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PETRONAS, which has more than two decades of strategic partnerships in India, is enhancing its business strategy to strengthen and expand its presence in the world’s fastest-growing economy, said its President and Group CEO, Datuk Wan Zulkiflee Wan Ariffin.

“PETRONAS aims to continue to be part of India’s exciting journey and support its sustainable growth ambitions and commitments through further collaborations with our existing partners as well as through new strategic-fit opportunities,” he said.

Wan Zulkiflee, currently on PETRONAS’ annual official visit to meet with India’s industry leaders and partners, said high on PETRONAS’ priority would be the expansion of its liquefied natural gas (LNG) supply in India to help meet the rising demands from the power, agriculture and transportation sectors.

Leveraging on its long history and sterling reputation in the global LNG business, PETRONAS has the added advantage to provide tailor-made solutions across the LNG value chain such as flexibility, engineering expertise and experience in operations management.

With over 30 mtpa supply capacity, PETRONAS is currently the third largest LNG player globally. It hopes to further contribute to the energy needs of India, which is the fourth largest LNG market in the world.

To date, PETRONAS has delivered 15 LNG cargoes to India. Recently PETRONAS took pride in delivering to India the first cargo produced from its floating LNG production facility, the first such facility in the world.

PETRONAS’ strategic partnerships in India have also resulted in successful advances in the marketing and trading of crude oil and other petroleum products, petrochemicals, as well as the distribution of lubricants.

PETRONAS also sees growth in demand for petrochemicals in India – especially with the growing affluence that will see the increased demand for consumer products. In 2016, India made up over 100,000 tonnes of PETRONAS’ petrochemicals sales volume.

To strengthen PETRONAS’ lubricants business in India, subsidiary PETRONAS Lubricants International (PLI), is investing US$150 million over the next five years. The investment includes the building of a US$50 million lubricant blending plant with a 110 million-litre capacity in Patalganga, to be completed by Q1 of 2018.

Wan Zulkiflee said this investment was also in line with the Indian government’s “Make in India” transformation initiative.

The plant is set to be the most modern facility in PLI’s global production network with unique capabilities to blend the most complex fluids. It is also equipped with a technical service facility that utilises the latest equipment in fluid analytics.

“We are aiming to triple our market share in India’s lubricant market by 2022. Globally, we are among the top 10 lubricants players by market share, and striving to eventually be among the top five in five years,” said Wan Zulkiflee.

PLI also has a reliable network of multiple OEM partnerships, notably with Tata Motors, Fiat, New Holland, Doosan, Case Construction, Maruti Suzuki India, Piaggio and Bharat Benz for branded and co-branded lubricants.

Wan Zulkiflee further noted that he was extremely encouraged by the growth and performance of PETRONAS’ LPG joint venture with Indian Oil Corporation Ltd which currently owns LPG bottling terminals in Haldia, West Bengal and in Ennore, Tamil Nadu.

During this official visit, PETRONAS also commemorated a three-year agreement between its wholly-owned subsidiary PETRONAS Chemicals Group and Reliance Industries Limited for the supply of up to 120,000 mt of paraxylene.

“I look forward to see more collaborations fostered between PETRONAS and our counterparts in India, to pave the way for a stronger cooperation for the mutual benefits,” Wan Zulkiflee added.

Issued by

Media Relations

Group Strategic Communications

PETRONAS

Media Contacts:

Mr. Auliya Rasyid

E: auliya_rasyid@petronas.com

M: + 6019 222 0179

Petrobras, as the company is known, said its U.S. subsidiary, Petrobras America Inc, would soon open a non-binding phase for interested companies to communicate willingness to take part in negotiations for the 110,000-barrels-per-day processing unit.

The Pasadena refinery has been the target of several investigations in Brazil, with prosecutors and members of an audit court suspecting bribes were paid to Petrobras executives as a result of the purchase of the facility in 2006.

The Brazilian oil company paid $360 million for half of the Pasadena refinery that year, more than eight times what its previous owner, Astra Oil, a unit of Belgian-controlled Astra Transcor Energy, paid for the complex a year earlier.

By 2012, Petrobras had sunk $1.18 billion into it, including the cost of buying out Astra’s remaining half after a legal dispute between the firms.

The purchase of the refinery was one of the targets of prosecutors behind the so-called Car Wash investigation centered on the state-controlled oil company, which lost billions of dollars as a result of widespread corruption in dozens of contracts.

Current Petrobras management has said the company was a victim in all the corruption cases. Federal prosecutors in Brazil presented corruption and money-laundering charges last December against 11 people related to the Pasadena deal.

Brazilian audit court TCU said the deal caused losses of more than $580 million to the company.The Brazilian oil company said on Tuesday it would also sell the other companies linked to the refining complex: PRSI Trading LLC and PRSI Real Property Holdings LLC.

Meanwhile, companies like ExxonMobil Corp.’s partner Oil Search Ltd. sell most of their output to Asian customers linked to crude prices, which are up about 40% over that period. About 70% to 80% of Royal Dutch Shell Plc’s LNG is priced off oil, Chief Financial Officer Jessica Uhl said last week. And about two-thirds of BP Plc’s gas portfolio is oil-linked, Chief Executive Officer Bob Dudley said Tuesday.

The dichotomy is a relic of LNG’s early days, when it competed against oil and lacked an internationally-accepted benchmark. The fundamentals of the two have deviated in recent years, as the Organization of Petroleum Exporting Countries and its allies cut output to tighten the oil market, while new LNG projects worsen a glut.

“The LNG market is facing the prospect of widely diverging prices,” said James Taverner, an IHS Markit energy analyst in London.
As OPEC-led cuts pushed Brent briefly above $70/bbl earlier this year, Morgan Stanley was among banks to recently lift 2018 price forecasts, saying they could average $75 in the third quarter.

Costlier oil
At $75, LNG priced at 13% of Brent — a common ratio — would cost $9.75/MMBtu. The benchmark crude will average 16% higher this year, according to the median of forecasts compiled by Bloomberg, which would be equivalent to about $8.27/MMBtu.

Meanwhile, U.S. Henry Hub prices are seen 1.7% higher this year at $3.07/MMBtu. And a slate of new export projects coming online and softer summer demand means spot LNG — that is, not bought through long-term contracts — will average $5.90/MMBtu this year in Singapore, BMI Research said in a Jan. 4 note, compared with an average $6.803 last year.

Australia’s Woodside Petroleum Ltd. sells more than 90% of its LNG through oil-linked contracts, Chief Executive Officer Peter Coleman said in an interview. Shell’s Uhl said the benefits of higher oil will be seen in first quarter results because the price feeds through on a lag of three to four months. Woodside and Oil Search also flagged a three-month delay.

Qatar, the biggest LNG supplier, also has a majority of its sales linked to oil, according to data compiled by Bloomberg New Energy Finance. State-owned Qatar Petroleum didn’t respond to a request for comment.

A similar gulf between oil and gas in Europe last decade led to adjustments in long-term contracts and gas hubs gaining greater roles, said IHS’s Taverner.

But a similar transformation in Asia will be difficult, said Poorna Rajendran, a Singapore-based analyst for energy consultant FGE. While Asian prices such as S&P Global Platts’ Japan-Korea Marker and Singapore Exchange Ltd.’s Sling Index are gaining traction, they lack the necessary liquidity and transparency.

“Although a number of potential benchmarks are springing up in the region, as of now they’re still very underdeveloped and illiquid,” said Emma Richards, senior oil and gas analyst for BMI. “As a result, prices are lumpy, volatile and vulnerable to distortion.”

Wrapping up a tour of Latin America and the Caribbean that focused on unifying the region against Venezuela, Tillerson said he has President Donald Trump’s backing for tougher restrictions against Maduro’s government. Tillerson said that while no final decision has been made, mitigating the impact of potential sanctions was high on his agenda during a stop Wednesday in Jamaica.

“I don’t want to get into specifics because we’re going to undertake a very quick study to see if there are some things that the U.S. could easily do with our rich energy endowment, with the infrastructure that we already have available what could we do to perhaps soften any impact of that,” Tillerson said at a news conference in Kingston. “There’s great unanimity in the region and certainly in the hemisphere that we all want to see some progress on this situation in Venezuela which only gets worse day by day.”

The consideration of sanctions represents a shift for Tillerson, who argued against them as chief executive of ExxonMobil Corp. But he also tangled with Venezuelan officials after the government of late President Hugo Chavez nationalized his company’s assets in the country, which has the world’s largest oil reserves.

Trump is “very supportive, he said, ‘Yeah, I know you haven’t been in favor of that in the past,’ and I said, ‘Well, I think things have changed,’” Tillerson said earlier to reporters en route to Kingston from Bogota. “So we’re going to do this work, take it to him and let him make the decision.”
Oil posted the biggest decline in more than two months Wednesday as record crude production from U.S. fields reignited worries that supplies will swamp demand. West Texas Intermediate for March delivery fell $1.61 to $61.78 at 3:14 p.m. New York time.

Under Chavez, Venezuela won allies by providing cheap financing for the purchase of the country’s oil, helping cash-strapped Caribbean nations and allies including Cuba and Nicaragua circumvent rising energy costs. The strategy, part of what Chavez and his successor Maduro called “21st Century Socialism,” began to crumble as global oil prices collapsed and Venezuelan government spending continued unabated.
Political talks

In recent years, Venezuela’s economic crisis has only deepened, with hyperinflation following the creation of a vast black market for dollars and basic goods like food and medicine, which are in critically short supply. The latest talks between Maduro’s government and the opposition, hosted by the Dominican Republic, broke down again on Wednesday.

A key concern for the U.S. ahead of any sanctions move has been how to mitigate the impact of possible oil restrictions, not just on Caribbean nations but also on U.S. refiners who import heavy Venezuelan crude.

Tillerson said the U.S., Mexico and Canada had agreed during his stop in Mexico City last week to establish a working group that would look at ways to mitigate the damage caused by such restrictions. Asked if sanctions were a certainty, he said, “I don’t want to say it’s a sure thing because I want to do the work.”

Jamaican Prime Minister Andrew Holness suggested the region is already moving on following years of dependence on subsidized Venezuelan oil.
U.S. exports

“We now don’t hardly import oil from Venezuela,” Holness said alongside Tillerson in Kingston. “With the new dynamics in the global trade and energy and the United States is becoming a net exporter of energy resources, Jamaica can in this new paradigm benefit from that.”

As part of its campaign to raise pressure on Maduro after accusations of electoral abuses and human-rights violations, the Trump administration has already imposed sanctions on more than a dozen top officials — including the president himself.

Maduro and top Venezuelan figures have pushed back on U.S. efforts to isolate the country, calling it part of an orchestrated campaign to overthrow his regime.

“Venezuela won’t be threatened by anything, not by one Rex Tillerson or a thousand of him,” Maduro said Feb. 5 while in a press conference with OPEC Secretary General Mohammad Barkindo. “If United Stated decides to sanction oil, our ships will go to other places and we will continue to sell.”

Hexion is the first company to develop mobile resin coating technology, offering customers efficient manufacturing of resin coated proppants on any substrate. Manufacturing can occur in any location that offers optimum logistics to the wellsite, even internationally.

Hexion’s mobile plant occupies a small footprint and offers a variety of advantages over a traditional manufacturing facility. Most notable is that the facility is mobile, which enables strategic and efficient placement near transloads and sand mines. With transportation being a major cost associated with the use of proppants, freight costs are significantly reduced by the ability to locate coating capacity in close proximity to areas of high drilling and completions activity.

“This new model allows for better alignment with our customers by unlocking supply chain synergies, resulting in unmatched coating operational efficiency and quicker delivery of resin coated proppants,” said Jerry Kurinsky, senior V.P. and general manager, OTG. “Ultimately, this translates to cost savings for our customers.”

In addition to being mobile, the Voyager mobile resin coating service is operated with fewer personnel, which further reduces costs. It is also supported by a mobile quality control center to ensure the highest quality standards through systematic monitoring and product testing.

Permitting of the survey has already commenced and data acquisition is expected to begin in second-quarter 2018, with preliminary data available during fourth-quarter 2018 and final data during first-quarter 2019. The data will be processed by TGS utilizing its modern land imaging technology to provide clients with high resolution imaging of prospective reservoir intervals.

The seismic survey is complemented by TGS’ extensive geologic products database in the SCOOP/STACK, comprising data from over 100,000 wells and multiple interpretive products including Basin Temperature Modeling.

“TGS continues to see momentum in our onshore seismic business. The Anadarko basin is recognized as a top U.S. shale play and it is generating high interest from producers nationwide.

This new survey helps to strengthen our leading position in the SCOOP/STACK play fairway and demonstrates continued support from our customers as they pursue exploration and development targets using our data. Along with the recently announced Hackberry Complex and existing Loyal Complex surveys, TGS now offers contiguous modern seismic data coverage in this prolific area,” commented Kristian Johansen, TGS CEO.

The Joint Venture Partners have proposed to the Government of Kenya that the Amosing and Ngamia fields be developed as the initial stage of the South Lokichar development. This phase of the development is planned to include a 60,000-to-80,000-bopd Central Processing Facility (CPF) and an export pipeline to Lamu, some 750 km from the South Lokichar basin on the Kenyan coast.

This approach is expected to bring significant benefits as it enables an early Final Investment Decision (FID) of Amosing and Ngamia fields taking full advantage of the current low-cost environment for both the field and infrastructure development, as well as providing the best opportunity to deliver first oil in a timeline that meets the Government of Kenya expectations. The installed infrastructure can then be utilized for the optimization of the remaining and yet to be discovered South Lokichar oil fields, allowing the incremental development of these fields to be completed in an efficient and low cost manner post first oil.

The initial stage is planned to include 210 wells through 18 well pads at Ngamia and 70 wells through seven well pads at Amosing, with a planned plateau rate of 60,000 to 80,000 bopd. Additional stages of development are expected to increase plateau production to 100,000 bopd or greater. It is anticipated that Front End Engineering and Design (FEED) for the initial stage will commence in 2018, with FID targeted for 2019 and first oil in 2021-2022.

A total of six appraisal wells have been drilled at Amosing field, 10 at Ngamia, three at Etom and two at Ekales. Additionally, extended well tests, water injection tests, well interference tests and water-flood trials have been undertaken, all of which have proved invaluable for planning the development of the oil fields. Tullow Oil plc has released (Feb. 7, 2018) their updated assessment of resources in the South Lokichar basin.

Details of Africa Oil’s most recent independent assessment of contingent resources in the South Lokichar basin are contained in the Company’s press release dated May 10, 2016. The Company intends to have an updated independent resource evaluation in accordance with National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities (“NI 51-101”) completed following the completion of the water injectivity and associated production testing planned for the first half of 2018.

Early oil pilot scheme (EOPS)
An agreement between the Joint Venture Partners and the Government of Kenya was signed on March 14, 2017 allowing all EOPS upstream contracts to be awarded. Initial injectivity testing has started at Ngamia-11 and oil production and water injection facilities are being constructed in the field, which are expected to be ready to commence production/injection in the first quarter of 2018. Oil produced is being initially stored until all necessary consents and approvals are granted and work is completed for the transfer of crude oil to Mombasa by road.

Africa Oil CEO Keith Hill commented, “We are pleased that the Joint Venture has now agreed on an optimized plan to move forward with the South Lokichar basin development, which will allow acceleration of a crude export pipeline through Northern Kenya. This development will set the stage for additional exploration, appraisal and development, unlocking the vast resources contained within the basin.”

The new ethane cracker, part of ExxonMobil’s multi-billion dollar Baytown chemical expansion project, will provide ethylene feedstock to the new performance polyethylene lines in Mont Belvieu, which began production in the fall of 2017.

“With the completion of the project in Baytown, we are on the verge of fully realizing one of ExxonMobil’s most significant U.S. Gulf Coast investments,” said John Verity, president of ExxonMobil Chemical Company. “Our new ethane cracker will allow us to economically meet rapidly growing demand for high-performance polyethylene products around the world while continuing to sustain economic development and create jobs for decades to come.”

The project has created more than 10,000 construction jobs and 4,000 related jobs in nearby Houston communities since construction began in 2014. Once operational, it is expected to support 350 new permanent positions at the Baytown complex, $870 million a year in regional economic activity and $90 million per year in local tax revenues.

The Baytown chemical expansion project is a key component of ExxonMobil’s previously announced Growing the Gulf initiative. In addition to the ethane cracker in Baytown, ExxonMobil and SABIC are proposing to build a jointly owned petrochemical complex in San Patricio County, Texas, that would include a 1.8 million ton-per-year ethane cracker – the largest capacity of any ethane cracker built to date.

Massive new supplies of oil and natural gas have dramatically reduced energy costs and created new sources of feedstock for U.S. refining and chemical manufacturing. Most of ExxonMobil’s planned new chemical capacity investment in the Gulf region is focused on supplying export markets such as Asia with high-demand products, which will contribute to strengthening the United States’ balance of trade.

Recent changes in the U.S. corporate tax rate also create an environment for increased future capital investments in projects such as these, and will further enhance the company’s competitiveness in global markets.

“The U.S. chemical industry is rapidly expanding along the Gulf Coast due to abundant supplies of domestically produced natural gas, as demonstrated by the investments ExxonMobil alone is making,” Verity said. “This expansion will not only increase the nation’s existing manufacturing and export capacity, but also further stimulate economic growth and create thousands of full-time jobs.”

To support the industry’s need for skilled workers as part of this growth, ExxonMobil has contributed $2 million over the last five years to the Community College Petrochemical Initiative, a training program offered by nine Houston-area community colleges to provide technical skills to high school graduates, returning military veterans and others.

Whale is operated by Shell (60%) and co-owned by Chevron U.S.A. Inc. (40%). It was discovered in the Alaminos Canyon Block 772, adjacent to the Shell-operated Silvertip field and approximately 10-miles from the Shell-operated Perdido platform.

“Whale builds on Shell’s successful, nearly 40-year history in the deep waters of the Gulf of Mexico and is particularly special in that it offers a combination of materiality, scope and proximity to existing infrastructure,” said Marc Gerrits, Executive Vice-President Exploration for Royal Dutch Shell. “The result is another opportunity to think differently about ways we can competitively develop deep-water resources.”

This major discovery in a Shell heartland adds to the company’s Paleogene exploration success in the Perdido area. Through exploration, Royal Dutch Shell has added more than one billion barrels of oil equivalent resources in the last decade in the Gulf of Mexico.

Shell currently has three Gulf of Mexico deep-water projects under construction – Appomattox, Kaikias, and Coulomb Phase 2 – as well as investment options for additional subsea tiebacks and Vito, a potential new hub in the region. The Shell group expects its global deep-water production to exceed 900,000 boe per day by 2020, from already discovered, established areas.