Production
The 2026 Upstream Scale Guidelines establish a common workflow for field measurements, scale modeling, and risk assessment to support more consistent operational decisions.
The long-term outlook analysis says a potential shift toward new construction could push 2026 production 3% above 2025 levels.
Lower operating expenditures and a changing asset mix helped UKCS operators cut average production costs by 9% year over year, despite relatively flat production levels, according to the NSTA.
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With millions of wells having been drilled in the US since the beginning of the oil age, the land is pocked with old, unused wellbores. For most, repurposing is a pipe dream. Plugging is the best option. -
Disposal wells remain the lowest-cost solution for produced water, but concerns over seismicity and long-term sustainability are accelerating interest in alternatives.
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This article from the SPE Research and Development Technical Section offers new insights to how the upstream industry can benefit from the emergence of quantum computing.
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After launching pre-salt production in Brazil, the ultradeepwater Tupi asset has become one of Petrobras’s most productive.
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North Sea operators produced an additional 16 million BOE from 56 reinstated wells in 2025 as improved intervention efficiency lowered costs and helped restore shut-in assets to production, according to the NSTA.
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This contributed article highlights the growing importance of fiber-optic sensing and its potential to advance thanks to emerging quantum technologies.
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The DOE-backed EGS-Twin project aims to simulate geothermal production systems, helping operators better predict performance and maximize output.
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Rock sample characterization, widely used in hydrocarbon exploration and production, is emerging as a critical tool for understanding and optimizing subsurface mineral extraction through in-situ leaching.
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This article from the SPE Integrated Reservoir Management Technical Section (IRMTS) addresses decisions that look stronger than they are and take longer to implement than the reservoir can afford.
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This work introduces an analytical model for nonisothermal CO2 injection that accounts for both Joule-Thomson cooling and interformation heat exchange.
