Abstract: A method of automatic optimization of ROP. The method obtains a plurality of drilling surface parameters for a field of interest, and determines an UCS data and a MSE data for a targeted formation based on well logs. The method further trains a ML model using the drilling surface parameters as inputs, and outputs a plurality of weights for drilling parameters in a ROP equation and in a Teale's MSE equation for the field of interest. The method further combines the ML ROP equation with the Teale's MSE equation to determine a plurality of optimum drilling parameters by simultaneously solving the set of ML ROP equation and the Teale's MSE equation. Furthermore, the method generates a work order to adjust the drilling parameters and cause display of the work order and the determined optimum drilling parameters in a user interface of a client device.

Abstract: Systems and methods include a computer-implemented method for determining risks of injector wells. Inputs for multiple risk criteria are received through an injector riskiness score (IRS) user interface for processing risks posed by an injector well to a new well being drilled in proximity to the injector well. A weighted sum of values corresponding to inputs for the risk multiple criteria is determined based on the inputs. An IRS score is determined based on the weighted sum. A determination is made whether the injector well has an IRS score above a predefined threshold. A shut-down recommendation for the injector well is identified in response to determining that the injector well has an IRS score above the predefined threshold.

Abstract: Some implementations of the present disclosure provide a computer-implemented method that includes: accessing measurement data obtained from a drilling operation, wherein the measurement data show multiple measurements during the drilling operation when a drilling bit is located at a range of depths; based on the measurement data, using machine learning analytics to construct a model that predicts a formation top when the drilling bit reaches a depth; determining a correlation between the measurement data and the predicted formation top; and in response to determining the correlation exceeds a pre-determined threshold, applying the model to predict a formation top when the drilling bit reaches the depth.

Abstract: A system for determining a well placement may include an analysis module. The analysis module, using a Bayesian Decision Network model, may perform a first assessment of data availability, saturation, fracture, and seismic data associated with a candidate area for drilling a first well, and may output a first probability that indicates a potential production level of the first well. The analysis module may perform a second assessment of offset, stress, thickness, and porosity data associated with a second, nearby well, and may output a second probability that indicates a potential production level of the first well if a lateral is placed in a layer and at a azimuth direction. The analysis module may perform a third assessment of tortuosity, washout, and porosity data, and a net-to-gross value associated with the first well and may output a third probability that indicates a completion type for the first well.

Abstract: A system for determining a well placement may include an analysis module. The analysis module, using a Bayesian Decision Network model, may perform a first assessment of data availability, saturation, fracture, and seismic data associated with a candidate area for drilling a first well, and may output a first probability that indicates a potential production level of the first well. The analysis module may perform a second assessment of offset, stress, thickness, and porosity data associated with a second, nearby well, and may output a second probability that indicates a potential production level of the first well if a lateral is placed in a layer and at a azimuth direction. The analysis module may perform a third assessment of tortuosity, washout, and porosity data, and a net-to-gross value associated with the first well and may output a third probability that indicates a completion type for the first well.

Abstract: A method of automatic optimization of ROP. The method obtains a plurality of drilling surface parameters for a field of interest, and determines an UCS data and a MSE data for a targeted formation based on well logs. The method further trains a ML model using the drilling surface parameters as inputs, and outputs a plurality of weights for drilling parameters in a ROP equation and in a Teale's MSE equation for the field of interest. The method further combines the ML ROP equation with the Teale's MSE equation to determine a plurality of optimum drilling parameters by simultaneously solving the set of ML ROP equation and the Teale's MSE equation. Furthermore, the method generates a work order to adjust the drilling parameters and cause display of the work order and the determined optimum drilling parameters in a user interface of a client device.

Abstract: A casing may have a tubular body formed by a wall extending axially from a first end to a second end, the tubular body having a bore therein throughout. The wall may radially extend from an inner surface of the tubular body to an outer surface of the tubular body. The wall may include a base layer and one or more secondary layers attached to the base layer. The one or more secondary layers may be a rubber or smart foam.

Abstract: A casing may have a tubular body formed by a wall extending axially from a first end to a second end, the tubular body having a bore therein throughout. The wall may radially extend from an inner surface of the tubular body to an outer surface of the tubular body. The wall may include a base layer and one or more secondary layers attached to the base layer. The one or more secondary layers may be a rubber or smart foam.

Abstract: Some implementations of the present disclosure provide a computer-implemented method that includes: accessing measurement data obtained from a drilling operation, wherein the measurement data show multiple measurements during the drilling operation when a drilling bit is located at a range of depths; based on the measurement data, using machine learning analytics to construct a model that predicts a formation top when the drilling bit reaches a depth; determining a correlation between the measurement data and the predicted formation top; and in response to determining the correlation exceeds a pre-determined threshold, applying the model to predict a formation top when the drilling bit reaches the depth.

Abstract: Embodiments relate to a method that includes measuring, by an electronic device at a surface of a wellbore, a functional characteristic of a drilling process. Embodiments may further include identifying, by the electronic device based on a change in the functional characteristic, a change in a petro-physical property of rock at a drill-bit while drilling. Embodiments may further include outputting, by the electronic device, an indication of the change in the petro-physical property of the rock at the drill-bit. Other embodiments may be described or claimed.

Abstract: Systems and methods for sealing a problem zone of a subterranean well include a wire mesh member with a tubular shape and a plurality of openings. The wire mesh member has an initial orientation with an initial outer diameter that is greater than an inner diameter of the wellbore, a reduced orientation with a reduced outer diameter that is less than the inner diameter of the wellbore and an induced bending stress, and an installed orientation with an installed outer diameter that is generally equal to the inner diameter of the wellbore and a residual bending stress. The wire mesh member is positioned within the problem zone and moved to the installed orientation so that an outer surface of the wire mesh member engages an inner surface of the wellbore. The plurality of openings are plugged to prevent a flow of fluid radially through the wire mesh member.

Abstract: Systems and methods for sealing a problem zone of a subterranean well include a wire mesh member with a tubular shape and a plurality of openings. The wire mesh member has an initial orientation with an initial outer diameter that is greater than an inner diameter of the wellbore, a reduced orientation with a reduced outer diameter that is less than the inner diameter of the wellbore and an induced bending stress, and an installed orientation with an installed outer diameter that is generally equal to the inner diameter of the wellbore and a residual bending stress. The wire mesh member is positioned within the problem zone and moved to the installed orientation so that an outer surface of the wire mesh member engages an inner surface of the wellbore. The plurality of openings are plugged to prevent a flow of fluid radially through the wire mesh member.

Abstract: A wellbore drill bit assembly includes a drill bit that includes a drilling fluid pathway that has an inlet fluidly connected to a drilling fluid entrance of the drill bit and an outlet fluidly connected to a drilling fluid exit of the drill bit; and a nozzle positioned in the drilling fluid pathway, where at least a portion of the nozzle includes a removable material configured to dissolve or erode in contact with a drilling fluid additive.

Abstract: A wellbore liner-hanger tie-back system includes a bore receptacle coupled with a liner hanger at a downhole end of the bore receptacle, where the liner hanger is configured to be positioned in a wellbore, a tieback casing configured to be disposed in the wellbore, where a portion of an outer surface of the tieback casing is disposed proximate to an inner surface of the bore receptacle, and a seal system including at least one swellable seal. The seal system is disposed between the tieback casing and the bore receptacle to seal a space between the portion of the outer surface of the tieback casing and the inner surface of the bore receptacle.

Abstract: A wellbore liner-hanger tie-back system includes a bore receptacle coupled with a liner hanger at a downhole end of the bore receptacle, where the liner hanger is configured to be positioned in a wellbore, a tieback casing configured to be disposed in the wellbore, where a portion of an outer surface of the tieback casing is disposed proximate to an inner surface of the bore receptacle, and a seal system including at least one swellable seal. The seal system is disposed between the tieback casing and the bore receptacle to seal a space between the portion of the outer surface of the tieback casing and the inner surface of the bore receptacle.

Abstract: A wellbore drill bit assembly includes a drill bit that includes a drilling fluid pathway that has an inlet fluidly connected to a drilling fluid entrance of the drill bit and an outlet fluidly connected to a drilling fluid exit of the drill bit; and a nozzle positioned in the drilling fluid pathway, where at least a portion of the nozzle includes a removable material configured to dissolve or erode in contact with a drilling fluid additive.

Abstract: A wellbore drill bit assembly includes a drill bit that includes a drilling fluid pathway that has an inlet fluidly connected to a drilling fluid entrance of the drill bit and an outlet fluidly connected to a drilling fluid exit of the drill bit; and a nozzle positioned in the drilling fluid pathway, where at least a portion of the nozzle includes a removable material configured to dissolve or erode in contact with a drilling fluid additive.

Abstract: A wellbore drill bit assembly includes a drill bit that includes a drilling fluid pathway that has an inlet fluidly connected to a drilling fluid entrance of the drill bit and an outlet fluidly connected to a drilling fluid exit of the drill bit; and a nozzle positioned in the drilling fluid pathway, where at least a portion of the nozzle includes a removable material configured to dissolve or erode in contact with a drilling fluid additive.

Abstract: A wellbore liner-hanger tie-back system includes a bore receptacle coupled with a liner hanger at a downhole end of the bore receptacle, where the liner hanger is configured to be positioned in a wellbore, a tieback casing configured to be disposed in the wellbore, where a portion of an outer surface of the tieback casing is disposed proximate to an inner surface of the bore receptacle, and a seal system including at least one swellable seal. The seal system is disposed between the tieback casing and the bore receptacle to seal a space between the portion of the outer surface of the tieback casing and the inner surface of the bore receptacle.

Abstract: A wellbore liner-hanger tie-back system includes a bore receptacle coupled with a liner hanger at a downhole end of the bore receptacle, where the liner hanger is configured to be positioned in a wellbore, a tieback casing configured to be disposed in the wellbore, where a portion of an outer surface of the tieback casing is disposed proximate to an inner surface of the bore receptacle, and a seal system including at least one swellable seal. The seal system is disposed between the tieback casing and the bore receptacle to seal a space between the portion of the outer surface of the tieback casing and the inner surface of the bore receptacle.