Most of field development plans need a countable simulation model. Simulation models are considered dependable when they match all aspects of the field's history-performance. This is achieved by matching pressure data and production phases of oil, water and gas production and injection. Many factors affect the process of history match. The most important factor is the relative permeability, which affects the partial flow of fluid phases through rock conduits. Measuring relative permeability and adjusting it to be included in simulation model is our focus in this work. Field 'X' is in our interest in this study. The field is under of water flooding implementation. After water-flooding project has been started, field 'X' suffered from high water cut (W.C) rates in large oil producers and low oil production rates. This urged to restudy the field and consequently we needed to build a full simulation model with a proper history-match. Special Core Analysis test with unsteady-state displacement experiment for relative permeability measurement has been performed for well 'X-4'. In this paper, we will show you how to process relative permeability data and adjust them to be introduced into simulation model to achieve a good history match performance.
In this research paper, a new methodology to design a progressive and win-win royalty model for upstream fiscal systems is developed. The proposed royalty model is designed as a function of different boundary conditions of the market and the productive resources. These boundary conditions include the associated exploration and production risks, commodity prices, the extraction costs, besides the expected production and depletion rate. The behavior of the proposed royalty model under different oil prices, development costs, production rates, and exploration risks is investigated using deterministic and stochastic analysis. Our results prove that the applicable royalty rate increases with both the price and production rate while it decreases with increasing the development costs and the associated exploration and production risks. In addition, the proposed royalty model provides the contractor with sufficient incentives to develop marginal or low profitability fields and the development of deep offshore or frontier fields with high development and operating costs.
Permanent monitoring of downhole equipment and production in artificial lift wells is an excellent method of diagnosing conditions and determining the appropriate approach to avoid loss of production or of the well.Belayim Petroleum Company in Egypt (Petrobel) has used permanent monitoring sensors since 1994. The systematic data are used by the reservoir and production engineering staff to tackle problems such as high failure rate, sand fill-up, scale, ESP wear, and electric failures.Petrobel currently has twenty downhole gauges, and 8 other systems are waiting associated accessories before installation. Each permanent gauge sends nine measurements per minute to the surface in real time yielding an incredible volume of information.Downhole gauges supply accurate information about the reservoir, downhole, and the pumping system. This knowledge, in turn, is used to increase the run life of the artificial lift system through optimization of the reservoir pressure and artificial lift system performance.This paper demonstrates the long-term benefits of using subsurface permanent gauges to complement artificial lift equipment and provide real-time data to optimize well and/or field production. Case studies illustrate both offshore and onshore problems. Examples are given of wells that have been converted into successful artificial lift completions through proper interpretation of the gauge measurements and use of the information to optimize production. This paper brings data interpretation to a new level of prediction, which enhances economics and minimizes risk in production operations, especially offshore.
Permanent monitoring of downhole equipment and production in artificial lift wells is an excellent method of diagnosing conditions and determining the appropriate approach to avoid loss of production or of the well.Belayim Petroleum Company in Egypt (Petrobel) has used permanent monitoring sensors since 1994. The systematic data are used by the reservoir and production engineering staff to tackle problems such as high failure rate, sand fill-up, scale, ESP wear, and electric failures.Petrobel currently has twenty downhole gauges, and 8 other systems are waiting associated accessories before installation. Each permanent gauge sends nine measurements per minute to the surface in real time yielding an incredible volume of information.Downhole gauges supply accurate information about the reservoir, downhole, and the pumping system. This knowledge, in turn, is used to increase the run life of the artificial lift system through optimization of the reservoir pressure and artificial lift system performance.This paper demonstrates the long-term benefits of using subsurface permanent gauges to complement artificial lift equipment and provide real-time data to optimize well and/or field production. Case studies illustrate both offshore and onshore problems. Examples are given of wells that have been converted into successful artificial lift completions through proper interpretation of the gauge measurements and use of the information to optimize production. This paper brings data interpretation to a new level of prediction, which enhances economics and minimizes risk in production operations, especially offshore.
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