Abstract: The invention discloses a method of treating a subterranean formation of a well bore, comprising: providing a treatment fluid comprising a carrier fluid, proppant, a viscosifying agent and a viscosifier material, wherein the viscosifier material is inactive in a first state and is able to increase viscosity of the treatment fluid when in a second state; introducing the treatment fluid into the wellbore; and, allowing the treatment fluid to interact with a trigger able to activate the viscosifier material from first state to second state.

Abstract: A system includes a hydraulic fracturing fluid including a polymeric constituent and an additive having particles including poly-vinyl acetate in an amount sufficient to control fluid loss. The system includes a formation of interest having a downhole temperature, and the particles including poly-vinyl acetate have a size and/or shape such that the poly-vinyl acetate hydrolyses at the downhole temperature. The particles may have a size and/or shape such that the particles are deformable at the downhole temperature. The poly-vinyl acetate in the particles may be a part of the particle substrate, a coating on the particles, and/or the entire particle may be poly-vinyl acetate. The poly-vinyl acetate may be included in any portion of the hydraulic fracturing fluid, or only the portion of the hydraulic fracturing fluid that is not proppant laden.

Abstract: A method and system are disclosed for low damage gravel packing. The method comprises: combining a carrier fluid and a solids mixture into a slurry, wherein the solids mixture comprises a plurality of particle size distribution modes such that a packed volume fraction exceeds 0.75; contacting a screen with leak-off control agent to form a bridge; positioning the screen and circulating the slurry through the wellbore in any order such that the solids mixture is deposited between the screen and the wellbore; degrading the degradable material to increase porosity and permeability of the pack; removing the bridge; and producing a reservoir fluid from the formation. The system comprises the slurry, a tubing string and slurry pump to position the screen and circulate the slurry to form the bridge on the screen.

Abstract: A slurry and method are disclosed for low damage gravel packing. The slurry comprises a solids mixture comprising a plurality of volume-averaged particle size distribution (PSD) modes such that a packed volume fraction (PVF) exceeds 0.75; a carrier fluid in an amount to provide a solids volume fraction (SVF) less than the PVF of the solids mixture; and a stability additive to inhibit settling of the solids mixture. The method comprises circulating the slurry into a wellbore to deposit the slurry downhole; terminating the slurry circulation for a period of time, wherein the stability additive inhibits settling of the solids mixture; and thereafter circulating the deposited slurry in contact with a surface of a screen. Stability additives disclosed include colloidal particles, hydratable polymer particles, and particles having an aspect ratio above 6.

Abstract: The invention discloses a method of controlling fluid loss from a subterranean formation of a well bore. In a first aspect, the method is done by providing a treatment fluid made of an aqueous fluid and a hydrophobic polymer; and introducing the treatment fluid into the wellbore. In a second aspect, the method is done by providing a treatment fluid made of water and a water soluble polymer; providing in the treatment fluid a fluid loss additive having a hydrophobic polymer; using the treatment fluid in a well bore of a subterranean formation; allowing the treatment fluid to establish a permeable filter cake with the water soluble polymer in at least a portion of the well bore; and allowing hydrophobic polymer to enter into the filter cake to reduce permeability of the filter cake.

Abstract: The invention discloses a method of treating a subterranean formation of a well bore: providing a treatment fluid made of: a fluid; a particulate material, and a viscosifier material; wherein the viscosifier material is inactive in a first state and is able to increase viscosity of the treatment fluid when in a second state; introducing the treatment fluid into the wellbore; and providing a trigger able to activate the viscosifier material from first state to second state.

Abstract: The invention discloses a method of treating a subterranean formation of a well bore: providing a treatment fluid made of: a fluid; a particulate material, and a viscosifier material; wherein the viscosifier material is inactive in a first state and is able to increase viscosity of the treatment fluid when in a second state; introducing the treatment fluid into the wellbore; and providing a trigger able to activate the viscosifier material from first state to second state.

Abstract: The invention discloses a method of controlling fluid loss from a subterranean formation of a well bore. In a first aspect, the method is done by providing a treatment fluid made of an aqueous fluid and a hydrophobic polymer; and introducing the treatment fluid into the wellbore. In a second aspect, the method is done by providing a treatment fluid made of water and a water soluble polymer; providing in the treatment fluid a fluid loss additive having a hydrophobic polymer; using the treatment fluid in a well bore of a subterranean formation; allowing the treatment fluid to establish a permeable filter cake with the water soluble polymer in at least a portion of the well bore; and allowing hydrophobic polymer to enter into the filter cake to reduce permeability of the filter cake.

Abstract: A method of fracturing a subterranean formation comprising at least in part shale formation, comprises providing a carrier fluid; providing a particulate blend including a first amount of particulates having a first average particle size between about 100 and 2000 microns and a second amount of particulates having a second average particle size between about three and twenty times smaller than the first average particle size, such that a packed volume fraction of the particulate blend exceeds 0.75; combining the carrier fluid and the particulate blend into a fracturing slurry; fracturing the formation with the fracturing slurry to create at least a fracture; and removing the second amount of particulates from the fracture.

Abstract: A method is disclosed where introducing into a wellbore a degradable material stabilized in a non-aqueous based fluid.

Abstract: A composition and method are disclosed. The composition includes a carrier fluid and a solids mixture combined to form a slurry, wherein the solids mixture comprises a plurality of volume-averaged particle size distribution (PSD) modes, wherein a first PSD mode comprises solids having a volume-average median size at least three times larger than the volume-average median size of a second PSD mode such that a packed volume fraction of the solids mixture exceeds 0.75, and wherein the solids mixture comprises a degradable material and includes a reactive solid. The method includes circulating the slurry through a wellbore to form a pack in a fracture and/or a screen-wellbore annulus; degrading the degradable material to increase porosity and permeability of the pack; and producing a reservoir fluid through the permeable pack.

Abstract: A gravel packing system, method and slurry. The system comprises a blending device to prepare a slurry comprising a carrier fluid suspending first, second and third particulates, wherein the carrier fluid comprises a brine and less than about 2.4 g/L (20 lb per 1000 gallons) of a viscosifier, and wherein the sum of the mass of the particulates is greater than about 2.4 kg/L (20 pounds per gallon), wherein the first average particle volume is between 27 and 3375 times larger than the second average particle volume, which in turn is between 27 and 3375 times larger than the third average particle volume. The system can also include tubing to position a screen in the wellbore and a slurry pump to circulate the slurry from the blending device in the wellbore in any order such that the particulates are deposited in the screen annulus to form a gravel pack.

Abstract: A method is disclosed for low damage gravel packing. The method includes combining a carrier fluid, a first amount of particulates, and a second amount of particulates into a slurry. The first amount of particulates have a first average size distribution and the second amount of particulates have a second average size distribution, and the first average size distribution is at least three times larger than the second average size distribution. The slurry includes particles which are at least partially degradable material, and with reactive solid constituents. The reactive solid reacts with the degradable material and/or a hydrolysis product of the degradable material. The method further includes positioning a screen in a wellbore, and circulating the slurry through the wellbore such that the first amount of particulates and the second amount of particulates are deposited on an outer surface of the screen.

Abstract: A system includes a wellbore in fluid communication with a formation of interest and a fracturing slurry include a carrier fluid with a low amount of a viscosifier, an amount of proppant including a first average particle size between about 200 and 2000 ?m, an amount particulates including a second average particle size between about three and ten times smaller than the first average particle size, and a third amount of particulates having a third average particle size smaller than the second average particle size. A sum of all of the particulates in the fracturing slurry exceed about 16 pounds per gallon of the carrier fluid. They system further includes a pumping device that creates a propped fracture in the formation of interest with the fracturing slurry, and a removal agent that removes the second amount of particulates and/or the third amount of particulates from the propped fracture.

Abstract: A system includes a hydraulic fracturing fluid including a polymeric constituent and an additive having particles including poly-vinyl acetate in an amount sufficient to control fluid loss. The system includes a formation of interest having a downhole temperature, and the particles including poly-vinyl acetate have a size and/or shape such that the poly-vinyl acetate hydrolyses at the downhole temperature. The particles may have a size and/or shape such that the particles are deformable at the downhole temperature. The poly-vinyl acetate in the particles may be a part of the particle substrate, a coating on the particles, and/or the entire particle may be poly-vinyl acetate. The poly-vinyl acetate may be included in any portion of the hydraulic fracturing fluid, or only the portion of the hydraulic fracturing fluid that is not proppant laden.

Abstract: A fluid loss control method uses a fluid loss control pill in a well in advance of a completion operation. An embodiment of the fluid loss control pill comprises polyester solids that are hydrolysable and can exhibit plastic deformation at formation conditions. An embodiment of the method comprises spotting the fluid loss control pill in the well adjacent to a formation to form a filtercake to inhibit fluid entry from the well into the formation, performing a completion operation comprising contacting the filtercake with overbalanced wellbore fluid, and degrading the filtercake wherein the polyester particles are hydrolyzed to remove formation damage.

Abstract: A method of controlling leak-off and reducing the concentration of polymers (and/or other materials) in filter cakes formed when oilfield treatment fluids flow through subterranean formation faces involves adding large plate-like degradable and/or non-degradable, particles to polymer or VES-viscosified oilfield treatment fluids, at concentrations of such particles that are less than that required to cover the contacted formation face with a monolayer of such particles. When these large plate-like degradable and/or non-degradable particles are included in the fluid, polymer concentrates to form filter cake only in regions on the formation face (for example fracture faces) not shielded by the large plate-like particles, and the remaining formation face is not covered by concentrated polymer. As a result, the damage due to concentration of polymer and/or other materials in the filter cake during leak-off is reduced, and subsequent clean-up of the filter cake is easier.

Abstract: A method is described for treating a subterranean formation with a low viscosity fluid system that contains a viscoelastic surfactant at a concentration too low to viscosify the fluid, but that is concentrated in the formation so that the fluid system gels. The fluid also contains a formation-dissolving agent. The fluid is used in acidizing, acid fracturing, and diversion.

Abstract: Disclosed are methods of modeling stimulation treatments, such as designing matrix treatments for subterranean formations penetrated by a wellbore, to enhance hydrocarbon recovery. The modeling methods describe the growth rate and the structure of the dissolution pattern formed due to the injection of a treatment fluid in a porous medium, based on calculating the length scales for dominant transport mechanism(s) and reaction mechanism(s) in the direction of flow lX and the direction transverse to flow lT. Methods of the invention may further include introducing a treatment fluid into the formation, and treating the formation.

Abstract: A method is disclosed for low damage gravel packing. The method includes combining a carrier fluid, a first amount of particulates, and a second amount of particulates into a slurry. The first amount of particulates have a first average size distribution and the second amount of particulates have a second average size distribution, and the first average size distribution is at least three times larger than the second average size distribution. The slurry includes particles which are at least partially degradable material, and with reactive solid constituents. The reactive solid reacts with the degradable material and/or a hydrolysis product of the degradable material. The method further includes positioning a screen in a wellbore, and circulating the slurry through the wellbore such that the first amount of particulates and the second amount of particulates are deposited on an outer surface of the screen.