# US 2014/0151052 A1 · Kobe sub with inflow control, wellbore tubing string and method > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 2014/0151052 A1 - Document ID: US20140151052A1 - Status: Published application - Kind: A1 - Application number: 13/883,218 - Filed: 2012-06-20 - Published: 2014-06-05 - Earliest claimed: 2011-06-20 - Assignees: Packers Plus Energy Services Inc. - Inventors: Daniel Jon Themig; Robert Joe Coon - Web page: https://patentgrep.com/patent/US20140151052A1 ## CPC - E21B 34/063: {Valve or closure with destructible element, e.g. frangible disc (E21B34/103 takes precedence)} - E21B 17/18: Pipes provided with plural fluid passages {(E21B17/203 takes precedence)} - E21B 29/00: Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground - E21B 34/14: operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools {(E21B34/066 takes precedence)} - E21B 43/2605: {using gas or liquefied gas} - E21B 43/27: by use of eroding chemicals, e.g. acids - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS ## Abstract A kobe sub includes a kobe installed in a port of the sub, the kobe includes a cap portion accessible in the inner bore, a base mounted in the port and connected to the cap portion, a channel extending through the base and closed by the cap portion; and an inflow controller positioned to control fluid flowing through the channel toward the inner bore when the cap portion is opened; and a port opening tool for opening the cap portion. The kobe may be employed with a frac port. ## Claims ### Claim 1 A kobe sub comprising: a tubular body connectable into a wellbore tubing string, the tubular body including a wall including an outer surface and an inner surface defining an inner bore and a port through the wall; a kobe installed in the port with a cap portion accessible in the inner bore, a base mounted in the port and connected to the cap portion, a channel extending through the base and closed by the cap portion; and an inflow controller positioned to control fluid flowing through the channel toward the inner bore when the cap portion is opened. ### Claim 2 (depends on 1) The kobe sub of claim 1 wherein the inflow controller is selected to filter oversize solids from the fluid flowing. ### Claim 3 (depends on 1) The kobe sub of claim 1 wherein the inflow controller is selected to control flow characteristics of the fluid flowing. ### Claim 4 (depends on 1) The kobe sub of claim 1 wherein the inflow controller is positioned in the channel. ### Claim 5 (depends on 1) The kobe sub of claim 1 wherein the inflow controller is a part of the channel. ### Claim 6 (depends on 1) The kobe sub of claim 1 further comprising a tool sized to move through the inner bore to contact and open the cap portion. ### Claim 7 (depends on 6) The kobe sub of claim 6 wherein the tool is a cutter sleeve installed in the inner bore. ### Claim 8 (depends on 1) The kobe sub of claim 1 further comprising an injection port through the wall and a closure for the injection port moveable between a closed position closing the injection port and an open position retracted from the injection port. ### Claim 9 A tubing string system for installation in a wellbore comprising: a tubular body including a tubular wall with an outer surface and an inner surface defining an inner bore and a port through the tubular wall; a kobe installed in the port with a cap portion accessible in the inner bore, a base mounted in the port and connected to the cap portion, a channel extending through the base and closed by the cap portion; and an inflow controller positioned to control fluid flowing through the channel toward the inner bore when the cap portion is opened; and a port opening tool for opening the cap portion. ### Claim 10 (depends on 9) The tubing string system of claim 9 wherein the inflow controller is selected to filter oversize solids from the fluid flowing. ### Claim 11 (depends on 9) The tubing string system of claim 9 wherein the inflow controller is selected to control flow characteristics of the fluid flowing. ### Claim 12 (depends on 9) The tubing string system of claim 9 wherein the inflow controller is positioned in the channel. ### Claim 13 (depends on 9) The tubing string system of claim 9 wherein the inflow controller is a part of the channel. ### Claim 14 (depends on 9) The tubing string system of claim 9 wherein the port opening tool is a cutter sleeve installed in the inner bore. ### Claim 15 (depends on 9) The tubing string system of claim 9 further comprising an injection port through the wall and a closure for the injection port moveable between a closed position closing the injection port and an open position retracted from the injection port. ### Claim 16 (depends on 15) The tubing string system of claim 15 wherein the closure is moveable to the open position without also opening the cap portion. ### Claim 17 (depends on 9) The tubing string system of claim 9 further comprising a first packer positioned uphole from the port and a second packer positioned downhole from the port. ### Claim 18 (depends on 9) The tubing string system of claim 9 further comprising a second stage of the tubing string positioned uphole from the first packer and including a second port through the tubular wall; a second kobe installed in the second port with a second cap portion accessible in the inner bore, a second base mounted in the second port and connected to the second cap portion, a second channel extending through the second base and closed by the second cap portion; and a second inflow controller positioned to control fluid flowing through the second channel toward the inner bore when the second cap portion is opened. ### Claim 19 (depends on 18) The tubing string system of claim 18 further comprising in the second stage: a second injection port through the wall and a second closure for the second injection port moveable between a closed position closing the injection port and an open position retracted from the injection port. ### Claim 20 A method for forming a fluid channel through a tubing string wall, the method comprising: installing a tubing string in a wellbore, the tubing string including a tubular wall including an outer surface and an inner surface defining an open inner bore and a port through the wall; a kobe installed in the port with a cap portion accessible in the inner bore, a base mounted in the port and connected to the cap portion, a channel extending through the base and closed by the cap portion; and an inflow controller positioned to control fluid flowing through the channel toward the inner bore when the cap portion is opened; manipulating a port opening tool in the inner bore to open the cap portion and to allow fluid flow through the inflow controller and the channel into the inner bore. ### Claim 21 (depends on 20) The method of claim 20 wherein manipulating includes running a mill through the inner bore. ### Claim 22 (depends on 20) The method of claim 20 wherein manipulating includes running a cutter sleeve through the inner bore. ### Claim 23 (depends on 20) The method of claim 20 wherein manipulating includes running a sleeve shifting tool through the inner bore. ### Claim 24 (depends on 20) The method of claim 20 wherein manipulating also closes an injection port in the tubing string. ### Claim 25 (depends on 20) The method of claim 20 further comprising opening an injection port in the tubing string and injecting wellbore treatment fluid therethrough to treat the formation. ### Claim 26 (depends on 20) The method of claim 20 further comprising pressuring up the string before the manipulating the port opening tool. ### Claim 27 A method for fluid treatment of a borehole, the method comprising: running a tubing string into a wellbore to a desired position for treating the wellbore; opening a frac port by application of a force to a closure for the frac port; injecting stimulating fluids through the frac port; closing the frac port; opening a fluid inflow control port by opening an inner cap over the fluid inflow control port; and permitting fluid to pass from the wellbore into the tool through the fluid inflow control port. ### Claim 28 (depends on 27) The method of claim 27 wherein opening a fluid inflow control port includes running a mill through the inner bore. ### Claim 29 (depends on 27) The method of claim 27 wherein opening a fluid inflow control port includes running a cutter sleeve through the inner bore. ### Claim 30 (depends on 27) The method of claim 27 wherein opening a fluid inflow control port includes running a sleeve shifting tool through the inner bore. ### Claim 31 (depends on 27) The method of claim 27 wherein opening a fluid inflow control port also closes an injection port in the tubing string. ### Claim 32 (depends on 27) The method of claim 27 further comprising pressuring up the string before opening the frac port.