Patent Abstract:
The present invention includes a communications system to measure and transmit date from a zone of interest below a downhole assembly to a remote location. The communications system preferably includes a sensor gauge engaged through a communications port of the downhole assembly upon a communications cable whereby the communications cable and sensor gauge have substantially the same outer profile diameter.

Full Description:
BACKGROUND OF THE INVENTION  
       [0001]     The present invention generally relates to a downhole gauge package integrated into a delivery and communications cable. More particularly, the present invention relates to a downhole gauge package integrated into a communications cable requiring no assembly and having a single uniform outer diameter.  
         [0002]     Downhole sensor gauges are used throughout the petroleum drilling and recovery industry to measure and report various downhole conditions. Gauges that record and measure temperature, pressure, and other types of information are deployed to a location of interest downhole for either long or short-term emplacement. Particularly, one form of long-term emplacement involves the installation of a gauge below a packer to report a condition below the packer back to a remote location. Packers are frequently installed in petroleum industry wellbores to isolate one zone or region from another, adjacent zone or region. Particularly, packers can be used in petroleum production to isolate the annulus between a string of production tubing and a cased borehole to prevent the unwanted escape of production fluids.  
         [0003]     Packers typically perform their functions by expanding an elastomeric packer element to fill any gaps between the production tube and the cased borehole. The packer element can be expanded by “inflating” the element with pressurized fluid or by activating the flexible element by axially compressing it between two pistons. Irrespective of construction or the deployment method used, the packer effectively creates a fluid seal between the production tubing and the remainder of the borehole.  
         [0004]     However, while a production zone is isolated by a packer, downhole condition measurements are still necessary to determine the status of the isolated zone. While gauges (e.g. temperature sensors and pressure transducers) can be deployed to the production zone through the bore of production tubing running through the packer, it is not preferred. Sensors that run through the production tubing bore can restrict the flow of production fluids or can interfere with the operation of production equipment located at the distal end of the production tubing. Furthermore, various pieces of equipment, for example downhole safety valves, require an unobstructed bore to be effective or to be in compliance with regulations.  
         [0005]     To accommodate sensor gauges, packer designs have formerly been produced that allow a conduit to pass through the production tubing-casing annulus and bypass the packer element. These former designs typically involve a port through the body of the packer through which a constant diameter communications conduit can pass. Seals inside the port seal with the outer profile of the communications conduit and therefore prevent fluids from escaping from or invading into the production zone. Because of the design of the seals, the communications conduit has to be of a substantially consistent outer profile. Irregularities in the outer profile of the communications conduit can prevent a proper seal with the packer, thereby compromising the packer&#39;s function to isolate upper and lower borehole zones.  
         [0006]     Former downhole gauge systems required the passage of the conduit through the port of the packer assembly followed by the attachment and connection of the gauge device to the distal end of the communications conduit once the packer was traversed. This was necessary because either the gauge assembly or the connection means between the conduit and the gauge typically had an outer profile that was larger than the communications conduit itself. The larger profiled gauge or connection means was unable to pass through the communications port designed to hydraulically seal against the smaller, more consistent communications conduit. Therefore, the communications conduit and the gauge assembly were typically delivered to the field location separately. Any functional checks that needed to be made on the gauge had to be performed prior to its final mating with the communications conduit and at the field location. As a result there was no way to test the integrity of the final conduit/gauge communications interface until after the gauge was installed below the packer, when a repair or replacement operation would be very costly.  
       SUMMARY OF THE INVENTION  
       [0007]     The invention comprises a sensor gauge assembly to measure and communicate conditions from a downhole zone to a remote location through a downhole assembly. The sensor gauge may include a main body having an outer profile, a sensor package, and a connection to the communications conduit. The communications conduit may include a second outer profile and is configured to transmit communications data from the sensor package to the remote location. The connection to the communications conduit may include a third outer profile and the first, second, and third outer profiles are substantially the same.  
         [0008]     The invention also comprises a sensor gauge assembly to measure and communicate conditions from a downhole zone to a remote location through a downhole assembly. The sensor gauge assembly may include a main body having a first outer diameter, a sensor package, and a connection to the communications conduit. The communications conduit may include a second outer diameter and is configured to transmit communications data from the sensor package to the remote location. The connection to the communications conduit has a third outer diameter and the first and third outer diameters are smaller than the second diameter.  
         [0009]     The invention also comprises a communications system to measure and transmit data from a zone of interest below a packer to a surface location. The communications system preferably includes a communications conduit extending from the remote location to the zone of interest through a communications port of the packer. Preferably, a lower portion of the communications conduit has a substantially consistent outer gauge diameter wherein the lower portion is configured to be sealingly engages with the communications port. The communications system preferably includes a sensor gauge connected to a distal end of the communications conduit by a seamless connection wherein the seamless connection and the sensor gauge preferably have concentric outer diameters equal to the outer gauge diameter.  
         [0010]     The invention also comprises a method to communicate with a zone of interest below a downhole assembly. The method preferably includes deploying a sensor gauge upon a distal end of a communications conduit to the downhole assembly. The method preferably includes engaging the sensor gauge and the distal end of the communications conduit through a communications port of the downhole assembly. The method preferably includes engaging the communications conduit with hydraulic seals within the communications port to prevent leakage of fluids from the zone of interest. The method preferably includes suspending the sensor gauge below the downhole assembly wherein the sensor gauge is configured to measure conditions of the zone of interest. The method preferably includes communicating the conditions of the zone of interest from the sensor gauge to a remote location through the communications conduit. Preferably, the distal end of the communications conduit and the sensor gauge have a uniform and continuous outer diameter. 
     
    
     BRIEF DESCRIPTION OF THE DRAWINGS  
       [0011]      FIG. 1  is a schematic cross-sectional view of a sensor gauge assembly in accordance with an embodiment of the present invention.  
         [0012]      FIG. 2  is a schematic cross-sectional view of a sensor gauge assembly of  FIG. 1  engaged through a downhole packer assembly.  
         [0013]      FIG. 3  is a schematic cross-sectional view of the sensor gauge assembly of  FIG. 1  installed in a testing station. 
     
    
     DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS  
       [0014]     Referring to  FIG. 1 , a sensor gauge  100  in accordance with the present invention is shown. Sensor gauge  100  is deployed at the end of a communications conduit  102  and includes a main body  104  and a stinger head  1   06 . Sensor gauge  100  may be any type of gauge used to measure wellbore parameters, such as temperature, pressure, flow, vibration, fluid differentiation, chemical properties, among others. Communications conduit  102  can be constructed as an armored cable assembly or can be any type or design of communications conduit known to one skilled in the art, including, but not limited to a hydraulic conduit, fiber-optic conduit, pneumatic conduit, electrical conduit, or the like.  
         [0015]     Stinger head  106  preferably includes a sensor port  108  and a stinger profile  110 . Main body  104  can include any electronics or signal processing devices (not shown) and is shown having a cavity  112  through which a communications conductor  114  extends from the rear of main body  104  into communications conduit  102 . A coil  116  of conductor wire  114  is preferably contained within cavity  112  to accommodate any displacement of or tension on conductor  114  relative to communications conduit  102 . In addition to sensor port  108 , stinger head  106  is shown having optional seal glands  118  to facilitate pressure testing of sensor gauge assembly  100  prior to deployment. Stinger profile  110  of stinger head  106  is preferably constructed to align and guide sensor gauge  100  through a clearance port in a packer or other downhole device. Sensor port  108  allows sensors contained within main body  104  to communicate with fluids coming into contact with stinger head  106 .  
         [0016]     Readings from sensor gauge assembly  100  through sensor port  108  are reported back either to electronics (not shown) in main body  104  or to a remote location at the end of communications conductor  114 . If main body  104  contains sensor electronics to process the signals read from sensor port  108 , conductor  114  can be used to transmit the processed signals from main body  104  to a remote location. For example, sensor electronics inside main body  104  can contain digital processors, so that communications conductor  114  extending from main body  104  to remote location through conduit  102  is a digital data path. While the term “conductor” is used, it is important that any communications mechanism, hydraulic, electrical, and optical, etc. may be employed for communications conductor  114  without departing from the spirit of the present invention.  
         [0017]     Main body  104  of sensor gauge assembly  100  is preferably connected to communications conduit  102  at  120  through a seamless welded connection. Once sensor gauge assembly  100  is welded (or similarly attached through brazing, soldering, etc.) to communications conduit  102 , the weld area  120  is ground down so that the transition between conduit  102  and main body  104  is geometrically insubstantial. As main body  104  is preferably constructed to have the same outer profile as that of communications conduit  102 , the connection therebetween at weld area  120  is preferably made with the same profile. Once welded, the communications conduit  102  and sensor gauge assembly  100  can have a single uniform outer profile from a remote location all the way to the main body  104 . Alternatively, to reduce costs, outer profile of communications conduit  102  can be uniform only along a length necessary to engage sensor gauge  100  through a piece of downhole equipment, for example, a packer.  
         [0018]     The primary benefit of having a uniform outer profile along communications conduit  102  through main body  104  of sensor gauge  100  is that simple, standard, off-the-shelf seal mechanisms can be used to isolate sensor gauge  100  and conduit  102  from a piece of downhole equipment. For example, in a packer, a simple o-ring seal is sufficient to ensure a tight seal between the packer and the sensor gauge assembly  100  or communications conduit  102  (such as an o-ring disposed on seal gland  118 ).  
         [0019]     Referring briefly to  FIG. 2 , a packer assembly  150  having a clearance bore  152  and a sensor gauge bore  154  therethrough is shown located in a cased wellbore  200 . Packer  150  functions to isolate a lower zone  202  from an upper zone  204  through the actuation of packer elements  156 , 158  and anchors  160 . With elements  156 ,  158  and anchors  160  actuated, any hydraulic communication between lower zone  202  and an upper zone (i.e.  204 ) or remote location must pass through bore  152 . A string of tubing (not shown) typically connects bore  152  to the surface, allowing zone  204  to be isolated completely. Such isolation prevents fluids flowing from production zones like lower zone  202  from being contaminated by fluids in upper zones  204 .  
         [0020]     Packer  150  also includes a sensor gauge bore  154  through which a sensor gauge assembly  100  at the distal end of a communications conduit  102  can pass. Because conduit  102  and main body  104  of assembly  100  are preferably constructed having a consistent outer diameter profile, o-ring seals (not visible) are all that are needed to seal sensor gauge assembly  100  with packer  150  to keep zones  202  and  204  isolated. While any size can be used for sensor gauge assembly, a standard 0.25 inch (6.35 mm) outside diameter geometry is preferred. The sensor assembly  100  is delivered to the downhole location at the distal end of communications conduit  102  and is “stripped” through port  154  of packer until a length  162  of conduit  102  and sensor assembly  100  protrudes below packer  150  into lower zone  202 . In this position, sensor port  108  of gauge assembly  100  is exposed to fluids in zone  202  and can report any information measured there back to a remote location.  
         [0021]     Referring briefly to  FIG. 3 , a test station assembly  180  for sensor gauge assembly  100  is shown. Sensor test station  180  is shown having a simple cylindrical test body  182 , a hydraulic port  184 , and a seal gland  186 . Elastomeric seals  188 , 190  help isolate communications conduit  102  and sensor gauge  100  from the atmosphere so that weld area interface  120  can be tested for hydraulic integrity. To perform the test, hydraulic pressure is applied to port  184  while sensor gauge  100  is plugged into a monitoring unit (not shown). As pressure to port  184  is increased, that pressure acts upon weld area  120  and the monitoring unit can detect any rupture or leak. Furthermore, if sensor gauge  100  includes a pressure gauge, a pressure cap  192  can be located upon the distal end of test body  182  so that pressure can be increased in a test volume  194  through a second hydraulic port  196 . Isolating the stinger head  110  of sensor gauge  100  allows different pressures to be applied to weld area  120  and sensor port  108  to test and certify sensor gauge  100  at a broad range of operating pressures.  
         [0022]     Formerly, sensor gauges were delivered to the rigsite in components and either assembled downhole or immediately before being run downhole. Using the former systems, the cable and sensor included a connector mechanism that was of considerably larger diameter than the cable and sensor assembly to be connected. Therefore, if a 0.25 inch (6.35 mm) conduit were connected to a 0.25 inch (6.35 mm) sensor gauge, the connection means would prevent the assembly from passing through a 0.25 inch (6.35 mm) port. Furthermore, as the connection between gauge and conduit was often made after the conduit was run down hole, there was no way to test the integrity of the connection prior to deployment. The assembly could be put together and tested prior to deployment, but was still disassembled prior to installation. Using the apparatuses and methods of the present invention, a communications conduit and attached sensor gauge can be stripped through a seal bore designed to accommodate 0.25 inch (6.35 mm) diameter conduits.  
         [0023]     Furthermore, the present invention enables a unitary communications conduit and sensor gauge manufacturable to a high degree of tolerance. Particularly, geometric dimensioning and tolerancing (GD&amp;T) standards for cylindricity (radial deviations along a cylindrical feature) as high as ±0.005 inches (±0.127 mm) are feasible. Additionally, using the apparatus and methods of the present invention, any deficiencies of the prior art are addressed and corrected. A cable/sensor assembly can be constructed and tested in a controlled environment and shipped to the rigsite ready to deploy on a large drum. Once at the rigsite, the integrity of the sensor/cable connection can be quickly and easily tested immediately prior to installation.  
         [0024]     Numerous embodiments and alternatives thereof have been disclosed. While the above disclosure includes the best mode belief in carrying out the invention as contemplated by the inventors, not all possible alternatives have been disclosed. For that reason, the scope and limitation of the present invention is not to be restricted to the above disclosure, but is instead to be defined and construed by the appended claims.

Technology Classification (CPC): 4