Abstract: A method for reducing water production from a hydrocarbon bearing subterranean formation includes identifying a high permeability zone in the formation and injecting a dense CO2 composition from a production well into the high permeability zone. The dense CO2 composition includes dense CO2 and a thickener soluble in the dense CO2. The thickener includes a copolymer that is the polymerized reaction product of monomers that include at least one alkenyl ether or dialkenyl ether monomer, at least one acrylate or methacrylate monomer, at least one structural monomer, and at least one allyl ester monomer. After injecting the dense CO2 composition into the high permeability zone, the method includes withdrawing hydrocarbons from the hydrocarbon bearing subterranean formation through the production well. The dense CO2 composition blocks pores in the high permeability zone to reduce or prevent flow of water from the high permeability zone into the production well.

Abstract: A contactless orientation system coupled with an inner core tube to one or more record carriers on or associated with a core sample held in the core tube having a longitudinal core axis and a core face accessible from an end of the inner core tube. An instrument guide is coupled to the end of the core tube from which the core face is accessible with an axis of the guide parallel to the core axis. Correlation information is generated between a rotational orientation of a known point P on the instrument guide about the guide axis and core orientation data known to the contactless orientation system. The instrument acts as the record carrier or generates the record carrier provided with the correlation information enabling orientation of the core sample to its in-situ orientation when released from the core tube.

Abstract: Methods and systems are provided for characterizing interfacial tension (IFT) of reservoir fluids, which involves obtaining fluid property data that represents fluid properties of a reservoir fluid sample measured downhole at reservoir conditions, and inputting the fluid property data to a computational model that determines a value of oil-water IFT of the reservoir fluid sample based on the fluid property data. In embodiments, the fluid property data represents single-phase fluid properties of the reservoir fluid sample, such as fluid density and viscosity of an oil phase of the reservoir fluid sample and fluid density of a water phase of the reservoir fluid sample. In embodiments, the computation model can be based on machine learning or analytics combined with a thermodynamics-based physics model.

Abstract: An over element line protector comprises a body having a first major surface including a first curvature of a first radius and a second major surface including a second curvature having a second smaller radius. The second radius is smaller than the first radius. The body has a longitudinal extent and a central region aligned with and along the longitudinal extent. The central region is of a first thickness. Wing regions extend laterally from the central region and have a second smaller thickness than the first thickness. A passageway is located in the central region extending along the longitudinal extent of the body configured to protect a line therein.

Abstract: A method, system and apparatus of optimizing operation of one or more tubing strings in a hydrocarbon well are provided. Each tubing string is located in a hydrocarbon well and has a plurality of valves. Each valve is actuatable between a fully open position and a fully closed position and is in communication with a respective zone of a formation defining a reservoir containing hydrocarbon material. The method includes characterizing an injectivity of one or more zones of the formation and determining an optimal operating schedule in accordance with the characterization. The optimal operating schedule comprises one or more valve configurations and an operating duration for each of the one or more valve configurations.

Abstract: A technique facilitates formation of a gravel pack along relatively lengthy wellbores. According to an embodiment, a completion system comprises a plurality of screen assemblies. The completion system also has an alternate path system disposed along the plurality of screen assemblies. The alternate path system includes shunt tubes, e.g. transport tubes, coupled together by jumper tubes. An anti-buckling structure is coupled to each jumper tube to prevent buckling when high operational pressures, e.g. operating pressures of 9000 psi or higher, are applied to the alternate path system.

Abstract: A method of monitoring a subterranean operation includes sampling fluid from a borehole during the operation, and estimating, in near real time, a concentration of one or more gases in the sampled fluid and an isotope composition of the sampled fluid. The method also includes identifying an operational inefficiency in the operation based on the isotope composition associated with the one or more gases, and performing, during the operation, at least one of: alerting an operator and adjusting an operational parameter of the operation, based on identifying the operational inefficiency.

Abstract: Aspects of the subject technology relate to systems and methods for controlling a hydraulic fracturing job. One or more perforations to create during a fracturing stage of a fracturing job at one or more corresponding perforation sites in a wellbore can be identified. The one or more perforations can be formed through one or more perforation devices disposed in the wellbore. Specifically, the one or more perforation devices can be selectively activated from a surface of the wellbore through a well intervention-less technique to selectively form the one or more perforations during the fracturing stage. Further, a volume of fracturing fluid can be pumped into the wellbore during the fracturing stage to form one or more first fractures in a surrounding formation through the one or more perforations.

Abstract: Systems and methods of the present disclosure generally relate to monitoring, evaluating, and controlling fracture geometry during a hydraulic fracturing operation, in real time. A method comprises measuring a signal representing a condition in a wellbore; inputting the signal into a model for estimating a dimension of a dominant fracture; determining the dimension of the dominant fracture; determining a target dimension for the dominant fracture; and minimizing a difference between the dimension of the dominant fracture and the target dimension in real time, by adjusting at least an injection pressure or flow rate of a hydraulic fracturing fluid into the wellbore.

Abstract: Systems and methods for performing a contamination estimation of a downhole sample including at least a formation fluid and a filtrate are provided. A plurality of downhole signals are obtained from the downhole sample and one or more of the signals are conditioned. At least two of the conditioned signals or downhole signals are fused into a multivariate dataset. A principle component analysis (PCA) is performed on the fused multivariate dataset to determine optical and density properties of the formation fluid. Based on at least the PCA, optical and density properties of the filtrate are determined. From the optical and density properties of the formation fluid and of the filtrate, a multivariate calculation is performed to generate concentration profiles of the formation fluid and the filtrate.

Abstract: Systems and methods consistent with the present disclosure may position a cementing tool within a casing string of a wellbore. Such a system may include a fiber optic cable coupled to the cementing tool and may include a distributed temperature sensing (DTS) system interrogator positionable at a surface of the wellbore for transmitting an optical signal through the fiber optic cable such that a plurality of temperatures along the fiber optic cable may be identified. A reel may be used when dispensing the fiber optic cable from a first end of the fiber optic cable in response to a tension in the fiber optic cable as the cementing tool travels down the casing string behind a cement composition. A processor in communication with the DTS system may be configured to monitor the plurality of temperatures along the fiber optic cable while the cement composition cures.

Abstract: A sealing apparatus includes a swellable metal. The swellable metal, when exposed to a fluid, is transitionable from an initial configuration having an initial volume to an expanded configuration having an increased volume. The swellable metal, upon transitioning to the expanded configuration in an annulus of a fluid channel, forms a seal against a surface of the fluid channel such that fluid communication across the swellable metal in the annulus is at least partially restricted.

Abstract: A method and system of providing source water and managing produced/flowback water during a hydraulic fracturing process in an oil and gas operation. The process is an environmentally friendly method of reducing use of fresh water and recycles frac water. The net result is that a volume of frac water is properly managed. Thus, less reliance on transportation vehicles and trucks reduces costs as well as reduction of piping systems. It further reduces a threat of seismic events from disposing of produced water and flowback.

Abstract: The application is directed to a power system that may be provided in a portable form and operationally configured for use at a work site as a single source of electric power, hydraulic power and pneumatic power for work site operations. In regard to hydraulic fracturing stimulation of a wellbore, the power system is operationally configured as the source of hydraulic power for transportable pumping units of a fracturing operation and for hydraulic power tools, as the source of pneumatic power for pneumatic power tools and as the source of electric power for electric power tools and electronic equipment at a well site.

Abstract: A system and method for injecting bailer content utilizing a dump bailer having an elongated, flexible bailer receptacle secured between a head assembly and an injection assembly. Disposed within the dump bailer are first and second piston assemblies, each of which includes a piston having a central fluid passage with a pressure actuated flow control mechanism in the form of a rupture disk disposed along the fluid passage of the piston. An electric, positive displacement pump within the head assembly draws wellbore fluid into the dump bailer assembly to drive the first piston assembly towards the second piston assembly so as to release bailer content into a wellbore. The elongated flexible bailer receptacle may be a hose stored on a bailer receptacle reel, which hose may be paid out by the reel to a length that corresponds with a volume of bailer content to be released into the wellbore.

Abstract: A pressure assisted oil recovery system and apparatus that has a pulsating effect unit, a multiphasic flow meter, and a production lift system that passes through a wellbore up to an oil reservoir. The pulsating effect unit has a control valve and a smart control unit. The production lift system has production tubing and a wellhead. The pulsating effect unit is connected to the production lift system. The multiphasic flow meter is connected to the production tubing to obtain well production parameters data. The control valve opens and closes having an opening/closing predetermined frequency. When the control valve opens and closes, it generates pressure variations along the production tubing. The pressure variations create a pulsating effect on walls of the wellbore. The multiphasic flow meter and the pulsating effect unit set an optimal opening/closing frequency of the control valve.

Abstract: A shoe for use with a casing string in a borehole. The shoe may include a first screen positioned within a bore of the shoe or of the casing string near the shoe. The first screen may include orifices sized to prevent the passage of lost circulation material or a material with properties similar to the lost circulation material from outside the shoe through the first screen.

Abstract: A lost circulation system and a method for reducing losses of drilling fluid in a lost circulation zone of a wellbore. The lost circulation system includes a sheet of lost circulation fabric and particles of a second lost circulation material. The sheet of lost circulation fabric is a material whose structure and composition limit a flow of fluids, particularly drilling fluid, through the sheet. The sheet of lost circulation material has a maximum thickness of 1 millimeter, a length of one foot to one thousand feet, and a width of one inch to twenty inches. The sheet of the lost circulation fabric has holes extending through the sheet.

Abstract: A tool comprising a movable sleeve with an inner diameter, an outer diameter, and a screen. The screen being configured to filter materials flowing into a first port within the moveable sleeve, wherein the outer diameter of the movable sleeve is positioned adjacent to an inner diameter of the tool, wherein the screen is configured to move with the moveable sleeve. The tool further comprising a temporary member positioned on the inner diameter of the moveable sleeve, the temporary member being configured to temporarily cover an inner sidewall of the screen.

Abstract: A method of drilling a subterranean geological formation is described. The method includes driving a drill bit to form a wellbore into the subterranean geological formation thereby producing a formation fluid including hydrogen sulfide (H2S). The method includes injecting a drilling fluid into the subterranean geological formation through the wellbore. The drilling fluid composition includes 0.25 to 2 wt. % of a primary H2S scavenger which is potassium permanganate. The drilling fluid composition includes an invert emulsion includes a continuous phase including diesel and a dispersive phase including water. The potassium permanganate present in the drilling fluid composition reacts with the H2S present in the formation fluid to produce a dispersion of manganese-containing particles which are at least one selected from the group consisting of manganese sulfide and manganese sulfate.