Conservative estimates suggest that in the wake of oil prices crashing in late 2014, the Malaysian oil and gas services and equipment (OGSE) sector contracted by at least 11%. Analysis of overall financials for the OGSE sector by the Malaysian Petroleum Resource Corp, an agency under the Prime Minister’s Department, reveal that revenue for 2015 fell by 11%, while profits contracted by a severe 52.3%. Including companies such as MISC, Sapura Energy, Dialog, Scomi, Bumi Armada, the numbers for 2016 are not available yet, but a glance over the financial reports released for the bigger players indicate that while sector revenue will probably be down for the year, profits maybe be up, after aggressive cost-cutting that included a tide of retrenchments.
So what is in store in 2017 and beyond?
If we go by the health of Petroliam Nasional Berhad, better known as Petronas, the word seems to be “cautiously optimistic”. The guardian and bellwether of Malaysia’s Oil & Gas sector, Petronas is one of the few major integrated state oil companies that is holding up fairly well during the current on-going oil crises. Petrobras is engulfed in debt, as is PDVSA, while Pertamina appears to be struggling with corruption and clarity of its long term investment direction while select Russian entities battle being used as political tools. Full year 2016 revenue for Petronas fell by 17.3% from lower sales coupled with weak crude prices but profit was up by a whopping 28% to RM16.95 billion (US$3.82 billion), just slightly behind Shell’s own profit for 2016. For 2017, Petronas projects better times ahead, promising no more staff redundancies and bolstering defences by pegging its 2017 capex expenditure at US$45/b, while it prepares to focus on natural gas - both at home in Sarawak and Sabah, and abroad in its Canadian LNG export project, and the recent go-ahead given to its massive US$27 billion RAPID refinery and petrochemicals project.
However if oil prices fall any further or just lingers within the US$50-55/b range, the so called recovery being experienced now, may just stagnate or not be strong enough to re-boot the industry to its previous glorious days and create the jobs badly needed for Malaysia. The threat of market oversupply is still there as US shale oil continues to grow unabatedly. The reality is low oil prices for (much) longer. The future prosperity of Petronas would depend on how much it can increase its productivity and lower production costs. Petronas has moved very decisively and embarked on intensifying its internal cost competitiveness through better collaboration amongst other upstream operators in Malaysia through the CORAL 2.0 project, and is beginning to see lower cost scenarios for its well engineering programs already. On the new technology front, Petronas is collaborating with MIT Innovation Sdn Bhd (MIT) to promote a smart and efficient technology that significantly lowers drilling costs. All moves in the right direction.
The weak link to Petronas’s current cost strategy and competitiveness globally could however be its very own local supply chain. As Petronas tries to prosper in the current climate, the industry that supports it needs to be similarly positioned to do the same - efficient and cost competitive. With the exception of a few large players like MISC, Sapura Energy and Dialog that have the width and breadth to survive challenging conditions like in 2015 and 2016, further down the supply chain, the smaller players many of whom are just agents or third-party equipment representatives do not necessarily own technology, are extremely vulnerable to volatility. (Debt is a particularly pressing concern in this end of spectrum especially in the offshore segment, with players like UMW Oil & Gas, Dayang Entreprise and Perisai Petroleum Teknologi facing recent problems in renegotiating their debt incurred during the good times. Those who can’t keep afloat will be targets for acquisition or forced mergers, like the recent merger between UMW Oil and Gas, Icon Offshore and Orkim.) In a recent business seminar, Malaysia Petroleum Resources Corp (MPRC) senior vice-president Syed Azlan Syed Ibrahim said that “although we foresee 2017 will not be far off than 2016, I do not think it will be worse. This is the opportunity for players to make the hard decision to restructure or reform. That time is now. They (local oil & gas supply chain companies) need to do it now so that when the market goes back up they will be ready” Calls for consolidation amongst local companies, especially in the upstream segment will help strengthen the industry, allowing for greater combination of resources for increased technological innovation and value creation that is urgently needed for Petronas to be competitive locally and overseas. Less reliance on foreign US dollar denominated technology or service providers will help Petronas achieve its low cost operations goal.
As Petronas announces fewer projects in 2017 compared to pre-2014 levels, local service player will need to compete and work outside Malaysia for revenue and business growth. It will be useful here for the local oil industry to emulate the success in the Norway. As we have seen and witnessed the growth of Statoil, Norway's national oil company, as a global player in the oil industry, it is backed-up with a group of highly matured and capable technology and services providers. The grouping is now known as Norwegian Energy Partners or NORWEP in short. NORWEP looks beyond the shores of Norway for new business, and compete for projects globally. It independently (without Statoil’s direct assistance) builds relations with other governments and strategically partners with other state controlled oil companies. To date, it has achieved a respectable track record in developing new technologies in enhanced oil recovery methods as well as strong health & safety in its operations.
Looking into the future of energy, the argument for diversification into how energy will be generated, distributed and utilised also seems compelling. Shell is convinced that the next phase of fossil fuel energy will belong to gas. Petronas is well positioned in the gas business, as it continues to be within the top 3 exporters of LNG globally with strong gas reserves and infrastructure locally as well as internationally, especially in Canada. However the argument for energy diversification goes further from fossil fuels. During the 2017 CERAWeek, the fossil fuel big annual conference, most speakers proclaim a long and prosperous future for their industry. But companies and countries that rely on oil and gas income are recognizing that renewable forms of electricity are gaining traction as prices come down and their popularity rises. Oil executives are adapting their portfolios to add cleaner fuels and moderating their rhetoric on climate change. "A low-carbon future will reshape the energy space. Some see this as a threat to our industry, but we should rather look for and act on the opportunities it offers," said Eldar Sætre, CEO of Norway's Statoil. "We have to respond more forcefully to the challenge of climate change." The oil and gas industry has clearly recognized that its monopoly on transportation fuels is weakening for the first time since automobiles replaced horse-drawn carriages. To be fair, Petronas has embarked on feasibility projects in renewable energy space with the commissioning of a Solar Independent Power Plant (IPP) project in Gebeng in Kuantan. The Solar IPP project came on-stream in 2013 has a capacity of 10 megawatt peak (MWp). However this venture seems to be dwarfed by recent announcements especially from the gulf operators. Saudi Aramco is planning to produce 10 gigawatts of power from renewable energy sources including solar, wind and nuclear by 2023 and transform Aramco into a diversified energy company. The kingdom also plans to develop a renewable energy research and manufacturing industry as part of an economic transformation plan announced by Deputy Crown Prince Mohammed bin Salman. Shell, Europe’s largest oil company, has also recently established a separate division, called New Energies, to invest in renewable and low-carbon power. The new division brings together its existing hydrogen, biofuels and electrical activities. Should Petronas make bigger investment in-roads into the renewable energy sector now rather than later? Shell is projecting that it will not make any money from renewable investments at least for another 10 years. Getting ahead in the game will certainly help any new player. Noting of course that there are other players in Malaysia in the renewable energy scene, for example Tenaga Nasional Berhad or TNB is growing its portfolio in solar energy aggressively.
In conclusion, Petronas seems to be generally on the right path in evolving its energy mix and growth strategy in the energy sector. Being a state controlled company, it will require undivided political support to transform its local supply chain and embark on a commercially driven low cost structure. If the large dividends that Petronas pays annually to Government are to continue, it should be an incentive for the Government for more action to reform the industry’s supply and support base.
Petronas being a large and complex business, reforms typically take time. However due to the prolonged nature of the low oil price climate, the pace of change impacting the industry seems to be moving faster compared to previous downturns. As the oil business is global and fairly transparent in terms of revenue and cost structure, Petronas is unfortunately unable to dictate it’s not own timeline in reforming itself and the industry that supports it. “Faster the better..lah” seems to come to mind. Easier said than done.
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Source: U.S. Energy Information Administration, Monthly Refinery Report
The API gravity of crude oil input to U.S. refineries has generally increased, or gotten lighter, since 2011 because of changes in domestic production and imports. Regionally, refinery crude slates—or the mix of crude oil grades that a refinery is processing—have become lighter in the East Coast, Gulf Coast, and West Coast regions, and they have become slightly heavier in the Midwest and Rocky Mountain regions.
API gravity is measured as the inverse of the density of a petroleum liquid relative to water. The higher the API gravity, the lower the density of the petroleum liquid, so light oils have high API gravities. Crude oil with an API gravity greater than 38 degrees is generally considered light crude oil; crude oil with an API gravity of 22 degrees or below is considered heavy crude oil.
The crude slate processed in refineries situated along the Gulf Coast—the region with the most refining capacity in the United States—has had the largest increase in API gravity, increasing from an average of 30.0 degrees in 2011 to an average of 32.6 degrees in 2018. The West Coast had the heaviest crude slate in 2018 at 28.2 degrees, and the East Coast had the lightest of the three regions at 34.8 degrees.
Production of increasingly lighter crude oil in the United States has contributed to the overall lightening of the crude oil slate for U.S. refiners. The fastest-growing category of domestic production has been crude oil with an API gravity greater than 40 degrees, according to data in the U.S. Energy Information Administration’s (EIA) Monthly Crude Oil and Natural Gas Production Report.
Since 2015, when EIA began collecting crude oil production data by API gravity, light crude oil production in the Lower 48 states has grown from an annual average of 4.6 million barrels per day (b/d) to 6.4 million b/d in the first seven months of 2019.
Source: U.S. Energy Information Administration, Monthly Crude Oil and Natural Gas Production Report
When setting crude oil slates, refiners consider logistical constraints and the cost of transportation, as well as their unique refinery configuration. For example, nearly all (more than 99% in 2018) crude oil imports to the Midwest and the Rocky Mountain regions come from Canada because of geographic proximity and existing pipeline and rail infrastructure between these regions.
Crude oil imports from Canada, which consist of mostly heavy crude oil, have increased by 67% since 2011 because of increased Canadian production. Crude oil imports from Canada have accounted for a greater share of refinery inputs in the Midwest and Rocky Mountain regions, leading to heavier refinery crude slates in these regions.
By comparison, crude oil production in Texas tends to be lighter: Texas accounted for half of crude oil production above 40 degrees API in the United States in 2018. The share of domestic crude oil in the Gulf Coast refinery crude oil slate increased from 36% in 2011 to 70% in 2018. As a result, the change in the average API gravity of crude oil processed in refineries in the Gulf Coast region was the largest increase among all regions in the United States during that period.
East Coast refineries have three ways to receive crude oil shipments, depending on which are more economical: by rail from the Midwest, by coastwise-compliant (Jones Act) tankers from the Gulf Coast, or by importing. From 2011 to 2018, the share of imported crude oil in the East Coast region decreased from 95% to 81% as the share of domestic crude oil inputs increased. Conversely, the share of imported crude oil at West Coast refineries increased from 46% in 2011 to 51% in 2018.
Headline crude prices for the week beginning 7 October 2019 – Brent: US$58/b; WTI: US$52/b
Headlines of the week
In the October 2019 Short-Term Energy Outlook (STEO), the U.S. Energy Information Administration (EIA) forecasts lower crude oil prices in the fourth quarter of 2019 and in 2020 despite tighter global balances. The tighter balances are largely the result of unprecedented short-lived loss of global supply following the September 14 attacks on crude oil production and processing infrastructure in Saudi Arabia. The production declines contribute to overall stock draws in the second half of 2019 with a relatively large stock draw in the third quarter. In the fourth quarter, however, EIA forecasts global supply growth will outpace global demand growth, resulting in an inventory build, offsetting some of the third quarter draws (Figure 1). EIA lowered its crude oil price forecast for the fourth quarter of 2019 by $1 per barrel (b) to $59/b, reflecting current price trends, and lowered its crude oil price forecast for 2020 by $2/b to average $60/b because of expected supply growth.
In the October STEO, EIA forecasts total global petroleum stocks in the second half of 2019 will decrease by an average of 290,000 barrels per day (b/d), compared with the September STEO forecast stock build of 250,000 b/d for the same period. EIA forecasts total world crude oil and other liquids production for the second half of 2019 to average 101.3 million b/d, down by 550,000 b/d from the September STEO. Most of the production decline is the result of lower output from Saudi Arabia, reducing the collective output of the Organization of the Petroleum Exporting Countries (OPEC) to 34.8 million b/d for the second half of 2019.
In the October STEO, EIA assumed the Abqaiq facility and Khurais oil field would produce at their pre-attack levels by the end of October. Compared with the September STEO, EIA revised OPEC spare capacity, most of which is located in Saudi Arabia, lower by an average of 200,000 b/d in the second half of 2019. Saudi Arabia's total capacity (including spare capacity) declined following the Abqaiq attack, and EIA expects Saudi Arabia will use some of its remaining spare capacity to backfill inventories and lost production through the end of 2019. Beginning in January 2020, EIA forecasts that OPEC spare capacity will return above 2.0 million b/d.
Crude oil prices increased sharply following the attacks; Brent front-month futures prices rose by nearly 15% on Monday, September 16, the first day of post-attack trading. This increase was the largest one-day percentage increase on record for Brent front-month futures prices. The increase was larger in the front months of the futures strip than in the later months, indicating the market expected the outage to be relatively short lived, and prices fell quickly after the attack (Figure 2). Saudi Arabia continued to export crude oil by drawing from inventories, increasing production in other fields, and reducing domestic refinery inputs. Abqaiq's relatively quick return to operations likely lessened the extent and duration of the price increases. Brent front-month futures prices fell to lower than pre-attack levels on October 1, settling at $59/b for the December contract and have fallen slightly since then.
The relatively quick return to pre-attack price levels likely reflects demand-side concerns and increased down-side price risk. Despite tighter forecast global petroleum markets in the second half of 2019, EIA expects that the Brent crude oil price will average $60.63/b in the second half of 2019, nearly unchanged from the $60.68/b forecast in the September STEO. EIA forecasts that global petroleum inventories will increase by nearly 550,000 b/d in the first half of 2020, which is expected to put downward pressure on crude oil prices. EIA forecasts the price of Brent crude oil to average $57.34/b during the first half of 2020. However, EIA expects the price of Brent crude oil to increase to $62.48/b in the second half of 2020 as global petroleum stock builds slow and petroleum balances are relatively tighter than during the first half of the year.
The price forecast is highly uncertain and supply or demand factors may emerge that could move prices higher or lower than EIA's current STEO forecast. Driven by revisions to global economic outlook, EIA has revised its 2019 liquid fuels demand growth outlook lower in the STEO for the last nine consecutive months and 2020 consumption has been revised down eight of the last nine months. EIA's price forecast also accounts for a higher level of petroleum supply risk in the aftermath of the attacks in Saudi Arabia.
U.S. average regular gasoline prices increase slightly, diesel prices fall
The U.S. average regular gasoline retail price rose less than 1 cent from the previous week to $2.65 per gallon on October 7, 26 cents lower than the same time last year. The West Coast price rose by nearly 10 cents to $3.64 per gallon, and gasoline prices in California continued to rise, increasing by 14 cents to $4.09 per gallon, 55% higher than the national average and 39 cents higher than the same time last year. The Midwest price increased by more than 1 cent to $2.50 per gallon, and the Rocky Mountain price increased by less than 1 cent, remaining at $2.71 per gallon. The Gulf Coast price fell by more than 4 cents to $2.28 per gallon, and the East Coast price fell by 2 cents to $2.49 per gallon.
The U.S. average diesel fuel price fell nearly 2 cents to $3.05 per gallon on October 7, 34 cents lower than a year ago. The East Coast and Gulf Coast prices each fell by more than 2 cents to $3.04 per gallon and $2.80 per gallon, respectively, the Midwest price fell by 2 cents $2.97 per gallon, the Rocky Mountain price decreased 1 cent to $3.02 per gallon, and the West Coast price decreased by less than 1 cent to $3.64 per gallon.
Propane/propylene inventories increase
U.S. propane/propylene stocks increased by 0.1 million barrels last week to 100.8 million barrels as of October 4, 2019, 11.9 million barrels (13.4%) greater than the five-year (2014-18) average inventory levels for this same time of year. Gulf Coast inventories increased by 1.0 million barrels, and Midwest inventories rose slightly, remaining virtually unchanged. East Coast inventories decreased by 0.9 million barrels, and Rocky Mountain/West Coast fell slightly, remaining virtually unchanged. Propylene non-fuel-use inventories represented 4.4% of total propane/propylene inventories.
Residential Heating Fuel Price Survey Begins This Week
Beginning this week and continuing through the end of March 2020, prices for wholesale and residential heating oil and propane will be included in This Week in Petroleum and on EIA's Heating Oil and Propane Update webpage.
As of October 7, 2019, residential heating oil prices averaged nearly $2.95 per gallon, 41 cents per gallon lower than at the same time last year. The average wholesale heating oil price for the start of the 2019–20 heating season is $1.99 per gallon, over 48 cents per gallon below the October 8, 2018, price.
Residential propane prices entered the 2019–20 heating season averaging nearly $1.86 per gallon, 53 cents per gallon less than the October 8, 2018, price. Wholesale propane prices averaged more than $0.58 per gallon, 43 cents per gallon lower than the same time last year.