Chevron Steps Up Venezuelan Crude Oil Sales to US Refiners

Chevron Corp has stepped up sales of Venezuelan crude oil to rival U.S. refiners, adding PBF Energy Inc and Marathon Petroleum Corp to its list of customers for the crude, vessel tracking and loading schedules showed.

U.S. Gulf Coast refiners, which historically processed Venezuelan oil, have shown a renewed appetite for the heavy sour crude grade after Chevron late last year received authorization from the U.S. Treasury Department to expand its operations in Venezuela and resume oil shipments to the U.S. after a four-year pause. 

Chevron, the last big U.S. oil producer still operating in U.S.-sanctioned Venezuela, has increased exports of the crude since January. 

So far in April, it has loaded about 148,000 barrels per day (bpd) of oil at Venezuelan ports, with cargoes going to at least three other U.S. refiners, besides Chevron’s own refinery. 

In mid-April, Chevron sold about 550,000 barrels of Venezuelan crude to PBF for its 185,000-bpdChalmette refinery, near New Orleans, U.S. Customs data on Refinitiv Eikon showed. 

Another 500,000 barrels were being loaded this week at Venezuela’s Jose terminal for delivery to Garyville, Louisiana, according to state-run oil company PDVSA loading schedules. 

Marathon Petroleum owns and operates the 596,000-bpd Garyville refinery.

PBF and Marathon did not immediately reply to requests for comment. Chevron said it conducts business in compliance with all laws, regulations and a sanctions framework provided by the U.S. Office of Foreign Assets Control (OFAC).

Valero Energy Corp also has received cargoes from Chevron with tanker Caribbean Voyager discharging about 500,000 barrels at its 340,000-bpd St. Charles, Louisiana, refinery on Thursday.

The top independent refiner did not immediately respond to a request for comment, however, Gary Simmons, its chief commercial officer, said in an earnings call on Thursday that Venezuelan production is forecast to grow and help ease tight supplies of heavy sour crude oil. 

Chevron has sent Venezuelan crude to its 369,000-bpd Pascagoula, Mississippi, refinery and this month shipped a cargo to a Bahamas oil-storage terminal, PDVSA’s schedules showed.

gCaptain by Arathy Somasekhar, June 2, 2023

Biofuels Pivot to Asia

The world of biofuels is evolving at a breakneck pace. Global production capacity is accelerating and according to the International Energy Agency (IEA) Renewables 2022 report, demand for vegetable/waste oil feedstocks is set to increase by 56% over the next five years.

The United States and Europe are moving from biodiesel and ethanol to renewable diesel, while Indonesia, Singapore and India expect growth in biodiesel, sustainable aviation fuel (SAF) and ethanol. Singapore has long been a participant in biofuels, in particular SAF and marine fuel, while China is the world’s largest exporter of used cooking oil. Indonesia has the world’s highest transport fuel blending mandate and relies heavily on domestic palm oil as a feedstock.

Chinese Used Cooking Oil to Power the World

Waste and residues, a feedstock category that includes used cooking oil, is poised for the fastest growth among biofuel inputs, with the IEA projecting total feedstock share of waste and residue to grow from 9% in 2021 to 13% in 2027. One motivator for the growth of waste and residue as a biofuel input is the natural limitations of growing more soybeans, the oil of which is the primary feedstock for biodiesel and renewable diesel in the United States.

Additionally, legislation in the European Union supports the feedstock use of waste and residual oils on environmental grounds: used cooking oil, for example, conveniently circumvents the food vs. fuel debate as it has already been used in a food application.

China has a rich and oil-rich culinary tradition. Already the world’s largest exporter of used cooking oil, according to a working paper from the International Council on Clean Transportation, China is only beginning to unlock its waste and residual feedstock potential. Bloomberg estimates that in the city of Chengdu alone, Sichuan hot pot produces an average of 12,000 tons of waste oil every month.

Renewable diesel is the fastest growing and arguably most in-demand biofuel, due to its ability to be used in unmodified diesel engines. Two years ago, U.S. production of biodiesel exceeded that of renewable diesel nearly threefold, while today renewable diesel has more than caught up and in late 2022 monthly production capacity of renewable diesel exceeded that of biodiesel in the United States.

Prior to a ramping up of U.S. renewable diesel capacity, U.S. used cooking oil was often exported to Singapore to be converted to renewable diesel before being re-imported to the United States for vehicular use. Now, with U.S. production capacity of renewable diesel increasing, the country is keeping its used cooking oil for domestic refining. China is now experiencing competition for destinations between Singapore, Europe and the United States for its residual and waste oil exports. As China eyes carbon neutrality, however, the country may begin to use its own waste and residual feedstock for domestic refining.

Sustainable Aviation Fuel and Marine Fuel Take Off in Singapore

Outside of Europe and the United States, Singapore and Japan are the world’s primary sources of SAF. SAF is seeing accelerated demand in large part due to the Carbon Offsetting and Reduction Scheme for International Aviation (CORSIA), an initiative adopted by the International Civil Aviation Organization, which required aviation emissions reporting from 2021 onwards. SAF is seen as a crucial factor in decarbonization, as aviation cannot be accommodated by electrification: no battery can yet power a plane. Biofuel producer Neste’s (OTCPK:NTOIF) (OTCPK:NTOIY) Singapore expansion is set to dramatically increase capacity of SAF in the near term.

A robust port in itself, Singapore has the goal of zero marine emissions by 2050, aimed to be achieved via full electrification and biofuel use for local harbor craft in port waters. Singapore has supplied marine vessels with 70,000 MT of biofuels, according to Argus.

Indonesian Palm Oil Persists

In February 2023, Indonesia increased its biodiesel blending mandate from B30 to B35, augmenting what was already the world’s highest threshold. Biofuel in Indonesia is used both to meet climate goals and to shelter the developing population from volatile international petroleum pricing, while making use of an abundant domestic resource: palm oil.

Palm oil is the primary feedstock for Indonesian biodiesel, and while palm oil is being phased out as an input in Western production due to its association with deforestation, it is not expected to slow down in its use in Indonesian biofuel. In fact, net use of palm oil as a feedstock is expected to increase through 2027 as Indonesian gains more than offset Europe’s divestment from the feedstock, according to IEA projections.

Evolving Landscape, Evolving Risks

As the global biofuel market landscape evolves and becomes more complex, so do the risks and thus the risk management needs of market participants. Weather, geopolitics, supply chain issues or other events could affect any of these commodities at any moment. Soybean Oil, Corn, Ethanol, Brazilian Soybeans, UCO and Malaysian Palm Oil futures and options are available to trade at CME Group, providing risk management tools throughout the supply chain and across global markets. All will be markets to watch in the months and years ahead as supply and demand patterns continue to shift.

by Seeking Alpha, June 2, 2023

Saudi Aramco’s Q1 Profit Falls to $31B

Oil giant Saudi Aramco reported a first-quarter profit on Tuesday of $31.88 billion, down nearly 20% from the same period last year as energy prices have sunk over global recession concerns.

The firm known formally as the Saudi Arabian Oil Co. blamed the drop — compared to $39.47 billion in the same quarter last year — on the lower crude oil prices. Aramco made a $30.73 billion profit in the fourth quarter of last year.

“We continue to deliver high reliability and low cost of production financially,” Aramco President and CEO Amin H. Nasser said on a conference call with analysts. “We continue to generate strong earnings and cash flows further, demonstrating our ability to deliver through oil price cycles.”

Benchmark Brent crude traded Tuesday around $76 a barrel, down from a high of $125 in the last year.

Saudi Arabia’s vast oil resources, located close to the surface of its desert expanse, make it one of the world’s least expensive places to produce crude. For every $10 rise in the price of a barrel of oil, Saudi Arabia stands to make an additional $40 billion a year, according to the Institute of International Finance.

In March, Aramco announced earning $161 billion last year, claiming the highest-ever recorded annual profit by a publicly listed company and drawing immediate criticism from activists amid concerns about climate change. However, as prices drop, so do Aramco’s revenues.

“Aramco is a very simple machine: It’s oil production times price, minus a little bit of cost,” said Robin Mills, the CEO of Qamar Energy, a Dubai-based consulting company. “Profit is down. That’s all oil-price driven.”

While saying Aramco was “working to further reduce the carbon footprint of our operations,” Nasser remained bullish on the world’s need for fossil fuels, citing future estimated demand from China and India.

“We continue to believe that oil demand is likely to grow, and we believe that the world will continue to need oil and gas for the foreseeable future to support a sustainable and affordable energy transition,” Nasser said. “Our concern remains that the industry is not investing enough to meet expected future demand.”

Nasser said Aramco also was looking at opportunities to produce liquid natural gas outside of the kingdom in “the U.S. and Australia and in other parts of the world.” The company also plans to spend up to $55 billion in capital projects as well to expand its production.

Those earnings came off the back of energy prices rising after Russia launched its war on Ukraine in February 2022, with sanctions limiting the sale of Moscow’s oil and natural gas in Western markets.

However, oil prices have sunk in recent weeks amid fears of a coming recession as central banks in the U.S. and elsewhere raise interest rates to try to tame inflation. That’s even after OPEC+, a group of countries including the cartel and those outside it like Russia, announced surprise production cuts in April totaling up to 1.15 million barrels. Recent OPEC+ cuts have seen U.S. President Joe Biden warn of potential “consequences” for Riyadh, even though his national security adviser just visited the kingdom and met with Saudi Crown Prince Mohammed bin Salman.

“In our view, the recent weakness seen in the oil market was driven by concern over tightening of monetary policy by central banks and (the) effect on economies,” Nasser said. “This was also worsened by the crisis (involving) regional banks in the U.S. and concern over its contagion effect. However, in our view, the markets overreacted to the situation, resulting in the sell-off by traders.”

Aramco stock rose 3% in trading Tuesday to close at $8.96, giving the oil firm a $1.97 trillion valuation and putting it only behind Apple and Microsoft for the highest market capitalization in the world. Just a sliver of its worth, under 2%, is traded on the exchange. The Saudi government holds 90% of the company, with about 8% held by Saudi sovereign wealth funds.

Separately Tuesday, Aramco announced it would begin issuing performance-based dividends to stockholders, on top of the dividends it already offers. Its base dividend in the fourth quarter of last year was $19.5 billion, ranking it as the highest in the world for a publicly traded firm.

Manufacturing Business Technology by Jon Gambrell, June 2, 2023

Cushing Chosen for $5.5 Billion Refinery Investment

Southern Rock Energy Partners, LLC selected Cushing as the site for its next-generation crude oil refinery.

The project is a $5.56 billion investment into the “pipeline capital of the world”, also bringing in more than 423 full-time jobs.

The total economic impact for the first decade of operations of the facility to the Cushing area and the state of Oklahoma is estimated to be more than $18 billion.

Bruce Johnson is the director of the Cushing Economic Development Foundation.

“[They] selected Cushing, Oklahoma to be that location for the first refinery to be built in the United States in the last 40 years,” he said. “We’re looking to supply energy not only to our area, but to the rest of United States for decades, if not centuries, to come just like we have in the century past.”

Johnson said just in the construction alone, 1,250 jobs will be available over the next two to three years.

“Since the discovery of the Cushing-Drumright Oil Field in the early 1900s, Cushing has been at the epicenter of North America’s energy markets. More than 50 refineries have called Cushing home over our history, and we are looking forward to another successful energy-supplying partnership based upon modern technological advancements,” stated Chairman Ricky Lofton, Cushing City Commission.

Cushing has about 100 million barrels of storage in the tank farms surrounding the community.

The refinery complex will produce about 91.25 million barrels or 3.8 billion gallons annually of fuels including gasoline, diesel and jet fuel from crudes sourced domestically.

The project will take 36-months to build with work starting in 2024. Commercial operations are expected to start in 2027.

Some Cushing locals have shared their excitement for the refinery.

George Hatfield lives in Cushing and said it’s good news for the town.

“It’d be good for the economy, I believe,” he said. “Why not us? We got all the oil and all we need do is just refine it and send it places that needs the refined oil.”

Another local, Billy Cooper, told FOX23 he’s happy to hear about the plans.

“For all the people around here, [it would] bring so much business into town, for sure, and jobs like … high paying jobs long term,” he said.

There was a question regarding the environmental impact this may cause.

Nicholas Hayman is the state geologist for Oklahoma. He said Oklahoma is working hard on its carbon footprint.

When I hear about a big refinery, my first thought is not earthquakes, it’s the carbon footprint, but then I also know that we’re working on ways to deal with that,” Hayman said.

Hayman said there is a lot of time spent in trying to manage the impact these large businesses have on the planet.

“And that’s where we’re really spending a lot of time both in the state university world and businesses,” he said. “Some of the largest investors are the corporations. To understand how to do this, and it’s a very serious challenge, but Oklahoma can very much play a role in that.”

By Fox 23 News, June 1, 2023

5 Interesting Facts About Dangote’s Newly Commissioned Oil Refinery

The conversation surrounding the subject of oil refining in Africa, couldn’t have come at a better time.

Now more than ever, Africa needs to examine its options for reducing its energy expenses, as energy cost heavily influences the growth or decline of any given economy.

Energy cost is a key determinant of inflation, alongside basic amenities like food, water and other commodities distinct and essential to different regions.

For an economy to thrive, energy must be as cheap as possible. Unfortunately, this has hardly been the case in Africa for the past year.

The ensuing conflict between Russia and Ukraine has brought about a substantial spike in the cost of energy, globally.

Needless to say, for a developing continent like Africa, the brunt of this crisis is being felt to extensive degrees, as numerous countries on the continent for the past year have been dealing with some level of inflation.

The inflation, while spurred in parts by food hikes, and other nuanced factors, is still majorly a result of the rising cost of energy that has plagued the entire planet.

Africa hardly refines its own oil despite its tremendous oil reserves, which in hindsight has caused a gargantuan deficit in its oil bottomline.

Simply put, most oil-producing African countries, particularly Sub-Saharan African countries, sell their crude to countries outside the continent for a specific amount, and then buy back said oil in a refined state for a similar amount.

This in itself is as financially counter-productive as it gets, however, what makes things significantly worse is when external factors like war make the oil importation costs much more expensive. A plight which almost every African state suffered in the previous year.

It is also disturbing that this problem would persist for the next two years, as numerous global economists have hinted at the possibility of a recession this year.

With this in mind, the glaring solution to remedy this problem is to simply build refineries in Africa. Fortunately, this idea has not only been floating all across Africa for some time now, yesterday, it became a reality.

On Monday, May 22nd, 2023, Aliko Dangote triumphantly commsioned his massive oil refinery. The much awaited project represents an important turning point for the nation’s energy industry and Dangote’s ambitious endeavors.

Dangote’s dedication to meeting Nigeria’s domestic gasoline demand is demonstrated by the commissioning event, which was attended by Nigerian President Muhammadu Buhari.

With this new development, here are a few interesting facts to know about the Dangote oil refinery.

Timeline: Although traders claim there are no indications of a rapid ramp-up in manufacturing, initial shipments are anticipated in July or August of 2023.

Location: The refinery is situated in Lagos Nigeria, specifically the Lekki Free zone, covering a land area of approximately 2,635 hectares, which according to the site is about six times the size of Victoria Island.

Capacity: The refinery would be able to produce 650,000 oil barrels per day, subsequently, with an initial rollout of 540,000 barrels per day. Also, the facility will produce 3 billion standard cubic feet of gas, 65 million liters of premium motor spirits (petrol), 15 million liters of diesel, and 4 million metric tones of jet fuel each day, approximately, 8 million tons of petroleum products annually. Additionally, Nigeria National Petroleum Co. has signed a contract to provide 300,000 barrels of crude oil per day to Dangote’s refinery.

Objective: With the refinery’s projected capacity, Dangote has noted that it would be in charge of Nigeria’s entire oil supply, effectively eliminating the need for oil importation. However, the company also disclosed plans to produce a petroleum surplus intended for sale across fellow African countries and perhaps other regions outside the continent, which would bring about an estimated $11 billion in petroleum products from Nigeria per year. The refinery is also intended to reduce the $26 billion spent on petroleum imports in 2022.

Cost: The ambitious projects costs a total of $19 billion to build, according to Bloomberg. This cost was initially estimated at $9 billion. However, the governor of the Central Bank of Nigeria disclosed that the Dangote refinery was delivered at a cost of $18 billion, 70% of which the governor, noted has been repaid, trhe 70% of course coming from the 50% of the entire cost, which the governor said Dangote borrowed from financial insstitutions. “Today, total loans outstanding have dropped from over $9 billion when this project started to N2.7 billion,” he said.

Business Insider Africa by Chinedu Okafor, June 1, 2023

Oil Supply won’t be Affected by Stricter Price Cap Enforcement, IEA Says

“It may have some impact but countries once again reiterated that if there are some impacts to slow down in that area, they are going to accelerate in the other areas that it will not change their determination of reaching the 1.5 degree Celsius goal,” Birol said.

The International Energy Agency (IEA) does not expect moves by the Group of Seven nations to counter the evasion of price caps on Russian energy will change the supply situation for crude oil and oil products, the IEA’s Executive Director Fatih Birol said.

The G7, the European Union and Australia agreed to impose a $60-per-barrel price cap on Russian seaborne crude oil and also set an upper price limit for Russian oil products to deprive Moscow of revenues for its invasion of Ukraine.

The G7 will enhance efforts to counter evasion of the caps “while avoiding spillover effects and maintaining global energy supply”, the group said on Saturday, without giving details, during its annual leaders’ meeting.

The IEA, which provides analysis and input to the G7 on energy, does not see the enhanced enforcement of the price caps affecting the global oil and fuel supply, Birol told Reuters in an interview on the sidelines of the summit.

“Any significant changes in the markets as always we will reflect in our analysis, in our reports, but for the time being I don’t see a reason to make a change in our analysis,” he said.

According to Birol, the price cap reached two main objectives: it did not trigger tightness in the markets as Russian oil continued to flow but at the same time Moscow’s revenues were reduced.

“Russia did play the energy card, and it did fail. But there are some loopholes, some challenges for the better functioning of the oil price cap,” Birol said.

GAS INVESTMENTS

The G7 has also brought support for the gas investment back to the communique on Saturday in that it said was a ‘temporary’ solution to address potential market shortfalls and as nations are trying to de-couple from the Russian energy.

The move has alarmed climate activists who warned the group may fail to deliver on its goal to achieve net-zero carbon emissions by 2050 and limit global warming to 1.5 degrees Celsius (2.7 Fahrenheit).

“The clean energy transition is happening and much faster than many think.”

The language change was brought in by Germany, once a top buyer of Russian gas, sources have said, and the communique did not have a time frame for investments into the gas sector.

“There is no determination of any time frame there, but I think the main issue is because of the reliance of especially European countries on Russian gas almost for decades. Now it is not easy to change everything from one day to another,” Birol said.

“(German) Chancellor (Olaf) Scholz made clear again and again that Germany is very keen to reach this 1.5 degrees target. And I believe in his words.”

By Reuters, June 2, 2023

Govt Plans to Set Up 3 More LNG Terminals

The government has planned to set up three more liquefied natural gas (LNG) terminals in addition to the existing two currently being operated to regasify imported gas.

Besides, the existing two floating storage and regasification unit (FSRU) will also be extended to 630 mmcft per day from 500 mmcft.

The proposed three new LNG terminals will be set up in Payra, Moheshkhali and Matarbari whose total regasification capacity would be 2000 mmcft per day including two floating and another land based.

Two floating terminals with 500 mmcft capacity will be set up at Payra and Moheshkhali while the land based terminal with the production capacity of 1000 mmcft will be set up at Matarbari.

Negotiations for signing agreement with foreign and local investors have been going on.

“Agreements with those investors may be signed by the current year,” Md Kamruzzaman Khan,Petrobangla Director of Operation told the Daily Observer on Saturday.

Petrobangla sources said that Excelerate Energy of USA has made an offer for the Payra site while Summit Group made an offer for Moheshkhali. Petrobangla has shortlisted 12 firms for the Matarbari site, sources said.

If the government gives approval for setting up the terminals, it will take 3-5 years to get them installed and ready for operation, Petrobangla source said.

Presently two floating LNG terminals have been in operation since 2018, of which one was set up by Excelerate Energy at Moheshkhali of Cox’s Bazar with 500 million cubic feet per day while another with the same capacity was set up by the Summit Group in the same area.

With the operation of three terminals including the extension of the existing terminals, the LNG production of the country will rise to 3200 mmcft per day.

Current demand of gas in the country is 4000 mmcft per day. But Petrobangla can supply only 3000 mmcft per day, Petrobangla sources said.

In future the demand of the country will increase furhter. So, there is no alternative to boost up production of gas in the country.

Meanwhile, the floating storage and regasification unit (FSRU) of Petrobangla went into operation on Saturday night after remaining suspended for 8 days.

A two-day disruption in the supply from LNG terminals inflicted by Cyclone Mocha has laid bare the energy crisis Bangladesh is facing, with power stations and factories forced to suspend or reduce production.

Besides power cuts denying people any respite from the scorching heat, low pressure or lack of gas in the kitchen has spelled trouble for many. Cars, auto-rickshaws and other vehicles waited in long queues for gas at refuelling stations. The government decided to suspend gas supply from two floating LNG terminals in Moheshkhali due to severe cyclonic storm Mocha since May 12. The Ministry of Power Energy and Mineral Resources issued a notice on May 12 last.

The daily observer by Nurul Amin, May 31, 2023

Oil Ministry Working on Proposal to Merge MRPL with HPCL

The oil ministry is drafting a proposal to combine the two publicly traded subsidiaries of Oil and Natural Gas Corp (ONGC), Mangalore Refinery and Petrochemicals Ltd (MRPL) and Hindustan Petroleum Corp Ltd (HPCL).

When ONGC bought HPCL from the government five years ago, the notion of a merger between MRPL and HPCL was discussed, but little progress was achieved. According to the aforementioned sources, the ministry is currently pressing for the merger, which will probably involve a share exchange.

They claimed that there would be no financial outlay and that HPCL would most likely issue new shares to MRPL owners as part of the merger. The ONGC and HPCL are MRPL’s promoters. The public owns 11.42% of MRPL, followed by HPCL at 16.96% and ONGC at 71.63%.

Through the acquisition, ONGC’s present 54.9% holding in HPCL will be dramatically increased, lowering the free float. The oil ministry will probably ask the cabinet for approval of the proposed combination of HPCL and MRPL. ONGC, HPCL, MRPL, the oil ministry, and ONGC all declined to comment.

The HPCL-MRPL combination might need to wait until next year, according to one individual, who argued that the rule calls for a minimum two-year buffer between any two mergers a business undertakes. Last year, MRPL completed the merger of its subsidiary, OMPL, with itself.

The merger plan, which aims to combine the majority of the downstream assets of the ONGC group under HPCL, will probably result in some tax gains. More fuel is sold by HPCL, which has a substantial retail network, than is produced at its refineries.

It will have internal access to MRPL’s goods following the merger. Since MRPL doesn’t have a robust domestic sales network, a substantial amount of its items are sold to merchants outside of Karnataka and are therefore subject to central sales tax (CST). People claimed that a merger may reduce MRPL’s CST expenses.

According to a person with knowledge of the matter, MRPL personnel may be concerned about a merger because they may be transferred to HPCL’s other refineries.

The oil ministry had suggested the former to conduct a three-way merger of HPCL, MRPL, and OMPL to combine the group’s downstream businesses shortly after ONGC’s Rs 37,000 crore acquisition of HPCL. However, the relationship between the two businesses had deteriorated as a result of HPCL’s year-long refusal to acknowledge ONGC as its promoter.

The merger of OMPL and MRPL was completed because ONGC opposed giving HPCL authority over MRPL. According to the previously referenced individuals, top officials at ONGC and HPCL have changed in the last year, and the two businesses are now more receptive to the concept of a combination.

By Industry Outlook, May 31, 2023

Higher Road Fuel Demand Weighs on ARA Stocks (Week 22 – 2023)

Higher demand for road fuels weighed on Independently-held oil product stocks at the Amsterdam-Rotterdam-Antwerp (ARA) oil trading hub in the week to 31 May, according to consultancy Insights Global. Total stocks held declined.

Gasoil stocks declined in the week to 31 May, its lowest since 27 April when stocks amounted. Inland demand remained strong with German traders filling up their tanks ahead of summer. Shell’s Pernis refinery in Rotterdam appears to be back online after an extensive maintenance period, according to market participants. Gasoil cargoes arrived from Saudi Arabia, Turkey and the US, and departed to France, Germany, the Mediterranean, Poland, Sweden and the UK.

Gasoline inventories marginally increased in the week to 31 May, as more products arrived in the region, higher than the week prior, according to Vortexa.

Export demand appeared stable as the arbitrage to the US remained open and some cargoes were seen heading towards Nigeria. Demand up the Rhine river was strong as cargoes went into northern and southern Germany, with Miro’s Karlsruhe refinery remaining offline.

Cargoes arrived from Denmark, Estonia, France, Germany, Lithuania, Singapore, Sweden and the UK and left for Brazil, Canada, France and Germany.

On the lighter side of the barrel, naphtha’s inventories went up.

Gasoline blending demand was slower in the week to 31 May while the petrochemical sector switched more towards rival propane feedstocks. Naphtha cargoes arrived from Norway, Spain, the UK and the US, while none left.

Jet fuel stocks declined in the week to 31 May. Demand appears stronger as is typical seasonally, and no cargoes arriving to the ARA has contributed to the fall in stocks.

At the heavier side of the barrel, fuel oil stocks declined, the lowest since 27 April.

The arbitrage for HSFO to Singapore appeared open, while most cargoes exported were destined for Gibraltar. Fuel oil cargoes arrived from Denmark, France and Georgia and left for the Mediterranean and Denmark.

Reporter: Mykyta Hryshchuk

Factbox: Philippines Starts LNG imports, More Projects in Pipeline

With just four more years to go before the Philippines‘ only gas field might halt production, the country has started importing liquefied natural gas (LNG), adding upward pressure to already worryingly high inflation.

Seven terminal projects have been approved by the Philippines‘ Department of Energy, as it looks to expand LNG usage into industrial, commercial, residential and transport sectors in addition to power.

Following are the project proponents and their partners, proposed capacities, timetable and status as of April 24, according to the energy department.

PHLNG import terminal

(previously Atlantic Gulf & Pacific Co of Manila Inc)

Partner: Osaka Gas Co Ltd 9532.T, which has technical services agreement with AG&P

Description: Floating Storage Unit and Onshore Regasification, and buffer LNG storage tank

Location: Batangas City

Capacity: 3 million tonnes per annum (mtpa)

Estimated Commercial Operations Date (COD): FSU and Onshore Regasification in May 2023, and buffer LNG storage tank in December 2023

Status: LNG cargo from trader Vitol has arrived and will fuel San Miguel Corp’s SMC.PS 1,200-megawatt power plant in Batangas, which is scheduled to come online by May 26

FGEN LNG of First Gen Corp FGEN.PS

Partner: Tokyo Gas Co Ltd 9531.T, which has a 20% interest

Description: Floating Storage and Regasification Unit (FSRU)

Location: Batangas City

Capacity: 5.26 mtpa

Estimated COD: September 2023

Status: Commissioning scheduled in third quarter

Energy world gas operations Philippines Inc.

Proponent: Energy World Corp Ltd EWC.AX

Description: LNG Storage and Regasification Terminal

Location: Pagbilao Grande Island, Quezon Province

Capacity: 3 mtpa

Estimated COD: December 2023

Status: Permit to construct extended for 1 year and issued on Jan. 31, 2023

Shell energy Philippines Inc. 

Proponent: Shell Pilipinas Corp SHLPH.PS

Description: FSRU

Location: Batangas City

Capacity: 3 mtpa

Estimated COD: September 2025

Status: 20-month extension of Notice To Proceed issued in January 2023

Luzon LNG Terminal Inc. 

Description: FSRU

Location: Batangas Bay

Capacity: 4.4 mtpa

Estimated COD: December 2025

Status: Permit to Construct issued in December 2022

Vires Energy Corp

Description: FSRU

Location: Batangas City

Capacity: 3 mtpa

Estimated COD: September 2025

Status: 2-year extension of Notice To Proceed issued and valid until October 2023

Samat LNG Corp

Description: Small-Scale LNG Terminal

Location: Mariveles, Bataan

Capacity: 0.32 mtpa

Estimated COD: Phase 1 in March 2024, Phase 2 in May 2025

Status: Notice To Proceed issued in January 2023

By Intraksyon, May 30, 2023