Apparatus and methods for measuring the efficiency of a thermal catalytic combustion unit. An example method provides a thermal catalytic combustion unit, a drying unit fluidically connected to the thermal catalytic combustion unit and configured to be downstream of the thermal catalytic combustion unit, and a sensor fluidically connected to the thermal catalytic combustion unit and configured to be downstream of the thermal catalytic combustion unit. The method further includes flowing a formation fluid sample through the thermal catalytic combustion unit, flowing a formation fluid sample through the drying unit, and sensing the formation fluid sample with the sensor after the formation fluid sample has flowed through the thermal catalytic combustion unit. The sensing detects the presence of a hydrocarbon and/or carbon monoxide in the formation fluid sample.
A method for preparing a wellbore treatment fluid includes contacting a fluid with a high temperature suspension additive to form the wellbore treatment fluid. The high temperature suspension additive can be a reaction product of at least one monomer, a thermally unstable crosslinker, and a thermally stable crosslinker comprising a compound with at least four functional groups. Also, the high temperature suspension additive can maintain a viscosity of the wellbore treatment fluid at a temperature of at least 250° F. (121° C.) for at least about 4 hours with a viscosity equal to or greater than about 25% of a peak viscosity.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 24/26 - Macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
Described herein are systems and techniques related to a propulsion device that moves equipment along a wellbore. While wellbore equipment may be deployed in a wellbore using gravity or with the flow of a fluid like drilling mud, in certain instances, such techniques are not well suited to this task. Systems and techniques of the present disclosure may be applied to deploy tools in a wellbore by controlling motion of a self-propelled device along the wellbore. This may include using wheels, tracks, propellers, impellers, or other devices to propel tools into a wellbore even when the wellbore has perforations that may disrupt conventional deployment techniques. Techniques of the present disclosure may include transferring power to a wellbore apparatus via one or more elements of a fiber optic cable.
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 47/135 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
4.
SYSTEM AND METHOD FOR DELIVERING PROPPANT FROM A PROPPANT SOURCE TO A WELL SITE
A proppant delivery system for delivering proppant to a well site comprises a first vehicle having a first container configured to carry a first load of proppant and deliver the first load of proppant to a location. The system further comprises a second vehicle configured to deliver a second container at the location to receive a portion of the first load into the second container. The container remains on the second vehicle during loading of the second container.
B65D 88/30 - Hoppers, i.e. containers having funnel-shaped discharge sections specially adapted to facilitate transportation from one utilisation site to another
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
A method for managing one or more hydrocarbon wells. The method comprises obtaining a well dataset for the one or more hydrocarbon wells and identifying one or more entities within the well dataset, wherein each of the one or more entities has at least one corresponding well attribute and corresponding entity dates. The method comprises generating a network graph of the one or more entities based on a similarity index between the one or more entities, wherein the similarity index utilizes the corresponding well attributes. The method comprises identifying a first cluster of the one or more entities within the network graph, wherein the one or more entities within the first cluster correspond to a first hydrocarbon well of the one or more hydrocarbon wells. The method comprises generating, on a display device, a visualization of the first hydrocarbon well including the one or more entities of the first cluster.
A system that includes an anchor that includes a first slot and a second slot, and a latch that includes a first key and a second key, where while the latch undergoes latch translation, the first key and the second key are adapted to translate into the first slot and the second slot, respectively.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
A method for preparing a wellbore treatment fluid includes contacting a fluid with a high temperature suspension additive to form the wellbore treatment fluid. The high temperature suspension additive can be a reaction product of at least one monomer, a thermally unstable crosslinker, and a thermally stable crosslinker comprising a compound with at least four functional groups. Also, the high temperature suspension additive can maintain a viscosity of the wellbore treatment fluid at a temperature of at least 250 °F (121 °C) for at least about 4 hours with a viscosity equal to or greater than about 25% of a peak viscosity.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
E21B 33/138 - Plastering the borehole wallInjecting into the formation
Disclosed herein are various embodiments of an isolation device comprising a top slip, a top slip prop in engagement with the top slip, a bottom slip, a bottom slip prop in engagement with the bottom slip, a packer element positioned between the top slip prop and the bottom slip prop, wherein movement of the top slip prop and the bottom slip prop towards each other causes the packer element to expand outwardly, an annular receptacle formed between the inner mandrel and the top slip prop, and a pressure transfer sleeve at least partially disposed within the annular receptacle.
Provided is a downhole tool and a well system. The downhole tool, in one aspect, includes a tubular providing one or more production fluid flow paths for a production fluid. The downhole tool, according to this aspect, further includes one or more float chambers located within the tubular, and two or more floats located within the one or more float chambers. In one aspect, a first of the two or more floats has a first density (ρ1) between a density of gas (ρg) and a density of oil (ρo), and a second of the two or more floats has a second density (ρ2) between the density of oil (ρo) and a density of water (ρw). The downhole tool, according to this aspect, further includes two or more non-contact proximity sensors configured to sense a radial location of the two or more floats to determine a gas:oil ratio and oil:water ratio.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
G01N 9/12 - Investigating density or specific gravity of materialsAnalysing materials by determining density or specific gravity by observing bodies wholly or partially immersed in fluid materials by observing the depth of immersion of the bodies, e.g. hydrometers
Methods can include preparing a thermally stable additive, comprising contacting at least one monomer, at least one thermally unstable crosslinker, and at least one thermally stable crosslinker with a solvent system to form a mixture; and reacting the at least one monomer, the at least one thermally unstable crosslinker, and the at least one thermally stable crosslinker in a reaction zone under conditions suitable to produce the thermally stable additive. The thermally stable additive increases viscosity of a wellbore treatment fluid at a high temperature by about two to about twelve times higher as compared to a suspension additive comprising the at least one monomer, the at least one thermally unstable cross linker, and the at least one thermally stable cross linker prepared in a single solvent system.
Apparatus and methods for measuring the efficiency of a thermal catalytic combustion unit. An example method provides a thermal catalytic combustion unit, a drying unit fluidically connected to the thermal catalytic combustion unit and configured to be downstream of the thermal catalytic combustion unit, and a sensor fluidically connected to the thermal catalytic combustion unit and configured to be downstream of the thermal catalytic combustion unit. The method further includes flowing a formation fluid sample through the thermal catalytic combustion unit, flowing a formation fluid sample through the drying unit, and sensing the formation fluid sample with the sensor after the formation fluid sample has flowed through the thermal catalytic combustion unit. The sensing detects the presence of a hydrocarbon and/or carbon monoxide in the formation fluid sample.
Methods can include preparing a thermally stable additive, comprising contacting at least one monomer, at least one thermally unstable crosslinker, and at least one thermally stable crosslinker with a solvent system to form a mixture; and reacting the at least one monomer, the at least one thermally unstable crosslinker, and the at least one thermally stable crosslinker in a reaction zone under conditions suitable to produce the thermally stable additive. The thermally stable additive increases viscosity of a wellbore treatment fluid at a high temperature by about two to about twelve times higher as compared to a suspension additive comprising the at least one monomer, the at least one thermally unstable cross linker, and the at least one thermally stable cross linker prepared in a single solvent system.
A method for managing one or more hydrocarbon wells. The method comprises obtaining a well dataset for the one or more hydrocarbon wells and identifying one or more entities within the well dataset, wherein each of the one or more entities has at least one corresponding well attribute and corresponding entity dates. The method comprises generating a network graph of the one or more entities based on a similarity index between the one or more entities, wherein the similarity index utilizes the corresponding well attributes. The method comprises identifying a first cluster of the one or more entities within the network graph, wherein the one or more entities within the first cluster correspond to a first hydrocarbon well of the one or more hydrocarbon wells. The method comprises generating, on a display device, a visualization of the first hydrocarbon well including the one or more entities of the first cluster.
E21B 47/002 - Survey of boreholes or wells by visual inspection
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 47/125 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using earth as an electrical conductor
Various examples of self-contained electrical power generation assemblies are described, the assemblies configured to generate electrical power using a flow of fluid flowing through a conduit configured as part of a wellbore tool or wellbore production tubing, the electrical power generation assemblies configured to be located downhole at various positions along a drill string, a section of production tubing, or some other type of conduit configured to provide a fluid passageway for a flow of one or more types of fluid within a wellbore.
Compositions and methods using subterranean treatment fluids comprising water-soluble polymers are provided. In some embodiments, the methods include: adding an anionic or amphoteric water-soluble polymer to a treatment fluid comprising an aqueous base fluid; adding a dewatering agent to the treatment fluid, wherein the dewatering agent comprises an aqueous phase, a solvent, a co-solvent, and one or more surfactants selected from the group consisting of: ethoxylated alcohol, a polyamine polyether, a resin alkoxylated oligomer, and any combination thereof; and introducing the treatment fluid into a well bore penetrating at least a portion of the subterranean formation.
C08L 101/14 - Compositions of unspecified macromolecular compounds characterised by physical features, e.g. anisotropy, viscosity or electrical conductivity the macromolecular compounds being water soluble or water swellable, e.g. aqueous gels
C09K 8/68 - Compositions based on water or polar solvents containing organic compounds
E21B 43/22 - Use of chemicals or bacterial activity
A system can be provided for supplying power to downhole equipment during a wellbore operation performed with respect to a wellbore. The system can include a tubing positioned downhole in the wellbore. The system can also include a tubing encapsulated conductor (TEC) positioned downhole in the wellbore. The TEC can be in contact with the tubing at one or more locations along a length of the tubing. The TEC can include an interior wire for transmitting electricity from a power source to at least one piece of electrical equipment during the wellbore operation. The TEC can also include a metal sheath positioned around the interior wire and a conductive encapsulation layer. The conductive encapsulation layer can be positioned on an outer side of the metal sheath and can be positioned to facilitate one or more electrical couplings between the metal sheath and the conductive item at the one or more locations.
A system can be provided for supplying power to downhole equipment during a wellbore operation performed with respect to a wellbore. The system can include a tubing positioned downhole in the wellbore. The system can also include a tubing encapsulated conductor (TEC) positioned downhole in the wellbore. The TEC can be in contact with the tubing at one or more locations along a length of the tubing. The TEC can include an interior wire for transmitting electricity from a power source to at least one piece of electrical equipment during the wellbore operation. The TEC can also include a metal sheath positioned around the interior wire and a conductive encapsulation layer. The conductive encapsulation layer can be positioned on an outer side of the metal sheath and can be positioned to facilitate one or more electrical couplings between the metal sheath and the conductive item at the one or more locations.
E21B 41/00 - Equipment or details not covered by groups
E21B 47/125 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using earth as an electrical conductor
18.
FLOW TUBE AND FLAPPER CONFIGURATION OF A SAFETY VALVE FOR A PRODUCTION WELLBORE
A safety valve for a wellbore for production of hydrocarbons from a surrounding subsurface formation includes a flow tube through which a flow of fluids from the surrounding subsurface formation downhole to a surface of the wellbore, wherein the flow tube comprises a lower end through which the flow of fluids is to enter the flow tube, wherein the flow tube is composed of metal, except for at least a cut out section of the lower end that is composed a polymeric material. The safety valve includes a flapper configured close the safety valve by changing positions to cover an opening at the lower end of the flow tube such that an impact force of the closing on the flapper onto the flow tube is at least partially absorbed by the polymeric material.
A system and a method for implementing a squeeze treatment to apply a scale inhibitor in a wellbore are provided. An exemplary method includes mixing a scale inhibitor pill. The scale inhibitor pill includes polyamino polyether methylene phosphonic acid (PAPEMP) and amino trimethylene phosphonic acid (ATMP). Pre-flush chemicals are injected into the wellbore. The scale inhibitor pill is injected into the wellbore. An over flush is injected into the wellbore. The wellbore is shut in for a target period of time and normal production is resumed.
C09K 8/528 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
C09K 8/536 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
20.
CHECK VALVE ADAPTER FOR ELECTRICAL SUBMERSIBLE PUMPS
One or more check valves may be used in a motor protector for an ESP assembly. Disclosed embodiments relate to a check valve adapter configured to provide additional versatility regarding such check valves. The adapter may have a first end portion, configured for removable attachment to an NPT screw-style vent port, and a second end portion configured to receive a cartridge-style check valve. The first end portion of the adapter is in fluid communication with the second end portion, and the second end portion can be configured to receive the cartridge-style check valve in either orientation, thereby allowing fluid flow through the adapter in either direction merely based on the orientation of the cartridge-style check valve. Systems for using an adapter with a cartridge-style check valve in an ESP assembly, as well as methods of controlling fluid flow in a motor protector using such an adapter, are also disclosed.
A system can be used to deploy a wet mate connector radially outward. The system can include a first sub-assembly and a second sub-assembly. The first sub-assembly can include a first wet mate connector and a deflection profile. The second sub-assembly can include (i) a wet mate carrier that can include a second wet mate connector and can be located on a second surface of the second sub-assembly, and (ii) a deflection actuator. The deflection actuator can be displaced by the deflection profile to cause the wet mate carrier to deflect outward to cause the second wet mate connector to couple with the first wet mate connector.
E21B 47/125 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using earth as an electrical conductor
22.
CHECK VALVE ADAPTER FOR ELECTRICAL SUBMERSIBLE PUMPS
One or more check valves may be used in a motor protector for an ESP assembly. Disclosed embodiments relate to a check valve adapter configured to provide additional versatility regarding such check valves. The adapter may have a first end portion, configured for removable attachment to an NPT screw-style vent port, and a second end portion configured to receive a cartridge-style check valve. The first end portion of the adapter is in fluid communication with the second end portion, and the second end portion can be configured to receive the cartridge-style check valve in either orientation, thereby allowing fluid flow through the adapter in either direction merely based on the orientation of the cartridge-style check valve. Systems for using an adapter with a cartridge-style check valve in an ESP assembly, as well as methods of controlling fluid flow in a motor protector using such an adapter, are also disclosed.
Systems and methods for downhole drilling and, more particularly, hydraulic control systems and methods for hydraulically locking and unlocking moveable elements of a drill bit are provided. A drill bit may include a body; a moveable element secured to the body, wherein the moveable element is configured to extend or retract from a surface of the drill bit; a communication channel from the moveable element to a bore in the body; and a hydraulic control system at least partially disposed in the body, wherein the hydraulic control system is configured to at least provide fluid communication from the bore to the communication channel to thereby lock or unlock the moveable element.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
24.
SYSTEMS AND METHODS FOR CONDUCTING HYDRAULIC FRACTURING OPERATIONS
A method of designing a multi-well fracturing operation comprising determining a probability of a large fracture stress extending from a treatment wellbore contacting an observation wellbore with a fracture model. The treating wellbore and the observation wellbore are arranged in a wellbore pattern within a subterranean formation. Determining with the fracture model a probability of a small fracture stress from a fracturing operation on the observation wellbore providing a threshold value of fracture conductivity to achieve a desired drainage radius for the observation wellbore. Outputting the treatment wellbore, the observation wellbore, the wellbore pattern, and the fracturing operation in response to the volume of fracturing fluid utilized in the observation wellbore being less than a threshold value.
36 - Financial, insurance and real estate services
41 - Education, entertainment, sporting and cultural services
Goods & Services
Business incubation and accelerator support services for others, namely, providing business advice in the field of energy, access to facilities in the nature of providing work space containing business equipment, and business networking and funding opportunities in the nature of matching potential private investors with entrepreneurs needing funding, all to clean energy early-stage companies; Business development services, namely, providing start-up support for businesses of others; Business development consulting services Business incubation and accelerator support services for others, namely, providing access to facilities in the nature of rental of office space to clean energy early-stage companies; business incubation and accelerator support services for others, namely, providing funding opportunities in the nature of providing venture capital, development capital, private equity, and investment funding to clean energy early-stage companies Business incubation and accelerator support services for others, namely, providing mentorship in the field of energy to clean energy early-stage companies
26.
CURRENT-CONTROLLED CIRCUIT BREAKER FOR ELECTRICAL SUBMERSIBLE PUMP MOTOR LEADS
Some implementations include an apparatus configured to, in a wellbore, eliminate voltage on one or more first conductors that are electrically connected to a surface-based power source. The apparatus may include a shorting ring electrically connectable to the first conductors and configured to electrically short the first conductors upon establishing an electrical connection with the first conductors. The apparatus may include a solenoid assembly to actuate in response to power on the first conductors from the surface-based power source. The apparatus may include a pin slider assembly connected to the first conductors and configured to move, in response to actuation by the solenoid assembly, between an electrical connection with the shorting ring and an electrical connection with one or more second conductors that have an electrical connection with a permanent magnet motor winding in the wellbore.
H02H 7/22 - Emergency protective circuit arrangements specially adapted for specific types of electric machines or apparatus or for sectionalised protection of cable or line systems, and effecting automatic switching in the event of an undesired change from normal working conditions for distribution gear, e.g. bus-bar systemsEmergency protective circuit arrangements specially adapted for specific types of electric machines or apparatus or for sectionalised protection of cable or line systems, and effecting automatic switching in the event of an undesired change from normal working conditions for switching devices
H02H 1/00 - Details of emergency protective circuit arrangements
27.
POWERED ORIENTATION OF DOWNHOLE SEPARATORS IN A WELL
In some implementations, a downhole oil-water separation (DOWS) assembly may be configured to be disposed downhole in a well. The DOWS assembly may include a DOWS device configured to operate on fluids in the DOWS assembly. The DOWS assembly also may include a controller configured to determine an orientation of the DOWS device and to cause a change to the orientation of the DOWS device.
In some implementations, a system includes a cartridge configured for insertion into a flow path in a well, wherein the cartridge includes one or more devices to separate fluids. The system also may include an elongated Y-block including a working space configured to enable a tool to remove the cartridge from the flow path.
A variety of methods and apparatus are disclosed, including, in one embodiment, a downhole tool for use in a borehole, wherein the downhole tool comprises a composite of an aromatic copolyester thermoset (ACT) and a reinforcement material, wherein the ACT has a glass transition temperature of at least 150° C., wherein the ACT is configured to degrade in a water-based fluid having high pH, and wherein the method can include providing the water-based fluid having the pH, such as a pH of at least 11, at least 12, at least 13, or at least 14 in the wellbore, thereby degrading or dissolving the ACT of the downhole tool in the wellbore.
Provided is a multilateral lateral bore completion, a well system, and a method. The multilateral lateral bore completion, in one embodiment, includes a tubular having a first end and a second end, and first and second packers located on a radial exterior surface of the tubular, the first and second packers configured to move from a radially retracted state to a radially extended state to engage with a wellbore tubular. The multilateral lateral bore completion, in accordance with this embodiment, further includes a transition joint coupled to the first end of the tubular, the transition joint configured to extend out into a main wellbore, and an expandable metal anchor positioned on the radial exterior surface of the transition joint, the expandable metal anchor including a metal configured to expand in response to hydrolysis to axially and rotationally fix the transition joint with respect to the wellbore tubular.
E21B 41/00 - Equipment or details not covered by groups
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
Provided is a multilateral mainbore completion, a well system, and a method. The multilateral mainbore completion, in one aspect, includes a tubular having a first end and a second end, and first and second packers located on a radial exterior surface of the tubular, the first and second packers configured to move from a radially retracted state to a radially extended state to engage with a wellbore tubular and separate the wellbore tubular into first and second production zones. The multilateral mainbore completion, in this one aspect, may further include an expandable metal anchor positioned on the radial exterior surface of the tubular, the expandable metal anchor including a metal configured to expand in response to hydrolysis to axially and rotationally fix the tubular with respect to the wellbore tubular.
E21B 41/00 - Equipment or details not covered by groups
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
A method for expanding a two-stage expandable liner hanger includes expanding a first section of an expandable tubular having the first section and a second section. The first section includes one or more anchoring ribs. The method further includes expanding the second section of the expandable tubular after cement is pumped into the expandable tubular.
E21B 43/10 - Setting of casings, screens or liners in wells
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
Lateral access control in downhole window joint is provided via a window joint. The window joint includes an interior cavity with a first end and a second end opposite to the first end, a first opening defined at the first end, and a lateral opening through a wall of the window joint and into the interior cavity between the first end and the second end. The window joint also includes a deflector where, in a first state, the deflector permits access between the first end and the second end and, in a second state, the deflector blocks access between the first end and the second end and permits access between the first end and the lateral opening by deflecting an object travelling through the lateral opening. The window joint also includes an access control system configured to transition the deflector between the first state and the second state.
A hydraulic cement composition is provided. The composition comprises a hydraulic cement and at least one anti-corrosion agent selected from the group consisting of urea, derivatives of urea, and combinations thereof. The composition can be mixed with water to form a carbon dioxide-resistant hydraulic cement slurry. A hydraulic cement slurry and a method of cementing in a carbon dioxide environment are also provided.
C04B 111/00 - Function, property or use of the mortars, concrete or artificial stone
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
35.
RATE LIMITING DEVICE TO ENHANCE THE PERFORMANCE RATIO AND LONGEVITY OF A WELLBORE INFLOW CONTROL DEVICE
An apparatus to be positioned in a wellbore formed in a subsurface formation. The apparatus comprises one or more generators disposed in a flow path within a flow control tool and configured to output electrical power to components of the flow control tool in response to flow of a fluid in the flow path, wherein the fluid enters the flow path from the wellbore. The apparatus comprises a flow rate limiting device disposed in the flow path and configured to control a flow rate of the fluid as the fluid flows to the one or more generators.
A machine learning-based system for automatically identifying and locating depositions or leaks in a conduit associated with a hydrocarbon well operation. The system may train a machine learning model using a training dataset comprising a multitude of measured pressure data samples received from a conduit monitoring system that operates by introducing a pressure wave into a conduit and using a sensor to measure the magnitude of pressure waves reflected by surfaces or objects in the conduit. The pressure data samples can be filtered to remove noise and focus on a frequency range of interest prior to being used to train the machine learning model. The machine learning model may be trained, using key attributes of the pressure data samples, to generate a predictive model that can predict a deposition or leak in a conduit of interest based on new measured pressure data associated with the conduit of interest.
In general, in one aspect, embodiments relate to a charge tube assembly that includes a charge tube, a detonator housing interlocked with the charge tube, an end alignment interlocked with the charge tube, and a detonation cord extending from the detonator housing to the charge tube.
A variety of methods/systems/apparatus/compositions are disclosed, including, in one embodiment, a downhole tool (for use in a borehole) having a mandrel, a sealing element including metal particles disposed about the mandrel, and a piston to move a containment component of the downhole tool in an axial direction to move the metal particles in the axial direction, thereby displacing the metal particles in a radial direction toward a borehole wall to expand the sealing element in the radial direction to form a seal between the downhole tool and the borehole wall.
An apparatus comprises one or more solids separators to be positioned downhole in a well formed in a subsurface formation, wherein each of the one or more solids separators are configured to receive a fluid from the subsurface formation and separate out sediment from the fluid, wherein the sediment is transported after separation to a destination location.
A system comprises a downhole separation system configured to be positioned downhole a well formed in a subsurface formation, wherein the downhole separation system is configured to receive formation fluid from the subsurface formation and configured to separate formation fluid into a production fluid and a nonproduction fluid. The downhole separation system comprises at least one device to be positioned in an opening of a downhole tubular through which the formation fluid is to be received from the subsurface formation, wherein the at least one device is to filter out at least a portion of solids in the formation fluid from entering the downhole tubular; and a controller configured to initiate an operation to clean the at least one device using a cleaning fluid.
A system for downhole separation of at least one of fluids or solids comprises a fluid flow diverter to be positioned downhole in a well. The fluid flow diverter is configured to receive a formation fluid in a multilayer flow structure that comprises a production fluid and a nonproduction fluid, wherein the fluid flow diverter is configured to separate the production fluid and the nonproduction fluid by being adjusted such that more of the production fluid is above the fluid flow diverter than below the fluid flow diverter and such that more of the nonproduction fluid is below the fluid flow diverter than above the fluid flow diverter.
Some implementations relate to a downhole separation system configured to be positioned downhole in a well formed in a subsurface formation, wherein the downhole separation system is configured to receive a formation fluid from the subsurface formation and configured to separate the formation fluid into a first fluid primarily comprised of a production fluid and a second fluid primarily comprised of a nonproduction fluid, the downhole separation system including, at least a first coalescer to be positioned within a downhole tubular, wherein the first coalescer is configured to separate out at least a portion of debris and the production fluid from the second fluid.
Provided is a multilateral junction sleeve assembly, a well system, and a method. The multilateral junction sleeve assembly, in one aspect, includes a multilateral deflector assembly, the multilateral deflector assembly including a deflector body having a deflector face and an opening extending therethrough, as well as a deflector assembly sleeve coupled to an uphole end of the deflector body, the deflector assembly sleeve having a sidewall opening in a sidewall thereof aligned with the deflector face. The multilateral junction sleeve assembly, in accordance with this aspect, further includes degradable material positioned on a radial exterior surface of the deflector assembly sleeve covering the sidewall opening, the degradable material configured to degrade over time and uncover the sidewall opening.
E21B 41/00 - Equipment or details not covered by groups
E21B 33/129 - PackersPlugs with mechanical slips for hooking into the casing
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
44.
MULTILATERAL LATERAL BORE COMPLETION EMPLOYING AN EXPANDABLE METAL ANCHOR ON THE EXPANSION JOINT
Provided is a multilateral lateral bore completion, a well system, and a method. The multilateral lateral bore completion, in one embodiment, includes a tubular having a first end and a second end, and first and second packers located on a radial exterior surface of the tubular, the first and second packers configured to move from a radially retracted state to a radially extended state to engage with a wellbore tubular. The multilateral lateral bore completion, in accordance with this embodiment, further includes a transition joint coupled to the first end of the tubular, the transition joint configured to extend out into a main wellbore, and an expandable metal anchor positioned on the radial exterior surface of the transition joint, the expandable metal anchor including a metal configured to expand in response to hydrolysis to axially and rotationally fix the transition joint with respect to the wellbore tubular.
Provided is a multilateral downhole assembly, a well system, and a method. The multilateral downhole assembly, in one aspect, includes a multilateral deflector assembly, the multilateral deflector assembly including a deflector body having a deflector face and an opening extending therethrough, and a running tool, the running tool coupled to the multilateral deflector assembly using a degradable material coupling mechanism, the degradable material coupling mechanism configured to degrade over time and allow the running tool to release from the multilateral deflector assembly..
Provided is a multilateral junction assembly, a well system, and a method. The multilateral junction assembly, in one aspect, includes a transition sleeve assembly, the transition sleeve assembly including a transition sleeve body having a sidewall opening in a sidewall thereof, the sidewall opening configured to align with a main wellbore when the transition sleeve assembly is at least partially insert within a lateral wellbore, and degradable material positioned on a radial surface of the transition sleeve body covering the sidewall opening, the degradable material configured to degrade over time and uncover the sidewall opening.
A variety of methods and apparatuses are disclosed, including, in one embodiment, an apparatus comprising a hollow profile for downhole in a borehole, the hollow profile comprising a composite of an aromatic copolyester thermoset (ACT) and a reinforcement material, wherein the reinforcement material comprises fibers or particles, or both.
Prepare a work order (WO) by: collecting user input; running an initial CFD-based cementing operation simulation, outputting a CFD result including simulated annular placement of cement with insufficient DE. Choose a section of casing; simulate mechanically coupling a turbulator to adjust displacement efficiency (DE) of cement within the annulus before casing installation; adjust turbulator mechanical properties to maximize DE; create the WO including adjusting turbulator spacing along the casing of the wellbore to one turbulator per joint; perform an additional CFD-based simulation with adjusted turbulator spacing to update and output simulated annular placement of cement and DE; determine a change in DE; adjust the WO based on a further simulation loop; and finalize the WO. Cement the wellbore by: transporting turbulators to a wellsite; installing wellbore casing spaced by turbulator spacing of the finalized WO; and pumping cement into the annulus, the cement contacting the turbulators to reduce channeling.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
49.
DESTABLIZING TURBULENCE IN DOWNHOLE FLUID AND SOLID SEPARATION IN A WELL
Some implementations may include a downhole oil-water separation (DOWS) system configured to be positioned downhole in a well. The DOWS system may include a perturbation device configured to be positioned in a borehole of the well and configured to perturb a fluid having turbulent flow to collapse the turbulent flow to a laminar flow, and a fluid separator configured to be disposed in the borehole and configured to separate the fluid.
Provided is multilateral junction sleeve assembly, a well system, and a method. The multilateral junction sleeve assembly, in one aspect, includes a multilateral deflector assembly, the multilateral deflector assembly including a deflector body having a deflector face and an opening extending therethrough, as well as a deflector assembly sleeve coupled to an uphole end of the deflector body, the deflector assembly sleeve having a sidewall opening in a sidewall thereof aligned with the deflector face. The multilateral junction sleeve assembly in accordance with this aspect, further includes an expandable metal anchor positioned on a radial exterior surface of the deflector assembly sleeve, the expandable metal anchor including a metal configured to expand in response to hydrolysis to axially and rotationally fix the multilateral deflector assembly within a wellbore tubular.
E21B 41/00 - Equipment or details not covered by groups
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
51.
MULTILATERAL JUNCTION SLEEVE ASSEMBLY EMPLOYING DEGRADABLE MATERIAL
Provided is a multilateral junction sleeve assembly, a well system, and a method. The multilateral junction sleeve assembly, in one aspect, includes a multilateral deflector assembly, the multilateral deflector assembly including a deflector body having a deflector face and an opening extending therethrough, as well as a deflector assembly sleeve coupled to an uphole end of the deflector body, the deflector assembly sleeve having a sidewall opening in a sidewall thereof aligned with the deflector face. The multilateral junction sleeve assembly, in accordance with this aspect, further includes degradable material positioned on a radial exterior surface of the deflector assembly sleeve covering the sidewall opening, the degradable material configured to degrade over time and uncover the sidewall opening.
Provided is a multilateral lateral bore completion, a well system, and a method. The multilateral lateral bore completion, in one aspect, includes a tubular having a first end and a second end, and first and second packers located on a radial exterior surface of the tubular, the first and second packers configured to move from a radially retracted state to a radially extended state to engage with a wellbore tubular and separate the tubular into first and second production zones. The multilateral lateral bore completion, according to this aspect, further includes an expandable metal anchor positioned on the radial exterior surface of the tubular, the expandable metal anchor including a metal configured to expand in response to hydrolysis to axially and rotationally fix the tubular with respect to the wellbore tubular.
E21B 41/00 - Equipment or details not covered by groups
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
Provided is a multilateral milling assembly, a well system, and a method. The multilateral milling assembly, in one aspect, includes a multilateral whipstock assembly, the multilateral whipstock assembly having a whipstock body with a whipface and an opening extending therethrough, and a two part milling and running tool coupled to the multilateral whipstock assembly, the two part milling and running tool including: a conveyance; a smaller assembly coupled to an end of the conveyance; and a larger bit assembly slidably coupled to the conveyance, the smaller assembly and larger bit assembly configured to slidingly engage one another downhole to form a combined bit assembly. The multilateral milling assembly, in accordance with this aspect, further includes degradable material axially fixing the smaller assembly relative to the whipstock body.
Provided is a multilateral whipstock assembly, a well system, and a method. The multilateral whipstock assembly, in one aspect, includes a whipstock body, the whipstock body having a whipface and an opening extending therethrough, and degradable material located in the opening, the degradable material configured to axially fix a smaller assembly of a two part milling and running tool relative to the whipstock body, the degradable material configured to degrade over time and allow the smaller assembly to release from the whipstock body and axially slide relative to a larger bit assembly of the two part milling and running tool to form a combined bit assembly.
E21B 29/02 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground by explosives or by thermal or chemical means
Provided is a multilateral fluid loss device, a well system, and a method. The multilateral fluid loss device, in one aspect, includes a fluid loss device body, the fluid loss device body having a first end and a second end coupled together by a fluid passageway, and a plug member located in the fluid passageway, the plug member configured to move between a first position allowing fluid to traverse the fluid passageway as it travels from the first end to the second end and a second position preventing the fluid from traversing the fluid passageway as it travels from the first end to the second end. The multilateral fluid loss device, in this one aspect, may further include degradable material located within the fluid passageway and engaged with the plug member.
Provided is a multilateral downhole assembly, a well system, and a method. The multilateral downhole assembly, in one aspect, includes a multilateral deflector assembly, the multilateral deflector assembly including a deflector body having a deflector face and an opening extending therethrough, and a running tool, the running tool coupled to the multilateral deflector assembly using a degradable material coupling mechanism, the degradable material coupling mechanism configured to degrade over time and allow the running tool to release from the multilateral deflector assembly.
E21B 41/00 - Equipment or details not covered by groups
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
57.
MULTILATERAL LATERAL BORE COMPLETION EMPLOYING DEGRADABLE MATERIAL
Provided is a multilateral lateral bore completion, a well system, and a method. The multilateral lateral bore completion, in one aspect, includes a tubular having a first end and a second end. The multilateral lateral bore completion, in accordance with this aspect, further includes a transition sleeve assembly coupled to the first end of the tubular, the transition sleeve assembly including a transition sleeve including a transition sleeve body having sidewall opening in a sidewall thereof, the sidewall opening configured to align with a deflector face of a multilateral deflector assembly as a portion of the transition sleeve extends out into a lateral wellbore, and degradable material positioned on a radial exterior surface of the transition sleeve body covering the sidewall opening.
E21B 41/00 - Equipment or details not covered by groups
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 34/06 - Valve arrangements for boreholes or wells in wells
58.
MULTILATERAL JUNCTION ASSEMBLY EMPLOYING DEGRADABLE MATERIAL
Provided is a multilateral junction assembly, a well system, and a method. The multilateral junction assembly, in one aspect, includes a transition sleeve assembly, the transition sleeve assembly including a transition sleeve body having a sidewall opening in a sidewall thereof, the sidewall opening configured to align with a main wellbore when the transition sleeve assembly is at least partially insert within a lateral wellbore, and degradable material positioned on a radial surface of the transition sleeve body covering the sidewall opening, the degradable material configured to degrade over time and uncover the sidewall opening.
E21B 41/00 - Equipment or details not covered by groups
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
59.
TWO PART MILLING AND RUNNING TOOL EMPLOYING A BODY LOCK RING
Provided is a two part milling and running tool, a well system, and a method. The two part milling and running tool, in one aspect, includes a conveyance, a smaller assembly coupled to an end of the conveyance, and a larger bit assembly slidably coupled to the conveyance, the smaller assembly and larger bit assembly configured to slidingly engage one another downhole to form a combined bit assembly, the larger bit assembly having a body lock ring in an interior thereof, the body lock ring configured to allow the smaller assembly to slide toward the larger bit assembly but prevent the smaller assembly from sliding away from the larger bit assembly.
A hydraulic cement composition is provided. The composition comprises a hydraulic cement and at least one anti-corrosion agent selected from the group consisting of urea, derivatives of urea, and combinations thereof. The composition can be mixed with water to form a carbon dioxide-resistant hydraulic cement slurry. A hydraulic cement slurry and a method of cementing in a carbon dioxide environment are also provided.
C04B 24/04 - Carboxylic acidsSalts, anhydrides or esters thereof
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
61.
DOWNHOLE WET-MATE SYSTEMS AND METHODS USING WET-MATE DEPLOYMENT CARRIER
A completion system for use in a wellbore includes an upper completion assembly including a stinger sub and a first portion wet-mate connector. The system also includes a lower completion assembly including a shift sleeve, a wet-mate deployment carrier, and a second portion wet-mate connector connectable with the first portion wet-mate connector. Axial movement of the shift sleeve in a first direction moves the wet-mate deployment carrier and the second portion wet-mate connector from a radially outward position to a radially inward position such that the second portion wet-mate connector is positioned to connect with the first portion wet-mate connector.
A system for automatically monitoring and performing diagnostic procedures on a conduit of a hydrocarbon well operation is disclosed. System examples can use a combination of sensors, data acquisition devices, and computing devices to provide fully automated conduit monitoring and diagnostic procedures that can be based on a variety of different triggering conditions. At least one sensor can be located in fluid communication with the interior of a conduit. A pressure wave traveling through the conduit as a result of deliberate action or a natural occurrence is reflected by abnormal conditions in the conduit. The sensor can receive signals comprising the pressure wave reflections. Pressure data generated by the sensor in response to receiving the signals may be automatically collected and subsequently provided to a computing device that can analyze the pressure data and determine the existence and nature of one or more abnormal conditions of the conduit.
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
63.
AUTOMATICALLY LOCATING AND TRACKING A TRANSIENT OBJECT IN A HYDROCARBON WELL CONDUIT
A machine learning-based system for automatically locating and tracking a transient object in a conduit of interest associated with a hydrocarbon well operation. The system may train a machine learning model using pressure data received from a conduit monitoring system that operates by introducing a pressure wave into the fluid within a conduit and using a sensor to measure the magnitude of pressure waves reflected by a transient object in the conduit. The pressure data can be filtered to remove noise and focus on a frequency range of interest prior to being used to generate a training dataset for training the machine learning model. The machine learning model may be trained to generate a predictive model that can predict the location and movement of a transient object in a conduit of interest based on new pressure measurements associated with the conduit of interest.
A system for benchmarking a flowline temperature model using acoustic detection techniques is disclosed. A predicted velocity of a pressure wave introduced into the flowline by an acoustic detection subsystem can be determined using temperature data from a known temperature model, and an expected time of flight of the pressure wave to a flowline target feature can be calculated using the predicted velocity. An actual time of flight of the pressure wave to the target feature can also be observed from received pressure data, and when the system detects a difference between the actual and predicted times of flight, an actual pressure wave velocity may be calculated based on the actual time of flight. A corrected temperature value corresponding to the actual pressure wave velocity may be subsequently calculated, and the known temperature model can be revised by substituting the corrected temperature value for the predicted temperature value.
Some implementations include an apparatus configured to, in a wellbore, eliminate voltage on one or more first conductors that are electrically connected to a surface-based power source. The apparatus may include a shorting ring electrically connectable to the first conductors and configured to electrically short the first conductors upon establishing an electrical connection with the first conductors. The apparatus may include a solenoid assembly to actuate in response to power on the first conductors from the surface-based power source. The apparatus may include a pin slider assembly connected to the first conductors and configured to move, in response to actuation by the solenoid assembly, between an electrical connection with the shorting ring and an electrical connection with one or more second conductors that have an electrical connection with a permanent magnet motor winding in the wellbore.
H02K 11/27 - Devices for sensing current, or actuated thereby
H02M 7/06 - Conversion of AC power input into DC power output without possibility of reversal by static converters using discharge tubes without control electrode or semiconductor devices without control electrode
66.
GAS CHROMATOGRAPHY CALIBRATION TECHNIQUE USING LINEAR RATIOS
In general, in one aspect, embodiments relate to a method that includes varying at least a concentration of one or more components of a multi-component sample gas across at least a concentration range while introducing the multi-component sample gas into a gas chromatograph that includes one or more chromatographic columns, measuring concentrations of the one or more components with the gas chromatograph at a first calibration setting, determining one or more non-linearities of the measured concentrations at the first calibration setting, forming a second calibration setting based at least in part on the one or more non-linearities, and measuring concentrations of one or more components of another sample gas with the gas chromatograph at the second calibration setting.
A variety of methods and systems are disclosed, including, in one example, a method that includes extracting one or more dissolved gases from one or more fluid samples to form one or more extracted gases. The method also includes configuring a dilution rate with an information handling system, automatically diluting the one or more extracted gases with diluent at the dilution rate to form one or more diluted extracted gases and adding the one or more diluted extracted gases to a carrier gas to form sample gas. The method also includes separating one or more components of the sample gas with one or more gas chromatographs, measuring one or more analytes of the sample gas with one or more detectors, and calibrating the one or more gas chromatographs based at least in part on the measuring of the one or more analytes.
A variety of methods and apparatuses are disclosed, including, in one embodiment, an apparatus comprising a hollow profile for downhole in a borehole, the hollow profile comprising a composite of an aromatic copolyester thermoset (ACT) and a reinforcement material, wherein the reinforcement material comprises fibers or particles, or both.
Prepare a work order (WO) by: collecting user input; running an initial CFD-based cementing operation simulation, outputting a CFD result including simulated annular placement of cement with insufficient DE. Choose a section of casing; simulate mechanically coupling a turbulator to adjust displacement efficiency (DE) of cement within the annulus before casing installation; adjust turbulator mechanical properties to maximize DE; create the WO including adjusting turbulator spacing along the casing of the wellbore to one turbulator per joint; perform an additional CFD-based simulation with adjusted turbulator spacing to update and output simulated annular placement of cement and DE; determine a change in DE; adjust the WO based on a further simulation loop; and finalize the WO. Cement the wellbore by: transporting turbulators to a wellsite; installing wellbore casing spaced by turbulator spacing of the finalized WO; and pumping cement into the annulus, the cement contacting the turbulators to reduce channeling.
In some implementations, a downhole oil-water separation (DOWS) assembly may be configured to be disposed downhole in a well. The DOWS assembly may include a DOWS device configured to operate on fluids in the DOWS assembly. The DOWS assembly also may include a controller configured to determine an orientation of the DOWS device and to cause a change to the orientation of the DOWS device.
A well system comprising: a sediment separator to be positioned downhole in a well, wherein the sediment separator is configured to receive a formation fluid from a subsurface formation surrounding the well, the sediment separator configured to separate out sediment from the formation fluid, wherein the sediment is disposed or stored at surface of the well or a different downhole location in the well; and a fluid separator to be positioned downhole in the well, the fluid separator configured to receive the formation fluid from the sediment separator, wherein the fluid separator is configured to separate the formation fluid into production fluid and nonproduction fluid.
In some implementations an apparatus may include a first tubular configured for use in a downhole oil-water separation (DOWS) system and for placement in a segment of a well. The apparatus also may include first and second support members configured to hold the first tubular at a preferred inclination in the well, wherein the first support member is configured to hold a first end of the first tubular at the preferred inclination inside a second tubular, and the second support member is configured to hold a second end of the first tubular at the preferred inclination inside the second tubular.
Some implementations may include a downhole oil-water separation (DOWS) system configured to be positioned downhole in a well. The DOWS system may include a perturbation device configured to be positioned in a borehole of the well and configured to perturb a fluid having turbulent flow to collapse the turbulent flow to a laminar flow, and a fluid separator configured to be disposed in the borehole and configured to separate the fluid.
In some implementations, a system includes a cartridge configured for insertion into a flow path in a well, wherein the cartridge includes one or more devices to separate fluids. The system also may include an elongated Y-block including a working space configured to enable a tool to remove the cartridge from the flow path.
A water-based drilling fluid can include a first and second viscosifier of a cross-linked starch and a cross-linked acrylamide-based polymer. The acrylamide-based polymer can be crosslinked and optionally include hydrophobic monomers. The viscosifiers create a synergistic effect that imparts desirable properties to the drilling fluid compared to using either of the viscosifiers alone. The viscosifiers can be used as an alternative to other types of viscosifiers such as xanthan gum.
Provided is a spring assembly, a valve assembly and a well system. The spring assembly, in one aspect, includes two separate independent wave springs positioned proximate one another such that peaks of adjacent ones of the two separate independent wave springs point toward one another, and valleys of the two separate independent wave springs point away from one another. The spring assembly, according to this aspect, further includes one or more anti-rotation features rotationally coupling the two separate independent wave springs together.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
77.
MULTILATERAL JUNCTION SLEEVE ASSEMBLY EMPLOYING AN EXPANDABLE METAL ANCHOR
Provided is multilateral junction sleeve assembly, a well system, and a method. The multilateral junction sleeve assembly, in one aspect, includes a multilateral deflector assembly, the multilateral deflector assembly including a deflector body having a deflector face and an opening extending therethrough, as well as a deflector assembly sleeve coupled to an uphole end of the deflector body, the deflector assembly sleeve having a sidewall opening in a sidewall thereof aligned with the deflector face. The multilateral junction sleeve assembly in accordance with this aspect, further includes an expandable metal anchor positioned on a radial exterior surface of the deflector assembly sleeve, the expandable metal anchor including a metal configured to expand in response to hydrolysis to axially and rotationally fix the multilateral deflector assembly within a wellbore tubular.
E21B 41/00 - Equipment or details not covered by groups
E21B 33/129 - PackersPlugs with mechanical slips for hooking into the casing
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
78.
MULTILATERAL LATERAL BORE COMPLETION EMPLOYING AN EXPANDABLE METAL ANCHOR
Provided is a multilateral lateral bore completion, a well system, and a method. The multilateral lateral bore completion, in one aspect, includes a tubular having a first end and a second end, and first and second packers located on a radial exterior surface of the tubular, the first and second packers configured to move from a radially retracted state to a radially extended state to engage with a wellbore tubular and separate the tubular into first and second production zones. The multilateral lateral bore completion, according to this aspect, further includes an expandable metal anchor positioned on the radial exterior surface of the tubular, the expandable metal anchor including a metal configured to expand in response to hydrolysis to axially and rotationally fix the tubular with respect to the wellbore tubular.
Provided is a multilateral milling assembly, a well system, and a method. The multilateral milling assembly, in one aspect, includes a multilateral whipstock assembly, the multilateral whipstock assembly having a whipstock body with a whipface and an opening extending therethrough, and a two part milling and running tool coupled to the multilateral whipstock assembly, the two part milling and running tool including: a conveyance; a smaller assembly coupled to an end of the conveyance; and a larger bit assembly slidably coupled to the conveyance, the smaller assembly and larger bit assembly configured to slidingly engage one another downhole to form a combined bit assembly. The multilateral milling assembly, in accordance with this aspect, further includes degradable material axially fixing the smaller assembly relative to the whipstock body.
E21B 29/00 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground
Provided is a multilateral whipstock assembly, a well system, and a method. The multilateral whipstock assembly, in one aspect, includes a whipstock body, the whipstock body having a whipface and an opening extending therethrough, and degradable material located in the opening, the degradable material configured to axially fix a smaller assembly of a two part milling and running tool relative to the whipstock body, the degradable material configured to degrade over time and allow the smaller assembly to release from the whipstock body and axially slide relative to a larger bit assembly of the two part milling and running tool to form a combined bit assembly.
E21B 41/00 - Equipment or details not covered by groups
E21B 29/00 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground
81.
MULTILATERAL FLUID LOSS DEVICE EMPLOYING DEGRADABLE MATERIAL
Provided is a multilateral fluid loss device, a well system, and a method. The multilateral fluid loss device, in one aspect, includes a fluid loss device body, the fluid loss device body having a first end and a second end coupled together by a fluid passageway, and a plug member located in the fluid passageway, the plug member configured to move between a first position allowing fluid to traverse the fluid passageway as it travels from the first end to the second end and a second position preventing the fluid from traversing the fluid passageway as it travels from the first end to the second end. The multilateral fluid loss device, in this one aspect, may further include degradable material located within the fluid passageway and engaged with the plug member.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
E21B 41/00 - Equipment or details not covered by groups
Provided is a multilateral mainbore completion, a well system, and a method. The multilateral mainbore completion, in one aspect, includes a tubular having a first end and a second end, and first and second packers located on a radial exterior surface of the tubular, the first and second packers configured to move from a radially retracted state to a radially extended state to engage with a wellbore tubular and separate the wellbore tubular into first and second production zones. The multilateral mainbore completion, in this one aspect, may further include an expandable metal anchor positioned on the radial exterior surface of the tubular, the expandable metal anchor including a metal configured to expand in response to hydrolysis to axially and rotationally fix the tubular with respect to the wellbore tubular.
E21B 33/129 - PackersPlugs with mechanical slips for hooking into the casing
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
Provided is a multilateral lateral bore completion, a well system, and a method. The multilateral lateral bore completion, in one aspect, includes a tubular having a first end and a second end. The multilateral lateral bore completion, in accordance with this aspect, further includes a transition sleeve assembly coupled to the first end of the tubular, the transition sleeve assembly including a transition sleeve including a transition sleeve body having sidewall opening in a sidewall thereof, the sidewall opening configured to align with a deflector face of a multilateral deflector assembly as a portion of the transition sleeve extends out into a lateral wellbore, and degradable material positioned on a radial exterior surface of the transition sleeve body covering the sidewall opening.
Provided is a two part milling and running tool, a well system, and a method. The two part milling and running tool, in one aspect, includes a conveyance, a smaller assembly coupled to an end of the conveyance, and a larger bit assembly slidably coupled to the conveyance, the smaller assembly and larger bit assembly configured to slidingly engage one another downhole to form a combined bit assembly, the larger bit assembly having a body lock ring in an interior thereof, the body lock ring configured to allow the smaller assembly to slide toward the larger bit assembly but prevent the smaller assembly from sliding away from the larger bit assembly.
E21B 29/00 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground
E21B 41/00 - Equipment or details not covered by groups
E21B 29/06 - Cutting windows, e.g. directional window cutters for whipstock operations
Electric high-pressure pumping units for use in oil or gas well hydraulic fracturing operations; high-pressure pumps for use in oil or gas well hydraulic fracturing operations; intelligent fracturing platform designed to provide hydraulic fracturing services; hydraulic fracturing services
A variety of methods/systems/apparatus/compositions are disclosed, including, in one embodiment, a downhole tool (for use in a borehole) having a mandrel, a sealing element including metal particles disposed about the mandrel, and a piston to move a containment component of the downhole tool in an axial direction to move the metal particles in the axial direction, thereby displacing the metal particles in a radial direction toward a borehole wall to expand the sealing element in the radial direction to form a seal between the downhole tool and the borehole wall.
Systems, methods, and apparatus including a downhole flow control valve that may be used in well systems. The downhole flow control valve may include a flow trim component and a ported housing. The flow trim component may include a plurality of ports that are arranged in a staggered configuration and allow a fluid flow into and out of a well tubing of the well system. The ported housing may include a ramp and a window providing access to the plurality of ports in the staggered configuration. The ramp may have a first angle of inclination and the plurality of ports of the flow trim component may have a second angle of inclination. The flow trim component may include flow trim sections positioned around a circumference of the flow trim component, and the ported housing may include ported housing sections positioned around a circumference of the ported housing.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A water-based drilling fluid can include a first and second viscosifier of a cross-linked starch and a cross-linked acrylamide-based polymer. The acrylamide-based polymer can be crosslinked and optionally include hydrophobic monomers. The viscosifiers create a synergistic effect that imparts desirable properties to the drilling fluid compared to using either of the viscosifiers alone. The viscosifiers can be used as an alternative to other types of viscosifiers such as xanthan gum.
An apparatus to be positioned in a wellbore formed in a subsurface formation. The apparatus comprises one or more generators disposed in a flow path within a flow control tool and configured to output electrical power to components of the flow control tool in response to flow of a fluid in the flow path, wherein the fluid enters the flow path from the wellbore. The apparatus comprises a flow rate limiting device disposed in the flow path and configured to control a flow rate of the fluid as the fluid flows to the one or more generators.
A machine learning-based system for automatically identifying and locating depositions or leaks in a conduit associated with a hydrocarbon well operation. The system may train a machine learning model using a training dataset comprising a multitude of measured pressure data samples received from a conduit monitoring system that operates by introducing a pressure wave into a conduit and using a sensor to measure the magnitude of pressure waves reflected by surfaces or objects in the conduit. The pressure data samples can be filtered to remove noise and focus on a frequency range of interest prior to being used to train the machine learning model. The machine learning model may be trained, using key attributes of the pressure data samples, to generate a predictive model that can predict a deposition or leak in a conduit of interest based on new measured pressure data associated with the conduit of interest.
G01M 3/28 - Investigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipes, cables, or tubesInvestigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipe joints or sealsInvestigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for valves
E21B 47/117 - Detecting leaks, e.g. from tubing, by pressure testing
91.
TEMPERATURE MODEL BENCHMARKING IN FLOWLINE ENVIRONMENTS
A system for benchmarking a flowline temperature model using acoustic detection techniques is disclosed. A predicted velocity of a pressure wave introduced into the flowline by an acoustic detection subsystem can be determined using temperature data from a known temperature model, and an expected time of flight of the pressure wave to a flowline target feature can be calculated using the predicted velocity. An actual time of flight of the pressure wave to the target feature can also be observed from received pressure data, and when the system detects a difference between the actual and predicted times of flight, an actual pressure wave velocity may be calculated based on the actual time of flight. A corrected temperature value corresponding to the actual pressure wave velocity may be subsequently calculated, and the known temperature model can be revised by substituting the corrected temperature value for the predicted temperature value.
E21B 47/095 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes by detecting acoustic anomalies, e.g. using mud-pressure pulses
E21B 47/22 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid by negative mud pulses using a pressure relief valve between drill pipe and annulus
92.
DOWNHOLE FLUID AND SOLID SEPARATION WITH SEDIMENT AND NONPRODUCTION FLUID MANAGEMENT IN A WELL
A well system comprising: a sediment separator to be positioned downhole in a well, wherein the sediment separator is configured to receive a formation fluid from a subsurface formation surrounding the well, the sediment separator configured to separate out sediment from the formation fluid, wherein the sediment is disposed or stored at surface of the well or a different downhole location in the well; and a fluid separator to be positioned downhole in the well, the fluid separator configured to receive the formation fluid from the sediment separator, wherein the fluid separator is configured to separate the formation fluid into production fluid and nonproduction fluid.
In some implementations an apparatus may include a first tubular configured for use in a downhole oil-water separation (DOWS) system and for placement in a segment of a well. The apparatus also may include first and second support members configured to hold the first tubular at a preferred inclination in the well, wherein the first support member is configured to hold a first end of the first tubular at the preferred inclination inside a second tubular, and the second support member is configured to hold a second end of the first tubular at the preferred inclination inside the second tubular.
In general, in one aspect, embodiments relate to a charge tube assembly that includes a charge tube, a detonator housing interlocked with the charge tube, an end alignment interlocked with the charge tube, and a detonation cord extending from the detonator housing to the charge tube.
A variety of methods and systems are disclosed, including, in one example, a method that includes extracting one or more dissolved gases from one or more fluid samples to form one or more extracted gases. The method also includes configuring a dilution rate with an information handling system, automatically diluting the one or more extracted gases with diluent at the dilution rate to form one or more diluted extracted gases and adding the one or more diluted extracted gases to a carrier gas to form sample gas. The method also includes separating one or more components of the sample gas with one or more gas chromatographs, measuring one or more analytes of the sample gas with one or more detectors, and calibrating the one or more gas chromatographs based at least in part on the measuring of the one or more analytes.
G01N 30/34 - Control of physical parameters of the fluid carrier of fluid composition, e.g. gradient
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
In general, in one aspect, embodiments relate to a method that includes varying at least a concentration of one or more components of a multi-component sample gas across at least a concentration range while introducing the multi-component sample gas into a gas chromatograph that includes one or more chromatographic columns, measuring concentrations of the one or more components with the gas chromatograph at a first calibration setting, determining one or more non-linearities of the measured concentrations at the first calibration setting, forming a second calibration setting based at least in part on the one or more non-linearities, and measuring concentrations of one or more components of another sample gas with the gas chromatograph at the second calibration setting.
B01D 53/02 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by adsorption, e.g. preparative gas chromatography
An electric submersible pump (ESP) assembly. The ESP assembly comprises having an electric motor a stator, a rotor, and a first drive shaft, wherein the rotor is coupled to the first drive shaft; a seal section having a second drive shaft coupled to the first drive shaft; a pump assembly having a third drive shaft coupled to the second drive shaft; and an angular position instrument that is configured to determine an angular position of the rotor and to transmit an indication of the angular position of the rotor to an electric motor controller.
Disclosed embodiments relate to inflatable packer elements, which may be configured to dynamically adjust the axial position of the seal element. The seal element may include an inflatable bladder having a thin-walled skin, which may be radially expanded into sealing position by inflation of the bladder. Embodiments may be configured to dynamically alter the configuration of the bladder by axial movement of the bladder in order to provide additional radial expansion of the bladder. For example, one or both of the top and bottom sides of the seal element bladder may be configured to dynamically translate axially towards the other of the top and bottom sides, which may provide additional material of the thin-walled skin of the bladder capable of expanding radially outward upon inflation. Systems and methods of using and making such packer devices are also disclosed.
Systems, methods, and apparatus including a downhole flow control valve that may be used in well systems. The downhole flow control valve may include a flow trim component and a ported housing. The flow trim component may include a plurality of ports that are arranged in a staggered configuration and allow a fluid flow into and out of a well tubing of the well system. The ported housing may include a ramp and a window providing access to the plurality of ports in the staggered configuration. The ramp may have a first angle of inclination and the plurality of ports of the flow trim component may have a second angle of inclination. The flow trim component may include flow trim sections positioned around a circumference of the flow trim component, and the ported housing may include ported housing sections positioned around a circumference of the ported housing.
A method for identifying a cement bond. The method may include disposing an acoustic logging tool into a tubing of a wellbore, wherein the wellbore further comprises casing cemented to a formation by a cement. The method may further include transmitting an acoustic signal into at least part of the tubing and at least part of the casing, measuring one or more signal waves from the at least part of the tubing and the at least part of the casing, and computing an array waveform from the one or more signal waves. Additionally, the method may include applying a beamforming algorithm to the array waveform to form a filtered signal, identifying eccentricity of the tubing within the casing using the filtered signal, and identifying a cement bond between the cement and the casing.
