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Collaborating Authors
Results
Investigation of Polymer-Enhanced Foam Flooding With Low Gas/Liquid Ratio for Improving Heavy Oil Recovery
Pei, H.. (China University of Petroleum) | Zhang, G.. (China University of Petroleum) | Ge, J.. (China University of Petroleum) | Wang, J.. (China University of Petroleum) | Ding, B.. (China University of Petroleum) | Liu, X.. (China University of Petroleum)
Abstract Severe viscous fingering during water flooding of heavy oil leaves a large amount of oil untouched in the reservoir. Improving sweep efficiency is vital for increasing heavy oil recovery. Previous researches have proved that foam flooding can increase the sweep efficiency and control gas mobility, and thus increase oil recovery. However, researches on foam flooding were always focusing on the effect of high gas/liquid ratio (The gas/liquid ratio is usually larger than 1:1). Little research was conducted on foam flooding with low gas/liquid ratio. This paper presents the results of a laboratory study of polymer enhanced foam flooding with low gas/liquid ratio for heavy oil in Shengli oilfield. For polymer enhanced foam (PEF), the displacement medium is N2 mixed with surfactant as foaming agent and HPAM. The experimental investigation evaluated the performance of foaming agent and studied the use of polymer to enhance foam properties. Polymer enhanced foam flooding were performed in cores, sandpacks and 3D physical model to study the factors affecting displacement efficiency such as gas/liquid ratio, injection slug size, and the viscosity of crude oil. The results of sandpack flood tests showed that the tertiary oil recovery of polymer enhanced foam flooding with the gas/liquid ratio of 0.2:1 could reach 39% IOIP for heavy oil with the viscosity of 325mPaยทs at 55, which was 11% higher than the alkali/surfactant/polymer flooding by injecting a 0.3 pore volume (PV) of the same chemical slug. However, the tertiary oil recovery decreased with the increasing viscosity of crude oil. The result obtained in 3D physical simulation indicated that polymer enhanced foam system had excellent profile modification effect to increase sweep area and thus increase oil recovery. The above results demonstrate that polymer enhanced foam flooding with low gas/liquid ratio is a promising economical method for improving heavy oil recovery after water flooding.
- Asia > China > Shandong Province (0.25)
- North America > United States > Oklahoma (0.15)
- Asia > China > Shandong > North China Basin > Shengli Field (0.99)
- Asia > China > Liaoning > Bohai Basin > Liaohe Basin > Liaohe Field (0.99)
- Asia > China > Heilongjiang > Songliao Basin > Daqing Field > Yian Formation (0.99)
- (2 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Chemical flooding methods (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Downhole and wellsite flow metering (1.00)
Abstract In recent years successful stimulation and extraction of hydrocarbons from unconventional reservoirs has led to various approaches to the stimulation process. Slickwater stimulations pumped at very high flow rates have become the staple in formations such as the Barnett Shale. High treatment rates are made possible by the implementation of low dosages of polyacrylamide, which lower the effective pipe friction. This type of treatment process is common among other shale and tight gas plays throughout North America. Other types of treatments include conventional crosslinked or linear gelled fluids. Some treatments combine the conventional crosslinked fluids and the slickwater approach. Experimentation with multiple stimulation programs is a response to the changes in formation properties that vary from one formation to the next and within areas of the same formation. Over the last few years there have been several successful treatments implementing a high-quality foam stimulation in some shale formations. These treatments have usually included a gas phase in excess of 90 quality and often as high as 99 quality. This type of treatment is especially fitting for low-pressure reservoirs and in depleted zones. One advantage of a high-quality foam is its reduced environmental impact by using very small quantities of water as compared to high-rate slickwater stimulations. In these particular high-quality foams, a viscoelastic surfactant gel is used in the liquid phase as the gelling and foaming agent. With the combination of high-quality foam and non-damaging viscoelastic gel, the total fluid is completely non-damaging to the formation. Successful treatments in formations in the northeastern United States have led to a demand for use in other formations, necessitating a better understanding of fluid properties in order to design treatments. Very little published data is available for high-quality foam fluid properties. A study has been conducted to examine the fluid characteristics of high-quality foams as compared to typical 50 - 70 quality foams. This study will show trends of viscosity, foam stability and temperature sensitivity of high-quality foams using xanthan, guar-based gelling agents and viscoelastic base fluids.
- North America > Canada (0.46)
- North America > United States > Texas (0.24)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- North America > United States > Tennessee > Appalachian Basin (0.99)
- North America > United States > Georgia > Appalachian Basin (0.99)
- (15 more...)