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Market Watch

Headline crude prices for the week beginning 7 May 2017 – Brent: US$76/b; WTI: US$70/b

  • WTI crude breached the US$70/b mark for the first time in four years, with the main topic being the US decision to re-impose sanctions on Iran, thereby pulling out of the nuclear deal that the EU has been trying to save.
  • Increasing trouble at PDVSA – which a former official opined could be ‘going down’ - has also stoked worries about the shock to the market.
  • By Tuesday, President Trump confirmed that he was leaving the Iran nuclear deal – calling it an ‘embarrassment’ and re-imposing sanctions, with the EU mulling moves that could insulate it from the impact of the new sanctions.
  • Though it is unknown how strict the new sanctions will be, there will be a timeline for 180 days before the strictest measure – targeting international banks – can be applied. Analysts believe Iranian exports could be cut by 200-300,000 b/d as a result.
  • In the US, production continues to surge as the EIA confirms that American output hits 10.26 mmb/d in February.
  • Meanwhile, nine new oil rigs entered service in the US last week, bringing the oil rig total up to 834, with six of the increases being in the Permian as US drillers respond to the new average price of US$70/b for crude.
  • Crude price outlook: The deteriorating outlook for the Iran deal will keep crude prices at their current levels. Expect Brent to trade at US$74-75/b and WTI/Shanghai to US$68-69/b.

Headlines of the week

Upstream

  • Spain’s Repsol has officially requested for compensation from PetroVietnam and Vietnamese authorities over the suspension of its oil project in the offshore Red Emperor block over Chinese pressure.
  • Iraq’s North Oil Company and the UK’s BP have signed an agreement to triple the output of the former’s Kirkuk oil fields to 1 mmb/d, as the Iraq central government capitalises on recapturing the fields from the KRG.
  • Brent cargoes for May and June deliveries have been delayed by a shutdown at the Sullom Voe oil terminal in the UK; some 100,000 barrels of crude scheduled for May loading are expected to be affected.
  • The hits keep coming in Egypt, as Eni announced a new oil discovery – the third in a month – at the A-2X prospect in the Western Desert’s South West Meleiha licence. Early tests point to 2,300 barrels of light oil per day.
  • Brazil has proposed September 28 for its planned fifth auction of oil blocks, which include the pre-salt offshore plays in the Saturno, Tita, Pau-Brasil and Tartaruga Verde fields in the Campos and Santos basin.
  • Between ExxonMobil and Chevron, some 50 drilling rigs by American supermajors will start up in the US Permian shale play this year.
  • Indonesia has secured operators for four of the five direct tender blocks offered earlier this year, with Eni taking the East Ganal block in the Kutei basin, while Repsol, Lion Energy and local players took the rest.

Downstream

  • US refiner Marathon Petroleum has agreed to buy rival Andeavor for US$23.3 billion, creating the largest independent refiner in the US.
  • Nigeria’s Forte Oil plans to divest its upstream and power businesses in the country as well as its downstream unit in Ghana, as the private firm reorganises to focus on retail fuel distribution in its home market.
  • Peru has revived plans for a petrochemical plant in southern Peru – fed by a natural gas pipeline – after the plan to expand its downstream industries was derailed by the corruption scandal engulfing Brazil’s Odebrecht.

Natural Gas/LNG

  • Russia’s Gazprom has unveiled a plan for a US$5 billion gas processing plant near St. Petersburg, which would serve as an alternative outlet if its proposed Nord Stream 2 gas pipeline project is axed by the EU.
  • BP expects to take FID on Phase 1 of its Tortue-Ahmeyim gas project offshore Senegal and Mauritania by the end of this year.
  • China’s CNOOC has set itself a target to increase LNG imports by 20% in 2018 – roughly 25 million tons from 20.46 million tons in 2017 – to power the country’s push to move towards cleaner energy.
  • Italy’s Eni is launching a study on a possible LNG terminal in the Barents Sea off Norway to exploit its recent gas discoveries in the Arctic region.
  • Iran has warned that Total is at risk of losing its stake in the South Pars natural gas field to Chinese partner CNPC. The French company is forced to withdraw from Iran by the US decision to re-impose sanctions.
  • Running out of gas at home, Thailand’s PTTEP is attempting exploration drills in north Australia’s Cash-Maple area to support new LNG volumes.
  • BP has set itself an ambitious target of boosting its LNG portfolio volumes to 25 million tons per year as it plays catch-up with Shell.

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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