Most of the evaluations of thermal enhanced oil recovery (EOR) methods in numerical simulations mainly focus on the identification of recovery processes with the greatest potential to increase oil recovery. In some cases, the economic aspects of the EOR methods evaluated are also considered. However, these studies often lack the evaluation of the energy efficiency of the proposed methods as a strategy to support the selection of profitable recovery processes. Therefore, this study aimed to identify the potential of different hybrid cyclic steam stimulation (CSS, with flue gas, foam, nanoparticles, or solvents) methods based on a numerical simulation study using a radial model representative of a large heavy oil reservoir in the Middle Magdalena Basin, Colombia. The simulation results were used to estimate the benefit–cost (B/C) ratios and energy efficiency (EE) indices that can be used to screen and rank the hybrid CSS methods studied. When comparing different hybrid methods, it was found that CSS with nanoparticles or solvents performed better during the first two steam cycles (higher oil saturations). However, CSS with foam and flue gases showed higher incremental oil production (≥3564 bbls or 567 m³) during the sixth steam cycle. Based on an energy cost index (ECI = [(B/C) / EE]), CSS with foam outperformed (ECI ≈ 453) cyclic steam injection with flue gases (ECI ≈ 21) and solvents (ECI ≈ 0.1) evaluated during the sixth steam cycle. The results show that this methodology can be used to guide decision-making to identify hybrid CSS methods that can increase oil recovery in a cost-effective manner and provide an efficient energy balance.

The development of heavy oil reservoirs under steam injection methods is facing multiple challenges due to the volatility of oil markets, energy efficiency, and new and stricter environmental regulations. This study aims to summarize the advances of a Research and Development (R&D) program established by Ecopetrol in 2018 to identify potential opportunities to improve the recovery performance of steam injection projects in heavyoil reservoirs in the Middle Valley Magdalena Basin (VMM) of Colombia.This paper summarizes an approach used to evaluate downhole heating and hybrid steam injection technologies assisted by basic benefit-cost ratios and energy and environmental indexes.Specifically, the methodology is described for the identification of optimum development plan scenarios for heavy oil wells. This study also summarizes recent advances in laboratory studies for the evaluation of hybrid steam flooding technologies (steam plus flue gas and solvents) and provides updates on the hybrid cyclicsteam-foam pilot carried out in two VMM wells.The proposed approach represents a fast screening method that has proven to be valuable in supporting management decision-making to allocate resources for laboratory and engineering studies to evaluate thermal enhanced oil recovery (tEOR) technologies in Colombia. The proposed methodology has also contributed to reducing the implementation cycle of tEOR technologies following the reservoir analog description ofreserve analysis. The latter was validated with the successful pilot results of the hybrid steam injection with foams implemented in July 2019.

Conventional steam injection projects have long been an iconic process in the development of heavy oil reserves; nevertheless, they face significant challenges in terms of energy efficiency, environmental compliance, and economic viability. Factors such as oil price fluctuations, the imperative for an energy transition, and the push to reduce carbon footprints are hindering new or ongoing implementations of traditional steam injection technologies. In response to these challenges, hybrid methods, such as the combination of steam and flue gas, are emerging as an opportunity to optimize thermal processes to improve oil recovery, energy efficiency, and environmental sustainability and extend reservoir productivity life. Steam injection enhances oil recovery by reducing the viscosity of crude oil, improving oil mobility and facilitating its extraction. The utilization of flue gas in steam injection processes has a significant impact on oil recovery and energy efficiency, leveraging industrial byproducts. This not only lowers operating costs but also reduces environmental emissions, aligned with energy transition trends. Incorporating the flue gas into a steam-based process in heavy oil reservoirs has emerged as a promising thermally enhanced oil recovery strategy. This work presents a comprehensive review based on experimental, numerical, and field studies of hybrid steam and flue gas technology as an EOR process. The main recovery mechanisms associated with the process are analyzed. In addition, the laboratory equipment required for experimental evaluations is presented, and reservoir modeling, kinetic and compositional effects on reservoir fluids, and the reduction in heat losses in the steam injection process are discussed. Furthermore, field implementations are reviewed to evaluate lessons learned and experiences on an operative scale. The combination of steam and flue gas represents an opportunity for carbon utilization and geological carbon sequestration. This dual functionality underscores its potential to enhance oil recovery and address carbon-related environmental concerns.

An experimental program has been designed and executed to evaluate the performance of hybrid Cyclic Steam Stimulation (CSS) recovery methods. The overarching goal is to improve the energy efficiency and reduce the carbon footprint of CSS in Colombian heavy oil fields. Specifically, this work compares the impact that adding solvent or flue gas to cyclic steam injection has on the recovery of a recombined heavy live oil at a laboratory scale. A novel experimental setup was designed to evaluate hybrid CSS methods, which allows displacement of fluids out of the core during injection cycles and the return of those fluids to the core during soaking and production periods, by the use of a ballast system. A CSS baseline test and two hybrid CSS tests were performed at reservoir conditions (RC) with recombined live oil and core material from a Colombian heavy oil field. Each test consisted of four cycles with the same amount of steam injection. The hybrid CSS tests consisted of a steam-solvent and a steam-flue gas hybrid test. The CSS baseline and the hybrid CSS tests were successfully performed in the core pack with the injection of 0.12 pore volume CWE (Cold Water Equivalent) of steam per cycle, at core pressure near 680 psi_g and an initial core temperature of 45°C. In addition, steam-solvent and steam-flue gas hybrid tests injected near 0.01 and 0.05 PV (CWE) of solvent and flue gas per cycle, respectively. The steam front location during each cycle was identified with temperature profiles recorded along the core during the tests. Core pressures and fluid volumes displaced to and from the ballast were also recorded. Post-test core analyses allowed to estimate residual liquid saturations after each test. The addition of solvent or flue gas did not hinder the CSS oil recovery process which was in the order of 40% for all tests. The recovery, energy efficiency and carbon footprint of the hybrid CSS tests are compared to the CSS baseline case. Although a small amount of hydrogen sulphide (H₂S) was detected at the end of the CSS baseline test, H₂S was not detected in the produced gas of the hybrid tests. The experimental program enhanced the understanding of hybrid steam cyclic methods and the impact of solvent and flue gas addition on the recovery, energy efficiency and carbon footprint reduction of heavy oil CSS recovery processes. These results assist in the quest of improving CSS performance and provide key data for tuning numerical models. This novel experimental apparatus is one of a kind as it captures the cyclic nature of fluid movement during CSS.

Tracer technology has been used in the oil industry to investigate the fluid flow behavior into the reservoir. Using this technology is possible to obtain relevant data from the reservoir such as remaining oil accumulations, estimate volumetric sweep efficiency, define reservoir heterogeneities, identify flow channeling, and determine residual oil saturation (Sor). This technology has been one of the most useful tools for reservoir characterization for several decades. The tracer is injected in the injector well and then monitored in the producer wells through the tracer concentration measurements. Although many tracer studies have been documented for reservoir characterization, the available information and methodologies related to the design, implementation, and interpretation of tracer tests are limited or confidential. The goal of his article is to show a methodology for the design, execution, and interpretation of interwell tracer tests, which includes procedures for field implementation, sampling, and monitoring of these tests. Laboratory analysis using ultra-high-performance liquid chromatography is described in the experimental evaluation of tracer tests. Additionally, for a better understanding of the technology, examples of laboratory and field cases are presented.