Delayed water-swelling materials and method of use

Abstract

A water absorbing composition includes a particle having a core of a water-swelling material. A coating substantially surrounds the core that temporarily prevents contact of water with the water-swelling material. The coating may be formed from a layer of water degradable material or a non-water-degradable, non-water absorbent encapsulating layer. A quantity of particles including delayed water-swelling particles formed at least in part from a water-swelling material and, optionally, non-water-swelling particles of the same or different size distributions can be used in treating a formation penetrated by a wellbore. A slurry of the particles is formed with a carrier fluid. The slurry of particles is introduced into the wellbore of the formation to facilitate treatment.

1 . A water absorbing composition comprising a particle having a core of a water-swelling material and a coating substantially surrounding the core that temporarily prevents contact of water with the water-swelling material, the coating being formed from at least one of (1) a layer or layers of water degradable material and (2) a non-water-degradable, non-water absorbent layer or layers of encapsulating material. 
     
     
         2 . The composition of  claim 1 , wherein:
 the water-swelling material comprises at least one of a clay and a superabsorbing material.   
     
     
         3 . The composition of  claim 2 , wherein:
 the clay is selected from the group consisting of bentonite, montmorillonite, smectite, nontronite, beidellite, perlite and vermiculite clays and combinations of these; and   the superabsorbing material is selected from the group consisting of polymers and copolymers of acrylate, acrylic acid, amide, acrylamide, saccharides, vinyl alcohol, urethane, and combinations of these materials.   
     
     
         4 . The composition of  claim 1 , wherein:
 the water degradable material comprises a solid polymer acid precursor.   
     
     
         5 . The composition of  claim 1 , wherein:
 the water degradable material comprises a polylactic acid coating.   
     
     
         6 . The composition of  claim 1 , wherein:
 the core further contains a weighting material.   
     
     
         7 . The composition of  claim 6 , wherein:
 the weighting material is selected from the group consisting of silicates, aluminosilicates, barite, hematite, ilmenite, manganese tetraoxide, manganosite, iron, lead, aluminum and combinations of these.   
     
     
         8 . The composition of  claim 1 , wherein:
 the core comprises an inner core of proppant material with an outer layer of the water absorbent material formed around the proppant material.   
     
     
         9 . The composition of  claim 1 , wherein:
 the water-swelling material comprises a superabsorbent material that has been surface cross-linked to delay swelling further.   
     
     
         10 . The composition of  claim 1 , wherein:
 the water-swelling material is capable of absorbing at least the water-swelling material's weight of water.   
     
     
         11 . A method of treating a formation penetrated by a wellbore comprising:
 providing a quantity of particles comprising delayed water-swelling particles formed at least in part from a water-swelling material and non-water-swelling particles of different size distributions;   forming a slurry of the particles with a carrier fluid; and   introducing the slurry of particles into the wellbore of the formation.   
     
     
         12 . The method of  claim 11 , wherein:
 the non-water-swelling particles have a particle size of from about 0.035 mm to about 2.35 mm.   
     
     
         13 . The method of  claim 11 , wherein:
 non-water-swelling particles of at least two different size distributions are used wherein the mean particle size of the larger non-water-swelling particles is at least 1.5 times greater than that of the smaller non-water-swelling particles.   
     
     
         14 . The method of  claim 11 , wherein:
 the non-water-swelling particles comprise coarse particles having a particle size of from about 0.2 mm to about 2.35 mm and at least one of fine particles having a particle size of less than about 0.1 mm and medium particles having a particle size of from about 0.1 mm to less than about 0.2 mm.   
     
     
         15 . (canceled) 
     
     
         16 . The method of  claim 11 , wherein:
 the particles have a specific gravity that is at least one of the same, greater or less than the specific gravity of the carrier fluid.   
     
     
         17 . The method of  claim 11 , wherein:
 the water-swelling material comprises at least one of a clay and a superabsorbing material.   
     
     
         18 . The method of  claim 17 , wherein:
 the clay is selected from the group consisting of bentonite, montmorillonite, smectite, nontronite, beidellite, perlite and vermiculite clays and combinations of these; and   the superabsorbing material is selected from the group consisting of polymers and copolymers of acrylate, acrylic acid, amide, acrylamide, saccharides, vinyl alcohol, urethane, and combinations of these materials.   
     
     
         19 .- 21 . (canceled) 
     
     
         22 . The method of  claim 11 , wherein:
 the delayed water-swelling particles contain a weighting material.   
     
     
         23 . The method of  claim 22 , wherein:
 the weighting material is selected from the group consisting of silicates, aluminosilicates, barite, hematite, ilmenite, manganese tetraoxide, manganosite, iron, lead, aluminum and combinations of these.   
     
     
         24 . The method of  claim 11 , wherein:
 the delayed water-swelling particles are formed from particles having an inner core of proppant material with a layer of the delayed water absorbent material formed around the proppant material.   
     
     
         25 .- 26 . (canceled) 
     
     
         27 . The method of  claim 11 , wherein:
 the slurry is introduced into the wellbore during or subsequent to introduction of a PAD fluid of a fracturing treatment; and wherein   the carrier fluid of the slurry has a specific gravity that is at least one of greater or less than the specific gravity of the PAD fluid.   
     
     
         28 . The method of  claim 27 , wherein:
 the slurry contains materials that provide buoyancy of the slurry within the PAD fluid.   
     
     
         29 . The method of  claim 28 , wherein:
 the buoyancy providing materials comprise at least one of polymer particles, hollow beads, ceramic materials, porous particles, fibers and foaming agents.   
     
     
         30 . The method of  claim 27 , wherein:
 the carrier fluid comprises the PAD fluid.   
     
     
         31 . The method of  claim 27 , wherein:
 the carrier fluid is immiscible with the PAD fluid.   
     
     
         32 . The method of  claim 27 , wherein:
 the carrier fluid is miscible with the PAD fluid.   
     
     
         33 . The method of  claim 11 , wherein:
 the carrier fluid comprises at least one of a drilling mud or a completion brine.   
     
     
         34 . A method of treating a formation penetrated by a wellbore comprising:
 providing a quantity of particles comprising delayed water-swelling particles formed at least in part from a water-swelling material;   forming a slurry of the particles with a carrier fluid; and   introducing the slurry into the wellbore during or subsequent to introduction of a PAD fluid of a fracturing treatment, wherein   the carrier fluid of the slurry has a specific gravity that is at least one of greater or less than the specific gravity of the PAD fluid.   
     
     
         35 . The method of  claim 34 , wherein:
 the slurry contains materials that provide buoyancy of the slurry within the PAD fluid.   
     
     
         36 . The method of  claim 35 , wherein:
 the buoyancy providing materials comprise at least one of polymer particles, hollow beads, ceramic materials, porous particles, fibers and foaming agents.   
     
     
         37 . The method of  claim 34 , wherein:
 the carrier fluid comprises the PAD fluid.   
     
     
         38 . The method of  claim 34 , wherein:
 the particles comprise non-water-swelling particles.   
     
     
         39 . The method of  claim 38 , wherein:
 non-water-swelling particles of at least two different size distributions are used wherein the mean particle size of the larger non-water-swelling particles is at least 1.5 times greater than that of the smaller non-water-swelling particles.   
     
     
         40 . The method of  claim 38 , wherein:
 the non-water-swelling particles comprise coarse particles having a particle size of from about 0.2 mm to about 2.35 mm and at least one of fine particles having a particle size of less than about 0.1 mm and medium particles having a particle size of from about 0.1 mm to less than about 0.2 mm.   
     
     
         41 . The method of  claim 34 , wherein:
 the water-swelling material comprises at least one of a clay and a superabsorbing material.   
     
     
         42 . The method of  claim 41 , wherein:
 the clay is selected from the group consisting of bentonite, montmorillonite, smectite, nontronite, beidellite, perlite and vermiculite clays and combinations of these; and   the superabsorbing material is selected from the group consisting of polymers and copolymers of acrylate, acrylic acid, amide, acrylamide, saccharides, vinyl alcohol, urethane, and combinations of these materials.   
     
     
         43 .- 45 . (canceled) 
     
     
         46 . The method of  claim 34 , wherein:
 the delayed water-swelling particles contain a weighting material.   
     
     
         47 . The method of  claim 46 , wherein:
 the weighting material is selected from the group consisting of silicates, aluminosilicates, barite, hematite, ilmenite, manganese tetraoxide, manganosite, iron, lead, aluminum and combinations of these.   
     
     
         48 . The method of  claim 34 , wherein:
 the delayed water-swelling particles are formed from particles having an inner core of proppant material with a layer of the delayed water absorbent material formed around the proppant material.   
     
     
         49 .- 50 . (canceled) 
     
     
         51 . The method of  claim 34 , wherein:
 the carrier fluid is immiscible with the PAD fluid.   
     
     
         52 . The method of  claim 34 , wherein:
 the carrier fluid is miscible with the PAD fluid.   
     
     
         53 . A method of treating a formation penetrated by a wellbore comprising:
 providing a quantity of delayed water-swelling particles having a core of a water-swelling material and wherein the core has a coating substantially surrounding the core that temporarily prevents contact of water with the water-swelling material, the coating being formed from at least one of (1) a layer or layers of water degradable material and (2) a layer or layers of non-water-degradable, non-water absorbent encapsulating material;   forming a slurry of the particles with a carrier fluid; and   introducing the slurry of particles into the wellbore of the formation.   
     
     
         54 . The method of  claim 53 , wherein:
 non-water-swelling particles are provided with the delayed water-swelling particles.   
     
     
         55 . The method of  claim 53 , wherein:
 the slurry of particles is positioned within a fracture of the formation.   
     
     
         56 . The method of  claim 53 , wherein:
 the water-swelling material is capable of absorbing at least the water-swelling material's weight of water.   
     
     
         57 . The method of  claim 54 , wherein:
 the non-water-swelling particles have a particle size of from about 0.035 mm to about 2.35 mm.   
     
     
         58 . The method of  claim 54 , wherein:
 non-water-swelling particles of at least two different size distributions are used wherein the mean particle size of the larger non-water-swelling particles is at least 1.5 times greater than that of the smaller non-water-swelling particles.   
     
     
         59 . The method of  claim 54 , wherein:
 the non-water-swelling particles comprise coarse particles having a particle size of from about 0.2 mm to about 2.35 mm and at least one of fine particles having a particle size of less than about 0.1 mm and medium particles having a particle size of from about 0.1 mm to less than about 0.2 mm.   
     
     
         60 . (canceled) 
     
     
         61 . The method of  claim 53 , wherein:
 the particles have a specific gravity that is at least one of greater or less than the specific gravity of the carrier fluid.   
     
     
         62 . The method of  claim 53 , wherein:
 the water-swelling material comprises at least one of a clay and a superabsorbing material.   
     
     
         63 . The method of  claim 62 , wherein:
 the clay is selected from the group consisting of bentonite, montmorillonite, smectite, nontronite, beidellite, perlite and vermiculite clays and combinations of these; and   the superabsorbing material is selected from the group consisting of polymers and copolymers of acrylate, acrylic acid, amide, acrylamide, saccharides, vinyl alcohol, urethane, and combinations of these materials.   
     
     
         64 .- 66 . (canceled) 
     
     
         67 . The method of  claim 53 , wherein:
 the delayed water-swelling particles contain a weighting material.   
     
     
         68 . The method of  claim 67 , wherein:
 the weighting material is selected from the group consisting of silicates, aluminosilicates, barite, hematite, ilmenite, manganese tetraoxide, manganosite, iron, lead, aluminum and combinations of these.   
     
     
         69 . The method of  claim 53 , wherein:
 the delayed water-swelling particles are formed from particles having an inner core of proppant material with a layer of the delayed water absorbent material formed around the proppant material.   
     
     
         70 .- 77 . (canceled) 
     
     
         78 . The method of  claim 53 , wherein:
 the carrier fluid comprises at least one of a drilling mud or a completion brine.   
     
     
         79 . A method of treating a subterranean formation immediately surrounding a wellbore penetrating the formation to reduce lost fluid circulation during drilling operations comprising:
 providing a quantity of particles comprising delayed water-swelling particles formed at least in part from a water-swelling material;   forming a slurry of the particles with a carrier fluid; and   introducing the slurry into the wellbore at a pressure sufficient to fracture a portion of the formation.   
     
     
         80 . The method of  claim 79 , wherein:
 the carrier fluid comprises at least one of a drilling mud or a completion brine.   
     
     
         81 . The method of  claim 79 , wherein:
 the delayed water-swelling particles comprise superabsorbing particles in a carrier fluid of one of a non-aqueous fluid, an emulsion and an aqueous metal salt solution that delays absorption of water.   
     
     
         82 . The method of  claim 79 , wherein:
 the particles also comprise non-water-swelling particles.   
     
     
         83 . The method of  claim 82 , wherein:
 non-water-swelling particles of at least two different size distributions are used wherein the mean particle size of the larger non-water-swelling particles is at least 1.5 times greater than that of the smaller non-water-swelling particles.   
     
     
         84 . The method of  claim 82 , wherein:
 the non-water-swelling particles comprise coarse particles having a particle size of from about 0.2 mm to about 2.35 mm and at least one of fine particles having a particle size of less than about 0.1 mm and medium particles having a particle size of from about 0.1 mm to less than about 0.2 mm.   
     
     
         85 . The method of  claim 79 , wherein:
 the water-swelling material comprises at least one of a clay and a superabsorbing material.   
     
     
         86 . The method of  claim 85 , wherein:
 the clay is selected from the group consisting of bentonite, montmorillonite, smectite, nontronite, beidellite, perlite and vermiculite clays and combinations of these; and   the superabsorbing material is selected from the group consisting of polymers and copolymers of acrylate, acrylic acid, amide, acrylamide, saccharides, vinyl alcohol, urethane, and combinations of these materials.   
     
     
         87 .- 89 . (canceled) 
     
     
         90 . The method of  claim 79 , wherein:
 the delayed water-swelling particles are formed from particles having an inner core of proppant material with a layer of the delayed water absorbent material formed around the proppant material.   
     
     
         91 . (canceled) 
     
     
         92 . The method of  claim 79 , further comprising:
 circulating a drilling fluid within the wellbore during drilling after introduction of the slurry.   
     
     
         93 . The method of  claim 79 , further comprising:
 introducing a cement into the wellbore after introduction of the slurry.   
     
     
         94 . The method of  claim 79 , further comprising:
 introducing a further well treatment fluid into the wellbore after introduction of the slurry.   
     
     
         95 . A method of positioning materials in a formation penetrated by a wellbore comprising:
 providing a quantity of particles;   forming a slurry of the particles with a carrier fluid;   introducing the slurry of particles into the wellbore of the formation; and   introducing a second fluid into the wellbore of the formation prior to or subsequent to the slurry, wherein   the carrier fluid of the slurry has a specific gravity that is at least one of greater or less than the specific gravity of the second fluid.   
     
     
         96 . The method of  claim 95 , wherein:
 the slurry contains materials that provide buoyancy of the slurry within the second fluid.   
     
     
         97 . The method of  claim 96 , wherein:
 the buoyancy providing materials comprise at least one of polymer particles, hollow beads, ceramic materials, porous particles, fibers and foaming agents.   
     
     
         98 . The method of  claim 95 , wherein:
 the carrier fluid is immiscible with the second fluid.   
     
     
         99 . The method of  claim 95 , wherein:
 the carrier fluid is miscible with the second fluid.