Injectivity Profile Monitoring and Hot Water Flooding Optimization for Horizontal Well 2G on Rospan's Russkoe Heavy Oil Field using DTS

There are abundant heavy oil deposits characterized by shallow depth, thin pay zone, low porosity, and bottom water in Western Canada. These types of reservoirs are neither suitable for thermal heavy oil recovery techniques (e.g. SAGD) nor for solvent injection (e.g. VAPEX). Coupling of Solvent and Hot Water (CSHW) injection was proposed and examined as an alternative to improve the heavy oil recovery in these reservoirs. In this study, a series of core flooding tests and numerical simulations were conducted to investigate and evaluate the CSHW injection performance in thin heavy oil reservoirs containing oil with viscosity of around 1,000 to 6,000 cP. To identify the contribution of hot water and solvent as well as their effectiveness when they combined, three types of core flooding tests were performed individually using hot water, solvent, and CSHW injection. In addition, the effects of oil viscosity, water injection temperature (15°C, 24°C, 50°C, 65°C) and solvent (C1, C3, C1+C3) on oil recovery were examined. Moreover, effects of parameters such as injection rate, displacement volume, slug size, and injection pattern were also investigated. Furthermore, the core flooding tests were history matched based on the established numerical simulation model. The effects of temperature and solvent components on multi-phase fluid flow were examined through numerical simulation. As the result, the optimal CSHW injection parameters were screened based on experimental and numerical studies conducted. Results of this study showed that the oil recovery factor was enhanced by 19.1% when temperature of injection water increases from 24°C to 65°C. More importantly, it was found that the CSHW is a more feasible option that recovers higher amount of oil at lower cost when compared with pure solvent or hot water injection. In addition results indicated that if smaller slugs of hot water and solvent are injected, the recovery process is more efficient. In this particular study, injection of smaller slugs resulted in 53.5% recovery factor. These results indicate that the CSHW is a promising hybrid process for the heavy oil recovery which requires low facility investment.

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Specifics and Challenges of Heavy oil Production in Northen Siberia Illustration Based on Biggest Heavy Oil Project in Russia

Vologodskiy¹,

Telkov²,

Aksenov³

et al. 2013

All Days

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Russkoye heavy oil field is located in the northern part of Siberia. The field was discovered in 1968. It is characterized by the huge reserves: more than 1.3 billion tonn of oil in place and remote location (the field is located to the north from the polar circle). Main challenges for the field development are: unconsolidated formation, gas cap, high heterogeneity of formation, permafrost zone and heavy oil. This paper covers latest experience (2007)(2008)(2009)(2010)(2011)(2012) obtained during field development pilot project implementation at the representative part of the Russkoye field. Pilot stage results will be used for the further field development strategy building. Effectiveness of different approaches has to be estimated, considering specifics of the field. Traditional field instrumentation did not provided reliable data for the analysis. New technologies (such as fiber optic distributed temperature sensors, specifically adopted multiphase metering etc.) were implemented for the building of the proper data acquisition system. During the pilot stage specific injection schedules, cold and hot water injection, various well completion applications were implemented. Depletion rate estimation based on real production data, determination of critical drawdown and numerous well testing activities including conventional buildup/drawdown pressure transient analysis and interference testing were made. Special attention is paid to the comparison of the cold and hot water injection and to the methods of control/monitoring of the well production. Monitoring and effectiveness estimation of the tested technology should be based on flow rate measurements data (MPFM), distributed pressure and temperature sensors (DP/TS) in horizontal production wells. Numerous new technologies were used for the pilot project. Paper describes approaches for integrated data acquisition implementation; development techniques comparison and new technologies adaptation workflow to the specific field conditions. New technologies application allowed to see specific field behavior and to estimate effect of various field development and management approaches tested. The results obtained during the pilot project will be used for the Russkoye field development planning, technical solutions will be implemented for the field monitoring and managing. Successful development of the first biggest heavy oil field should lead to initiation of development of other numerous challenging heavy oil fields in Russia.

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Injectivity Profile Monitoring and Hot Water Flooding Optimization for Horizontal Well 2G on Rospan's Russkoe Heavy Oil Field using DTS

Cited by 5 publications

References 2 publications

Creation and registration of thermal marks for horizontal wells monitoring

Creation and registration of thermal marks for horizontal wells monitoring

Coupling of Solvent and Hot Water to Improve Heavy Oil Recovery: Experimental and Simulation Studies

Specifics and Challenges of Heavy oil Production in Northen Siberia Illustration Based on Biggest Heavy Oil Project in Russia

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