Abstract: A system and method for acquiring and processing single point viscosity measurements in well operations to predict flow curves, e.g., for mud flow, for monitoring and predicting viscosity of fluid flow in order to identify abnormal conditions for taking remedial action.

Abstract: Systems and methods of the disclosed embodiments include taking a first sample of a drilling fluid at a first time, measuring, with a rheometer, a first viscosity dial reading of the first sample, taking a second sample of a drilling fluid at a second time, measuring, with the rheometer, a second viscosity dial reading of the second sample, weighting the first dial reading and the second dial reading based on an elapsed time since the first time and an elapsed time since the second time, and calculating a shear stress vs. shear rate function of the drilling fluid for a plurality of temperatures and a plurality of pressures based on the weighted first viscosity dial reading and the weighted second viscosity dial reading.

Abstract: Methods to perform wellbore strengthening, methods to pulse hydraulic fracture a downhole formation, and wellbore strengthening systems are disclosed. A method to perform wellbore strengthening includes deploying an annular isolation device in a wellbore of a well. The method also includes pumping a fluid carrying a loss circulation material through a conveyance into a zone of an annular region of a wellbore. The method further includes activating the annular isolation device to reduce fluid flow in the zone. The method further includes generating a hydraulic pulse to form one or more fractures. The method further includes injecting a loss circulation material into the one or more fractures.

Abstract: A drilling operation can be optimized based on feedback provided by density sensors in a flow pipe. The drilling can be in a wellbore penetrating a subterranean formation while circulating a drilling fluid. The sensor can be used to detect an actual density of cuttings in the drilling fluid and within a region of the flow pipe. A modelled density of the cuttings can be calculated for the region based on an initial model. The initial model can be based on a comparison of an equivalent circulating density profile to a fracture gradient of the subterranean formation. Based on a comparison of the actual density of the cuttings to the modelled density of the cuttings, the initial model can be adjusted to generate an adjusted model. At least one operational parameter of the drilling can be changed based on the adjusted model.

Abstract: A method including determining a concentration of one or more components of a fluid during a wellbore servicing operation of a wellbore, and providing a trigger signal to actuate mechanical operation of a tool based on the determining of the concentration of the one or more components. The determining of the concentration of the one or more components includes contacting a sample of the fluid with a microelectromechanical system (MEMS) device to provide a sample response indicative of the concentration of the one or more components.

Abstract: A passive sequential pump system for use in moving a fluid is provided. The system comprises a plurality of valves. Each valve of the plurality of valves is positioned adjacent to another valve of the plurality of valves. Each of the plurality of valves includes an opening and an inner surface. The inner surface is expandable towards the opening. The system also comprises a conduit defined by the opening of each of the plurality of valves. The system further comprises an air source providing air to each of the plurality of valves and a controller controlling the air source to each of the plurality of valves. The system generates peristaltic motion to move a fluid through the conduit by increasing the air in each of the plurality of valves, thereby correspondingly closing each opening in sequence, peristaltic motion is generated to move a fluid through the conduit.

Abstract: A method of servicing a wellbore extending from a surface of the earth and penetrating a subterranean formation, including: removing water from an aqueous based wellbore servicing fluid by contacting the aqueous based wellbore servicing fluid with a porous substrate coated with a hydrophilic and oleophobic coating, whereby water is removed from the aqueous based wellbore servicing fluid via passage through the porous substrate, and whereby a water concentration and a volume of the aqueous based wellbore servicing fluid are reduced and a density of the aqueous based wellbore servicing fluid is increased to provide a modified aqueous based wellbore servicing fluid.

Abstract: Methods for the use of treatment fluids that include thermally responsive anti-sag agents in subterranean formations are provided. In one embodiment, the methods include introducing a treatment fluid including a base fluid and an anti-sag agent including a thermally responsive hydrogel that includes at least one thermoresponsive polymer into at least a portion of a subterranean formation.

Abstract: Methods and compositions for the use of thermally responsive lost circulation materials in subterranean formations are provided. In one embodiment, the methods include introducing a treatment fluid including a base fluid and a thermally responsive lost circulation material including a thermally responsive hydrogel that includes at least one thermoresponsive polymer into a wellbore penetrating at least a portion of a subterranean formation including a loss zone; allowing the thermally responsive lost circulation material to reach a thickening transition temperature; and allowing the treatment fluid to at least partially set in the subterranean formation.

Abstract: Methods for the use of treatment fluids that include thermally responsive viscosifiers in subterranean formations are provided. In one embodiment, the methods include introducing a treatment fluid including an aqueous base fluid and a thermally responsive hydrogel including at least one thermoresponsive polymer into at least a portion of a subterranean formation.

Abstract: Disclosed are methods in which measurements are obtained from a plurality of sensors secured in spaced relation to one another across at least a portion of the depth of reservoir of some form in order to identify one or more characteristics of the fluids within the reservoir. The sensors are used to monitor ambient forces exerted by fluids within the tank proximate each sensor. An example mechanism for obtaining the measurements includes a plurality of sensors, such as strain gauges, supported on a structure that supports the sensors in fixed relation to one another, and can, in some examples, support the sensors in a known relation relative to boundaries of the reservoir.

Abstract: Various embodiments disclosed relate to weighted compositions for treatment of a subterranean formation. In various embodiments, the present invention provides a method of treating a subterranean formation. The method can include placing in the subterranean formation a coated weighting agent. The coated weighting agent can include a weighting agent and an inorganic coating material on the weighting agent.

Abstract: Methods for breaking polymer-containing treatment fluids for use in subterranean formations are provided. In one or more embodiments, the methods include providing a treatment fluid comprising a base fluid and a polymer, wherein the treatment fluid was recovered from at least a portion of a subterranean formation located at a wellsite; transporting the treatment fluid from the wellsite to an off-site location; and applying a cavitation technique to at least a portion of the treatment fluid at the off-site location.

Abstract: Provided is a water retort apparatus, methods of using the water retort apparatus, and systems including the water retort apparatus. An example of the water retort apparatus comprises a sample test cell, a heating element configured to heat the sample test cell to a temperature between about 212° F. and about 400° F., a condenser in fluidic communication with the sample test cell, a sight glass in fluidic communication with the condenser, a camera configured to capture images of the sight glass, and a controller configured to analyze the images captured by the camera and estimate a volume of water in the sight glass.

Abstract: A method of detecting a shale inhibitor and/or a salt content in a wellbore servicing fluid (WSF), the method comprising determining a water salinity of a wellbore servicing fluid; dosing a known volume of the wellbore servicing fluid into a container; optionally adding a known volume of diluent (e.g., water) and mixing to provide a test sample; combining the test sample with a chromophore specific to the shale inhibitor and/or the salt, respectively, and optionally mixing; measuring the shale inhibitor content and/or the salt content, respectively, of the test sample using colorimetry; reporting the data from the measuring to a computer control system; determining a wellbore servicing fluid treatment based on the measured shale inhibitor content and/or salt content; subjecting the wellbore servicing fluid system to the treatment; and optionally waiting for a waiting time to retest the wellbore servicing fluid system and repeating.

Abstract: Certain aspects and features of the present disclosure relate to real-time management of excessive torque, drag, and vibration along a drill string. In some aspects, torque, drag, vibration or any combination of these may be monitored at locations along the drill string, and these forces may be mitigated by adjusting the drilling fluid composition in real time. In some aspects, the forces may be mitigated by making real-time operational changes during wellbore drilling instead of or in addition to drilling fluid treatments.

Abstract: A method and systems for performing a borehole operation with a borehole fluid that includes applying an amplitude oscillation deformation force to a sample of the borehole fluid over a period of time, measuring the deformation force from the sample, determining a storage modulus of the borehole fluid over the period of time based on the measured deformation force, determining a gel strength of the borehole fluid by correlation with the storage modulus, comparing the gel strength with a desired gel strength and if the gel strength is outside of an acceptable range of the desired gel strength, adjusting a drilling parameter, a composition of the borehole fluid, or a combination thereof, and using the borehole fluid in the borehole operation. Determining the storage modulus and the gel strength may be done using a processor and the force may be applied using a piezoelectric device.

Abstract: In some examples, a downhole torque measurement tool comprises a first surface of a structure and a second surface of the structure. The second surface is facing the first surface, and a shear stress sensor is positioned on the first surface. A flexible coupling is positioned between the shear stress sensor and the second surface, and the flexible coupling is coupled to the first and second surfaces.

Abstract: Methods to perform wellbore strengthening, methods to pulse hydraulic fracture a downhole formation, and wellbore strengthening systems are disclosed. A method to perform wellbore strengthening includes deploying an annular isolation device in a wellbore of a well. The method also includes pumping a fluid carrying a loss circulation material through a conveyance into a zone of an annular region of a wellbore. The method further includes activating the annular isolation device to reduce fluid flow in the zone. The method further includes generating a hydraulic pulse to form one or more fractures. The method further includes injecting a loss circulation material into the one or more fractures.

Abstract: Methods and systems for modeling the efficiency of fluid transfer between a wellbore and containers during a displacement operation. In one embodiment, the methods and systems may include providing a fluid transfer model based on constraints determined from data obtained from a wellbore servicing system, wherein the fluid transfer model comprises expected properties of the wellbore servicing system at one or more intervals during a fluid displacement operation, selecting containers for transferring a wellbore servicing fluid to a wellbore based on the expected properties, selecting containers for transferring a return fluid from the wellbore based on the expected properties, determining actual properties of the wellbore servicing system from data obtained from the wellbore servicing system, comparing the expected properties and the actual properties, and if the expected properties are different from the actual properties, modifying at least one of the expected properties of the wellbore servicing system.