Fracturing Process to Enhance Propping Agent Distribution to Maximize Connectivity Between the Formation and the Wellbore

Abstract

A method of treating a subterranean formation may include placing a first treatment fluid into a subterranean formation through an access conduit connecting the subterranean formation to a wellbore at a pressure sufficient to form at least a portion of a fracture network; pumping a second treatment fluid comprising a propping agent into the fracture network such that the propping agent forms a proppant pack in at least a portion of the fracture network; placing a third treatment fluid comprising a secondary diverting agent into the fracture network so as to substantially inhibit fluid flow through at least a portion of the fracture network without substantially inhibiting fluid flow through the access conduit; and placing a fourth treatment fluid comprising a primary diverting agent into the wellbore such that the primary diverting agent substantially inhibits fluid flow through the access conduit.

1 . A method comprising:
 providing a wellbore penetrating a subterranean formation, wherein the subterranean formation is able to support a fracture network;   providing at least one access conduit to the subterranean formation from the wellbore;   placing a first treatment fluid into the subterranean formation through at least one access conduit at a pressure sufficient to form at least a portion of a fracture network extending from at least one access conduit;   pumping a second treatment fluid comprising a propping agent into the fracture network such that the propping agent forms a proppant pack in at least a portion of the fracture network;   placing a third treatment fluid comprising a secondary diverting agent into the wellbore such that the secondary diverting agent goes through the access conduit and into at least a portion of the fracture network so as to substantially inhibit fluid flow through at least a portion of the fracture network without substantially inhibiting fluid flow through the access conduit; and   placing a fourth treatment fluid comprising a primary diverting agent into the wellbore such that the primary diverting agent substantially inhibits fluid flow through the access conduit.   
     
     
         2 . The method of  claim 1  further comprising:
 producing hydrocarbons from the subterranean formation. 
 
     
     
         3 . The method of  claim 1 , wherein pumping the second treatment fluid, placing the third treatment fluid, and placing the fourth treatment fluid are performed in any order. 
     
     
         4 . The method of  claim 1 , wherein pumping the second treatment fluid is done continuously while placing the third treatment fluid and placing the fourth treatment fluid. 
     
     
         5 . The method of  claim 1 , wherein the concentration of the propping agent in the second treatment fluid is changed during pumping. 
     
     
         6 . The method of  claim 1 , wherein a step selected from the group consisting of pumping the second treatment fluid, placing the third treatment fluid, placing the fourth treatment fluid, and any combination thereof are performed more than once. 
     
     
         7 . The method of  claim 1 , wherein the first treatment fluid, the second treatment fluid, the third treatment fluid, and the fourth treatment fluid comprise the same base fluid with different additives. 
     
     
         8 . The method of  claim 1 , wherein the propping agent comprises a proppant particulate coated with a consolidating agent. 
     
     
         9 . The method of  claim 1 , wherein the secondary diverting agent has a diameter of about 150 microns or less. 
     
     
         10 . The method of  claim 1 , wherein the secondary diverting agent is at least partially degradable, 
     
     
         11 . The method of  claim 1 , wherein the primary diverting agent has a bimodal particle size distribution. 
     
     
         12 . The method of  claim 1 , wherein the primary diverting agent comprises first particulates, wherein the secondary diverting agent comprises second particles, and wherein the first particles have a larger average diameter than the second particulates. 
     
     
         13 . The method of  claim 1 , wherein the primary diverting agent comprises perf balls. 
     
     
         14 . The method of  claim 1 , wherein the primary diverting agent comprises a gel. 
     
     
         15 . The method of  claim 1 , wherein the primary diverting agent is at least partially degradable. 
     
     
         16 . The method of  claim 1  further comprising:
 introducing a cleanup treatment fluid into the wellbore to enhance fluid flow through at least a portion of the fracture network. 
 
     
     
         17 . The method of  claim 1  further comprising:
 placing a fifth treatment fluid comprising a degradable particle into the fracture network such that the degradable particle is capable of forming voids within at least a portion of the proppant pack. 
 
     
     
         18 . The method of  claim 17 , wherein placing a fifth treatment fluid and pumping a second treatment fluid are performed simultaneously. 
     
     
         19 . The method of  claim 17 , wherein the fifth treatment fluid further comprises the propping agent. 
     
     
         20 . The method of  claim 17  further comprising:
 introducing a cleanup treatment fluid into the wellbore to enhance fluid flow through at least a portion of the fracture network. 
 
     
     
         21 . The method of  claim 17 , wherein a step selected from the group consisting of pumping the second treatment fluid, placing the third treatment fluid, placing the fourth treatment fluid, placing a fifth treatment fluid, and any combination thereof is performed more than once. 
     
     
         22 . A method comprising:
 providing a wellbore penetrating a subterranean formation, wherein the subterranean formation has a closure pressure greater than about 500 psi;   providing at least one access conduit to the subterranean formation from the wellbore;   placing a first treatment fluid into the subterranean formation through the at least one access conduit at a pressure sufficient to form at least a portion of a fracture network extending from the at least one access conduit;   pumping a second treatment fluid comprising a propping agent into the fracture network such that the propping agent forms a proppant pack in at least a portion of the fracture network;   placing a third treatment fluid comprising a secondary diverting agent into the wellbore such that the secondary diverting agent goes through the access conduit and into at least a portion of the fracture network so as to substantially inhibit fluid flow through at least a portion of the fracture network without substantially inhibiting fluid flow through the access conduit; and   placing a fourth treatment fluid comprising a primary diverting agent into the wellbore such that the primary diverting agent substantially inhibits fluid flow through the access conduit.   
     
     
         23 . A method comprising:
 providing a wellbore penetrating a subterranean formation, wherein the subterranean formation is able to support a fracture network and the wellbore has at least one access conduit to the subterranean formation from the wellbore;   placing a first treatment fluid into the subterranean formation at a pressure sufficient to form at least a portion of a fracture network extending from at least one access conduit;   pumping a second treatment fluid comprising a propping agent into the fracture network such that the propping agent forms a proppant pack in at least a portion of the fracture network,
 wherein the propping agent comprises proppant particulates at least partially coated with a consolidating agent and at least a portion of degradable particles; 
   placing a third treatment fluid comprising a secondary diverting agent into the wellbore such that the secondary diverting agent goes through the access conduit and into at least a portion of the fracture network so as to substantially inhibit fluid flow through at least a portion of the fracture network without substantially inhibiting fluid flow through the access conduit,
 wherein the secondary diverting agent is at least partially degradable; 
   placing a fourth treatment fluid comprising a primary diverting agent into the wellbore such that the primary diverting agent substantially inhibits fluid flow through the access conduit,
 wherein the primary diverting agent is at least partially degradable; and 
   repeating at least one step selected from the group consisting of pumping the second treatment fluid, placing the third treatment fluid, placing the fourth treatment fluid, placing the fifth treatment fluid, and any combination thereof.