Optimal subsurface design for high bubble point pressure reservoirs

Abstract

A well system includes a primary wellbore extending vertical from a service rig and penetrating a subterranean formation including a hydrocarbon-bearing, undersaturated reservoir. The primary wellbore includes a first tangent section extending at a first inclination from vertical and a second tangent section extending from the first tangent section and at a second inclination from vertical. The well system includes an electrical submersible pump (ESP) positioned in the first tangent section or the second tangent section based on a bubble point pressure of the hydrocarbon-bearing reservoir.

1 .- 10 . (canceled) 
     
     
         11 . A method, comprising:
 conveying an electrical submersible pump (ESP) into a primary wellbore extending vertical from a service rig and penetrating a subterranean formation including a hydrocarbon-bearing, undersaturated reservoir, the primary wellbore including:
 a first tangent section extending at a first inclination from vertical; and 
 a second tangent section extending from the first tangent section and at a second inclination from vertical; 
   positioning the ESP within the second tangent section when a pore pressure of the reservoir is at or within 100 psi of a bubble point pressure of the reservoir; and   positioning the ESP within the first tangent section when the pore pressure of the reservoir exceeds the bubble point pressure of the reservoir by at least 200 psi.   
     
     
         12 . The method of  claim 11 , wherein the primary wellbore further includes:
 a first build section extending from vertical to the first tangent section, the first build section transitioning the primary wellbore from vertical to the first inclination; and   a second build section extending from the first tangent section and transitioning the primary wellbore from the first inclination to the second inclination.   
     
     
         13 . The method of  claim 11 , wherein the first inclination from surface ranges between 1° and 55° from vertical. 
     
     
         14 . The method  claim 11 , wherein the second inclination ranges between 70° and 90° from vertical. 
     
     
         15 . The method of  claim 11 , wherein the primary wellbore further includes one or more lateral wellbores extending from the primary wellbore, the method further comprising:
 conveying a completion string into the wellbore, the completion string being located downhole from the ESP;   positioning one or more inflow control valves included in the completion string adjacent the one or more lateral wellbores; and   regulating hydrocarbon flow into the completion string from the one or more inflow control valves.   
     
     
         16 . The method of  claim 11 , further comprising controlling operation of the ESP with a controller and a variable speed drive positioned at the service rig. 
     
     
         17 . The method of  claim 16 , further comprising:
 setting the variable speed drive to a predetermined pump intake pressure; and adjusting a speed of the variable speed drive when the predetermined pump intake pressure is achieved.   
     
     
         18 . A well system, comprising:
 a primary wellbore extending vertical from a service rig and penetrating a subterranean formation including a hydrocarbon-bearing, undersaturated reservoir, the primary wellbore including:
 a first tangent section extending at a first inclination from vertical; and 
 a second tangent section extending from the first tangent section and at a second inclination from vertical; 
   one or more lateral wellbores extending from the primary wellbore;   a completion string including one or more inflow control valves positioned adjacent the one or more lateral wellbores and operable to regulate hydrocarbon flow; and   an electrical submersible pump (ESP) positioned in the primary wellbore based on a bubble point pressure of the hydrocarbon-bearing reservoir, wherein the ESP is positioned within the first tangent section when a pore pressure of the reservoir exceeds the bubble point pressure of the reservoir by at least 200 psi and positioned within the second tangent section when the pore pressure of the reservoir is at or within 100 psi of the bubble point pressure of the reservoir.   
     
     
         19 . (canceled) 
     
     
         20 . (canceled) 
     
     
         21 . The well system of  claim 18 , the completion string further comprising:
 a first wellbore isolation device and a second wellbore isolation device straddling a lateral wellbore of the one or more lateral wellbores and sealing against a surface of the primary wellbore, the first and second wellbore isolation devices being downhole from the ESP; and   the one or more inflow control valves including an inflow control valve interposing the first and second wellbore isolation devices,   wherein the completion string is attached to a production tubing including the ESP at a matable interface.   
     
     
         22 . The well system of  claim 18 , wherein the primary wellbore further includes:
 a first build section extending from vertical to the first tangent section, the first build section transitioning the primary wellbore from vertical to the first inclination; and   a second build section extending from the first tangent section and transitioning the primary wellbore from the first inclination to the second inclination.   
     
     
         23 . The well system of  claim 18 , wherein the first inclination ranges between 1° and 55° from vertical. 
     
     
         24 . The well system of  claim 18 , wherein the second inclination ranges between 70° and 90° from vertical. 
     
     
         25 . The well system of  claim 18 , wherein the ESP is operatively coupled to production tubing extended into the primary wellbore, the well system further comprising:
 one or more lateral wellbores extending from the primary wellbore; and   a completion string extending from the production tubing and including one or more inflow control valves positioned adjacent the one or more lateral wellbores and operable to regulate hydrocarbon flow into the production tubing.   
     
     
         26 . The well system of  claim 18 , further comprising a controller and a variable speed drive positioned at the service rig and operable to control operation of the ESP. 
     
     
         27 . The well system of  claim 26 , wherein the variable speed drive is programmed to maintain a predetermined pump intake pressure. 
     
     
         28 . The well system of  claim 27 , wherein the predetermined pump intake pressure is set to 100 psi above the bubble point pressure of the reservoir. 
     
     
         29 . The method of  claim 15 , wherein the completion string includes a pair of wellbore isolation devices straddling each inflow control valve, wherein each wellbore isolation device seals against a surface of the primary wellbore. 
     
     
         30 . The method of  claim 29 , wherein the completion string is attached to a production tubing that includes the ESP at a matable interface.