Published: 06/17/2010
Published: 06/17/2010
South America’s Loma La Lata (LLL) field is located approximately 60 mi northwest of Neuquén, Argentina, in the southwest region of the country. With more than 300 active wells, it is the main gas producer in Argentina, accounting for 26% of the total national gas production. Hydrocarbons are mainly gas and condensate and sit in the flank of an anticline in the fine- to coarse-grained Aeolian sands of the Sierras Blancas formation. The reservoir has an average depth of 9,500 ft, an initial reservoir pressure of 4,500 psi, and a bottomhole temperature of 240 degF.
Despite continued drilling and fracturing activity, gas production has declined in LLL field. This situation, combined with increasing demand, prompted YPF, S.A., to seek novel well stimulation methods.
During a stimulation campaign in LLL field, the company chose to implement HiWAY channel fracturing. This fracturing technique creates stable flow channels to maximize formation deliverability, removing the link between fracture flow and proppant conductivity. These flow channels are infinitely conductive and extend to the tip of the fracture, allowing for better fracture half-length and more fluid and polymer recovery.
For this field study, seven wells were stimulated with HiWAY channel fracturing, and eight offset wells used a conventional hydraulic fracturing technique.
The average initial production rate for the conventionally stimulated wells was 5.4 MMcf/d, while those that used HiWAY channel fracturing saw an initial production rate of 8.2 MMcf/d. This difference represents a 53% improvement in gas production over the conventional technique. Recoverable reserves are expected to increase by 15% over 10 years (at an average of 1 Bcf per well).
Challenge: Increase gas recovery in a field with declining production.
Solution: Use HiWAY flow-channel hydraulic fracturing technique to create infinitely conductive channels that enable more fluid and polymer recovery, leading to longer effective fracture half-length.
Results: Increased initial gas production by 53% compared to conventionally treated wells. Increased average estimated ultimate recovery (EUR) by 1 Bcf per well.
