Understanding reservoir fluid properties is a prerequisite to successful field development, especially as wells have become increasingly multifaceted with more deviated and extended-reach trajectories. To meet these challenges, operators are looking for smart downhole fluid analysis techniques that provide an accurate, comprehensive picture of fluid distribution at all stages of the life of the reservoir—in real time while drilling—to enhance completions and meet production goals.
Traditionally, fluid properties are determined by analyzing samples in a laboratory after the well has been drilled. This after-the-fact approach adds time and does not address the risk of poor well placement. Samples collected many hours after drilling, typically on wireline, are subjected to contamination from drilling fluid filtrate. Such contamination increases dramatically the time required at each pumping station and subsequently increases operational issues. Moreover, when applied to highly deviated wells, this methodology—unlike assessing fluid composition while drilling—might fail to reduce the risk to well integrity and contribute to the minimization of production potential.
An article in E&P “Charting a Bigger Reservoir Picture” highlights how engineers developed a reservoir mapping service to overcome these limitations. The service delivers highly accurate fluid composition data while drilling to help operators gain a broad and dynamic understanding of the reservoir. Described as a downhole fluid laboratory, the real-time service ensures that wells are optimally positioned to mitigate wellbore risks and results in better productivity during steering and completions to deliver greater production.