Integrated Reservoir Description From Seismic, Well Log, to Production Data (1997)

Integrated Reservoir Description From Seismic, Well Log, to Production Data An-Ping Yang An-Ping Yang Texaco Search for other works by this author on: This Site Google Scholar Paper presented at the SPE Rocky Mountain Regional Meeting, Casper, Wyoming, May 1997. Paper Number: SPE-38381-MS https://doi.org/10.2118/38381-MS Published: May 18 1997 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Yang, An-Ping. "Integrated Reservoir Description From Seismic, Well Log, to Production Data." Paper presented at the SPE Rocky Mountain Regional Meeting, Casper, Wyoming, May 1997. doi: https://doi.org/10.2118/38381-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu toolbar search search input Search input auto suggest filter your search All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE Rocky Mountain Petroleum Technology Conference / Low Permeability Reservoirs Symposium Search Advanced Search AbstractThe increasing need to improve production from developed oil and gas fields requires more detailed and more accurate reservoir description. Our answer is a multidisciplinary approach integrating geophysics, geology, geostatistics, and engineering. For a field with seismic data, well logs, and production data, an integrated reservoir model can be more accurate than the conventional approach of passing the model from geophysicists to geologists then to engineers. In the development stage of a field, a geological model would have been built. The model would have been tested against production data. Now If we are going to build a more detailed model, the existing reservoir model is a valuable input. When dealing with seismic data, time permitting, known information of structure and stratigraphy may be used. When converting time data to depth, well data may be used together with seismic information to build a 3D velocity model. Geostatistics may be used with velocity logs and seismic data to build a more accurate and detailed velocity model. Without a reasonable velocity model for time depth conversion, it is difficult to integrate well data and seismic data. A lithology model or porosity model may be built with well data, structure information, and seismic attribute as soft data. Seismic attributes are calibrated to well data. Geostatistics provides a way to properly weight between well data and seismic data. The reservoir model may be compared or calibrated with production data. Then we may go back and modify the velocity model or horizon picks, or we may modify the conversion from seismic attribute to soft data used in the geostatistical gridding. By iteration, our reservoir model will become more accurate because it honors geophysical, geological, and engineering data. Common data links and tools like geostatistics make the integration easier.Field applications show that an integrated iterative approach to detailed reservoir modeling can provide a better model and help optimize production.IntroductionReservoir description is an essential tool for producing more hydrocarbon at lower cost. Depending on the purpose of the reservoir description, the complexity and time required can be very different. For the best results, integration is the key. Integration includes integration of various disciplines, integration of various data types and various models, and a common reservoir description that can be reconciled from various aspects.Let's consider a typical reservoir description process from seismic to production data. In a non-integrated approach as shown in Fig. 1: seismic data is processed without the benefit of a reservoir description model, horizons are picked and used as is, geological model is built without understanding how the seismic data was interpreted, then a reservoir simulation model is built with modification to the geological model in order to match production history without going back to the geologist or geophysicist. There are at least four reservoir models here: one velocity model for seismic processing, one velocity model for time-depth conversion, one geological model before reservoir simulation, and one geological model in reservoir simulation. It is not uncommon that these models become inconsistent, as illustrated in Fig. 2. When each step of the modeling process is isolated, the tendency is to modify the reservoir model in such a way that other workers may not agree from their understanding of the data. In a non-integrated process, each reservoir model, such as seismic velocity models, geological model, and engineered reservoir model actually used in reservoir flow simulation, is modified to honor one group of data but may contradict other groups of data. The result is that each reservoir model is less realistic than the available data and the predictions are less accurate than possible with an integrated approach.When we need to modify the reservoir model to honor our data, which part should we change? P. 295^ Keywords: resolution, Reservoir Description, velocity model, conversion, Modeling & Simulation, seismic data, reservoir property, structure information, direct construction mode, structure data Subjects: Reservoir Characterization, Seismic processing and interpretation This content is only available via PDF. 1997. Society of Petroleum Engineers You can access this article if you purchase or spend a download.