Techno-economic evaluation of production integration from a reservoir to market under multiple scenarios: a case study of a condensate gas reservoir

Abstract This study investigates the optimization of condensate recovery in a retrograde gas reservoir, where production efficiency is hindered by complex interactions between subsurface and surface processes. Accurate modeling of these interactions is essential for reliable production forecasting and economic assessment. This research compares the efficacy of two simulation methodologies: (1) standalone reservoir modeling and (2) integrated modeling encompassing the reservoir, wells, pipelines, and surface facilities under various gas reinjection and production scenarios. Key economic metrics, including Net Present Value (NPV) and Modified Internal Rate of Return (MIRR), are employed to assess scenario feasibility and identify optimal recovery strategies. The findings demonstrate that integrated modeling significantly enhances production forecasts' accuracy by capturing interdependencies often neglected in standalone models. Specifically, optimized gas reinjection in the integrated model resulted in a 15% increase in condensate recovery and improved reservoir pressure maintenance, thereby facilitating sustained productivity. Economically, integrated simulations yielded an NPV up to 10% higher than the standalone approach under optimal reinjection conditions, indicating enhanced economic resilience to market fluctuations. Through this methodology, the study provides a more comprehensive framework for evaluating technical and economic performance in gas condensate reservoir management, offering refined tools for informed decision-making in complex field operations.