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Collaborating Authors
Results
Influencing Factors Analysis in the Combination of Gel Treatment and Low Salinity Water Flooding Using Sensitivity Analysis
Alhuraishawy, Ali K. (Missan Oil Company, Missouri University of Science and Technology) | Alfarge, Dheiaa (Missouri University of Science and Technology) | Wei, Mingzhen (Missouri University of Science and Technology) | Bai, Baojun (Missouri University of Science and Technology) | Almansour, Abdullah (King Abdulaziz City for Science and Technology)
Abstract Gel treatment is often used to control the excessive water production in fractured reservoirs. Combined technology has drawn a great interest in the oil industry over the last decade. Recently, gel treatment combined with low salinity waterflooding brought a significant attention in reservoir engineering. It has been reported that low salinity waterflooding can improve displacement efficiency. Gel treatment has been proved to plug fractures and improve sweep efficiency. The objective of this paper is to provide a deeper understanding of this combined technology by applying experimental and simulation approach (sensitivity analysis). The purpose of sensitivity analysis is to determine how sensitive the oil recovery factor obtained at different conditions to different parameters. The experimental results found that the low-salinity water can improve oil recovery factor by 6% and plugging efficiency was also improved. The sensitivity analysis results showed that the initial oil saturation, oil viscosity, porosity, and matrix permeability were the most important parameters affecting improved oil recovery when combined technology applied. The matrix permeability was the most important parameter impacting the obtained oil recovery, and the oil saturation was the lowest. The performance of using low-salinity water increased when matrix permeability increased, and porosity decreased. Identifying the parameters which have a significant impact on oil recovery would give a good prediction for combined technology success or failure depending on reservoir properties.
- Asia > Middle East (0.93)
- North America > United States > California (0.28)
- Geology > Mineral (0.47)
- Geology > Rock Type > Sedimentary Rock (0.46)
A Parametric Study on the Applicability of Miscible Gases Based EOR Techniques in Unconventional Liquids Rich Reservoirs
Alfarge, Dheiaa (Iraqi Ministry of Oil, Missouri University of Science and Technology) | Wei, Mingzhen (Missouri University of Science and Technology) | Bai, Baojun (Missouri University of Science and Technology)
Abstract Shale formations in North America such as Bakken, Niobrara, and Eagle Ford have a huge oil volume in place, 100-900 Billion barrels of oil in Bakken only. However, the predicted primary recovery is still below 10%. Therefore, seeking for techniques to enhance oil recovery in these complex plays is inevitable. In shale oil reservoirs, EOR is relatively novel compared with in conventional oil reservoirs. The most investigated technique among EOR methods to be applied in shale oil reservoirs is injecting miscible gases which mainly include CO2, N2 and enriched natural gases. However, these different gases showed different performance in both of lab scale and field pilots conducted in shale reservoirs. In this paper, numerical simulation methods of compositional models have been incorporated with LS-LR-DK (logarithmically spaced, locally refined, and dual permeability) models to mimic the performance of CO2 as well as natural gases (lean gas and rich gas) in different scenarios of unconventional reservoirs. The models of this study are mainly built on the sensitivity analysis for the fluid and rock properties of Bakken formation. Sensitivity analysis methods used in this study were conducted by using two main methods of Design of Experiments (DOE) which are Response Surface Methodology (RSM) and One Parameter At A Time (OPAAT) approach. This study found that the main parameters affecting CO2-EOR performance are not the same parameters influencing natural-gases (NGs) EOR performance in shale reservoirs. This happens due to the difference in the physical nature among gases, especially the molecular weight difference between CO2 and NGs where the molecular diffusion flow is the dominated flow type in those very tight formations. This study also indicated that NGs-EOR performance exceeds the performance of CO2-EOR in the formations with very small pore throats (Permeability in range of 0.00001-1 mD). However, injecting CO2 is highly recommended over injecting NGs in the reservoirs with the permeability of more than 1 mD. Moreover, it has been observed that NGs are not very strong function of natural fractures intensity as CO2. Furthermore, due to the small molecular weight of NGs, they do not require very large contact areas as CO2 does. This study explains the effects of different nano and macro mechanisms on the performance of CO2-EOR and natural-gases EOR in unconventional reservoirs since these plays are much complex and very different from conventional formations. Also, general guidelines have been provided in this study to enhance success of CO2-EOR in unconventional reservoirs.
- North America > Canada (1.00)
- North America > United States > Montana (0.89)
- North America > United States > North Dakota > Mountrail County (0.28)
- Europe > United Kingdom > North Sea > Central North Sea (0.24)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.99)
- North America > United States > North Dakota > Williston Basin > Bakken Shale Formation > Middle Bakken Shale Formation (0.99)
- North America > United States > North Dakota > Sanish Field > Bakken Shale Formation (0.99)
- (2 more...)
Submicron-Pore Characterization of Shale Gas Plays
Elgmati, Malek (Missouri University of Science & Technology) | Zhang, Hao (Missouri University of Science & Technology) | Bai, Baojun (Missouri University of Science & Technology) | Flori, Ralph (Missouri University of Science & Technology) | Qu, Qi (Baker-Hughes Company)
Abstract Gas storage and flow behavior in the shale gas rocks are complex and hard to identify by conventional core analysis. This study integrates clustering analysis techniques from material science, petrophysics, and petrology to characterize North American shale gas samples from Utica, Haynesville, and Fayetteville shale gas plays. High pressure (up to 60,000 psi) mercury porosimetry analysis (MICP) determined the pore size distributions. A robust, detailed tomography procedure using a dual-beam (Scanning Electron Microscope and Focused Ion Beam, also called SEM-FIB) instrument successfully characterized the submicron-pore structures. SEM images revealed various types of porosities. Pores on a scale of nanometers were found in organic matter; they occupy 40–50% of the kerogen body. Two-hundred two-dimensional SEM images were collected and stacked to reconstruct the original pore structure in a three-dimensional model. The model provided insights into the petrophysical properties of shale gas, including pore size distribution, porosity, tortuosity, and anisotropy. This paper presents the pore model constructed from Fayetteville shale sample. The work used X-ray diffraction (XRD) to semi-quantify shale gas clay and non-clay minerals. The Haynesville and Utica (Indian Castle formation) shale samples have a high illite content. The Utica (Dolgeville formation) shale samples show high calcium carbonate (calcite) content. Moreover, wettability tests were performed on the shale samples, and the effect of various fracturing fluid additives on their wettability was tested. Most additives made the shale gas surfaces hydrophilic-like (water-wet).
- North America > United States > Texas (0.94)
- North America > United States > Arkansas > Washington County > Fayetteville (0.46)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Mineral (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.67)