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Egypt Oil & Gas Report Q1 2014

Published by Business Monitor International on Dec 20, 2013 - 130 pages
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Political risk in Egypt has peaked, and we expect a slight moderation over the coming months. The interim government has brought a semblance of stability to Egypt's political scene and a degree of policy continuity that has not been present in Egypt for much of 2013. Nevertheless, we believe that operational risk and lack of policy certainty will affect the country's oil and gas output for the coming months and possibly years. That said, we stress that the country's below-ground potential remains extensive, as exemplified by a series of recent discoveries in onshore and offshore concessions. This leads us to believe that Egypt still holds large upside potential, but this will only be monetised over the long term as current woes are alleviated.

We highlight the following trends and developments in Egypt's oil and gas sector:
  • A series of recent discoveries by Beach Energy and Apache in their Western Desert concessions and BP Egypt in the deepwater East Nile Delta highlight that below-ground potential remains promising.
  • We see serious downside risk to our production forecasts for 2013 and 2014, as companies are likely to reduce their exposure to operational risks. Both BG and BP have already announced reductions in their activities. Apache also divested 33% stake in its Egyptian business to Sinopec for US$3.1bn, reducing its exposure to the country, which - before the divestment - accounted for 20% of total production.
  • In addition, U$6bn in unpaid debts to companies by the Egyptian Natural Gas Holding Company and Egyptian General Petroleum Corporation (EGPC) highlight the financial strains of the state-owned energy companies. While a repayment schedule has been agreed to, it highlights the additional operational and financial risk operating in the country.
  • While political risk is pertinent and certainly the main concern in the short term (at least until 2014 elections, but most likely after that as well), we see the domestic fuel-pricing environment as a long-term, persistent worry for foreign operators. With the country failing to reach an agreement with the IMF and not implementing a rationalisation of its downstream market, producers face growing risk that output may be redirected to meet domestic demand rather than their contracted export obligations.
  • Although gas production is expected to grow from 61.2bn cubic metres (bcm) to 79.9bcm in the 2013-2022 period, consumption will rise at an ever more rapid pace, from 50.7bcm to 78.0bcm. Net gas exports, especially liquefied natural gas (LNG), will fall over the forecast period as consumption increases sharply. We have downgraded our 2013 production and consumption forecasts to reflect a fall in gas production and fall in gas consumption (especially from the power sector).
  • We expect Egyptian oil production to decline from 729,400 barrels per day (b/d) in 2013 to 711,000b/d in 2022. At the same time, consumption is expected to rise significantly, from 759,900b/d to 1.07mn b/d over the same period, close to quadrupling Egypt's oil import bill.
  • Despite several proposals to increase capacity, we do not see refineries advancing over our forecast period. With refining capacity set to remain flat, imports of refined products are set to rise.
  • EGPC and Egypt's other state-owned companies will continue to push their own licensing rounds, hoping that political challenges will not ensnare investment in upstream hydrocarbons projects. In the June 2012 licensing round (with contracts finally awarded in April 2013) EGAS offered a total of 53,700 square kilometres of acreage in 15 blocks, 13 of which were offshore. Eight blocks were awarded, including to Petroceltic, BP and Edison.

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