Testing page for app

One of my focus areas as SPE President is strengthening the feedstock of incoming talent into our industry.

Hess is testing whether it can drive drilling improvement by combining drilling rigs equipped with automated functions and humans determined to find a way to beat the programmed drilling.

Production data from the oldest horizontal wells in the three largest oil plays in the US show that annual decline rates remain relatively high for a long period of time. This challenges assumptions held about production after 5 years and directly affects reserve and ultimate recovery estimates.

Rigs drilling faster earn less money per foot because they are contracted by the day. But at least they are still working. Now service companies are developing new rigs with more automated functions, and want increased rates based on the productivity gains achieved.

Oil companies are considering whether shutting in a well for a month or so may mean stronger production later by allowing more time for water to soak into the rock, which gets it out of the way of the oil and gas. But this is not always effective, and additional work is needed.

This paper shows how high-frequency, real-time drilling data from wired drillpipe has helped optimization of drilling performance and achievement of additional improvements in the New Mexico Delaware Basin.

This paper describes how new technology was implemented and deployed through a downhole acoustic network through a sequence of runs in complex North Sea wells under managed-pressure conditions.

This paper discusses how oil and gas companies are using a new generation of AI-driven applications powered by computational-knowledge graphs and AI algorithms to create a digital knowledge layer for oil and gas wells that provides a timeline of significant well events.

In my inaugural column as editor of the Well Testing Technology Focus feature, I want to shine a light on the notable trend among operators of seizing on the tremendous untapped potential that exploration and appraisal wells represent for far-field reservoir characterization and connectivity.

This paper describes the use of a downhole temperature-sensor array during a commingled drillstem test (DST) to determine the density of produced fluids accurately.