Selective zonal testing using a coiled tubing deployed submersible pump

Abstract

An apparatus for measuring a property of a formation comprising a coiled tubing unit having one or more downhole sensors capable of being lowered into a wellbore, a submersible pump capable of being lowered into a wellbore by the coiled tubing unit, means to power the submersible pump, and a packer lowered into the wellbore by the coiled tubing unit to isolate a formation. A method of servicing a hydrocarbon well using one or more sensors, one or more packers, and a submersible pump, all lowered on coiled tubing into a well that penetrates a predetermined formation; and using surface well testing equipment, determining a property of a formation while flowing the well assisted by the submersible pump and using flow data measured using the surface well testing equipment integrated with pressure data measured using the one or more sensors lowered into the well penetrating the formation on the coiled tubing; treating the formation by pumping fluid into the formation using the coiled tubing; and repeating the determining a property of the formation while flowing the well as described above, wherein the coiled tubing remains deployed within the well throughout the determining, treating, and repeating the determining processes.

1 . An apparatus for measuring a property of a formation comprising:
 i. a coiled tubing unit having one or more downhole sensors capable of being lowered into a wellbore;   ii. a submersible pump capable of being lowered into a wellbore by said coiled tubing unit;   iii. means to power the submersible pump; and,   iv. a packer lowered into said wellbore by said coiled tubing unit to isolate a formation.   
   
   
       2 . An apparatus as in  claim 1 , further comprising surface well testing equipment capable of measuring flow rate data. 
   
   
       3 . An apparatus as in  claim 1 , further comprising means for transmitting said sensors measurements to a server capable of collecting, storing, and retransmitting the measured data. 
   
   
       4 . An apparatus as in  claim 1 , further comprising means for transmitting the measurements to a processing unit capable of calculating the properties of the formation. 
   
   
       5 . An apparatus as in  claim 1 , wherein said sensors are sensors from the group comprising pressure, temperature, flow, spectroscopy, viscosity, H2S, CO2, bubble count, dielectric, venturi, gas/oil ratio, water/gas ratio, water/oil ratio and gamma. 
   
   
       6 . An apparatus as in  claim 1 , wherein said submersible pump is powered by a cable lowered from surface with the coiled tubing. 
   
   
       7 . An apparatus as in  claim 6 , wherein said submersible pump cable is clamped to the outside of the coiled tubing and along its length. 
   
   
       8 . An apparatus as in  claim 7 , wherein said cable is clamped to the coiled tubing as the coiled tubing is lowered into a wellbore. 
   
   
       9 . An apparatus as in  claim 7 , wherein said cable is clamped to the coiled tubing through a work window device designed to be deployed together with the coiled tubing surface pressure control equipment that allows access to both the coiled tubing and the submersible pump cable; said work window can be closed to preserve pressure integrity of the surface pressure control system when desired. 
   
   
       10 . An apparatus as in  claim 6 , wherein the submersible pump cable is deployed through a stuffing box to preserve pressure integrity of the surface pressure control system. 
   
   
       11 . An apparatus as in  claim 1 , wherein the packer is located below the submersible pump. 
   
   
       12 . An apparatus as in  claim 1 , wherein the packer is a straddle type packer. 
   
   
       13 . An apparatus as in  claim 12 , wherein the straddle packer has a pup joint in between said straddle packer that allows fluid from the outside to enter said pup joint. 
   
   
       14 . An apparatus as in  claim 12 , wherein the straddle packer has a perforated or slotted pup joint in between said straddle packer. 
   
   
       15 . An apparatus as in  claim 1 , further comprising a pup joint that allows fluid from the outside to enter said pup joint and a swab cup assembly below said pup joint. 
   
   
       16 . An apparatus as in  claim 1  or  12 , wherein the packer is replaced by a swab cup assembly. 
   
   
       17 . An apparatus as in  claim 1 , wherein at least one pressure sensor is located inside the joint below the packer. 
   
   
       18 . An apparatus as in  claim 1 , wherein at least one flow sensor is located inside the join below the packer. 
   
   
       19 . An apparatus as in  claim 1 , wherein at least one Gas-Oil Ratio sensor is located inside the join below the packer. 
   
   
       20 . An apparatus as in  claim 1 , wherein at least one temperature sensor is located inside the join below the packer. 
   
   
       21 . An apparatus as in  claim 1 , wherein at least one pressure sensor is located inside the joint above the pup joint in between the straddle packer that allows fluid to enter. 
   
   
       22 . An apparatus as in  claim 1 , wherein at least one flow sensor is located inside the join above the pup joint in between the straddle packer that allows fluid to enter. 
   
   
       23 . An apparatus as in  claim 1 , wherein at least one Gas-Oil Ratio sensor is located inside the joint above the pup joint in between the straddle packer that allows fluid to enter. 
   
   
       24 . An apparatus as in  claim 1 , wherein at least one temperature sensor is located inside the joint above the pup joint in between the straddle packer that allows fluid to enter. 
   
   
       25 . An apparatus as in  claim 1 , where in at least one pressure and temperature sensor is located in the submersible pump. 
   
   
       26 . An apparatus as in  claim 1 , wherein a safety valve is located above the submersible pump. 
   
   
       27 . An apparatus as in  claim 1 , wherein an emergency release sub is located above the submersible pump. 
   
   
       28 . A method of servicing a hydrocarbon well using one or more sensors, one or more packers, and a submersible pump, all lowered on coiled tubing into a well that penetrates a formation; and surface well testing equipment, comprising:
 i. determining a property of a formation while flowing the well assisted by said submersible pump and using flow data measured using said surface well testing equipment integrated with pressure data measured using said one or more sensors lowered into said well penetrating said formation on said coiled tubing;   ii. treating said formation by pumping fluid into said formation using said coiled tubing; and   iii. repeating said determining a property of a formation while flowing the well assisted by said submersible pump and using flow data measured using said surface well testing equipment integrated with pressure data measured using said one or more sensors lowered into said well penetrating said formation on said coiled tubing; wherein said coiled tubing remains deployed within said well throughout said determining, treating, and repeating said determining processes.   
   
   
       29 . A method of servicing a hydrocarbon well in accordance with  claim 28 , wherein said property of said formation determined in process i) is included within a report that is created prior to process ii). 
   
   
       30 . A method of servicing a hydrocarbon well in accordance with  claim 28 , wherein one or more process parameters in said treatment process ii) is determined based on said property of said formation determined in process i).