Materials and methods to prevent fluid loss in subterranean formations

Abstract

Methods of preventing fluid loss in a downhole formation may include preparing an emulsion containing: an oleaginous phase; an aqueous phase; one or more fibers; injecting the emulsion into the wellbore; allowing the one or more fibers within the emulsion to seal a permeable interval of the formation. In another aspect, methods of stimulating hydrocarbon production in a wellbore may include: injecting a diverting treatment into a subterranean formation, the diverting treatment containing: a non-oleaginous fluid, an oleaginous fluid, and one or more fibers; injecting a stimulating treatment into the subterranean formation; and stimulating the production of hydrocarbons.

What is claimed: 
     
         1 . A method of preventing fluid loss in a downhole formation, comprising:
 injecting the emulsion into the wellbore, the emulsion comprising:
 an oleaginous phase, 
 an aqueous phase, 
 one or more fibers; and 
   allowing the one or more fibers within the emulsion to seal a permeable interval of the downhole formation.   
     
     
         2 . The method of  claim 1 , wherein the emulsion is a water-in-oil emulsion. 
     
     
         3 . The method of  claim 1 , wherein the emulsion is an oil-in-water emulsion. 
     
     
         4 . The method of  claim 1 , wherein the average length of the one or more fibers ranges from 100 μm to 20 mm. 
     
     
         5 . The method of  claim 1 , wherein the one or more fibers are added at a concentration of 1 ppg to 15 ppg. 
     
     
         6 . The method of  claim 1 , wherein the one or more fibers are oleophilic. 
     
     
         7 . The method of  claim 6 , wherein the one or more fibers are selected from a group consisting of homopolymers, copolymers, multi-block interpolymers, and higher order polymers of ethylene, tetrafluoroethylene, vinylidene fluoride, propylene, butene, 1-butene, 4-methyl-1-pentene, styrene, p-phenylene-2,6-benzobisoxazole, aramids, and urethanes. 
     
     
         8 . The method of  claim 1 , wherein the one or more fibers are hydrophilic. 
     
     
         9 . The method of  claim 8 , wherein the one or more fibers are selected from a group consisting of polymers, copolymers, multi-block interpolymers, and higher order polymers of polylactic acid, polyhydroxyalkanoates, polycaprolactones, polyhydroxybutyrates, polyethylene terephthalates, polytriphenylene terephthalate, polybutylene terephthalate, polyvinyl alcohols, polyacrylamide, partially hydrolyzed polyacrylamide, polyvinyl acetate, and partially hydrolyzed polyvinyl acetate. 
     
     
         10 . The method of  claim 1 , wherein the one or more fibers are one or more hydrophilic inorganic fibers selected from a group consisting of calcium carbonate, calcium/magnesium carbonate, magnesium carbonate, magnesium oxide, and calcium oxide. 
     
     
         11 . The method of  claim 1 , wherein the one or more fibers are high surface area fibers. 
     
     
         12 . The method of  claim 1 , further comprising injecting an acid to dissolve the one or more fibers, thereby stimulating production of hydrocarbons. 
     
     
         13 . The method of  claim 1 , wherein the emulsion further comprises one or more particulate weighting agents. 
     
     
         14 . The method of  claim 13 , wherein the particulate weighting agents are acid soluble. 
     
     
         15 . The method of  claim 13 , wherein the particulate weighting agents have an average particle size (d 50 ) that ranges from 100 nm to 100 μm. 
     
     
         16 . The method of  claim 13 , wherein the particulate weighting agents are added at a concentration that ranges from 1 ppg to 20 ppg. 
     
     
         17 . A method of stimulating hydrocarbon production in a wellbore comprising:
 injecting a diverting treatment into a subterranean formation, the diverting treatment comprising: a non-oleaginous fluid, an oleaginous fluid, and one or more fibers;   injecting a stimulating treatment into the subterranean formation; and   stimulating the production of hydrocarbons.   
     
     
         18 . The method of  claim 17 , wherein the diverting treatment further comprises at least one particulate solid. 
     
     
         19 . The method of  claim 17 , wherein the diverting treatment is an invert emulsion. 
     
     
         20 . The method of  claim 17 , wherein the stimulating treatment is an acid wash.