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Last Updated: June 22, 2016
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  1. Oil had a jittery week, with the dominant theme being fears of Brexit – the upcoming referendum in the UK on whether to remain or leave the European Union; fears over the economic impact if the UK was to vote ‘Leave’ sent crude prices down earlier in the week, then regaining to float just under US$50/b as ‘Remain’ gained momentum. The country goes to vote this Thursday.

  2. Ties between Asia and Iran continue to warm; China and Iran are reportedly developing an oil terminal project on Oeshm Island, a US$550 million project that will help ramp up Iranian crude exports, much of which will be destined for China as it attempts to diversify crude sources away from dependence of Russia and Saudi Arabia.

  3. As the race to satisfy Asian crude demand heats up with Iran upping the ante, traditional suppliers are looking to lock in with long-term customers; Abu Dhabi’s ADNOC visited the company’s client base in South Korea and Japan, aimed at securing and retaining the business of the NOC’s reliable clients in the East.

  4. Shell’s deepwater Malikai development in Sabah, Malaysia took one step closer to completion with the completion of the onshore fabrication and commissioning of the Malikai TLP. Operations are expected to commence in 2017 on schedule, with peak production of 60,000 b/d, opening up a new forefront of deepwater development in Malaysia.

  5. Vladimir Putin is reportedly weighing selling part of Rosneft and other government-owned oil ‘jewels’ to China and India as the Russian governments attempt to cover budget shortfalls triggered by falling oil prices and tensions with the EU and US over geopolitical interventions ahead of his re-election in two years.

  6. Gazprom has abandoned attempts to expand crude deliveries to India, due to ‘difficult’ logistics but left the door open if market conditions improve.

  7. In more Russia-Asian news, Vietnam’s PV Oil secured a long-term crude contract with Rosneft last week. PV Oil is the subsidiary of PetroVietnam that handles crude sourcing for Vietnam’s sole refinery Dung Quat, and also lifts refined products from the refinery.

  8. Indonesia is at it again; Pertamina has announced that it intends to build two new refineries of 300 kb/d each by 2023 to ease the country’s chronic oil product import issue. One of them will be the Tuban refinery, in partnership with Russia’s Rosneft, while Pertamina is still searching for a partner for its planned Bontang site. 

  9. As the world’s largest imported of natural gas, Japan is attempted to use the current supply glut as an opportunity to rewrite the rules of Asian natural gas pricing. Japan, which traditionally pays huge premiums for LNG, wants to move Asian LNG pricing away from the rigid, opaque market based on individual contract pricing towards embracing Japan as a trading hub where prices are set on the market. Part of this will include removing restrictions on reselling LNG cargoes; Tokyo Electric Power and Chubu Electric signed Japan’s first resale deal last month.

  10. India’s GAIL is looking at re-aligning the route of a proposed gas pipeline in the state of Tamil Nadu to run in parallel to motor highways. Debates over the course of the pipeline have hindered the start-up of the Petronet’s Kochi LNG terminal, which opened three years ago.

  11. The cost of falling oil prices has been tabulated: consulting firm Wood Mackenzie estimates that the upstream industry has responded by cancelling and deferring projects to the tune of some US$740 billion over 2015-2020 since crude prices first starting tumbling in Q42014

  12. The fires have been put out; after wildfires in Alberta sent Canadian oil sands production way down last month, producers have returned and the IEA expects Canadian production to return to normal by mid-July, removing a supply factor that has supported stronger prices recently.

  13. There was only a single attack by the Niger Delta Avengers in Nigeria last week – on June 16 at the NNPC Oruk Anam crude pipeline – as the military thwarted a planned sabotage at an Eni pipeline and arrested 19 suspects, fighting back against the sustained disruption that has made Nigeria the third most expensive country in which to produce oil.

  14. The US oil rig count rose up again last week, with nine more sites coming online, bringing the total number t o 337. All of the gains are coming from onshore projects – offshore rigs remain static at 21. The gas rig count rose by one to 86.

  15. Lukoil is reportedly looking into spinning off or selling its downstream assets in Western Europe, as improving crude prices is pushing the Russian giant to focus on expanding upstream at home and abroad. Lukoil has some refining assets in Italy and the Netherlands, as well as a retail network across east Europe.

  16. The trend back to upstream is echoed by other oil majors, with Chevron and Shell both putting some of their smaller refineries – Chevron’s Burnaby in Canada and Shell’s Martinez in California – up for sale, am attempt to rationalise their downstream portfolio.

  17. Russia’s Gazprom and Belgium’s Fluxys are in discussions to develop LNG facilities across western Europe, including LNG bunkering, as Europe’s appetite for LNG increases and more import facilities are required. 

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Nigeria’s Energy Focus Must Change From Crude Oil to Gas – Dr Chukwueloka Umeh

According to the Nigeria National Petroleum Corporation (NNPC), Nigeria has the world’s 9th largest natural gas reserves (192 TCF of gas reserves). As at 2018, Nigeria exported over 1tcf of gas as Liquefied Natural Gas (LNG) to several countries. However domestically, we produce less than 4,000MW of power for over 180million people.

Think about this – imagine every Nigerian holding a 20W light bulb, that’s how much power we generate in Nigeria. In comparison, South Africa generates 42,000MW of power for a population of 57 million. We have the capacity to produce over 2 million Metric Tonnes of fertilizer (primarily urea) per year but we still import fertilizer. The Federal Government’s initiative to rejuvenate the agriculture sector is definitely the right thing to do for our economy, but fertilizer must be readily available to support the industry. Why do we import fertilizer when we have so much gas?

I could go on and on with these statistics, but you can see where I’m going with this so I won’t belabor the point. I will leave you with this mental image: imagine a man that lives with his family on the banks of a river that has fresh, clean water. Rather than collect and use this water directly from the river, he treks over 20km each day to buy bottled water from a company that collects the same water, bottles it and sells to him at a profit. This is the tragedy on Nigeria and it should make us all very sad.

Several indigenous companies like Nestoil were born and grown by the opportunities created by the local and international oil majors – NNPC and its subsidiaries – NGC, NAPIMS, Shell, Mobil, Agip, NDPHC. Nestoil’s main focus is the Engineering Procurement Construction and Commissioning of oil and gas pipelines and flowstations, essentially, infrastructure that supports upstream companies to produce and transport oil and natural gas, as well as and downstream companies to store and move their product. In our 28 years of doing business, we have built over 300km of pipelines of various sizes through the harshest terrain, ranging from dry land to seasonal swamp, to pure swamps, as well as some of the toughest and most volatile and hostile communities in Nigeria. I would be remiss if I do not use this opportunity to say a big thank you to those companies that gave us the opportunity to serve you. The over 2,000 direct staff and over 50,000 indirect staff we employ thank you. We are very grateful for the past opportunities given to us, and look forward to future opportunities that we can get.

CLICK HERE TO READ MORE

July, 19 2019
Your Weekly Update: 15 - 19 July 2019

Market Watch 

Headline crude prices for the week beginning 15 July 2019 – Brent: US$66/b; WTI: US$59/b

  • Global oil prices gained as US crude inventories shrank more than expected and a hurricane in the Gulf of Mexico threatened American offshore production
  • Tropical Storm Barry – which became a hurricane on landfall in Louisiana – was in the path of up to a third of Gulf of Mexico crude output, prompting producers to shut down most of their operations; resumption of normal service has begun
  • At the same time, US crude oil stockpiles fell by almost 10 million barrels, far more than expected, with US refineries ramping up production ahead of summer demand to add some bullishness to the market
  • The ongoing tensions between the US and Iran have not escalated further yet, but Iran has vowed to continue retaliating against the British seizure of its crude tanker in the Mediterranean off Gibraltar
  • These factors have been enough to keep current crude prices trending higher, but oil producing club OPEC warns that the market will swing back into surplus next year, estimating that it is currently producing 560,000 b/d more than will be needed without even factoring in rising US shale production
  • In Venezuela, where oil production has been crippled by sanctions, Chevron is reportedly seeking a waiver to continue operating in the country after the current waiver expires in July 27
  • The US active oil and gas rig count fell once again, shedding a net five rigs (including 4 oil rigs) as merely stable prices reduced the appetite for investment; the total active rig count is now 958, 96 sites lower than this period last year
  • As the threat of Tropical Storm Barry abated, crude prices fell back in line. Without any further disruptions on the horizon, Brent should trend in the US$62-64/b range and WTI in the US$55-57 range


Headlines of the week

Upstream

  • Norway’s Equinor has bought a 16% stake in Swedish upstream firm Lundin Petroleum for US$650 million, which gains it an additional 2.6% interest in the giant Johan Sverdrup oil field bringing Equinor’s total stake up to 42.6%
  • Inpex has picked up the exploration permit for Block AC/P66 in Australia’s Northwest Shelf, which lies in the vicinity of existing promising oil fields
  • US independent Callon Petroleum Company has acquired Carrizo Oil & Gas for US$3.2 billion, deepening its holdings in the Permian and Eagle Ford shale basins, including 90,000 net acres in the prolific Delaware Basin
  • Total has agreed to divest several of its non-core assets in the UK – covering the Balloch, Dumbarton, Lochranza, Drumtochty, Flyndre, Affleck, Cawdow, GoldenEagle, Scott and Telford fields – to Petrogas NEO for US$635 million
  • CNOOC and Sinopec has signed a new agreement to collaborate on exploration activities in the Bohai Basin, Beibu Gulf, North Jiangsu and South Yellow Sea
  • Murphy Oil has completed the sale of its Malaysian upstream assets to a unit of Thailand’s PTTEP for US$2.035 billion for five offshore projects in Sabah
  • Seven upstream discoveries were made in Colombia in 2Q19, making it the market with the most discoveries during the period, leading India, Russia and Pakistan which each made three new oil and gas finds
  • Turkey has vowed to continue drilling offshore Cyprus unless a cooperation proposal between Turkish and Greek Cypriots is accepted
  • Encana is reportedly selling off its assets in eastern Oklahoma’s Arkoma Basin for US$165 million in cash to an undisclosed buyer
  • Sinopec is hunting for partners or buyers for its Buck Lake assets in Alberta’s Duvernay shale basin in Canada, to reduce its current full ownership

Midstream/Downstream

  • The Governor of Pennsylvania Tom Wolf has ruled out using state funds to save the Philadelphia Energy Solutions refinery after it was shuttered following a massive fire that took out the entire site last month
  • Blackouts hit Venezuela’s Amuay and Cardon refineries, bringing the 955,000 b/d Paraguana refining Center to a complete halt on total lack of power
  • Chevron Phillips Chemical (CP Chem) and Qatar Petroleum have agreed to develop a new 2 mtpa petrochemical complex on the US Gulf Coast, with the US Gulf Coast II Petrochemical Project drawing on NGLs from the Permian
  • Marathon Petroleum will shut down the gasoline FCCU unit at its 585,000 b/d Galveston Bay Refinery in Texas for up to 8 weeks for repairs

Natural Gas/LNG

  • Total has agreed to buy NG from Tellurian’s Driftwood LNG facility in Lake Charles, Louisiana in two separate deals – 1 million tons per annum for Total Gas & Power North America and 1.5 mtpa for Total Gas & Power – as well as invest US$500 million in Driftwood Holdings LP
  • Mozambique has put on hold plans to raise funds for its stake in the Anadarko-led Mozambique LNG project, citing current bad market conditions
  • ExxonMobil and Lucid Energy Group have agreed to collaborate on a long-term natural gas gathering and processing project, bringing natural gas from New Mexico’s Delaware Basin to the South Carlsbad gas processing system before being delivered to ExxonMobil’s downstream facilities in the US Gulf Coast
July, 19 2019
Iran drives unplanned OPEC crude oil production outage to highest levels since late 2015

Unplanned crude oil production outages for the Organization of the Petroleum Exporting Countries (OPEC) averaged 2.5 million barrels per day (b/d) in the first half of 2019, the highest six-month average since the end of 2015. EIA estimates that in June, Iran alone accounted for more than 60% (1.7 million b/d) of all OPEC unplanned outages.

EIA differentiates among declines in production resulting from unplanned production outages, permanent losses of production capacity, and voluntary production cutbacks for OPEC members. Only the first of those categories is included in the historical unplanned production outage estimates that EIA publishes in its monthly Short-Term Energy Outlook (STEO).

Unplanned production outages include, but are not limited to, sanctions, armed conflicts, political disputes, labor actions, natural disasters, and unplanned maintenance. Unplanned outages can be short-lived or last for a number of years, but as long as the production capacity is not lost, EIA tracks these disruptions as outages rather than lost capacity.

Loss of production capacity includes natural capacity declines and declines resulting from irreparable damage that are unlikely to return within one year. This lost capacity cannot contribute to global supply without significant investment and lead time.

Voluntary cutbacks are associated with OPEC production agreements and only apply to OPEC members. Voluntary cutbacks count toward the country’s spare capacity but are not counted as unplanned production outages.

EIA defines spare crude oil production capacity—which only applies to OPEC members adhering to OPEC production agreements—as potential oil production that could be brought online within 30 days and sustained for at least 90 days, consistent with sound business practices. EIA does not include unplanned crude oil production outages in its assessment of spare production capacity.

As an example, EIA considers Iranian production declines that result from U.S. sanctions to be unplanned production outages, making Iran a significant contributor to the total OPEC unplanned crude oil production outages. During the fourth quarter of 2015, before the Joint Comprehensive Plan of Action became effective in January 2016, EIA estimated that an average 800,000 b/d of Iranian production was disrupted. In the first quarter of 2019, the first full quarter since U.S. sanctions on Iran were re-imposed in November 2018, Iranian disruptions averaged 1.2 million b/d.

Another long-term contributor to EIA’s estimate of OPEC unplanned crude oil production outages is the Partitioned Neutral Zone (PNZ) between Kuwait and Saudi Arabia. Production halted there in 2014 because of a political dispute between the two countries. EIA attributes half of the PNZ’s estimated 500,000 b/d production capacity to each country.

In the July 2019 STEO, EIA only considered about 100,000 b/d of Venezuela’s 130,000 b/d production decline from January to February as an unplanned crude oil production outage. After a series of ongoing nationwide power outages in Venezuela that began on March 7 and cut electricity to the country's oil-producing areas, EIA estimates that PdVSA, Venezuela’s national oil company, could not restart the disrupted production because of deteriorating infrastructure, and the previously disrupted 100,000 b/d became lost capacity.

July, 18 2019