fracture modeling

Despite energy companies' enthusiasm for implementing digital technologies in drilling analysis, many predictions still include a high level of uncertainty.

The authors of this paper define a work flow that constrains solutions that match models and field observations and obtains a more-representative model for forecasting and optimizing fracture behavior.

This paper presents a numerical simulation work flow, with emphasis on hydraulic fracture simulation, that optimizes well spacing and completion design simultaneously.

The authors of this paper compare case studies from the Bakken and the STACK plays to conclude that mineralogy, petrophysics, and reservoir-condition differences between basins cause differences in the effect of fracture-driven interactions.

Devon, Shell, and SM Energy offer some of their latest learnings from recent independent subsurface diagnostics projects. Their work underscores why this arena of technology has become a cornerstone for hydraulic-fracture design in tight-rock reservoirs.

A growing volume of free data and reports from US shale fracturing test sites is available, with more on the way.

The complete paper describes the first implementation of a solution to control fracture height for conventional wells in the Pannonian Basin.

This paper presents a work flow to match the history of reservoirs featuring complex fracture networks with a novel forward model.

x

One of the oldest names in geomechanical modeling has learned some new tricks, and like so many recent advances in the oil and gas industry, it has everything to do with the North American shale revolution.