Abstract: A method may include receiving data acquired during one or more well construction operations; detecting one or more fluid states using a number of predefined fluid states and the data, where the predefined fluid states include operational fluid states and associated fluid sub-states; generating, using the one or more fluid states, an assessment of a fluid treatment; and outputting the assessment of the fluid treatment.

Abstract: A method may include receiving measurements of drilling fluid properties of drilling fluid during drilling indicative of a current drilling fluid condition; automatically determining a forecast drilling fluid condition based on the measurements using a model-based computational framework; analyzing the current drilling fluid condition and the future drilling condition; based on the analyzing, automatically generating a treatment recommendation and an associated projected drilling fluid condition based on the measurements using the model-based computational framework; responsive to implementation of the treatment recommendation, receiving additional measurements of the drilling fluid properties indicative of an actual drilling fluid condition; and, based at least in part on a comparison of projected drilling fluid condition and the actual drilling fluid condition, generating a quality indicator of the treatment recommendation.

Abstract: A method may include receiving data acquired during one or more well construction operations; detecting one or more fluid states using a number of predefined fluid states and the data, where the predefined fluid states include operational fluid states and associated fluid sub-states; generating, using the one or more fluid states, an assessment of a fluid treatment; and outputting the assessment of the fluid treatment.

Abstract: Methods and systems are provided that determine at least one fluid parameter for a drilling fluid and a particular drilling operation, wherein the at least one fluid parameter is selected from the group consisting of: i) a first fluid parameter that relates to shear forces that break apart components of the drilling fluid during the particular drilling operation, ii) a second fluid parameter that characterizes mixing of drill cuttings with the drilling fluid during the particular drilling operation, and iii) third and fourth fluid parameters that characterize normal stress in the drilling fluid during the drilling operation. The methods and systems can evaluate one or more of these fluid parameters to determine a drilling fluid formulation that optimizes the drilling fluid for effective transport of drill cuttings.

Abstract: A downhole wellbore planner builds a fracture model of a wellbore using fracture data identified from geological information. Using the fracture model and a target wellbore location at the formation, the wellbore planner may identify or select one or more lost circulation materials (LCMs). The drilling operator may then procure the LCMs before drilling the wellbore. In this manner, the impact of a lost circulation event may be reduced by having the LCMs on site or nearby.

Abstract: A drilling fluid manager receives measurements of drilling fluid data over a period of time. The drilling fluid manager analyzes the time-series drilling fluid data to diagnose a contaminant type, contaminant concentration, and a rate of change of contaminant concentration. The drilling fluid manager develops a treatment plan with a treatment type, a treatment mass, and a treatment schedule for the contaminant type.

Abstract: A downhole wellbore planner builds a fracture model of a wellbore using fracture data identified from geological information. Using the fracture model and a target wellbore location at the formation, the wellbore planner may identify or select one or more lost circulation materials (LCMs). The drilling operator may then procure the LCMs before drilling the wellbore. In this manner, the impact of a lost circulation event may be reduced by having the LCMs on site or nearby.

Abstract: A surface rig system includes components that consume power (e.g., using electrical motors). The power consumption of the components is monitored and used to infer other operational parameters. Illustratively, power consumption (e.g., current draw) of a shale shaker is monitored and used to infer: the volume of cuttings on the screen; changes in fluid viscosity, density, or rheology; health of the shaker screen; fluid cycle times; or screen clogging/blinding. Power consumption of pumps, fluid agitators, draw works, and other devices can also be monitored and used to infer parameters such as: fluid viscosity, density or rheology; hook load, or fluid slugging. Based on inferred parameters, changes may be made or advised for operation of equipment, including a shale shaker, downhole tool, pump, shaker screen, top drive, drilling fluid, or draw works.