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Collaborating Authors
Results
Validation of Fracture Lineaments with Dynamic Well Data, Improves History Matching of a Dual Porosity-Permeability Model
Al-Mubarak, Saeed Mohammed (Saudi Aramco) | Alali, Zaki (Saudi Aramco) | Pham, Tony Reuben (Saudi Aramco) | Lemaux, Thierry (Beicip-Franlab) | Colomar, Francois-Michel (Beicip-Franlab)
Abstract Simulating fractured carbonate oil reservoirs using the conventional single-porosity/single-permeability (SPSP) model does not normally capture the whole fluid flow mechanism in the system. A dual-porosity/dual-permeability model (DPDP) conditioned by field dynamic data can lead to better fluid saturation matches. This paper presents a new approach to history matching of naturally fractured reservoirs using a DPDP model that incorporates integrating production field performance data into the geological fracture model. A case example from a carbonate reservoir model will be used to illustrate this approach. The construction of the fracture model was done by emplying structural lineaments from 3D seismic data, and then enhanced by integrating engineering data into the model. The engineering data included mud losses during drilling, flowmeter surveys, transient well test analysis and water production data. The upscaled 3D fracture model was then used for history matching. With only minor modifications to the fracture model, a simulation model yielded a reliable match for water production. Furthermore, eighty percent of mud loss occurrences were in agreement with the 3D seismic lineaments mapping. Introduction The area under study is part of a carbonate reservoir that has been on stream for the last 30 years. The area of interest has been produced at a limited rate under fluid expansion augmented by a weak aquifer drive before a peripheral waterflooding project was put in place. Characterization work was made to obtain an improved model of the three main heterogeneities: matrix, stratiform Super-K intervals and fractures. The natural fractures were modeled using a few image logs run on vertical wells and from curvature analysis made on the top structure seismic map. Consentino et al. described the modeling and simulation work of a sector model located in the northern part of the studied reservoir. The authors showed how dual media simulation model was used to match the localized water breakthrough experienced in few up-dip wells. Since then, numerous horizontal wells were drilled. Additional data, both static and dynamic were gathered from these wells and were used to improve the fracture model.
- Asia > Middle East > Saudi Arabia (1.00)
- Asia > Middle East > Yemen (0.93)
- Africa > Sudan (0.93)
- (3 more...)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.66)
- Geology > Structural Geology > Fault (0.50)
- Geology > Rock Type > Sedimentary Rock (0.46)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Lower Fadhili Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Khuff D Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Khuff C Formation (0.99)
- (4 more...)
Reservoir Characterization: Integrating Advanced Production Logging and Near Wellbore Modeling in a Maximum Reservoir Contact (MRC) Well
Al-Mubarak, Saeed Mohammed (Saudi Aramco) | Pham, Tony Reuben (Saudi Aramco) | Al-Afaleg, Nabeel Ibrahim (Saudi Aramco) | Soleimani, Arash (Schlumberger Oilfield Services) | Seybek, Murat (Schlumberger Oilfield Services)
Abstract This paper presents a methodology for more accurate reservoir characterization with a field example of Maximum Reservoir Contact (MRC) well evaluation using dynamic production logging and near wellbore simulation modeling. Ultimately, once the results of these analyses are input into geological models and field simulators, more accurate answers would be obtained. The study was initiated to honor advance production logging results in inverse manner and to explain crossflow behavior. MRC well consisted of two lateral and motherbore and production logging results provided contributions of each lateral (3 rates) and crossflow during shut-in (total of 4 rates during survey) and during small choke. These measurements and results suggested that the choke size should be optimized for better production and drainage strategy. Comprehensive data integration was performed for more accurate modeling, including all production and injection histories of offset wells and drilling history. Fine unstructured grid refinement was utilized for near wellbore modeling. The multilateral well has been numerically modeled including friction to match production logging results and to obtain horizontal and vertical permeabilities between layers. Crossflow was also reconstructed in a quantitative manner. To the best of our knowledge, this is the first study with actual data honoring flow contributions and capturing such observations. Sensitivities were also carried out for injection and production history on crossflow behavior. Introduction It has been known that number of multilateral wells has been increasing in recent years. MRC wells are defined having reservoir contact in excess of 5 kms, through a single or multilateral configuration. MRC wells are designed mainly to maximize reservoir contact in formations and to achieve low drawdown and well productivities much higher than those of limited contact horizontal wells. Because MRC wells target much higher productivities, more accurate evaluation and reservoir characterization can be beneficiary for well performances. The evaluation of a multilateral completion and well testing can be quite challenging due to complex geometries and heterogeneities. Although MRC well developments and performances are studied, comprehensive and integrated case studies for reservoir characterization honoring production logging results are not reported in quantitative terms. Multilateral well could be equipped with controlling device to shut or open different branches. To model these advance wells, near wellbore modeling simulator can be used together with main reservoir simulator. Near wellbore model (NWM) is a fully implicit, strongly coupled well model, in which the main variables for the well are solved simultaneously with those of the reservoir grid block. Due to high flow rates and smaller completion sizes of multilateral wells, the effects of friction are generally required to be included. The wellbore friction model is readily adopted to handle multilateral wells by using NWM including segmented well representation. Production logging can be challenging in this type of completions considering intervention. In this work, advanced production logging results were obtained. As part of this work, we used an integrated comprehensive study which includes geological and petrophysical logs along with full field simulation model. The segmented conceptual simulation model was set up with three horizontal injection and two producing offset wells with full history to simulate flow contributions of each lateral and crossflow during shut-in.
- North America > United States (0.47)
- Asia > Middle East (0.30)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)