Assessing the Geothermal Resource Potential of an Active Oil Field by Integrating a 3D Geological Model With the Hydro-Thermal Coupled Simulation

Abstract

Assessment of available geothermal resources in the deep oil field is important to the synergy exploitation of oil and geothermal resources. A revised volumetric approach is proposed in this work for evaluating deep geothermal potential in an active oil field by integrating a 3D geological model into a hydrothermal (HT)-coupled numerical model. Based on the analysis of the geological data and geothermal conditions, a 3D geological model is established with respect to the study area, which is discretized into grids or elements represented in the geological model. An HT-coupled numerical model was applied based on the static geological model to approximate the natural-state model of the geothermal reservoir, where the thermal distribution information can be extracted. Then the geothermal resource in each small grid element is calculated using a volumetric method, and the overall geothermal resource of the reservoirs can be obtained by making an integration over each element of the geological model. A further parametric study is carried out to investigate the influence of oil and gas saturations on the overall heat resources. The 3D geological model can provide detailed information on the reservoir volume, while the HT natural-state numerical model addressed the temperature distribution in the reservoir by taking into account complex geological structures and contrast heterogeneity. Therefore, integrating the 3D geological modeling and HT numerical model into the geothermal resource assessment improved its accuracy and helped to identify the distribution map of the available geothermal resources, which indicate optimal locations for further development and utilization of the geothermal resources. The Caofeidian new town Jidong oil field serves as an example to depict the calculation workflow. The simulation results demonstrate in the Caofeidian new town geothermal reservoir that the total amount of geothermal resources, using the proposed calculation method, is found to be 1.23e+18 J, and the total geothermal fluid volume is 8.97e+8 m3. Moreover, this approach clearly identifies the regions with the highest potential for geothermal resources. We believe this approach provides an alternative method for geothermal potential assessment in oil fields, which can be also applied globally.

Review of discrete fracture network characterization for geothermal energy extraction

“…The use of seismic attributes is used to generated 3D DFN models due to their capability to detect the principal trends, and presence of faults that can represent preferential flow pathways for the geothermal fluids (Bense et al, 2013;Schneider et al, 2016;Cho et al, 2019;Marchesini et al, 2019;Cho, 2021;Fadel et al, 2022;Huang et al, 2022;Xing et al, 2022;Zhang E. Y. et al, 2022;Chiodini et al, 2023).…”

How temperatures derived from fluid flow and heat transport models impact predictions of deep geothermal potentials: the “heat in place” method applied to Hesse (Germany)

“…Purely conductive simulations, however, are not convincing in regions, clearly influenced by fluid flow, like the Upper Rhine Graben area, or other sedimentary basins with deep porous aquifer layers. In such convectiondominated regions differences between measured subsurface temperatures and purely conductive models can exceed up to ± 50 • C. Therefore, we used thermo-hydraulic simulations to predict the deep temperature distribution, like in the recent work from Huang et al (2022) to involve the physical complexity of heat transport into the prediction of the HIP. We have extensively studied the deep thermal and hydraulic field of the entire Federal State of Hesse (Germany) by means of 3D thermohydraulic simulations as based on regional geological models (Koltzer et al 2019a).…”