Alvopetro Provided 197(2) Well Test Results

Source: www.gulfoilandgas.com 4/16/2015, Location: South America

Alvopetro Energy Ltd. is pleased to announce the pressure transient analysis conducted on the first interval of our 197(2) well and the results of the test of the second interval.

In December 2014, our 197(2) well located on Block 197 in the Recôncavo basin in the State of Bahia, Brazil, reached a total depth of 1,669 metres, discovered natural gas, and was cased and cemented. Based on logs, the well encountered 78 metres of potential net natural gas pay, with an average 33% water saturation and an average porosity of 12%, using an 8% porosity cut-off. We perforated and completed the deepest sandstone interval, at 1,460 - 1,469 metres, and completed a 72 hour wireline perforated cased-hole test. This average 12.6% porosity interval flowed natural gas, on an unstimulated basis, at an average rate of 101,000 m3/d (3.6 MMcfpd or 600 boepd), with a 32/64" choke, using 2-7/8 inch tubing, from the Caruaçu Member of the Maracangalha Formation. The initial pressure transient analysis of this first interval forecasts potential post-stimulation rates at 261,000 m3/d (9.2 MMcfpd or 1,530 boepd) after three months of continuous production and 125,000 m3/d (4.4 MMcfpd or 730 boepd) after one year of continuous production, in both instances at 1,000 psi sandface pressure.

We have now completed our second test, including the intervals from 1,371 - 1,376 and 1,384 - 1,389 metres, which contained 10.5 metres of potential net pay and 13.6% average porosity. Over the 72 hour tubing conveyed perforated cased-hole test, the second intervals flowed natural gas, on an unstimulated basis, at an average rate of 53,000 m3/d (1.9 MMcfpd or 310 boepd), with a 32/64" choke, using 2-7/8 inch tubing, from the Caruaçu Member of the Maracangalha Formation.

At commencement of the test, the flowing tubing pressure at the wellhead was 3,100 kPa (450 psig) and decreased to 2,140 kPa (310 psig) at the end of the test. The initial shut-in casing pressure in the wellbore at commencement of the test was 9,970 kPa (1446 psig) and the ending shut-in casing pressure was 2,480 kPa (360 psig). Cumulatively, over the duration of this 72 hour test, the well produced 158,000 m3 (5.6 MMcf) of natural gas. During the course of this test, in addition to the natural gas and not included in any flow rates reported in this press release, we recovered 7 barrels of 60° API condensate and 2 barrels of water.

The 197(2) well is currently shut-in to measure reservoir pressure and obtain pressure build-up data to undertake a pressure transient analysis, which will allow Alvopetro to predict the deliverability of this second interval. After completing the pressure build-up test, the second interval will be temporarily suspended with a retrievable bridge plug and the completion will proceed up-hole to test the third interval within the gas column. The third interval test will assess a sandstone reservoir at 1,322 - 1,327 metres that has no stratigraphic equivalent in the offset well.

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Related Categories: Artificial Lift  Cementing, Stimulation  Directional Drilling  Drilling  Drilling Engineering & Equipment Systems  Enhanced Oil Recovery  General  Logging, Perforating, Testing  Offshore Drilling  Reservoir/Completion Consultants  Workover & Well Services  Workover Rigs/Services 

Related Articles: Artificial Lift  Cementing, Stimulation  Directional Drilling  Drilling  Drilling Engineering & Equipment Systems  Enhanced Oil Recovery  General  Logging, Perforating, Testing  Offshore Drilling  Reservoir/Completion Consultants  Workover & Well Services  Workover Rigs/Services 


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