# US 2009/0260807 A1 · Selective zonal testing using a coiled tubing deployed submersible pump > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 2009/0260807 A1 - Document ID: US20090260807A1 - Status: Published application - Kind: A1 - Application number: 12/105,391 - Filed: 2008-04-18 - Published: 2009-10-22 - Earliest claimed: 2008-04-18 - Assignees: Schlumberger Technology Corporation - Inventors: Hisham Abou El Azm; Agha Hassan Akram - Web page: https://patentgrep.com/patent/US20090260807A1 ## CPC - E21B 43/128: {Adaptation of pump systems with down-hole electric drives} - E21B 19/22: Handling reeled pipe or rod units, e.g. flexible drilling pipes {(lifting or hauling appliances using two or more cooperating endless chains B66D3/003)} - E21B 49/08: Obtaining fluid samples or testing fluids, in boreholes or wells - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS ## 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. ## Claims ### Claim 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. ### Claim 2 (depends on 1) An apparatus as in claim 1, further comprising surface well testing equipment capable of measuring flow rate data. ### Claim 3 (depends on 1) 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. ### Claim 4 (depends on 1) 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. ### Claim 5 (depends on 1) 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. ### Claim 6 (depends on 1) An apparatus as in claim 1, wherein said submersible pump is powered by a cable lowered from surface with the coiled tubing. ### Claim 7 (depends on 6) An apparatus as in claim 6, wherein said submersible pump cable is clamped to the outside of the coiled tubing and along its length. ### Claim 8 (depends on 7) An apparatus as in claim 7, wherein said cable is clamped to the coiled tubing as the coiled tubing is lowered into a wellbore. ### Claim 9 (depends on 7) 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. ### Claim 10 (depends on 6) 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. ### Claim 11 (depends on 1) An apparatus as in claim 1, wherein the packer is located below the submersible pump. ### Claim 12 (depends on 1) An apparatus as in claim 1, wherein the packer is a straddle type packer. ### Claim 13 (depends on 12) 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. ### Claim 14 (depends on 12) An apparatus as in claim 12, wherein the straddle packer has a perforated or slotted pup joint in between said straddle packer. ### Claim 15 (depends on 1) 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. ### Claim 16 (depends on 1, 12) An apparatus as in claim 1 or 12, wherein the packer is replaced by a swab cup assembly. ### Claim 17 (depends on 1) An apparatus as in claim 1, wherein at least one pressure sensor is located inside the joint below the packer. ### Claim 18 (depends on 1) An apparatus as in claim 1, wherein at least one flow sensor is located inside the join below the packer. ### Claim 19 (depends on 1) An apparatus as in claim 1, wherein at least one Gas-Oil Ratio sensor is located inside the join below the packer. ### Claim 20 (depends on 1) An apparatus as in claim 1, wherein at least one temperature sensor is located inside the join below the packer. ### Claim 21 (depends on 1) 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. ### Claim 22 (depends on 1) 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. ### Claim 23 (depends on 1) 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. ### Claim 24 (depends on 1) 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. ### Claim 25 (depends on 1) An apparatus as in claim 1, where in at least one pressure and temperature sensor is located in the submersible pump. ### Claim 26 (depends on 1) An apparatus as in claim 1, wherein a safety valve is located above the submersible pump. ### Claim 27 (depends on 1) An apparatus as in claim 1, wherein an emergency release sub is located above the submersible pump. ### Claim 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. ### Claim 29 (depends on 28) 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). ### Claim 30 (depends on 28) 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).