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Tight gas reservoir at well X has a permeability of 0.09 md and porosity of 0.17. The skin around the well is about 5.31. Due to the relatively small permeability value, hydraulic fracturing will be implemented to increase the gas productivity of the well. Hydraulic fracturing is applied on the hori...
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| Format: | Final Project |
| Language: | Indonesia |
| Online Access: | https://digilib.itb.ac.id/gdl/view/28095 |
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| Institution: | Institut Teknologi Bandung |
| Language: | Indonesia |
| Summary: | Tight gas reservoir at well X has a permeability of 0.09 md and porosity of 0.17. The skin around the well is about 5.31. Due to the relatively small permeability value, hydraulic fracturing will be implemented to increase the gas productivity of the well. Hydraulic fracturing is applied on the horizontal well and the resulting fractures will form transverse fractures. In order to obtain the optimum level of productivity an optimum hydraulic fracture design is required. <br />
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In this study, the authors presented results and analysis of each sensitivity; such as pump flow rate, proppant concentration, fluid type and proppant mesh size. The sensitivities were performed using FracCade 7.0 and P3D as the fracture geometry model. Each of the results will be used as input for designing the optimum fracture geometry. <br />
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Based on the sensitivities that have been conducted, the optimum flow rate is 14 bpm, the optimum proppant concentration is 6 PPA, the optimum fluid type is PrimeFrac 30 and the optimum mesh proppant size is CarboProp 20/40. The Fracture length, which is obtained from the model, is 121.40 ft. The fracture width from the optimum model is 0.68 inches and finally the FOI is 7.32 and Qoperating is 4.78 MMSCFD. There is an increase of productivity from well X at 3.66 MMSCFD after conducting optimum hydraulic fracture at well X. |
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