Published: 01/01/2006
Published: 01/01/2006
In the Arcabuz field of the Burgos basin, a better fracturing treatment was needed. PEMEX decided to evaluate the performance of FiberFRAC fiber-based fracturing fluid technology by comparing it to conventional fracturing applications in two wells with comparable reservoir characteristics.
The FiberFRAC fracturing treatment was used for the first well, Arcabuz 316. It consisted of 90,718 kg [200,000 lbm] of ceramic proppant and 2,268 kg [5,000 lbm] of resin-coated ceramic proppant pumped at a rate of 35 bbl/min. After 1 week of flow, the production was 2.2 MMcf/d of gas and 30 bbl/d of water at 34.5-MPa [5,000-psi] wellhead flowing pressure.
A conventional fracturing stimulation treatment was performed on the comparable well, offset Arcabuz 307. The fracture treatment used 90,718 kg [200,000 lbm] of ceramic proppant and 22,680 kg [50,000 lbm] of resin-coated ceramic at a pumping rate of 35 bbl/min. Polymer fluid was injected at 3,595 kg/m3 [30 lbm/gal] with no fiber added. After 1 week, Arcabuz 307, interval Wilcox 4, showed production of only 300,000 cf/d of gas with 360 bbl/d of water at 5.2-MPa [750-psi] wellhead flowing pressure. Additionally, a considerable drop in pressure at the final treatment stage suggested excess height growth in zones of high water saturation.
The WellWatcher real-time reservoir and production monitoring system helped to simultaneously analyze production decline over time and study fracture geometry, enabling a direct comparison of production results between the two wells.
Based on low production and the pressure drop, the treated interval of Arcabuz 307, Wilcox 4, was plugged and abandoned, and PEMEX moved upward to evaluate other Wilcox zones.
No drop in pressure was observed during the treatment on Arcabuz 316 and production was 7 times greater. After the cleanup period, the well was placed on production. The FiberFRAC technology allowed PEMEX to fully exploit the production potential of the Wilcox 4 gas interval in the Burgos field, reduced the risk of fracture extension into nearby water-bearing zones, and ultimately enhanced ROI.
After 1 week of flow, the production from the well treated with FiberFRAC fluid was 2.2 MMcf/d of gas.
Challenge: Identify more effective fracturing options by comparing the performance of fiber-based fracturing fluid technology with conventional fracturing applications in two tight-gas wells in the Arcabuz field.
Solution: FiberFRAC technology provided substantially increased production post treatment. WellWatcher real-time production monitoring and surveillance system was used to simultaneously analyze production over time and study fracture geometry with a production history match.
Results: Production was 7 times higher in the well treated using FiberFRAC technology. The treated interval of the conventionally fractured well was plugged and abandoned.
