Abstract: A storable composition for oilfield application including a slurry of a carrier fluid and a particulate blend made of proppant; the particulate blend comprising at least a first amount of particulates having a first average particle size between about 100 and 5000 ?m and at least 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 0.74 and the particulate blend volume is sufficient to substantially avoid settling of the particulate in the carrier fluid.

Abstract: A composition, treatment fluid and method using hydrolyzable fines. A treatment fluid, which may optionally include a high solids content fluid (HSCF) and/or an Apollonianistic solids mixture, includes a fluid loss control agent comprising a dispersion of hydrolyzable fines, optionally with one or more of a surfactant, plasticizer, dispersant, degradable particles, reactive particles and/or submicron particles selected from silicates, ?-alumina, MgO, ?-Fe2O3, TiO2, and combinations thereof.

Abstract: A technique includes completing a well, including installing a tubing string that includes a screen in the well and installing a fiber-based material outside of the screen. The technique further includes using the well as an injection well, including communicating a fluid into the tubing string to cause an injection flow to be communicated in a fluid flow path from an interior of the tubing string, through the screen and into a formation.

Abstract: Treatment fluids and methods for treating a subterranean formation are disclosed that include introducing a treatment fluid into a subterranean formation, the treatment fluid containing temporarily inactive cellulose nanoparticles.

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 method of placing proppant into a fracture formed in a subterranean formation from a wellbore is disclosed. The method comprises injecting through the wellbore a first treatment fluid to initiate the fracture in the subterranean formation; injecting through the wellbore a second treatment fluid comprising a particulate blend slurry made of proppant; the particulate blend comprising at least a first amount of particulates having a first average particle size between about 100 and 5000 ?m and at least a second amount of particulates having a second average particle size between about three and twenty times smaller than the first average particle size; and forming with the particulate blend slurry a plurality of proppant-rich clusters spaced apart by proppant-free regions forming open channels.

Abstract: A method for forming proppant aggregates, for example downhole in an injection well, includes injecting a slurry including a thermo-responsive polymer with a low critical solution temperature and a proppant downhole, and heating the slurry above the low critical solution temperature of the polymer. The heating of the slurry above the low critical solution temperature of the polymer aggregates the proppant. A composition of the slurry includes a carrier fluid including a thermo-responsive polymer, a proppant, and optional additives.

Abstract: A method to improve fluid flow in a hydraulic fracture from a subterranean formation which includes the steps of (1) formulating a slurry which comprises (a) proppant particles, (b) a carrier fluid, and (c) low density particles, wherein the fluid is capable of undergoing a transformation to cause an agglomeration of two or more proppant particles and/or low density particles; and (2) injecting the slurry into the formation; and (3) the agglomeration of the proppant particles and/or low density particles, is provided.

Abstract: A composition, treatment fluid and method using hydrolyzable fines. A treatment fluid, which may optionally include a high solids content fluid (HSCF) and/or an Apollonianistic solids mixture, includes a fluid loss control agent comprising a dispersion of hydrolyzable fines, optionally with one or more of a surfactant, plasticizer, dispersant, degradable particles, reactive particles and/or submicron particles selected from silicates, ?-alumina, MgO, ?-Fe2O3, TiO2, and combinations thereof.

Abstract: Treatment fluids and methods for treating a subterranean formation include introducing a treatment fluid into a subterranean formation, the treatment fluid containing a nanocrystalline cellulose. The treatment fluid may be a fracturing fluid, well control fluid, well kill fluid, well cementing fluid, acid fracturing fluid, acid diverting fluid, a stimulation fluid, a sand control fluid, a completion fluid, a wellbore consolidation fluid, a remediation treatment fluid, a spacer fluid, a drilling fluid, a frac-packing fluid, water conformance fluid or a gravel packing fluid.

Abstract: A method includes providing a slurry comprising a carrier fluid and a solids mixture, and injecting said slurry in a wellbore wherein the solids mixture comprises at least two 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 (PVF) of the solids mixture exceeds 0.75.

Abstract: High solids content slurry, systems and methods. The slurry comprises a carrier fluid and a solids mixture of first, second, third and fourth particle size distribution (PSD) modes wherein the first PSD mode is at least three times larger than the second PSD mode, which is larger than the third PSD mode, which is larger than the fourth PSD mode, and wherein at least one of the second and third PSD modes is less than 3 times larger than the respective third or fourth PSD mode. The method comprises forming the slurry, positioning a screen in a wellbore and circulating the slurry through the wellbore such that the solids mixture is deposited between the screen and the wellbore. The system comprises a pump to circulate the slurry, a workstring to position the screen and means for converting the slurry to a gravel pack.

Abstract: A composition, treatment fluid and method using hydrolyzable fines. A treatment fluid, which may optionally include a high solids content fluid (HSCF) and/or an Apollonianistic solids mixture, includes a fluid loss control agent comprising a dispersion of hydrolyzable fines, optionally with one or more of a surfactant, plasticizer, dispersant, degradable particles, reactive particles and/or submicron particles selected from silicates, ?-alumina, MgO, ?-Fe2O3, TiO2, and combinations thereof.

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: 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 of placing proppant into a fracture formed in a subterranean formation from a wellbore is disclosed. The method comprises injecting through the wellbore a first treatment fluid to initiate the fracture in the subterranean formation; injecting through the wellbore a second treatment fluid comprising a particulate blend slurry made of proppant; the particulate blend comprising at least a first amount of particulates having a first average particle size between about 100 and 5000 ?m and at least a second amount of particulates having a second average particle size between about three and twenty times smaller than the first average particle size; and forming with the particulate blend slurry a plurality of proppant-rich clusters spaced apart by proppant-free regions forming open channels.

Abstract: The application discloses a storable composition for oilfield application including a slurry of a carrier fluid and a particulate blend made of proppant; the particulate blend comprising at least a first amount of particulates having a first average particle size between about 100 and 5000 ?m and at least 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 0.74 and the particulate blend volume is sufficient to substantially avoid settling of the particulate in the carrier fluid.

Abstract: A method for treating a subterranean formation penetrated by a wellbore comprising combining a carrier fluid, a first amount of particulates, and a second amount of particulates into a slurry, wherein the first amount of particulates have a first average size distribution and the second amount of particulates have a second average size distribution, wherein at least one of the first amount of particulates and the second amount of particulates comprise an expanding material, placing the slurry in the wellbore, and lowering a screen into the slurry.

Abstract: High solids content slurry, systems and methods. The slurry comprises a carrier fluid and a solids mixture of first, second, third and fourth particle size distribution (PSD) modes wherein the first PSD mode is at least three times larger than the second PSD mode, which is larger than the third PSD mode, which is larger than the fourth PSD mode, and wherein at least one of the second and third PSD modes is less than 3 times larger than the respective third or fourth PSD mode. The method comprises forming the slurry, positioning a screen in a wellbore and circulating the slurry through the wellbore such that the solids mixture is deposited between the screen and the wellbore. The system comprises a pump to circulate the slurry, a workstring to position the screen and means for converting the slurry to a gravel pack.

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.