Abstract: A coating protects a dissolvable component of a downhole tool, so that the dissolvable component can be deployed to a desired downhole location, perform under high stress for fracturing operations, and be efficiently dissolved after the fracturing operations are completed. The present invention elevates known greases for this functionality usually performed by complex factory fabricated polymer and metal coatings. The coating includes an activation layer, a first grease layer, and a second grease layer. The first grease layer and the second grease layer have differential grease layer consistency ranges and thickness rages. The coating includes non-uniform layers of manually applied greases onsite to control degradation of the component substrate as effectively as factory coatings pre-fabricated on the components.

Abstract: A downhole assembly includes a float tool configured to be connected to a casing string and including one or more one-way valves configured to permit fluid flow in a downhole direction and to prevent fluid flow in an uphole direction, and a first wiper plug configured to be deployed into a well via the casing string and engage the float tool. The first wiper plug comprises a valve element that is configured to prevent fluid flow through the first wiper plug at least in the uphole direction.

Abstract: A method for treating a well in a hydrocarbon-producing subterranean production zone. The method for treating well-producing hydrocarbons from a subterranean production zone includes dry mixing a granite waste powder (GWP) in a form of rock aggregates and a cement to form a mixture. Then the mixture is added to the cement composition containing water, pre-hydrated sodium bentonite, calcium chloride, a dispersant, and an alcohol-based defoamer to form a cement slurry. The cement slurry is prepared at a density of from 13.5 pounds per gallon (ppg) to 14.5 ppg and contains the GWP in a range of from 5 wt. % to 20 wt. % of the cement slurry. 10 wt. % to 15 wt. % perlite is added into the cement slurry to form a ternary blend which is cured and then the cured product is injected into the well to seal the well at the subterranean production zone.

Abstract: Methods of wellbore cementing are provided. A method of cementing may comprise calculating a lime to silica correlation for two or more cementitious components of a cement composition; and adjusting a concentration of at least one of the cementitious components such that the lime to silica correlation meets or exceeds a target.

Abstract: Provided is a method of introducing a scavenger composition into a fluid contaminated with a sulfur contaminant, mixing the scavenger composition with the fluid in a vessel, and recovering the fluid containing a reduced amount of sulfur contaminant from the effluent. The scavenger composition comprises a hydrogen sulfide scavenger and a linear anionic polymer. The linear anionic polymer is present in an amount of about 0.1% to about 50% by weight of the scavenger composition and has a number average molecular weight of about 1.0×103 to about 2.0×104 Daltons.

Abstract: A system for establishing a bypass flow path includes a plug assembly having bypass ports extending from the exterior to the interior; a wiper dart to engage and seal the first flow path and bypass flow path, and initiate release of the plug assembly from a first position, the plug assembly having a dart nose attached to the dart body; once the plug has moved to a second position, pressure applied through the bypass ports communicates to the dart nose to cause detachment of the dart nose from the dart body; a first flow path extends through the central bore of the plug assembly when the wiper dart is not present; and a second flow path extends through the bypass ports on the plug assembly below the dart body to the detachable dart nose, once detached, the bypass flow path is established thru the bore below the dart body.

Abstract: A cement spacer fluid and a method for making and a method for using the cement spacer fluid are provided. The cement spacer fluid includes a polyethyleneimine hydrochloride (PEI HCl) salt, an aqueous solvent, a viscosifier, and a weighting agent.

Abstract: A method of reducing corrosion in tubular strings installed in wellbores includes dispensing an accelerated cement composition into a wellbore annulus, a casing-casing annulus, or both, the accelerated cement composition comprising a cement composition and an accelerant composition, where: the cement composition comprises a cement precursor and water; the accelerant composition comprises triethanolamine; and a concentration of the triethanolamine in the accelerated cement composition is greater than or equal to 10,000 parts per million by weight; allowing the accelerated cement composition to cure in the annulus to form a cured cement, where the triethanolamine reacts with a metal of the tubular string, the reaction forming a protective layer on the surfaces of the tubular string that inhibits dissolution of iron from the metal of the tubular string.

Abstract: A running tool sets and cements a liner in a borehole. While the tool's bypass section is closed, a plug deployed to the tool diverts hydraulic pressure to set a liner hanger in the borehole. The setting plug is unseated, and the bypass section is switched opened by deploying another plug to an opening seat and shifting a control sleeve open relative to a bypass port. While the tool's packoff remains sealed in the hanger, cement pumped out the bypass port is bullheaded into a lap of the liner and borehole. When cementing is complete, the bypass section is switched closed by deploying another plug to a closing seat and shifting the control sleeve closed relative to the bypass port. The bypass section is then placed in a flow-through condition where fluid communication is reestablished through the tool to the liner by allowing fluid to flow past the plugs in the tool.

Abstract: A cross BOP swivel joint for crossing over a blowout preventer of a drilling apparatus includes a swivel housing, an internal pipe received through the swivel housing. The internal pipe includes an upper loading shoulder and a lower loading shoulder. The cross BOP swivel joint includes an upper journal bearing, lower journal bearing, and at least one central bearing between the swivel housing and the internal pipe. The central bearings are axially disposed between the journal bearings. When engaged, the BOP contacts the outer surface of the swivel housing of the cross BOP swivel joint. The journal bearings allow the internal pipe to rotate relative to the swivel housing when the BOP is engaged with the swivel housing. This allows rotation of the drill string during well control events. The central bearing provides radial support to the swivel housing to reduce inward deflection of the swivel housing.

Abstract: A system used to dislodge and, if necessary, sever a tubular string that is stuck within a cased wellbore. The system utilizes a jar, a plurality of plugs, and a tubular severance device. Components of the system are carried to their respective desired downhole positions by downward fluid flow within the wellbore. The jar is configured to jar the string in an effort to dislodge the string from its stuck point. The plugs are configured to fill open perforations formed in the casing in order to direct the fluid toward the stuck point and away from the perforations. If the string cannot be freed by the jar, the tubular severance device is deployed within the string above the stuck point. Detonation of the device severs the string above the stuck point.

Abstract: A very light weight, noncompressible drilling fluid including a very light weight hydrocarbon base liquid, and a styrenic butadiene diblock copolymer is heated to achieve excellent rheology including thixotropicity, making an effective drilling fluid with a density of 8 pounds per gallon or less. Densities as low as 4 pounds per gallon are achieved with the addition of glass bubbles. The glass bubbles may, but normally will not, exceed 50% by volume. A method of making the drilling fluid includes passing the light weight liquid and the copolymer through a cavitation device. The invention includes drilling and with and recirculating the fluid to maintain the desired density, viscosity and rheology by adjusting the ingredients accordingly. A method of managed pressure drilling employs the novel fluid, enabling control of drill pressure and physical properties of the fluid including equivalent circulating density.

Abstract: Systems and methods include a computer-implemented method for handling loss circulation zones in wells. A tool is deployed on a work string. The tool includes isolation packers in an un-inflated state and a stinger in a closed position. The tool is run to a target depth along the work string. The isolation packers are inflated, setting the isolation packers in place adjacent to the stinger at the target depth. Circulation ports are opened after the isolation packers are inflated, exposing a diversion flow path. A cement slurry is pumped through the diversion flow path into a loss circulation zone. The circulation ports are closed after the cement slurry is pumped. The work string is disengaged from the stinger.

Abstract: Methods and systems for determining whether a base oil for use in drilling muds will be compatible with cement during subsequent cementing operations include: providing a drilling fluid that includes a base oil; using the drilling fluid to drill at least a portion of a wellbore penetrating at least a portion of a subterranean formation; measuring a compositional characteristic of the base oil using one or more analytical tests; determining whether the base oil is a compatible base oil or an incompatible base oil based at least in part on the compositional characteristic of the base oil; injecting an amount of spacer fluid into the wellbore, wherein the amount of spacer fluid is selected based on the determination of whether the base oil is a compatible base oil or an incompatible base oil; and injecting the one or more cementing or completion fluids into the wellbore.

Abstract: A method for cementing a wellbore, including pumping a volume of an anti-corrosion fluid comprising at least one corrosion inhibitor into a casing and displacing the anti-corrosion fluid into an annular space outside the casing with a volume of cement. A displacement fluid may then be injected into the casing to displace the cement into the annular space, wherein a combined volume of cement and anti-corrosion fluid fills the annular space along a height of the casing. A height of the cemented annular space may be less than the height of the casing, the anti-corrosion fluid being retained in the annular space axially above a cemented annular space, forming an anti-corrosion fluid annular space. Partially cementing in this manner may simultaneously protect the casing from corrosion while allowing easier workover operations proximate the anti-corrosion fluid annular space.

Abstract: A method is described for strengthening a carbonate formation rock within a subterranean formation. The method involves contacting the rock with a composition of Ca(OH)2 nanoparticles in an organic solvent, which results in a treated rock having a Young's modulus that is increased by at least 10%. The composition may optionally comprise a CO2 source.

Abstract: A method of servicing a wellbore includes introducing a fluid into a wellbore, the wellbore having particulate matter disposed therein and entraining at least a portion of the particulate matter within the fluid. The fluid includes a polymer having at least one hydrophobic monomer and at least one hydrophilic monomer. The fluid is also included within an analytical tool within a coiled tubing system for performing operations in a wellbore. The fluid is also included within a formation-tester tool.

Abstract: A system used to dislodge and, if necessary, sever a tubular string that is stuck within a cased wellbore. The system utilizes a jar, a plurality of plugs, and a tubular severance device. Components of the system are carried to their respective desired downhole positions by downward fluid flow within the wellbore. The jar is configured to jar the string in an effort to dislodge the string from its stuck point. The plugs are configured to fill open perforations formed in the casing in order to direct the fluid toward the stuck point and away from the perforations. If the string cannot be freed by the jar, the tubular severance device is deployed within the string above the stuck point. Detonation of the device severs the string above the stuck point.

Abstract: In one embodiment, a spacer fluid may comprise a base fluid and a surfactant package. The surfactant package may comprise one or more surfactants, where the surfactant package comprises a first surfactant having the chemical structure R—(OC2H4)x—OH. R may be a hydrocarbyl group having from 9 to 20 carbon atoms, and x may be an integer from 5 and 15. The first surfactant may have a hydrophilic-lipophilic balance (HLB) of from 12 to 13.5.

Abstract: A wellbore servicing composition comprising: cement kiln dust (CKD), an organic acid, and water. A method of servicing a wellbore penetrating a subterranean formation, comprising: placing a wellbore servicing composition into the wellbore, wherein the wellbore servicing composition comprises CKD, an organic acid, and water. A method of servicing a wellbore with annular space between a wellbore wall and casing disposed therein, wherein a first fluid is present in at least a portion of the annular space, comprising placing a second fluid into at least a portion of the annular space and displacing at least a portion of the first fluid from the annular space, and placing a third fluid into at least a portion of the annular space and displacing at least a portion of the second fluid from the annular space, wherein the second fluid, the third fluid, or both comprise CKD, an organic acid, and water.

Abstract: A method of reducing lost circulation in a wellbore 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 a subsurface formation to reduce lost circulation in the wellbore.

Abstract: An operational system for an oil well wellhead for launching, managing and controlling a robotic autonomous unit (RAU) is described, said system comprising a) main body for housing said RAU, a lower safety valve, an upper safety valve, a connector for connection with the well head and an end cap for communication with said RAU; b) a PMD unit for programming, managing and data collection; and c) at the ground surface, a unit for remote transmission and reception, for receiving information collected by said PMD unit. The method for well logging with the aid of said operational system is also described.

Abstract: An example system for isolating cement slurry from drilling fluids includes a tool configured for installation on a landing collar of a casing. The tool includes a base that conforms to an inner circumference of the casing and a tube that extends uphole from the base. The tube has a first borehole that extends downhole through the base. The tube is perforated to allow cement slurry to pass from the casing into the first borehole. A cementing plug is configured to seal to the casing uphole of the base. The cementing plug includes a second borehole to receive the tube. The cementing plug includes a covering that extends across at least part of the borehole and that is configured to break in response to contact with the tube.

Abstract: A subsurface wellbore wiper deployment system includes a plug having an elongated body with an exterior surface; one or more exposed wipers extending away from the exterior surface; and one or more hidden wipers secured to the exterior surface and positioned underneath a removable sleeve; and a landing collar having a landing seat extending into an interior of the landing collar; the removable sleeve is to engage with the landing seat upon deployment of the plug; and the landing collar removes the removable sleeve to expose the one or more hidden wipers.

Abstract: Spacer fluid compositions comprising water, a clay, and a sulfur-containing polyether surfactant are disclosed, and such compositions often can further include a weighting additive, an antifoaming additive, and a co-solvent. These spacer fluid compositions can be used to treat metal casing and to remove drilling fluid residue for improved cement bonding in wellbore applications.

Abstract: A spacer fluid contains one or more hydratable polymeric viscosifying agents having a particle size distribution such that a minimum of 90% of the particulates are retained on a 20 mesh screen. The spacer fluid may further contain one or more surfactants, viscosity thinners, organic solvents, weighting materials, suspending agents and antifoaming agents. The spacer fluid may be used to position a first fluid into a wellbore annulus of a wellbore containing a second fluid. The spacer fluid may further be used to fluidly isolate at least a portion of a wellbore annulus in a wellbore containing an oil-based drilling mud and an aqueous cement slurry.

Abstract: Dissolvable casing liners are utilized to isolate existing perforations. A dissolvable casing liner is deployed downhole along the interior of a casing string having a plurality of perforations. The casing liner is then secured against the casing string, thereby effectively sealing the perforations. Once the perforations are isolated, refracturing operations may be conducted. At some time thereafter, the casing liner is dissolved and removed from the wellbore.

Abstract: An example method includes pumping fluid into a wellbore to fill, at least partly, a region in a lost circulation zone, with the fluid having a first density; and after pumping the fluid, pumping cement slurry into the wellbore. The cement slurry has a second density. The first density is greater than, or equal to, the second density, which causes the fluid to prevent, at least partly, the cement slurry from mixing with other fluid in the lost circulation zone for at least a period of time.

Abstract: A method to control a heat transfer profile in a defined space, the method comprising the steps of introducing a thermally insulating packer fluid into the defined space such that the thermally insulating packer fluid forms a gelled solid and reduces a rate of heat transfer through the defined space as compared to a prior rate of heat transfer through the defined space before introducing the thermally insulating packer fluid, where the thermally insulating packer fluid comprises an acidic nanosilica dispersion and a polyamine.

Abstract: A plugging tool and method of plugging a petroleum well permanently or temporarily is provided. The plugging tool, for instance, is used during a plug and abandonment operation (P&A) or during other operations where setting of a barrier in the well is required, by the use of a multitask tool. The multitasking nature enables the making and sealing verification of a plug in one trip. The multitasking tool comprising interconnected releasable sections, each comprising at least one packer arrangement, perforating means and a vibration device.

Abstract: Spray dried emulsifier compositions are described, which have desirable emulsifying and wetting characteristics. Among other advantages, the solid particulate emulsifier compositions greatly reduce transportation costs and simplify the logistics and environmental concerns associated with shipping large volumes of solvent-containing liquids. The emulsifier comprises (1) a carboxylic acid terminated fatty amine condensate or (2) a modified tall oil or (3) a blend of (1) and (2) that is converted to its alkali or alkaline earth metal salt and spray dried.

Abstract: A method includes conveying a junction isolation tool, a junction support tool, a lateral completion assembly, and a completion deflector into a parent wellbore lined with casing. The completion deflector is coupled to the casing and the lateral completion assembly is detached and advanced into a lateral wellbore. After fracturing the lateral wellbore, the junction isolation tool is detached from the junction support tool, retracted back into the parent wellbore, and coupled to the completion deflector by advancing a stinger into an inner bore of the completion deflector. After hydraulically fracturing a lower wellbore portion of the parent wellbore, the junction isolation tool removes the completion deflector from the parent wellbore.

Abstract: Fluid additives suitable for use in a wellbore (e.g., a liquid comprising an aqueous miscible fluid, a liquid surfactant, or both) may be converted into a liquid-infiltrated porous silica that is a flowable bulk solid. The flowable bulk solid may then be handled and stored as a traditional solid wellbore additive. For example, the flowable bulk solid may be added to an aqueous fluid to produce a wellbore fluid that is then introduced into a wellbore penetrating a subterranean formation.

Abstract: A dissolvable bridge plug configured with components for maintaining anchoring and structural integrity for high pressure applications. These components may substantially dissolve to allow for ease of plug removal following such applications. The plug may effectively provide isolation in a cased well for applications generating over about 8,000-10,000 psi. At the same time, by employment of a dissolve period for the noted components, such a plug may be drilled-out in less than about 30 minutes, even where disposed in a lateral leg of the well.

Abstract: A re-closable toe sleeve is disclosed where the toe sleeve has a port allowing fluid access from the interior of the toe sleeve to the exterior of the toe sleeve. A burst disk is placed inside the port to prevent fluid access from the interior of the toe sleeve to the exterior of the toe sleeve. However upon the fluid in the interior of the toe sleeve reaching a predetermined level the burst disk is removed or otherwise modified to allow fluid access through the port. A sliding sleeve is placed within the toe sleeve so that the sliding sleeve can be moved to cover the port thereby preventing fluid access from the interior of the toe sleeve to the exterior of the toe sleeve or the sliding sleeve may be moved to uncover the port thereby allowing fluid access from the interior of the toe sleeve to the exterior the toe sleeve. The sliding sleeve is mechanically moved from the surface and is typically run into the well in the open position such that the port is uncovered by the sliding sleeve.

Abstract: A wellbore fluid may include a base fluid, and a ground weight material comprising barite and quartz and having a d50 between about 4 and 8 microns and a d90 between about 15-25 microns. The ground weight material of the wellbore fluid may have a specific gravity of less than or equal to about 4.2.

Abstract: A method for transferring barite for use in wellbore fluids may include providing a ground weight material comprising barite and quartz having a d50 between about 4 and 8 and a d90 between about 15-25 microns to a pneumatic transfer vessel, supplying an air flow to the ground weight material in the pneumatic transfer vessel, and pneumatically transferring the ground weight material from the pneumatic transfer vessel to a storage vessel.

Abstract: Some embodiments described herein provide a method comprising method comprising providing an oil-in-water emulsified spacer fluid comprising a binary surfactant mixture, solvent non-aqueous base fluid, and an aqueous base fluid, wherein the binary surfactant mixture comprises a surfactant and an amphiphilic co-surfactant, wherein the surfactant is present in an amount in the range of from about 0.5% to about 30% by weight of the oil-in-water emulsified spacer fluid and wherein the amphiphilic co-surfactant is present in an amount in the range of from about 0.5% to about 30% by weight of the oil-in-water emulsified spacer fluid, and introducing the oil-in-water emulsified spacer fluid into a subterranean formation comprising a residual non-aqueous fluid therein, wherein the binary surfactant mixture in the oil-in-water emulsified spacer fluid emulsifies at least a portion of the residual non-aqueous fluid.

Abstract: Disclosed herein are cement compositions and methods of using cement compositions in subterranean formations. An embodiment comprises a method of cementing in a subterranean formation comprising: providing a cement composition comprising water, a pozzolan, hydrated lime, and a zeolite activator; introducing the cement composition into a subterranean formation; and allowing the cement composition to set in the subterranean formation, wherein the zeolite activator accelerates compressive strength development of the cement composition.

Abstract: A deflector assembly includes an upper deflector arranged within a main bore of a wellbore, the upper deflector having first and second plates spaced apart by a distance. At least one of the first and second plates includes a ramped surface. A lower deflector is arranged within the main bore, the lower deflector defining a first conduit and a second conduit. One of the first and second conduits is in communication with a lower portion of the main bore and another of the first and second conduits is in communication with a lateral bore. The upper and lower deflectors are configured to direct a bullnose assembly into either the lateral bore or the lower portion of the main bore based on a size of a bullnose tip of the bullnose assembly.

Abstract: A method of drilling a subterranean well may include drilling the subterranean well while circulating a wellbore fluid in the subterranean well, wherein the wellbore fluid includes a base fluid; and a ground weight material comprising barite and quartz and having a d50 between about 4 and 8 microns and a d90 between about 15-25 microns.

Abstract: A method of removing a corrodible downhole article having a surface coating includes eroding the surface coating by physical abrasion, chemical etching, or a combination of physical abrasion and chemical etching, the surface coating comprising a metallic layer of a metal resistant to corrosion by a corrosive material.

Abstract: In some embodiments, a subsurface wiping plug apparatus includes an internal bore that extends for less than a length of the apparatus. A ported case encloses internal components of the apparatus such that each port of the case is configured to couple the internal bore to an external side of the case. A plug capsule is coupled to an end of the ported case. The plug capsule contains an internal wiping plug that is releasable by internal pressure.

Abstract: A chromium-free, distributed hardfacing disposable on a surface of a wellsite component is disclosed. The hardfacing includes a metal filler (e.g., nickel) and particles distributed about the filler. The particles include pellets made of tungsten carbide and pieces made of angular molybdenum carbide. The pieces are smaller than the pellets for distribution in the filler between the pellets whereby a uniform distribution of particles is provided about the filler.

Abstract: A method of using a wellbore isolation device comprises: introducing the wellbore isolation device into the wellbore, wherein the isolation device comprises: (A) a matrix, wherein the matrix has a phase transition temperature less than or equal to the bottomhole temperature of the wellbore; and (B) at least one reinforcement area, wherein the reinforcement area: (i) comprises at least a first material, wherein the first material undergoes galvanic corrosion; and (ii) has a greater tensile strength and/or shear strength than the matrix.

Abstract: A ported sub is operated with a pressure actuated shifting sleeve. A first rupture disc is set at a lower pressure than the test pressure for the tubing string that houses the ported sub. The first rupture disc breaks at a lower pressure than the string test pressure to expose well fluids to a disintegrating plug. The plug slowly disintegrates to then expose tubing pressure to a chamber and a second rupture disc with the chamber configured to have no effect on moving the sliding sleeve. When the tubing pressure is then raised to a predetermined pressure below the test pressure for the string, the second disc breaks exposing a piston to tubing pressure on one side and trapped low pressure being the opposite side of the string. The differential moves the sleeve to open a port to let tools be pumped into position without a need to perforate.

Abstract: A method of producing petroleum from at least one open hole in at least one petroleum production zone of a hydrocarbon well comprising the steps of locating a plurality of sliding valves along at least one production tubing; inserting the plurality of sliding valves and the production tubing into the at least one open hole; cementing the plurality of sliding valves in the at least one open hole; opening at least one of the cemented sliding valves; removing at least some of the cement adjacent the opened sliding valves without using jetting tools or cutting tools to establish at least one communication path between the interior of the production tubing and the at least one petroleum production zone; directing a fracing material radially through the at least one sliding valve radially toward the at least one production zone; producing hydrocarbons from the at least one petroleum production zone through the plurality of the sliding valves the cement adjacent to which has been removed.

Abstract: A transition fluid comprises: a hydrocarbon liquid, wherein the hydrocarbon liquid is the external phase of the transition fluid; an aqueous liquid, wherein the aqueous liquid is the internal phase of the transition fluid and wherein the aqueous liquid comprises a water-soluble salt; and a calcium aluminate cement. A method of cementing in a subterranean formation comprises: introducing the transition fluid into the subterranean formation; and introducing a cement composition into the subterranean formation, wherein the step of introducing the cement composition is performed after the step of introducing the transition fluid and wherein the cement composition comprises cement and water.

Abstract: Spray dried emulsifier compositions are described, which have desirable emulsifying and wetting characteristics. Among other advantages, the solid particulate emulsifier compositions greatly reduce transportation costs and simplify the logistics and environmental concerns associated with shipping large volumes of solvent-containing liquids. The emulsifier comprises (1) a carboxylic acid terminated fatty amine condensate or (2) a modified tall oil or (3) a blend of (1) and (2) that is converted to its alkali or alkaline earth metal salt and spray dried.

Abstract: The present invention relates to methods and compositions for the treatment of subterranean formations. In various embodiments, the method includes obtaining or providing a composition including at least one-ion sequestering compound, sequestering at least one ion from a polymer in the composition with the at least one ion-sequestering compound, and contacting a subterranean material downhole with the composition.