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Last Updated: September 21, 2017
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Last week in World Oil:

Prices

  • Oil prices remain close to multi-month highs as the market assesses the impact of two recent major hurricanes, as well as indications that OPEC is considering extending the current supply freeze deal beyond March 2018. Brent is trading at about US$55/b, while WTI stands at about US$50/b.

Upstream

  • Uganda has signed the first exploration deal from its 2015 licensing round. Australia’s Armour Energy will be allowed to explore the Kanywataba block in the Albertine rift valley near the Democratic Republic of Congo. The block had previously been licensed to Total, CNOOC and Tullow Oil, which surrendered the block in 2012. Deals for the remaining five blocks offered at auction have yet to be finalised.
  • After acquiring exploration rights in Mexico’s first-ever deepwater auction in 2016, CNOOC is now searching for partners in a ‘farmout’ proposition that will offer a stake in return with drilling and production assistance. CNOOC holds the rights to two Gulf of Mexico blocks in the Perdido Fold Belt, where Mexico estimates the bulk of its untapped oil lies. One of the deepest exploration areas in the world, CNOOC cannot afford to go it alone, and is soliciting potential partners for the projects.
  • US drillers shut down seven oil rigs last week – the steepest cut since January 2017 – the latest indication that drilling recovery has stalled.  

Downstream & Midstream

  • The series of earthquakes roiling Mexico over the past two weeks has Wrecked Pemex’s refining network, causing fuel shortages and driving up price, which are no longer state-controlled. Output from three of its six refineries has been affected, removing up to 50% of national capacity. With Mexico’s nearest source of fuel imports – the US – also recovering from Hurricane Harvey, the tight situation could continue for a while.

Natural Gas and LNG

  • Nexen is shelving its proposed Aurora LNG export terminal on Canada’s west coast, citing a poor market environment and low prices. Owned by CNOOC since 2012, Nexen has been conducting a feasibility study into the project for four years, finally pulling out as global LNG prices do not look likely to gain strength for the foreseeable future. The project, with a capacity of 24 mtpa of LNG, is the third Canadian project to be cancelled, after the Petronas and Shell projects. With the political situation in British Columbia currently unfavourable to LNG projects, it appears that Canada’s ambitions to be a major LNG supplier to Asia is diminished.
  • Nigeria’s Shoreline has signed a US$300 million agreement with Shell to develop commercial natural gas infrastructure around Lagos. In line with Shell’s objective to focus more on gas than oil in Nigeria, the deal will be the two companies work together on developing distributing and selling piped natural gas to the city’s Victoria Island, Ikoyi, Lekki and Epe district, which constitute Lagos’ business hub and upscale residential areas.
  • Premier Oil will be selling off half of its stake in the North Sea’s Babbage gas field, as well as a 25% stake in the Cobra field, as it attempts to pare down debt accrued over the past three years. Both assets were gained last year through its US$120 million acquisition of E.ON’s North Sea business.

Last week in Asian oil

Upstream

  • Italy’s Eni has signed a cooperation agreement with China’s CNPC, a move that could give the firm a greater foothold in the Chinese market. The broad agreement covers joint activities in upstream E&P, as well as LNG, trading, refining and petrochemicals – both within China and abroad. For Eni, this boosts its financial firepower as it looks to expand activities globally, while CNPC will have the benefit of an established partner with a long global history to help expand its international ambitions. This isn’t the first time both companies have worked together; in 2013, CNPC bought a 20% stake in Eni’s gas field offshore Mozambique – planned to eventually produce LNG for export to Asia – while both firms are also shareholders in Kazakhstan’s giant Kashagan oil field.
  • After a century of producing oil in Iraq, Shell is forsaking oil in favour of gas, citing low-margin production contracts. Shell will relinquish operations at the Majnoon field, after being offered new ‘unfavourable fiscal terms’, as well as selling its 20% stake in the West Qurna 1 oil field, which is operated by ExxonMobil. Instead, it will focus on developing and expanding the Basra Gas Company – in which it has a 44% stake - which processes gas from the Rumaila, West Qurna and Zubair fields.

Downstream & Midstream

  • Chinese refining output increased by 6.5% in August, rebounding from a low of 10.71 mmbpd in July. The rise comes as a new series of crude quotas was issued to China’s independent teapot refineries – causing a stampede to increase production – as well as the startup of PetroChina’s new 260 kb/d refinery in Yunnan. However, YTD refining output remains down y-o-y – at a -4.6% - as last year’s teapot refining bonanza tapers down to a more controlled pace at the state’s instigation.
  • In India, heavy rainfall causing severe flooding across the country has caused oil demand to fall by 6.1% y-o-y in August, to 15.75 million tons from 16.78 million tons. Gasoline and diesel have been particularly hard hit, as heavy waters impeded transportation and industrial traffic. Kerosene usage also shrank severely, by 41%, though this was more to do with the ongoing drive to replace it with LPG as a cooking fuel.

Natural Gas & LNG

  • Bangladesh has signed its first long-term LNG agreement, agreeing to import fuel from Qatar’s RasGas over 15 years. Initial supply will be at 1.8 mtpa for the first five years, followed by 2.5 mtpa for the remaining ten, which is less than the 4 mtpa figure bandied about when the initial Petrobangla and RasGas MoU emerged in 2011. Bangladesh will be looking to fill in that gap with spot purchases, as it battles with dwindling domestic production and the departure of Chevron from its waters.
  • The quest to build The Philippines’ first LNG import terminal continues to hit choppy waters, with the government now asking for ‘unsolicited private sectors proposals’, after deeming plans submitted by international players from Singapore, Japan, South Korea, China, Indonesia and the UAE (among others) ‘unsatisfactory’. The stumbling block, it appears, is the estimated price tag of US$2 billion and that state oil company PNOC failed to convince the proposers to accept its share of banked gas from the Malampaya field as equity for the terminal project.  

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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