Touchstone: Ortoire block well testing supports initial gross production rate of 40-50 MMcfd
Touchstone Exploration Inc. finalized production tests from Cascadura-1ST1 exploration well, Ortoire exploration block, onshore Trinidad and Tobago. Analysis of the data supports initial gross production rate of 40-50 MMcfd with estimated 1,100-1,400 b/d condensate (6,200-7,760 boe/d net production). The rate estimate is based on AOF modeling following analysis of flow and buildup pressure data and reflect well production from the upper interval (test 2), with the lower interval (test 1) initially isolated, as per the current well configuration. Touchstone will design the production and surface facilities to meet these production capabilities.
The well encountered substantial volumes of liquids rich natural gas in two sand packages in the Herrera Gr7b formation with a total combined thickness in excess of 777 ft. Evaluation of these sands was undertaken in two stages, with the first test evaluating 162 ft of pay in the lowermost section of the wellbore and the second test evaluating 345 ft of pay in the uppermost section.
Lower stage 1 (6,056-6,218 ft) 24-hr extended flow test produced an average 26.8 MMcfd natural gas and estimated 691 b/d condensate (5,157 boe/d, 13% liquids). The well yielded 55° API condensate at a ratio of about 26 bbls/MMcf. Produced gas was liquids rich with no hydrogen sulfide, no entrained water and no solids. Following flow testing, the well was shut in for an extended pressure buildup survey which concluded on Feb. 27. During the buildup period, bottomhole pressures returned to 4,783 psi pre-test levels. Final downhole flowing pressure at end of the 24-hr flow test was 4,221 psi, indicating a 12% sandface drawdown. Estimated sandface absolute open flow (AOF) is 92 MMcfd. No physical boundaries were observed during the pressure buildup test period, and no skin damage was visible at the sandface. Pressure data suggests that the well was continuing to clean up during the extended test.
Upper stage 2 (5,570-5,915 ft) produced an average rate of 28.1 MMcfd natural gas and estimated 783 b/d of natural gas liquids (5,472 boe/d, 14% liquids). During the final extended flow test, the well yielded 55° API condensate at a ratio of 28 bbls/MMcf. As with the lower stage, the produced gas was liquids rich with no hydrogen sulfide, no entrained water and no solids. Following flow testing, the well was shut in for an extended pressure buildup survey which concluded on May 13. During this buildup, observed bottomhole pressures returned to 4,728 psi pre-test level. Final downhole flowing pressure at the end of the 24-hr flow test was 4,550 psi, indicating a 4% final sandface drawdown. Estimated sandface AOF rate is 390 MMcfd. No physical boundaries were observed during the pressure buildup test period, and no skin damage was visible at the sandface. Pressure data suggests that the well was continuing to clean up during the extended flow test.
Results for both lower test and upper test have been reviewed by GLJ Ltd. Touchstone is operator with 80% working interest. Heritage Petroleum Co. Ltd. is partner with the remaining 20%.