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Completing the Well

Moving from surface readouts to real-time data reduces guesswork to improve intervention efficiencies

The xSight Smart Intervention Service consists of a BHA deployed on drill pipe that is outfitted with sensors measuring torque, WOB, pressure, vibration, toolface orientation and temperature. Data is transmitted wirelessly via mud-pulse telemetry to the surface. The data is fed into a software program for interpretation, then presented as a visualization.

As oilfield sensors and digital technologies grow more sophisticated, the industry is increasingly relying on real-time data to optimize the well intervention process. In today’s intervention operations, downhole data can make the difference between success and failure – and we know that operators can’t afford failures in this low-price environment...

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Multistage fracturing sleeve system developed for North American shales deployed in Saudi Arabia to complete record horizontal well

This graph shows the average treating pressure of all the stages in the well.

Multistage completions using sliding sleeves that allow one-stage, multi-clustered implementation with variable or consistent nozzle sizes were introduced for acidizing completions in the North Sea in the late 2000s. As the practice evolved, it became clear that North American shale projects would be more difficult. Although drilling and completion of extended horizontal wells remained more economical than drilling new wells for further access to the pay zone, there were challenges with perforating the extended section. Open-hole completion had been practiced as a solution but was not ideal for use in shale. Injected fluid took the path of least resistance to the formation, rarely covering the entire payzone accurately or efficiently...

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SPE/ICoTA conference to showcase technologies, real-world applications for well interventions


Knowledge sharing and innovation are the key benefits of attending this year’s SPE/ICoTA Coiled Tubing and Well Intervention Conference and Exhibition, according to Ian Chapman and Matt Billingham, Chair and Vice-Chair for the upcoming event. The conference takes place 27-28 March in The Woodlands, Texas. Mr Chapman and Mr Billingham agree that, after several difficult years for the industry, the acceptance of interventions as a critical maintenance tool, both from a reservoir management and production enhancement perspective throughout the life of a well, has become critically important...

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Proppant intensity may increase by 35% in Permian Basin before reaching optimal economics

Figure 3: Wells in the Delaware-Wolfcamp sub-play are expected to reach an NPV maximum at a proppant intensity of 3,000 lb/ft. Proppant intensity as of mid-2017 was reported to be 2,200 lb/ft.

To maximize well productivity in the current low oil-price environment, operators in North America have adjusted their completion designs and substantially increased their proppant use. At $50 oil prices, that trend is expected to continue – particularly in the Permian, where our analysis indicates that proppant intensity will rise by 35% before reaching optimal economics. The resulting increase in North American demand – up from 45 million tons in 2016 to 110 million tons in 2018 – will be a boon for suppliers and a key driver of low-cost sand flooding into the Permian...

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Comparison of Haynesville wells shows benefits of tighter cluster spacing, higher proppant loads


Techniques for optimized completions shown to result in higher EURs, flattened decline curves By Kelli Ainsworth Robinson, Associate Editor Optimized completion techniques – including longer laterals, tighter cluster spacing, and higher proppant loads and stage counts – can significantly increase the number of conductive transverse fractures and the estimated ultimate recovery (EUR) of Haynesville wells. The finding was made by Halliburton and Dallas-based E&P company Covey Park Energy in a study comparing two Haynesville wells – one completed in 2010 and one in 2016. Additionally, the study found that modern completion techniques can flatten the decline curve in Haynesville wells. The evolution of completion designs in the Haynesville have been driven, in large part, by the play’s low reservoir permeability, ...

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Expandable liners enhanced for more precise, reliable refracs


Enventure has launched its enhanced versions of its ESeal RF and ESeal RFHT refrac expandable liners at the 2018 SPE Hydraulic Fracturing Technology Conference and Exhibition, held 23-25 January in The Woodlands, Texas. The Enhanced ESeal RF and ESeal RFHT provide 16% and 45% higher strength, respectively, than the original ESeal RF Liner. This has expanded the operating envelope for installations using higher treatment pressures and in higher temperature reservoirs, which could exceed 300°F. The liners now offer more predictable zonal isolation and better ID preservation, said Matt Meiners, Technology and Product Development Manager at Enventure. The enhancements were made in response to recent surges in refracturing programs as operators seek to increase production and estimated ultimate recoveries of shale wells. Watch ...

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