Cable injector for deploying artificial lift system

Abstract

An injector for deploying a cable into a wellbore includes a traction assembly having at least a stationary segment and a movable segment. Each segment includes: a drive sprocket; an idler sprocket; a track looped around and between the sprockets; a set of grippers fastened to and disposed along the respective track, and a frame. The frame: is connected to the stationary segment, has a coupling for connection to a pressure control assembly (PCA), and has a passage for receiving the cable. The injector further includes a motor torsionally connected to the drive sprocket of the stationary segment.

1 . An injector for deploying a cable into a wellbore, comprising:
 a traction assembly comprising at least a stationary segment and a movable segment, each segment comprising:
 a drive sprocket; 
 an idler sprocket; 
 a track looped around and between the sprockets; 
 a set of grippers fastened to and disposed along the respective track, 
   a frame:
 connected to the stationary segment, 
 having a coupling for connection to a pressure control assembly (PCA), and 
 having a passage for receiving the cable; and 
   a motor torsionally connected to the drive sprocket of the stationary segment.   
     
     
         2 . The injector of  claim 1 , wherein each gripper has an opening for receiving a cog of the respective sprockets. 
     
     
         3 . The injector of  claim 2 , wherein each track is a belt having a passage adjacent each gripper for passing the cog. 
     
     
         4 . The injector of  claim 1 , wherein each gripper:
 is made from a metal, alloy, or cermet,   has a recess formed therein for receiving the cable, and   has teeth formed in the recess.   
     
     
         5 . The injector of  claim 4 , wherein each gripper has wings extending transversely from the recess. 
     
     
         6 . The injector of  claim 1 , wherein the movable segment is pivoted to the stationary segment for swinging between an open position for receiving the cable and a closed position for deploying the cable. 
     
     
         7 . The injector of  claim 6 , wherein:
 each segment further comprises a gear torsionally connected to the respective drive sprocket, and   the gears mesh upon closing of the movable segment.   
     
     
         8 . The injector of  claim 6 , wherein each segment further comprises a body having a hinge knuckle formed at each inner end thereof. 
     
     
         9 . The injector of  claim 1 , wherein each segment further comprises:
 a tensioner operable to tighten the respective track, and   a counter bearing for supporting the tightened track.   
     
     
         10 . The injector of  claim 1 , wherein the traction assembly further comprises a second movable segment. 
     
     
         11 . The injector of  claim 1 , further comprising a linear actuator operable to move the movable segment toward and away from the stationary segment. 
     
     
         12 . A launch and recovery system (LARS), comprising:
 the injector of  claim 1 ;   a winch having the cable;   a boom for guiding the cable into the PCA;   the PCA for connection to a production tree; and   a downhole assembly of an artificial lift system for deployment into the wellbore using the cable.   
     
     
         13 . The LARS of  claim 12 , further comprising a stuffing box having a coupling for connection to the PCA and a coupling for connection to the injector. 
     
     
         14 . The LARS of  claim 13 , further comprising a seal head having the stuffing box and a grease injector. 
     
     
         15 . The LARS of  claim 14 , further comprising a lubricator having the seal head and a tool housing. 
     
     
         16 . A method of deploying a downhole tool into a wellbore, comprising:
 connecting the downhole tool to a cable;   lowering the downhole tool into a pressure control assembly (PCA) and wellhead adjacent to the wellbore using the cable;   after lowering the downhole tool, connecting a cable injector to the PCA and closing the cable injector around the cable; and   operating the cable injector, thereby injecting the cable into the wellbore and lowering the downhole tool to a deployment depth in the wellbore.   
     
     
         17 . The method of  claim 16 , wherein the downhole tool is lowered by:
 assembling the PCA onto a production tree connected to the wellhead;   inserting a first deployment section of the downhole tool into a lubricator;   landing the lubricator onto the PCA;   connecting the lubricator to the PCA;   lowering the first deployment section into the PCA;   engaging a clamp of the PCA with the first deployment section;   after engaging the clamp, isolating an upper portion of the PCA from a lower portion of the PCA by engaging a seal of the PCA with the first deployment section; and   after isolating the PCA, removing the lubricator from the PCA.   
     
     
         18 . The method of  claim 16 ,
 further comprising connecting a stuffing box to the PCA,   wherein the cable injector is connected to the PCA by being connected to the stuffing box.   
     
     
         19 . The method of  claim 18 , further comprising:
 engaging a mold with an outer surface of the cable;   injecting sealant into the mold and into armor of the cable, thereby sealing a portion of the cable;   engaging a seal of the stuffing box with the sealed portion of the cable; and   operating the downhole tool using the cable.   
     
     
         20 . The method of  claim 18 , wherein:
 the stuffing box is part of a seal head having a grease injector, and   the method further comprises:
 engaging the seal head with the cable; and 
 operating the downhole tool using the cable. 
   
     
     
         21 . The method of  claim 16 , wherein:
 the downhole tool is an electrical submersible pump (ESP), and   the method further comprises operating the ESP to pump production fluid from the wellbore.   
     
     
         22 . The method of  claim 21 , wherein the ESP is operated by receiving a power signal from the cable. 
     
     
         23 . The method of  claim 21 , wherein:
 the ESP lands into a dock of production tubing at the deployment depth, and   the ESP is operated by receiving a power signal from the dock.   
     
     
         24 . The method of  claim 23 , wherein:
 the PCA is mounted on a production tree connected to the wellhead,   the method further comprises:
 disconnecting the cable from the ESP; 
 retrieving the cable from the wellbore; and 
 removing the PCA and cable injector from the production tree. 
   
     
     
         25 . The method of  claim 16 , wherein the cable is coaxial wireline.