tools may be a tool commonly conveyed by wireline cable as known to one having ordinary skill in the art. For example, the wireline tools may be logging tools for sampling or measuring characteristics and/or properties of the formation  14 , such as gamma radiation measurements, nuclear measurements, density measurements, resistivity measurements and/or porosity measurements. In embodiments, the one or more downhole components  22 ,  32  may be a well completion tool for extracting reservoir fluids after completion of drilling. It should be understood that the downhole components  22 ,  32  may be any wireline tool as known to one of ordinary skill in the art. 
     In an embodiment, the downhole components  22 ,  32  may be or may include one or more transmitters, receivers and/or sensors (hereinafter “sensors”) that may be housed within one or more drill collars and/or one or more walls of the one or more drill collars. The sensors may be in communication with the BHA  18 , the downhole components  22 ,  32 , other downhole components and/or one or more additional sensors associated with the downhole components  22 ,  32 . It should be understood that the drill string  16 , the BHA  18  and/or the downhole components  22 ,  32  may include any number of sensors and the sensors may be any sensor as known to one of ordinary skill in the art. 
     In embodiments, the downhole components  22 ,  32  may include sensors that may detect, collect, log and/or store data concerning the operation of the wellsite  10 , the borehole  12 , the formation  14 , the drill string  16  and/or the drill bit  20 . For example, the sensors of the downhole components  22 ,  32  may be provided to measure parameters such as standpipe pressure, hookload, depth, surface torque, rotary rpm and the like. The sensors of the downhole components  22 ,  32  may detect, collect, log and/or store any data that may be detected, collected, logged and/or stored as known to one of ordinary skill in the art. 
     In embodiments, the sensors of the downhole components  22 ,  32  may be provided in an interface to measure various wellbore parameters, such as temperature, pressure (standpipe and/or mud), mud flow, noise, vibration and/or drilling mechanics (i.e. torque, weight, acceleration and/or pipe rotation). The sensors of the downhole components  22 ,  32  may also be linked to an analog front end for signal conditioning and/or to a processor for processing and/or analyzing data. The sensors of the downhole components  22 ,  32  may also be used to perform diagnostics. The diagnostics can be used to locate faults in the drill string  16 , measure noise and/or characteristics associated with the drill string  16 , the BHA  18  and/or the drill bit  20  and perform other diagnostics of the wellsite  10 . 
     The sensors of the downhole components  22 ,  32  may detect, collect and/or log data associated with resistivity of the formation, such as, for example, attenuation and phase shift resistivity at different transmitter spacing and frequencies, resistivity at the drill bit  20  and/or deep directional resistivity. The sensors of the downhole components  22 ,  32  may detect, collect and/or log data associated with formation slowness, such as, for examples, compressional slowness and shear slowness. In addition, the sensors of the downhole components  22 ,  32  may detect, collect and/or log formation images, such as, for example, density borehole images and/or resistivity borehole images. Furthermore, the sensors of the downhole components  22 ,  32  may detect, collect and/or log data associated with formation pressure and/or formation fluid samples. Still further, the sensors of the downhole components  22 ,  32  may detect, collect and log data associated with total gamma rays, spectral gamma rays and/or azimuthal gamma rays. The sensors of the downhole components  22 ,  32  may also detect, collect and/or log data associated with formation caliper, such as, for example, ultra sonic azimuthal caliper and/or density caliper. It should be understood that the data and/or information detected, collected, logged and/or stored by the sensors of the downhole components  22 ,  32  may be any data and/or information as known to one of ordinary skill in the art. 
     The downhole components  22 ,  32  may comprise, may include or may incorporate one or more power sources (not shown in the drawings). The power source may be, for example, a power turbine and/or motor, a generator, a capacitor, a battery, a rechargeable battery, land-line extending from the Earth&#39;s surface  11  (hereinafter “surface  11 ”) into the borehole  12 . In embodiments, the drill pipes  17  of the drill string  16  may be wired drilling pipe which may provide electrical power or electrical energy downhole to the BHA  18  and/or the downhole components  22 ,  32 . In embodiments, the downhole components  22 ,  32  may be a power source itself or the power source may be located and/or connected to the drill string  16 . The power source may produce and may generate electrical power or electrical energy to be distributed throughout the drill string  16  and/or the BHA  18  and/or may power the downhole components  22 ,  32 . It should be understood the power source may be any other electrical power generating source as known to one of ordinary skill in the art 
     The present disclosure should not be deemed as limited to a specific embodiment of the tools for the downhole components  22 ,  32 . While the above description sets forth a description of the downhole components  22 ,  32  with respect to the drill string  16 , it should be appreciated by those having ordinary skill in the art that the invention should not be deemed as limited to only drilling applications. It should be understood that the drill string  16  may include any number and any type of downhole components as known to one of ordinary skill in the art. 
     The drill string  16 , the BHA and/or the downhole components  22 ,  32  may include one or more uphole components  34  (hereinafter “uphole components  34 ”), such as, for example, an uphole interface to provide an interface between communications circuitry of a telemetry system and the BHA  18  and/or the downhole components  22 ,  32 . The uphole interface of the uphole components  34  may transmit and/or radiate telemetry communications received by the telemetry system of the uphole interface from the BHA  18  and/or the downhole components  22 ,  32  to the surface  11  as known to one of ordinary skill in the art. The telemetry system may comprise one or more of the following telemetry systems: mud pulse telemetry, acoustic telemetry, electromagnetic telemetry, wired drill pipe telemetry, wireline telemetry or any other data transmission methods as known to one of ordinary skill in the art. The present disclosure should not be deemed limited to a specific embodiment of the telemetry utilized by the telemetry system of the uphole interface  34 . 
     In embodiments, the uphole components  34  may be, for example, low-power telemetry repeaters, pressure sensors, temperature sensors, acoustic sensors, mud sensors and/or other low-power sensors, which may be located between two separate adjacent drill pipes  17  within the drill string  16 . The repeater and/or the temperature sensor of the uphole components  34  may increase and/or intensify telemetry communications transmitted to the surface  11  from the BHA  18  and/or the downhole components  22 ,  32 . The uphole components  34  may be any component located within and/or positioned in the drill string  16  as known to one of ordinary skill in the art. 
     The downhole components  22 ,  32  may be one or more drill collars or may have one or more drill collars incorporate therein to form, for example, a wireline logging tool string  100  as shown in  FIG. 2 . For example, the downhole components  22  and  24  may have drill collars which may be connected to the drill string  16  to form the BHA  101  or a portion of the bottom hole assembly  101  (hereinafter “BHA  101 ”) of the wireline logging tool string  100 . 
     The drill collars or one or more portions of the drill collars may be made of a composite material. In embodiments, the one or more portions of the drill collars may include a wall  102  of the drill collars, one or more connectors  104  of the drill collars and/or other components of the drill collars. The present specification should not be deemed as limit to a specific embodiment of the portion(s) of the one or more drill collars that may be made of the composite material. 
     The composite material may be a lower density non-conductive, non-magnetic, and substantially non-conductive or a substantially non-magnetic composite material. As a result, the drill collars and/or the portions of the one or more drill collars may be conductively and/or magnetically transparent or substantially transparent to one or more downhole components  106  (hereinafter “downhole components  106 ”) and/or one or more sensors  108  (hereinafter “sensors  108 ”) which may be housed within, embedded within and/or located within the drill collars and/or the wall  102  of the drill collars. 
     In embodiments, the composite material may be a high-temperature, high strength, chemical resistant and/or wear resistant composite material. The composite material may be, for example, a fiber reinforced polymer composite material. In embodiments, the composite material may be made from a combination of one or more fiber materials and one or more resin matrixes. For example, the composite material may be made of an epoxy matrix reinforced with carbon fibers. It should be understood that the present specification should not be deemed as limited to a specific embodiment of the composite material which may be any composite material that is non-conductive or substantially non-conductive and suitable for use in the borehole  12 . 
     In embodiments, the downhole components  22  and  24  may be drill collars sized and/or adapted to receive and/or secure, for example, the wireline logging tool string  100 . The downhole components  106  may be, for example, wireline tools which may include the sensors  108  and/or be housed in or located within the one or more drills collars and/or within the wall  106  of the drill collars. The wireline tools  106  and/or the sensors  108  may be connected to wireline  110  as known to one of ordinary skill in the art and/or positioned within the drill collars via the wireline  108 . The drill collars and/or portions of the drill collars made of composite material (hereinafter “composite drill collars”) and the wireline logging tool string may form the BHA  101  which may be conveyed in the borehole  12  via the drill string  16  and/or may be used for formation evaluation and/or logging operations. Optionally, the drill string  16  and the BHA  101  may be configured and/or adapted to be used for drilling the borehole  12 . Moreover, the wireline tools  106  and/or the sensors  108  may be any wireline tools and/or any sensors, respectively, as known to one of ordinary skill in the art. 
     The wireline tools  106  and/or the sensors  108  housed within the composite drill collars may collect one or measurements relating to one more characteristics and/or properties of, for example, formation  14  surrounding the borehole  12 . The drill collars made of non-conductive or substantially non-conductive composite material do not interfere with or prevent the wireline tools  106  and/or the sensors from collecting one or more measurements associated with properties of the formation  14  surrounding the borehole  12 , such as, for example, electromagnetic (hereinafter “EM”) waves measurements, gamma ray radiation measurements, nuclear measurements, acoustic measurements, surveying measurements and/or the like. The composite drill collars may be transparent or substantially transparent to the EM waves, gamma ray radiation, nuclear, acoustic and surveying measurements and/or other measurements associated with the formation  14 . 
     The one or more wireline tools  106  and/or the one or more sensors  108  may collect the measurements associated with the formation  14  through the drill collar without or substantially without any interference from the composite material of the drill collars. As a result, the composite drill collars will not require one or more slots within the wall  102  and/or ceramic sleeves to allow the measurements to be collected by the wireline tools  106  and/or the sensors  108  housed within the composite drill collars. The measurements collected by the one or more wireline tools  106  and/or the one or more sensors  108  may be enhanced by the transparency or substantial transparency of the composite drill collar to measurements, such as, for example, electromagnetic, nuclear, resistivity, acoustic and/or surveying measurements. As a result, the composite drill collars may allow the wireline tools  106  and/or the sensors  108  to collect improved measurements in what is known as tough logging conditions. 
     The connectors  104  of the composite drill collars may be male or female plugs configured to connect to ends of the wireline tools  106 . A pair of connectors  104  having both male plug and a female plug may form a threaded connection  112  to secure the composite drill collars together. Securing and connecting devices  114  (hereinafter “devices  114 ”) may connect the wireline tools  106  to the connectors  104  of the composite drill collars and/or to the composite drill collars themselves. As a result, the wireline tools  106  may be connected, attached and/or secured to the connectors  104  and/or the composite drill collar via the devices  114 . The male or female plugs of the connectors may, optionally, be coupled to a coiled wire bundle  116  which may protect interiors  118  of the composite drill collars from drilling mud located within the borehole  12 . The connectors  104  and/or the devices  114  may be made of the composite material to prevent the connectors  104  and/or the securing and connecting devices  114  from interfering with and/or degrading the measurements that may be collected by the wireline tools  106  and/or the sensors  108  within the interiors  118  of the composite drill collar. The coiled wire bundle  116  may be made of a conductive metallic material, such as, for example, ferrite, copper and/or the like. 
     In embodiments, at least one of the downhole components  22 ,  32  may be a downhole tool which may have one or more sensors collecting one or measurements under tough downhole drilling conditions. For example, downhole component  26  may be a downhole tool which may have one or more sensors for collecting measurements associated with rock properties of the formation  14 . To protect the sensor, the downhole component  26  may have a shielding element  130  made of the composite material (hereinafter “composite shield  130 ”) covering the sensors as shown in  FIGS. 3-8 . The composite shield may be attached to the downhole component  26  to package and protect the sensors of the downhole component  26 . In embodiments, the downhole component  26  may be a composite collar which may be a shielding element for the sensors of the downhole component  26 . 
     The composite shield  130  may be manufactured and/or produced as a hollow cylinder or sleeve made out of the composite material which may be positioned, slid over and/or on tops the sensors of the downhole component  26  as shown in  FIGS. 3 ,  5  and  7 . The composite shield may contact and/or abut a collar shoulder  132  of the downhole component  26 . The collar shoulder  132  may have a threaded ring  134  which may be sized and adapted to receive the composite shield  132  such that the composite shield may lock with the threaded ring  134  as shown in  FIG. 3 . As a result, the composite shield  130  may be secured, connected and/or attached to the downhole component  26  via the threaded ring  134 . Alternatively, the composite shield  130  may be in the form of a composite drill collar. 
     The sensors of the downhole component  26  may be protected by the composite shield  130 . The composite shield  130  may be transparent or substantially transparent to measurements collected by the sensors. For example, the composite shield  130  may be transparent or substantially transparent to nuclear magnetic resonant, EM and/or acoustic field measurements. As a result, the composite shield  130  may not attenuate nuclear magnetic resonant, EM and/or acoustic field measurements and the one or more sensors may collect enhanced measurements through the composite shield  130 . 
     In embodiments, the composite shield  130  may be manufactured and/or produced as a pair of half-shells  140  which may be locked on a collar  142  of the downhole component  26  as shown in  FIGS. 4 ,  6  and  8 . Each half-shell  140  may have threaded rings (not shown in the drawings) which may be overlapped at both ends of the pair of half-shells to connect, attach and/or secure the pair of half shells  140  of the composite shield  130  to each other and the downhole component  26 . As a result, the composite shield  130  may be connected, attached and/or secured to the composite shield  130  for protecting the sensors of the downhole component  26 . 
     In embodiments, the composite shield  130  may be utilized to filter one mode of radiation out from being collected by the sensors of the downhole component  26 . For example, the composite shield  130  may have, for a z-directed coil (whereby the z-axis is along the downhole component axis), slots that may be parallel or substantially parallel to the axis of the downhole component  26 . The coil (not shown in the drawings) may be wound around a circumference of the composite shield  130 , and since any coil with more than one turn is helical in nature, the current may flow mostly in the x-y plane, but may also have a small component along the z-axis. A portion of current in the x-y plane may be equivalent to a magnetic dipole perpendicular to the x-y plane (i.e., in the z-axis). Superimposed on the magnetic dipole is a smaller dipole that may be caused by the component of the current along the z axis. The smaller latter dipole may be perpendicular (has no component along) or substantially perpendicular with respect to the z-axis. The large and small dipoles may be perpendicular or substantially perpendicular to each other; however, for a z-directed coil, only the large dipole may be desired and the small dipole may be parasitic or unwanted. The composite shield  130  may have axial slots which may allow radiation from the large dipole to pass while the shield attenuates the field from the small dipole. As such, the composite shield  130  may be viewed as having a filtering effect in favor of the large dipole. 
     In some applications, it is desirable to use the filtering effect of one or more slots  150  (hereinafter “slots  150 ”) in the composite shield  130  as shown in  FIG. 8 . The composite shield  130  may have a body  152  made of non-conductive and may have slots  150  which may be made of a conductive material. In embodiments, the slots  150  of the composite shield may be, for example, rods made of one or more metallic materials (hereinafter “metallic rods”) which may be embedded in the body of the composite shield  130  during the manufacturing of the composite shield  130 . As a result, the composite shield  130  and the slots  150  in the form of metallic rods may have a filtering effect and/or may provide a protective effect for both the metal rods and the non-conductive body of the composite shield. The one or more metallic materials of the slots  150  may be made of ferrite, copper and/or the like. The present specification should not be limited to a specific embodiment of the metallic materials of the slots  150 . 
     The composite shield  130  with the slots  150  may not be limited to the z-directed coils. For example, the slots  150  may be a tilted coil  154  with the body  152  of the composite shield  130  designed and/or configure to fit the tilted coil of the slots  150 . For example, the composite shield  130  may be designed having a tilted coil  154  which may be tilted at 45 degree angle with respect to an axis of the downhole component  26  as shown in  FIGS. 7 and 8 . In embodiments, the slots  150  are distributed around the composite shield  130  at angles that may be, for the most part, not inline with the axis of the downhole component. As a result, the slots  150  may provide filtering effect and/or mechanical protection for the tilted coil  154 . The body  152  of the composite shield  130  may be non-conductive while the slots  150  may be strips made of metal embedded into the body  152 . 
     The composite shield  130  made of the composite material may not, degrade or substantially degrade measurements collected by the one or more sensors of downhole component  26  because the composite material has low conductivity or substantially low conductivity. The composite shield  130  may be manufactured in any shape required by a geometry of the downhole component  26 . It should be understood that the present specification should not be deemed as limited to a specific shape and/or geometry of the composite shield  130  and/or the downhole component  26 . 
     In embodiments, nuclear particles may be used in measurements collected by the one or more sensors of the downhole component  26 , such as, for example, the naturally occurring radiation of rocks of the formation  14  to returning streams of thermalized neutrons. The composite shield  130  and/or the composite drill collar may provide significantly reduced attenuative properties to the nuclear particles both for (i) transmission from a source contained in the body  152  inside a center of the composite shield  130  and/or the composite drill collar and (ii) to the return path of the nuclear particles from the formation  14  back in to sensors housed within the composite shield  130  and/or the composite drill collar. As a result, reduced attenuative properties provide by the composite shield and/or the composite drill collar may substantially increase logging speeds and/or resolution from the detectors housed within the composite drill collar. 
     In embodiments, at least one of the downhole components  22 ,  32  may be a drill collar made of the composite material and having at least a LWD tool, a MWD tool, electronics and/or a sensor housed within a wall of the composite drill collar. For example, downhole component  28  may be composite drill collar  160  housing a LWD tool, a MWD tool, electronic circuitry and/or sensor  162  (hereinafter “the tool  162 ”) as shown in  FIG. 9 . The tool  162  may be configured and/or adapted to collect one or more measurements through the wall  164  of the composite drill collar  160 . The tool  162  may be configured and/or adapted to perform, execute and/or complete one or more tasks associated with the wellsite system  10 , the borehole  12 , the formation  14 , a drill string  16 , the BHA  18  and/or the drill bit  20 . The tool  162  may have or be programmed with logic for performing the one or more tasks and/or collecting the one or more measurements. During manufacturing of the composite drill collar  160 , the composite material may be built and/or formed around the tool  162  such that the tool  162  may be housed and/or located within the wall  164  of the composite drill collar  16 . 
     The composite drill collar  160  and/or the tool  162  may be positioned between other downhole components within the BHA  18 , such as, for example, between the downhole components  26  and  30  as shown in  FIG. 9 . The tool  162  of the composite drill collar  160  may be capable of transmitting wireless communication through the wall  164  of the composite drill collar  160  because the composite material of the composite drill collar  160  may be conductively and/or magnetically transparent to the tool  162  based on the non-conductive, substantially non-conductive, and non-metallic properties of the composite material. As a result, the tool  162  may wirelessly transmit and/or receive data, electronic instructions and/or electrical power and/or energy (hereinafter “power”) while the BHA  18  may be located within the borehole  12  and/or when the tool  162  may be at the surface  11 . In embodiments, the wireless data may include wireless telemetry data and/or one or more measurements collected by the downhole components  22 ,  32  and/or the tool  162 . Moreover, the tool  162  may, upon receiving the wireless power, execute the logic to perform the one or more tasks and/or to collect the one or more measurements. The wireless electronic instructions may relate to one or more tasks which may be performed by the tool  162  within the borehole  12  and/or the formation  14 . After receiving wireless power, the tool  162  may be actuated by the wireless power and may collect the one or more measurements and/or perform the one or more tasks. 
     The transparency of the composite drill collar  160  with respect to the tool  162  allows for transmitting and receiving of wireless data, electronic instruction and/or power from the tool  162  without the need for and use of a read-out port provided in the composite drill collar  160 . Inclusion of the read-out port within the composite drill collar  160  may weaken the structural integrity of the composite drill collar  160  and should be avoided when possible. By allowing for wireless communication and/or transmission of data, electronic instructions and/or power to and from the tool  162  through the wall  164  of the composite drill collar  160 , establishing and/or maintaining a wired connection between the tool  162  and a computer (not shown in the drawings) and/or a retrievable mandrel  166  (hereinafter “mandrel  166 ”) may be avoided. Establishing and maintaining a wired connection between the tool  162  and computer and/or the mandrel  166  may be cumbersome, inconvenient and/or time consuming and should also be avoided when possible. 
     The tool  162  housed within the composite drill collar  160  may perform one or more tasks and/or collect one or more enhanced measurements based on the transparency of the composite drill collar  160  with respect to the tool  162 . Additionally, the transparency of the composite drill collar  160  with respect to the tool  162  may improve efficiency and/or prevent negatively affecting and/or degrading the one or more tasks and/or measurements, such as, for example, resistivity measurements that may be collected by the tool  162 . For nuclear measurements, the non-conductive or substantially non-conductive composite drill collar  160  protects the tool  162  without shielding the tool  162  from radiation returning from the formation  14 . 
     In embodiments, the mandrel  166  may be connected to the wireline  110  and lowered into and/or positioned within the borehole  12  and/or the BHA  18 . The mandrel  166  may be centrally inserted into and/or positioned within an interior  168  of the composite drill collar  160 . The mandrel  166  may have one or more sensors, electronics and batteries (not shown in the figures). In embodiments, the mandrel  166  may be incorporated into a wireline tool or may be a wireline tool. The mandrel  166  and/or the one or more sensors of the mandrel  166  may be configured and/or adapted to collect one or more measurements related to characteristics and/or properties associated with the borehole  12 , the formation  14 , the drill string  16 , the BHA  18  and/or the drill bit  20 . The mandrel  166  and/or the one or more sensors of the mandrel  166  may collect the one or more measurements through the wall  164  of the composite drill collar  160  because the wall  164  may be transparent with respect to the mandrel  166  and/or the one or more sensors of the mandrel  166 . 
     The mandrel  166  may have one or more coils and/or antennas  180  (hereinafter “inner coils  180 ”) as shown in  FIGS. 10-13 . The mandrel  166  may be configured and/or adapted to transmit and/or receive at least one EM signal, such as, for example, at least one radio frequency (hereinafter “RF”) signal via the inner coils. As a result, the mandrel  166  may be configured and/or adapted to transmit and/or receive wireless communication of data, electronic instructions and/or power via the inner coils  180 . The mandrel  166  may be scaled and/or sized small enough so as to leave available space within the interior  168  of the composite drill collar  160  for necessary fluid-flows of drilling fluids  170  through the interior  168  of the composite drill collar  160 . As a result, an annular flow path for the drilling fluids may be providing around the mandrel  166  and an inside of the wall  164  of the composite drill collar  160 . 
     The tool  162  may have one or more outer coils and/or antennas  182  (hereinafter “outer coils  182 ”) as shown in  FIGS. 10-13  which may be configured and/or adapted to transmit and/or receive wireless data, electronic instructions and/or power via at least one signal, for example, EM signals, such as, RF signals. In embodiments, the outer coils  182  may be embedded into the walls  164  and/or other portions of the composite drill collar  160  during the manufacturing of the composite drill collar  160 . The inner coils  180  of the mandrel and/or the outer coils  182  of the tool  162  and/or the composite drill collar  160 , respectively may be made of one or more metallic materials, such as, for example, ferrite, copper and/or the like. It should be understood that the present specification should not be deemed limited to a specific embodiment of the metallic material of the inner coils  180  and/or the outer coils  182 . Moreover, it should be understood that the present specification should not be deemed as limited to a specific embodiment of the at least one signal for transmitting and/or receiving wireless data, electronic instructions and/or power. 
     In embodiments, the wireless communication and/or transmission of data, electronic instructions and/or power between the tool  162  and the computer and/or the mandrel  166  may be carried out by induction, resonant inductive coupling, inductive power transfer, electrodynamic inductive effect, radio wave frequencies, microwave frequencies or transmissions, laser beams and/or evanescent wave coupling, as known in the art. In embodiments, the wireless communication between the tool  162  and the computer and/or the mandrel  166  may require the tool  162  and the computer and/or the mandrel  166  to be in a line of sight with each other, directly adjacent to each other, and/or in a close proximity to each other. 
     The wireless communication may be based on a strong coupling between electromagnetic resonant objects, such as, the inner coils  180  of the mandrel  166  and the outer coils  182  of the tool  162  to wirelessly transfer the data, the electronic instructions and/or the power. The tool  162  and the mandrel  166  may contain one or more magnetic loop antennas critically tuned to the same or substantially the same frequency. In embodiments, the inner coils  180  of the mandrel and the outer coils  182  of the tool  162  may form the one or more magnetic look antennas which may be critically tuned to the same or substantially the same frequency. As a result of the magnetic loop antennas being tuned to the same or substantially the same frequency, strong-coupled resonances may be achieved between the tool  162  and the mandrel  166  to achieve high wireless communication and/or power-transmission efficiency between the tool  162  and the mandrel  166 . Moreover, transmission of data and/or electronic instructions may be embedded into and/or included with high wireless power transmissions between the tool  162  and the mandrel  166 . In embodiments, the wireless data, electronic instructions and/or power transfer technology may be, for example, WiTricity or a wireless resonant energy link as known in the art. 
     The non-conductive or substantially non-conductive composite drill collar  160  may not load the outer coils  182  of the tool  162  and/or the composite drill collar  160  which may improve and/or enhance wireless communication properties of the tool  162 , the composite drill collar  160  and/or the mandrel  166 . Data, electronic instructions and/or power may be wirelessly transmitted to and/or received by the composite drill collar  160 , the tool  162 , the mandrel  166  and/or the computer. In embodiments, data, electronic instructions and/or power may be wirelessly transmitted between the mandrel  166  and the tool  162  and/or the composite drill collar  160  via the inner coils  180  of the mandrel and the outer coils  182  of the tool  162 , respectively. The wireless data that may be wirelessly communicated and/or transmitted from the mandrel  166  to the tool  162  may include telemetry data and/or the one or more measurements which may be collected by the mandrel  166  and/or the one or more sensors of the mandrel  166 . In embodiments, the wireless communication and/or transmission of data, electronic instructions and/or power between the tool  162  and/or the composite drill collar  160  and the computer and/or the mandrel  166  may occur within the borehole as shown in  FIG. 9 . Alternatively, the wireless communication and/or transmission of data, electronic instructions and/or power between the computer and the tool  162  and/or the composite drill collar may occur at the surface  11  after the tool  162  and drill collar  160  have been pulled from the borehole  12 . 
     Upon receiving the wireless electrical instructions and/or power from the mandrel  166 , the tool  162  may be actuated and/or the logic may be executed to collect the one or more measurements and/or perform the one or more tasks. As a result, the mandrel  166  may control when and/or where one or more tasks may be performed, executed and/or completed by the tool  162 . The mandrel  166  may wirelessly provide necessary wireless electronic instructions and/or power to the tool  162  for performing, executing and/or completing the one or more tasks and/or collecting the one or more measurements. For example, data and/or electronic instructions wirelessly communicated to the tool  162  from the mandrel  166  may be, for example, data and/or electronic instructions relating to setup, programming and/or operation of the tool  162  and/or instructions to perform an inventor of any downhole components located within the range of the at least one signal. The one or more tasks performable and/or the one or more measurements collectable by the tool  162  may be any downhole task and/or measurement, respectively, as know to one of ordinary skill in the art. 
     In embodiments, the composite drill collar  160  and/or the tool  162  may be electrically connected to a power source (not shown in the drawings) which may be located locally or remotely with respect to the composite drill collar  160 . The composite drill collar  160  and/or the tool  162  may transmit wireless power from the power source to the mandrel  166  via the outer coils  182  of the composite drill collar  160  and/or the tool  162  and the inner coils  180  of the mandrel  166 . Alternatively, the mandrel  166  may be electrically connected to a power source (not shown in the drawings) which may be located locally or remotely with respect to the mandrel  166 . The mandrel  166  may transmit wireless power from the power source to the composite drill collar  160  and/or the tool  162  via the inner coils  180  of the mandrel and the outer coils  182  of the composite drill collar  160  and/or the tool  162 . 
     In embodiments, the outer coils  182  may be embedded in the composite drill collar  160  and may be configured to filter and/or shape the at least one EM signal that may be produced and/or transmitted by the inner coil  180  of the mandrel  166 . By filtering and/or shaping at least one EM signal of the inner coil  180 , a signal strength and/or intensity of the at least one EM signal may be substantially increased which may increase an efficiency of the wireless communication and/or transmission of data, electrical instructions and/or power between the inner coil  180  and the outer coil. The inner coils  180  and the outer coils  182  may be configured to allow for wireless communication and/or transmission of data, electronic instructions, power and/or telemetry between the inner coils  180  and outer coils  182  without requiring holes, feedthroughs and/or wires for the composite drill collar  160  and/or the mandrel  166 . 
       FIG. 10  illustrates the inner coil  180  embedded in the mandrel  166  which may be incorporated into, for example, a wireline tool centrally located within the composite drill collar  160 .  FIG. 11  shows an embodiment where the outer coils  182  of the composite drill collar  160  and the inner coils  180  of the mandrel are tilted with respect to each other. The outer coil  182  of the composite drill collar  160  may act as a shield, filter or resonator to the inner coil  180  mounted on the mandrel  166 . To enhance field focusing of the inner coil  180  of the mandrel  166 , more than one outer coils  184   a ,  184   b  may be separately embedded in the composite drill collar  160  as shown in  FIG. 11 . Wireless data, electronic instructions and/or power may be transmitted between inner coil  180  of the mandrel and the outer coils  184   a ,  184   b  which may be made of a conductive metallic material, such as, for example ferrite, copper and/or the like. The present specification should not be deemed as limited to a specific number of outer coils that may be embedded in the composite drill collar  160 . 
     In embodiments, strips (not shown in the drawings) of metallic material, such as, ferrite may be embedded in the composite drill collar  160 . The strips embedded in the composite drill collar may focus the one or more signals transmitted from the inner coil  180  of the mandrel  166  to the tool  162 . 
     In embodiments, the outer coils  182  of the composite drill collar  160  may receive wireless power and/or bidirectional telemetry from the inner coils  180  of the mandrel  166  and/or may direct the wireless power and telemetry through circuitry to a sensor of, for example, the tool  162  as shown in  FIG. 13 . The inner coils  180  and the outer coils  182  (hereinafter collectively known as “the coils  180 ,  182 ”) may operate at a different frequency and/or may have different winding arrangements, such as, for example, a transverse arrangement as opposed to coaxial. As a result, the transverse arrangement may allow directional changes in the EM field of the coils  180 ,  182 . 
     Interactions between the coils  180 ,  182  may be improved if a layer (not shown in the drawings) may be positioned between the coils  180 ,  182  which may contain materials with high magnetic permeability such as, for example, ferrite. By placing the layer between the coils  180 ,  182 , the resulting structure may be electrically equivalent to a transformer whose efficiency depends on the magnetic permeability of the material carrying the magnetic flux from, for example, the inner coils  180  to the outer coils  182 . The materials of the layer may be any high magnetic permeable material as known to one of ordinary skill in the art. 
     In embodiments, the outer coils  184   a ,  184   b  may be physically connected by a connecting wire  186  which may provide maximum efficiency for wireless communication and transmission of data, wireless instructions and/or power between the inner coils  180  and the outer coils  184   a ,  184   b  as shown in  FIG. 12 . The connecting wire  186  may be made of a conductive metallic material, such as ferrite, copper and/or the like. The composite drill collar may be made and/or grown around the outer coils  184   a ,  184   b  and the wire  186 . A result, the connecting wire  186  may be embedded in the composite drill collar  160  without any loss of mechanical integrity of the composite drill collar  160 . The conductive material of the inner coils  180 , the outer coils  182 , the outer coils  184   a ,  184   b  and/or the connecting wire  186  may be made of any conductive material as known to one of ordinary skill in the art. 
     Another advantage of the non-conductive composite drill collar may be antenna efficiency. In embodiments, antenna coils  172  may be wound around an outside perimeter  174  of the composite drill collar  160  either as tilted antennas or as axial antennas as shown in  FIG. 9 . A groove (not shown in the drawings) may be cutting and/or formed in the outside perimeter  174  to house and/or secure the antenna coils  172 . The groove may not have a great depth with respect to a thickness of wall  164  of the composite drill collar  160  because the depth of the groove may adversely effect the mechanical integrity of the composite drill collar  160  which may be a priority over the depth of the groove. However, the depth of groove may be an important parameter controlling the efficiency of the antenna coils  172 . When a metallic object is brought close to a flowing current, an Eddy current is induced in the metallic object which contracts the original current (flows in opposite direction to it). In the limit when the conducive object touches the current carrying structure, the two currents cancel each other and the antenna is shorted. As the conductive object is moved away from the coil its effect is reduced. 
     With the composite drill collar  160  made of non-conductive material, the intensity of the Eddy current may be proportional to the conductivity of the composite drill collar  160  which may be very low. As a result, the antenna coils  172  may become more efficient to the extent that the closest metallic object may be farther away than case of a metallic drill collar. 
     Electrical components, such as, for example, the mandrel  166  and the flowing drilling fluids, which may be conductive, in the interior  168  of the composite drill collar  160  may affect the antenna coils  172 . As a result, the electrical components may be shielded by a layer (not shown in the drawings) of metal to create a constant internal environment for the antenna coils  172 . The metal layer may affect loading the antenna coils  172  which may be proportionally less than that of a metal drill collar  160 . Additionally, any necessary feed throughs for the antenna coils  172  may be made an integral part of the composite drill collar. Moreover, the wire of the antenna coils  172  may go directly through the wall  164  of the composite drill collar  160  because the collar may be made after the coil without the no need to drill any holes or to pressure seal using O-rings. 
     In embodiments, at least one of the drill pipes  17 , the downhole components  22 ,  32  and/or the uphole components  34  may be made of the composite material and may have a RF identified tag  176  (hereinafter “RFID tag  176 ”) embedded in the composite material as shown in  FIG. 9 . For example, the composite drill collar  160  may have the RFID tag  176  which may be housed in the wall  164  of the composite drill collar  160  during the manufacture of the composite drill collar  160 . The RFID tag  176  may be configured and/or adapted to store and/or process information associated with, for example, the composite drill collar  160 . Additionally, the RFID tag  176  may having an antenna (not shown in the drawings) configured and/or adapted for receiving and/or transmitting one or more RF signals The information stored and/or processed by the RFID tag  176  may be information related to, for example, the specifications of the composite drill collar  160 . The information stored and/or processed by the RFID tag  176  may be any information as known to one of ordinary skilling the art that may relate to and/or be relevant to the drill pipe, downhole component and/or uphole component which may house the RFID tag  176 . 
     A RFID reader (not shown in the drawings) may be utilized to access the information that may be stored by the RFID  176  via one or more RF signals. For example, the RFID reader may access the information associated with the composite drill collar  160  that may be stored by the RFID tag  176  via the one or more RF signals. As a result, the specifications of the composite drill collar  160  may be quickly and easily identified by the user of the RFID reader. Additionally, the RFID reader, when used multiple RFID tags may identified which assets may be deployed in the borehole  12  or location and/or may track the functionality of identically looking downhole components. In some cases, multiple different tools with different functionalities may be protected with the same type of composite drill collar and/or composite material which may make it difficult to identify the multiple different tools without the use of RFID tags. In embodiments, the RFID reader may be a hand held device or may be located on, for example, a floor of a drilling rig (not shown in the drawings). The RFID reader may be any RFID reader as known to one of ordinary skill in the art. 
     In embodiments, one or more composite short pipes  190  (hereinafter “composite pipes  190 ”) may be incorporated into the drill string  16  as shown in  FIG. 14 . Each of the composite pipes  190  may be located between and/or connected to two separate drill pipes  17 . The composite pipes  190  may be made of the composite material. One or more energy harvesting devices  192  (hereinafter “devices  192 ”) may be embedded within the composite pipes  190  during manufacture of the composite pipes  190 . The devices  192  may be extensionally and/or radially deployed and/or embedded within the composite pipes  190 . The devices  192  may be, for example, energy harvesting piezoelectric strips  194  as shown in  FIG. 15 , energy harvesting electromagnetic devices and/or the like. The devices  192  may be any number of and/or any type of energy harvesting devices suitable for embedding into the composite material of the composite pipes  190 . 
     The devices  192  of the composite pipes  190  may be configured and/or adapted to convert one or more deformations of the drill string  16  into electrical power which may be utilized to power one or more uphole components  34  and/or downhole components  22 ,  32 . The deformation of the drill string  16  may be a result of stress on the drill string  16 , such as, for example, Hoop stresses, extensional motions and/or the like. The one or more deformations may occur at and/or within the one or more drill pipes  17  and/or at the composite pipes  190 . It should be understood that the present specification is not limited to a specific embodiment of the one or more deformations of the drill string  16 . 
     The devices  192  may be electrically connected to one or more uphole components  34  and/or downhole components  22 ,  32  to provide and/or supply harvested energy and/or the electrical power to the downhole components  22 ,  32  the uphole components  34 , such as, for example, low-power repeaters or sensors via wires  196 . The one or more uphole components  34  may be embedded within the composite pipes  190  and/or located within one of the drill pipes  17  as shown in  FIG. 14 . For example, one or more energy harvesting piezoelectric strips  194  may be embedded within the composite pipes  190 , may convert Hoop stresses and extensional motions of the drill string  16  into electrical power and may supply the electrical power to the uphole components  34  via the wires  196 . In embodiments, a length of the composite pipes  190  may be selected to induce a system resonance at a desired frequency as known to one of ordinary skill in the art. 
     In embodiments, at least one or more composite housings  200  (hereinafter “composite housings  200 ”) of at least one of the drill pipes  17 , the downhole components  22 ,  32 , and/or the uphole component  34  may be made of the composite material as shown in  FIG. 16 . A flow line  202  may be embedded in the composite housing  200  during the manufacture of the composite housing  200 . The flow line may extend along a length of the composite housings  200  from a first end  204  of the composite housings  200  to a second end  206  of the composite housings  200  which may be located opposite to the first end  204 . A diameter and/or a radius of the flow line  202  may be any diameter and/or radius as known to one of ordinary skill in the art. 
     The flow line  202  may be sized, configured and/or adapted to permit one or more clean fluids to flow across the length of the composite housing  200 . As a result, the one or more clean fluids may be distributed to at least one of the BHA  18 , the downhole components  22 ,  32  and/or the uphole components  34 . The clean fluids provided via the flow line  202  may provide, for example, hydraulic power to at least one of the BHA  18 , the downhole components  22 ,  32  and/or the uphole components  34 . For example, hydraulic fluids may be provided to, for example, a power drive stirring tool and/or to a piston of a downhole tool. 
     The first end  204  of composite housings  200  may have first threading  208  and a first annulus  210 , and second end  206  of the composite housings  200  may have second threading  212  and a second annulus  214 . The first threading  208  at the first end  204  may correspond to the second threading  212  at the second end  206 . The second end  206  of the composite housings  200  may have one or more sealing elements  215  for providing a complete seal around the second annulus  214 . For example, the sealing elements  215  may be a mechanical gasket, O-rings and/or the like. The sealing elements  215  may be any sealing elements as known to one or ordinary skill in the art. 
     The first treading  208  of the first end  204  of a first composite housing  216  may be threaded, secured and/or connected to the second threads  212  of the second end  206  of a second composite housing  218  as shown in  FIG. 17 . The first and second composite housings  216 ,  218  may be secured together and the first annulus  210  at the first end  204  of the first composite housing  216  may be aligned with or substantially aligned with the second annulus  214  of the second composite housing  218 . As a result, the first annulus  210  and flow line  202  of the first composite housing  216  may be in fluid communication with the second annulus  214  and/or the flow line  202  of the second composite housing  218 . Moreover, the fluid communication between first annulus  210  and the second annulus  214  may be sealed by the sealing elements  215  at the second end  206  of the second composite housing  218 . 
     In embodiments, the first end  204  of the first composite housing  216  may have a first arm  220  with a male connector  222  which may extend outward with respect to the first threading  208  of the first composite housing  216  as shown in  FIG. 18 . The flow line  202  of the first composite housing  216  may extend up to and/or terminate at the male connector  222 . The second end  206  of the second composite housing  218  may have a second arm  224  with a female connector  226  which may extend outward with respect to the second threading  212  of the second composite housing  218 . The flow line  202  of the second composite housing  218  may extend up to and/or terminate at the female connector  222 . The male connector  222  may have the securing elements  215  to provide a seal when the male connector  222  may be inserted into the female connector  226 . 
     The first and second composite housings  216 ,  218  may be attached and/or secured together via the first and second threading  208 ,  212  and the male connector  222  of the first composite housing  216  may be mated with and/or located within the female connector  226  of the second composite housing  218 . As a result, the flow line  202  of the first composite housing  216  may be in fluid communication with the flow line  202  of the second composite housing  218 . Moreover, the fluid communication between first annulus  210  and the second annulus  214  may be sealed by the sealing elements  215  of the male connector  222 . 
     In embodiments, at least one of the downhole components  22 ,  32  may be connected to or may be an acoustic attenuator  230  which may be made of the composite material (hereinafter “composite attenuator  230 ”) as shown in  FIGS. 19-21 . For example, the composite attenuator may be connected to a LWD tool and/or a wireline logging tool. In embodiments, the acoustic attenuator  230  may be located between two downhole tools. For example, the composite attenuator  230  may located and/or positioned between two wireline logging tools or between the downhole components  22 ,  24  of  FIG. 1 . The composite attenuator  230  may be connected to and/or used with any downhole component as known to one of ordinary skill in the art. 
     The composite attenuator  230  may have one or more acoustic impedance elements which may have been embedded within a wall  232  of the composite attenuator  230  during manufacture of the composite attenuator. In embodiments, the acoustic impedance elements may be one or more air gaps  234  (hereinafter “air gaps  234 ”) as shown in  FIG. 19  and/or one or more metallic rings  236  (hereinafter “metallic rings  236 ”) as shown in  FIGS. 20 and 21 . The air gaps  234  and/or the metallic rings  236  may be embedded within the wall  232  of the composite attenuator  230  during manufacture of the composite attenuator  230 . It should be understood that the present specification is not deemed limited to the specific embodiments of the acoustic impedance elements which may be embedded in the composite attenuator  230 . 
     The air gaps  234  and/or metallic rings  236  of the composite attenuator  230  may be configured to and/or adapted to break, terminate or substantially terminate a wave propagation path which may have entered the wall  232  of the composite attenuator  230  and/or may be propagating and/or moving through the composite attenuator  230 . Alternatively, a pattern of the air gaps  234  and/or the metallic rings  236  within the wall  232  of the composite attenuator  230  may be designed and/or manufactured to improve wave propagation attenuation across the composite attenuator  230  as known to one of ordinary skill in the art. 
     In order to provide the air gaps  234  within the wall  232  of the composite attenuator  230 , one or more hollow metallic cubes  235  may be embedded within the wall  232  of the composite attenuator  230  during the manufacture of the composite attenuator  230 . The metallic rings  236  may be, for example, one or more metal rings having an acoustic impedance that may be higher than an acoustic impedance of the composite material of the composite attenuator  230  which may have a low impedance property. The air gaps  234 , metallic cubes  235  and/or the metallic rings  236  may be located and/or embedded inside the wall  232  of the composite attenuator  230  as shown in  FIGS. 19 and 20 . Alternatively, the metallic cubes  235  and/or the metallic rings  236  may be embedded such that an edge or a side of the metallic cubes  235  and/or the metallic rings  236  extend to and/or terminate at an outside surface  238  of the wall  232  of the composite attenuator  230  as shown in  FIG. 21 . 
     In embodiments, at least one of the downhole components  22 ,  32  may be configured to and/or adapted to transmit one or more signals and at least another of the downhole components  22 ,  32  may be configured and/or adapted to receive the one or more signals, such as, for example, EM signals. For example, the downhole component  26  may have one or more transmitter coils  36  for transmitting one or more EM signals, and the downhole component  30  may have one or more receiver coils  38  for receiving the one or more EM signals that may be transmitted by the one or more transmitting coils  36  the downhole component  26  as shown in  FIG. 1 . The downhole component  28  may be located between downhole components  26 ,  30  and may be an electrical gaps isolator collar which may be configured and/or adapted to electrically isolate the downhole components  26 ,  30  from each other. The electrical gaps isolator collar of the downhole component  28  may be made of the composite material (hereinafter “composite isolator collar”) which may be non-conductive and/or substantially non-conductive to provide an isolation gap between the downhole components  26 ,  30 . As a result, the composite isolator collar may be electromagnetically transparent with respect to the transmitter coils  36  and the receiver coils  38  of the downhole components  26 ,  30 , respectively. Moreover, the composite isolator collar may insulate a first position on the BHA  18 , for example, downhole component  26 , from a second position on the BHA  18 , for example, downhole component  30 . 
     The composite isolator collar may electrically isolate and/or insulate the one or more transmitter coils  36  of the downhole component  26  from the one or more receiver coils  38  of the downhole component  30 . The composite isolator collar may prevent the one or more signals transmitted by the downhole component  26  from passing through the composite isolator collar of the downhole component  28  and into the downhole component  30 . As a result, the one or more signals transmitted by the downhole component  26  may be radiated into the formation  14  by the composite isolator collar whereby the one or more signals may penetrate the formation  14  and/or be received and/or detected by the receiving coils  38  of the downhole component  30  as shown in  FIG. 1 . The downhole component  30  may collect one or more measurements related to characteristics and/or properties associated with the formation  14  based on the one or more signals received from the downhole component  26  and/or radiated by the composite isolator collar. As a result, the electromagnetically transparent composite material of the composite isolator collar may substantially improve efficiency and/or accuracy of the one or more measurements that may be collected by electromagnetic telemetry tools, anti-collision electromagnetic tools, electromagnetic look ahead tools and/or other known electromagnetic tools. Further, the composite isolator collar of the downhole component  28  may be electrically and mechanically stronger than conventional metallic electrical isolator subs. As a result, the composite isolator collar may increase reliability and/or may lower costs associated with manufacturing electromagnetic tools. 
       FIG. 22  shows a composite drill collar  300  which may be made of the non-conductive or substantially non-conductive composite material. In embodiments, at least one composite drill collar  300  may be incorporated in the BHA  18  of the wellsite system  10 . One or more electrodes or sensors  302  (hereinafter “sensors  302 ”) may be embedded into the composite material of the composite drill collar  300  during manufacturing of the composite drill collar  300 . The one or more electrodes  302  may be modular and/or azimuthal electrodes mounted on the composite drill collar  300 . As a result, at least one large array of electrodes  302  which may be azimuthally mounted on the composite drill collar  300  may be provide for improved vertical and azimuthal measurement resolution. Any number of electrodes  302  may be embedded into the composite drill collar  300  and/or incorporated into the large array of electrodes  302  as known to one of ordinary skill in the art. It should be understood that the present specification should not be deemed as limited to specific embodiments of the electrodes  302  which may be suitable embedded into the composite drill collar  300 . 
     Isolating portions  304  of the non-conductive or substantially non-conductive composite material may be located between two adjacently located electrodes  302 . As a result, each of the electrodes  302  may be electrically isolated from each other via the isolating portions  304  of the composite material. The electrically isolated electrodes  302  may be utilized to collect one or more measurements relating one or more characteristics and/or properties associated with the borehole  12 , the formation  14 , the drill string  16 , the BHA  18 , the drill bit  20  and/or drilling fluid  170 . For example, the electrically isolated electrodes  302  may be utilized for collecting streaming potential measurements having applications in LWD operations and/or permanent monitoring for fluid front measurement. The measurements collected by the one or more electrodes  302  may be any type of measurements as known to one of ordinary skill in the art. 
     The composite drill collar  300  having one or more electrodes  302  may be arranged along the BHA  18  at a position near and/or adjacent to the drilling bit  20 , such as, for example, on a near-bit tool. As a result, the composite drill collar  300 , during drilling, may collect one or more measurements associated with, for example, formation pressure of the formation  14 . In embodiments, the one or more electrodes  302  may be permanent electrodes for fluid front monitoring application. As a result, the one or more electrodes  302  may be mounted on the composite drill collar  300  such that the one or more electrodes  302  may collect measurements associated with a reservoir of the borehole  12  and/or monitor the natural electrical properties of the reservoir as a function of time and production rate. 
       FIG. 23  shows wellsite system  250  which may have the drill string  16  and a bottom hole assembly  252  (hereinafter “BHA  252 ”) which may be connected to the drill string  16 . The drill string  16  and/or the BHA  252  may be positioned inside the borehole  12  in the formation  14 . The BHA  252  may include downhole components  26 ,  30 ,  32 , the drill bit  20  and other downhole components, such as, for example, composite drill collars  254 ,  256 . The composite drill collars  254 ,  256  may be made of the non-conductive or substantially non-conductive composite material. For example, the composite drill collar  254  may be located and/or positioned between the one or more drill pipes  17  and downhole component  26 , and composite drill collar  256  may be located and/or positioned between downhole component  26  and downhole components  30 ,  32 . 
     In embodiments, at least one of the downhole components  26 ,  30 ,  32  may be a formation evaluation tool which may perform and/or collect rock formation conductivity measurements by supplying a current between a pair of electrodes and measuring the voltage between the pair of electrodes in contact with the formation  14 . In embodiments, the downhole components  26 ,  30 ,  32  may have one or more transmitters, receiver and/or detectors. For example, the downhole component  26  may have a first electrode  258 , and at least one of the downhole components  30 ,  32  may have a second electrode  260 . Alternatively, the first electrode  258  may be located at the surface  11 . At least one of the first and second composite drill collars  254 ,  256  may be located and/or positioned between the first electrode  258  and the second electrode  260 . The first electrode  258  may be configured and/or adapted to transmit current into the borehole  12  and/or the formation  14 , the current may transverse the borehole  12  and/or the formation  14 , and the second electrode  260  may be configured and/or adapted to detect and/or receive the current from the borehole  12  and/or the formation  14 . As a result, the second electrode  260  may detect and/or receive current from the borehole  12  and/or the formation  14  which may have been transmitted from the first electrode  258 . At least one of the downhole components  30 ,  32  may collect measurements related to characteristics and/or properties of the borehole  12  and/or formation  14  based on the current detected and/or received from the borehole  12  and/or the formation  14 . The first and second composite drill collars  254 ,  256  may have at least one receiver  264  which may be configured and/or adapted to collect one or more measurements related to one or more characteristics and/or properties associated with the borehole  12  and/or the formation  14 . 
     For example, the first electrode  258  may transmit and/or emit an electrical current which may be prevented and/or blocked from entering the drill pipes  17  via the first composite drill collar  254  which may have insulating properties and/or the downhole components  30 ,  32  via the second composite drill collar  256  which may have insulating properties. As a result, the electrical current may be radiated into the borehole  12  and/or the formation  14  via the first and/or second composite drill collars  254 ,  256 , and the second electrode  260  of at least one of the downhole component  30 ,  32  may detect and/or receive the radiated electrical current from the borehole  12  and/or the formation  14 . Alternatively, the first electrode  258  at the surface  11  may transmit and/or radiate an electrical current into the borehole  12  and/or the formation  14 , and the second electrode  260  of at least one of the downhole component  30 ,  32  may detect and/or receive the electrical current from the borehole  12  and/or the formation  14 . At least one of the downhole components  30 ,  32  may collect one or more measurements relating to one or more characteristics and/or properties of the borehole  12  and/or the formation  14  based on the current received by the second electrode  260 . 
     Presence of a metallic component, such as, for example, a metallic drill collar near and/or adjacent to the first and second electrodes  258 ,  260  may cause unwanted current flows into the metallic component. As a result of the unwanted current flows, the sensitivity to the formation resistivity may be substantially reduced, this may require one or more compensation methods to be utilized to minimize the effects of the unwanted current flows. Additionally, the unwanted current flows may cause a voltage drop across the first and second electrodes  258 ,  260 . By providing at least one of the first and second composite drill collars  254 ,  256  between the first and second electrodes  258 ,  260 , the unwanted current flows through the first and/or second composite drill collar  254 ,  256  may be minimized or eliminated. As a result, the formation resistivity may be increased which may eliminate the need for using the one or more compensation methods for the unwanted currents flows. Use of first and/or second composite drill collars  254 ,  256  to minimize and/or eliminate unwanted current flows may also improve other downhole measurements, similar to a laterolog, such as, for example, surface to borehole LWD measurements in which a pair of current generating electrodes may be on the surface  11  and a pair of voltage measuring electrodes may be mounted downhole on at least one of the first and second composite drill collars  254 ,  256 . 
     In embodiments, some logging applications may require an electrical gap between two conductors, such as, for example, downhole components  26  and  30  which may be created by the second composite drill collar  256 . A first electrical current source may be provided above the second composite drill collar  256  by downhole component  26 , the first electrode  258  of the downhole component  26  or the first electrode  258  at the surface  11 . A second electrical current source may be provided below the second composite drill pipe  256  by the at least one of the downhole components  30 ,  32  or by the second electrode  260  of at least one of the downhole components  30 ,  32 . 
     By providing an electrical gap between the first and second electric sources via the second composite drill collar  256 , current may be transmitted and/or radiated into the borehole  12  and/or the surrounding formation  14  and may provide an electric dipole radiation pattern within the borehole  12  and/or the formation  14 . Alternatively, the electrical gap created by the second composite drill collar  256  may be used to electrically isolate the downhole component  26  from the downhole components  30 ,  32  in which case the electrical gap may not be acting as a source. Instead, the electrical gap created by the second composite drill collar  256  may be a receiver, and presence of the electrical gap created by the second composite drill collar  256  may prevent shorting an electrical potential which may develop on metallic components that may be present above (i.e., the downhole component  26 ) and below (i.e., the downhole components  30 ,  32 ) the electrical gap created by the second composite drill collar  256 . 
     An electrical gap may be created by the first composite drill collar  254  and may be used for wireless telemetry wherein an excitation current may be modulated at a telemetry source, such as, for example, the downhole component  26 . The modulated current transmitted and/or emitted from the downhole component  26  may be radiated into the borehole  12  and/or formation  14  by the electrical gap created by the first composite drill collar  254 . As a result, the modulated current may propagate in the borehole  12  and/or the formation  14  which may be detected at some distance away, such as, for example, by a detector  262  at the surface  11  as shown in  FIG. 23 . The detector  262  may interpret the received modulated current as telemetry data from the telemetry source. 
     The electrical gaps created by first and/or second composite drill collars  254 ,  256  may create and/or lead to the electric dipole radiation pattern, and the strength of the electric dipole radiation pattern may be proportional to a length of the electrical gap. The length of the electrical gaps may be determined by the lengths of the first and second composite drill collars  254 ,  256  which may be, for example, a few centimeters to several meters. Additionally, a depth of penetration for the current radiated from the electrical gap may be proportional to the length of the electrical gap. As a result, the electrical gaps created by the composite drill collars  254 ,  256  may be capable of generating improved and/or enhanced electric dipole radiation patterns with substantially large depths of penetration. Moreover, use of the first and/or second composite drill collars  254 ,  256  to create electrical gaps may allow downhole components to collect enhanced measurements relating to characteristic and/or properties of the borehole  12  and/or the formation  14 , such as, for example, resistivity of the formation  14 . 
     The electrical gaps created by first and/or second composite drill collars  254 ,  256  have at least one receiver  264  and lengths of the electrical gaps may be proportional to a resolution of measurements which may be collected by the receiver  264 . The length of the electrical gaps and the composite drill collars  254 ,  256  may be designed based on the desired resolution of measurements collected by the receiver  264  and may be incorporated into the BHA  252 . 
     The electrical gap may be created by at least one of the first and second composite drill collars  254 ,  256  which may have the receiver  264  for measuring electrical potentials developed in an environment of the borehole  12 . The one or more receivers  264  may be configured and/or adapted to receive one or more electrical potentials, such as, for example, electrokinetic potentials, induced potentials and/or the like. In embodiments, electrokinetic potentials may be used for collecting well logging measurements, such as, for example, spontaneous potential measurements which may be caused by a salinity difference between an invading fluid and a virgin fluid coupled with a membrane potential of shale layers. Other electrokinetic potentials that may be measured may include streaming potentials, electro-acoustic potentials, electro-osmosis and/or the like. The electrical potentials that may be received by the at least one receiver  264  may be any electrical potential as known to one of ordinary skill in the art. 
     With induced potentials, the electrical gap created by the first composite drill collar  254  may be a current source with respect to the electrical gap created by the second composite drill collar  256  and/or the receiver  264  of the second composite drill collar  256 . Alternatively, the current source may be any source of current that may use the electric current to induce a potential difference at the receiver  264  of the second composite drill collar  256 . The downhole components  26 ,  30  on the both sides of the electrical gaps created by the second composite drill collar  256  may have metallic material incorporated therein and may act as equipotential surfaces, but the respective potentials of the downhole components  26 ,  30  may not be the same. Thus, the metallic material of the downhole components  26 ,  30  may be used as electrodes to measure the potentials. Alternatively, the first and second electrodes  258 ,  260  may be provided and/or utilized to measure the potentials. 
     In embodiments, the electrical gap that may be created by at least one of the first and second composite drill collars  254 ,  256  may have a length that is large or substantially large, such as, for example, several meters. As a result, electrical current that may radiate from the electrical gap may have increased intensity and/or proportionally deeper depth of penetration into the formation  14 . The increased intensity and deeper depth of penetration into the formation  14  may allow the wellsite system  250  to perform cross-well type measurements, such as, for example, resistivity, with an adjacently located target well  266  (hereinafter “target well  266 ”). Moreover, the increased intensity deeper depth of penetration into the formation  14  may allow the wellsite system  250  to perform other large scale measurements, such as, for example, borehole to surface measurements, surface to borehole measurements and/or the like 
     For example, the first electrode  258  of the downhole component  26  may emit an electrical current which may be radiated into the formation  14  by the first and second composite drill collars  254 ,  256 . Alternatively, the first electrode  258  at the surface  11  may emit an electrical current which may radiate into the formation  14 . The electrical current from the first electrode  258 , either of the downhole component  26  or at the surface  11 , may propagate through the formation  14  and/or may reach a metal casing or component  268  (hereinafter “metal casing  268 ”) of the target well  266  as shown in  FIG. 23 . The electrical current that reached the metal casing  268  may propagate through the metal casing  268  and create at least one electromagnetic field  270  which may extend and/or propagate into the formation  14 . The second electrode  60  of at least one of the downhole components  30 ,  32  detect the at least one electromagnetic field  270  created by the metal casing  268  of the target well  266 . As a result, at least one of the downhole components  30 ,  32  may collect one or more measurements relating to one or more characteristics and/or properties associated with the metal casing  268  and/or the target well  266 . In embodiments, the receive  264  of at least one of the first and second composite drill collars  254 ,  256  may detect the at least one electromagnetic field  270  created by the metal casing  268  of the target well  266 . As a result, at least one of the first and second composite drill collars  254 ,  256  may collect one or more measurements relating to one or more characteristics and/or properties associated with the metal casing  268  and/or the target well  266 . 
     It will be appreciated that various of the above-disclosed and other features and functions, or alternatives thereof, may be desirably combined into many other different systems or applications. Also, various presently unforeseen or unanticipated alternatives, modifications, variations or improvements therein may be subsequently made by those skilled in the art, and are also intended to be encompassed by the following claims.