In my inaugural column as editor of the Well Testing Technology Focus feature, I want to shine a light on the notable trend among operators of seizing on the tremendous untapped potential that exploration and appraisal wells represent for far-field reservoir characterization and connectivity.
The concept is straightforward. Upon reaching total depth and running a suite of logs and tools (which may or may not include a well test), gauges are installed as part of the plug-and-abandonment phase, thus turning an otherwise throw-away reservoir penetration into a long-term observation well. Brilliant! The gauges communicate wirelessly by electromagnetic telemetry, cleverly capitalizing on the well’s casing. Well tests conducted elsewhere in the field then can be monitored from these gauges, thereby providing valuable insight into reservoir connectivity, interwell average properties to further calibrate geologic/reservoir models, and in-place resources (or at least a minimum connected volume).
This is not new; however, the technology has become more powerful and reliable, now lasting longer and withstanding more-challenging environments. Fast forward to 2020. These systems are remarkably seamless add-ons to an exploration well design. The advances epitomize the virtuous circle of service company research and development tailored to meet the needs of operators, who, in turn, test these systems and help build a track record. Issues and failures are part of the game of innovative technologies, improving robustness and adding features, job after job.
The value proposition is undoubtedly appealing. The marketing around it is compelling but rarely dwells on the implications of installing such systems. What will it take to yield a conclusive test? Two common pitfalls are the false negative and false positive. The former misleadingly suggests no connectivity when the signal is merely not strong enough or is not given enough time. With the latter, an unrelated response is misconstrued for evidence of connectivity. Successfully designing and interpreting an interference test amid subsurface unknowns, tidal effects, and gauge drift, to name but a few, remains an engineering feat.
While compartmentalization is often flagged as an uncertainty in field-depletion plans (and as a fatal flaw in some instances), only after start-up is its severity revealed—for example, production falling off plateau early or producer/injector pair not in communication. Early dynamic data collection from well tests paired with such long-term systems may help minimize or circumvent this altogether. This enabling technology truly gives a whole new meaning to “data wells.”
This month’s feature illustrates the vitality of our discipline. Deconvolution is being extended to multiwell applications, opening the door to its use in production. Temperature is measured continuously from top to bottom of a test interval to determine zonal contribution over time, sans production logging intervention. Interval pressure transient tests are used for the consistent characterization of fractured carbonates. The diversity of original concepts and technologies is a reminder that well testing is far more than just pressure transient analysis.
Check out as well the additional-reading suggestions. Take a look back with a service company’s review of 40 years of operational best practices. Peruse an operator’s case study taking a formation tester to new limits. Look ahead to the elusive permeability log from an audacious joint industry project.
This Month's Technical Papers
Recommended Additional Reading
IPTC 19369 Innovative Mini-DST and Production-Evaluation Approach at Challenging HP/HT Conditions for the KeShen Tight Gas Reservoir: A Case Study at Tarim Basin by Shichen Shuai, PetroChina, et al.
SPE 193195 Successful Well-Test Operations in Complex Reservoir Fluids: Lessons Learned and Best Practices Over 40 Years of Worldwide Operations by Yakov Shumakov, Schlumberger, et al.
SPE 196116 Permeability Logging Through Constant Pressure Injection Test: In-Situ Methodology and Laboratory Tests by Sivaprasath Manivannan, Ecole Polytechnique, et al.
|Jordan Mimoun, SPE, is a reservoir engineering subject-matter expert and well testing team lead at ExxonMobil. He and his team oversee ExxonMobil’s worldwide exploration and appraisal testing (including design and planning, onsite operations supervision, and data interpretation and integration), while supporting pressure transient analysis for producing assets. Mimoun recently served on the steering committees of the SPE Applied Technology Workshops on well testing, as chairperson in 2017 and session chair in 2014. He is the ExxonMobil representative to WinCubed’s Welltesting Network. Mimoun holds an MS degree in petroleum engineering from The University of Texas at Austin and a diplôme d’ingénieur degree from École Centrale de Lille, France. He is a member of the JPT Editorial Committee and can be reached at firstname.lastname@example.org.|
Jordan Mimoun, SPE, Well Testing Team Lead, ExxonMobil
01 February 2020
Upstream Digitalization Is Proving Itself in the Real World
For the upstream industry, where improvement in efficiency or production can drive significant financial results, there is no question that the size of the digital prize is huge. So are the challenges.
Production-Logging Technologies Enhance Inflow Profiling in Deepwater Gulf of Mexico
This paper discusses the effectiveness of third-generation (Gen3) production-logging-tool (PLT) technology, which uses co-located digital sensors for simultaneous acquisition of flow data to provide the most accurate characterization of the flow condition at each depth surveyed.
Virtual Metering Tool Brings Real-Time Benefits to Production Monitoring
This paper describes a virtual metering tool that can monitor well performance and estimate production rates using real-time data and analytical models, integrating commercial software with an optimization algorithm that combines production and reservoir information.
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27 March 2020