A practical method to adapt fractures both micro and macro as flow enhancing properties in a single porosity model is introduced to simulate Ujung Pangkah fractured carbonate reservoir. This approach is taken because dual porosity modeling attempt fails to explain the behavior of many wells which experience early water breakthrough and/or excessive water production in Ujung Pangkah field. The enhancement factor term is used to define the degree of permeability enhancement by diffuse or micro fractures. At well location, the enhancement factor can be determined by the ratio of production test to the production of matrix-only model. The enhancement factor 3D distribution is derived from well data and seismic minimum curvature attributes as trend. Fracture corridors correspond to macro fractures in the order of meters extending vertically and/or laterally. As normally scattered spatially, fracture corridors cannot be modeled in a discrete fracture network model which is the integral part of dual porosity model. Some wells show behavior anomalies, such as rapid, early water breakthrough with excessive water production in unlikely location. It is observed that the location of these anomalies coincide with the fracture lineaments derived from the seismic incoherency attribute. As the fractures are well characterized, diffuse fractures as permeability enhancement and fracture corridors as high permeability streaks, the further improvement of history match is then easily achieved by calibrating two other key parameters; relative permeability curves and aquifer strength. The relative permeability is calibrated to the shape of fracture relative permeability. Oil rate match is greatly improved. Water rate match is achieved by placing adequate aquifer strength. Reservoir dynamic of Ujung Pangkah carbonate fractured reservoir can be simulated as a single porosity model with permeability enhancement adapted from two types of fracture distribution. Diffuse fractures enhance the overall permeability and fracture corridors dominantly influence flow dynamic in certain local area. Compared to dual porosity model, adapting fractures as permeability enhancement in single porosity model is more practical, more efficient in simulation run time – computational cost.
Pangkah field located at offshore East Java Indonesia is an oil and gas producer within fractured carbonate reservoir lithology. Fractured corridors introduce challenges during drilling and production phase. To optimize production, several wells had been completed with novel Inflow Control Device (ICD) design. This paper highlights the potentials of such customized ICD's innovation with integral sliding sleeve. This novel ICD design preserves intended ICD position, and in addition could be shifted in the downhole later either to be in open or closed position if required. Either coil tubing or electric-line could be deployed to shift the downhole 3-positions of this integral ICD with sliding sleeve. The integral design allows a fully open position for well stimulation or circulation in formation damage treatment. Meanwhile another position enables ICD configuration for inflow control. The last position which is fully-shut or closed can be activated during completions string Run in Hole (RIH) to allow floating toward Total Depth (TD), minimizing torque and drag, and maintaining wash-down capability without wash pipe. The whole closed or floating system while RIH makes it possible to set assemblies of open hole hydraulic set packers or any pressure activated devices. During late-life, selective compartment could be shut-off against excessive water production decisively whenever required. Good sealing of the open hole packers against borehole is essential for the effectiveness of open hole compartmentalization and ICD production. The open hole hydraulic packers must be placed and set properly within its expanding range. Combination of petrophysical analysis, caliper log, image log, seismic coherency, and drilling loss data are used to define the compartments and packer placement. This novel ICD's innovation with water shut-off capability in addition to the main ICD's inflow control is designed comprehensively with 3D single wellbore dynamic modeling. ICD's single well dynamic modeling were executed along three phases i.e. pre-drilled, real-time and post-job. Each phase respond to operation readiness and reservoir management. Intensive engagement with asset team and realistic modeling design range lead to positive production results.
Mutiara-Pamaguan Field are gas - oil field, located onshore in Sanga-Sanga PSC, Kutai Basin, East Kalimantan, Indonesia, consist of numerous complex- stacked-sand of deltaic environment. The challenge to fully develop the field is lack of knowledge on reservoir distribution and geometry. A semi-statistical (grid base) drilling has been applied as development strategy to increase the near term production rate and maximize recovery from these fields. The paper will focus on the "grid base" drilling development concept and actual results. A justification to drill the wells is used to be focused on the incremental reserves coming from the remaining recoverable reserves of the known-reservoirs that can be predicted by combining the static and dynamic modelling. Unfortunately, hydrocarbon in place and recoverable reserves from the new-pools zones can only be determined after drilling. It is a challenge to predict new-pools zones in fluvio-deltaic reservoir due to reservoir uncertainty. However, the drilling results statistic improves the understanding of relationship between the distances from the new well to the existing wells with the hydrocarbon reserves from the unknown-reservoirs. Based on the complete understanding of known-reservoir and statistical knowledge of unknown-reservoir, a grid base drilling concept was then implemented to further develop the crestal area and to add a take-off point on spares in Mutiara - Pamaguan Field. The actual results from the last three years have successfully sustained field production. The grid base wells have delivered more than 52 bcf and 2 mmbo of incremental reserves, and turned around Mutiara- Pamaguan production rate. The production performance has increased from 100 mmscfd to 125 mmscfd whereas oil production has doubled from 4000 bopd to 8000 bopd. Currently grid base wells contribute 75% of that production. In term of development cost ($/boe), a successful of grid bas drilling strategy in Mutiara and Pamaguan Fields is one most efficient field development in Sanga-Sanga PSC.
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