Abstract: A fracturing fluid is injected under a high pressure into a well drilled in a formation to create a hydraulic fracture. Then a suspension of the hydraulic fracturing fluid mixed with proppant particles is injected into the well and the created hydraulic fracture, the suspension having a consistency coefficient greater than 0.1 Pa sn at any flow index n and a yield stress higher than 5 Pa. Then, an overflush fluid having a consistency coefficient lower than 0.01 Pa·sn is injected into the well.

Abstract: A method for preventing formation of a slug flow regime of a gas-liquid mixture in a non-linear wellbore or a pipeline comprises determining at least one most probable place of fluid slugs development in the wellbore or the pipeline by mathematical simulation based on expected values of the gas-liquid mixture flow and known geometry of the wellbore or the pipeline and mounting a device, in the determined place of fluid slug development, that converts the stratified gas-liquid mixture flow into a dispersed flow.

Abstract: To create stable conductive channels in propped fractures a first fracturing fluid free of proppant particles is injected into a wellbore and then a second fracturing fluid which is a suspension of proppant particles is injected into the wellbore. The second fluid possesses a yield stress and an aging behavior. A ratio of viscosity of the first fluid to viscosity of the second fluid is not less than 0.1. Then, a third fracturing fluid free of proppant particles is injected into the wellbore, a ratio of the viscosity of the first fluid to viscosity of the third fluid being not less than 0.1, and a ratio of densities of the first and the third fluid being from 0.8 to 1.2. The second fracturing fluid is re-injected into the wellbore, and then the third fracturing fluid is re-injected.

Abstract: The method for orienting hydraulic fractures in a subterranean formation comprises injecting a first fluid into a first horizontal wellbore penetrating the subterranean formation and open to the formation in at least one specified segment and pressurizing the first fluid in the first wellbore to create a stress field around each specified segment of the first wellbore. A second pressurized fracturing particle-laden fluid is simultaneously injected into a second horizontal wellbore open to the formation in at least one specified segment and vertically spaced apart from the first wellbore for inducing fractures propagating from the specified segments of the second wellbore towards the specified pressurized segments of the first wellbore.

Abstract: To improve the accuracy of multiphase mixture flow rate measurements, properties of a multiphase mixture are determined under conditions expected inside a pipeline and flow regimes are determined for the expected flow rates. Slug reducing parameters of the pipeline are provided at a pipeline section and a flowmeter is installed at the end of that pipeline section.

Abstract: Method of a formation hydraulic fracturing provides injection of a hydraulic fracturing fluid into a borehole with the increase of a fluid flow rate to a working value. During the injection a power consumption of a pump used for the injection is measured continuously. A pump power consumption jump indicates the fracturing fluid flow turbulization in the borehole.

Abstract: Method of a formation hydraulic fracturing provides injection of a hydraulic fracturing fluid into a borehole with the increase of a fluid flow rate to a working value. During the injection a power consumption of a pump used for the injection is measured continuously. A pump power consumption jump indicates the fracturing fluid flow turbulization in the borehole.

Abstract: A method is given for creating a fracture, in a subterranean formation, that has a fluid flow barrier at the top, at the bottom, or at both the top and the bottom. The method is applied before or during a conventional hydraulic fracturing treatment and is used to limit undesired vertical growth of a fracture out of the productive zone. A lower-viscosity pad fluid is used to initiate the fracture; a higher-viscosity fluid containing barrier particles is then injected; a lower-viscosity particle-free fluid is then injected to promote settling (or rising) of the barrier particles and to finger through the slug of barrier particles and cut it into an upper and lower portion. If the barrier is to be at the bottom of the fracture, the barrier particles are denser than the fluids; if the barrier is to be at the top of the fracture, the barrier particles are less dense than the fluids.