Abstract: Tubular cut monitoring systems and methods to cut a tubular are presented. The method includes running a downhole cutting tool to a location in a tubular. During a cutting operation, the method also includes monitoring, with an inertial sensor of the downhole cutting tool, for stick slip vibrations produced by a cutter blade of the downhole cutting tool. The method further includes determining whether a total number of stick slip vibrations produced by the cutter blade within a threshold number of revolutions of the cutter blade is greater than a threshold number of tolerable stick slip vibrations. In response to a determination that the total number of stick slip vibrations produced by the cutter blade within the threshold number of revolutions is greater than the threshold number of tolerable tick slip vibrations, the method further includes ceasing the cutting operation.

Abstract: A CO2 sequestration system sequesters carbon dioxide as carbon dioxide hydrate in offshore saline aquifers. The system includes an offshore aquifer in a tropical region. A plurality of wellbores are positioned inside or around a perimeter of the aquifer. The CO2 may be injected into the aquifer via separate injectors located in the wellbores connected to the aquifer while aquifer water or brine is produced from one or more of the other wellbores and provided to the aquifer. Injection of the CO2 into and production of water from the offshore aquifer at separately timed intervals may maintain the reservoir pressure below the reservoir fracture pressure and the hydrate formation pressure so that the CO2 may be stored as carbon dioxide hydrate within the aquifer. Depending on the specific output desired, the aquifer may be positioned either straddling or within a hydrate stability zone. A method for sequestering CO2 uses the aforementioned system to carry out CO2 sequestration.

Abstract: The invention includes a method of reducing a need to re-acidize a hydrocarbon-containing formation. The method comprises providing a composition a HCl and lysine mixture and water wherein a molar ratio between the HCl and the lysine mixture ranges between 3:1 and 12.5:1, and the composition has an initial pH of less than 1; injecting the composition into the formation; allowing a sufficient time for the composition to become a spent acid composition and to subsequently create wormholes in the formation by dissolving calcium carbonate in the formation; maintaining the dissolved calcium carbonate in suspension in the spent acid composition to prevent reprecipitation of the calcium carbonate into the wormholes; removing the spent acid composition containing the dissolved calcium carbonate from the formation; and wherein a pH of the spent acid composition ranges between 4 and 6.

Abstract: A method for enhancing wellbore integrity and/or for sealing a wellbore by sealing formation or micro-annulus fractures in a wellbore. Such sealing can be at least partially accomplished by the use of timed expansion of an expandable sealant material that is placed a wellbore. The expansion of the expandable sealant material causes the cement surface or formation surface to be compressed, thereby creating a tight seal and/or eliminating annulus cracking, fracture, and/or gas channels in the wellbore. A degradable polymer can be used when restoration of the wellbore formation is desired.

Abstract: Systems and methods for deployment of electric-based fracturing tools in vertical wells are disclosed. A method of electric-based fracturing may include lowering an electrical stimulation tool into a wellbore using a drill pipe and isolating a lower portion of the wellbore that is downhole from an upper portion of the wellbore. The electrical stimulation tool may be disposed in the lower portion of the wellbore. A system for electric-based fracturing may include an isolation mechanism and an electrical stimulation tool. The isolation mechanism may be configured to expand from a retracted configuration spaced from an interior surface of a wellbore to an expanded configuration in contact with the inner surface of the wellbore. The electrical stimulation tool may be operatively coupled with the isolation mechanism and may be configured to be disposed distally relative to the isolation mechanism when positioned in the wellbore.

Abstract: A downhole shut-in device includes a valve body with an inlet. An inner sleeve is coupled to an inner surface of the valve body and moves between a closed position and an open position to control a fluid flow from the wellbore through the inlet of the valve body. The downhole shut-in device includes a screen surrounding an outer surface of the valve body to filter the particulate from the fluid flow through the inlet of the valve body to reduce a quantity of the particulate in the inlet of the valve body below a predetermined threshold quantity. A method includes identifying a production fluid flow containing particulates of a size and quantity to be filtered from entering the downhole shut-in device.

Abstract: A slurry composition that includes (A) a solvent, (B) a suspension aid, (D) an alkoxylated fatty amine, (E) an active ingredient, and optionally (C) a polar activator. The slurry composition may be formulated with up to 75 wt. % of the active ingredient (E), based on a total weight of the slurry composition, and remain as a pumpable and stable suspension. A concentrated slurry base is also disclosed which includes the solvent (A), the suspension aid (B), the polar activator (C), and the alkoxylated fatty amine (D), all being present at a higher concentration in the concentrated slurry base than a slurry composition made therefrom. A method of treating a subterranean formation is also disclosed, whereby the slurry composition is mixed with an aqueous fluid to form a treatment fluid, and the treatment fluid is introduced through a wellbore penetrating the subterranean formation.

Abstract: A method of completing an injection well includes determining a volume of recoverable oil in each of a plurality of intervals along the injection well in a reservoir, and determining a target steam flow for respective ones of the intervals to facilitate recovery of the recoverable oil from the intervals. A quantity of steam outlets in devices along the injection well is determined for delivery of the target volume of steam determined for the ones of the intervals. The injection well is completed including steam injection tubing having the determined number of steam outlets for delivery of the target volume of steam to the ones of the intervals.

Abstract: Systems and methods for providing virtual assays of an oil sample such as crude oil based on fluorescence spectroscopy carried out on the oil sample, and the density of the oil sample. The virtual assay provides a full range of information about fractions of the oil sample including naphtha, gas oil, vacuum gas oil, vacuum residue, and other information about the properties of the oil sample. Using the system and method herein, the virtual assay data pertaining to these several fractions of the oil sample and the oil sample itself are obtained without fractionation of the oil sample into the several components.

Abstract: Systems and methods for providing virtual assays of an oil sample such as crude oil based on fluorescence spectroscopy carried out on the oil sample, and the density of the oil sample. The virtual assay provides a full range of information about fractions of the oil sample including naphtha, gas oil, vacuum gas oil, vacuum residue, and other information about the properties of the oil sample. Using the system and method herein, the virtual assay data pertaining to these several fractions of the oil sample and the oil sample itself are obtained without fractionation of the oil sample into the several components.

Abstract: A perf and wash system for plugging a casing and wellbore, the perf and wash system including a cleaning tool having at least one nozzle making a first angle with a longitudinal axis of the system; a perforating gun assembly having at least one shaped charge making a second angle with the longitudinal axis; and a plug connected with a first end to the cleaning tool and with a second end, opposite to the first end, to the perforating gun assembly. The first angle is substantially equal to the second angle and the first and second angles are different than 90 degrees.

Abstract: A pumping system includes a motor and a drive shaft configured for rotation by the motor. The pumping system includes an upper pump positioned above the motor, an upper pump shaft and an upper directional coupling connected between the drive shaft and the upper pump shaft. The upper directional coupling is configured to lock the upper pump shaft to the drive shaft when the drive shaft is rotated in a first direction. The pumping system further includes a lower pump positioned below the motor, a lower pump shaft, and a lower directional coupling connected between the drive shaft and the lower pump shaft. The lower directional coupling is configured to lock the lower pump shaft to the drive shaft when the drive shaft is rotated in a second direction.

Abstract: Methods and treatment fluids for removing mixed scale. A treatment fluid is introduced into a wellbore comprising a mixed scale of interspersed calcium carbonate and calcium sulfate. The treatment fluid comprises: phosphonomethyliminodiacetic acid, N,N-bis(phosphonomethyl)glycine, or a combination thereof; and an aqueous base fluid. The treatment fluid has a pH in a range between about 6 to about 8. The method further comprises contacting the mixed scale with the treatment fluid.

Abstract: System, method, and apparatus for classifying fracture quantity and quality of fracturing operation activities during hydraulic fracturing operations, the system comprising: a sensor coupled to a fracking wellhead, circulating fluid line, or standpipe of a well and configured to convert acoustic vibrations in fracking fluid in the fracking wellhead into an electrical signal; a memory configured to store the electrical signal; a converter configured to access the electrical signal from the memory and convert the electrical signal in a window of time into a current frequency domain spectrum; a machine-learning system configured to classify the current frequency domain spectrum, the machine-learning system having been trained on previous frequency domain spectra measured during previous hydraulic fracturing operations and previously classified by the machine-learning system; and a user interface configured to return a classification of the current frequency domain spectrum to an operator of the fracking wellhead

Abstract: In a well in a subterranean formation, treatment fluids for time-released iron control are utilized. These treatment fluids contain a time-released form of a complexing agent or reducing agent, wherein the agent forms a soluble product with iron. The time-released form prevents loss of the agent prior to delivery to the desired site and at the desired time(s). Methods for controlling iron in a well in a subterranean formation utilize these treatment fluids containing a time-released form of a complexing agent or reducing agent and these methods create soluble products when the agent interacts with the iron to control the iron from the formation and/or well.

Abstract: In a well in a subterranean formation, treatment fluids for time-released iron control are utilized. These treatment fluids contain a time-released form of a complexing agent, wherein the complexing agent forms an insoluble complex with iron. The time-released form prevents loss of the agent prior to delivery to the desired site and at the desired time(s). Methods for controlling iron in a well in a subterranean formation utilize these treatment fluids containing a time-released form of a complexing agent and these methods create insoluble complexes of the agent with the iron to control the iron from the formation and/or well.

Abstract: This document relates to methods for improving the tensile and elastic properties of cement of an oil well using cement compositions that contain sliding-ring polymer additives. The cement compositions containing the sliding-ring polymer additives exhibit increased stiffness while having a minimum impact on compressive strength, as compared to the same cement without the sliding-ring polymer additive.

Abstract: A method of plugging a hydrocarbon well includes deploying a downhole tool to remove at least a portion of a casing at a section of well to be plugged. Then a plugging material is put downhole onto a blocking device to fill an area to be plugged. An exothermic fluid is added, wherein activation of the exothermic material liquefies the plugging material. Allowing the plugging material and the exothermic fluid to solidify form a cast-in-place plug that fills the section of well to be plugged.

Abstract: A screen assembly. The screen assembly may include an inner tubular, a filter screen, a shunt tube, and a perforated shroud. The inner tubular may be configured to flow a formation fluid produced at a first production zone of a formation having multiple production zones that is downhole of the screen assembly. The filter screen may be disposed radially outward from the inner tubular and configured to filter a formation fluid produced at a second production zone that is proximate the screen assembly prior to the formation fluid entering an annulus between the filter screen and the inner tubular. The shunt tube may be disposed radially outward from the filter screen to flow a fluid to a location within the borehole that is downhole of the screen assembly. The perforated shroud may be perforated shroud disposed radially outward from the shunt tube.

Abstract: Described herein are compositions and methods that stabilize an injection fluid when exposed to reservoir conditions, reducing formation damage and increasing the amount of hydrocarbon recovered. Specifically, the formulation is a single-phase liquid surfactant package which comprises an anionic surfactant including a hydrophobic tail comprising from 6 to 60 carbon atoms and optionally one or more secondary surfactants.