Importance Of Relative Permeability Samples †MyAssignmenthelp.com

Question: Discuss about the Importance Of Relative Permeability. Answer: Importance of relative permeability In hydrocarbon reservoirs, the flow of fluids involves multi-fluids, each of which has its own permeability. The permeability of a particular fluid is minimized by the presence of the other liquids and or gases in the voids. The flow of the multi-phased system is best described using relative permeability; relative permeability described as the ratio of effective permeability of a fluid to the absolute permeability of a rock. Relative permeability is depended on by water breakthrough. In heavy oil production, water breakthrough is a huge challenge which causes increased water cut during the production process. However, if water breakthrough is delayed, it increases the volume of pure oils produced and also reduces the operational and maintenance costs (Ediriweera Halvorsen, 2015). Therefore, manipulating relative permeability; through oil recovery methods; will delay water break through. Measurement of relativity permeability Relative permeability can be determined using laboratory techniques; steady and unsteady state techniques; and also, empirical techniques and also calculations from field data (Honarpour Mahmood, 1988). The steady state system utilizes Darcy's law and gives the most dependable relative permeability data ("5. Measurement of Relative Permeability | Global CCS Institute", 2018). In this strategy, a few fluids are injected at the same time at the same rates or pressure for stretched out spans to achieve equilibrium. Parameters such as flow rates, saturation, pressure are estimated and utilized as a part of Darcy's law to acquire the effective permeability for every stage and in thus relative permeability. Changes in saturation are controlled to be unidirectional (i.e., imbibition or drainage) so that hysteresis can be prevented. Unsteady-State Techniques maybe the fastest strategies for getting relative permeability in the laboratory. In these procedures, saturation equilibrium isn't accomplished; hence, a batch of relative-permeability versus saturation curves can be acquired within a couple of hours. Typically, it includes displacing on site fluids by constant-rate or pressure, then a driving fluid is injected while observing the effluent volumes consistently. Analysis of the production data is done; a set of relative-permeability curves is obtained using various mathematical methods. Experimental Technique models are now and then used to estimate relative permeability due to the huddles involved in measurement. Limited laboratory data may be extrapolated using these models. The porous medium hs been idealized as a bundle of capillaries in several proposed predictive models. The flow via a single capillary is portrayed numerically, thereafter, the volume through the entire set of capillaries is obtained using the idea of capillary pressure. Mathematical methods have likewise been utilized to portray irregularity of pore-size distribution in a porous media. Relative permeability might be established from the production history of a reservoir and its gas and liquid properties. In this method, relative-permeability computations require complete production history data and average values affected by saturation gradients and pressure will be given, in addition, contrasts in phases of depletion, and saturation variations in stratified reservoirs will also be given. A different potential technique for determining on site effective permeability is the pressure-transient testing which is used in besides accurate downhole flow-measurement instruments. How numerical methods is used to characterize the relative permeability for the core Relative permeability can be gotten from laboratory data obtained from core flooding experiments. This data may be analyzed using numerical or analytical methods (Hou et al., 2012). The numerical models may use an Implicit Pressure and Explicit Saturation (IMPES) technique which has been produced to numerically simulate two phase immiscible, incompressible, linear, unsteady state displacement tests carried out on core samples. The IMPES model uses either linear interpolation or parameterization for the relative permeability and capillary pressure input data (Li et al., 2014). The simulation is carried out on a block centered grid, i.e. pressures and saturations calculated at the center of the block, with all blocks having the same length. Single point upstream weighting of relative permeability is utilized (Heaviside, Black J.F. Berry, 1983). Even though the idea of relative permeability is hypothetically independent of experimental parameters, laboratory data has previously suggested a dependence on variables, for example, flow rate, and center length. When a drainage case is considered, drainage displacement on the core scale is controlled by the balance between viscous and capillary forces. Capillary pressure can manifest itself in two ways, firstly by causing sample scale artefacts (end effects) and secondly by influencing the nature of the displacement on the pore scale (dispersion of the flood front). Provided suitable capillary pressure data is available, the numerical simulation method can be used in a history matching mode to generate relative permeability curves from low rate displacement tests. However, the general form of the relative permeability curves has to be assumed. However, for imbibition systems, the usefulness of simulation is limited. Empirical observations are not consistent with the predictions from theory. Therefore, solutions are regarded as approximate and it is recommended that laboratory measurements are conducted under conditions as close as possible to the reservoir situation References Hou, J., Wang, D., Luo, F., Zhang, Y. (2012). A Review on the Numerical Inversion Methods of Relative Permeability Curves.Procedia Engineering,29, 375-380. https://dx.doi.org/10.1016/j.proeng.2011.12.726 Honarpour, M., Mahmood, S. (2015). Relative-Permeability Measurements: An Overview.Journal Of Petroleum Technology,40(08), 963-966. https://dx.doi.org/10.2118/18565-pa Ediriweera, M., Halvorsen, B. (2015). Study of the Effect of Relative Permeability and Residual oil Saturation on Oil Recovery.Proceedings Name. https://dx.doi.org/10.3384/ecp15119339 Heaviside, J., Black, C., Berry, J. (1983). Fundamentals of Relative Permeability: Experimental and Theoretical Considerations.Society Of Petroleum Engineers Of AIME. Measurement of Relative Permeability | Global CCS Institute. (2018).Hub.globalccsinstitute.com. Retrieved 5 March 2018, from https://hub.globalccsinstitute.com/publications/relative-permeability-analysis-describe-multi-phase-flow-co2-storage-reservoirs/5-measurement-relative-permeability Li, F., Yang, S., Chen, H., Zhang, X., Yin, D., He, L., Wang, Z. (2014). An improved method to study CO2oil relative permeability under miscible conditions.Journal Of Petroleum Exploration And Production Technology,5(1), 45-53. https://dx.doi.org/10.1007/s13202-014-0122-1