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Innovating While Drilling®

Schlumberger announces new dual telemetry service to help reduce influence from drilling noise

The first day of the 2020 IADC/SPE International Drilling Conference in Galveston, Texas, saw Schlumberger launch a new dual telemetry drilling service, xBolt G2, that it says enables operators to switch from electromagnetic mud pulse and dual telemetry modes while drilling, reducing influence from drilling noise and potentially reducing lost rig time. In this video with DC following the product’s launch, Shadi Mussa, Global Product Champion at Schlumberger, speaks about the benefits the system may provide in well placement and geosteering.

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Stena Drilling: A journey from zero MPD capability to fully integrated, ‘owned and operated’ MPD service

Having functionally identical systems across MPD fleet and taking collaborative approach to develop procedures cited as key success factors By Nick Ward and Stuart Wyse, Stena Drilling Responding to a competitive deepwater rig market, as well as operators’ increasing requests for managed pressure drilling (MPD) capability in rig tenders, Stena Drilling identified a requirement to establish MPD capability within its deepwater fleet and, in February 2016, sanctioned the purchase and integration of two deepwater MPD systems. Since then, the company has successfully utilized both systems to drill seven deepwater MPD exploration and appraisal wells across multiple regions and for multiple operators. Following the successes of the first two MPD systems, a third system was approved in 2019, with three additional ...

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Gyro-while-drilling technology enables wellbore collision risk management in ERD application

Gyroscopic surveying system combined with advanced RSS helps operator to drill new well to access bypassed oil from aging Gulf of Thailand field By Manchukarn Naknaka and Praisont Prasertamporn, Mubadala Petroleum; Adrián Ledroz and Jayaneethe Naranasamy, Gyrodata; and Kesavan Ramasamy, Baker Hughes In complex oilfields with diminishing production values, accessing untapped reservoir areas is one method of improving overall field economics. Operators typically drill many wells in the same field, creating a risk to safety and production when attempting to drill a new prospect well near the existing ones. As the risk of wellbore collision increases, the value of drilling the well effectively decreases, and relying on MWD surveys opens the operator up to additional challenges with the quality of ...

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In evaluating the business case for implementing MPD, well design optimization is too often overlooked

Dynamic formation mapping and design kick tolerance among critical enablers to fully realize benefits of MPD By Oscar Gabaldon, Romar Gonzalez Luis, Patrick Brand, Sherif Saber, Anton Kozlov and William Bacon, Blade Energy Partners; and Catherine Sugden, Sugden Consulting Inherent to the unpredictable nature of high-pressure, high-temperature (HPHT) reservoirs and exploratory wells, especially in deepwater, are increased operational costs due to nonproductive time (NPT) and operational problems. Typically considered after the initial well design process, managed pressure drilling (MPD) techniques are well recognized as a cost-effective approach to increasing the likelihood of achieving well and cost objectives for challenging wells with narrow windows. However, the implementation of MPD early in the project life cycle offers further potential savings that many ...

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Surge and swab during drill pipe connections on floaters may affect pressure windows in calm weather

Significant rig-heave induced pressure variations revealed in study of drillship offshore Brazil, highlighting need for simulation tool for harsh conditions By John-Morten Godhavn and Banzi Olorunju, Equinor; Dmitri Gorski, Martin Kvernland and Mateus Sant’Ana, Heavelock Solutions; Ole Morten Aamo and Sigbjørn Sangesland, NTNU During drilling and completion, the downhole pressure in a well should be kept lower than the fracture pressure and higher than both the pore pressure and wellbore collapse pressure. Falling below that lower limit pressure could lead to wellbore stability challenges and a possible undesired influx of hydrocarbons into the well, while exceeding the upper limit could cause the well to fracture, resulting in costly mud losses. All of this means an increase in nonproductive time (NPT) ...

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