Operational conditions in certain fields can cause various difficulties during logging operations. When such situations occur, we usually opt for logging-while-drilling (LWD) tools. In this paper, we present field applications and advantages of a new generation of tools called shuttle-deployed memory (SDM) tools. Because they can operate under critical borehole conditions and highly deviated wells, SDM tools offer a viable alternative to LWD. We successfully applied this technology to acquire well-log data in two fields of clastic and carbonate reservoirs in the Barinas-Apure Basin, Southwest Venezuela. In this area, conditioning the hole is a required procedure before running logging tools; therefore, the logging system's capacity to get information while conditioning the borehole favored its application when logging under harsh conditions. We show three cases considering wells with angle of deviation up to 40º, dog leg severity up to 4º/100 ft, and several washout and unsteady zones. A comparison with resistivity measurements obtained using an LWD tool is also included in one of the cases, illustrating remarkable improvements in log quality. We also used the acquired information as an input for petrophysical assessment. The results satisfactorily compared against neighbor wells with data obtained from conventional wireline logging tools and rock-core measurements. Likewise, a detailed analysis of time and cost describes the impact of the application of this type of technology on operations in Guafita and La Victoria Fields in Venezuela. We conclusively found that the application of SDM tools for formation evaluation data acquisition reduces logging time by 62% and logging costs up to 44% in these fields. In addition, we obtained reliable well-log information with significant improvements in log quality. More important, the application of SDM tools allowed us to bypass the limitations in terms of variety and quantity for logs that were commonly acquired with LWD tools.
A meandering system where sandbodies produced are complex, so that fluvial deltaic reservoir consist of channel belt sandbodies with highly variable permeability patterns pose a significant challenge for further development of a mature oil field in the Southwest Venezuela. To obtain an optimal strategy a multi-disciplinary reservoir characterization study was carried out. This study combined all available data (geophysics, geology, petrophysics, and engineering) into a 3D stochastic geo-model to build a reservoir simulation model, many sensitivities with grid size and reservoir description in fluvially dominated deltaic facies were undertaken. These sensitivities included various assumptions on sand content of main producing horizons, sandbody dimensions, permeability distribution, and continuity of flood plain acting as vertical barriers in some reservoir areas. All these sensitivities were tested during history matching as alternatives to reach a history match. Drilling locations and some exploitation strategies were made in order to improve the oil recovery factor through closing some wells for several periods (3 months - 6 months) and then opening those wells, this technique helped to decrease the water production rate and increased slightly the oil production rate. The associated economic evaluations were based on simulated forecasts while connected volume calculation was made for the chosen realization.
Unexpected high water cut, sand production and low productivity have negatively affected multiple wells producing from reservoirs in the Apure Area fields of southwest Venezuela. As a result, multiple well interventions have been conducted which increase costs and delay oil production. Several of these wells are inactive today but could be potential candidates for reactivation by reperforating prospective intervals. In several cases, the selection of the perforated interval for these reservoirs is considered inefficient because the effects of multiple dynamic and static petrophysical properties are not considered in the current method, such as vertical permeability, anisotropy or pore throat size, among others. We propose a systematic analysis to optimize the interval to be perforated for inactive and new wells that will minimize such related production problems.The proposed analysis involves the incorporation of multiple variables (type of perforation, interval to perforate, distribution of reservoir fluids, fluid of completion, etc.) to consider the effects of the different petrophysical properties on well productivity. The latter are obtained by integration of rock-core data and conventional and advanced well logs acquired in open and cased hole. In addition, we conducted a sensitivity study to analyze other parameters, such as perforating method and production behavior. A technical analysis was performed to select the optimum design based on different conditions leading to a complete study. The results show that the optimum interval selection and type of perforation to be implemented should not involve only a simple net pay consideration but also multiple factors such as reservoir properties, reservoir fluids distribution and perforating method that play a key role in well production behavior. Finally, we present field applications that confirm the success of this method that enables the reliable selection of an optimized perforated interval.
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