Abstract: Systems and methods include a method for multi-segmented oil production. A multi-segmented well production model representing production at a multi-segmented oil production facility is calibrated. The model models production based on well rates and flowing bottom-hole pressure data at various choke settings for multiple flow conditions for each segment of the multi-segmented well. Real-time updates to the well rates and the flowing bottom-hole pressure data are received. Changes to triggers identifying thresholds for identifying production improvements are received. The model is re-calibrated based on the changes to the triggers and the real-time updates. An optimization algorithm is executed to determine new optimal inflow control valve (ICV) settings. Using the re-calibrated multi-segmented well production model, a determination is made whether the new optimal ICV settings improve production. If so, the optimal ICV settings are provided to a control panel for the multi-segmented oil production facility.

Abstract: A method for optimizing water injection in a reservoir may include obtaining a first dataset from a first pipeline system in a first reservoir, training a first model by the first dataset, and determining reliability of the first dataset by the first model. The method may include upon determining that the first dataset is reliable, generating a first categorized dataset by the first dataset and a second model, and training a third model by the first categorized dataset. The method may include optimizing water injection control parameters of a second reservoir in accordance to a final water injection scheme by the third model.

Abstract: Systems and methods include a method providing automated production optimization for smart well completions using real-time nodal analysis including comingled production calibration. Real-time well rates and flowing bottom-hole pressure data are collected at various choke settings for multiple flow conditions for each lateral of a multilateral well during regular field optimization procedures. Surface and downhole pressures and production metrics for each of the laterals are recorded for one lateral at a time during production of the well. Flowing parameters of individual laterals are estimated using the multilateral well production model. An optimum pressure drop across each downhole valve is determined using the multilateral well production model. Each lateral of the multilateral well is calibrated during the commingled production at various choke valves settings.

Abstract: A core flooding system includes a core holder that encloses a core sample of a subterranean formation. The core holder includes a fluid inlet and a fluid outlet; at least one sensor coupled to the core holder or positioned in the inner volume of the core holder; an acoustic vibrating assembly coupled to the core holder; and a control system communicably coupled to the at least one sensor and the acoustic vibrating assembly. The control system performs operations including operating the acoustic vibrating assembly to transmit at an acoustic wave energy or a vibration energy to the core holder; during the transmission of the at least one of the acoustic wave energy or the vibration energy to the core holder; measuring at least one parameter of the core sample; and based on the at least one measured parameter, determining at least one property of the core sample.

Abstract: Systems and methods for reducing friction between a casing string and a bore of a subterranean well when moving the casing string within the bore of a subterranean well include a roller bearing assembly. The roller bearing assembly has a bearing body and a plurality of spherical bearings spaced around an outer diameter of the bearing body. The bearing body is secured in line with the casing string.

Abstract: Systems and methods include a method providing automated production optimization for smart well completions using real-time nodal analysis including real-time modeling. Real-time well rates and flowing bottom-hole pressure data are collected by a multilateral well optimizing system at various choke settings for multiple flow conditions for each lateral of a multilateral well during regular field optimization procedures. Surface and downhole pressures and production metrics for each of the laterals are recorded for one lateral at a time. A multilateral well production model is calibrated using the surface and downhole pressures and the production metrics for each of the laterals. Flowing parameters of individual laterals are estimated using the multilateral well production model. An optimum pressure drop across each downhole valve is determined using the multilateral well production model.

Abstract: Systems and methods include a method for optimizing smart well completions using real-time nodal analysis including recommending changes to downhole settings. Real-time well rates and flowing bottom-hole pressure data at various choke settings for multiple flow conditions are collected for each lateral of a multilateral well. Recommended optimizing changes to downhole inflow control valve (ICV) settings for surface and subsurface ICVs are determined based on the real-time well rates and the flowing bottom-hole pressure data. The optimizing changes are designed to optimize production in the multilateral well. The recommended optimizing changes to the downhole ICV settings for the surface and subsurface ICVs in the laterals are provided for presentation to a user in a user interface of a multilateral well optimizing system. A user selection of one or more of the recommended optimizing changes is received. The recommended optimizing changes selected by the user are implemented.

Abstract: A core flooding system includes a core holder that encloses a core sample of a subterranean formation. The core holder includes a fluid inlet and a fluid outlet; at least one sensor coupled to the core holder or positioned in the inner volume of the core holder; an acoustic vibrating assembly coupled to the core holder; and a control system communicably coupled to the at least one sensor and the acoustic vibrating assembly. The control system performs operations including operating the acoustic vibrating assembly to transmit at an acoustic wave energy or a vibration energy to the core holder; during the transmission of the at least one of the acoustic wave energy or the vibration energy to the core holder; measuring at least one parameter of the core sample; and based on the at least one measured parameter, determining at least one property of the core sample.

Abstract: A first expandable tubular is longitudinally extendable from a housing. The first expandable tubular is expandable to a diameter equal to an internal surface of a wellbore. A first expander is configured to expand the expandable tubular. A second expandable tubular is longitudinally extendable from the housing. The second expandable tubular is configured to expand to a diameter equal to an internal surface of the wellbore. The second expandable tubular is downhole of the first expandable tubular. A second expander is configured to expand the second expandable tubular. The second expander is downhole of the first expander. A sensor is downhole of the second expander. The sensor is configured to detect a presence of a wellbore obstruction proximal to the tool.

Abstract: A core flooding system includes a core holder that encloses a core sample of a subterranean formation. The core holder includes a fluid inlet and a fluid outlet; at least one sensor coupled to the core holder or positioned in the inner volume of the core holder; an acoustic vibrating assembly coupled to the core holder; and a control system communicably coupled to the at least one sensor and the acoustic vibrating assembly. The control system performs operations including operating the acoustic vibrating assembly to transmit at an acoustic wave energy or a vibration energy to the core holder; during the transmission of the at least one of the acoustic wave energy or the vibration energy to the core holder; measuring at least one parameter of the core sample; and based on the at least one measured parameter, determining at least one property of the core sample.

Abstract: Systems and methods for cementing an annular space radially outward of a casing of a subterranean well include a float shoe located at a downhole end of the casing. A float valve is located within the float shoe and within a fluid flow path extending through the float shoe from an internal bore of the casing to an exterior surface of the float shoe. At least two wing members are located on an outer diameter surface of the casing, each of the wing members extending from the float shoe to an uphole end of the casing. The wing members are sized to define two or more separate sections of the annular space. A downhole splitter is located on a downhole surface of the float shoe. The downhole splitter is sized to seal between the downhole surface of the float shoe and an end surface of the subterranean well.

Abstract: A first expandable tubular is longitudinally extendable from a housing. The first expandable tubular is expandable to a diameter equal to an internal surface of a wellbore. A first expander is configured to expand the expandable tubular. A second expandable tubular is longitudinally extendable from the housing. The second expandable tubular is configured to expand to a diameter equal to an internal surface of the wellbore. The second expandable tubular is downhole of the first expandable tubular. A second expander is configured to expand the second expandable tubular. The second expander is downhole of the first expander. A sensor is downhole of the second expander. The sensor is configured to detect a presence of a wellbore obstruction proximal to the tool.

Abstract: Systems and methods include a method for multi-segmented oil production. A multi-segmented well production model representing production at a multi-segmented oil production facility is calibrated. The model models production based on well rates and flowing bottom-hole pressure data at various choke settings for multiple flow conditions for each segment of the multi-segmented well. Real-time updates to the well rates and the flowing bottom-hole pressure data are received. Changes to triggers identifying thresholds for identifying production improvements are received. The model is re-calibrated based on the changes to the triggers and the real-time updates. An optimization algorithm is executed to determine new optimal inflow control valve (ICV) settings. Using the re-calibrated multi-segmented well production model, a determination is made whether the new optimal ICV settings improve production. If so, the optimal ICV settings are provided to a control panel for the multi-segmented oil production facility.

Abstract: Systems and methods for reducing friction between a casing string and a bore of a subterranean well when moving the casing string within the bore of a subterranean well include a roller bearing assembly. The roller bearing assembly has a bearing body and a plurality of spherical bearings spaced around an outer diameter of the bearing body. The bearing body is secured in line with the casing string.

Abstract: Systems and methods for measuring properties within a subterranean well include a measuring tool having a tool body with a central axis and a tool attachment located at an axial end of the tool body. A delivery line attachment is operable to attach the measuring tool to a delivery line that supports the measuring tool within the subterranean well. A primary treatment platform is in mechanical communication with the tool body. The primary treatment platform has a platform attachment sized to mate with the tool attachment, and at least one treatment system. The at least one treatment system is operable to perform a treatment function within the subterranean well during delivery of the measuring tool into the subterranean well.

Abstract: System and methods for completing a subterranean well include a casing string, the casing string being an elongated tubular member formed of successive casing joints and having a central axis. A plurality of ribs are secured to the casing string, the ribs being elongated members spaced circumferentially around an outer diameter of the casing string. The ribs extend axially from a downhole end of a casing joint to an uphole end of the casing joint.

Abstract: Systems and methods include a method for optimizing smart well completions using real-time nodal analysis including recommending changes to downhole settings. Real-time well rates and flowing bottom-hole pressure data at various choke settings for multiple flow conditions are collected for each lateral of a multilateral well. Recommended optimizing changes to downhole inflow control valve (ICV) settings for surface and subsurface ICVs are determined based on the real-time well rates and the flowing bottom-hole pressure data. The optimizing changes are designed to optimize production in the multilateral well. The recommended optimizing changes to the downhole ICV settings for the surface and subsurface ICVs in the laterals are provided for presentation to a user in a user interface of a multilateral well optimizing system. A user selection of one or more of the recommended optimizing changes is received. The recommended optimizing changes selected by the user are implemented.

Abstract: Systems and methods include a method providing automated production optimization for smart well completions using real-time nodal analysis including real-time modeling. Real-time well rates and flowing bottom-hole pressure data are collected by a multilateral well optimizing system at various choke settings for multiple flow conditions for each lateral of a multilateral well during regular field optimization procedures. Surface and downhole pressures and production metrics for each of the laterals are recorded for one lateral at a time. A multilateral well production model is calibrated using the surface and downhole pressures and the production metrics for each of the laterals. Flowing parameters of individual laterals are estimated using the multilateral well production model. An optimum pressure drop across each downhole valve is determined using the multilateral well production model.

Abstract: Systems and methods include a method providing automated production optimization for smart well completions using real-time nodal analysis including comingled production calibration. Real-time well rates and flowing bottom-hole pressure data are collected at various choke settings for multiple flow conditions for each lateral of a multilateral well during regular field optimization procedures. Surface and downhole pressures and production metrics for each of the laterals are recorded for one lateral at a time during production of the well. Flowing parameters of individual laterals are estimated using the multilateral well production model. An optimum pressure drop across each downhole valve is determined using the multilateral well production model. Each lateral of the multilateral well is calibrated during the commingled production at various choke valves settings.