Wellbore Servicing Compositions and Methods of Making and Using Same

Abstract

A method of servicing a wellbore in a subterranean formation having one or more lost circulation zones comprising placing a wellbore servicing fluid comprising a sealing composition into the wellbore, wherein the sealing composition comprises a latex and an accelerator and wherein the latex, the accelerator or both are encapsulated with an encapsulation material. A wellbore servicing fluid comprising a latex and an accelerator wherein the latex, the accelerator, or both are encapsulated.

1 . A method of servicing a wellbore in a subterranean formation having one or more lost circulation zones comprising:
 placing a wellbore servicing fluid comprising a sealing composition into the wellbore, wherein the sealing composition comprises a latex and an accelerator and wherein the latex is encapsulated with an encapsulation material, wherein the wellbore servicing fluid comprises a calcium chloride and/or a calcium bromide brine, and wherein the calcium chloride and/or the calcium bromide brine are reactive with the latex in the absence of the encapsulation material to form a latex sealant composition.   
     
     
         2 . The method of  claim 1  wherein the latex comprises a naturally-occurring material, a synthetic material, or combinations thereof. 
     
     
         3 . The method of  claim 1  wherein the latex is a solid latex or a latex emulsion. 
     
     
         4 . The method of  claim 1  wherein the latex comprises a latex-polymer, an alkali-swellable latex; a polar monomer-based latex; an elasticity enhancing monomer-based latex;
 a stiffness enhancing monomer-based latex; a cationic latex; or combinations thereof. 
 
     
     
         5 . The method of  claim 4  wherein the latex polymer comprises isoprene, styrene, acrylonitrile, butadiene, or combinations thereof. 
     
     
         6 . The method of  claim 4  wherein the alkali-swellable latex comprises vinyl aromatic monomers, styrene based monomers, ethylene, butadiene, vinylnitrile, acrylonitrile, olefinically unsaturated esters of C 1 -C 8  alcohols, non-ionic monomers that exhibit steric effects and that contain ethoxylate or hydrocarbon tails, derivatives thereof, or combinations thereof. 
     
     
         7 . The method of  claim 4  wherein the polar monomer-based latex comprises vinylamine, vinyl acetate, acrylonitrile, acrylic acid derivatives, acrylates, or combinations thereof; the elasticity enhancing monomer-based latex comprises ethylene, propylene, butadiene, 1,3-hexadiene, isoprene, or combinations thereof; and the stiffness enhancing monomer-based latex comprises styrene, t-butylstyrene, α-methylstyrene, sulfonated styrene, or combinations thereof. 
     
     
         8 . The method of  claim 1  wherein the accelerator comprises pH-modifying material precursors, acid precursors, acids, base precursors, inorganic bases, organic bases, salts, or combinations thereof. 
     
     
         9 . The method of  claim 8  wherein the acid precursor comprises monoethylene monoformate, monoethylene diformate, ethylene glycol monoformate, ethylene glycol diformate, diethylene glycol monoformate, diethylene glycol diformate, triethylene glycol diformate, glyceryl monoformate, glyceryl diformate, glyceryl triformate; formate esters of pentaerythritol,tri-n-propyl orthoformate, tri-n-butyl orthoformate, methyl lactate, ethyl lactate, propyl lactate, butyl lactate, trilactin, polylactic acid, poly(lactides), methyl acetate, ethyl acetate, propyl acetate, butyl acetate, monoacetin, diacetin, triacetin, glyceryl diacetate, glyceryl triacetate, tripropionin (a triester of propionic acid and glycerol), methyl glycolate, ethyl glycolate, propyl glycolate, butyl glycolate, poly(glycolides), or combinations thereof. 
     
     
         10 . The method of  claim 8  wherein the acid comprises formic acid; acetic acid;  lactic acid; glycolic acid; oxalic acid; propionic acid; butyric acid; monochloroacetic acid; dichloroacetic acid; trichloroacetic acid; hydrochloric acid; nitric acid; sulphuric acid; sulphonic acid; para-toluene sulfonic acid; sulphinic acid; phosphoric acid; phosphorous acid; phosphonic acid; phosphinic acid; sulphamic acid; citric acid; or combinations thereof. 
     
     
         11 . The method of  claim 8  wherein the base precursor comprises ammonium, alkali and alkali earth metal carbonates and bicarbonates, alkali and alkali earth metal oxides, alkali and alkali earth metal hydroxides, alkali and alkali earth metal phosphates and hydrogen phosphates, alkali and alkaline earth metal sulphides, alkali and alkaline earth metal salts of silicates and aluminates, water soluble or water dispersible organic amines, polymeric amines, amino alcohols, or combinations thereof. 
     
     
         12 . The method of  claim 8  wherein the salt comprises salts of monovalent, divalent, trivalent cations, or combinations thereof. 
     
     
         13 . The method of  claim 1  wherein the accelerator comprises a brine having a density of from about 9 lb/gal to about 20 lb/gal. 
     
     
         14 . The method of  claim 8  wherein the salt comprises an ammonium salt, ammonium sulfate, ammonium chloride, ammonium acetate, and the like, or combinations thereof. 
     
     
         15 . The method of  claim 1  wherein the encapsulation is an external coating comprising EDPM rubber, polyvinyldichloride, nylon, waxes, polyurethanes, cross-linked partially hydrolyzed acrylics, cross-linked polyurethane or combinations thereof 
     
     
         16 . The method of  claim 1  wherein the ratio of latex to accelerator in the sealing composition is about 10:1. 
     
     
         17 . The method of  claim 1  wherein the wellbore servicing fluid comprises a water-based drilling mud or an oil-based drilling mud. 
     
     
         18 . (canceled) 
     
     
         19 . (canceled) 
     
     
         20 . (canceled) 
     
     
         21 . The method of  claim 1  wherein the lost circulation zone has a rate of fluid loss of from about 10 bbl/hr to about 100 bbl/hr. 
     
     
         22 . A method of servicing a wellbore in a subterranean formation having one or more lost circulation zones comprising:
 placing a wellbore servicing fluid comprising a sealing composition into the wellbore, wherein the sealing composition comprises a latex and an accelerator, wherein the latex is encapsulated with an encapsulation material, and wherein the wellbore servicing fluid comprises a calcium chloride and/or a calcium bromide brine;   deteriorating the encapsulation material such that at least a portion of the latex contacts the calcium chloride and/or the calcium bromide brine; and   reacting the calcium chloride and/or the calcium bromide brine with the latex to form a latex sealant composition within the wellbore proximate one or more of the lost circulation zones.   
     
     
         23 . The method of  claim 22  wherein the wellbore servicing fluid comprises a drilling fluid and the latex sealant composition prevents loss and/or migration of drilling fluid into the one or more lost circulation zones. 
     
     
         24 . The method of  claim 22  wherein the wellbore servicing fluid is placed into the wellbore through a drill bit, and wherein the drill bit is located proximate the lost circulation zone.