Things have been quite active in the Eastern Mediterranean lately, with Israel, Cyprus and Greece pushing forward for the realization of the EastMed pipeline, a new gas conduit destined to diversify Europe’s natural gas sources and find a long-term reliable market outlet for all the recent Mediterranean gas discoveries. The three sides have reached an agreement in late November (roughly a year after signing the MoU) to lay the pipeline, the estimated cost of which hovers around $7 billion (roughly the same as rival TurkStream’s construction cost). Yet behind the brave facade, it is still very early to talk about EastMed as a viable and profitable project as it faces an uphill battle with traditionally difficult Levantine geopolitics, as well as field geology.
The EastMed gas pipeline is expected to start some 170 kilometers off the southern coast of Cyprus and reach Otranto on the Puglian coast of Italy via the island of Crete and the Greek mainland. Since most of its subsea section is projected to be laid at depths of 3-3.5 kilometer, in case it is built it would become the deepest subsea gas pipeline, most probably the longest, too, with an estimated length of 1900km. The countries involved proceed from the premise that the pipeline’s throughput capacity would be 20 BCM per year (706 BCf), although previous estimates were within the 12-16 BCm per year interval. According to Yuval Steinitz, the Israeli Energy Minister, the stakeholders would need a year to iron out all the remaining administrative issues and 4-5 years to build the pipeline, meaning it could come onstream not before 2025.
The idea of EastMed was first flaunted around 2009-2010 as the first more or less substantial gas discovery in the Eastern Mediterranean, the Tamar gas field in Israel’s offshore zone, paved the way for speculations about an impending gas boom. Then came the 535 BCm (18.9 TCf) Leviathan in 2010 and the 850 BCm (30 TCf) Zohr discovery in offshore Egypt five years later and suddenly it seemed that an Eastern Mediterranean gas expansion is inevitable. Yet over the years, the operators of Leviathan have already allocated part of their total gas volumes to domestic power generating companies and most notably NEPCO, the Jordanian electric power company (1.6-2BCm per year). Egypt has been concentrating on meeting domestic needs and getting rid of LNG imports, moreover once it bounces back to gas exporter status in 2019, it will only use its own 2 LNG terminals in Damietta and Idku. Related: Has Oil Hit Rock Bottom?
Thus, a pertinent question arises – whose gas would be used to fill the EastMed pipeline? If the pipeline starts in offshore Cyprus, then it would be logical to expect that Cyprus’ gas bounty would be somehow utilized. Yet Cyprus has been lagging behind Egypt and Israel in its offshore endeavors and so far lacks a clear-cut giant field to base its supply future on. The two discoveries appraised heretofore, the 6-8 TCf Calypso operated by ENI and the 4.5 TCf Aphrodite operated by Noble Energy, are not enough to support the construction of a relatively expensive gas pipeline – all the more so as Noble has signed a provisional deal to send Aphrodite gas to Egypt’s Idku LNG terminal, most likely by means of a subsea gas pipeline. If we are to judge the viability of the EastMed on the current situation, there is only Calypso and Israel to fill the pipeline, as Greece’s gas export plans are close to zero on the probability scale.
The subsea section from Cyprus’ offshore zone to the island of Crete lies in depths of 3km and is stretched across a seismically active zone. But there is even more – should Turkey claim rights on Cyprus’ offshore hydrocarbon deposits (in February 2018 it sent warships to scare away ENI’s drilling rig that was on its way to xxx), the project is all but dead. This is far from an implausible scenario as President Erdogan stated that Turkey would never allow for the extortion of natural resources in the East Mediterranean by means of excluding Ankara and Northern Cyprus. Cognizant of the risks inherent in an East Mediterranean gas pipeline, there has been no interest from oil and gas majors to participate in the project. This is worrying as the $7 billion are expected to be financed from private investors, of which there is a palpable dearth – despite the EU’s 35 million funding to promote what it sees as a Project of Common Interest. Related: Wall Street Sees Oil Price Recovery In 2019
Yet even for the European Union, the EastMed gas pipeline presents a bit of a headache as its commissioning would render the Southern Gas Corridor, comprising so far only of Trans Adriatic Pipeline (TAP) with a 10 BCm per year throughput capacity, irrelevant by creating a sort-of competitor. The price of the natural gas to be supplied via the EastMed pipeline might become the biggest obstacle of them all – if the cost of producing offshore Mediterranean gas turns out to be $4-5/MMBtu as expected, the addition of further transportation costs to it all would place EastMed supplied at the bottom range of European gas supply options (Russian gas supply is alleged to be profitable with price levels as low as $4/MMbtu). All this might change if any of the East Mediterranean countries were to discover a giant gas field, altering the economics of production or possibly even liquefaction.
In fact, 2019 will witness several key wells being drilled across Cyprus, Egypt and possibly even Israel. ExxonMobil’s testing of Block 10 in offshore Cyprus would largely point to the overall attractiveness of Cyprus as an oil and gas producing country – the drilling has already started, with results expected in Q1 2019. The ENI-operated Noor offshore field in Egypt, adjacent to Zohr, is a much hotter prospect with BP buying into it lately – most likely it will outshine all the other drilling sites in the Eastern Mediterranean, however, if a big discovery is confirmed, it would be most likely used for Egyptian purposes which run counter to the EastMed gas pipeline. Thus, EastMed’s only hope is that Israel 2nd international licensing round, results to be announced in July 2019, will elicit a couple of Leviathan-like finds that would make pipeline construction profitable. Until then, the prospects are rather bleak.
By Viktor Katona for Oilprice.com
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