Resin molecules play a crucial role in the stability of colloidal asphaltene particles in petroleum reservoirs. De-stabilization of the asphaltene/resin interaction due to changes in thermodynamic parameters can cause asphaltene precipitation, thus leading to petroleum field problems such as decreased in situ permeability, as well as severe plugging problems in production facilities. One remedial technology used in the oil industry involves developing synthetic resins with enhanced chemical potential to increase the stability of asphaltene in the oil phase. However, accurately predicting what synthetic resin structures are compatible with asphaltenes in this context can be difficult and ineffective. Here, we introduce a method that enhances the stability of colloidal asphaltene in petroleum fluid by increasing the concentrations of natural-state oil resins and increases reservoir oil recovery by increasing the oil’s aromatic power solvency. The stability of colloidal asphaltene and improvements in oil reservoir recovery were investigated by using an oil prefractionation process and a solvent deasphalting technology based on the residuum oil supercritical extraction process to develop three types of deasphalted oils derived from Kuwait Marrat oil. Using these methods, we found that resin concentration by volume in Marrat oil increased with the removal of more oil fractions. Asphaltene stability in the oil phase was strongly influenced by resin concentration. The deasphalted oils’ aromatic power solvency increased the oil reservoir permeability by twofold. No formation damage was observed for all DAO products in core flooding tests.
Reservoir souring while water flooding North Kuwait reservoirs has been predicted by modeling studies in the past. One of Sabiriyah Mauddud wells showed up H 2 S as first indication of reservoir souring, which was an alarm bell for production facilities designed for only sweet crude. Surface/ Bottomhole fluid samples were required to confirm whether it is localized or reservoir-wide. In order to track reservoir souring and monitor on continuous basis, a process for tracking of reservoir souring annually was developed and initiated for the first time in 2006. Subsequently, this has been made part & parcel of fluid study requirements each year.As sea water is being injected into traditionally sweet reservoir like Sabiriyah Mauddud, some degree of reservoir souring is expected due to Sulfate reducing bacterial (SRB) activity, as was projected happen sometime in 2005 in wells, needing monitoring/ mitigation actions. Expected H 2 S levels being very low (50-200 ppm), risk of loosing and not capturing these concentrations using conventional samplers/ bottles due to absorption/ reaction with the metallurgy of the samplers was felt, thus posing a challenge for obtaining a representative bottomhole sample for the analysis of H 2 S.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractAn important parameter used to determine the feasibility of miscible displacement is the minimum miscibility pressure (MMP). In oil recovery, gas injection can be a very efficient method for improving the productivity of the wells, particularly in the case when miscibility develops during the displacement process. Extensive use of carbon dioxide mixed with light hydrocarbon such as ethane and propane for this purpose has the secondary benefits of being a temporary means of sequestering these green house gases. MMP at which a gas should be injected into the reservoir in order to obtain a multicontact miscible displacement has consequently attained a very important status in enhanced oil recovery studies. MMP can be estimated from phase equilibria data using pseudo-ternary conceptualization of Benham et al. The full advantages of the use of carbon dioxide as a selective solvent can only be realized through knowledge and understanding of its phase behavior and equilibria with different hydrocarbons. In this paper binary and ternary phase equilibrium studies involving a heavy hydrocarbon such as n-eicosane, light hydrocarbon such as ethane and propane with carbon dioxide was performed. Peng-Robinson equation of state with binary interaction parameters were applied to represent vapor-liquid equilibria and to optimize the representation with minimum use of ternary parameters. The experimental data obtained was used to predict the MMP using pseudo-ternary conceptualization of Benham et al. and examine its variation with nature and amount of light hydrocarbons in the injected gas.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractReservoir oil viscosity is one of the important reservoir fluid properties used for many petroleum engineering calculations such as evaluating hydrocarbon reserves, planning enhanced oil recovery methods, calculating fluid flow rate through reservoir rocks, etc. Therefore, achieving an accurate reservoir oil viscosity value is very crucial for petroleum engineers. Viscosity of reservoir oil can be obtained by a laboratory measurements and empirical correlations. Many of the common correlations in use were developed using data collected from different regions of the world.The literature contains many different viscosity models, the viscosity models found in the literature range from highly theoretical to simple empirical correlations. Two typical viscosity correlations are applicable to both liquid and gas phases; the Corresponding States Method (CSM), semi-empirical, and the empirical Lohrenz-Bray-Clark (LBC) method. In this paper, the applicability of both models were tested to predict the experimental viscosity measurements for pure n-eicosane, ethane/neicosane, propane/n-eicosane binary systems. After normal quality checks, nonlinear multiple regression with linear partial correlation coefficient techniques were applied to develop friction theory and binary interaction parameter were used to modify the representation of friction theory model. The comparisons among LBC, Corresponding State Principle (CSP), general model of friction theory and modified friction theory (using binary interaction parameter) were performed. Based on the error statistical analysis results, the developed friction theory model has shown to provide accurate estimates of viscosity in all pressure regimes.
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