Argentina Seismic Coverage Extended
Spectrum, in partnership with BGP Marine, has started a multi-client 2D seismic survey covering the Austral and Malvinas basins offshore southern Argentina.
Through the authorization of the Ministry of Energy and Minerals, the expected survey size is about 14,500 km (9,010 mi) but may vary based on input from participating clients.
Data is being acquired with a 12,000-m (39,370-ft) streamer with continuous recording to enable extended recording lengths and high fold data to enable full interpretation from Moho to water bottom. The data will be processed with PSTM, PSDM, and Broadband products with first deliveries expected in early 2Q 2018.
The new data will be used to assist the Ministry in placement and design of parcels for the future license rounds offshore Argentina.
Richie Miller, EVP Multi-Client Americas, said: “The strong support and interest Spectrum generated for the ongoing Argentine deepwater program allowed us to continue to build on our Argentinian multi-year program with the addition of the Austral Malvinas program.
“The industry appreciates the need for new, modern, long offset broadband data to help them evaluate the full potential of the area prior to the expected license round in 2H 2018. Spectrum expects to collect, process and deliver over 50,000 km [31,069 mi] of data to industry in time for these rounds.”
This survey is supported by industry funding.
Tunisia Allows Offshore Drilling
Tunisia’s Director General of Hydrocarbons (DGH) has accepted an application by Alpine Oil and Gas (AOG) to vary work commitments on the offshore Kerkouane license.
AOG, a subsidiary of ADX Energy, will now drill the DouggaSud well and conduct productivity testing of the Dougga gas/condensate reservoirs.
The previous requirement had been for an exploration well and the acquisition of 500 sq km (193 sq mi) of 3D seismic.
These revisions are pre-condition to the entry into a second, three-year renewal period for the permit.
DGH has also advised it requires a bank guarantee in relation to the modified program, although this will be lifted on the testing of the DouggaSud well.
Last month ADX agreed to[WU1] sign a contract with Noble Drilling Services for use of the drillship GlobeTrotter II for the well.
In addition, the company is in talks with various parties interested in participating in and providing funding for the well.
Norway Maria Field Close to Startup
The Norwegian Petroleum Directorate (NPD) has authorized Wintershall to start-up the Maria field in the Norwegian Sea, around 10 months ahead of the original date targeted in the field development plan.
Production is now expected to begin in December. The NPD says good project execution and efficient drilling have helped Wintershall beat its schedule.
The development has also been cheaper than expected at just over NOK12 billion ($1.46 billion), against the originally estimated NOK15.7 billion ($1.92 billion).
Kalmar Ildstad, NPD’s Assistant Director for Development and Operations in the Norwegian Sea, said: “With a total of four host facilities, the project is also a good example of the value creation generated from good collaboration with the licensees in surrounding infrastructure.”
The consent for start-up is issued to the partners in production licenses 475 BS and 475 CS.
Maria is 240 km (149 mi) northwest of Trondheim, 20 km (12.4 mi) east of the Kristin field, and 45 km (28 mi) southwest of the Heidrun field.
Development involved installation of two, four-slot seabed templates which will house four oil production and two water injection wells.
Maria’s wellstream will be transported via a seabed pipeline to Kristin for processing and metering. There, the stabilized oil will be routed to the Åsgard C - FSU for storage and offloading, while the rich gas will be routed through the Åsgard Transport System to Kårstø, for extraction of NGLs and condensate.
Gas for lift purposes at Maria will be imported from Åsgard B via the Tyrihans D template, with pressure support obtained through the injection of sulfate-reduced water from the Heidrun TLP.
Wintershall estimates the field’s recoverable reserves at 28.9 MMcm of oil, 1.32 MM metric tons (1.45 MM tons) of NGLs, and 2.31 bcm of gas. Maria should remain in product
Oil Find in Vietnam
Murphy Oil has discovered oil with the CM-1X well in the Nam Con Son basin offshore southern Vietnam.
The company will continue to assess the commercial potential of the block, which includes the successful CT-1X discovery well drilled in 2Q.
In Vietnam’s offshore Cuu Long basin, Murphy is working with its partners on the block 15-1/05 LDV discovery for a declaration of commerciality in 2018, and also plans a nearby exploration well, while continuing to pursue entry into the adjacent 15-2/17 block.
During 3Q, the company entered into a farm-in agreement with QueirozGalvãoExploração e Produção (QGEP) to acquire a 20% interest in blocks SEAL-M-351 and SEAL-M-428 in the deep-water Sergipe-Alagoas basin offshore Brazil.
In a separate but related transaction, ExxonMobil ExploraçãoBrasil has farmed into the remaining 50% interest as the operator (QGEP retains 30%).
In addition, Murphy and its co-venturers were the high bidder for the adjacent blocks SEAL-M-501 and SEAL-M-503 in Brazil’s Round 14 lease sale. ExxonMobil will operate, and each company will maintain the same working interest in each of these blocks.
Offshore Mexico, Murphy has been working through the permitting process for the first exploration well in deepwater block 5 and is reviewing reprocessed wide azimuth seismic data across the acreage.
3-Studies Continue on Australia Offshore Projects
AWE says that field development studies continue for the AndeAndeLumut (AAL) oil field project in the northwest Natuna Sea off Indonesia.
The present focus is on optimizing on drilling and completions for the K and G sands resources, while minor modifications are under review for the FPSO processing infrastructure to maximize comingled production from the two reservoirs.
Indonesia’s government is said to be keen to advance the project and has advised the partners that it intends to exercise its right to assign 10% of their interest to a local Indonesian entity in 2018.
Under the PSC terms, the existing partners will carry the local entity through the development phase but will be reimbursed from production.
The partners are preparing an application to jointly develop the G sand and K sand reservoirs from field start-up, which may require an amendment to the approved plan of development prior to the final investment decision.
Offshore southeast Australia, AWE is a 35% partner in the BassGas project. Here third-quarter production was up 23% on the previous quarter, mainly due to compression starting on the Yolla platform.
However, there have been issues with the onshore sales gas compressor at the Lang Lang gas plant which resulted in a period of downtime while repairs were implemented.
A change of operator is likely now that Origin Energy has agreed to sell its subsidiary Lattice Energy to Beach Energy. Next year’s plans include a wireline program.
In the offshore T/RL2 concession (AWE 40%), the Shearwater 3D seismic reprocessing has finished, and concept studies are progressing for the Trefoil field development, with updated static and dynamic modeling of the reservoirs nearing completion.