Methods of Using Wellbore Servicing Compositions

Abstract

A method of servicing a wellbore comprising preparing a composition comprising a non-aqueous carrier fluid, an oil-wetting surfactant, a water-imbibition enhancing surfactant, and a cementitious material; placing the composition within a detrimentally permeable zone; and contacting the composition with water. A method of servicing a wellbore comprising placing a composition comprising a non-aqueous carrier fluid, an oil-wetting surfactant, a water-imbibition enhancing surfactant, and a cementitious material into the wellbore wherein the wellbore comprises hydrocarbon-producing zones and water-producing zones and wherein the composition enters the water-producing zone and forms a solid mass that obstructs the flow of water in the water-producing zone. A method of servicing wellbore comprising placing a composition comprising a non-aqueous carrier fluid, an oil-wetting surfactant, a water-imbibition enhancing surfactant, and a cementitious material into a lost circulation zone within the wellbore; and contacting the composition in situ with a water source.

What is claimed is: 
     
         1 . A method of servicing a wellbore comprising:
 (a) preparing a composition comprising a non-aqueous carrier fluid, an oil-wetting surfactant, a water-imbibition enhancing surfactant, and a cementitious material;   (b) placing the composition within a detrimentally permeable zone; and   (c) contacting the composition with water.   
     
     
         2 . The method of  claim 1  wherein the cementitious material comprises a hydraulic cement. 
     
     
         3 . The method of  claim 2  wherein the cementitious material comprises Portland cements, pozzolana cements, gypsum cements, phosphate cements, high alumina content cements, silica cements, high alkalinity cements, shale cements, acid/base cements, magnesia cements, fly ash cement, zeolite cement systems, cement kiln dust cement systems, slag cements, micro-fine cement, or combinations thereof. 
     
     
         4 . The method of  claim 1  wherein the composition further comprises a filler. 
     
     
         5 . The method of  claim 4  wherein the filler comprises pumice, ASTM Class F fly ash, sand, silica, metakaolin, slag, or combinations thereof. 
     
     
         6 . The method of  claim 1  wherein the cementitious material has an average particle size of equal to or less than about 50 microns. 
     
     
         7 . The method of  claim 4  wherein the cementitious material has an average particle size of equal to or less than about 50 microns. 
     
     
         8 . The method of  claim 1  wherein the cementitious material is present in the composition in an amount of from about 15 wt. % to about 90 wt. % based on the total weight of the composition. 
     
     
         9 . The method of  claim 1  wherein the non-aqueous carrier fluid comprises internal olefins, linear alpha olefins, poly alpha olefins, diesel, mineral oil, kerosene, silicone fluids, oxygenated solvents, or combinations thereof. 
     
     
         10 . The method of  claim 1  wherein the non-aqueous carrier fluid comprises less than about 5% water by total weight of the fluid. 
     
     
         11 . The method of  claim 1  wherein the composition further comprises a dehydrating agent. 
     
     
         12 . The method of  claim 1  wherein the oil-wetting surfactant has a hydrophilic-lipophilic balance of equal to greater than about 7. 
     
     
         13 . The method of  claim 1  wherein the water-imbibition enhancing surfactant has a hydrophilic-lipophilic balance of greater than or equal to about 10. 
     
     
         14 . The method of  claim 13 , wherein the water-imbibition enhancing surfactant is a quaternary ammonium compound comprising a benzyl group and an alkyl group selected from the group consisting of a coco alkyl group and a hydrogenated tallow alkyl group. 
     
     
         15 . The method of  claim 1  wherein the water contacting the cementitious composition is endogenous to the detrimentally permeable zone. 
     
     
         16 . The method of  claim 1  wherein the water contacting the cementitious composition is exogenous to the detrimentally permeable zone. 
     
     
         17 . The method of  claim 1  wherein a portion of the cementitious material forms a solid mass when contacted with water. 
     
     
         18 . The method of  claim 17  wherein the portion of cementitious material that forms a solid mass when contacted with water is equal to or greater than about 75% of the cementitious material by weight. 
     
     
         19 . The method of  claim 1  wherein the detrimentally permeable zone comprises an area of lost circulation. 
     
     
         20 . The method of  claim 1  wherein the detrimentally permeable zone comprises a water-producing area in a hydrocarbon producing wellbore. 
     
     
         21 . The method of  claim 1  wherein the detrimentally permeable zone comprises an area of lost structural integrity in a set cement sheath. 
     
     
         22 . A method of servicing a wellbore comprising placing a composition comprising a non-aqueous carrier fluid, an oil-wetting surfactant, a water-imbibition enhancing surfactant, and a cementitious material into the wellbore, wherein the wellbore comprises hydrocarbon-producing zones and water-producing zones and wherein the composition enters the water-producing zone and forms a solid mass that obstructs the flow of water in the water-producing zone. 
     
     
         23 . A method of servicing wellbore comprising:
 placing a composition comprising a non-aqueous carrier fluid, an oil-wetting surfactant, a water-imbibition enhancing surfactant, and a cementitious material into a lost circulation zone within the wellbore; and   contacting the composition in situ with a water source.