Abstract
Intensive field development is being executed with extended reach Maximum Reservoir Contact (MRC) wells in a giant offshore field in Abu Dhabi. Given the drilling complexity in brown fields with various pressure regimes, the integration between static and dynamic reservoir data is crucial to ensure that wells are optimally placed in the right reservoir zone with an optimized performance. The process helps to identify opportunity generation, and thus maximizes asset value. The process is streamlined to become efficient covering multi-disciplinary aspects for hundreds of drilled wells.
For improved outcomes, the process typically is conducted about six months after the first production date. The degree of details included varies depending on the well objectives and the asset requirements. The process involves data-driven integration of static and dynamic data (well logs, production, pressure, etc.) obtained from a newly drilled well and compare them against pre-drill expectations. Digital platforms are utilized, and multi-disciplinary team members discuss the observations after proper compilation of the data acquired. All the observations, action items (including surveillance and mitigations plan), and recommendations are summarized, documented, and shared with entire Field Development Planning (FDP) team to learn from drilled wells.
The outcomes of the process have a significant impact on decision making of field development. The process enables identifying potential opportunities to maximize production and oil recovery of the field through optimizing well placement, well spacing, horizontal length, and completion designs. The values of information are clearly addressed from data gathered and surveillance activities to support FDP decisions. For example, production logging tools gathered assure production/injection and assess stimulation effectiveness in long reach laterals. Thus, deployment of Limited Entry Liner (LEL) designs for lower completion has been remarkably successful in facilitating cost effective stimulation to maximize areal sweep efficiency. Reservoir models are also assessed as part of the process by comparing them to actual observations to ensure their quality for optimal FDP decisions. Ultimately, implementing such integration can greatly optimize field performance, achieve anticipated production growth, and realize net impact.
