Monthly Features
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This case study describes how edge computing and industrial internet of things platforms were deployed to automate and optimize production operations across four distinct basins. -
This case study presents a procedure in which the operator compared production from wells with adjusted wettability to a control group, finding that the adjustments resulted in significant improvements in production and reductions in produced water. -
As equipment advances to handle extreme pressures and temperatures, new Gulf opportunities are emerging—alongside increasing operator demands for standardized, scalable, faster, and more affordable solutions. -
Ultradeepwater prospects along the northern coast of Brazil could help offset decline in legacy basins, though permitting hurdles remain a wild card. -
The US federal government is working to stymie offshore wind power, but proponents aren’t going quietly. Armed with data, they are taking on a sea of misinformation and hostility to defend the burgeoning resource in the US, while the rest of the world moves ahead briskly. -
This case study from SLB and offshore producer PRIO describes the longest openhole section in Latin America with the highest extended-reach drilling ratio in Brazil’s history.
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JPT interviewed Saudi Aramco President and Chief Executive Officer Amin Nasser during IPTC. He discussed the company’s outlook for the new year and the current state of the oil and gas industry. -
After 4½ years out of service, the massive Wafra oil field is set to resume production soon, and ensuring a smooth restart is no small order.
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Produced water is an inevitable byproduct of oil and gas production. The use of online oil-in-water monitors plays an important role in the management of produced water.
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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.
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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.
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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.
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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.
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The shale sector is seeking answers to a complex issue involving casing deformations that block access to long sections of a lateral. As opposed to frac hits, this rising problem is considered to be an intrawell phenomena.
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Merging new knowledge and technological capabilities among the disciplines—and beyond—will be crucial to sustaining the industry for the long term.
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Heavy production spiked in two Canadian wells heated by an electric cable, but it is hard to find customers there at a time when Canadian oil prices and customers remember cables in the past that died young.
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