Making Better Real Time Decisions While Testing in Deepwater Exploratory Wells

Of critical importance, exploratory wells both represent the initial reservoir evaluation opportunity and help define subsequent development strategies. Hence the importance of obtaining high quality data with which to portray accurate static-dynamic reservoir characterization. This is the reason the drill stem test (DST) is one of the most important tests oil companies use to execute their exploratory wells.

DST Operative Time and Cost

DST evaluation, however, involves high operative costs and risks due to the complexity of working with semi-submersible equipment in terms of non-conventional completions, semi-submersible platforms and very low seabed temperatures.

For this reason, it is necessary to optimize evaluation times and avoid risk situations that can compromise the original evaluation program by increasing operative costs and adversely impacting well safety.

Help Ensure Test Success with a Telemetry System

Real time drill stem testing is a critical technology for monitoring, optimizing time, and improving reservoir data quality. A key part of the DST process is a telemetry system, which is a technology that obtains bottom hole pressure and temperature data via acoustic waves while testing the reservoir.

The most important benefits gained by using this acoustical system while testing are as follows:

  • Within the well, you’ll see perforating validation, well hermetical validation and flow assurance in hydrates, with sand control, and in heavy oil. Further, well hermetical validation will provide pertinent and timely data about liner leaks, plug leaks, surface equipment leaks. This test will also provide you communication behind the casing and slug test evidence so you can better evaluate your well.
  • Within the wellbore, a telemetry system allows for flowing and shut-in period time optimization. You’ll be able to test, measure and determine next steps in bottom hole flow pressure stability. You’ll easily see time when pressure test reaches “radial flow” in log-log plot  and partial penetration effects, all leading to reduce the cost of operations.
  • Within the reservoir, effective time for determining “border effects” can easily be seen. You’ll be able to structure border identification, see water or gas contact identification, measure interference effects and evaluate heterogeneities.

With a telemetry system, it is also possible to set several gauges at different depths (including seabed) and obtain pressure gradients in real time. That’s because the system’s acoustic signal is sent through tubing to the surface in wireless mode. Finally, by using this real time while drilling system, it is possible to optimize the time of the drill stem test, increase the quality of the reservoir data, decrease operative risk and thereby better helps assure evaluation success.

A telemetry system in testing is critical to your well’s success. Consider adding it to your next project.

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Walter DaleAbout Jan Loaiza
Global Sales Technical Advisor

Jan Loaiza has over 16 years experience in the oil and gas industry working for two service companies in North and Latin America. His experience includes participating in multidisciplinary teams to create complex onshore and offshore field studies around the world. Mr. Loaiza, has also served as a reservoir and production engineer in areas such as well testing, production logging, numerical simulation, production optimization, completion design, unconventional reservoir, stimulation, and others.Mr. Loaiza has worked directly with many E&P operators providing Technical Support on projects and promoting new technologies that help carry out their projects successfully. He currently serves as a Global Sales Technical Advisor for Halliburton’s Unconventional, Deep Water and Mature Field Technical Solutions Team.His background as a reservoir, completion and production engineer has provided him the skill to have a holistic understanding of the different reservoir processes. Jan has combined his field, well analysis and sales experience to develop processes and solutions focused on the reservoir.

Mr. Loaiza has published and presented numerous SPE and PennWell papers and has provided technical training for E&P operators and Halliburton engineers. He was also a professor at Universidad de Oriente in Venezuela and has been a mentor to more than 10 junior engineers and 15 students on their college theses. Mr. Loaiza has a degree in Petroleum Engineering from Universidad Central de Venezuela.

 

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