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Collaborating Authors
Results
Laboratory Study of CO2 Foam for Enhanced Oil Recovery: Advanced Screening, Optimization, and Evaluation
Ahmed, Shehzad (Universiti Teknologi PETRONAS) | Elraies, Khaled Abdalla (Universiti Teknologi PETRONAS) | Hashmet, Muhammad Rehan (Khalifa University of Science and Technology) | Hanamartani, Alvinda Sri (Universiti Teknologi PETRONAS) | Bt Mohd Shafian, Siti Rohaida (PETRONAS Research Sdn Bhd)
Abstract CO2 foam has been proposed as mobility control agent to overcome various limitation of CO2 injection such as viscous fingering, gravitational override and reservoir heterogeneities which lead to poor sweep efficiency. In this study, CO2 foam formulation was screened and optimized under HPHT conditions to achieve strong foam which results in high oil recovery. For this purpose, different surfactant formulations were prepared in brine with fixed salinity. The stability of bulk foam was measured using FoamScan (Teclis) in the presence of Malaysian crude oil. Whereas, a HPHT foam rheometer was used to perform advanced level screening and optimization at different foam qualities and shear rates. The best foam formulation obtained was then evaluated in core flooding experiment using Berea sandstone (250mD) by co-injection mode under HPHT condition. Among various formulated surfactant mixtures, the combination of alpha olefin sulfonate (AOS) and betaine with specific composition was able to generate strong supercritical CO2 foam at different shear rates under reservoir conditions. Foam rheology results showed that 80% foam quality as the optimum condition for having a high apparent viscosity. Results from co-injection experiments in porous media show that the designed CO2 foam has successfully improved the cumulative oil recovery from 57.58% to 74.08%.
- North America > United States (1.00)
- Asia > Middle East > Saudi Arabia > Eastern Province (0.46)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.66)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (21 more...)
Experimental Investigation and Optimization of Polymer Enhanced CO2 Foam Stability and Apparent Viscosity
Ahmed, Shehzad (Universiti Teknologi PETRONAS) | Elraies, Khaled Abdalla (Universiti Teknologi PETRONAS) | Hashmet, Muhammad Rehan (Petroleum Institute) | Bt Mohd Shaifan, Siti Rohaida (PETRONAS Research Sdn Bhd) | Hsia, Ivy Chai (PETRONAS Research Sdn Bhd) | Bahrim, Ridhwan Zhafri (PETRONAS Research Sdn Bhd)
Abstract Polymer enhanced foam (PEF) provides an additional strength over conventional CO2 foams for mobilizing oil from the unswept low permeable oil rich zones during an enhanced oil recovery process. The efficiency of the process depends on two major factors i.e. stability and apparent viscosity of PEF. In this study, an experimental investigation of apparent viscosity and stability of polymer enhanced CO2 foam is presented with an objective to assess the polymer performance and to identify the best performing polymer under reservoir conditions of 1500 psi and 80 °C. For this purpose, conventional standard hydrolyzed polymacrylamide (HPAM) polymers and an associative polymer i.e. Superpusher P329 were used in combination with a widely used foamer i.e. alpha olefin sulfonate (AOS) and a foam stabilizer i.e. betaine. Foam stability tests were conducted in the presence of crude oil using FoamScan. Whereas for foam rheological study, a high pressure high temperature Foam Rheometer was utilized and the foam was sheared over the range of 10 to 500 sec inside the recirculating loop. As compared to other HPAMs, an associative polymer i.e. Superpusher P329 significantly amplified foam longevity and provided a more prolonged liquid drainage. A shear thinning behavior was observed for the entire range of shear rate tested and for all the tested foam. HPAMs were found ineffective in improving foam apparent viscosity and the viscosities obtained were found equivalent to that to polymer free foam. Superpusher P329 showed interesting combination with AOS and significant viscosity enhancement has been reported in this paper. This research concluded that Superpusher P329 has the ability to generate strong foam and it is a potiential candidate for mobility control during polymer enhanced CO2 foam flooding process. Keywords: Polymer Enhanced Foam, foam stability, apparent viscosity; CO2 foam.
- Asia > China > Shandong > North China Basin > Shengli Field (0.99)
- Asia > China > East China Sea > Bohai Basin > Jiyang Basin > Gudao Field > Guantao Formation (0.99)
Injection of Polymer for Improved Sweep Efficiency in High Temperature High Salinity Carbonate Reservoirs: Linear X-Ray Aided Flood Front Monitoring
Hashmet, Muhammad Rehan (ADNOC Research and Innovation Center, Abu Dhabi) | Qaiser, Yemna (ADNOC Research and Innovation Center, Abu Dhabi) | Mathew, Eric Sonny (ADNOC Research and Innovation Center, Abu Dhabi) | AlAmeri, Waleed (ADNOC Research and Innovation Center, Abu Dhabi) | AlSumaiti, Ali M. (ADNOC Abu Dhabi)
Abstract Polymer flooding is one of the most commonly used techniques to improve oil recovery; however its application is dependent on the technical and economic feasibility along with the knowledge of the risks involved. The presented work is focused on quantifying the uncertainties affecting the mobility of injected fluid in polymer flooding along with a sensitivity analysis of influential parameters. Initially, a coreflooding experiment on carbonate core sample is performed using partially hydrolyzed polyacrylamide, SAV 10 under high temperature high salinity conditions. The coreflood apparatus is aided with linear X-ray in order to record real time saturations for the entire length of core sample in addition to the pressure and production data. The experimental data are then history matched using commercial software to generate relative permeability curves and to optimize polymer slug size and initiation time. The optimized model is then used as a reference and a coredflood is conducted on the optimized conditions i.e. slug size and initiation time. The recovery obtained from the experimental run is compared with the simulation results. Polymer viscosity, adsorption on the rock surface and mechanical degradation are some of the other parameters included in the study. The optimum polymer flooding scenario established in this study is injection of 0.1 PV of polymer after 0.3 PV water injection. Encouraging results are obtained at the optimized conditions resulting in an overall recovery factor of 84% and early injection of polymer also helped to delay the breakthrough time. The small slug size resulted in low adsorption and residual residual factor for the optimized case is found to be 1.73.
- North America > United States (1.00)
- Europe (1.00)
- Asia > Middle East > UAE (0.29)