Abstract: In general, in one aspect, embodiments relate to a downhole tool that includes a coring module for obtaining at least one rotary core sample from a formation, and a core marker module for marking the at least one rotary core sample with earth coordinates, where the coring module is separate from the core marker module.

Abstract: A ranging system having magnets positioned at various locations along the drive system. Location of the magnetics is shifted to different points on the drilling string to remove the need for a nearby bit sub that would detrimentally affect the steerability of the drilling system.

Abstract: A method of perforating a well that includes suspending a first perforating gun and a second perforating gun on a conveyance into a well, transmitting a signal down the conveyance, where the signal at least partially traverses the first perforating gun, a perforating gun connection, and the second perforating gun, and in response to the signal selecting the second perforating gun to fire, and firing a shaped charge in the second perforating gun, where the first perforating gun and the second perforating gun are connected via the perforating gun connection, where the perforating gun connection includes a pin which extends from the first perforating gun to a contact tab of the second perforating gun, and where a spring element, coupled with the contact tab, elastically deforms in response to the contact tab engaging with the pin.

Abstract: Some implementations transmit nuclear magnetic resonance (NMR) data between downhole tools and surface-based computers. A method may include generating a first vector in which each entry includes a spectrum coefficient associated with NMR echo signals. The method may include generating a cumulative sum vector in which each entry includes a sum including a spectrum coefficient of a corresponding entry in the first vector plus any spectrum coefficients of any entries that precede the first corresponding entry in the first vector. The method may include down sampling the cumulative sum vector to form a down-sampled vector including a subset of the cumulative sum vector. The method may include generating a compressed vector in which each entry includes a difference of a corresponding entry in the down sampled vector and any entry directly preceding the corresponding entry in the down sampled vector and transmitting the compressed vector over a communication channel.

Abstract: Injection into a subterranean formation is optimized using a computation model to optimize injection. An optimization objective is to maximize the cumulative fluid mass rates injection that span over the remaining life of the field, while maintaining a dense or supercritical phase and operating within the equipment operational parameters. The phase at each location may be determined based on pressure and temperature, and flow is dynamically adjusted to maintain a phase having at least a threshold density of the carbon dioxide injected at each injection location.

Abstract: A treatment fluid can include a base fluid and a lost-circulation package. The lost-circulation package can include plurality of pieces of a first lost-circulation material and a second lost-circulation material. The plurality of pieces can be an open-cell, natural or biodegradable material, for example natural sponges such as loofah. The plurality of pieces can enter permeable areas of a subterranean formation and form a mesh-like matrix that the second lost-circulation material can be retained within. The second lost-circulation material can be insoluble particles such as ground walnut shells or include ingredients that form a cementitious substance. The first and second lost-circulation materials can form a plug and provide adequate fluid loss control. The treatment fluid can be used in an oil and gas operation.

Abstract: A system for leak detection. The system may comprise an acoustic logging tool that includes a hydrophone array with a plurality of hydrophones. The system may further include an information handling system communicatively connected to the acoustic logging tool and wherein the information handling system chooses three or more hydrophones from the plurality of hydrophones to operate during measurement operations.

Abstract: The life of internal components of a frack pump is affected by the frack fluid being pumped. Manually trying to keep track of the frack fluid type being pumped is a tedious task that is susceptible to incorrect data or missing data. As such, the disclosure provides automated tracking of the amount of time or fluid volume that frack pumps pump the different fluid types and managing usage of the frack pumps using a history of the pumping. An example method of managing usage of a frack pump includes: (1) obtaining, for a time period or fluid volume, a proppant presence for a frack fluid being pumped by a frack pump, (2) automatically determining a flow type history for the frack pump over the time period or fluid volume based at least on the proppant presence, and (3) controlling a usage of the frack pump using the flow type history.

Abstract: Systems and methods are provided for determining the wideband spectrum of downhole fluids based on downhole optical measurements. In some aspects, a plurality of optical data measurements associated with a subsurface fluid can be obtained from a subsurface optical measurement device. In some cases, a comparison can be made between the plurality of optical data measurements associated with the subsurface fluid and one or more sets of optical data stored in an optical data library. In some examples, the one or more sets of optical data can correspond to a plurality of different fluid samples. In some instances, a first fluid sample from the plurality of fluid samples that corresponds to at least a portion of the subsurface fluid can be identified based on the comparison. In some aspects, an absorbance spectrum of the subsurface fluid can be determined based on the first fluid sample.

Abstract: A system can be used to control shock applied to a downhole tool. The system can include an internal component, an outer component, and a wedge pin. The internal component can be positioned in the downhole tool. The internal component can include an axial shoulder and an angled seating surface. The outer component can be positioned in the downhole tool. The outer component can include (i) an opening sized to receive a preload cap, and (ii) a flange positionable to contact the axial shoulder. The wedge pin can be positioned in the opening and abutting the angled seating surface to apply a preload to the internal component and the outer component in response to the preload cap being positioned in the opening.

Abstract: Provided is a two part drilling and running tool, a downhole tool, a well system, and a method for forming a well system. The two part drilling and running tool, in at least one aspect, includes a smaller assembly coupled to an end of a conveyance, the smaller assembly having a spline or slot located along an entire length (LS) thereof. The two part drilling and running tool, in accordance with this aspect, further includes a larger bit assembly slidably coupled to the conveyance, the larger bit assembly including an other of the slot or spline, wherein the spline or slot in the smaller assembly and the other of the slot or spline in the larger bit assembly are configured to engage one another to rotationally fix the smaller assembly relative to the larger bit assembly as the smaller assembly and the larger bit assembly slidingly engage one another.

Abstract: A packer for use in a well has a packer mandrel with a stepped outer surface defining first, second and third progressively smaller outer diameters. The third outer diameter is a reduced outer diameter portion. A setting sleeve with a stepped inner surface defining first and second inner diameters is engaged with and slidable on the second and third outer diameters on the outer surface of the packer mandrel. A packer element is disposed about the reduced outer diameter portion of the packer mandrel and the setting is sleeve movable from a first position to a second position on the packer mandrel.

Abstract: A method comprises receiving a time series of data values for a time window of each operational parameter of a number of operational parameters of equipment; calculating a time derivative feature that comprises a change of the data values of a first operational parameter of the number of operational parameters over the time window; and classifying, using a machine learning model and based on the time derivative feature, an operational mode of the equipment into different failure categories.

Abstract: Described herein are systems and techniques for improving accuracies of determinations made using a nuclear magnetic resonance (NMR) sensing device when the NRM sensing device collects data in a wellbore. NMR sensing devices include a magnet that provides a magnetic field that aligns the spins of protons in substances near the NMR sensing device. The magnetic field strength provided by this magnet affects the sensitivity of the NMR sensing device and affects frequencies that the NMR sensing device effectively uses when the NMR sensing device operates. Furthermore, the field strength of magnets used in an NMR sensing device varies with temperature. Since temperatures within a wellbore vary significantly and since these temperatures affect how an NMR sensing device operates, systems and techniques of the present disclosure collect calibration data in a calibration chamber such that data sensed by the NMR sensing device can be interpreted more accurately when temperatures change.

Abstract: A packer assembly has a packer mandrel and a packer element movable from an unset to a set position on the packer mandrel. An annular lock ring with a plurality of lock ring teeth is positioned in an annular space between the packer mandrel and a setting sleeve movable on the packer mandrel from a first to a second position to move the packer element to the set position. The mandrel has a plurality of mandrel teeth thereon in engagement with the lock ring teeth.

Abstract: A method for designing a cement composition may include: providing a target compressive strength and a target composition density; selecting at least one cementitious material from a plurality of cementitious materials; calculating a required amount of water to produce a cement composition with the target composition density, the cement composition comprising the water and the at least one cementitious material; calculating a compressive strength of the cement composition based at least in part on a model of compressive strength; comparing the calculated compressive strength to the target compressive strength; and preparing the cement composition with the calculated compressive strength.

Abstract: A downhole shifter tool assembly configured to operate a downhole tool. The shifter tool assembly comprises a anchor tool, an extension tool, a shifting key, and a standoff spacer. The standoff spacer is configured to locate the shifter tool assembly at a reference position by contacting an isolation member on the downhole tool. An anchoring mechanism within the anchor tool can anchor the shifter tool assembly in the reference position. An extend-retract mechanism within the extension tool can extend move the shifting key on a shifting tool into engagement with a shifting profile on the downhole tool and move the shifting profile to a second position. The downhole tool can be operated by the shifting key moving the shifting profile from an initial position to the second position.

Abstract: A spool valve assembly and methods for use downhole to control fluid flow into a borehole from a downhole formation. The assembly includes a valve body having an interior. The assembly also includes a spool moveable within the valve body interior from a first position wherein the spool prevents flow through the valve body, to a second position wherein the spool allows flow through the valve body at a first flow rate, and to a third position wherein the spool allows flow through the valve body at a second flow rate different than the first flow rate. The spool is moveable from the first position to the second position using hydrostatic fluid pressure acting on the spool from outside the valve body. The spool is moveable from the second position to the third position using gas pressure from a chemical reaction producing a force sufficient to overcome the hydrostatic pressure.

Abstract: A well interval isolation device is disclosed. The wellbore isolation device may have a plurality of expandable elements that cooperate upon expansion downhole in a wellbore to create multiple isolated well intervals. At least two pairs of expandable elements that are spaced apart on a tool string are usable to create both a primary isolated well interval and at least one isolated guard interval on each of an uphole side and a downhole side of the primary isolated well interval. The isolated guard intervals function to further isolate the primary isolated well interval from surrounding well fluid, thereby allowing a difference between the pressure within the primary isolated well interval and the hydrostatic pressure of the well fluid (i.e., the differential pressure) to safely exceed the maximum differential pressure at which any of the individual expandable elements can operate while simultaneously maintaining isolation of the well intervals.

Abstract: A system may include a fluid separator disposed within a lateral bore of a multilateral well. The fluid separator may be configured to receive formation fluid from a main bore of the multilateral well, separate the formation fluid into formation water and production fluid, and output the production fluid to flow uphole. The system may also include a lower lateral packer, disposed within the lateral bore in a position downhole from the fluid separator, and a downhole pump disposed in the lateral bore. The downhole pump is configured to receive the formation water from the fluid separator and pump the formation water to flow into a portion of the lateral bore downhole from the lower lateral packer.