Entek Flows Rates of 9.5 MMcfd at GA A133 Discovery

- Entek Flows Rates of 9.5 MMcfd at GA A133 Discovery

Tuesday, August 16, 2011
Entek Energy Ltd.

Entek announced the development of its GA A133 gas discovery, made in 2010, has been completed and gas is flowing at the planned 9.5 MMcfd on restriction. At current gas prices this should net Entek around US $250,000 per month. Entek has a 38% working interest in the block which is operated by Peregrine Oil & Gas II, LLC.

The GA A133 block has gross reserves of approximately 10 BCF associated with the recent discovery, with additional reserves linked to previous gas discovered on the block to be targeted at a later date.

Due to proximity to analogue production the GA A133 discovery well was not tested. This is common practice in the Gulf of Mexico where numerous existing producing analogues give a high level of confidence. The well is performing as predicted based on wireline log interpretation and correlation with offset analogue production.

For the same reason the Company did not flow test its recent oil discovery in VR 342. In this case analogue studies based on numerous existing producing analogues (performed independently on Entek's request) suggest potential flow rates of 500-1000 BOPD with minimal decline for the first 3-4 years.

Development planning is currently underway for the VR 342 oil discovery based on the flow rates described above and the independently certified gross reserves of circa 7.5 MMBO (1P 2.5 MMbo; 2P 4.8 MMbo; 3P 7.5 MMbo) and 9.5 Bcfg (1P 3.8 Bcfg; 2P 6.3 Bcfg; 3P 9.5 Bcfg) or 9.1 MMboe.

Additional wells are expected to be drilled in first half of 2012. First oil production is anticipated in 3Q 2012. Entek has 50% working interest in the VR 342 block.

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TAG Flows Rates of 8.8 MMcf/d at Sidewinder-2

- TAG Flows Rates of 8.8 MMcf/d at Sidewinder-2

Thursday, June 23, 2011
TAG Oil Ltd.

TAG Oil reported that a 4-Point Isochronal flow test was completed over the main discovery zone in the Sidewinder-2 discovery well, which achieved stabilized flow rates of 8.8 million cubic feet per day (~1467 BOE per day) with less than a 25% drawdown.

The results from Sidewinder-2 further strengthen the already robust project economics, with anticipated full-time commercial production commencing upon completion of the new Sidewinder production facilities in a few months time. The Sidewinder-2 well is the fourth Sidewinder well that has been flow tested, all of which have achieved excellent flow rates, as summarized below:

Sidewinder Discovery Flow Test Results

Sidewinder Well	Gas Flow Rate (MMcfpd)	BOE Flow Rate (boepd)	Final Drawdown Rate	Net O&G Encountered
Sidewinder-1	7.40	1,233	28%	14 meters
Sidewinder-2	8.80	1,467	25%	47 meters
Sidewinder-3	7.21	1,202	40%	15.4 meters
Sidewinder-4	6.98	1,163	25%	19 meters
Totals	30.39 MMcfpd	5,065 Boepd

The Sidewinder-2 exploration well was drilled to a depth of 1,597 meters (5,238 feet), intersecting the main Sidewinder discovery zone, as well as four other separate oil-and-gas charged zones of interest totaling 47 meters (157 feet) of net pay. The interpreted pay zones are primarily within the Miocene-aged Mt. Messenger Formation; however oil shows were also encountered in the shallower Urenui Formation.

The Sidewinder oil and gas discoveries are located in TAG Oil's Petroleum Exploration Permit 38748 (TAG 100%) in the Taranaki Basin, New Zealand, with further exploration drilling in the lightly-explored area scheduled to recommence in September 2011. TAG will continue to target the widespread high-impact prospects identified in the Mt. Messenger Formation.

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McMoRan Runs at Rate of 54 MMcf/d at Laphroaig Well

McMoRan Runs at Rate of 54 MMcf/d at Laphroaig Well

Wednesday, April 13, 2011
McMoRan Exploration Co.

McMoRan announced a successful production test at the Laphroaig No. 2 well in St. Mary Parish, Louisiana. The production test indicated a gross rate of approximately 54 million cubic feet of natural gas per day (MMcf/d) (approximately 15 MMcf/d net to McMoRan) and zero barrels of water on a 30/64th choke with flowing tubing pressure of 9,989 pounds per square inch (PSI). McMoRan will use the results of the production test to determine the optimal flow rate for the well. The well is expected to commence production in the second quarter of 2011 using facilities in the immediate area. McMoRan has a 37.3 percent working interest and a 28.5 percent net revenue interest in the Laphroaig field. EXXI holds an 18.6 percent working interest.