Abstract: A method moves a tube wave reflector in a well, generates a tube wave, receives a reflection, and determines the depth of one or more reflector locations from the elapsed time. Also, a method to locate a feature in a well deploys a bottom hole assembly (BHA), generates acoustic noise from the BHA, and autocorrelates to determine the BHA depth. Also, a system has a coiled tubing string to a BHA, a surface wave generator, a surface and/or distributed receiver, and a recorder to determine elapsed times between generation and receipt.

Abstract: Methods of treating a subterranean formation penetrated by a well bore, by providing a first acidic treatment fluid comprising fibers to fracture the formation and providing a non-acidic treatment fluid comprising multiple particle size acid precursors having a first average particle size between about 3 mm and 2 cm and a second amount of acid precursors 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.

Abstract: In one aspect, a method of optimizing a sequenced hydraulic fracturing treatment to be performed on a well includes predicting, based on a well model of the well and a hydraulic fracturing treatment schedule, a seal state of a perforation cluster. The method may further include updating, based on the predicted seal state, a pilling operation of a stage of the hydraulic fracturing treatment schedule. The method may further include modifying the sequenced hydraulic fracturing treatment schedule to be performed based on the updated pilling operation. The well model includes a geomechanical model of the well and a geological formation.

Abstract: Aqueous compositions contain hydrochloric acid at a concentration between 8 wt % and 28 wt % inclusive. The amino acid; hydrochloric acid mole ratio may be between 0.2 and 1.5. Sufficient water is present to dissolve the hydrochloric acid and the amino acid. Such compositions have utility as retarders for acid compositions employed in the stimulation of subterranean formations. Slowing the reaction between the acid and formation helps maximize formation permeability and productivity.

Abstract: Methods of treating a subterranean formation penetrated by a well bore, by providing a treatment fluid comprising non-homogeneous particulates including a degradable material and a stabilizer; by introducing the treatment fluid into the well bore; and by creating a plug with the treatment fluid.

Abstract: Methods of treating a subterranean formation penetrated by a well bore, by providing a treatment fluid comprising non-homogeneous particulates including a degradable material and a hydrolysis catalyst; by introducing the treatment fluid into the well bore; and by creating a plug with the treatment fluid.

Abstract: A fracture treatment method includes forming propped regions having an optimized conductivity. Also disclosed are systems to treat a fracture interval and to produce reservoir fluids from a formation.

Abstract: Aqueous compositions contain hydrochloric acid at a concentration between 8 wt % and 28 wt % inclusive. The amino acid; hydrochloric acid mole ratio may be between 0.2 and 1.5. Sufficient water is present to dissolve the hydrochloric acid and the amino acid. Such compositions have utility as retarders for acid compositions employed in the stimulation of subterranean formations. Slowing the reaction between the acid and formation helps maximize formation permeability and productivity.

Abstract: A method for treating a subterranean formation utilizing a slurry having a plurality of shrinkable material. The method of treatment may include a diversion treatment during a fracturing operation. The shrinkable material may be adapted to shrink in response to a temperature change. The slurry may be used to perform a plugging of a perforation or fracture in the formation.

Abstract: Methods of treating a subterranean formation are disclosed that include introducing a treatment fluid including shaped particle and/or shaped uniform particles into a subterranean formation via a wellbore, and creating a plug including the shaped particle and/or shaped uniform particles of the treatment fluid.

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: A degradable composite composition including polyglycolic acid and a boron-containing accelerator, and methods of using the same (for example, as a constituent of a treatment fluid of a subterranean formation) are described. The degradable composite composition may be a composition that degrades in environments typically encountered downhole, such as oilfield environments/conditions and/or fluids.

Abstract: A method for treating a subterranean formation and for controlling a fracture geometry of a fracture in a subterranean formation. The treatment includes injection of a treatment fluid comprising particles having different sizes and a fiber that does not allow for the particles to settle in a near wellbore area. The treatment fluid triggers particle bridging in the far field.

Abstract: An aqueous solution includes HCl present in an amount exceeding 37% by weight. The solution further includes a fixing agent that is urea and/or a urea derivative. The fixing agent is present in the solution in a molar ratio of between 0.25 and 2.0 of fixing agent to HCl, inclusive.

Abstract: This invention relates to petroleum industry, in particularly, to control and monitoring of processes related to reservoir stimulation. A method of real time diagnostic of fracture operations with combination of tube waves and microseismic monitoring, comprising performing a fracture in a wellbore, recording microseismic activity generated during the fracturing operations. Determining of microseismic event locations, generating low frequency pressure waves (tube waves) near the wellbore, recording of tube waves reflections from the fractures in real time and analyzing microseismic event locations and tube waves reflections from the fractures.

Abstract: The method allows employing proppant surface modification with the emulsified treatment material for proppant delivery deep into far-field fracture zone during operations of hydraulic fracturing or heterogeneous proppant placement via proppant aggregation. In the case of gravel packing operations, to maintain the circulation of the proppant slurry for homogeneous proppant settling to the desired wellbore location. The emulsified treatment material can be degradable of non-degradable in downhole conditions.

Abstract: A method moves a tube wave reflector in a well, generates a tube wave, receives a reflection, and determines the depth of one or more reflector locations from the elapsed time. Also, a method to locate a feature in a well deploys a bottom hole assembly (BHA), generates acoustic noise from the BHA, and autocorrelates to determine the BHA depth. Also, a system has a coiled tubing string to a BHA, a surface wave generator, a surface and/or distributed receiver, and a recorder to determine elapsed times between generation and receipt.

Abstract: A method to locate fracture zones in a well by emitting tube waves from different emission locations, sensing responses from the fracture zones at different corresponding receiving locations, and analyzing the responses to map the location of the fracture zones. Also, a system to locate the fracture zones in a well with an emitter movable to emit tube waves at different emission locations in the well, a downhole receiver adapted to sense responses at respective receiving locations a fixed distance relative to the emission locations, and a recorder to track the time between the emission and the response for the different emission locations. Also a downhole tool equipped with a tube wave emitter, a tube wave response receiver in a tandem arrangement with the emitter, and a deployment system selected from wireline, coiled tubing, tractor, and combinations thereof to move the emitter and receiver together in tandem.

Abstract: A degradable diverter is placed in a flow path to divert fluid flow and exposed to degradation conditions, and after sensing a response to a pressure wave to determine the diverter has degraded, placing the well in service. Also, a treatment sequence is initiated according to a treatment schedule, a degradable diverter is placed in a flow path to divert treatment fluid, and, before completing the treatment, an interruption of the treatment schedule is followed by sensing a response to a pressure wave generated in the well to determine the status of the degradable diverter. Also, in a series of stages a degradable diverter is placed in a flow path, a response to a pressure wave is sensed to confirm placement, fluid flow is diverted, and the sequence repeated for subsequent stages.

Abstract: Method for well re-stimulation treatment using instantaneous shut-in pressure (ISIP) to guide the design and execution of refracturing stages. Pore pressure and optional cluster stresses are determined at a start of the treatment. Goal ISIPs for the refracturing correspond to undepleted regions of the formation, and target ISIPs versus treatment progression/stage range from about a lowest pore pressure corresponding to depleted regions of the formation up to within the goal range ISIPs. Diversion and proppant pumping schedules are designed, and the refracturing treatment is initiated in accordance with the design. ISIP is measured at stage end, and if it varies from the target ISIP, subsequent stages are modified from the design as needed to more closely match the ISIP schedule.