Karoon Gas Australia Ltd’s Kangaroo-2 appraisal well, located in exploration Block S-M-1165, off Brazil, confirmed a 250 metre gross (135 metre net) oil column in Paleocene and Maastrichtian aged reservoirs, as announced on November 26 , 2014.
The company says that as at 0600 hrs AEST on January 6, 2015, production testing over the Paleocene A, B and C oil bearing reservoirs was complete. Preparations are underway to start a side-track program to better define the resource size and recovery factors.
Karoon is the operator and has a 65% interest in the jointly held Block S-M-1165, Santos Basin, Brazil. Pacific Rubiales Energy Corp holds the remaining 35% interest.
The results from the test are as follows:
Oil Flow Rate
Production test DST-2A was conducted in the Paleocene A, B and C sandstone reservoirs over the intervals 1,663- 1,681 mRT, 1,695-1,729 mRT and 1,735-1,753 mRT with a 12 hour main flow period. The maximum oil flow rate attained was 3,700 stb/d (stabilised rate of 3,450 stb/d) through an 88/64” choke with a flowing tubing head pressure of 270 psia, a gas-oil-ratio of 540 scf/stb.
Production test DST-2 was conducted in the Paleocene C sandstone reservoir over the interval 1,735- 1,753 mRT. The maximum oil flow rate attained was 2,500 stb/d through a 44/64” choke with a flowing tubing head pressure of 425 psia and a gas-oil-ratio of 450 scf/stb. The well was then flowed on a 40/64” choke at a stabilised rate of 1,820 stb/d with a flowing tubing head pressure of 420 psia, a gas-oil-ratio of 450 scf/stb. At the end of a main 24 hour flow period, the well was shut-in for a 48 hour pressure build-up period.
Oil Specification
DST-2A produced a 33° API oil with zero CO2, H2S, water or sand produced. DST-2 produced a 31° API oil with zero CO2, H2S, water or sand produced.
Production Well Potential
Based on the oil rates obtained in DST-1A (Maastrichtian section) and DST-2A (Paleocene section), Managing Director, Robert Hosking said: “Karoon is very pleased with the production testing results from Kangaroo-2. Based on the flow rates achieved in both the Paleocene and Maastrichtian reservoirs, a vertical production well could produce 6,000 to 8,000 stb/d from the combined reservoirs. In addition, horizontal production wells could be expected to produce at higher rates.”
Kangaroo-2 Side-Track Program
After the well testing string is removed and the Paleocene reservoirs are plugged back with cement and a cement retainer, the well will be side-tracked in both a down-dip and up-dip location in order to better define the resource size and recovery factors, Karoon notes in the press release.
Side-track-1 will be drilled to a down-dip location to target the Paleocene and Maastrichtian reservoirs on the eastern side of an interpreted north-south trending fault, and to evaluate potential hydrocarbon accumulations in the Campanian. Wire-line logs and a pressure survey will be conducted.
Side-track-2 will be drilled into Paleocene and Maastrichtian reservoirs in an up-dip location to test reservoir and hydrocarbon potential towards the salt wall.
The company explains that the information obtained from Kangaroo-2 will be important for assessing the commerciality of the Kangaroo oil field and will be valuable for a Front End Engineering and Design (’FEED’) phase bringing the project a step closer to commerciality.
The Kangaroo-2 appraisal well is located in exploration Block S-M-1165, approximately 300 metres up-dip and 4 kilometres south of Kangaroo-1 and is the first well in the Santos Basin exploration and appraisal drilling campaign.
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