Schlumberger Intellectual Property Department

A method implements automation of product carbon footprint computations. A process map view is displayed, including multiple process nodes and product nodes. A process view is displayed for a process model associated with one of the process nodes. The process map view is updated with a footprint node that is connected to one or more process nodes. A set of process models, including the selected process model, is processed using footprint data from the footprint node to calculate process emissions. The process map view is updated to display the calculated emissions for the connected process nodes. The process emissions are further processed to determine an overall emission value. A dashboard view is displayed showing the emission value for a product represented by a product node.

An electrical cable includes a central electrical conductor disposed in a center portion of the electrical cable and one or more additional electrical conductors, such that the one or more additional electrical conductors are disposed proximate to the central electrical conductor and form a core of the electrical cable. Additionally, the electrical cable includes one or more fillers disposed between the one or more additional electrical conductors. Further, the electrical cable includes a first layer of armor wires disposed circumferentially around an external surface of the core, such that the first layer of armor wires is partially embedded within an inner carbon fiber reinforced polymer layer, and a second layer of armor wires disposed circumferentially around the first layer of armor wires, such that the second layer of armor wires is partially embedded within an outer carbon fiber reinforced polymer layer.

A method for improving subsurface images includes receiving data from at least one source and one receiver disposed at a subsurface location. The method may include representing the subsurface location with a dense grid of point scatterers, calculating a wavefield of the source based on the position of the source within the subsurface location, calculating a wavefield of the receiver based on the position of the receiver within the subsurface location and on the grid of point scatterers, and forming an unweighted image of point spread functions (PSFs). The method may also include forming a weighted image of PSFs. The method may also include calculating an image of the weight based on the weighted image of PSFs and the unweighted image of PSFs, and generating a partitioned image of PSFs based on the image of the weight, thereby preventing PSFs from overlapping and improving images of the subsurface location.

A method of synthesizing a monolithic structure is provided, which involves casting a gel of nanoparticle material using a mold body. The gel includes the nanoparticle material in reaction media. The mold body is dissolvable in media different from the reaction media at predefined process conditions. Other aspects are described and claimed.

A packed bed unit for chemical processing is described. The packed bed unit includes packing material disposed within the packed bed unit, wherein the packing material includes a plurality of different compositions distributed in the packed bed unit.

An apparatus is provided for use in a chemical process, which includes at least one metal tube or flow channel having at least one surface with at least one organic linker attached thereto. The at least one organic linker has first and second molecular groups, wherein the first molecular group is configured to bind to the at least one surface, and wherein the second molecular group is configured to bind to at least one compound that functions as an adsorbent or catalyst in the chemical process in order to attach the at least one compound to the at least one surface. Methods of constructing an apparatus for use in a chemical process are also described and claimed.

A method can include receiving a target density value for a drilling fluid exiting a sedimentation device; receiving a measured density value for the drilling fluid directed to the sedimentation device, a measured density value for the drilling fluid exiting the sedimentation device, and an incoming flow rate value for the drilling fluid directed to the sedimentation device; and generating control instructions for control of an injection pump to regulate a diluent injection pump rate to dilute the drilling fluid entering the sedimentation device to achieve the target density value.

A subsea electrical junction box (180) is provided. The subsea electrical junction box (180) includes a pressurized fluid source, a busbar (102a, b), a switch (100a, b) isolator module, and an electrical connector (124a, b, c). The switch (100a, b) is in selective fluid communication with the pressurized fluid source, the pressurized fluid source supplying hydraulic fluid to actuate the switch (100a, b) from a retracted configuration (130) to an extended configuration (140). The switch (100a, b) is in electrical communication with the busbar (102a, b). The electrical connector (124a, b, c) is in selective electrical communication with the busbar (102a, b) via the switch (100a, b).

Systems and methods for enhancing wireline conveyance modeling in wireline conveyance using a physics-informed neural network (PINN) are provided. A method includes: receiving historical job data from at least one past wireline conveyance operation, the historical job data including: static input data, and timeseries input data, processing the historical job data through a neural network (NN) configured to learn the relationships between input features and target variables including: an input layer, a plurality of hidden layers, and an output layer, integrating the neural network with a numerical physics-based wireline conveyance model to form a physics-informed neural network (PINN), training the PINN using the historical job data and estimation results of the physical model to enhance prediction accuracy, utilizing the trained PINN to predict at least one physical parameter for a current wireline conveyance operation, and outputting the predicted at least one physical parameter for use in the wireline conveyance operation.

Systems and methods presented herein provide for cutting in a borehole or casing. A cutting device can include a first arm having a cutting blade, wherein the cutting blade has side cutting teeth and an axis of rotation that is substantially at a right angle with respect to an axis of the tool body. The cutting device can also include a second arm with a bumper. The first and second arms articulate away from the elongate body in different directions to reduce vibrations while cutting. A control device can automate the cut based on hydraulic pressure measurements. Additionally, the cutting device can also be extended or rotated on a rotary index. The cutting device can rotate around a J slot, in an example.