Touchstone Exploration (LON: TXP) has today announced the final production test results for the Coho-1 well on the Ortoire exploration block, onshore in the Republic of Trinidad and Tobago (Touchstone 80% working interest operator, Heritage Petroleum Company Limited 20% working interest). The final test results have been reviewed by the Company’s independent reserves and resources evaluator, GLJ Petroleum Consultants Ltd., and the following information is intended to complement initial test results previously released by the Company on November 18, 2019.
James Shipka, Touchstone Exploration Chief Operating Officer, commented:
“Final testing of the Coho-1 exploration well displayed natural gas rates that greatly exceeded the Company’s expectations and is expected to materially contribute to our near-term growth. With production testing and analysis completed and verified independently, the Company has a clear indication of the potential of Coho-1 and is moving forward to bring the well on stream in the first half of 2020.”
· Flow and build-up test results suggest an Absolute Open Flow (“AOF”) rate of 46.0 million cubic feet per day (“MMCFD”) (approximately 7,671 barrels of oil equivalent per day (“boe/d”)).
· Modelling supports initial production rates of 10 to 12 MMCFD per day (1,667 to 2,000 boe/d) gross, 8.0 to 9.6 MMCFD (1,333 to 1,600 boe/d) net.
· Gas analysis indicated pure, sweet, dry gas with 98.7% methane, no hydrogen sulfide and negligible associated liquids.
· No physical subsurface boundaries were observed during the test period
· Final 24-hour extended flow test rate was confirmed at 11.6 MMCFD (1,925 boe/d) at an average sandface drawdown of only 8.8%.
As previously announced, the Coho-1 exploration well encountered material volumes of natural gas in two sand packages in the Herrera Gr7b formation. Production testing commenced on November 16, 2019, with flow tests spanning a total of 45.3 hours comprised of an initial clean-up flow period followed by an initial shut-in period and a four-step rate test, including a final extended flow test over a 24-hour period. Peak rates during flow testing were 19.8 MMCFD (3,300 boe/d) with an average rate of 11.6 MMCFD (1,925 boe/d) recorded during the final 24-hour extended flow test. A total of 17.2 million cubic feet of gas (2,867 barrels of oil equivalent) was produced during testing with 445 barrels of associated water including c. 37 barrels of load fluid. Natural gas rates observed during testing were significantly higher than the Company’s pre-test expectation of 8 MMCFD while water rates were significantly lower. Compositional analysis of the produced gas indicated 98.7% pure methane, with no hydrogen sulfide content, negligible associated measurable liquids and no sand or sediment.
Following flow testing, the well was shut in for an extended pressure build-up survey which concluded on December 6, 2019. During the build-up period, the Company observed bottom hole pressures returning to pre-test levels of approximately 3,830 psi. Flow and pressure build-up measurements were analyzed by GLJ, resulting in an estimated AOF rate of 46 MMCFD (7,671 boe/d). Analysis of the data supports an initial gross production rate of 10 to 12 MMCFD (net production rate of 8.0 to 9.6 MMCFD or 1,333 to 1,600 boe/d respectively). No physical boundaries were observed during the pressure build-up test period and no skin damage was visible at the sandface.