This article demonstrates an integration platform that combines physical and mathematical models of oil and gas field units into a single holistic calculation process and allows you to find consistent solution in the Reservoir - Well - Surface Pipeline Network – etc. system, an integrated asset model (IAM). The main goal is to introduce integrated asset modeling into production processes and obtain the maximum business benefit from production at current capacities. The software package implemented on the web-platform called Hybrid IAM allows to predict the operation of the production and injection wells for single-layer and multi-layer objects. The main well performance indicators obtained as a result of the IAM calculation are the flow rates of production wells for each fluid component, the injection volumes of injection wells, the dynamics of reservoir pressure, PVT-properties and other field indicators. To solve various oil production problems, it is possible to automatically define the necessary models configuration depending on the requirements for the speed and accuracy of the final solution. A method is proposed for reducing the time of optimization calculations by using a hierarchy of models. On the example of a synthetic oilfield, successful validation of calculations with the reference software product for the calculation of integrated models (IPM Petex) was carried out. Acceptable convergence between the IMA calculation and the historical fluid production for the selected assets of the company has been achieved. On the example of real business cases, the possibility of IMA for calculating various options for optimizing the current oil production wells is demonstrated. Thus, the proposed integrated asset model can be used to predict and optimize the operation of the current oil production wells and sets of well interventions, taking into account multiple goals (production efficiency maximization, reduction of CAPEX, OPEX) and restrictions (capacity of the surface infrastructure, external restrictions on production volumes, etc).
References
1. Vogel J.V., Inflow performance relationships for solution-gas drive wells, Journal of Petroleum Technology, 1968, V. 20, pp. 83-92.
2. Dake L.P., Fundamentals of reservoir engineering, Elsevier Scientific Publishing Company, 1978, 443 p.
3. Beggs H.D., Brill J.P., A study of two-phase flow in inclined pipes, Journal of Petroleum Technology, 1973, V. 25, pp. 607-617, DOI:10.2118/4007-PA
4. Brill J.P., Mukherjee H., Multiphase flow in wells, SPE Monograph, Henry L. Dogherty Series, V.17, 1999, p. 17.
5. Hagedorn A.R., Brown K.E., Experimental study of pressure gradients occurring during continuous two-phase flow in small-diameter vertical conduits, Journal of Petroleum Technology, 1965, V. 17(04), pp. 475–484.
6. Yudin E.V., Khabibullin R.A., Galyautdinov I.M. et al., Creation of a proxy-integrated model of the Eastern section of the Orenburgskoye oil-gas-condensate field under the conditions of lack of initial data (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 12, pp. 47-51, DOI: https://doi.org/10.24887/0028-2448-2019-12-47-51
7. Khamidullin R.D., Ismagilov R.R., Kan A.V. et al., The choice of regional infrastructure development strategy in conditions of production uncertainty using software ERA:ISKRA (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 12, pp. 64-67, DOI: https://doi.org/10.24887/0028-2448-2017-12-64-67
