Olinda Star Semisub to Drill Kangaroo West-1 Well in Santos Basin Soon
Karoon Gas Australia Ltd.’s disclosed Friday that the Kangaroo-2 appraisal well, located in exploration Block S-M-1165, confirmed a 820 foot (250 meter) gross or 443 foot (135 metre) net oil column in Paleocene and Maastrichtian aged reservoirs, announced Nov. 26, 2014. Karoon is the operator and has a 65 percent interest in the
jointly held Block S-M-1165, Santos Basin, Brazil. Pacific Rubiales Energy Corp holds the remaining 35 percent interest.
As at 0600 hrs AEST Jan. 6, production testing over the Paleocene A, B and C oil bearing reservoirs was complete. Preparations are underway to commence a side-track program to better define the resource size and recovery factors. 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 5,456-5,515 feet (1,663- 1,681 meters) rotary table (RT), 5,561-5,672 feet (1,695-1,729 meters) RT and 5,692-5,751 feet (1,735-1,753 meters) RT with a 12 hour main flow period. The maximum oil flow rate attained was 3,700 stock tank barrel per day or stb/d (stabilized rate of 3,450 stb/d) through an 88/64 inch choke with a flowing tubing head pressure of 270 psia, a gas-oil-ratio of 540 standard cubic feet (scf)/stb.
Production test DST-2 was conducted in the Paleocene C sandstone reservoir over the interval 5,692-5,751 feet (1,735-1,753 meters) RT. The maximum oil flow rate attained was 2,500 stb/d through a 44/64 inch 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 inch 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.
DST-2A produced a 33 degree API oil with zero carbon dioxide (CO2), hydrogen sulfide (H2S), water or sand produced.
DST-2 produced a 31 degree 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.”
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