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Last Updated: November 3, 2017
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Last week in the world oil:

Prices

  • As signs points to OPEC and Russia extending their production cuts beyond March 2018, crude oil prices surged to their highest level since July 2015, with Brent hitting, and staying above, US$60/b. WTI remains strong as well, as American crude exports hit an all-time high.

Upstream

  • Brazil has allowed private companies to operate pre-salt acreage for the first time, handing out eight offshore blocks to international supermajors and their partners. Previously, Petrobras was required to participate in all pre-salt blocks, but reforms have allowed private companies to lead searches. Shell walked away with three blocks, BP two and ExxonMobil one, with two more blocks yet to be awarded.
  • With the situation in Kirkuk now largely settled, Iraq’s North Oil Co is now working with the Kurdish Kar Group to resume production at two oil fields. Lying within disputed areas, the Bai Hassan and Avana oil fields halted production during the Baghdad-led offensive to retake Kirkuk from Kurdish troops. This could restore some 275,000 barrels of production, which might dent OPEC’s current efforts to bolster crude prices.
  • Canada’s Suncor reports that it was making progress in resolving a dispute with Total over their joint venture Fort Hills oil sands project in Alberta. Total has refused to provide more funding for Fort Hills, the last of the major oil sands projects to be developed, and resolving the dispute paves the way for the 190 kb/d project to start up in Q418.
  • The US lost another four active rigs last week, with a lone oil addition outweighed by the loss of five gas rigs. Rigs have been on a declining trend, but with crude prices rising, some additions are expected.

Downstream & Midstream

  • The US Commerce Department confirmed that it would be moving ahead with anti-dumping duties on biodiesel imports from Argentina and Indonesia, recommending import taxes of up to 70.05% for Argentina and 50.71% for Indonesia. Argentina has already indicated that it is opening up negotiation channels to suspend the duties in favour of a mutual deal.

Natural Gas and LNG

  • More delays are expected at Algeria’s southern Touat gas field, with startup delayed until Q118. Sonatrach reports that only 3 of 21 wells are ready to come online, hampering the country’s goal to boost annual gas production to 95 bcm, of which more than half is targeted as exports.
  • As it prepares for startup of commercial deliveries, Russia’s Yamal LNG project announced that its debut cargo would be sent to China as a ‘symbolic point’. CNPC bought a 20% stake in the project last year, putting it back on track after US sanctions. Novatek has also signed an MoU with China Development Bank to develop the Arctic LNG 2 project – which will develop the Utrenneye field on the Gydan Peninsula in West Siberia.
  • Dominion’s Cove Point LNG terminal on the US East Coast is expected to start production next month, becoming the second official American LNG exporter after Cheniere. The Maryland terminal has long-term supply agreements with India’s GAIL and a joint venture between Sumitomo and Tokyo Gas, which will leave little room for spot cargo sales.

Last week in Asian oil

Upstream

  • Singapore’s KrisEnergy will be moving ahead with Phase 1A of the Apsara oil field in Cambodia, signing off on the FID last week. The offshore field in the Gulf of Thailand will be Cambodia’s first oil-producing asset, with KrisEnergy planning a single, unmanned facility with processing capacity for 30,000 b/d of fluids. KrisEnergy holds a 95% stake in Block A, with the Cambodian government holding the remaining 5%.

Downstream

  • As India continues to vastly expand energy capacity, Kuwait’s Al Arfaj Group has announced plans to build a 600 kb/d oil refinery in the coastal state of Andra Pradesh. An MoU has been signed with Andhra Pradesh’s Economic Development Board, which will also include a petrochemical complex. A mega 10 mtpa LNG terminal is also being planned within the same energy complex. A timeline has not yet been announced, but the scale of the project suggests a provisional startup date beyond 2022.
  • India’s HPCL-Mittal is planning to start its naphtha cracker in 2021, part of a US$3 billion plan to set up a petrochemical complex at the joint venture’s refinery in Bhatinda, Punjab. HPCL and Mittal Energy Investments each own 49% in the project, with capacity at the refinery recently raised by 28% to 230 kb/d. The cracker will have an initial capacity of 1.2 mtpa, and is planned to absorb all naphtha output from the refinery, halting further naphtha exports.

Natural Gas & LNG

  • In an unusual reversal, Chevron has decided to stay in Bangladesh. The US supermajor had originally planned to sell its three subsidiaries to China’s Himalaya Energy and exit natural gas production in Bangladesh, prompting state energy firm PetroBangla to demand the gas blocks be handed over to it. No reason was given for the reversal, and instead Chevron has pledged to invest some US$400 million in Bibiyana, Bangladesh’s largest gas field, and will remain the country’s largest gas producer, at some 58% of domestic output.
  • In an echo of its oil industry, Pertamina now projects that Indonesia will become a net importer of LNG in 2020. This will expand to a deficit of 4 billion bcf/d by 2030, as population increases and industrial expansion boost gas demand, particularly in Java, where most of the population resides. Efforts to introduce flexibility and more investor-friendly terms for upstream production have failed to boost upstream oil and gas production; Indonesia became a net importer of oil in 2008, forcing it to leave OPEC, and that has now spread to gas – see the protracted development of East Natuna and Masela-Abadi LNG projects. The key point that scuppers many potential deals is Indonesia’s DMO (Domestic Market Obligation) that channels oil and gas output to domestic use, but is generally set at levels that dissuade international investors.
  • Petronas has signed a new LNG supply agreement with JERA, the fuel purchasing joint venture between Tokyo Electric Power and Chubu Electric Power. But instead of the previous 15-year contract, which expires next year, JERA has opted for a three-year contract for 2.5 mtpa, foretelling the advent of shorter and smaller contracts. This is the first LNG contract signed by JERA since the Japan Free Trade Commission ruled destination clauses to be anti-competitive in July this year.

State energy firm Indian Oil announced plans to develop 13.5 mtpa of LNG import capacity by 2021, in line with the government’s goal of raising natural gas share in the national energy mix to 15%, from a current 6.5%. IndianOil currently imports LNG through the Petronet LNG Dahej terminal in western Gujarat, and has plans to build its own regasification facility and invest in others.

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New PNG Government Reviews Past Oil Agreements

A lot of complications arise when a government changes. Particularly if the new government comes in on a mandate to reverse alleged deficiencies and corruption of previous governments. This is amplified when significant natural resources are involved. It has happened in the past – when Iran nationalised its oil industry by kicking out BP – and it could happen again in the future – in Guyana where the promise of oil riches in the hands of foreign firms has already caused grumbles. And it is also happening right now in Papua New Guinea, as the new government led by Prime Minister James Marape took aim at the Papua LNG deal.

Negotiated by the previous government of Peter O’Neill, the state’s new position that is the current gas deal is ‘disadvantageous’ to country. A complex set of manoeuvres – accusing O’Neill of multiple levels of corruption – led to a proposed vote of no confidence and an eventual resignation. With the departure of O’Neill, public opinion on the Papua LNG project (as well as the PNG LNG project) switched from being viewed as a boon to the economy to one of unequal terms that would not compensate the nation fairly for its resources.

So, despite a previous assurance in early August that the new government of Papua New Guinea would stand by the previous gas deal agreed with the Papua LNG stakeholders in April, Marape sent a team led by the Minister of Petroleum Kerenga Kua to Singapore to renegotiate with the project’s lead operator Total.

As the meeting was announced, suggestions pointed to a hardline position by Papua New Guinea… that they could ‘walk away from a new deal’ if the new terms were not acceptable. In a statement, Kua stated that the negotiations could ‘work out well or even disastrously’. From Total’s part, CEO Patrick Pouyanne said in July that he expected the government to respect the gas deal while Oil Search stated that it was seeking ‘further clarity on the state’s position’. The gas deal covers framework of the Papua LNG project, which was scheduled to enter FEED phase this year with FID expected in 2020, drawing gas from the giant onshore Elk-Antelope fields ahead of planned first LNG by 2024. So, the stakes are high.

With both sides locked into their positions, reports from Singapore suggested that the negotiations broke down into a ‘Mexican standoff’. No grand new deal was announced, and it can therefore be inferred that no progress was made. There is a possibility that PNG could abandon the deal altogether and seek new partners under more favourable terms, but to do so would be a colossal waste of time, given that Papua LNG is nearing a decade in development. Total and ExxonMobil have already raised the possibility of legal moves if the deal is aborted, with compensation running into billions – billions that the PNG government will not have unless the Papua LNG project goes ahead.

But the implications of the deal or no-deal are even wider. The PNG state has already stated that it will look at the planned expansion of the PNG LNG project (led by ExxonMobil and Santos) next, which draws from the P’nyang field. Renegotiation of the current gas deals in PNG may have populist appeal but have serious implications – alienating two of the largest oil and gas supermajors and two of PNG’s largest foreign investors could lead to a monetary gap and a mood of distrust that PNG may be unable to ever fill. Hardline positions are a good starting position, but eventual moderation is required to ever strike a deal.

Papua LNG Factsheet:

  • Ownership: Total (31.1%), ExxonMobil (28.3%), Oil Search (17.7%), state (22.5%)
  • Feed: Elk-Antelope onshore fields,
  • Capacity: 5.4 million tons per annum
  • Structure: 2 trains of 2.7 mtpa capacity each
August, 22 2019
This Week in Petroleum: 2018 OPEC net oil export revenues highest since 2013, but likely to decline

The U.S. Energy Information Administration (EIA) estimates that members of the Organization of the Petroleum Exporting Countries (OPEC) earned almost $711 billion in net oil export revenues in 2018 (Figure 1). The estimate is up 29% from 2017, but about 40% lower than the record high of almost $1,200 billion in 2012. The 2018 earnings increase is mainly a result of higher crude oil prices. The Brent spot price rose from an annual average of $54 per barrel (b) in 2017 to $71/b in 2018. However, EIA forecasts annual OPEC net oil export revenues will decline to $593 billion in 2019 and to $556 billion in 2020. Decreasing OPEC revenues are primarily a result of decreasing production among a number of OPEC producers.

Figure 1. OPEC net oil export revenues

EIA estimates net oil export revenues based on oil production—including crude oil, condensate, and natural gas plant liquids—and total petroleum consumption estimates, as well as crude oil prices forecast in the August 2019 Short-Term Energy Outlook (STEO). EIA’s net oil export revenues estimate assumes that exports are sold at prevailing spot prices and adjusts the prices for benchmark crude oils forecast in STEO (Brent, West Texas Intermediate, and the average imported refiner crude oil acquisition cost) with historical price differentials among spot prices for the different OPEC crude oil types. For countries that export several different varieties of oil, EIA assumes that the proportion of total net oil exports represented by each variety is the same as the proportion of the total domestic production represented by that variety. For example, if Arab Medium represents 20% of total oil production in Saudi Arabia, the estimate assumes that Arab Medium also represents 20% of total net oil exports from Saudi Arabia.

Although OPEC net export earnings include estimated Iranian revenues, they are not adjusted for possible price discounts that trade press reports indicatedIran may have offered its customers after the United States announced its withdrawal from the Joint Comprehensive Plan of Action in May 2018. The United States reinstated sanctions targeting Iranian oil exports in November 2018. Similarly, EIA does not adjust for Venezuelan crude oil exports to China or India for volumes that are sent for debt repayments to China and Russian energy company Rosneft, respectively, and thus do not generate cash revenue for Venezuela.

If the $711 billion in net oil export revenues by all of OPEC is divided by total population of its member countries and adjusted for inflation, then per capita net oil export revenues across OPEC totaled $1,416 in 2018, up 26% from 2017 (Figure 2). The increase in per capita revenues likely benefited member countries that rely heavily on oil sales to import goods, fund social programs, and otherwise support public services.

Figure 2. OPEC real net and per capita oil export revenues

In addition to benefiting from higher prices, some OPEC member countries have increased export revenues by reducing domestic consumption and consequently exporting more. For example, Saudi Arabia has significantly reduced the amount of crude oil burned for power generation. Limiting crude oil burn allowed Saudi Arabia to export more crude oil and to maximize revenues.

Others have been able to charge higher premiums based on the quality of their crude oil streams. As the global slate of crude oil has changed with more light crude oil production (with higher API gravity), OPEC members have benefited from a narrowing price discount for their heavy crude oils, which are typically priced lower than lighter crude oils because of quality differences. Smaller discounts for OPEC members’ heavier crude streams contributed to higher spot prices for the OPEC crude oil basket price, which incorporates spot prices for the major crude oil streams from all OPEC members (Figure 3).

Figure 3. Gasoline crack spreads (250-day moving average)

Despite the increase in annual average crude oil prices in 2018, OPEC revenues fell during the second half of 2018, mainly because of lower production and export volumes from Iran and Venezuela (Figure 4). EIA estimates that OPEC total petroleum liquids production decreased slightly in 2018 when increased production in Saudi Arabia, Iraq, and Libya could not offset significant declines in Iranian and Venezuelan production. Combined crude oil production in Iran and Venezuela fell by almost 800,000 barrels per day (b/d), or 14%, in 2018 and again by over 1.0 million b/d in the first seven months of 2019. Although Iranian net oil export revenues increased by 18% from 2017 to 2018, a year-to-date comparison indicates a significant decrease in revenues in 2019 (Figure 4). EIA estimates that from January to July 2018, Iran received about $40 billion in export revenues, compared with an estimated $17 billion from January to July 2019. Further decreases in OPEC members’ production beyond current EIA assumptions would further reduce EIA’s OPEC revenue estimates for 2019 and 2020.

Figure 4. Number of days Singapore had the highest and lowest gasoline crack spread among global refining centers

U.S. average regular gasoline and diesel prices fall

The U.S. average regular gasoline retail price fell nearly 3 cents from the previous week to $2.60 per gallon on August 19, 22 cents lower than the same time last year. The Gulf Coast price fell nearly 6 cents to $2.27 per gallon, the East Coast price fell nearly 4 cents to $2.52 per gallon, the West Coast and Rocky Mountain prices each fell nearly 2 cents to $3.24 per gallon and $2.67 per gallon, respectively, and the Midwest price fell nearly 1 cent, remaining at $2.52 per gallon.

The U.S. average diesel fuel price fell nearly 2 cents to $2.99 per gallon on August 19, 21 cents lower than a year ago. The Midwest price fell over 2 cents to $2.90 per gallon, the West Coast and East Coast prices each fell nearly 2 cents to $3.56 per gallon and $3.02 per gallon, respectively, the Gulf Coast price fell more than 1 cent to $2.75 per gallon, and the Rocky Mountain price fell less than 1 cent, remaining at $2.94 per gallon.

Propane/propylene inventories rise

U.S. propane/propylene stocks increased by 4.0 million barrels last week to 90.5 million barrels as of August 16, 2019, 10.2 million barrels (12.7%) greater than the five-year (2014-18) average inventory levels for this same time of year. Gulf Coast, East Coast, Midwest, and Rocky Mountain/West Coast inventories increased by 2.0 million barrels, 1.0 million barrels, 0.7 million barrels, and 0.4 million barrels, respectively. Propylene non-fuel-use inventories represented 4.4% of total propane/propylene inventories.

August, 22 2019
The Australian 590 Student Guardian Visa Process In A Nutshell

Student guardian visa subclass 590 allows you to stay in Australia as a guardian or custodian or relative of an overseas student who is pursuing an education course in Australia. With 590 student guardian visa, You can stay with your child to take care of him/her in Australia until the course complete. Your child age must below then 18th years old before applying for a student guardian visa 590. If you're a relative then you can stay with the child by submitting written permission of a child’s caretakers like a guardian or grandparents. If your child is older then eighteen years then to apply for visa subclass 590 you need to show that you have special emergency circumstances. You can apply for a 590 student guardian visa outside from Australia and acquire enrollment in alternative courses up to three months with a 590 visa. You will be authorized to take care more then one child if you have. You can do the other study or coach just for 3 months with this Student Guardian Visa Subclass 590

Step By Step Process About 590 Visa

1.Before Applying for Visa

Meet Eligibility Criteria

    • You must be a parent or grandparents or relative of a non-Australian child who is below 18th of age.

    • If you want to apply from inside of Australia then you need to hold a substantive visa except for domestic worker, temporary work visa, transit visa, visitor visa, etc.

    • If your another child who is below 18th and not coming to Australia with you then you need to give evidence that you have made welfare arrangement for the child.

    • You have to account for your all healthcare expenses so make sure that medical insurance can only reduce your expenses.

    • Your past immigration history must be credible like you must not have any visa cancellation history.

    • Your intention should be genuine at the time of applying for student guardian visa 590 and it should be not against Australian culture and policies.

    • If your family members are also applying with you then they also need to meet health policies of the Australian government

    • Only a parent or grandparents or custodian or step parents of an overseas student visa 500 holder can apply for this student guardian visa subclass 590.

    • If parents are not present due to any reason for looking after the visa subclass 500 holder student then any relative can apply for this 590 student guardian visa. 

    • You must be a guardian of an international student who must be below 18th of age except for exceptional circumstances.

    • You have to give assurance to immigration authorities that you will be able to provide welfare.

    • Your age must be above 21 years old before going to apply for a student guardian visa 590.

    • You have to pay back any type of debt to the Australian government if you have.

    • If you have another child aged 6 years old then you can bring him/her to Australia but if your child if older then 6           years then you need to show emergency condition to bring him/her to Australia.

  Collect Documents

    •Provide character certificate and other national identities.

    •Submit bank documents and salary slips to prove that you will be enough capable to give welfare to the student.

    •Provide guardianship documents to prove your credibility to that child.

    •Translate your non-English documents into English.

    •Submit legal student guardianship form.

    •Provide dependent under 6 documents if you bring your child who is under 6 years of age.

2. Processing Time And Cost Of This Visa

Visa subclass 590 cost starts from AUD 560. This visa 590 may proceed in 2 to 4 months. But in case you forget to submit any documents then you processing time of visa can be increased. Your visa application processing time can be increased if you provide incomplete information.

3. Apply For The Visa

You need to apply online for the 590 student guardian visa 6 weeks before the student’s course starts. At the time applying for the visa, you have to prove that you are genuine and legal applicant by submitting legal documents. If you submit illegal information to immigration authorities then they have the authority to cancel your visa application immediately. You and your relative which is listed in visa application will not able to get a visa for the next 10 years in case of any fraud by you. You should contact an experienced Immigration Agent Adelaide.

4. Conditions After You Have Applied For The Visa

    • You are not allowed to do any type of work in Australia.

    • You can study only for 3 months.

    • With visa subclass 590 you can’t apply for another visa

    • At the time of leaving Australia, you must have brought the student to your country.

    • If you have another child who is below 6th years of age then you can bring him/her to Australia.

Get The Direction To Migration Agent Adelaide - ISA Migrations and Education Consultants.



August, 21 2019