OPTIMIZING DEVELOPMENT COSTS BY APPLYING A MONOBORE WELL DESIGN SPE 69498
Language: Inglés Series: García, Rodolfo ; Publication details: Dallas, Texas Society of Petroleum Engineers 2001Online resources: Summary: The An Aike–Barda Las Vegas field, located in the Austral basin 80 km west of Rio Gallegos, Argentina, represents an important discovery in basin development in recent years. The field is an important Springhill formation gas reservoir at an approximate depth of 3100 m and with static pressure of 4400 psi. Gas rates are up to 1 MM m 3 /d/well. Drilling appraisal and development wells requires the optimization of every operation involved. In this context, improvements in well construction and completion methodology are important contributions. Original well design included 13 3 /8-in. surface and 9 5 /8-in. and 7-in. casings, with a permanent packer and 4 1 /2-in. tubing. The new monobore well design reduces the diameter of each drilled section, narrowing to a 4 1 /2-in. monobore installation through the pay zone. The rigless completion includes coiled tubing. Before adopting the design change, potential risk analyses were made to account for the possibility of future reentries and for simultaneous development of a second target (Magallanes formation) at 1700 m. The final well design model showed a cost savings of 30 percent, a sizeable impact on the economics of this project.| Current library | Status | Barcode | |
|---|---|---|---|
| Biblioteca virtual | Not for loan | 200003061 |
The An Aike–Barda Las Vegas field, located in the Austral basin 80 km west of Rio Gallegos, Argentina, represents an important discovery in basin development in recent years. The field is an important Springhill formation gas reservoir at an approximate depth of 3100 m and with static pressure of 4400 psi. Gas rates are up to 1 MM m 3 /d/well. Drilling appraisal and development wells requires the optimization of every operation involved. In this context, improvements in well construction and completion methodology are important contributions. Original well design included 13 3 /8-in. surface and 9 5 /8-in. and 7-in. casings, with a permanent packer and 4 1 /2-in. tubing. The new monobore well design reduces the diameter of each drilled section, narrowing to a 4 1 /2-in. monobore installation through the pay zone. The rigless completion includes coiled tubing. Before adopting the design change, potential risk analyses were made to account for the possibility of future reentries and for simultaneous development of a second target (Magallanes formation) at 1700 m. The final well design model showed a cost savings of 30 percent, a sizeable impact on the economics of this project.
