Medco Energi has completed its wildcat Nowera 1 in the South Sumatra PSC EXT, located in the South Sumatra Basin, around end-April 2018. The well was drilled to a TD of 1,478 m MD (4,850 feet), with bottom hole in the Basement, and it has been suspended as a gas discovery after testing.  The company also reported in June 2018 that it continued land clearance in preparation to spud its next well, Flamboyan 1. Total cost for the Nowera 1 operation is approximately USD 4.35 million.   As of end-March 2018, the company reported to have carried out well testing operations at Nowera 1.   Nowera 1 was spudded on 10 February 2018, using the âDreco 750 Hpâ land rig. Drilled depth was approximately 556 m (1,826 feet), as of end-February 2018. Nowera 1 is the second of a three-well exploration drilling campaign in the block.  In late December 2017, Medco plugged and abandoned wildcat Cempaka 1 as a dry hole. The well was spudded on 20 November 2017, using a Medco-owned land rig, and had a PTD of approximately 304 m (996 ft) MD/TVD.  The targets for the wells could be the Lower Miocene Batu Raja carbonates which is the most prolific reservoir in the Musi platform area. Secondary targets could be the fractured Basement and the Upper Oligocene-Lower Miocene Talang Akar Formation.  The final drilling cost for Cempaka 1 was reported at approximately USD 2.6 million.  Cempaka 1 was the first of a three-well drilling campaign in the block. After the completion of Cempaka 1, the operator began well site construction for Nowera 1, while land clearance was ongoing for the final well (Flamboyan 1).  Preparations for the campaign, including land clearance, licensing and environmental studies, were first reported in late January 2017.  Medco was also planning to acquire 330 km of 2D seismic data in the block, in Q1 2017, however the plan was postponed to Q4 2018. The company has received SKK Migas approval for the survey.  The previous exploration activity in the block was a 3D seismic survey covering 110 sq km in the Temelat area, completed in April 2015.  Medco is operator and sole interest holder in the South Sumatra PSC Extension which received a 20-year extension on 28 October 2010.  Background Information  Medco was previously planning to drill appraisal well Rambutan Deep 2 in 2015, but the plan likely did not push through. According to operatorâs report in late July 2014, the purpose of the well was to explore gas play in the deeper reservoir of Rambutan field, which has estimated unrisked resources of 277 Bcfg. Rambutan Deep 2 was planned to be drilled to a TD of 3,000 m, targeting Upper Oligocene to Lower Miocene Talang Akar Formation.  Medco spudded Lagan Deep 1A on 22 August 2013, with a PTD of 3,444 m, primarily targeting the Upper Oligocene to Lower Miocene Talang Akar Formation. The well was temporarily shut-in for future testing in February 2014. The company reported that total drilling cost for Lagan Deep 1A until end of June 2014 was USD 27,661,111.  In late September 2011, the operator conducted preparations to kill the Lagan Deep 1 deeper pool wildcat in the South and Central Sumatra PSC, as there was unintended gas and fluid flow to the surface within the vicinity of the well. The unintended flow started on 13 September 2011 (2300H) after the well reached a depth of 816 m. Loss circulation material has been pumped but well has continued to flow. There were no fatalities, injuries, facilities damage and fire related to this incident. Safety measures have been performed and will continue to be conducted until well has been controlled. The Test was also conducted on the gas and fluid flowing and were deemed non-toxic., drill site location is about 2 km away from the nearest communities.  Lagan Deep 1 was spudded on 7 September 2011 using the âAntareja-8â rig. The well lies in the Kebur I sub-block and is located 13 km south of Rambutan Deep 1. It has a PTVD of 3,505m and it will primarily target gas bearing sandstones of the Upper Oligocene to Lower Miocene Talang Akar Formation. Possibly secondary targets were the Lower to Middle Miocene Gumai sandstones and Lower Miocene Batu Raja carbonates. Drilling was expected to take 75 days and in the event of a success, the well will be put onstream via existing facilities in the area and gas will be delivered to the nearby Rambutan station. The main Lagan field was discovered in 1941 by Stanvac. It has gas with condensate reservoirs in the sandstones of the Middle to Upper Miocene Air Benakat Formation, at depths of around 600 to 1,200m. Estimated 2P recoverable reserves for the field were around 285 Bcfg plus 5.5 MMbc. Production commenced in 1986 and the field has produced more than 100 Bcfg and 2 MMbc.
Nowera 1 (Dart Egy 50% op, PT Medco 50%) in South Sumatra PSC EXT drilled to a TD=1478m MD, with bottom hole in the Basement, and it has been suspended as a gas discovery after testing.