Abstract:The method of Dykstra-Parsons, originally developed to model water flood performance, has been adapted to screen reservoirs for their Chemical / Polymer Flood suitability.Firstly, this paper summarises Dykstra-Parsons' Theory alongside an automated method of tuning reservoir layer properties to [pre-chemical] water flood performance.(Methods of determining both layer permeability and oil-phase relative permeability end-points, from water-cut development, are presented.)Secondly, this paper describes the adapta… Show more
“…Much interest has been shown recently in the application of the Dykstra-Parsons method to chemical flooding, especially for polymer injection (Mahfoudhi and Enick 1990;Morrison 2005). The method has also been used with streamline simulation, which simplifies the computations significantly.…”
The Dykstra-Parsons method (Dykstra and Parsons 1950) is used to predict the performance of waterflooding in noncommunicating stratified reservoirs. Much interest has been shown recently in the application of the method to chemical flooding, particularly for the case of polymer injection used for mobility control. The original method assumes that the reservoir layers are horizontal; however, most oil reservoirs exhibit a dip angle, with water being injected in the updip direction. Therefore, it is important to account for the effect of inclination on the performance of the method.A modification of the Dykstra-Parsons equations is obtained to account for reservoir inclination. The developed model includes a dimensionless gravity number that accounts for the effect of the dip angle and the density difference between the displacing and displaced fluids. The derived equation that governs the relative locations of the displacement fronts in different layers is nonlinear, includes a logarithmic term, and requires an iterative numerical solution. This solution is used to estimate the fractional oil recovery, the water cut, the injected pore volume, and the injectivity ratio at the time of water breakthrough in successive layers.Solutions for stratified systems with log-normal permeability distribution were obtained and compared with horizontal systems. The effects of the gravity number, the mobility ratio, and the Dykstra-Parsons permeability-variation coefficient (V DP ) on the performance were investigated. Cases of updip and downdip injection are discussed.It was found that for a positive gravity number (updip water injection), performance is enhanced in terms of delayed water breakthrough, increased fractional oil recovery, and decreased water cut as compared with horizontal layers. This occurs for both favorable and unfavorable mobility ratios but is more evident in unfavorable mobility ratios and more-heterogeneous cases. For the case of a negative gravity number (downdip water injection or updip gas injection), the opposite behavior was observed.The results were also compared with the performance of inclined communicating reservoirs with complete crossflow. The effect of communication between layers was found to improve fractional oil recovery for favorable and unit mobility ratios and decrease recovery for unfavorable mobility ratio.
“…Much interest has been shown recently in the application of the Dykstra-Parsons method to chemical flooding, especially for polymer injection (Mahfoudhi and Enick 1990;Morrison 2005). The method has also been used with streamline simulation, which simplifies the computations significantly.…”
The Dykstra-Parsons method (Dykstra and Parsons 1950) is used to predict the performance of waterflooding in noncommunicating stratified reservoirs. Much interest has been shown recently in the application of the method to chemical flooding, particularly for the case of polymer injection used for mobility control. The original method assumes that the reservoir layers are horizontal; however, most oil reservoirs exhibit a dip angle, with water being injected in the updip direction. Therefore, it is important to account for the effect of inclination on the performance of the method.A modification of the Dykstra-Parsons equations is obtained to account for reservoir inclination. The developed model includes a dimensionless gravity number that accounts for the effect of the dip angle and the density difference between the displacing and displaced fluids. The derived equation that governs the relative locations of the displacement fronts in different layers is nonlinear, includes a logarithmic term, and requires an iterative numerical solution. This solution is used to estimate the fractional oil recovery, the water cut, the injected pore volume, and the injectivity ratio at the time of water breakthrough in successive layers.Solutions for stratified systems with log-normal permeability distribution were obtained and compared with horizontal systems. The effects of the gravity number, the mobility ratio, and the Dykstra-Parsons permeability-variation coefficient (V DP ) on the performance were investigated. Cases of updip and downdip injection are discussed.It was found that for a positive gravity number (updip water injection), performance is enhanced in terms of delayed water breakthrough, increased fractional oil recovery, and decreased water cut as compared with horizontal layers. This occurs for both favorable and unfavorable mobility ratios but is more evident in unfavorable mobility ratios and more-heterogeneous cases. For the case of a negative gravity number (downdip water injection or updip gas injection), the opposite behavior was observed.The results were also compared with the performance of inclined communicating reservoirs with complete crossflow. The effect of communication between layers was found to improve fractional oil recovery for favorable and unit mobility ratios and decrease recovery for unfavorable mobility ratio.
The Dykstra-Parsons method is used to predict the performance of waterflooding in non-communicating stratified reservoirs. Much interest was shown lately for the application of the method for chemical flooding and in particular for the case of polymer injection used for mobility control. The original method however assumes the layers to be horizontal. Most oil reservoirs exhibit a dip angle with the water being injected in the up dip direction. It is there for important to account for the effect of the inclination on the performance.
A modification of the Dykstra-Parsons equations is obtained to account for reservoir inclination. The developed model includes a dimensionless gravity number that accounts for the effect of the dip angle and density difference between the displacing and displaced fluids. The derived equation that governs the relative locations of the displacement fronts in different layers is non linear and include a logarithmic term. Iterative numerical solution is used to obtain the location of the front in the different layers at the time of water breakthrough in successive layers. This solution is used to obtain values for the fractional oil recovery, the water cut, the dimensionless time and the injectivity ratio.
Solutions for stratified systems with log normal permeability distribution were obtained and compared with the horizontal systems. The effects of the gravity number, the mobility ratio and the Dykstra-Parsons permeability variation coefficient (VDP) on the performance are investigated.
It was found that the gravity (dip angle) enhances the performance in terms of delaying water breakthrough, increasing the fractional oil recovery, and decreasing water cut as compared to horizontal layers. This occurs for both favorable and unfavorable mobility ratios but is more evident in unfavoorable mobility ratios and more heterogeneous cases.
The results were also compared with the performance of inclined communicating reservoirs with complete crossflowand the communication was found to improve fractional oil recovery for unit and favorable mobility ratios and decrease recovery for unfavorable mobility ratio.
Barrow Island's Windalia reservoir is Australia's largest onshore waterflooding operation and has been under active waterflood since 1967. The highly heterogeneous reservoir consists of fine-grained, bioturbated argillaceous sandstone that is high in glauconite clay. The high clay content results in a low average permeability (5 md) despite high porosities (25-30%) and hence fracture stimulation is required to achieve economic production rates.The Windalia reservoir and fluid properties preclude the use of traditional EOR technology, with thermal, miscible and mobility control processes all deemed unfeasible through screening studies. Consequently, the in-depth flow diversion mechanism was developed and applied, which utilizes a low molecular weight polymer to drive the growth of induced hydraulic fractures in the treated injection wells. A 3-injector pilot was executed involving polymer injection for two years, with no detrimental injectivity losses observed for polymer concentrations up to 750 ppm. Considerable fracture growth, oil production rate uplift and reduction in water cut were observed throughout the pilot pattern, in line with predictions: Fracture half-lengths increased from 6 ft to 400 ft in one injector and from 141 ft to 322 ft in another An initial oil rate uplift of 38% relative to the production baseline was observed; a more conservative estimate suggested that at least half of this was attributable to the tertiary recovery process The water-oil ratio was observed to fall from 15 to 11, similarly timed with the oil production increase.These improvements were observed consistently throughout the pilot area and were distinct from the waterflood behavior elsewhere in the field. This paper briefly summarizes the technology screening and pilot execution stages, after which the results from the pilot are presented and discussed. This technology may be of use in other low-permeability waterfloods with induced injector fractures, for which traditional EOR practices are believed to be unfeasible.
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