Papua New Guinea LNG force majeure a week after expansion plans announced

ExxonMobil has declared force majeure on PNG LNG after Papua New Guinea was hit by a 7.5 magnitude earthquake on Monday. The partners in the plant, which exported 7.8 million tonnes last year, are ExxonMobil (33.2% operator), Oil Search (29%), State of Papua New Guinea (16.8%), Santos (13.5%), JX Nippon (4.7%) and Mineral Resources Development Company of Papua New Guinea (2.8%). Latest reports are that the pipeline and liquefaction plant sustained minimal damage, but could potentially be another six weeks before it can be restarted.

This comes a week after the announcement by the upstream partners in Papua New Guinea’s giant gas resources to more than double the country’s liquefaction capacity to 16mmtpa at a cost of USD13 billion. The partners are planning to help add a further three trains in the country – one to support growth at ExxonMobil’s P’nyang field, and two to service new gas from Total’s Elk-Antelope development. FEED is planned to start later this year, but will require agreement of terms with the PNG government first including domestic supply obligations.

Given this is a brownfield expansion, it is significantly cheaper than the original USD19.5 billion construction cost of the project. The partners were previously toying with the idea of having a separate facility for Elk-Antelope gas as Total and ExxonMobil could not reach agreement. ExxonMobil was pushing for the gas to go through PNG LNG supported by train expansions, while Total was considering a new plant (Papua LNG). While the details on the new three trains remain high level and could still see a separate Papua LNG project, this agreement thaws the development discussions which have been frozen for more than a year. The separate trains supporting the different upstream gas sources will also be conducive to structuring and financing of the proposed project – avoiding the complexity involved with unitisations and co-mingled gas marketing. The new LNG could come onstream by the early 2020s and would arrive in time for an emerging LNG supply gap that is foreseen by the industry.

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OVL and GeoPark announce strategic partnership across Latin America

ONGC Videsh, the international arm of Indian oil & gas giant ONGC, and GeoPark have entered into a long-term partnership to acquire and invest in upstream projects across Latin America. Both companies have an existing presence in the region and the partnership will help the two companies work together as a consolidator of assets to build a large scale business.

GeoPark has a sporadic portfolio throughout Latin America and has aspired to build a large portfolio. It has been semi-successful at doing so with recent growth underpinned by its Colombian position in LLA-34 (55% operator, with Parex 45%) and current production of c.30mboepd. In Chile, Argentina and Peru, GeoPark is also operator and one of the few Latin American focused E&Ps that has made an attempt at venturing beyond Colombia.

GeoPark acreage
Source: GeoPark

ONGC has a small presence in Latin America with production of c.34mboepd. It has built its position through a series of compact partnerships and assets dominated by heavy oil. ONGC aspires to build its international business noting that it announced its intention to spend USD10-12 billion in overseas acquisitions and partnerships back in 2015. It now appears to have found its niche in Latin America where it can build up a larger platform having tested the waters.

GeoPark and ONGC acreage
Source: Wood Mackenzie, OGInsights

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FAR goes further with another industry partner

On 26^th February, FAR announced that it had agreed to farm-out a 40% interest in Blocks A2 and A5 in The Gambia to Petronas. FAR will retain 40% and operatorship; the remaining 20% is held by Erin Energy – FAR farmed in to the blocks in March 2017 in return for upfront payment of USD5.2 million and FAR funding an exploration well (to be drilled in 2018) up to USD8 million.

Under the deal, Petronas will fund 80% of the Samo-1 exploration well up to USD45 million with the option to take on operatorship for the development. Petronas will also pay USD6 million on closing of the transaction, well back costs of USD6.4 million and non-well back costs of USD1.1 million. The well is planned to be drilled in late 2018 targeting unrisked prospective resources of 825mmbbl.

These are highly exciting blocks, lying to the south of the large SNE and FAN discoveries in Senegal and presents an opportunity to potentially capture the successful trend to date along the coast of West Africa. FAR has completed detailed geotechnical studies and from 3D seismic, FAR has identified large prospects similar to the fields that FAR has participated in in Senegal. FAR has mapped two drillable prospects, Samo and Mambo with further leads identified on the block.

The entry of Petronas comes a year after FAR attracted another major NOC into the basin – in March 2017, FAR and CNOOC entered into an Area of Mutual Interest (“AMI”) agreement with CNOOC with the two companies agreeing to partner in evaluation, bidding and negotiating farm-ins and licences across Senegal and The Gambia. The AMI lasts for a period of two years.

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Aker Energy buys Hess’ Ghana business

Aker Energy, a 50-50 JV between Aker and TRG, has acquired Hess’ 40% interest in Deepwater Tano Cape Three Points, offshore Ghana for USD100 million, with USD25 million payable at close and a further USD75 million payable on PDO approval.

The block lies south of the Jubilee and TEN blocks operated by Tullow and covers over c.2,100km² with a 2C resource estimate of ~550mmbbl. Aker will present a development plan for the block later this year with the first phase targeting c.400mmbbl using a FPSO with a subsea production system. First oil is anticipated in 2021.

The ultra-deepwater block (~2,000-2,500m depth) contains seven discoveries. Hess declared commerciality on four of the fields in March 2016 with Pecan identified as the development hub. However, with the fields straddling the Ghanaian / Cote d'Ivoire border and the ongoing dispute at the time, the partners were unable to apply for a development licence. With the border dispute now settled, the development can now go ahead.

Post transaction, the ownership of the block will be Aker Energy (40%), Lukoil (50%) and GNPC (10%) The development helps Ghana develop its hydrocarbon resources beyond TEN and Jubilee which currently produce c.200mboe/d.

Hess: Deepwater Tano Cape Three Points drilling results (2015)

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OVL to bid for South Azadegan oil development in Iran

Indian oil giant ONGC Videsh Limited ("OVL") will bid for the development rights of the giant South Azadegan in Iran. There is strong competition with the likes of Gazprom, Lukoil, Rosneft, Shell, Total, Eni Petronas, Inpex, Sinopec and CNPC. of Malaysia and Russia’s Gazprom. OVL is one of 34 companies that pre-qualified last year for development of the field which is estimated to contain 6bnboe recoverable and currently produces 80mbbl/d - with the right investment, this could reach 320mbbl/d.

The National Iranian Oil Co ("NIOC") will issue a tender for the development shortly.

Separately, OVL will also rework the Farzad B gas field at a cost of USD6.2 billion, which it had discovered a decade ago and is trying to get Iran to award rights of the field to it. Sources say that OVL had last year made its ‘best’ offer to invest USD11 billion in developing the Farzad-B field and building export infrastructure but Iran has deterred awarding the rights of the field to OVL owing to differences over pricing of the fuel. OVL has now instead offered to do just the upstream part of bringing the field to production while leaving the marketing of the fuel to Iran, which will cost USD6.2 billion.

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Kurdistan players receive payment for November exports

Genel Energy and DNO have received payment from the KRG for November oil sales.

DNO received USD54.73 million for crude oil deliveries to the export market from the Tawke. The funds will be shared by DNO and Genel pro-rata to the companies' interests in the licence (75% DNO/25% Genel). Separately, a payment of USD4.7 million was received by DNO, representing 3% of gross Tawke licence revenues during November, as provided for under receivables settlement agreement from August 2017.

The Taq Taq partners have received a gross payment of USD11.05 million, with Genel's share of the payments being USD6.08 million.

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Faroe finds a Valentine in Suncor – farms out 17.5% in Fenja to Suncor

Faroe has announced the sale of a 17.5% interest in the Fenja development to Suncor for USD54.5 million which includes the transfer of tax losses.

Faroe will retain a 7.5% interest which fully aligns its equity interest with that of the other fields in the Greater Njord Area (Njord, Bauge, Hyme and Fenja). The transaction crystallises value of the asset pre-development and reduces Faroe’s capex (estimated to GBP70 million).

The PDO for Fenja was submitted in December 2017 and the operator VNG expects recoverable reserves of 97mmboe (72% oil). Fenja contains the Pil and Bue discoveries and will be developed as a subsea tie back to Njord. Pil will be developed first using three horizontal producers supported by water and gas injection wells. Bue will be brought online at a later date.

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