Abstract: An evaporative cooler for cooling drilling fluid includes a flow pipe having an inner surface in contact with drilling fluid and an outer surface in contact with an evaporative medium. The flow pipe has a serpentine configuration within a transportation frame. A system for cooling a drilling fluid includes a mud circulation system connecting the drilling fluid between a well and a surface where an evaporative cooler is coupled to the mud circulation system and has a serpentine flow pipe in a transportation frame. A method includes pumping heated drilling fluid from a wellbore to an evaporative cooling system, with an evaporative cooler to cool the heated drilling fluid, and sending the cooled drilling fluid back to the wellbore. Another method includes using an intermediate cooler, wherein the intermediate cooler comprises a heat exchanger and an intermediate fluid.

Abstract: A diagnostics and control system (DCS) for an artificial lift system (ALS) in a well, comprising: a sensor network comprising a plurality of sensors for monitoring and obtaining measurements at a power source of the ALS and at a downhole pump of the ALS; a conditioning subsystem configured to measure ALS system performance data; a processing subsystem configured to receive communications from the conditioning subsystem and comprising a processor configured to process sensor data obtained by the sensor network; and a permanent local wellsite monitor that is controlled by the processing subsystem and is powered using a production controller of the ALS, wherein the permanent local wellsite monitor comprises a central surveillance center for transmitting commands and coordinating testing of the ALS among the sensor network, the conditioning subsystem, and the processing subsystem; wherein a condition of the ALS is evaluated by the permanent local wellsite monitor using the processed sensor data, testing results a

Abstract: A method for determining flow rates and phase fractions within a throughbore is disclosed. The method includes providing a mixture of one or more fluids through a fluid flow path in a throughbore at a flow rate, reducing the flow rate, slidably moving a first and second sleeve along the throughbore to a first position of a plurality of positions, measuring a first and second differential pressure at the first position, calculating a first loss pressure ratio from the first and second differential pressure. The method further includes slidably moving the first sleeve and second sleeve to each of the others of the plurality of positions in succession after the first position, measuring a plurality of differential pressures and calculating a loss pressure ratio at each of the plurality of positions, and calculating a plurality of flow rates phase fractions of the fluids flowing through the fluid flow path.

Abstract: An apparatus for applying pressure to a pipe and measuring internal pressure. The apparatus including jacket disposed on the pipe, one or more of a first set of strain gauges disposed on a wall of the pipe, one or more of a second set of strain gauges disposed on the wall of the pipe, and a temperature sensor disposed on the wall of the pipe. The pipe has an inner diameter, an outer diameter, and a length.

Abstract: A system for monitoring an annular fluid level may include a floating element disposed on a surface of a drilling fluid within an annulus of the well, during mud cap drilling operations. The system may also include an antenna disposed above the floating element. The antenna may be configured to transmit a first signal to the floating element, and to receive a second signal from the floating element in response to the first signal. The system may also include a processor configured to determine a time value that measures a time between a transmittal, by the antenna, of the first signal and a receipt, by the antenna, of the second signal. The processor may also determine a state of a drilling fluid level within the annulus based on the time value, and update a drilling program for the well based on the state of the drilling fluid level.

Abstract: A method is disclosed. The method includes creating a chamber within an annulus between a wellbore casing and a drillpipe, wherein an upper boundary of the chamber comprises a seal and a lower boundary of the chamber comprises a liquid surface and determining a volume of the chamber at a first time. Determining the volume of the chamber includes measuring, using a pressure gauge, a first pressure within the chamber, changing an amount of a gas in the chamber, measuring, using the pressure gauge, a second pressure within the chamber, and determining a first volume of gas within the chamber based on the first and second pressure measurements and the change in the amount of gas. The method further includes determining a first fluid level based on the first volume of the chamber.

Abstract: A tool is used to inject a rapidly solidifying sealant into and across highly fractured oil and gas wellbore formations when a significant loss circulation zone or event is encountered. A system including the tool allows for application of the sealant to the formation without requiring removal of the drill string from the hole. The tool may have operatively associate with containers storing sealant and or sealant components that are provided downhole from the surface via wireline or the like.

Abstract: A system for a spark plume generator system for igniting flammable gases at a drilling rig includes a support disposed within a fireproof housing proximate to the drilling rig. A grinder is mounted on the support. The grinder includes a rotatable grinder axle with an abrasive grinder surface and an igniter mounted on the support so as to cooperatively contact the grinder. The igniter includes an igniter surface that creates sparks when abraded. The fireproof housing includes an opening. Upon rotation of the grinder axle, the grinder surface abrades the igniter surface to create sparks. The support is positioned within the fireproof housing so that sparks created by the igniter surface exit the fireproof housing through the opening. The fireproof housing is positioned such that the opening is facing the drilling rig and sparks exiting the opening will ignite any flammable gases at the drilling rig.

Abstract: A method for optimizing drilling performance is disclosed.

Abstract: A method includes installing an influx device into a bell nipple. The influx device has an opening, a pumping port entrance, a pumping port exit, a measuring port entrance, and a measuring port exit. The pumping port exit is disposed in the annulus and the measuring port entrance is disposed adjacent the opening. The method further includes pumping a control gas, at a flow rate, from the pumping port entrance to the annulus using the pumping port exit, receiving the control gas at the measuring port exit using the measuring port entrance, detecting the control gas, using a gas measuring device connected to the measuring port exit, to determine a displacement time, and measuring the size of the void in the annulus using the flow rate and the displacement time.

Abstract: A downhole tool includes a bore isolation valve, a sensor configured to receive to a downlink signal, an annular pressure sensor, a valve actuation mechanism coupled to the bore isolation valve and responsive to the downlink signal, a pressure relief mechanism configured to provide a negative pressure pulse signal indicative of the annular pressure by venting fluid from a bore of the tool body, and a battery. A method includes drilling a well with a drill bit coupled to an on demand annular pressure tool initially in a deactivated mode, and activating the tool by a downlink signal when fluid flow out of the annulus drops below the fluid flow into the well to close a bore of the tool, pressurizing the drill string, holding pressure in the drill string, measuring annular pressure with the tool, and sending a negative pressure pulse signal indicative of the annular pressure.

Abstract: A method, and related apparatus, involves providing one or more drill pipe segments and disposing a quantity of lost circulation material objects within the one or more drill pipe segments. A retention element is provided to retain the lost circulation material objects within the one or more drill pipe segments. The one or more drill pipe segments are connected to a drill string at a wellbore, and drilling fluid is flowed through the drill string. The flowing of drilling fluid through the drill string causes the retention element to release the lost circulation material objects to propagate further.

Abstract: A retrievable whipstock assembly for a wellbore includes a whipstock including a longitudinal body and an anchor connection, a deflection surface provided on the longitudinal body with a first engagement element, and a drilling assembly including a drill housing and a second engagement element. The second engagement element is selectively extendible between a recessed position and an extended position. In the extended position the second engagement element is engageable with the first engagement element.

Abstract: A system includes an upper connection having a ring shape with an external surface, where upper splines are formed on the external surface and the upper connection is fixed to the upper section. The system also includes a lower connection having a ring shape with an internal surface, where lower splines are formed on the internal surface and the lower splines are configured to mate with the upper splines of the upper connection. Further, the system includes a fishing sub having a first lateral end and a second lateral end, where the first lateral end is fixed to the lower connection by shear pins configured to shear when a pre-determined tension is applied to the system, and the second lateral end is fixed to the lower section. The upper connection is inserted into the lower connection to form an engagement between the upper section and the lower section.

Abstract: Provided are a process and a system for treating both a high-pressure (HP) and a low-pressure (LP) acid gas-containing gas streams. The system includes a HP absorber unit, a flash drum coupled downstream of the HP absorber unit, and a LP absorber unit coupled downstream of the flash drum. The process includes introducing a HP rich amine solution from a HP absorber unit into a flash drum, operating the flash drum such that a flashed sour gas and a flash drum rich amine solution are produced, and introducing the flashed sour gas and the LP acid gas-containing gas stream into a LP absorber unit.

Abstract: A pump down device is deployed at an anchor point in a pipe to perform a pipe severing operation. The pump down device includes: a cutting head positioned at one end of the pump down device that severs the pipe; one or more centralizers that are positioned adjacent to the cutting head and configured to provide friction for deployment of the pump down device at the anchor point and centralize the cutting head; a seal that is positioned near an end opposite to the one end of the pump down device; and an electronics housing that includes a plurality of electronic sensors. The pump down device releases an anchor mechanism upon reaching the anchor point as determined by the plurality of electronic sensors based on preprogrammed inputs. The seal prevents fluid from moving past the pump down device when in operation.

Abstract: A monitoring system for a drill string controlled by a drilling program may include a contactless sensor arranged to capture data at a second time. The data may be associated with a parameter at a position along a drill line associated with the drill string. The system may include a processor operatively connected to the contactless sensor. The processor may be configured to access a machine learning (ML) model that is trained using the data captured at a first time, prior to the second time, and an image analysis algorithm. The processor may be configured to identify, using the trained ML model, a condition pertaining to the drill string based on interpreting the data captured at the second time. The processor may be configured to cause an adjustment to the drilling program based on the identified condition.

Abstract: A monitoring system for a drill string controlled by a drilling program may include a contactless sensor arranged to capture data associated with a parameter at a position along a drill line associated with the drill string of a drilling system. The system may include a processor operatively connected to the contactless sensor. The processor may be configured to interpret the data and to cause an adjustment to the drilling program based on the interpreted data.

Abstract: Systems and methods for moving a tubular string within a subterranean well include a downhole assembly. The downhole assembly includes a torque disconnecting member and a shock generating member. During normal drilling activities, both components are inactive. When a stuck pipe event occurs, first the torque disconnecting member is activated while the shock generating member is still inactive. Once the torque disconnecting member is activated, then the shock generating member is activated. A laterally-protruding shock pad of the activated shock generating member produces shocks against the proximate side of a wellbore wall while the shock generating member is rotating. Systems and methods for moving a tubular string within a subterranean well include a fishing assembly. The fishing assembly includes a fishing member, a swivel member, and an imbalanced member.

Abstract: Systems and methods for moving a tubular string within a subterranean well include a downhole assembly. The downhole assembly includes a torque disconnecting member and a shock generating member. During normal drilling activities, both components are inactive. When a stuck pipe event occurs, first the torque disconnecting member is activated while the shock generating member is still inactive. Once the torque disconnecting member is activated, then the shock generating member is activated. A laterally-protruding shock pad of the activated shock generating member produces shocks against the proximate side of a wellbore wall while the shock generating member is rotating. Systems and methods for moving a tubular string within a subterranean well include a fishing assembly. The fishing assembly includes a fishing member, a swivel member, and an imbalanced member.