Reservoir fluid characterization and optimization of condensate banking treatment with dimethyl ether in the shale gas condensate reservoir
| dc.contributor.advisor | Sepehrnoori, Kamy, 1951- | |
| dc.creator | Liu, Wendi | |
| dc.date.accessioned | 2018-10-30T20:19:59Z | |
| dc.date.available | 2018-10-30T20:19:59Z | |
| dc.date.created | 2018-08 | |
| dc.date.issued | 2018-09-05 | |
| dc.date.submitted | August 2018 | |
| dc.date.updated | 2018-10-30T20:19:59Z | |
| dc.description.abstract | As the bottomhole pressure drops below dew point during gas production from hydraulic-fractured shale gas condensate reservoirs, condensate-banking forms near the wellbore and compromises the gas productivity. Dimethyl ether (DME) is used to efficiently mitigate the condensate banking. However, the cost of injecting DME in field scale is one of the challenges hindering its further application. Also, complexity of shale gas condensate reservoir requires the accurate phase behavior model for reliable long-term oil and gas production forecast. This study investigates the efficiency of DME treatment and optimizes its application based on a rich gas condensate fluid model to obtain the highest net present value (NPV) with different reservoir permeabilities. An in-house simulator, UTCOMP, with a composition-dependent relative permeability model was used for this study. The production rates with and without solvent treatment are compared to determine the benefit of DME injection. The effectiveness of DME is also evaluated for rich and lean gas condensate reservoirs and rich gas condensate reservoirs with different permeabilities. The result proves the eligibility of DME removing the blockage for different types of reservoir fluids and reservoirs with very low permeabilities. It also indicates that slug size would affect the efficiency of DME mixture ratio and reinjection. Therefore, further simulation is proposed to analyze the impact from the amount of DME on NPV at varying permeabilities for one-time injection. The practical optimum strategies in this study make it possible to inject DME for shale gas production economically. | |
| dc.description.department | Petroleum and Geosystems Engineering | |
| dc.format.mimetype | application/pdf | |
| dc.identifier | doi:10.15781/T2RR1Q61Q | |
| dc.identifier.uri | http://hdl.handle.net/2152/69257 | |
| dc.subject | Dimethyl ether | |
| dc.subject | Gas condensate reservoir | |
| dc.subject | NPV | |
| dc.title | Reservoir fluid characterization and optimization of condensate banking treatment with dimethyl ether in the shale gas condensate reservoir | |
| dc.type | Thesis | |
| dc.type.material | text | |
| thesis.degree.department | Petroleum and Geosystems Engineering | |
| thesis.degree.discipline | Petroleum Engineering | |
| thesis.degree.grantor | The University of Texas at Austin | |
| thesis.degree.level | Masters | |
| thesis.degree.name | Master of Science in Engineering |