Rationalizing the Concept of Net-to-Gross With Respect to Reservoir Heterogeneity and Flow Behavior Utilizing Machine Learning Analyses
- Sheldon Gorell (Texas Tech University) | Justin Andrews (Texas Tech University) | Jim Browning (Texas Tech University)
- Document ID
- Society of Petroleum Engineers
- SPE Eastern Regional Meeting, 15-17 October, Charleston, West Virginia, USA
- Publication Date
- Document Type
- Conference Paper
- 2019. Society of Petroleum Engineers
- Net to Gross, Volumetrics, Flow Behavior, Upscaling, Reservoir Simulation
- 0 in the last 30 days
- 51 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 5.00|
|SPE Non-Member Price:||USD 28.00|
Though seemingly straightforward, the concept of "net-to-gross" (NTG) is often a source of confusion. Its proper use is still being debated in some portions of the oil and gas industry. NTG is a method to account for non-reservoir quality rock when calculating oil volumes within a reservoir. This is normally accomplished by applying cutoffs to calculated quantities, such as porosity, which then get excluded from the volumetric calculation. To the extent there have been recent discussions of this, the focus has been primarily on how to determine appropriate cutoffs. There has been very little mention of the implications of using NTG in flow equations within a reservoir simulator. The paper discusses the derivation and implied assumptions for the simulator NTG formulation and possible errors and proposes modifications to account for inconsistencies.
Resolving the NTG flow equations can be viewed as an upscaling problem, subject to implied assumptions about reservoir continuity. Many fine-scale reservoir simulations were run to test this and to calibrate the NTG equations. The underlying attributes were sampled from a bimodal distribution, which represent pay and non-pay. The results show the effects of NTG ratio, values of fine-scale attributes and spatial correlation on steady state, single phase effective permeability and immiscible flow displacements. They demonstrate errors in effective horizontal and vertical permeability when using NTG within a simulator. These errors cause potentially significant differences in production responses between underlying detailed fine-scale models and coarser models. The results demonstrate a possible need for corrections to the simulator net-to-gross formulations due to underlying implied assumptions and inconsistencies. Some possible modifications are also presented. Both standard and machine learning techniques were used to analyze the results.
|File Size||14 MB||Number of Pages||22|
Waleed Bulushi, Kraaijveld Martin A., and Mahrooqi Sultan, "Integration of Five Different Data Sources to Derive Robust Net-to-Gross Cut-Offs and Their Ranges." SPWLA Middle East Regional Symposium, Abu Dhabi, UAE, 2007/1/1/, 2007, https://doi.org/.
Helba, A. A., Sahimi, M., Scriven, L. E., & Davis, H. T. (1992, February 1). Percolation Theory of Two-Phase Relative Permeability. Society of Petroleum Engineers. doi:10.2118/11015-PA
Lalanne, Bruno J. P. and J. Massonnat Gerard, "Impacts of Petrophysical Cut-Offs in Reservoir Models." SPE Annual Technical Conference and Exhibition, Houston, Texas, 2004/1/1/, 2004, https://doi.org/10.2118/91040-MS.
Roadifer, R. D. and Scheihing M. H., "Impacts of the Porosity-Permeability Transform Throughout the Reservoir Modeling Workflow." SPE Annual Technical Conference and Exhibition, Denver, Colorado, USA, 2011/1/1/, 2011, https://doi.org/10.2118/146574-MS.
Worthington, Paul F. and Luca Cosentino, "The Role of Cut-Offs in Integrated Reservoir Studies." SPE Annual Technical Conference and Exhibition, Denver, Colorado, 2003/1/1/, 2003, https://doi.org/10.2118/84387-MS.