Wellbore injection system

Abstract

A device is provided for delivering and distributing injection fluids into a subsurface formation from a horizontal wellbore. The device includes one or more steam pups having an outer sleeve and an inner sliding sleeve in concentric relationship. One or more sets of nozzles are arranged on the outer sleeve. A means is provided for actuating movement of the inner sliding sleeve within the outer sleeve, to at least partially cover one or more sets of nozzles on the outer sleeve. A method is also provided for delivering injection fluids into a subsurface formation from a horizontal wellbore. First, one or more steam pups are introduced into the horizontal well, said steam pups having an outer sleeve and an inner sliding sleeve with one or more sets of nozzles arranged on the outer sleeve. Next the inner sliding sleeve is moved inside the outer sleeve to at least partially cover one or more sets of nozzles on the outer sleeve. Finally, injection fluid is injected through the steam pup nozzles into formation. A further method is provided that comprises introducing into a heel location of the wellbore a first and second pairs of flow control hangers and polished bore receptacles, connected to an intermediate casing and cemented in place. The first pair of flow control hanger and polished bore receptacle are connected to an injection/production liner and one or more steam pups are then connected to the second pair of flow control hanger and polished bore receptacle.

1 . A device for delivering and distributing injection fluids into a subsurface formation from a wellbore or for producing fluids from the subsurface formation into the wellbore, said device comprising:
 a. one or more steam pups removably located inside the wellbore, each steam pup comprising an outer sleeve and an inner sliding sleeve in concentric relationship;   b. one or more sets of nozzles arranged on the outer sleeve of the steam pup through which injection fluids or production fluids are transferred into or out of the subsurface formation; and   c. means for actuating movement of the inner sliding sleeve within the outer sleeve;   
       wherein movement of the inner sliding sleeve within the outer sleeve acts to at least partially cover one or more sets of nozzles on the outer sleeve, thereby controlling fluid flow into or out of the subsurface formation. 
     
     
         2 . The device of  claim 1  wherein one or more steam pups are joined by lengths of blank casing to form a steam pup string. 
     
     
         3 . The device of  claim 1 , wherein the one or more steam pups are removably connected to an injection/production liner which interfaces with the subsurface formation. 
     
     
         4 . The device of  claim 3 , wherein the injection/production liner is selected from the group consisting of wire-wraps, slotted liners and meshrite. 
     
     
         5 . The device of  claim 3 , wherein the injection/production liner interfaces an entire length of the subsurface formation. 
     
     
         6 . The device of  claim 3 , further comprising one or more packers for positioning and centralizing the steam pup within the injection/production liner, said one or more packers being sized larger than an outside diameter of the steam pup and small enough to fit securely within an inside diameter of the injection/production liner. 
     
     
         7 . The device of  claim 6 , wherein the one or more packers are set inside the injection/production liner at a heel location, one third and two thirds of the way along the length of the wellbore to sealing off the annular space between the subsurface formation and the injection/production liner and the one or more steam pups. 
     
     
         8 . The device of  claim 1 , further comprising at least one retainer ring positioned in an inner surface of the outer sleeve, to limit motion of the inner sliding sleeve within the outer sleeve and prevent loss of the inner sliding sleeve through the outer sleeve. 
     
     
         9 . The device of  claim 1 , wherein an inner surface of the outer sleeve further comprising one or more locking rings that matingly engage with corresponding locking ring grooves located an outer surface of the inner sliding rings to position the inner sliding sleeve within the outer sleeve. 
     
     
         10 . The device of  claim 1 , wherein an outer surface of the inner sliding sleeve further comprises a series of o-rings to minimize and prevent flow of debris between an outer diameter of the inner sliding sleeve and an inner diameter of the outer sleeve. 
     
     
         11 . The device of  claim 1 , wherein the means for actuating movement of the inner sliding sleeve within the outer sleeve comprises a setting tool that is inserted into and connects with the inner sliding sleeve of the device to thereby move the inner sliding sleeve within the outer sleeve. 
     
     
         12 . The device of  claim 11 , wherein an outside diameter of the setting tool comprises one or more grooves extending over a length of the setting tool, said grooves matingly corresponding with one or more pins located on the inner sliding sleeve to allow movement of the setting tool inside the inner sliding sleeve when the one or more grooves are aligned with the one or more pins, and causing abutment of the setting tool against the inner sliding sleeve when the one or more grooves are not aligned with the one or more pins. 
     
     
         13 . The device of  claim 1 , wherein the means for actuating movement of the inner sliding sleeve within the outer sleeve comprises remote, hydraulic actuation. 
     
     
         14 . The device of  claim 1 , wherein the one or more sets of nozzles are set at an orientation of from 1° to 90° relative to an axis of the outer sleeve. 
     
     
         15 . The device of  claim 14 , wherein the orientation of the one or more sets of nozzles is 60° to the axis of outer sleeve. 
     
     
         16 . The device of  claim 14 , wherein the orientation of each nozzle in the set of nozzles is alternated. 
     
     
         17 . The device of  claim 14 , wherein the one or more sets of nozzles are machined into the outer sleeve. 
     
     
         18 . The device of  claim 14 , wherein the one or more sets of nozzles form part of a separate unit that is attached to the outer sleeve. 
     
     
         19 . The device of  claim 14 , wherein the one or more sets of nozzles have a cross sectional geometry selected from the group consisting of circular, tapered, conical, oval, square and rectangular. 
     
     
         20 . A method for delivering and distributing injection fluids into a subsurface formation from a wellbore or for producing fluids from the subsurface formation into the wellbore, said method comprising the steps of:
 d. introducing into the wellbore one or more steam pups, said steam pups comprising an outer sleeve and an inner sliding sleeve in concentric relationship and one or more sets of nozzles arranged on the outer sleeve;   e. actuating movement of the inner sliding sleeve within the outer sleeve to at least partially cover one or more sets of nozzles on the outer sleeve; to control fluid flow into or out of the subsurface formation; and   f. transferring injection or production fluids through the nozzles into and out of the subsurface formation via the steam pups.   
     
     
         21 . The method of  claim 20 , wherein actuating movement of the inner sliding sleeve within the outer sleeve comprises inserting a setting tool into the outer sleeve and connecting with the inner sliding sleeve to thereby move the inner sliding sleeve within the outer sleeve. 
     
     
         22 . The method of  claim 21 , wherein movement of the inner sliding sleeve within the out sleeve comprises inserting the setting tool into the outer sleeve until the setting tool abuts against the inner sliding sleeve and pushing the setting tool against the inner sliding sleeve to move the inner sliding sleeve within the outer sleeve. 
     
     
         23 . The method of  claim 21 , wherein movement of the inner sliding sleeve within the out sleeve comprises inserting the setting tool into the outer sleeve and through the inner sliding sleeve; and pulling the setting tool back up against the inner sliding sleeve to move the inner sliding sleeve within the outer sleeve. 
     
     
         24 . The method of  claim 20 , wherein actuating movement of the inner sliding sleeve within the outer sleeve comprises hydraulically actuating movement from a remote location. 
     
     
         25 . The method of  claim 20 , wherein the method is used for SAGD applications, the method further comprising a circulation phase prior to fluid injection, in which the inner sliding sleeve is set to cover half or more of the one or more sets of nozzles on the outer sliding sleeve, to thereby provide steam at low pressure to heat production fluids in the subsurface formation to increase mobility and steam chamber growth, followed by a higher pressure steam injection phase and a production phase. 
     
     
         26 . The method of  claim 20 , wherein the method is used for fluid injection into the subsurface formation at injections pressures above the fracture pressure of the subsurface formation. 
     
     
         27 . A method for delivering and distributing injection fluids into a subsurface formation from a wellbore or for producing fluids from the subsurface formation into the wellbore, said method comprising the steps of:
 a. introducing into a heel location of the wellbore a first and second pairs of flow control hangers and polished bore receptacles, wherein the polished bore receptacles are connected to an intermediate casing and cemented in place;   b. connecting the first pair of flow control hanger and polished bore receptacle to an injection/production liner;   c. connecting one or more steam pups to the second pair of flow control hanger and polished bore receptacle, said steam pups comprising an outer sleeve and an inner sliding sleeve in concentric relationship and one or more sets of nozzles arranged on the outer sleeve;   d. actuating movement of the inner sliding sleeve within the outer sleeve to at least partially cover one or more sets of nozzles on the outer sleeve; to control fluid flow into or out of the subsurface formation; and   e. processing injection or production fluids through the nozzles into or out of the subsurface formation via the steam pups.