Abstract: A tool for use in a wellbore includes an annular body having an inner flow passage extending axially therethrough, at least one gripping member positioned around an outer perimeter of a retainer section of the annular body, and a gate member positioned in the inner flow passage. When the gate member is in a closed configuration, an upstream portion of the inner flow passage is sealed from a downstream portion of the inner flow passage by the gate member. When the gate member is in an open configuration, the upstream portion of the inner flow passage is fluidly connected to the downstream portion of the inner flow passage. At least one static mixing blade extends through the downstream portion of the inner flow passage to mix fluid when it flows through the open gate member.

Abstract: A method may include: circulating an oil-based drilling fluid though a drill string to extend a wellbore through a subterranean formation, wherein the oil-based drilling fluid comprises an invert emulsion; separating at least a portion of the oil-based drilling fluid from the circulated oil-based drilling fluid to form a separated portion of oil-based drilling fluid; mixing a metal salt and a metal oxide into the separated portion of the oil-based drilling fluid to form a chemical sealing pill; introducing the chemical sealing pill into the drill string and flowing the chemical sealing pill into a lost circulation zone in the subterranean formation; allowing at least a portion of the chemical sealing pill to set in the lost circulation zone to form a set plug, wherein the set plug seals the lost circulation zone and reduces loss of fluid into the lost circulation zone from subsequently introduced fluids; and preventing loss of fluid into the lost circulation zone from subsequently introduced fluids with the s

Abstract: A particulate plugging agent, such as a diverting agent and/or loss circulation material, using a particular polyvinyl alcohol with a certain amount of monovalent metallic salt, which is water-soluble and has a buffer effect even if the environment is acidic, and thus stable, which in particular finds use in various subsurface oil production operations.

Abstract: The present invention relates to a composite material, in particular a switchable functional material, comprising (a) a porous carrier material and a swellable material, a method for its preparation and its use in coatings. The composite material is suitable for the production of water-repellent and water-vapor diffusion-open coatings, as well as the use of the composite material.

Abstract: Compressed lost circulation materials for use in subterranean formations are provided. In some embodiments, the methods include: introducing a treatment fluid that includes a base fluid and a compressed lost circulation material into a wellbore penetrating at least a portion of a subterranean formation including a loss zone, the compressed lost circulation material including a binding material and a compressed material; allowing the binding material to at least partially degrade or dissolve; and allowing the compressed lost circulation material to at least partially expand in the subterranean formation.

Abstract: A method comprising drilling through a plurality of differing zones of a subterranean formation using a drilling fluid comprising a non-oleaginous continuous phase, an oleaginous discontinuous phase and at least a first salt dissolved into the non-oleaginous continuous phase. The amount of the at least first salt dissolved into the non-oleaginous continuous phase is maintained such that a density of the drilling fluid varies by no more than 10% while drilling through the plurality of zones.

Abstract: A method of servicing a wellbore penetrating a subterranean formation, comprising placing a wellbore servicing fluid (WSF) into the wellbore proximate a permeable zone having an average fracture width of about W microns, wherein the WSF comprises a particulate blend and water, and wherein the particulate blend comprises (a) a type A particulate material characterized by a weight average particle size of equal to or greater than about W/3 microns, and (b) a type B particulate material characterized by a weight average particle size of less than about W/3 microns, wherein a weight ratio of the type A particulate material to the type B particulate material is from about 0.05 to about 5.

Abstract: A wellbore loss zone remediation method to reduce losses of drilling fluid in a lost circulation zone of a wellbore is described. The wellbore loss zone remediation method includes identifying a lost circulation zone in a wellbore, selecting a lost circulation fabric, selecting a lost circulation material for a slurry, disposing the lost circulation fabric in the wellbore, circulating the slurry in the wellbore, and determining if the lost circulation zone is remediated.

Abstract: Embodiments of the disclosure provide a method and device for controlling lost circulation in a target lost circulation zone in a borehole. A swellable lost circulation material device includes a permeable membrane and a swellable lost circulation material enclosed within the membrane. The swellable lost circulation material device in a non-swollen state is introduced to a target lost circulation zone where a fluidic component permeates into the swellable lost circulation material device through the membrane such that the fluid component is in contact with the swellable lost circulation material such that the swellable lost circulation material device transitions to a swollen state.

Abstract: The present disclosure provides methods, compositions, and systems embodying cement compositions and the synergistic effect of lost circulation materials (LCMs) and fluid loss control additives (FLCAs) thereupon for cementing subterranean zones. A method of subterranean well cementing, comprising providing a cement composition comprising a hydraulic cement, a first FLCA, an LCM, and water, wherein the first FLCA comprises a water-soluble polymer with repeating units comprising a 5- to 6-membered cyclic amide; introducing the cement composition into a wellbore penetrating a subterranean formation, wherein inclusion of the first FLCA and the LCM in the cement composition fluid reduces fluid loss into the subterranean formation, wherein the subterranean formation has fractures with a width of from about 1 micron to about 800 microns, and wherein the subterranean formation has a permeability of about 1 milliDarcy to about 300 Darcy; and allowing the cement composition to set in the subterranean formation.

Abstract: Methods for drilling a wellbore into a subterranean formation include preparing a drilling fluid and circulating the drilling fluid in the wellbore while drilling in the subterranean formation, forming a filtercake from the drilling fluid, creating or encountering one or more fractures in the subterranean formation while drilling, and allowing a portion of the filtercake formed to at least partially seal the one or more fractures while continuing the drilling.

Abstract: A method of reducing fluid loss includes pumping a wellbore fluid including resin coated solid particulate into a wellbore having fractures therein, the resin coated solid particulate forming a substantially impermeable plug in the fractures. A method of drilling a wellbore includes drilling a wellbore through a formation using a first wellbore fluid; and upon experiencing a fluid loss event to the formation, pumping a second wellbore fluid including resin coated solid particulates into the wellbore.

Abstract: A method of sealing a water-bearing subsurface formation includes introducing an activation solution including an aqueous solution, Na2SiO3, NaOH, and one or both of CaCO3 or Mn3O4 into the wellbore. The method further includes introducing Saudi Arabian volcanic ash into the wellbore. The Saudi Arabian volcanic ash comprises SO3, CaO, SiO2, Al2O3, Fe2O3, MgO, and K2O. The method further includes allowing the Saudi Arabian volcanic ash to contact the activation solution in the wellbore, thereby forming a geopolymer barrier between the wellbore and the water-bearing subsurface formation and sealing the water-bearing subsurface formation.

Abstract: A lost circulation material (LCM) having flakes formed from date tree leaflets is provided. The flakes of the date tree leaflet LCM may be formed by tearing and shredding date tree leaflets from date trees. The date tree leaflets may be obtained from date tree pruning performed by date tree farming industries. The date tree leaflet LCM may be added to o a drilling fluid to mitigate or prevent lost circulation in a well. Methods of lost circulation control with the date tree leaflets LCM are also provided.

Abstract: A method of managing water content of a pulsed power drilling fluid, the method comprising contacting the pulsed power drilling fluid with a water absorbent material, wherein the pulsed power drilling fluid comprises water at a first water concentration, and whereby the water absorbent material absorbs at least a portion of the water from the pulsed power drilling fluid to provide a treated pulsed power drilling fluid and a spent water absorbent material comprising absorbed water, wherein the treated pulsed power drilling fluid comprises water at a second water concentration, wherein the second water concentration is lower than the first water concentration. A pulse power drilling fluid and a system for carrying out the method are also provided.

Abstract: A system includes a mud pump for pumping a drilling mud from a drilling mud source, through a drill string, out a drill bit and into an annular, and a plurality of chokes disposed down stream from the mud pump, including a first choke disposed between the mud pump and the drill string, and a second choke disposed between the mud pump and a mud tank. The system further includes a fluid discharge conduit in fluid communication with the annular space for transferring the drilling mud to handling equipment in fluid communication with the mud tank. The first choke receives the drilling mud from the mud pump at a first flow rate, the first choke reduces drilling mud flow rate to a second flow rate less than the first flow rate, and the second choke reduces drilling mud flow rate to a third flow rate.

Abstract: A wellbore fluid may include a base fluid and milled polymeric fibers, wherein the base fluid is an oil-based fluid or an aqueous-based fluid, and wherein the milled polymeric fibers may have a length distribution in which the lowest point in the length distribution is up to about 50% of the average fiber length.

Abstract: Technologies are described for a method of making an encapsulated reactant having a desired shape or size. The method comprises providing solid reactant particles and an encapsulating material. The encapsulating material is heated above its solidification temperature to form a molten, semi-solid, or liquid encapsulating material. The solid reactant particles are added to the molten, semi-solid, or liquid encapsulating material and mixed to disperse the solid reactant particles in the encapsulating material and form a mixture. The mixture may be extruded or formed into the desired shape or size of the encapsulated reactant, or the mixture may be solidified and extruded, granulated, shredded, ground, or pressed into the desired shape or size.

Abstract: At least one petroleum coke may be added to an oil-based fluid to improve the electrical conductivity of the oil-based fluid. The oil-based fluid may be a drilling fluid, a completion fluid, a drill-in fluid, a stimulation fluid, a servicing fluid, and combinations thereof. In a non-limiting embodiment, the downhole fluid composition may be circulated in a subterranean reservoir wellbore.

Abstract: A rapidly dehydrating lost circulation material (LCM) composition that forms an acid-soluble plug is provided. The LCM composition may include a carrier fluid, an acid-soluble-particulate material, a viscosifier, and date tree rachis fibers. The carrier fluid may be water and the viscosifier may be a cellulosic microfiber. The LCM composition may alter a lost circulation zone by forming an acid-soluble plug in a fracture of the lost circulation zone. The acid-soluble plug may be removed via an acid solution, such as a hydrochloric acid solution. Methods of lost circulation control and manufacture of a rapidly dehydrating LCM are also provided.

Abstract: A hybrid particle mix lost circulation material (LCM) is provided. The hybrid particle mix LCM includes date palm seed particles produced from date palm seeds and scrap tire particles produced from scrap tires. The LCM may include date palm seed particles in the range of about 50 wt % to about 80% and scrap tire particles in the range of about 50 wt % to about 20 wt %. Methods of lost circulation control and manufacture of a hybrid particle mix LCM are also provided.

Abstract: The present invention relates to the field of drilling fluids, and discloses a drilling fluid that can inhibit surface hydration of clay and a preparation method of the drilling fluid. The drilling fluid contains water, bentonite, an intercalation inhibitor, a tackifier, a flow pattern regulator, a filtrate reducer, a lubricant, and a weighting agent, wherein, based on 100 parts by weight of water, the content of the bentonite is 2-9 parts by weight, the content of the intercalation inhibitor is 0.3-4 parts by weight, the content of the tackifier is 1-10 parts by weight, the content of the flow pattern regulator is 0.8-7 parts by weight, the content of the filtrate reducer is 1-8 parts by weight, the content of the lubricant is 0.

Abstract: A method of swelling an oil-swellable elastomer in a well comprising the step of: contacting the oil-swellable elastomer in the well with a treatment fluid, wherein the treatment fluid comprises: (A) an oil selected from the group consisting of alkanes and naphtha, wherein the oil comprises hydrocarbons having anywhere in the range of 5 to 21 carbons; (B) an ?-olefin having anywhere in the range of 18 to 26 carbons; and (C) an activator for oil-swelling, the activator selected from the group consisting of: ketones, dodecane, terpenes, terpenoids, haloalkanes having from 9 to 20 carbons, and any combination thereof. An oil-swelled elastomer as produced by the method is also contemplated.

Abstract: Compositions for lost circulation materials (LCM) and methods for using same in drilling and/or completing wellbores that help solve lost circulation problems in a wide range of fracture sizes, thereby advantageously eliminating the need for a variety of products for lost circulation in a field at any one time. The compositions provide specific LCM components in specific ratios that are analogs to lost circulation fractures and that yield superior performance in preventing or alleviating lost circulation in drilling and cementing boreholes. The compositions have a multi-modal particle size distribution (PSD) which provides a higher concentration of component materials in the same range of two or more fracture widths or median pore size diameters, thus allowing plugging to occur over a wider range than a single mode or narrow PSD.

Abstract: Methods including preparing a surface modification agent emulsion comprising an aqueous base fluid, a surfactant, and a hydrophobically-modified amine-containing polymer (HMAP), the HMAP comprising a plurality of hydrophobic modifications on an amine-containing polymer, and wherein the aqueous base fluid forms an external phase of the surface modification agent emulsion and the HMAP forms an internal phase of the surface modification agent emulsion; and introducing the surface modification agent emulsion into a subterranean formation.

Abstract: A strap assembly includes a chest strap and shoulder straps. Similarly configured left and right cups are provided. The strap assembly is attached to the cups whereby the strap assembly adheres the cups to a wearer. Each cup has curved upper, lower, interior and exterior edges. Each cup has inside and outside surfaces. A patch is operatively associated with each cup. Each patch has a linear upper edge and curved lower, interior and exterior edges. Each patch has inside and outside surfaces. Stitching couples the lower, interior and exterior edges of each patch to the lower, interior and exterior edges of an associated cup. A linear opening is formed along the upper edge of each patch. Piping covers the upper edge of each patch. The piping is adapted to allow the patch to move away from and back toward the cup between open and closed orientations.

Abstract: Methods for detection of the presence and distribution of oil in subsurface formation are described herein. The present invention involves injection of an aqueous dispersion of the nanoparticles into the potentially oil containing subsurface formation, followed by a remote detection of the oscillation responses of the nanoparticles in the oil/water interfaces in the reservoir rock by applying magnetic field.

Abstract: A water absorbing composition includes a particle having a core of a water-swelling material. A coating substantially surrounds the core that temporarily prevents contact of water with the water-swelling material. The coating may be formed from a layer of water degradable material or a non-water-degradable, non-water absorbent encapsulating layer. A quantity of particles including delayed water-swelling particles formed at least in part from a water-swelling material and, optionally, non-water-swelling particles of the same or different size distributions can be used in treating a formation penetrated by a wellbore. A slurry of the particles is formed with a carrier fluid. The slurry of particles is introduced into the wellbore of the formation to facilitate treatment.

Abstract: There is described a drilling fluid for wellbore strengthening having nanoparticles and granular particles. In one aspect described herein, the drilling fluid is an invert emulsion based fluid. In a further aspect, the nanoparticles are iron hydroxide or calcium carbonate, and in a further aspect from about 1 to 30 nm in size. In one aspect described herein, the granular particles are graphite or calcium carbonate and in a further aspect, up to 250 ?m in size. The nanoparticles and granular particles plug fractures in the wellbore to strengthen the wellbore.

Abstract: A method of triggering heating within a subterranean formation, that includes introducting a wellbore fluid containing a dispersed carbon nanomaterial into a wellbore through the subterranean formation; lowering a microwave or ultraviolet radiation source into the wellbore; and irradiating the wellbore with microwave or ultraviolet radiation, thereby increasing the temperature of the wellbore fluid and/or wellbore is disclosed.

Abstract: A wellbore fluid that includes an aqueous based fluid; an amphoteric, viscoelastic surfactant; and a modified starch is disclosed. Methods of drilling subterranean wells, methods of reducing the loss of fluid out of subterranean wells, and methods of completing wellbores using aqueous-based fluids having an ampoteric, viscoelastic surfactant and a modified starch are also disclosed.

Abstract: An oil-in-water emulsion is provided to place a sealant within a subterranean formation by being deployed into the formation to reacte with the formation's included water to break the emulsion, leaving the emulsified components, some of which act as the sealant to form at least a partial seal. The emulsion does not form a seal until emulsified in response to formation water conditions (salinity, pH, calcium ion concentration, temperature), and can be a drilling fluid or a pill during drilling activities.

Abstract: Compositions for controlling fluid loss may include an aqueous fluid, a viscosifier, a water soluble polar organic solvent, a delayed acid source, and a weighting agent. The composition may further comprise at least one selected from bridging solids, cleaning agent, dispersant, interfacial tension reducer, pH buffer, thinner, or surfactant. Such compositions may be used in producing a hydrocarbon from a formation by drilling the formation with a drill-in fluid to form a wellbore, emplacing the composition in the wellbore, and shutting the well for a predetermined time to allow the viscosity of the fluid loss composition to decrease.

Abstract: The disclosed invention is a unique drilling fluid composition and method for reducing lost mud circulation in wellbores due to seepage loss into fluid permeable subterranean formations. The drilling fluid composition comprises a variety of shapes and sizes of distinctive unadulterated elastomeric rubber particles derived from the tire retreading (recapping) process. These elastomeric rubber particles are incorporated into an aqueous, hydrocarbon, or synthetic drilling fluid in sufficient amounts as to plug holes, fractures, and fissures, form a mud cake, and thus stem the loss of drilling fluids from the lost circulation zone.

Abstract: A method of servicing a wellbore comprising identifying lost circulation zone within a wellbore; and placing in the wellbore a composition comprising a wax and a water-based mud wherein placement of the composition reduces or prevents a loss of fluids to the lost circulation zone. A wellbore servicing fluid comprising a water-based mud, a sized calcium carbonate particle and a wax.

Abstract: A method of conversion of a water-based mud to a gel-based LCM quickly to control lost circulation in a lost circulation zone in a wellbore during continuous drilling with a drilling mud, the drilling mud comprises a volcanic ash, water, a de-foamer, a pH buffer, and a polymer. The method comprises the steps of entering the lost circulation zone, determining a lost circulation volumetric flow rate, metering a first amount of a binder into the drilling mud to create a binder containing mud, pumping the binder containing drilling mud into the wellbore, and suspending metering of the first amount of the binder to the drilling mud after a pre-defined regulating period of time effective to permit the binder containing drilling mud to create a gel-based LCM operable to alter the lost circulation zone.

Abstract: Treatment fluid compositions may comprise transient polymer networks for use in methods related to subterranean applications. In one aspect, a method may include providing a treatment fluid comprising an aqueous base fluid and a transient polymer network, and placing the treatment fluid in a subterranean formation. In another aspect, a subterranean treatment fluid may include an aqueous-base fluid and a transient polymer network.

Abstract: This invention relates to drilling a well, particularly an oil or gas well, where casing or liner will be installed to stabilize the wellbore. The present invention is intended to permit more drilling and longer lengths of casing or liner to be installed at one time. The present invention includes a combination of a smear tool and specially sized granular lost circulation material solids in the drilling mud which work together to close and seal leaking formations and fractures whether pre-existing or induced by drilling. By the natural collection of the inventive solids along with the conventional particles in the drilling mud to form a filter cake at the problem areas along the wall of the wellbore and the smear tool arranged to compress the filter cake into the problem areas, lost circulation is minimized Maintaining circulation naturally allows for longer drilling cycles and potentially fewer liner joints in the well.

Abstract: The present invention relates to processes for consolidating an underground formation with a consolidating mineral. The consolidating material is a carbonate and is produced from an alkaline treatment fluid containing, in at least some embodiments, environmentally friendly and inexpensive components. In one embodiment, the process can be applied to consolidation of an underground formation during or following drilling. The present invention also provides a treatment fluid suitable for use in such processes.

Abstract: A method of segregating flowable materials in conjunction with a subterranean well can include segregating flowable cement from a fluid by placing a flowable barrier substance between the cement and the fluid, and the barrier substance substantially preventing displacement of the cement by force of gravity through the barrier substance and into the fluid. Another method of segregating flowable materials can include flowing a barrier substance into a wellbore above a fluid already in the wellbore, and then flowing cement into the wellbore above the barrier substance. A system for use in conjunction with a subterranean well can include a flowable cement isolated from a fluid by a flowable barrier substance positioned between the cement and the fluid, whereby the barrier substance substantially prevents displacement of the cement by force of gravity through the barrier substance and into the fluid.

Abstract: Methods of providing fluid loss control in a portion of a subterranean formation comprising: providing a treatment fluid comprising a base fluid and a plurality of seeds; introducing the treatment fluid into a portion of a subterranean formation penetrated by a well bore such that the seeds block openings in the subterranean formation to provide fluid loss control; and degrading the seeds over time within the subterranean formation. In some methods, the seeds are present in the treatment fluid in an amount of at least about 5 pounds per barrel. In addition, in some methods the seeds are preferably degradable.

Abstract: A plurality of solid particles including a thermoplastic composition having a softening temperature in a range from 50° C. to 180° C. and a blocked isocyanate resin; optionally at least some of the particles in the plurality of solid particles comprise both the thermoplastic composition and the blocked isocyanate resin. A composition comprising the plurality of particles dispersed in a fluid is also disclosed. A method of modifying a wellbore within a geological formation is also disclosed. The method includes introducing the fluid composition into the wellbore. A method of making a plurality of particles, for example, to use in the fluid composition, is also disclosed.

Abstract: Methods for sealing voids and cracks in subterranean-formation rock that contains carbonate minerals, thereby minimizing or stopping fluid flow between the formation rock and the wellbore of a subterranean well, comprise pumping a solution of one or more lattices that contains at least one carboxylated monomer down a well during drilling and allowing it to enter voids (e.g., pores, fractures, vugs and caverns) in the carbonate-containing formation. The solution reacts with divalent cations liberated by the carbonates and forms a plug.

Abstract: This invention relates to drilling a well, particularly an oil or gas well, where casing or liner will be installed to stabilize the wellbore. The present invention is intended to permit more drilling and longer lengths of casing or liner to be installed at one time. The present invention includes a combination of a smear tool and specially sized granular lost circulation material solids in the drilling mud which work together to close and seal leaking formations and fractures whether pre-existing or induced by drilling. By the natural collection of the inventive solids along with the conventional particles in the drilling mud to form a filter cake at the problem areas along the wall of the wellbore and the smear tool arranged to compress the filter cake into the problem areas, lost circulation is minimized. Maintaining circulation naturally allows for longer drilling cycles and potentially fewer liner joints in the well.

Abstract: Embodiments include drilling through a formation using a drill bit conveyed by a tubular string having an outer diameter at least 70 percent of the wellbore being drilled. The formation is drilled at a first rate of penetration (ROP) while pumping drilling fluid at a first flow rate. After drilling through the formation, the ROP is reduced to a second ROP, the flow rate is reduced to a second flow rate, and pressure is increased in the wellbore until drilling fluid begins to leak into the formation. While maintaining the increased pressure in the wellbore, the volume of drilling fluid lost to the formation is monitored until the rate at which the drilling fluid loss occurs is reduced. Components of this procedure are repeated until a selected wellbore strength is achieved.

Abstract: Mixtures of fibers and solid particles are effective for curing fluid losses and lost circulation in a subterranean well. Stiff fibers are more effective than flexible ones; however, mixtures of stiff and flexible fibers have a synergistic effect. The quantity and particle-size distribution of the solids are optimized according to the stiffness, dimensions and concentrations of fibers.

Abstract: A composition comprises: a treatment fluid comprising a lost-circulation material, wherein the lost-circulation material comprises a ceramic, and wherein the lost-circulation material has a median particle size in the range from about 0.001 millimeters to about 25.4 millimeters. According to another embodiment, a composition comprises: the treatment fluid comprising a lost-circulation material, wherein the lost-circulation material comprises a ceramic, and wherein the median particle size and the concentration of the lost-circulation material is selected such that the treatment fluid has a sealing pressure of at least 50 psi (0.3 MPa). A method of eliminating or reducing lost circulation from a well comprises: introducing the treatment fluid into at least a portion of the well.

Abstract: A variety of methods and compositions are disclosed, including, in one embodiment, a method of treating a subterranean formation comprising: providing coated particles, wherein the coated particles comprise solid particles coated with an expandable coating; and introducing the coated particles into a permeable zone of the subterranean formation such that the coated particles form a barrier to fluid flow in the permeable zone. In another embodiment, a method of drilling a well bore may be provided, the method comprising: including coated particles in a drilling fluid, the coated particles comprising solid particles coated with an expandable coating; using a drill bit to enlarge the well bore; and circulating the drilling fluid past the drill bit.

Abstract: An encapsulated thixotropy agent may be added to aqueous well service fluids. Such fluids include drilling fluids, cement slurries and polymer pills. The well service fluid may be subjected to shearing action downhole, causing the thixotropy agent to be released and imparting thixotropy to the fluid. The thixotropy agent comprises a dry suspension of synthetic layered silicates.

Abstract: The invention provides a system for adapting an HVAC system in an existing building for utilizing geothermal energy, the system comprising an incoming flux of geothermal energy; a plurality of heat exchange surfaces adapted to receive the incoming flux of geothermal energy; and an interface between the HVAC system and the heat exchange surfaces, said interface adapted to transfer the geothermal energy to the system.