Shell has discovered oil at the Leopard prospect in the deep-water US Gulf of Mexico (GoM).
Shell has discovered oil at the Leopard prospect in the deep-water US Gulf of Mexico (GoM). The Leopard well encountered more than 183 m net oil pay at multiple levels. Leopard is located in OCS block Alaminos Canyon (AC) 691, 32 km east of the Whale discovery, 32 km south of the recently appraised Blacktip discovery and 53 km from the Perdido host. Leopard is an opportunity to increase production in the Perdido Corridor, where Shell’s Great White, Silvertip and Tobago fields are already producing. Meanwhile, the Whale discovery, also in the Perdido Corridor, is progressing towards a final investment decision in 2021. Leopard is operated by Shell (50%) and co-owned by Chevron (50%).
Wintershall Dea has made a big gas, condensate and oil discovery at the Dvalin North prospect in the Haltenbanken area of the Norwegian Sea. The Dvalin North discovery, estimated to hold between 33-70 million barrels of oil equivalent (boe), is 12 km north of the company’s operated Dvalin field, and 65 km north of the Maria field. The well also encountered hydrocarbons in two shallower secondary targets, with a combined resource estimate of 38-87 million boe. The well encountered gas, condensate and oil columns of 33 m and 114 m respectively in the Cretaceous Lysing and Lange Formations. In the primary target in the Garn Formation, the well found a gas column of 85 m. Wintershall Dea is the operator with a 55% share. Other partners are Petoro and Sval Energi.
Equinor (operator), ExxonMobil, Petrogal Brasil and Pré-sal Petróleo (PPSA) have decided to develop phase one of the Bacalhau field in the Brazilian pre-salt Santos area – the first greenfield development by an international operator in the presalt area. For an $8 billion investment, the break-even is below $35 and estimated recoverable reserves in the first phase are more than one billion barrels of oil. First oil is planned in 2024.
Reconnaissance Energy Africa (Recon Africa) has confirmed a working petroleum system in the Kavango Sedimentary Basin in Namibia. Based on initial analysis, 134 m of light oil and gas shows from the 6-1 well. The shows are similar in character (with clastic and thick carbonate sections) to those seen in the 6-2 well, 16 km to the south. The 6-1 and 6-2 wells are in the same sub-basin, one of five major sub-basins of the larger, more laterally extensive Kavango Sedimentary Basin. The upcoming 2D seismic survey will tie in the data from these two wells and provide the first regional interpretation of the overall basin. Schlumberger, Geomark Research and Netherland Sewell and Associates have been providing research.
Eni has encountered 43 m of gas-bearing net sands with excellent reservoir characteristics of Pliocene Age after drilling the Maha 2 appraisal well in the West Ganal block offshore Kalimantan, Indonesia. The field is 16 km south-east of Jangkrik FPU, operated by Eni. The well has been drilled to a depth of 2970 m in 1115 m water depth. Through the test and the coring of the reservoir, important data have been collected to perform all the studies required for the preparation of a field development plan for the Maha field, where two other appraisal wells are planned. The development plan foresees a sub-sea completion and a tie-in to Jangkrik FPU. Eni is the operator of West Ganal Block holding 40% interest while Neptune and P.T. Pertamina Hulu hold a 30% each.
Turkey has discovered 135 billion cubic metres of additional natural gas in the southern Black Sea with the Amasra-1 well in the Sakarya gas field, raising the total discovery in the region to 540 billion cubic metres.
