Abstract: A method of hydraulic fracturing of an oil producing formation includes the provision of a heating apparatus which is transportable and that has a vessel for containing water. A water stream of cool or cold water is transmitted from a source to a mixer, the cool or cold water stream being at ambient temperature. The mixer has an inlet that receives cool or cold water from the source and an outlet that enables a discharge of a mix of cool or cold water and the hot water. After mixing in the mixer, the water assumes a temperature that is suitable for mixing with chemicals that are used in the fracturing process, such as a temperature of about 40°-120° F.+(4.4-48.9 C+). An outlet discharges a mix of the cool and hot water to surge tanks or to mixing tanks. In the mixing tanks, a proppant and an optional selected chemical or chemicals are added to the water which has been warmed.

Abstract: The present application relates to methods and systems for mitigating condensate banking. In some embodiments, the methods and systems involve altering the wettability of a rock formation in the vicinity of a wellbore for a gas condensate reservoir.

Abstract: A method of evaluating a geometric parameter of a first fracture emanating from a first wellbore penetrating a subterranean formation is provided. The method includes the steps of forming the first fracture in fluid communication with the first wellbore; forming a second fracture in fluid communication with a second wellbore; measuring a first pressure change in the second wellbore in proximity to the first wellbore; and determining the geometric parameter of the first fracture using at least the measured first pressure change in an analysis which couples a solid mechanics equation and a pressure diffusion equation.

Abstract: A dampener device is configured for incorporation into a downhole measurement tool in a drilling system, for absorbing axial, lateral and torsional shocks and vibrations to protect measurement instrumentation located above the device during drilling. The device includes: a main sleeve having a main cavity containing a main spring; an adapter connected to or formed monolithically relative to the main sleeve, the adapter configured for connection to a first tool component; a plunger configured to compress the main spring; a connector configured for connection to a second tool component, the connector attached to or formed monolithically relative to the plunger; a shaft extending between the adapter and the connector, the shaft provided with an anti-rotation structure; and one or more passages leading from the outside of the device into the main cavity. The passages are provided to allow drilling fluid to enter the main cavity to act as vibration dampening fluid.

Abstract: A fracturing system can include a fracturing manifold coupled to a plurality of fracturing trees. The fracturing manifold may include adjustment joints that enable adjustment of the length of the fracturing manifold. The fracturing manifold can also include pivot joints that allow angular displacement of portions of the fracturing manifold with respect to other portions. The adjustment and pivot joints can accommodate spacing and elevation differences between the fracturing trees.

Abstract: Methods and systems for optimizing the placement of perforation clusters in horizontal wells for completion include conveying a carrier through a borehole into a horizontal section of the borehole; obtaining acoustic data using one or more acoustic sensors; defining a first location for each of a plurality of perforation clusters based on a geometrical distribution; identifying a minimum horizontal stress (Shmin) for each first location based on the acoustic data; calculating a differential net pressure for the first locations based on the minimum horizontal stress (Shmin) for each first location; adjusting the location of each of the plurality of perforation clusters to a respective second location such that the differential net pressure of the second locations is less than the differential net pressure of the first locations; and deploying a plurality of perforation clusters to the second locations such that fracturing of a formation at the second locations is achieved.

Abstract: Apparatus and methods for reducing the force required to pull a device from a tubular, the apparatus including a tubular sealing device for mating with a downhole tubular component, the tubular sealing device having an axial length and a longitudinal bore therethrough; and an elongated rod slidably positionable within the longitudinal bore of the tubular sealing device, the elongated rod having a first end, a second end, and an outer surface, the outer surface structured and arranged to provide i) a hydraulic seal when the elongated rod is in a first position within the longitudinal bore of the tubular sealing device, and ii) at least one external flow port for pressure equalization upstream and downstream of the tubular sealing device when the elongated rod is placed in a second position within the longitudinal bore of the tubular sealing device.

Abstract: Selective stimulation ports including sealing device retainers and methods of utilizing the same are disclosed herein. The selective stimulation ports (SSPs) are configured to be operatively attached to a wellbore tubular that defines a tubular conduit. The SSPs include an SSP conduit, which extends at least substantially perpendicular to a wall of the wellbore tubular, and a sealing device receptacle, which defines at least a portion of the SSP conduit and is sized to receive a sealing device. The SSPs also include a sealing device seat, which is shaped to form a fluid seal with the sealing device. The SSPs further include a sealing device retainer, which is configured to retain the sealing device within the sealing device receptacle. The methods include methods of stimulating the hydrocarbon well utilizing the SSPs and/or methods of conveying a downhole tool within the hydrocarbon well utilizing the SSPs.

Abstract: A coiled adaptive seat is held to a smaller diameter for delivery with a tool that can feature a locating lug for desired alignment of the seat with an intended groove in the inner wall of a tubular. The release tool retracts a cover from the seat allowing its diameter to increase as it enters a groove. Alternatively the adaptive seat is released near the groove and pushed axially in the string to the groove for fixation. Once in the groove the inside diameter of the string is a support for a blocking object so that sequential treatment of parts of a zone can be accomplished. The blocking object is removed with pressure, dissolving, milling or disintegration leaving a narrow ledge in the tubular bore from the seat that can simply be left in place or milled as well. An E4#10 from Baker Hughes is modified for adaptive seat delivery.

Abstract: A control system for a CO2 fracking system includes a phase detector, a control valve, and a controller. The phase detector is disposed proximate to at least one of an inlet conduit and an outlet conduit of a fracking component. The control valve is fluidly coupled to the inlet conduit. The controller is communicatively coupled to the phase detector, the control valve, and the fracking component. The phase detector is configured to determine CO2 phase in at least one of a CO2 stream incoming into the fracking component and CO2 phase discharged from the fracking component, and to generate an input signal based on the phase. The controller is configured to control one or both of a flow of the incoming CO2 stream into the fracking component via the control valve and an operation condition of the fracking component, based on the input signal received from the phase detector.

Abstract: A method of designing a well control operation includes obtaining sub-surface data related to a formation surrounding a well, building a geomechanical model of the formation based on the sub-surface data, obtaining operational data related to the well control operation, performing, on a processor, a hydraulic fracture simulation of the formation, wherein the simulation is based on the operational data and the geomechanical model, and determining an estimated volume of fluid required for a fracture to breach an upper surface of the formation.

Abstract: Compositions and methods are provided for treatment of a wellbore in a subterranean formation. Exemplary compositions comprise a mixture of particles, some of the particles being degradable and other particles being elongated, having good compressive strength, and not being readily degradable at the conditions of the formation. The mixture of particles can temporarily bridge or plug fractures within the formation, and thus acts as a temporary diversion agent. After the degradable particles dissolve, the particles which are not readily degradable can remain in the fracture, helping to keep the fracture open and acting as a proppant.

Abstract: A rock fragmentation device and method is provided which includes a shaft and a plurality of expandable members positioned along a length thereof. The shaft has a hollow length therethrough for the passage of a pressurized fluid, and a plurality of feed apertures for delivery of the pressurized fluid to the expandable members. The shaft further includes a feed inlet for receiving the pressurized fluid from a hydraulic system. The plurality of expandable members each have an inner diameter dimensioned to receive the shaft in a tightly engaging connection, and are positioned on the shaft in fluid tight engagement effective for receiving pressurized fluid via the feed apertures without leaking fluid. The expandable members are expandable, upon filling with the pressurized fluid, to sufficient dimensions to break apart rock when fitted inside a cavity formed therein.

Abstract: A method for mining using a laser to cause spalling includes the steps of generating and delivering a laser beam to a work surface of a geological strata having a sought after mineral to be removed from the stratum; moving the laser beam about three perpendicular axes so that a focal point of the laser beam moves across the working surface and rapidly increases the surface temperature of the working surface; providing a source of a cooling media, and delivering the cooling media to the working surface so as to rapidly cool the working surface subsequent to the rapid surface temperature increase generated by the laser beam so as to effect a fracturing of the working surface and to generate a plurality of chips from the working surface; and removing the chips spalled from the working surface.

Abstract: Methods of fracturing a subterranean formation are described wherein sintered ceramic proppants are used in at least two different stages. Each stage can utilize the same or a different type of proppant relative to one or more of the other stages, and the same or a different type of fracturing fluid relative to one or more of the other stages. At least one of the stages uses a proppant having a monodispersity of 3-sigma distribution or lower. A first stage can be used that exhibits at least one proppant performance property having a first value. A second stage can be used that exhibits the same proppant performance property as the first stage but at a value that differs from the first value by at least 10%.

Abstract: Systems and methods for analyzing and designing a customized pulse fracturing operation for fracturing a wellbore in a reservoir formation are disclosed. Pulsed fracturing can create multiple fractures that radiate away from the wellbore while minimizing near wellbore damage. This network can further be extended into the reservoir by utilizing an optimized pumping rate over a predetermined amount of time. The optimized pulse rate and duration can be determined by using a geomechanical and a reservoir simulator which can help in quantifying the production efficiency of the induced fracture network.

Abstract: The use of a distributed fiber optic strain sensor system in horizontal hydraulic fracturing wells to determine several measurements of hydraulic fracture system geometry including number of far-field fractures, hydraulic and propped fracture length, fracture azimuth, and multi-planar fracture complexity.

Abstract: The disclosure pertains to methods for completing a well may comprise lowering a coiled-tubing in the well thus forming an annulus between the casing and the coiled-tubing, pumping down said annulus a treatment fluid above the fracturing pressure of the formation while also pumping fluid through the coiled tubing. The methods may also comprise monitoring in real-time the bottom hole pressure and increasing the pump rate through the coiled-tubing if an increase of bottom hole pressure is observed.

Abstract: Examples of the present disclosure relate to systems and methods for fracturing systems that maintain a substantially constant pressure differential between a first pressure zone and a second pressure zone.

Abstract: A one trip system for perforating and fracking multiple intervals uses a releasable barrier. The barrier can be an inflatable. A pressure booster system is associated with the BHA so that the existing hydrostatic pressure is boosted when the gun or portions thereof are fired. After firing in one interval, the BHA is raised and the barrier is redeployed and the pattern repeats. Instruments allow sensing the conditions in the interval for optimal placement of the gun therein and for monitoring flow, pressure and formation conditions during the fracturing. Circulation between gun firings cleans up the hole. If run in on wireline a water saving tool can be associated with the BHA to rapidly position it where desired. A multitude of perforation charges mounted in the BHA can be selectively fired by selected corresponding detonator based on a predetermined sequence or surface telemetry command.

Abstract: Generally, a system for hydraulic fracturing of a geologic formation. Specifically, a transportable heating apparatus and method for the production of heated water for use in hydraulic fracturing of a geologic formation.

Abstract: A downhole tool is arranged for connection to a fluid-carrying string. The downhole tool includes: a first reversibly expandable sealing element; a second reversibly expandable sealing element placed at an axial distance from the first reversibly expandable sealing element; one or more fluid ports positioned between the two reversibly expandable sealing elements and arranged to be put in fluid communication with the fluid-carrying string; a first anchoring device arranged to engage a pipe body in a well; and one or more electromotors arranged at least to operate the two reversibly expandable sealing elements and the first anchoring device. The downhole tool further includes a first mechanically activatable release mechanism arranged at least to disengage the first anchoring device from the pipe body. A method is for utilizing a downhole tool.

Abstract: A treatment fluid comprising: a base fluid; and a surfactant, wherein the surfactant: (i) is a polymer; and (ii) comprises a hydrophilic head group and a hydrophobic tail group, wherein the hydrophilic head group comprises a protein, and wherein the hydrophobic tail group comprises a lipid. A method of treating a subterranean formation comprising: introducing the treatment fluid into a well, wherein the well penetrates the subterranean formation.

Abstract: Various embodiments disclosed relate to a fracture network model for simulating treatment of subterranean formations. In various embodiments, the present invention provides a method of simulating treatment of a subterranean formation. The method includes flowing a proppant slurry composition including proppant into each of one or more inlets of a fracture network model. The fracture network model includes a solid medium including a channel network, the one or more inlets, and one or more outlets. The channel network is free of fluidic connections leading outside of the solid medium other than the one or more inlets and the one or more outlets. The channel network includes a primary channel fluidly connected to each of the one or more inlets. The channel network also includes at least one secondary channel and fluidly connected to the primary channel, with the primary channel having a channel cross-section with a greater area than an area of a channel cross-section of the secondary channel.

Abstract: A method of evaluating a geometric parameter of a first fracture emanating from a first wellbore penetrating a subterranean formation is provided. The method includes the steps of forming the first fracture in fluid communication with the first wellbore; forming a second fracture in fluid communication with a second wellbore; measuring a first pressure change in the second wellbore in proximity to the first wellbore; and determining the geometric parameter of the first fracture using at least the measured first pressure change in an analysis which couples a solid mechanics equation and a pressure diffusion equation.

Abstract: The present invention relates to water treatment. In one embodiment there is provided a method of treating an aqueous system to inhibit growth of one or more micro-organisms therein and/or to reduce the number of live micro-organisms therein. The method comprises adding treatment agents to said aqueous system and wherein said treatment agents comprise: (a) a phosphonium compound; and (b) an nitro compound.

Abstract: The flow of well treatment fluids may be diverted from a high permeability zone to a low permeability zone within a fracture network within a subterranean formation by use of a divert system comprising dissolvable diverter particulates and proppant. At least a portion of the high permeability zone is propped open with the proppant of the divert system and at least a portion of the high permeability zone is blocked with the diverter particulates. A fluid is then pumped into the subterranean formation and into a lower permeability zone of the formation farther from the wellbore. The diverter particulates in the high permeability zones may then be dissolved at in-situ reservoir conditions and hydrocarbons produced from the high permeability propped zones of the fracture network. The divert system has particular applicability in the enhancement of production or hydrocarbons from high permeability zones in a fracture network located far field from the wellbore.

Abstract: A selective locking apparatus for an indicating tool, the selective locking apparatus includes a mandrel having a rotational collet finger receiving area including a plurality of unlocked-position tracks alternatingly arranged with a plurality of locked-position detents. A rotational collet rotatably supported on the mandrel, the rotational collet including a j-track on an outer periphery of the rotational collet, the rotational collet further including a plurality of rotational collet fingers having heads engageable within the rotational collet finger receiving area of the mandrel.

Abstract: This invention is a fracturing component and method having a fluid and a plurality of three dimensional structures mixed in the fluid wherein each structure has a longitudinal axis, center of mass and center of pressure wherein the center of mass and the center of pressure do not align in a stable manner causing the structure to flutter in the fluid to reduce the structure from settling out of the fluid when injected into a fissure. Each three dimensional structure can include a first end of the structure having a first plane having an angle of incident ?1 offset from perpendicular to the longitudinal axis and a second end of the structure having a second plane having an angle of incident ?2 offset from perpendicular to the longitudinal axis. The difference between ?1 and ?2 can be in a range of 0° to 65°.

Abstract: A system includes a regional blending facility having a number of bulk receiving facilities, where each bulk facility receives and stores a particle type having a distinct size modality, a bulk moving device that transfers particles between the bulk receiving facilities and of a blending/continuously receiving vessel and/or a mixer, and a carrying medium vessel. The mixer receives particles from the blending/continuously receiving vessel and/or the bulk moving device, receives a carrying medium from the carrying medium vessel, mixes the particles with the carrying medium, and provides a mixed treatment fluid. The system includes a fluid conduit that fluidly couples a wellsite location with the regional blending facility, where the fluid conduit delivers the mixed treatment fluid to the wellsite and/or delivers produced fluid from a wellbore positioned at the wellsite to the regional blending facility.

Abstract: A method of reducing restriction in a borehole that is configured for a multizone fracturing operation wherein the borehole has a plurality of plug reception assemblies and each of the plurality of plug reception assemblies includes at least one component configured to disintegrate upon exposure to a selected condition. The method includes exposing the at least one component to a disintegrating environment and facilitating restriction reduction.

Abstract: A method and apparatus for removing the barium and strontium salts in water that flows back to the well head after hydrofracturing in gas well drilling. Trace levels of iron salts may also be removed from the waste frac water, followed by removal of the calcium and magnesium salts, where applicable. The barium and strontium salts are precipitated in the inert sulfate form, which renders the resulting solids mass suitable for conventional landfill or on-site disposal, and more significantly, for potential reuse and as an additive to certain well drilling processes. The calcium and magnesium salts are similarly inert and suitable for conventional disposal. The process may be managed to selectively remove barium and strontium salts to desired levels, depending upon the intended reuse or disposition. The apparatus may be provided in a highly compact portable configuration that is transportable by a highway vehicle.

Abstract: A method that includes obtaining log data of a downhole formation, and characterizing the downhole formation by determining stiffness coefficients including C33, C44, C66, C11, C12, and C13. C13 is a function of C33, C44, C66, and at least one of a kerogen volume and a clay volume derived from the log data. In another method or system, C13 is derived based at least in part on C11 calculated as C11=k1[C33+2(C66?C44)]+k2 or C33 calculated as C33=((C11?k2)/k1)?2(C66?C44), where k1 and k2 are predetermined constants. In another method or system, C13 is derived in part from at least one of a kerogen volume derived from the log data, a clay volume derived from the log data, C11 calculated as C11=k1[C33+2(C66?C44)]+k2, or C33 calculated as C33=((C11?k2)/k1)?2(C66?C44), where k1 and k2 are predetermined constants.

Abstract: Methods for designing lost circulation materials for use in drilling wellbores penetrating subterranean formations may involve inputting a plurality of first inputs into a numerical method, the plurality of first inputs comprising a lost circulation material property input of a first LCM; calculating a plurality of first outputs from the numerical method; inputting a plurality of second inputs into the numerical method, the plurality of second inputs comprising the lost circulation material property input of a second lost circulation material; calculating a plurality of second outputs from the numerical method; comparing the first outputs to the second outputs; and developing a drilling fluid comprising a third lost circulation material based on the comparison of outputs.

Abstract: A sleeve fracturing assembly includes a composite sleeve and an opening tool. The composite sleeve and the opening tool can automatically engage with each other via teeth-shaped members arranged thereon so as to open the composite sleeve. A sleeve fracturing device includes a plurality of composite sleeves and opening tools, wherein each composite sleeve and opening tool can achieve unique engagement. A method of using the sleeve fracturing device is also provided.

Abstract: A slick water fracturing fluid including a brine, an inorganic nitrate, a nitrogen reducing bacteria, a scale inhibitor selected from the group consisting of a polyacrylate polymer, a polyacrylate copolymer, a polyacrylate terpolymer, and mixtures thereof, and a friction reducer, wherein the friction reducer is a polyacrylamide.

Abstract: A pressure relief device and a hydraulic fracturing system having a pressure relief device are provided. In one form, the pressure relief device has a valve body with a linearly extending throughbore between the inlet and outlet thereof. A rupture disc is secured in the valve body so that a frangible dome wall portion thereof has a reverse-acting orientation in the valve body bore. The hydraulic fracturing system includes a pump and a delivery line that receives pressurized fracturing fluid from the pump and delivers it to a well. A pressure relief device is installed along the delivery line. A sensor detects fluid flow downstream of the pressure relief device which allows the pump to be shut down when the downstream fluid flow is detected. The pressure relief device can have a body with a domed rupture disc and the sensor therein.

Abstract: There is provided high power laser systems, high power laser tools, and methods of using these tools and systems for cutting, sectioning and removing structures objects, and materials, and in particular, for doing so in difficult to access locations and environments, such as offshore, underwater, or in hazardous environments, such as nuclear and chemical facilities. Thus, there is also provided high power laser systems, high power laser tools, and methods of using these systems and tools for removing structures, objects, and materials located offshore, under bodies of water and under the seafloor.

Abstract: In at least some embodiments, a system for pump down operations includes a wireline unit and a pump unit. The system also includes a controller coupled to the wireline unit and the pump unit. The controller is to automate at least one control function selected from the group consisting of: a pump rate for the pump unit based on at least one of a monitored wireline speed and a monitored wireline tension for the wireline unit; and a wireline speed for the wireline unit based on at least a monitored pump rate for the pump unit.

Abstract: A method of treating a subterranean formation includes combining self-degrading particles with a carrier fluid, placing the self-degrading particles and the carrier fluid into a zone in a formation, said zone comprising fractures, allowing the self-degrading materials to penetrate and plug off the connection to existing fractures and to bridge off fracture propagation near the wellbore, and initiating a re-fracture treatment comprising re-fracture fluids and proppant materials prior to the degradation of the self-degrading particles.

Abstract: A method of opening an orifice in a downhole article includes forming a downhole article having an orifice, the orifice having a selectively removable plug sealingly disposed therein, the selectively removable plug comprising a selectively removable plug body formed of a plug body material and a selectively removable sealant coating formed of a coating material disposed on an outer surface thereof. The method also includes disposing the article within a wellbore. The method further includes exposing the selectively removable plug to a first wellbore fluid that is configured to selectively remove the sealant coating and provide a fluid access to the plug body. The method also includes exposing the selectively removable plug body to a second wellbore fluid through the fluid access that is configured to selectively remove the plug body.

Abstract: An embodiment of a method for constructing a fracture network includes: receiving seismic data collected from a stimulation operation in an earth formation, the seismic data including seismic event data including a first seismic event associated with a first time increment and a second seismic event associated with a subsequent second time increment; and constructing a fracture network model. The model is constructed by: constructing an initial portion of the model based on the first seismic event; and subsequently updating the initial portion of the model based on the second seismic event.

Abstract: A wellbore servicing system comprising one or more wellbore tool nodes disposed within a wellbore, wherein each of the one or more wellbore tool nodes is configurable from a first configuration to a second configuration, and a controller node, wherein the controller node communicates with the wellbore tool node via a near field communication (NFC) signal.

Abstract: In some aspects, a closed boundary is computed based on locations of microseismic events associated with a stimulation treatment of a subterranean region. Based on the boundary, a stimulated reservoir volume (SRV) for the stimulation treatment is identified. The boundary encloses a first subset of the locations and a second, different subset of the locations reside outside the boundary.

Abstract: In some aspects, a boundary is computed based on locations of microseismic events associated with a stimulation treatment of a subterranean region. A major axis of a stimulated reservoir volume (SRV) for the stimulation treatment is identified based on the boundary. In some examples, the boundary is an ellipsoid, and the major axis of the ellipsoid is identified.

Abstract: Downhole tools for use in oil and gas production which degrade into non-toxic materials, a method of making them and methods of using them. A frac ball and a bridge plug comprised of polyglycolic acid which can be used in fracking a well and then left in the well bore to predictably, quickly, and safely disintegrate into environmentally friendly products without needing to be milled out or retrieved.

Abstract: A method, computer-readable medium and apparatus for delivering a material to a downhole location in a formation is disclosed. A device is operated at a surface location to produce an action at the downhole location related to delivery of the material to the formation. A downhole parameter is measured at the downhole location, wherein the downhole parameter is affected by the operation of the device at the surface location. The downhole parameter is measured using a sensor proximate the downhole location. The measured downhole parameter is used to alter operation of the device at the surface location to deliver the material to the formation at the downhole location.

Abstract: A method and apparatus for sequestering carbon dioxide (CO2) gas and releasing natural gas from underground coal and/or gas shale formations using CO2 gas captured from the flue gas of a coal burning power plant, and processing it to produce cold liquid pressurized CO2, and injecting the cold liquid CO2 under pressure to create fractures within the formation and causing the CO2 to be adsorbed into the coal or gas shale and natural gas (CH4) to be desorbed, released and recovered. A special pressure cycling process is used to enable the pressure within the formation to be increased and decreased, including allowing the liquid CO2 to change phase to a gaseous CO2, and injecting the liquid CO2 under pressure repeatedly, which causes greater expansion of the proliferation zone within the formation, and more efficiently releases CH4.

Abstract: Apparatus and methods of treating a subterranean formation including introducing a coiled tubing string into a wellbore to a wellbore zone, wherein the string comprises a packer on a bottom hole assembly; introducing an acid fracture treatment through the string; introducing bridging fluid comprising particulates through the string; circulating a portion of fluid in the wellbore; introducing a final portion of fluid with a higher concentration of particulates to further form and consolidate bridge-packer, wherein the concentration of particulates in the final portion of fluid is higher than the introducing the bridging fluid comprising the particulates; squeezing the bridging fluid to isolate a perforation into the zone; moving the string to next zone; and repeating introducing and moving.

Abstract: A cement masking system includes a tubular having a wall with at least one radial port. At least one swellable member is arranged to cover the at least one port. The at least one swellable member is configured to at least partially displace cement radially of the tubular during radial expansion of the at least one swellable member. A method of masking ports in a tubular from cement employs the cement masking system.