You are an expert at summarizing long articles. Proceed to summarize the following text:

You are an expert at summarizing long articles. Proceed to summarize the following text: 
TECHNICAL FIELD OF THE INVENTION 
   This invention relates in general to preventing the production of particulate materials through a wellbore traversing an unconsolidated or loosely consolidated subterranean formation and in particular to an apparatus and method for monitoring gravel placement throughout the entire length of a production interval. 
   BACKGROUND OF THE INVENTION 
   Without limiting the scope of the present invention, its background is described with reference to the production of hydrocarbons through a wellbore traversing an unconsolidated or loosely consolidated formation, as an example. 
   It is well known in the subterranean well drilling and completion arts that particulate materials such as sand may be produced during the production of hydrocarbons from a well traversing an unconsolidated or loosely consolidated subterranean formation. Numerous problems may occur as a result of the production of such particulate. For example, the particulate causes abrasive wear to components within the well, such as tubing, pumps and valves. In addition, the particulate may partially or fully clog the well creating the need for an expensive workover. Also, if the particulate matter is produced to the surface, it must be removed from the hydrocarbon fluids by processing equipment at the surface. 
   One method for preventing the production of such particulate material to the surface is gravel packing the well adjacent the unconsolidated or loosely consolidated production interval. In a typical gravel pack completion, a sand control screen is lowered into the wellbore on a work string to a position proximate the desired production interval. A fluid slurry including a liquid carrier and a particulate material known as gravel is then pumped down the work string and into the well annulus formed between the sand control screen and the perforated well casing or open hole production zone. 
   Typically, the liquid carrier is returned to the surface by flowing through the sand control screen and up a wash pipe. The gravel is deposited around the sand control screen to form a gravel pack, which is highly permeable to the flow of hydrocarbon fluids but blocks the flow of the particulate carried in the hydrocarbon fluids. As such, gravel packs can successfully prevent the problems associated with the production of particulate materials from the formation. 
   It has been found, however, that a complete gravel pack of the desired production interval is difficult to achieve particularly in long production intervals that are inclined, deviated or horizontal. One technique used to pack a long production interval that is inclined, deviated or horizontal is the alpha-beta gravel packing method. In this method, the gravel packing operation starts with the alpha wave depositing gravel on the low side of the wellbore progressing from the near end to the far end of the production interval. Once the alpha wave has reached the far end, the beta wave phase begins wherein gravel is deposited in the high side of the wellbore, on top of the alpha wave deposition, progressing from the far end to the near end of the production interval. 
   It has been found, however, that as the desired length of horizontal formations increases, it becomes more difficult to achieve a complete gravel pack even using the alpha-beta technique. Therefore, a need has arisen for an improved apparatus and method for gravel packing a long production interval that is inclined, deviated or horizontal. A need has also arisen for such an improved apparatus and method that achieve a complete gravel pack of such production intervals. Further, a need has arisen for such an improved apparatus and method that provide for enhanced control over the gravel placement process in substantially real time. 
   SUMMARY OF THE INVENTION 
   Accordingly, the present invention provides an apparatus and method for gravel packing long production intervals that are inclined, deviated or horizontal. The present invention overcomes the limitations of the existing methodologies by providing for enhanced control over the gravel placement process. In particular, the apparatus and method of the present invention enable fluid properties within a production interval of a wellbore to be monitored in substantially real time, thereby allowing substantially real time adjustments to be made during a gravel packing operation. 
   In one aspect, the present invention is directed to an apparatus for treating a production interval of a wellbore. The apparatus includes a packer assembly and a sand control screen assembly connected relative to the packer assembly. A cross-over assembly provides a lateral communication path downhole of the packer assembly for delivery of a treatment fluid and a lateral communication path uphole of the packer assembly for a return fluid. A wash pipe assembly is positioned in communication with the lateral communication path uphole of the packer assembly and extends into the interior of the sand control screen. At least one sensor is operably associated with the wash pipe assembly in order to collect data relative to at least one property of the treatment fluid during a treatment process such that a characteristic of the treatment fluid is regulatable during the treatment process based upon the data. 
   In one embodiment, the wash pipe comprises a body that includes a plurality of composite layers and a substantially impermeable layer lining an inner surface of the innermost composite layer forming a pressure chamber. In this embodiment, an energy conductor is integrally positioned within the body. The sensor may be directly or inductively coupled to the energy conductor which may take the form of an optical fiber that provides for communication between the sensor and other downhole devices such as a downhole processor or the surface. The sensor may measure properties of the treatment fluid such as viscosity, temperature, pressure, velocity, specific gravity, conductivity, fluid composition and the like. In one embodiment, a series of sensors may be embedded within the body of the wash pipe at predetermined intervals such that the treatment fluid properties may be monitored as a function of position along the length of the interval. Based upon the data collected by the sensors, various characteristics of the treatment fluid may be regulated such as fluid viscosity, proppant concentration, flow rate and the like. In one embodiment, the apparatus may further comprise a downhole mixer which provides a mixing area wherein constituent parts of the treatment fluid such as the carrier fluid and the solids are combined to form the fluid slurry downhole which reduces the delay in the downhole effect of the real time regulation of treatment fluid characteristics. 
   In another aspect, the present invention is directed to an apparatus for monitoring treatment fluid in a production interval of a wellbore during a treatment process. The apparatus comprising at least one sensor operably positioned within the production interval of the wellbore, wherein the sensor is operable to collect data relative to at least one property of the treatment fluid during the treatment process such that at least one characteristic of the treatment fluid is regulatable during the treatment process based upon the data. 
   In one embodiment, the sensor is operably associated with a tubular that may comprise a substantially impermeable layer lining an inner surface of a composite structure forming a pressure chamber therein. The tubular may form a portion of a washpipe, a base pipe, a production tubing or the like. The sensor may be attached or embedded within the inner surface of the composite structure or may be attached or embedded on the exterior of the body of the composite structure. 
   In a further aspect, the present invention is directed to a method for treating a production interval of a wellbore. The method includes positioning a sand control screen assembly within the production interval, disposing a wash pipe assembly interiorly of the sand control screen assembly, injecting a treatment fluid into the production interval exteriorly of the sand control screen assembly, sensing data relative to a property of the treatment fluid during the injecting with a sensor operably associated with the wash pipe and regulating a characteristic of the treatment fluid during the injecting based upon the data. 
   In one embodiment, the sensor is directly or inductively coupled to an energy conductor that is operably associated with the wash pipe such as an optical fiber integrally associated with the wash pipe. The data may include information relative to fluid viscosity, temperature, pressure, velocity, specific gravity, conductivity, fluid composition or the like. Once the data is processed either at the surface or by a downhole processor, real time alterations to the treatment may be performed such as regulating the fluid viscosity of the treatment fluid, regulating the proppant concentration of the treatment fluid, regulating the flow rate of the treatment fluid or the like. 
   In another aspect, the present invention is directed to a method for monitoring treatment fluid in a production interval of a wellbore during a treatment process. The method includes positioning at least one sensor within the production interval of the wellbore, sensing data relative to a property of the treatment fluid during the treatment process and regulating a characteristic of the treatment fluid during the treatment process based upon the data. 

   
     BRIEF DESCRIPTION OF THE DRAWINGS 
     For a more complete understanding of the features and advantages of the present invention, reference is now made to the detailed description of the invention along with the accompanying figures in which corresponding numerals in the different figures refer to corresponding parts and in which: 
       FIG. 1  is a schematic illustration of an offshore oil and gas platform operating an apparatus for gravel packing a production interval of a wellbore in accordance with the teachings of the present invention; 
       FIG. 2  is a half sectional view depicting the operation of an apparatus for gravel packing a horizontal open hole production interval of a wellbore of the present invention; 
       FIG. 3  is a partial half sectional view depicting the operation of an apparatus for gravel packing a horizontal open hole production interval of a wellbore of the present invention during the propagation of an alpha wave; 
       FIG. 4  is a partial half sectional view depicting the operation of the apparatus for gravel packing the horizontal open hole production interval of the wellbore of the present invention during the propagation of the alpha wave; 
       FIG. 5  is a partial half sectional view depicting the operation of the apparatus for gravel packing the horizontal open hole production interval of the wellbore of the present invention after a real time adjustment in the gravel packing slurry during the propagation of the alpha wave; 
       FIG. 6  is a partial half sectional view depicting the operation of the apparatus for gravel packing the horizontal open hole production interval of the wellbore of the present invention during the propagation of a beta wave; 
       FIG. 7  is a partial half sectional view depicting the operation of the apparatus for gravel packing the horizontal open hole production interval of the wellbore of the present invention at the completion stage of the treatment process; 
       FIG. 8  is a cross sectional view depicting a composite coiled tubing having energy conductors and sensors embedded therein in accordance with the teachings of the present invention; 
       FIG. 9  is a cross sectional view depicting an alternate embodiment of a composite coiled tubing having energy conductors and sensors embedded therein in accordance with the teachings of the present invention; 
       FIG. 10  is a half sectional view depicting the operation of an alternate embodiment of an apparatus for gravel packing a horizontal open hole production interval of a wellbore of the present invention; 
       FIG. 11  is a half sectional view depicting the operation of a further embodiment of an apparatus for gravel packing a horizontal open hole production interval of a wellbore of the present invention; 
       FIG. 12  is a half sectional view depicting the operation of another embodiment of an apparatus for gravel packing a horizontal open hole production interval of a wellbore of the present invention during the propagation of an alpha wave; and 
       FIG. 13  is a half sectional view depicting the operation of another embodiment of an apparatus for monitoring fluid parameters during production from a horizontal open hole production interval of a wellbore of the present invention. 
   

   DETAILED DESCRIPTION OF THE INVENTION 
   While the making and using of various embodiments of the present invention are discussed in detail below, it should be appreciated that the present invention provides many applicable inventive concepts which can be embodied in a wide variety of specific contexts. The specific embodiments discussed herein are merely illustrative of specific ways to make and use the invention, and do not delimit the scope of the present invention. 
   Referring initially to  FIG. 1 , an apparatus for gravel packing a horizontal open hole production interval of a wellbore operating from an offshore oil and gas platform is schematically illustrated and generally designated  10 . A semi-submersible platform  12  is centered over a submerged oil and gas formation  14  located below sea floor  16 . A subsea conduit  18  extends from deck  20  of platform  12  to wellhead installation  22  including blowout preventers  24 . Platform  12  has a hoisting apparatus  26  and a derrick  28  for raising and lowering pipe strings such as work string  30 . 
   A wellbore  32  extends through the various earth strata including formation  14 . A casing  34  is cemented within a portion of wellbore  32  by cement  36 . Work string  30  extends beyond the end of casing  34  and includes a series of sand control screen assemblies  38  and a cross-over assembly  40  for gravel packing the horizontal open hole production interval  42  of wellbore  32 . When it is desired to gravel pack production interval  42 , work string  30  is lowered through casing  34  such that sand control screen assemblies  38  are suitably positioned within production interval  42 . Thereafter, a fluid slurry including a liquid carrier and a particulate material such as sand, gravel or proppants is pumped down work string  30 . 
   As explained in more detail below, the fluid slurry is injected into production interval  42  through cross-over assembly  40 . Once in production interval  42 , the gravel in the fluid slurry is deposited therein using the alpha-beta method wherein gravel is deposited on the low side of production interval  42  from the near end to the far end of production interval  42  then in the high side of production interval  42 , on top of the alpha wave deposition, from the far end to the near end of production interval  42 . While some of the liquid carrier may enter formation  14 , the remainder of the liquid carrier travels through sand control screen assemblies  38 , into a wash pipe (not pictured) and up to the surface via annulus  44  above packer  46 . Sensors distributed along the length of production interval  42  monitor the fluid slurry at various locations and relay data relative to the fluid slurry to a downhole processor or to the surface. Various characteristics of the fluid slurry such as proppant concentration, fluid viscosity, fluid flow rate and the like may be regulated based on the relayed data to avoid, for example, sand bridges and to insure a complete gravel pack within production interval  42 . 
   Even though  FIG. 1  and the following figures depict a horizontal wellbore and even through the term horizontal is being used to describe the orientation of the depicted wellbore, it should be understood by those skilled in the art that the present invention is equally well suited for use in wellbores having other orientations including inclined or deviated wellbores. Accordingly, the use of the term horizontal herein is intended to include such inclined and deviated wellbores and is intended to specifically include any wellbore wherein it is desirable to use the alpha-beta gravel packing method. Additionally, it will be appreciated that the present invention is not limited to open hole production intervals. Moreover, it should be appreciated that the present invention is not limited to alpha-beta gravel packing treatments. As should be understood by those skilled in the art, the teachings of the present invention are also applicable to other treatment processes such as fracturing, frac packing, acid or other chemical treatments, resin consolidations, conformance treatments or any other treatment processes involving the pumping of a fluid into a downhole environment wherein it is beneficial to monitor various fluid properties as a function of position and use this data to regulate various treatment fluid characteristics during the treatment process. 
   Referring now to  FIG. 2 , therein is depicted a horizontal open hole production interval of a wellbore that is generally designated  50 . Casing  52  is cemented within a portion of a wellbore  54  proximate the heel or near end of the horizontal portion of wellbore  54 . A work string  56  extends through casing  52  and into the open hole production interval  58  of wellbore  54 . A packer assembly  60  is positioned between work string  56  and casing  52  at a cross-over assembly  62 . Work string  56  includes a sand control screen assembly  64 . Sand control screen assembly  64  includes a base pipe  70  that has a plurality of openings  72  which allow the flow of production fluids into the production tubing. The exact number, size and shape of openings  72  are not critical to the present invention, so long as sufficient area is provided for fluid production and the integrity of base pipe  70  is maintained. 
   Wrapped around base pipe  70  is a screen wire  74 . Screen wire  74  forms a plurality of turns with gaps therebetween through which formation fluids flow. The number of turns and the gap between the turns are determined based upon the characteristics of the formation from which fluid is being produced and the size of the gravel to be used during the gravel packing operation. Screen wire  74  may be wrapped directly on base pipe  70  or may be wrapped around a plurality of ribs (not pictured) that are generally symmetrically distributed about the axis of base pipe  70 . The ribs may have any suitable cross sectional geometry including a cylindrical cross section, a rectangular cross section, a triangular cross section or the like. In addition, the exact number of ribs will be dependant upon the diameter of base pipe  70  as well as other design characteristics that are well known in the art. 
   It should be understood by those skilled in the art that while  FIG. 2  has depicted a wire wrapped sand control screen, other types of filter media could alternatively be used in conjunction with the apparatus of the present invention, including, but not limited to, a fluid-porous, particulate restricting, diffusion bonded or sintered metal material such as a plurality of layers of a wire mesh that form a porous wire mesh screen designed to allow fluid flow therethrough but prevent the flow of particulate materials of a predetermined size from passing therethrough. 
   Disposed within work string  56  and extending from cross-over assembly  62  is a wash pipe assembly  76 . Wash pipe assembly  76  extends substantially to the far end of work string  56  near the toe or far end of production interval  58 . In the illustrated embodiment, wash pipe assembly  76  is a composite coiled tubing  78  that includes a series of sensors  80  embedded at predetermined intervals along wash pipe assembly  76  each of which is connected to one of a plurality of energy conductors  82  integrally positioned within composite coiled tubing  78 . As illustrated, sensors  80  include optical pressure sensors. It should be appreciated, however, that other types of pressure sensors may be used, including, but not limited to, electronic pressure sensors and the like. Moreover, as will be explained in further detail hereinbelow, the sensors may include viscosity sensors, temperature sensors, velocity sensors, specific gravity sensors, conductivity sensors, fluid composition sensors and the like. Additionally, it should be appreciated that multiple types of sensors may be employed together to collect data. For example, temperature sensors, pressure sensors and conductivity sensors may be employed together to achieve a better understanding of downhole conditions. Also, even though sensors  80  are depicted as being directly coupled to energy conductors  82 , it should be understood by those skilled in the art that sensors  80  could alternatively communicate with energy conductor  82  by other means including, but not limited to, by inductive coupling. 
   Referring now to  FIG. 2  and  FIG. 3  in which the operation of the apparatus for gravel packing the horizontal open hole production interval of the wellbore during the propagation of an alpha wave is depicted. Sensors  80  monitor data relative to the various properties of fluid slurry  84  and the downhole environment in production interval  58  and relay this data to a downhole processor or to the surface so that the composition of fluid slurry  84  may be regulated by regulating various fluid characteristics such as fluid viscosity, proppant concentration and flow rate of fluid slurry  84 . Energy conductors  82  are preferably fiber optic strands that carry optical information. The fiber optic strands may form a bundle  86  at the top of wash pipe assembly  76  which extends to the surface in annulus  88 . Alternatively, energy conductor  82  may be electrical wires. Communication may alternatively be achieved using a downhole telemetry system such as an electromagnetic telemetry system, an acoustic telemetry system or other wireless telemetry system that is known or subsequently discovered in the art for communications with the surface or a downhole processor. 
   During a gravel packing operation, the objective is to uniformly and completely fill horizontal production interval  58  with gravel. This is achieved by delivering a fluid and gravel slurry  84  down work string  56  into cross-over assembly  62 . Fluid slurry  84  containing gravel exits cross-over assembly  62  through cross-over ports  90  and is discharged into horizontal production interval  58  as indicated by arrows  92 . In the illustrated embodiment, fluid slurry  84  containing gravel then travels within production interval  58  with portions of the gravel dropping out of the slurry and building up on the low side of wellbore  54  from the heel to the toe of wellbore  54  as indicated by alpha wave front  94  of the alpha wave portion of the gravel pack. At the same time, portions of the carrier fluid of the fluid slurry pass through sand control screen assembly  64  and travel through annulus  96  between wash pipe assembly  76  and the interior of sand control screen assembly  64 . These return fluids enter the far end of wash pipe assembly  76 , flow back through wash pipe assembly  76  to cross-over assembly  62 , as indicated by arrows  98 , and flow into annulus  88  through cross-over ports  100  for return to the surface. 
   As the propagation of alpha wave front  94  continues from the heel to the toe of horizontal production interval  58 , sensors  80  monitor data relative to fluid slurry  84  and the downhole environment such as viscosity, temperature, pressure, velocity, fluid composition and the like, to ensure proper placement of the gravel and to avoid, for example, sand bridge formation with wellbore  54 . 
   Using sensors  80  of the present invention, the height of alpha deposition within production interval  58  may be regulated. Specifically, as best seen in  FIG. 4 , during the alpha wave portion of the gravel placement, portions of the alpha deposition are building up toward the high side of wellbore  54 . The changes in pressure caused by the build up of the alpha deposition are monitored by sensors  80  such that data may be sent to the surface or to a downhole processor in substantially real time, such that fluid slurry characteristics such as fluid viscosity, proppant concentration and flow rate of fluid slurry may be adjusted. 
   Referring now to  FIG. 5 , responsive to the real time indications that the alpha deposition is too high, the composition, flow rate or other characteristic of fluid slurry  84  is adjusted so that the height of the alpha deposition can be returned to a desirable level in substantially real time, as illustrated. Accordingly, by positioning sensors  80  at predetermined intervals, the present invention provides for the collection, recording and analysis of substantially real time data as a function of position relative to physical qualities within the wellbore. In this regard, the exact number of sensors and spacing of the sensors will be dependent on the specific type of treatment process being performed. It should be appreciated that a variety of sensors may be used to measure a variety of qualities to regulate the completion process. For example, properly positioned sensors could measure the change in the density of fluid slurry  84  within production interval  58 . Specifically, as the composition of constituent matter in production interval  58  at a particular sensor changes from a fluid slurry to a gravel pack as alpha wave front  94  passes a location, the density at this location significantly increases. Accordingly, by sensing the density at this location, the progress of alpha wave front  94  may be monitored and regulated. Other properties such as absolute pressure, absolute temperature, upstream-downstream differential temperature, flow velocity in production interval  58  and the like could also be measured by sensors  80  to regulate the alpha deposition. Hence, by improving the control over gravel placement the present invention insures a more complete gravel pack along the entire length of the production interval. In particular, the present invention ensures complete gravel packs of long, horizontal wellbores by providing substantially real time data relative to a plurality of locations along the completion interval. 
   Referring now to  FIG. 6 , as the beta wave portion of the treatment process progresses, sensors  80  monitor the progress of beta wave front  118 , fluid slurry  84  and the wellbore environment and relay the monitored data to a downhole processor or to the surface so that various parameters of the gravel slurry may be regulated in substantially real time to ensure a complete gravel pack.  FIG. 7  depicts wellbore  54  after the beta wave gravel placement step and the treatment process of production interval  58  is complete. It should be appreciated that the present invention is applicable not only to gravel placement processes, but also to other fluid treatments such as stimulations, fractures, acid treatments and the like. Following the completion process, sensors  80  of the present invention may continue to be employed to provide the downhole hardware necessary to monitor one or more physical qualities of the wellbore including production fluid properties. In this respect, the teachings presented herein are not limited to the completion phases of a wellbore, but are also applicable to other phases of a wellbore including production. For example, after the completion of wellbore, the sensors of the present invention provide real time measurements at a series of points along the production interval that allow information to be obtained as a function of position relative to the location or locations of hydrocarbon production, water encroachment, gas breakthrough and the like. 
   Referring now to  FIG. 8 , a composite coiled tubing  130  having energy conductors  132  and sensors  134  embedded therein is depicted. Composite coiled tubing  130  includes an inner fluid passageway  136  defined by an inner thermoplastic liner  138  that provides a body upon which to construct the composite coiled tubing  130  and that provides a relative smooth interior bore  140 . Fluid passageway  136  provides a conduit for transporting fluids such as the completion and production fluids discussed hereinabove. Layers of braided or filament wound material such as Kevlar or carbon encapsulated in a matrix material such as epoxy surround liner  138  forming a plurality of generally cylindrical layers, i.e., a composite structure, such as layers  142 ,  144 ,  146 ,  148 ,  150  of composite coiled tubing  130 . 
   The materials of composite coiled tubing  130  provide for high axial strength and stiffness while also exhibiting high pressure carrying capability and low bending stiffness. For spooling purposes, composite coiled tubing  130  is designed to bend about the axis of the minimum moment of inertia without exceeding the low strain allowable characteristic of uniaxial material, yet be sufficiently flexible to allow the assembly to be bent onto the spool. 
   Layer  148  has energy conductors  132  that may be employed for a variety of purposes. For example, energy conductors  132  may be power lines, control lines, communication lines or the like. Preferably, energy conductors  132  may be optical fiber strands wound within layer  148 . Sensors  134  are embedded within outer layer  150  and are coupled to one of the energy conductors  132 . Sensors  134  may provide data relative to viscosity, temperature, pressure, velocity, specific gravity, conductivity, fluid composition, or the like. For example, sensors  134  may be fiber optic pressure sensor that measure the pressure in the region surrounding composite coiled tubing  130 . Alternatively, sensors  134  may be strain gage pressure sensors, or micro sensors such as a micro electrical sensors. As another example, sensors  134  may be electrodes operable to detect the presence of non-conducting oil or conducting water. Additionally, it should be appreciated that a variety of types of sensors may be employed to collect data about a fluid surrounding composite coiled tubing  130 . Moreover, it will be appreciated that the selection of sensors will be dependant upon the desired attributes to be monitored within the well. 
   Although a specific number of energy conductors  132  and sensors  134  are illustrated, it should be understood by one skilled in the art that more or less energy conductors  132  or sensors  134  than illustrated are in accordance with the teachings of the present invention. Moreover, it should be appreciated that sensors  134  may alternatively be embedded within interior bore  140  or within both interior bore  140  and outer layer  150 . 
   The design of composite coiled tubing  130  provides for fluid to be conveyed in fluid passageway  136  and energy conductors  132  and sensors  134  to be positioned in the matrix about fluid passageway  136 . It should be understood by those skilled in the art that while a specific composite coiled tubing is illustrated and described herein, other composite coiled tubings having a fluid passageway and one or more energy conductors could alternatively be used and are considered within the scope of the present intention. 
   For example, with reference to  FIG. 9 , an alternate embodiment of a composite coiled tubing  160  having energy conductors  162  and sensors  164  embedded therein in accordance with the teachings of the present invention is illustrated. Layers  166 ,  168  of braided or filament wound material encapsulated in a matrix material form a composite structure. Contrary to composite coiled tubing  130  of  FIG. 7 , composite coiled tubing  160  does not include a conduit for transporting fluids. Similar to composite coiled tubing  130  of  FIG. 7 , a plurality of energy conductors  162 , which may take the form of optical fibers, are embedded in the matrix to relay data between sensors  164  and the surface. It should be appreciated that the composite coil tubing presented in  FIGS. 7 and 8  are not limited to tubular goods or tubings having circular cross-sections. The teachings of the present invention are applicable to composite coiled tubings having non-circular cross-sections such as rectangular or irregular cross-sections. 
     FIG. 10  is a half sectional view depicting the operation of an alternate embodiment of an apparatus  180  for gravel packing a horizontal open hole production interval  182  of a wellbore  184  of the present invention during a treatment operation. Casing  186  is cemented within a portion of wellbore  184 . Work string  188  includes a sand control screen assembly  190  that extends into open hole production interval  182  of wellbore  184 . Packer assembly  196  is positioned between work string  188  and casing  186  at a cross-over assembly  198 . Disposed within work string  188  and extending from cross-over assembly  198  is a wash pipe assembly  200 . 
   Sand control screen assembly  190  includes base pipe  202  which comprises composite coiled tubing  204  that includes energy conductors  206  integrally positioned therein. A series of sensors  208  embedded on the outer surface of base pipe  202  are coupled to energy conductors  206  to monitor fluid properties within an annulus  210  formed between base pipe  202  and wellbore  184 . Preferably, sensors  208  are embedded on base pipe  202  inside of screen wire  212 . As illustrated, during an alpha-beta gravel packing operation, sensors  208  positioned on the exterior of base pipe  202  monitor fluid properties and the wellbore environment within annulus  210  to determine any number of a variety of wellbore properties including fluid viscosity, temperature, pressure, fluid velocity, fluid specific gravity, fluid conductivity and fluid composition. The measured data is relayed to a downhole processor or to the surface in substantially real time via energy conductors  206 . Energy conductors  206  may extend to the surface embedded within work string  188  which may be formed entirely as a composite coiled tubing. Alternatively, energy conductors  206  may form a bundle that extends to the surface within the annulus between work string  188  and casing  186 . 
     FIG. 11  is another embodiment of an apparatus  220  for gravel packing a horizontal open hole production interval  222  of a wellbore  224  of the present invention during a treatment operation. Similar to  FIG. 10 , the production interval of  FIG. 11  includes a casing  226 , a work string  228 , sand control screen assembly  230 , a packer assembly  236 , a cross-over assembly  238  and a wash pipe  240 . Base pipe  242  of sand control screen assembly  230  comprises composite coiled tubing  244  that includes energy conductors  246  integrally positioned therein. A series of sensors  248  embedded within the interior surface of base pipe  242  are coupled to energy conductors  246  to monitor wellbore properties within the annulus  250  formed between base pipe  242  and wash pipe  240 . 
   Referring flow to  FIG. 12 , an apparatus  260  for monitoring fluid properties within a production interval  262  is depicted. A wellbore  264  includes casing  266  which is cemented therewith. A work string  268  extends through casing  266  and into production interval  262 . An outer tubular  270  is positioned within work string  268  and a packer assembly  272  provides a seal therebetween. An inner tubular  274  is positioned within outer tubular  270 . In operation, tubular  270  provides carrier fluid and a tubular  274  provides sand, gravel or proppants into a downhole mixer which provides a mixing area  276  wherein the carrier fluid and the solids mix to form fluid slurry  278 . Fluid slurry  278 , in turn, is delivered to production interval  262  via a cross-over assembly  260  as indicated by arrows  282 . 
   As previously discussed, a wash pipe  284  positioned within sand control screen assembly  286  includes sensors  288  to monitor data relative to fluid slurry  278  and the wellbore environment in production interval  262  and to relay this data preferably to a downhole process the controls valving or other control equipment associated with tubulars  270 ,  274  so that the characteristics of fluid slurry  278  may be adjusted by, for example, regulating the relative volume of carrier fluid to solids or the over all rate of component delivery to mixing area  276  from tubular  270  and tubular  274 , thereby regulating the characteristics of fluid slurry  278  in substantially real time. In particular, this embodiment allows for rapid changes in fluid slurry characteristics as the fluid slurry composition is mixed close to its delivery point as opposed to at the surface, thereby further enhancing the benefits of the present invention. It should be appreciated that the exemplary mixing embodiment presented herein may be employed with any of the apparatuses for monitoring fluid properties presented hereinabove. 
     FIG. 13  is a further embodiment of an apparatus  300  for monitoring fluid properties in a horizontal open hole production interval  302  of a wellbore  304  of the present invention. Casing  306  is cemented within a portion of wellbore  304 . Production tubing string  308  includes sand control screen assembly  310  and packer assembly  312  that provides a seal between production tubing string  308  and casing  306 . 
   A tubular  314  extending from the surface is formed from composite coiled tubing  316  and is positioned within production tubing string  308 . Energy conductors  318  are integrally positioned within composite coiled tubing  316 . Preferably, composite coiled tubing  316  includes a relatively small diameter so that composite coiled tubing  316  does not interfere with the production of the well. A series of sensors  320  embedded within composite coiled tubing  316  are coupled to energy conductors  318  which are spaced at predetermined intervals along the exterior of composite coiled tubing  316  to monitor fluid properties within the production tubing string  308  to develop production profiles including hydrocarbon production, water encroachment, gas breakthrough and the like. It should be appreciated from the foregoing exemplary embodiments that the sensors of the present invention may be positioned in a variety of places such as within the interior or exterior of a base pipe, within the interior or exterior of a wash pipe or within the interior or exterior of a tubular positioned within a production tubing string. Moreover, it should be appreciated that the sensors may be employed in a combination of the aforementioned places. 
   Accordingly, the present invention provides an apparatus and method for gravel packing long production intervals that are inclined, deviated or horizontal. In particular, the systems and methods of the present invention are useful in extremely long wellbores where substantially real time data about fluid properties is essential to achieve an effective treatment. Hence, the present invention enables fluid properties at a plurality of locations within a production interval of a wellbore to be monitored in substantially real time, thereby providing for the enhanced regulation of treatment processes and fluid production. 
   While this invention has been described with reference to illustrative embodiments, this description is not intended to be construed in a limiting sense. Various modifications and combinations of the illustrative embodiments as well as other embodiments of the invention, will be apparent to persons skilled in the art upon reference to the description. It is, therefore, intended that the appended claims encompass any such modifications or embodiments.

Summary:
An apparatus ( 50 ) for monitoring a treatment process in a treatment interval ( 58 ) includes a packer assembly ( 60 ) and a sand control screen assembly ( 64 ) connected relative to the packer assembly ( 60 ). A cross-over assembly ( 62 ) provides lateral communication paths ( 92, 98 ) downhole and uphole of the packer assembly for respectively delivering of a treatment fluid ( 84 ) and taking return fluid. A wash pipe assembly ( 76 ) is positioned in communication with the lateral communication path ( 98 ) uphole of the packer assembly ( 60 ) and extending into the interior of the sand control screen assembly ( 64 ). At least one sensor ( 80 ) is operably associated with the wash pipe assembly ( 76 ) to collect data relative to at least one property of the treatment fluid during a treatment process such that a characteristic of the treatment fluid ( 84 ) is regulatable during the treatment process based upon the data.