Method of enhancing treatment fluid placement in shale, clay, and/or coal bed formations

Abstract

Provided are methods that include a method comprising: placing a treatment fluid into a well bore that penetrates a subterranean formation, wherein the subterranean formation comprises at least one selected from the group consisting of: a shale, a clay, a coal bed, and a combination thereof; and applying a pressure pulse to the treatment fluid.

1 . A method comprising:
 placing a treatment fluid into a well bore that penetrates a subterranean formation, wherein the subterranean formation comprises at least one selected from the group consisting of: a shale, a clay, a coal bed, and a combination thereof; and   applying a pressure pulse to the treatment fluid.   
   
   
       2 . The method of  claim 1  wherein the subterranean formation further comprises at least one fracture and the treatment fluid is placed into the subterranean formation so that the at least one fracture is at least partially dilated. 
   
   
       3 . The method of  claim 1  further comprising pressurizing the treatment fluid above the ambient fluid pressure in the well bore prior to applying the pressure pulse. 
   
   
       4 . The method of  claim 1  wherein the pressure pulse exceeds the formation fracture gradient. 
   
   
       5 . The method of  claim 1  wherein the pressure pulse straddles the formation fracture gradient. 
   
   
       6 . The method of  claim 1  wherein the subterranean formation further comprises one or more pairs of adjacent bedding planes and the treatment fluid is placed into the subterranean formation so that the one or more pairs of adjacent bedding planes is at least partially separated. 
   
   
       7 . The method of  claim 1  wherein the pressure pulse applied to the treatment fluid generates a pressure pulse in a portion of the subterranean formation in the range of from about 10 psi to about 3,000 psi. 
   
   
       8 . The method of  claim 1  wherein the pressure pulse is applied at a frequency in the range of from about 0.001 Hz to about 1 Hz. 
   
   
       9 . The method of  claim 1  further comprising generating a pressure pulse having an amplitude different from the amplitude of a previous pressure pulse. 
   
   
       10 . The method of  claim 1  further comprising at least one of the following: allowing the treatment fluid to at least partially dehydrate at least a portion of the subterranean formation; allowing the treatment fluid to at least partially stabilize at least a portion of the subterranean formation; and allowing the treatment fluid to at least partially shrink at least a portion of the subterranean formation. 
   
   
       11 . The method of  claim 1  wherein the treatment fluid comprises at least one selected from the group consisting of: a cationic polymer; a cationic oligomer; a methanol; a glycerin; an ethylene glycol; a low molecular weight consolidation fluid; a polymeric composition; a quaternary ammonium compound having inorganic anions and carboxylate anions; a polymeric composition; a rheology stabilizer; a rheology thinner; a consolidation fluid; a stimulation fluid; a relative permeability modifier; and a combination thereof. 
   
   
       12 . The method of  claim 1  wherein the treatment fluid comprises at least one selected from the group consisting of: a potassium ion, a calcium ion, an ammonium ion, a hydrogen ion, a tetramethylammonium ion, potassium chloride, calcium chloride, sodium chloride, ammonium chloride, tetramethylammonium chloride, and a combination thereof. 
   
   
       13 . A method comprising:
 placing a treatment fluid into a well bore that penetrates a subterranean formation, wherein the subterranean formation comprises at least one selected from the group consisting of: a shale, a clay, a coal bed, and a combination thereof; and   applying a pressure pulse that exceeds the formation fracture gradient to the treatment fluid.   
   
   
       14 . The method of  claim 13  further comprising pressurizing the treatment fluid above the ambient fluid pressure in the well bore prior to applying the pressure pulse. 
   
   
       15 . The method of  claim 13  further comprising at least one of the following: allowing the treatment fluid to at least partially dehydrate at least a portion of the subterranean formation; allowing the treatment fluid to at least partially stabilize at least a portion of the subterranean formation; and allowing the treatment fluid to at least partially shrink at least a portion of the subterranean formation. 
   
   
       16 . The method of  claim 13  wherein the treatment fluid comprises at least one selected from the group consisting of: a cationic polymer; a cationic oligomer; a methanol; a glycerin; an ethylene glycol; a low molecular weight consolidation fluid; a polymeric composition; a quaternary ammonium compound having inorganic anions and carboxylate anions; a polymeric composition; a rheology stabilizer; a rheology thinner; a consolidation fluid; a stimulation fluid; a relative permeability modifier; and a combination thereof. 
   
   
       17 . The method of  claim 13  wherein the treatment fluid comprises at least one selected from the group consisting of: a potassium ion, a calcium ion, an ammonium ion, a hydrogen ion, a tetramethylammonium ion, potassium chloride, calcium chloride, sodium chloride, ammonium chloride, tetramethylammonium chloride, and a combination thereof. 
   
   
       18 . A method comprising:
 placing a treatment fluid into a well bore that penetrates a subterranean formation, wherein the subterranean formation comprises at least one selected from the group consisting of: a shale, a clay, a coal bed, and a combination thereof;   pressurizing the treatment fluid to a first pressure wherein the first pressure exceeds the ambient fluid pressure in the well bore; and   applying a pressure pulse to the treatment fluid, wherein
 the minimum pressure of the pressure pulse exceeds the first pressure; and 
 the maximum pressure of the pressure pulse exceeds the formation fracture gradient. 
   
   
   
       19 . The method of  claim 18  wherein the minimum pressure of the pressure pulse exceeds the formation fracture gradient. 
   
   
       20 . The method of  claim 18  wherein the treatment fluid comprises at least one selected from the group consisting of: a cationic polymer; a cationic oligomer; a cation; a methanol; a glycerin; an ethylene glycol; a low molecular weight consolidation fluid; a polymeric composition; a quaternary ammonium compound having inorganic anions and carboxylate anions; a polymeric composition; a rheology stabilizer; a rheology thinner; a consolidation fluid; a stimulation fluid; a relative permeability modifier; and a combination thereof.