Our team of engineers and geoscientist has the world-wide experience, gained from solving reservoir management problems in various oil and gas provinces around the globe
We tap on our global experience to
find sound solutions
tailored to meet reservoir management challenges
Flowgrids Limited has a field-tested, technical staff
with the requisite experience and technical know-how
to solve reservoir management problems.
We have had opportunities to work on many
integrated studies to support field development planning.
When a client requests for our services, we identify experienced industry professionals to complement our technical staff to form a multi-disciplinary team of geologists, geophysicists, petrophysicist, petroleum production, and reservoir engineers. As a team, we develop advanced, fit-for-purpose workflows and harness appropriate computing hardware and software to execute the project. We maintain a clear line of communication with our clients throughout the project. We believe in building long-term relationships with our clients. We are committed to the delivery of quality results without compromise.
Flowgrids was asked to evaluate different reservoir management scenarios in a mature field to maximize reservoir productivity and forecast reserves. Flowgrids completed a comprehensive reservoir analysis to develop a static model as input for dynamic simulation. The fluid flow model was history-matched and used to forecast well and field-wide performance considering different reservoir management schedules. Flowgrids’ recommendations to the project sponsor included the optimum number and type of infill wells to drill, well placement and reservoir development schedule, and workover/intervention operations to maximize production from existing and infill wells.
Flowgrids was asked to identify the causes of early water breakthrough in a newly drilled horizontal well. An integrated reservoir engineering and dynamic modeling study was designed to diagnose cause of early water breakthrough in the horizontal well. After reservoir analysis, we recommended reservoir management solution of well recompletion to mitigate water production and to maximize well performance.
Flowgrids has conducted many integrated field development studies. These are multi-disciplinary studies designed to give upstream oil and gas companies a blueprint for making reservoir management decisions. Typically, our geoscientists interpret seismic data, combine seismic data with petrophysical data to define the reservoir structure and faulting; capture the geology, incorporate the stratigraphy and structural models, and integrate the petrophysical properties, production and reservoir data to create the geomodel. Working in concert with the geoscientists, the reservoir and production engineers transform the static geomodel into a dynamic model. Upon calibration of the dynamic model to observed historical data, it is used with appropriate subsurface and surface facility constraints to forecast reserves, evaluate multiple field development scenarios, quantify uncertainty and risks of asset development. We also evaluate nearby exploratory prospects before recommending a field development plan to maximize the value of the asset.
The scope of the study included identification of dynamic units; evaluation of reservoir performance; estimation of in-place volumes and aquifer parameters; evaluation of possible increase in reserves and recovery factors.
Flowgrids used a four-step methodology to solve the problem:
Value to the client: Aquifer properties, STOOIP, reserves forecast, and pressure depletion trends firmed decision of the client on the sequence of asset development and prioritization to save costs and maximize value.
The scope of the study is the interpretation of multi-year pressure fall-off test data to support reservoir characterization.
Flowgrids used industry-standard software to interpret multi-year falloffs using analytical and numerical models to determine
Value to the client:
Flowgrids was asked to correct the misplaced zones introduced in a static model. We developed a fit-for-purpose reservoir characterization workflow to identify the static model’s correct sequence of reservoir flow units and propagated the model with the corrected petrophysical properties. The revised model was used as input for dynamic modeling. Relevant static model uncertainties were generated to support the client in making informed reservoir management decisions.