Abstract: A method for treating a subterranean formation penetrated by a wellbore, comprising: providing a treatment slurry comprising a carrying fluid, a solid particulate and an anchorant; injecting the treatment slurry into a fracture to form a substantially uniformly distributed mixture of the solid particulate and the anchorant; and transforming the substantially uniform mixture into areas that are rich in solid particulate and areas that are substantially free of solid particulate, wherein the solid particulate and the anchorant have substantially dissimilar velocities in the fracture and wherein said transforming results from said substantially dissimilar velocities is provided.

Abstract: Methods of treating a subterranean formation penetrated by a well bore, by providing a treatment fluid comprising a blend including a first amount of particulates having a first average particle size between about 3 mm and 2 cm and a second amount of particulates having a second average size between about 1.6 and 20 times smaller than the first average particle size or a second amount of flakes having a second average size up to 10 times smaller than the first average particle size; by introducing the treatment fluid into the well bore; and by creating a plug with the treatment fluid.

Abstract: Methods and apparatuses for hydraulically fracturing a subterranean wellbore while drilling and/or tripping are disclosed. A method for hydraulically fracturing a subterranean formation may include rotating a drill string to drill the wellbore and hydraulically fracturing the subterranean formation at a plurality of axially spaced locations along the wellbore while tripping the drill string out of the wellbore. The drill string may include a hydraulic fracturing assembly. The hydraulic fracturing operation may include translating the drill string in an uphole direction so that a set of frac ports in the hydraulic fracturing assembly is adjacent a region of the formation selected for fracturing, expanding at least one pair of packers to seal an annular region of the wellbore exterior to the frac ports, and pumping fracturing fluid downhole through the frac ports to hydraulically fracture the subterranean formation.

Abstract: Proppant cluster placement in fractures with foamed carrying fluid. A formation treatment method includes injecting a treatment fluid stage, having a particulate-containing substage containing a self-agglomerating solid composition and a foamed carrying fluid, above a fracturing pressure, and alternating pulses of a pumping parameter to transform the self-agglomerating composition into a channelized solids pack, and closing the fracture. Also disclosed are methods of modeling a fracture treatment interval for such a method, and methods of treatment and systems to treat with such a treatment fluid stage, wherein solid particulate-rich substages are larger than the solid particulate-lean substages to form particulate-rich island regions, an interconnected network of open channel regions between the island regions and the island regions are channelized to form particulate clusters within the island regions separated from adjacent particulate clusters by open voids in the island regions.

Abstract: Compound cluster placement in fractures. A fracture treatment method includes forming propped regions having a larger coverage area than channels between the propped regions, and channelizing the propped regions in situ. Also disclosed are systems to treat a fracture interval and to produce reservoir fluids from a formation.

Abstract: Hybrid gas fracturing methods and systems utilizing an early stage gas treatment fluid, which may contain a dispersed phase of fluid loss control agent particles, followed by a proppant stage(s) to form a fracture system having a branched tip region and a propped region between the branched tip region and the wellbore. Also, treatment fluids suitable for use in the methods and systems are disclosed.

Abstract: Gas fracturing methods and systems utilizing a gas treatment fluid, which may contain a dispersed phase of fluid loss control agent particles. Also, treatment fluids suitable for use in the methods and systems are disclosed.

Abstract: Swellable ball sealers comprising swellable material are described. A swellable ball sealer may be used as a diversion agent by being suspended in a fluid injected into a wellbore and swelling once seated on a perforation such that the swellable ball sealer adapts to the shape of a perforation opening on which the swellable ball sealer has seated.

Abstract: A method and system for increasing fracture conductivity. A treatment slurry stage has a continuous first solid particulate concentration and a discontinuous anchorant concentration between anchorant-rich substages and anchorant-lean substages within the treatment slurry stage.

Abstract: Electromagnetically active slurries comprising stabilized fluids and methods of using the stabilized, electromagnetically active slurries in fluid flow control and detection. Also, methods, fluids, equipment and/or systems for treating a subterranean formation penetrated by a wellbore, relating to treatment fluids based on the stabilized, electromagnetically active slurries.

Abstract: Methods of treating a subterranean formation penetrated by a well bore, by providing a treatment fluid comprising a blend including a first amount of particulates having a first average particle size between about 3 mm and 2 cm and a second amount of particulates having a second average size between about 1.6 and 20 times smaller than the first average particle size or a second amount of flakes having a second average size up to 10 times smaller than the first average particle size; by introducing the treatment fluid into the well bore; and by creating a plug with the treatment fluid.

Abstract: Proppant pillar placement in a fracture with a stabilized slurry treatment fluid. A method of placing a proppant pack by injecting a well treatment fluid comprising proppant and a stabilized slurry, and a slurry destabilizing system to consolidate solids from the slurry, and placing the proppant in the fracture in a plurality of proppant clusters forming pillars spaced apart by fluid flow channels from the formation through the fracture toward the wellbore. Also, a system for implementing the method, and the propped fracture system obtained as a result of placing the proppant pack into the fracture according to the method.

Abstract: A method is given for diverting injected slickwater in a hydraulic fracturing treatment. The diversion fluid is preferably a substantially proppant free viscous fluid that causes a net pressure increase and plugging of some of the microfractures in the initial fracture system created, which induces formation of supplementary microfractures connected to the initial fracture network and in-creases the contact area with the formation rock. The method generates a greater fracture network complexity and thus a higher contact area with the reservoir during a single treatment cycle.