The Intelligent field is the oil industry's new trend that enables continuous monitoring and optimization of individual wells and overall reservoir performance. This is achieved by integrating fields' real time data in the reservoir management business processes. The results from this integration are anticipated to increase production rates, identify opportunities for higher hydrocarbon recoveries and reduce operating costs and future capital expenditures.Saudi Aramco has embarked on implementing the Intelligent Field (I-Field) initiative through new pilot projects in Qatif and Haradh increment III fields. The objectives of the pilot projects are to provide real-time diagnostic capabilities, highlight and address implementation challenges, and develop a comprehensive architecture for I-Field implementation in Saudi Aramco fields.This paper discusses the implementation approach of the intelligent field initiatives in Saudi Aramco. It will shed light on the challenges encountered and will present the process and methodology of developing the roadmap of the "surveillance layer," the first building block of Saudi Aramco's I-Field architecture.
Horizontal wells are becoming popular for primary and enhanced oil recovery operations because of unique advantages of horizontal wells in comparison to those for vertical wells. However, horizontal well testing is considerably more complex than vertical well testing.This study uses numerical integration to evaluate an analytical solution for the transient pressure response of a horizontal well located in a closed, box-shaped, anisotropic reservoir. Results from this study show that numerical integration can be used to evaluate the solution with a comparative degree of accuracy, while avoiding the convergence problems associated with the analytical integration. Both drawdown and buildup responses have been studied.New time criteria, based on the semi-log pressure derivative response, are proposed for well test analysis and design purposes. These time criteria generally suggest shorter flow period durations than those corresponding to the time criteria based on the pressure response. The effects of well radius, we! location and reservoir size on the drawdown pressure derivative response are discussed.Producing time effects on the buildup pressure derivative responses are also investigated. Results show that for a horizontal well in a closed reservoir, the late linear flow period will not occur on the buildup response for any case, even when the late linear flow period is present on the drawdown response. Design equations are presented for the time at which buildup response deviates away from the corresponding drawdown response to establish the applicability and limitations of using drawdown type curves to analyze buildup data obtained from a horizontal well.References and illustrations at end of paper
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractConceptual reservoir models are the basis for any reservoir engineering study and constitute the backbone of pressure transient analysis. The selection of the correct reservoir model is of paramount importance and cannot be overstated since the validity of the well test itself is totally dependent on the applicability of selected reservoir model. Once the proper model has been selected, various computer-aided interpretation techniques and nonlinear estimation methods can be employed to obtain quantitative descriptions of important reservoir parameters and near wellbore conditions.
Pressure derivatives have been shown to be more sensitive to disturbances in the reservoir than pressure signals; resulting in more detail on derivative graphs than is apparent on pressure graphs. The semilog pressure derivative is widely used in well test analysis. One reason for its popularity is that, for radial systems, the response appears as a horizontal line during the infinite- acting radial flow period, resulting in easier identification. However, when the semilog pressure derivative is applied to flow geometries other than radial, the responses are not horizontal; making identification of flow regimes more difficult. Thus, a generalized pressure derivative is necessary to simplify the identification of flow regimes in any flow geometry. In this study, a generalized pressure derivative is defined and used to identify the various flow regimes for composite systems in radial, elliptical, linear and spherical geometries. This generalized pressure derivative is of the power law type, and is characterized by a different exponent for each of the flow geometries. Using well test data from analytical solutions for radial, elliptical, linear and spherical composite reservoirs, a graph of the generalized pressure derivative versus time, for any of the flow geometries appears as a horizontal line during the primary flow regime characteristic of that geometry. Design and analysis equations, based on the generalized pressure derivative, are presented for well testing of composite reservoirs in various flow geometries. Reservoir parameters estimated using these equations will add to the degree of confidence in the estimated parameters based on pressure analysis. The generalized pressure derivative is also used to investigate differences and similarities among the four flow systems. Results from this study confirm that for radial and elliptical systems, the long term pressure derivative behaviour is influenced only by the mobility ratio between the inner and outer regions of the composite system. For linear and spherical systems, however, long term derivative behaviour is governed by both the mobility ratio and the storativity ratio. This finding has a significant impact on the development of type curves for either manual or automated type curve matching for the various flow geometries. Introduction Pressure derivatives have been shown to be more sensitive to disturbances in the reservoir than pressure signals. This results in greater detail on a derivative graph than is apparent on a pressure graph. Pressure derivatives were first introduced by Tiab and Kumar(1), who presented the derivative of pressure with respect to time. Later, Bourdet et al.(2) introduced the semi-log pressure derivative, defined as the derivative of the well pressure with respect to the natural logarithm of time. The semilog pressure derivative response appears as a horizontal line during the infinite- acting radial flow period, resulting in an easy identification of the radial flow regime. As a result, the semilog pressure derivative is widely used in well test analysis of not only homogeneous, but also composite reservoirs. To analyse well tests for thermal recovery projects, reservoirs have been idealized as composite reservoirs.
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