A method for determining an end-of-stage (EoS) state indication of a fracking operation occurring at a fracking site comprises: receiving an end-of-stage (EoS) detection model; receiving wellsite activity data; determining a positive activity data health indication in relation to the wellsite activity data using the EoS detection model; determining an idle activity indication from the wellsite activity data using the EoS detection model; receiving wellsite stage data; determining a positive stage data health indication in relation to the wellsite stage data based on the EoS detection model; and determining a positive EoS state indication from the wellsite stage data using the EoS detection model.

A method can include receiving production fluid flow rate data from a well in a field that includes a plurality of wells; generating a gas lift profile for the well using the production fluid flow rate data; solving a system of equations representing at least two gas lift profiles for at least two of the plurality of wells to generate results; and issuing an instruction based at least in part on the results to control gas lift for production of fluid by the well.

A directional drilling-exploring-monitoring integrated method for guaranteeing safety of an underwater shield tunnel includes: drilling a small-diameter borehole below a water area, and establishing an initial geological model; reaming the small-diameter borehole into a large-diameter borehole, placing a parallel electrical method (PEM) power cable and a monitoring optical fiber cable into the large-diameter borehole, acquiring zero field data, primary field data and secondary field data through carbon rod measurement electrodes before tunnel excavation, and processing the data with an existing inversion method to form an inversion image, thereby obtaining a refined geological model of a stratum; starting the tunnel excavation, and respectively acquiring a disturbance condition of rock and soil and a sedimentation and deformation condition of rock and soil around the tunnel during the excavation, thereby implementing safety excavation of the tunnel; and continuously monitoring the tunnel and the surrounding rock and soil in later use of the tunnel.

Examples described herein provide a method for drilling a wellbore by a wellbore operation system into a subsurface of the earth. The wellbore operation system includes a bottom hole assembly. The method includes conveying the bottom hole assembly into the wellbore. The method further includes selecting a well plan for the wellbore. The method further includes measuring well data by at least one sensor in the wellbore operation system while the bottom hole assembly is in the wellbore. The method further includes generating, by a processing device, a steering proposal based at least in part on the well plan and the well data. The method further includes drilling, with the wellbore operation system, at least a portion of the wellbore based at least in part on the steering proposal.

Systems and methods include a computer-implemented method for performing well placement and configuration. Two-dimensional (2D) target entry (TE) points are generated in an area of interest (AOI) for wells to be drilled in an oil reservoir, where the 2D TE points are positioned according to a defined well length resolution. A single lateral is designed for each well using the 2D TE points, where each single lateral is designed with a different length, completion zone, azimuth, and orientation. Using the single laterals, a dynamic reservoir simulation is executed for the wells to be drilled in the oil reservoir, including rotating between different three-dimensional (3D) configurations for each 2D TE. A 3D configuration for each 2D TE is selected for each lateral and based on executing the dynamic reservoir simulation.

Systems and methods for selecting and performing gas deliverability tests are disclosed. In one embodiment, a method of performing a gas deliverability test includes drilling a well, operating the well to produce gas, determining a sustainability of the well, and determining at least one of a shut-in bottom hole pressure and pressure build-up of the well and a geochemical analysis of the well. The method further includes selecting a deliverability test based at least in part on a duration of an operation of the well, a sustainability of the well, and at least one of the shut-in bottom hole pressure, the pressure build-up and the geochemical analysis of liquids of the well. The method also includes applying the deliverability test to the well.

Techniques for predicting a landing zone of a wellbore include identifying a first subsurface geological model of a first subterranean layer located under a terranean surface that includes an upper boundary depth of the first subterranean layer and a lower boundary depth of the first subterranean layer; identifying a second subsurface geological model of a second subterranean layer deeper than the first subterranean layer that is independent of the first subsurface geological model and includes an upper boundary depth of the second subterranean layer; correlating a predicted landing zone for a plurality of wellbores using the first and second subsurface geological models that is based on a location of a horizontal portion of each wellbore; and generating data that comprises a representation of the correlated plurality of wellbores for presentation on a graphical user interface (GUI).

Embodiments provide techniques for using data from a select set of wells to develop correlations between surface-measured properties, downhole coring parameters, and properties typically determined from subsurface measurements (e.g., from logging tool responses, core analysis, or other subsurface measurements). When new wells are drilled, the surface data acquired while drilling and coring parameters used downhole may be used as an input to these correlations in order to predict properties associated with subsurface measurements.

The invention relates to a method for recovery of hydrocarbons present in an underground formation by injection of a saline aqueous solution comprising at least one surfactant, by means of a numerical flow simulator including a model of the evolution of the interfacial tension between the saline aqueous solution and the hydrocarbons as a function at least of salinity, wherein the interfacial tension evolution model is calibrated as follows: i) carrying out interfacial tension measurements for a plurality of emulsions having distinct salinity values corresponding at least to the optimum salinity, to two salinities bounding the optimum salinity in a 5-10% limit, to the zero salinity and to the solubility limit of the salts; ii) determining the constants of the interfacial tension evolution model by minimizing a difference between the model and the interfacial tension measurements.

Estimating wear on bottom hole assembly (BHA) components utilizes a rock hardness index using analysis of drill cutting. Estimating the amount of wear on borehole assembly components comprises measuring the rock properties in drilled cuttings from a borehole. A hardness value is assigned to each mineral present in the drilled cuttings. A hardness index is calculated for a drilled borehole interval. A wear resistance factor is assigned to each BHA component of the BHA. The wear resistance factor depends on the wear resistance of each BHA component. A wear value for each BHA component is calculated based on the hardness index for the drilled borehole interval, the wear resistance of the BHA component, and drilling parameters.