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Characterisation of Reservoir Rock and Fluids for CO2 Foam Enhanced Oil Recovery Application
| Content Provider | Scilit |
|---|---|
| Author | Phukan, Ranjan Gogoi, Subrata Borgohain Tiwari, Pankaj |
| Copyright Year | 2020 |
| Description | Book Name: Advances in Petroleum Technology |
| Abstract | The characterisation of reservoir rock and fluids is essential before embarking on any enhanced oil recovery (EOR) process. Moreover, the successful application of EOR processes requires a detailed reservoir description, including engineering and geological considerations. In this chapter, the reservoir rock, crude oil and formation water (FW) of an Upper Assam oilfield were characterised to evaluate the feasibility of implementing a $CO_{2}$ foam EOR process. First, routine core analysis was done to determine the important petrophysical properties of reservoir rocks, including porosity and permeability. Second, characterisation of the reservoir rock was done to evaluate its mineralogy and clay content through X-ray diffraction (XRD) and field emission scanning electron microscopy (FESEM) studies. Third, the important physicochemical properties of crude oil affecting the process of oil recovery, including American Petroleum Institute (API) gravity, viscosity, pour point, resin-asphaltene 122content and acid number, were determined. Fourth, FW analyses were done to evaluate its physciochemical properties. The porosity of the core plugs ranged from 11% to 28% and was found to bear an inverse correlation with the depth of the formation. The gas permeability of the core plugs was observed to be greater than the permeability value obtained by flowing liquid. The values of liquid and gas permeabilities of the core plugs ranged from 3 to 30 mD and 16 to 47 mD, respectively, which classified the oilfield formation as fair- to moderate-permeability reservoirs. Porosities and permeabilities of the core plugs were observed to be directly related as more porous rocks were also more permeable. Further, the XRD study of powered rock samples indicated the presence of silica (quartz) in the rock sample, which classified the reservoir rock as anionic type. Additionally, the FESEM micrograph of the rock sample showed the presence of smectite clays in the rock matrix. The experimental investigation confirmed that the crude oil was medium-gravity (API gravity 31°) with a dead oil viscosity of 4.46 cP at 70°C. The pour point of the crude oil was high (24°C ± 3°C), which indicated the paraffinic nature of the crude oil. The wax content was also fairly high at 12.47% ± 0.70%. The resin-to-asphaltene ratio of the crude oil was high enough for asphaltene stabilisation during $CO_{2}$ injection. The analysis also marked the crude as acidic and suitable for alkaline flooding. The FW analysis showed the presence of different types of dissolved cations and anions with a total salinity of 3458 ppm. |
| Related Links | https://content.taylorfrancis.com/books/download?dac=C2020-0-13339-3&isbn=9781003049937&doi=10.1201/9781003049937-7&format=pdf |
| Ending Page | 145 |
| Page Count | 25 |
| Starting Page | 121 |
| DOI | 10.1201/9781003049937-7 |
| Language | English |
| Publisher | Informa UK Limited |
| Publisher Date | 2020-10-09 |
| Access Restriction | Open |
| Subject Keyword | Book Name: Advances in Petroleum Technology Petroleum Engineering Oil Recovery Reservoir Rock Resin Asphaltene |
| Content Type | Text |
| Resource Type | Chapter |
