Alvopetro Energy Ltd. announces initial results from the second interval tested in our 183-B1 well on our 100% owned and operated Block 183.
In July 2022, we completed drilling the 183-B1 exploration well to a total measured depth ("MD") of 2,917 metres. Based on open-hole wireline logs and fluid samples confirming hydrocarbons, the well discovered hydrocarbons in multiple formations with a total of 34.3 metres of potential net hydrocarbon pay, with an average porosity of 10.6% and average water saturation of 29.0% using a 6% porosity cut-off, 50% Vshale cut-off and 50% water saturation cut-off.
Alvopetro has completed the 183-B1 formation test in the Agua Grande formation, the second deepest of three formations with hydrocarbons shows during drilling of the well. We perforated a total of 8.5 metres in the Agua Grande formation at various intervals between 2,680 metres and 2,699 metres MD. During the clean up flow period we recovered 16 bbls of completion fluid and 1 bbl of 52°API natural gas liquids (condensate). After a short shut-in we initiated the production test on a 32/64" choke. Cumulatively, over the duration of the 72-hour production test, we recovered 2.4 bbls of 48°API natural gas liquids (condensate), 9.4 bbls of formation water and 2.4 MMcf of gas. During the test, the flowing rate decreased from 5.7 MMcfpd to 0.3 MMcfpd, the average gas rate during testing operations was 0.8 MMcfpd. At the beginning of the testing operations the shut-in wellhead pressure ("SIWHP") was 2,555 psi, and the final flowing wellhead pressure was 40 psi. After 32 hours of buildup the SIWHP was 610 psi.
These results indicate a high permeability zone that delivered strong initial production flow rates but, based on pressure and production declines over the flow period, and slow pressure build up following the test, the Agua Grande reservoir appears to be areally constrained in the high permeability zone and likely sub-commercial in the remaining Agua Grande zones. We will now proceed up-hole to test the Candeias Formation. Based on open-hole logs, using a 6% porosity cut-off, 50% Vshale cut-off and 50% water saturation cut-off the Gomo member of the Candeias Formation was encountered at 2,578 to 2,583 metres total vertical depth, with 5.3 metres of potential net light oil pay, at an average 35.0% water saturation and average porosity of 15.7%. A fluid sample in this Candeias interval was also collected with a dual packer wireline tool recovering 37.1°API oil with no water to surface from 2,580 metres depth at a formation pressure of 4,317 psi.
We previously announced the results of the 183-B1 formation test in the Sergi Formation, the deepest of three formations with hydrocarbons shows during drilling of the well. We perforated a total of 26.5 metres in the upper portion of the Sergi formation at various intervals between 2,811 metres MD and 2,886 metres MD. We initially swabbed 63 bbls of oil and 7 bbls of completions fluid during the clean-up period. After a short shut-in we then initiated the production test. Cumulatively, over the duration of the 72-hour production test, we recovered 59 bbls of 43°API oil, 7 bbls of water identified as completion fluid, and 0.28 MMcf of associated gas. The daily oil rate recovered during swabbing operations averaged 20 bopd. We are engineering a stimulation plan for this upper Sergi section in this well and we have submitted applications to drill two follow up wells from this 183-B1 surface location targeting the full Sergi hydrocarbon column and the potential in the deeper Boipeba Formation.