Lion Confirms Major Gas Potential at Seram (Non-Bula) PSC in Indonesia

Lion Energy Ltd. reported Thursday that the Lofin-2 well appraising the 2012 Lofin-1 discovery in Seram (Non-Bula) Production Sharing Contract (PSC) in eastern Indonesia has met key pre-drill objectives. It has significantly extended the proven gas column and provides valuable geological and engineering data including fluid samples, core data and wireline log data. Wireline pressure tests and samples, supported by the ongoing open hole test results, indicates a potential gas column of at least 3,269 feet (1,106 meters). This gas column could be up to 4,265 feet (1,300 meters) based on evaluation of gas readings and interpretation of pressure data.

Testing of an open hole section of Lofin-2 is ongoing with the well flowing gas at up to 17.8 million cubic feet per day (MMcf/d) through a 52/64 inch choke at 2,250 pounds per square inch (psi) flowing pressure. The well is also flowing some water interpreted to be from the lower part of well below the substantial gas column. The well is currently undergoing a multi-rate test to provide valuable reservoir engineering data. The forward plan is currently under discussion within the joint venture.

Commenting on the results Lion’s CEO Kim Morrison noted “The test results confirm the significant gas potential in the Lofin feature. Valuable data has been obtained and we look forward to working with the operator in the evaluation and integration of well results on this material discovery for Lion.”

Lofin-2 Appraisal Well

The Lofin-2 appraisal well, in which Lion has a 2.5 percent interest, was spud Oct. 31, 2014. The well is being drilled to appraise the 2012 Lofin-1 discovery which flowed gas and some oil/condensate from the Manusela Formation. The well is operated by CITIC Seram Energy Ltd. (51 percent) with other co-venturers being KUFPEC (Indonesia) Ltd. (30 percent) and Gulf Petroleum Investment Company (16.5 percent).

Lofin-2 had a planned total depth of 17,799 feet (5,425 meters) measured depth (MD) or 17,457 feet (5,321 meters) total vertical depth referenced to sea level (ssTVD) with the primary objective Manusela Formation projected at 14,724 feet (4,488 meters) MD (14,383 feet or 4,384 meters ssTVD). The primary objective was intersected at 15,141 feet (4,615 meters) MD (14,790 feet or 4,508 meters ssTVD), some 410 feet (125 meters) deeper than prognosed. Wireline logging of the open-hole section above 17,949 feet (5,471 meters) MD (17,546 feet or 5,348 meters ssTVD), including pressure measurements, provide strong evidence that the hydrocarbon column continues deeper and therefore the well was drilled to a revised total depth of 19,229 feet (5,861 meters) MD (18,655 feet or 5,686 meters ssTVD). Encouraging gas shows were encountered to approximately 18,356 feet (5,595 meters) MD (17,923 feet or 5,463 meters TVD) and some oil shows continued to be recorded while drilling through to the revised total depth within the Manusela limestone.

On pulling out of hole the drill pipe became stuck and on attempting to pull free the drill pipe parted with the top of the stuck drill string at 16,486 feet (5,025 meters) MD (16,234 feet or 4,948 meters ssTVD). Numerous attempts to free the stuck pipe were unsuccessful and the joint venture elected to conduct a flow test over the open hole section of the Manusela.

The well test commenced flowing May 21, and is being conducted as a multi-rate test to maximize reservoir information. On a 52/64 inch choke the well flowed at approximately 17.8 MMcf/d with approximately 2,634 barrels per day (bpd) water and completion fluid and approximately 54 bpd of 34.9 degree API condensate/oil with a flowing wellhead pressure of 2,250psi. On a 16/64 inch choke the well was flowing gas at approximately 4.95 MMcf/d with approximately 12 barrels condensate/oil and approximately 280 bpd water with a flowing wellhead pressure of 5,000psi. The results suggest well flow is occurring around the stuck drill pipe.


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