As the demand for energy increases, the role of reservoir characterization grows to further optimize harnessing available reserves. Well testing, as a core dynamic reservoir characterization technology, continues to evolve in all dimensions to meet the added expectations. Development of innovative tools is one of the growth dimensions of well testing. New tools are needed as the industry drills deeper and longer reaching wells, accesses higher pressure and temperature fields, and attempts to obtain continuous real time data from measurements in the wellbore and even deeper in the reservoir. In this session, we will discuss the evolution in intelligent field technology, nanosensors and downhole robots that could be transmitted to the reservoir and used to measure various properties. This should enable obtaining more precise information in real time and monitoring changing reservoir properties, thereby optimizing the ultimate recovery factor and producing maximum amount of oil and gas.
To provide an insight into new developments in the analysis of dynamic reservoir data.
Conventional exploration or development well testing continues to be the backbone of reservoir and field evaluation across the world. This is especially true for ageing fields where implementation of new technology may not be possible or during exploration where costs or risks drive a conservative approach. So how can we drive conventional well testing further, and by pushing the boundaries further end up getting more bang for our buck?
One of the most frequently asked questions in well testing is "Should we test the next well or not?". Value of Information or VOI is a powerful technique to answer such questions. VOI is being used to answer even more complex questions such as "Which is the best technique for testing?". This question has become relevant since many alternative ways of testing are available now: Wireline Formation Testing, Mini-DST, Conventional Testing, permanent down hole gauges, and production data analysis. How can VOI help us in coming up with an optimum testing strategy in such situation. How can VOI help in engineer's quest for more data and managers desire of cost reduction? More importantly, how can VOI be used to expand the scope of well testing beyond the traditional build up testing?
With the continuous improvements in the reliability, accuracy and installation of Permanent Downhole Gauges (PDHGs) for real time pressure and temperature measurement, the use of PDHGs in the industry has increased significantly over the past 2 decades. The values and business benefits PDHGs bring compared to the traditional memory gauges have led many companies to make PDHGs standard components in their wells. Although the benefits of lower life cycle operating costs and deferments, availability of real time data enabling fast decisions for production optimisation are well recognised as the attraction for deploying PDHGs, challenges remain in the areas of interpretation, managing the large amount data generated and consistent reliability when the boundaries of operating environment are continuously being stretched.
Temperature well testing includes distributed temperature sensing (DTS) along the wellbore (vertical or horizontal) and transient temperature measurement during well flowing (production) and well shut in (during pressure build-up), particularly recorded by permanent down hole gauges (PDG). As supplements of traditional transient pressure measurements, temperature measurements can provide additional information to reduce uncertainty during well test interpretation. Examples include testing layered reservoir formations, and interpretation of transient pressures from PDG data with multiple flowing and shut in periods. This session will focus on both case studies and new developments in the temperature testing field.
This session will share the actual field cases where the well testing plays an important role for active reservoir management, especially focusing on experiences of designing and conducting well tests in the new environment.
As the petroleum industry has moved into more economically challenging areas, it has necessarily moved into highly complex reservoir architectures, often in areas where appraisal costs form a significant fraction of the project costs. In meeting these challenges the industry has adopted complex intricate well designs often across multiple intervals. Further, as a consequence of the extraordinary costs of acquiring appraisal information, significantly more uncertainties are carried into the development stages of these megaprojects than was historically the case.This session will share and address the way engineers have solved the challenges of obtaining critical decision-driving information in these complex geological well interfaces. The emphasize will be on sharing practical experiences that have allowed this critical information to be cost effectively acquired through well testing.
Formation testing on wireline and while drilling (LWD) is undergoing accelerated changes in response to the new challenges in the industry. These challenges can be both economics as well as formation related such as high temperature and pressure (HTHP) environments, heavy oils, condensates, water sampling in WBM, tight gas, heterogeneous formations (i.e., carbonates and laminated sandstones) and even unconventional shale formations. In efforts to reduce sampling times and improve sample quality, new probe technologies have been developed such as oval or elongated probes and focused sampling. In development wells, horizontal drilling is the norm which has accelerated the deployment of Logging While Drilling (LWD) tools to lower costs. Over the past decade, pressure testing while drilling was introduced and now sampling while drilling is in its infancy. In Asia, high temperature gradient formations has pushed the technology with wellbore temperatures exceeding 450F and in some other regions pressures over 30,000 psi. Heavy oils where the in situ viscosity can exceed 1,000 cp is another difficult challenge where there have been recent success primarily in carbonate reservoirs found in South American and the Middle East. The spotlight of this session will be to review and assess some of these new technologies and discuss future challenges in for WL and LWD testing and sampling.
The objective of this session is to present current practices and case histories of production analysis and pressure transient analysis performed on data obtained from shale gas/shale liquids reservoirs. "Quick look" cases histories are provided for orientation and discussion. Current and emerging tools/methods are presented and discussed, with an emphasis on data diagnostices, interpretation, and analysis. This session focuses on the similarities and differentiating factors of shale gas/shale liquids systems and conventional reservoirs systems. What can we use? What can we adapt? What tools/methods do we need to create?