A sustained low oil price environment is a challenging one, with ‘survival of the fittest’ being an undeniable reality of the sector. Upstream E&P operators, in the past two years, have scurried to re-evaluate their operational Business as Usual (BAU) practices, implementing a myriad of measures ranging from immediate cost cutting steps such as the downsizing of the workforce, the elimination of redundancies as well as the rebalancing of portfolios as they aspire to come out of this battle stronger.
Offshore MMO Expenditure by Region 2012-2021
Whilst complying with legislative standards, an apparent trend that has surfaced is the postponement of non-critical work which otherwise would have been sanctioned in a $100 oil period. For some upstream operators, associated Inspection Repair & Maintenance (IRM) requirements have retracted by some 20-30% relative to pre-downturn levels.
While efforts to reduce bottom line figures have paid off and continue to be in play, E&P operators must acknowledge the inevitable threshold levels of Maintenance, Modifications & Operations (MMO) and IRM spending that are required in the prevention of lost-time incidents. It’s inevitable that a current ‘fix on failure’ attitude is not sustainable and operators need to re-assess the long-term sustainability of their approach given ever growing cost accruals.
As the recent World Offshore Maintenance, Modification & Operations Market Forecast 2017-2021 shows, perhaps the only positive spin on the current trough for the wider industry is a foreseeable wave of upstream MMO and IRM contracts that are due to be awarded in the coming years given existing backlogs that can no longer be postponed.
Michelle Gomez, Douglas-Westwood Singapore
Leading international energy logistics group Peterson Offshore Group BV (“Peterson”),has announced its consolidated results for the 12 months ending 31st December 2015.
Commenting on the Group’s performance Erwin Kooij, CEO of Peterson said:
“Peterson has remained profitable in what continues to be a challenging time for the energy sector. We remain committed to supporting our clients to deliver safe, innovative, cost effective solutions that enable collaboration and drive efficiency in the supply chain. Throughout the downturn we continue to invest in the design of unique concepts, technology, equipment, infrastructure and in our people. In 2015, we committed £3.1m which included new cranes, trucks, trailers and SPMT’s (self-propelled modular transporters).”
The group’s UK based companies, including Peterson UK Ltd, 80:20 Procurement Services, Peterson Freight Management and Streamba Ltd contributed 50% of the group’s operating profit, with Peterson investing in new international opportunities. North Sea revenue1 was down on 2014 at £207m generating profit before tax of £4.4m down 32% on 2014.
We successfully retained existing contracts with Maersk, BP, ENI, Centrica, and were awarded new contracts with TAQA, Transocean and ONE. We are working in close partnership with a number of operators to establish a vessel pool to share resources in the Central & Northern North Sea (CNNS), similar to our long-established and successful model in the Southern North Sea. Our decommissioning facility in Great Yarmouth, which we opened in 2015, is now fully operational, and secured its first substantial decommissioning contract. We were awarded2 two long term contracts to provide logistics support for Statoil’s Dudgeon offshore wind farm; and we are firmly into the operational phase with our nuclear industry business.
We continue to invest to take our North Sea experience overseas. We opened new offices in Trinidad and Malta to support customers in these regions and we successfully secured a number of international logistics projects. Significant investment has been made in expanding the geographic footprint of our procurement business 80:20 and we are now operating in Norway, the Netherlands, Houston and Malta.
Our ongoing commitment to technology is focused on driving efficiency and generating maximum value across our clients’ logistics operations. We made significant investment into broadening our eSuite technologies. With a continued focus on asset utilisation across the industry, our new eHire application provides simple and effective visibility and control over all third party rentals, whether regular or high cost rental; and our receipt, store and pack tools support bar coding and Warehouse Management.
Sitting above all our applications is our unique proprietary technology VOR that seamlessly connects people directly and in real time to inventory and assets throughout the supply chain. VOR provides transparency, from ordering a piece of equipment quickly, to seeing what space is available on a vessel to ship it offshore, enabling better, data driven decisions.
Our people are fundamental to our ability to deliver operational excellence and we increased our headcount by 6% in the last year and currently employ 400 people in the Aberdeen area. We made a number of key appointments to further strengthen our management team and support the next phase of the company's growth.
Our parent company approaches its centenary with a strong balance sheet, this enables us to take a long view, invest for the future and allows our clients to trust in Peterson.”
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1. Revenue, inclusive of vessel charters was down sharply on 2014, mainly driven by the reduction in vessel charter day rates with oversupply of vessels.
Another Substantial U.S. Inventory RecoveryTotal commercial stocks fell 5.1 million barrels this past week led by an almost 10 million barrel stock decline in products, with refinery turnarounds near peak levels. The 3.7 million barrel reported distillate stock decline was one of the largest this year, signaling the U.S. is in the heart of the harvesting season. Reported U.S. crude stocks now exclude lease stocks, which lowered them by roughly 30 million barrels, and week to week crude inventories built 4.8 million barrels largely because of low runs. Cushing crude stocks fell 1.3 million barrels this past week and are forecast to decline 2.3 million barrels next week because of Basin pipeline maintenance. Another large stock decline is forecast for distillate next week (-580 MB/D) with another strong pull from the farm economy, while gasoline inventories modestly build from weaker demand because of the Columbus holiday and the aftereffects of Hurricane Matthew.
Dependency on Lower 48 gas will likely increase next year as expanding domestic production losses leave a widening import gap to serve incremental demand growth. In particular, another round of PEMEX budget cuts has recently been approved, setting the stage for oil and gas production to fall by more than 10% year-on-year. Fortunately, a host of critical infrastructure projects is set to emerge in 2017, enabling imports to meet the organic demand growth within the power and industrial sectors.
With APLNG T2, the last train of the six coalseam projects in Australia, starting production, China plays a key role. Not only does it have 25% equity in two of these unconventional projects, the second largest equity stake of any Asian buyer in any liquefaction project to date, but is also a big buyer from these projects. With a slowly recovering gas demand, LNG faces competition from increased domestic production and pipeline supplies.
Seaborne coal pricing was decidedly bullish this week, with continued tightness in the prompt market pushing forwards higher, particularly in Asia. 4Q16 and 1Q17 FOB Newcastle prices rose from last week as Chinese market players returned from the Golden Week holiday. FOB Newcastle prices are now up over 100% for the year. 4Q16 API#4 prices also jumped while API#2 prices finished the week down. Pricing in the Pacific Basin has shown virtually no signs of cooling off, particularly as coking coal price settlements have been confirmed at over $200/mt. With crossover supply moving into the coking coal market, there is not much prompt thermal coal supply that could come into the market to prevent further price gains.
The International Civil Aviation Organization agreed to adopt a market-based approach to cover global aviation GHG emissions, which requires acquiring and submitting carbon offsets to cover only the increases in international aviation emissions vs. 2019-2020 levels. Exact offsetting mechanisms eligible for compliance have yet to be specified, but the design of the program suggests that costs will be very low in the early years of the program. Voluntary country-level compliance begins in 2021, with mandatory compliance not starting until 2027. Efficiency initiatives also seek to reduce aviation fuel consumption, but PIRA expects aviation emissions to continue to grow, implying that increasing levels of offsetting will be necessary for compliance.
On-peak prices weakened in New England/Mid-Atlantic and Ontario but firmed in most other Eastern Interconnect markets — primarily due to warmer-than-normal weather. Loads in the East edged up 0.5% year-on-year, while ERCOT climbed 4.7%. Henry Hub prices through October have shown remarkable strength, especially in the context of waning shoulder season demand. In contrast, Appalachian prices have inflected sharply to the downside. Looking ahead, heating season power prices will likely lag year-on-year gas gains outside of the Northeast, reducing margins.
Regionally, Asian LPG markets performed best last week. Propane cargoes arriving in November were called 5% higher at $389/MT, and butane rose by the same amount in percentage terms to $418/MT. Butane’s discount to naphtha narrowed to just $27, a price at which it becomes increasingly non-competitive as a petrochemical feedstock.
The S&P 500 moved lower on the week, with volatility up slightly, while high yield debt and emerging market debt moved a bit lower in price. The dollar was generally stronger. For commodities, there continued to be a slight upward bias, but ex-energy appears to have weakened a bit. There continues to be noted declines in the precious metals complex and an upward movement in long-term yields for a host of countries, with a lesser rise on the short end of the curve.
With fairly good weather last week, PIRA expects a 10-15% increase in both corn and soybean harvest numbers today. After posting a 35% completion rate as of last Sunday, PIRA expects that between 45% and 50% of the corn should have been harvested as of Sunday. In soybeans we expect a number close to 55% in this afternoon’s report against 44% last week.
Crude runs eased once again, with higher crude imports such that crude stocks built 2 MMBBls. Finished product stocks drew, across the board, on higher demands. Gasoline demand was modestly higher and stocks drew 0.3 MMBbls to a new 2016 low. Gasoil demand was also modestly higher and helped draw stocks. Kerosene demand was hyped by secondary and tertiary inventories pulling on primary inventories. Stocks posted their first seasonal draw of 37 MB/D. Margins and cracks eased on the week for all the major products, but they staged a bit of improvement in the last few days. Margins in September and into October have improved nicely from the abysmal levels seen in August. Levels are now judged acceptable and supportive of rising runs, post-turnaround.
Coal-to-gas switching has been a big theme emerging in European energy since late last year, but only now are we seeing it come to a head. The switch has migrated from the U.K. to the Continent, which means a potentially larger swing in gas demand on a day-to-day basis. The major flag in recent weeks is that, despite a strong push in European gas prices of more than 50%, we haven’t seen gas-to-power demand disappear. Coal prices have also experienced similar, if not greater, strength due to supply reductions, and it looks like what was once a gas market that was desperate to encourage flexible demand with weak prices is now unable to jettison it.
U.S. ethanol prices rose the week ending October 7 after a bullish DOE report and support from higher corn and oil values. Manufacturing margins declined. D6 RIN values were higher as the EPA will finalize the 2017 margins soon.
Prices increased in September with continued weak trading, but they slipped in October, with the final auction at the 2016 reserve price a month away. Going into the November 1 partial surrender requirements, sources hold enough CP2 compliance instruments to cover emissions through 2016 and free allocations for 2017 are also on the way. A severely undersubscribed November auction could see unsold allowances go to the Reserve, reducing CP2 supply. The market may deem the federal Canadian carbon price proposal bearish, but PIRA believes it can be aligned with WCI cap and trade. Environmental justice concerns over cap and trade have intensified, the market awaits the auction court decision, and critical emissions data releases are expected in coming weeks (CA, QC, perhaps ON).
Permian Basin crude and condensate production growth, as in other U.S. tight oil plays, has slowed dramatically this year. But in contrast to other plays, growth is likely to remain positive, both in 2016 and 2017. In 2018, Permian crude and condensate production is projected to rise more than 300 MB/D. New pipelines out of West Texas have more than kept up with production growth so far. Nearly 1.5 million barrels per day of takeaway capacity have been added in the past four years, creating a pipeline surplus of around a half-million barrels per day this year. As production continues to grow, this pipeline surplus capacity will erode. The only new pipeline project currently planned is a 300 MB/D Enterprise Products line from Midland to Sealy, slated for completion in 2018.
The latest EIA Monthly Crude Oil and Natural Gas Production (914) report broadly reflects PIRA’s reference case, with all regions reported either flat or in month-on-month decline for July. However, the report fails to convey the complete narrative on real-time supply.
In September, global auto sales rose to their highest level on record. In the U.S., vehicle sales remained at elevated levels and played a key role in the expansion of consumer spending. In Europe, a jump in car sales during September sent an encouraging signal about industrial production. In China and India, major growth in car sales is driving gasoline demand substantially higher.
Pakistan’s Oil and Gas Regulatory Authority (Ogra) has said that no increase in the gas price for domestic as well as fertilizer feedstock was proposed by the authority. A spokesman clarified that a news item — that claimed an increase in gas prices by 36% was forthcoming — was not true. The spokesman further explained that the Ogra had issued its decisions with respect to SSGCL and SNGPL’s petitions for determination of prescribed price for FY 2016-17 on October 6, 2016. In the case of SSGCL, Ogra determined the average prescribed price at Rs354/MMBtu ($3.37/MMBtu). In the case of SNGPL, Ogra had determined its average prescribed price at Rs480/MMBtu ($4.57/MMBtu).
One side effect of the ongoing French nuclear issues is the disruption of the historical interconnector flows across Europe. Those French flows with Spain are no exception. Last week, Spain turned into a net exporter to France, reaching a daily flow of 2 GW on Wednesday, a multi-year high in the fourth quarter. This amount of exports is occurring even in the context of relatively stronger demand in Spain (weather-adjusted loads are reported to be up 1.6% year-over-year), together with low hydro and wind output, supporting domestic Spanish thermal generation from both coal and CCGTs.
The announcement of Mexico’s intention to export Maya to the USWC signals that the domestic refining system is struggling with operational issues and that the USWC could be an economically advantaged destination relative to Asia or Europe, the usual marginal Maya markets.
U.S. ethanol dropped 22 MB/D to 962 MB/D the week ending October 7, the lowest since June as some plants continue their seasonal maintenance. Stocks fell by 784 thousand barrels to 19.4 million barrels, the lowest level thus far in 2016. Ethanol-blended gasoline value was relatively flat.
Chinese car sales rose at a fast pace this year, and gains were particularly strong in September. The number of cars on the road, therefore, continues to expand rapidly, and gasoline demand is rising accordingly. PIRA’s model, comprised of car fleet size, distance traveled, and fuel efficiency, pointed to recent demand growth of about 300 MB/D year-on-year, and this estimate was roughly in agreement with reported demand figures. Recent gains in truck sales were more modest, and pointed to a small increase in transport-related diesel demand.
Global equities were broadly lower on the week. In the U.S., utilities posted a moderate gain and consumer staples were little changed, but all the other indices fell back. Energy basically matched the market decline of about 1%. Internationally, Latin America moved higher, but all the other tracking indices gave ground. Most of those declines exceeded that seen in the U.S. market.
The new heating season is off to a cold start in Europe and Japan while weather is warmer in the U.S. With half the month completed and a second half forecast, October is expected to be 6% colder than the 10-year normal and 7% warmer on a 30-year-normal basis.
French nuclear outages are an ongoing factor, but EU carbon prices also rose in early October in sympathy with strong rises in thermal fuels prices. Continued gains in thermal fuels prices should support carbon prices in their current range for the balance of 2016. An EU Parliamentary committee (ITRE) approval of post-2020 market reforms seems positive, but a lack of substantive progress in a more important committee (ENVI) ahead of a December vote is concerning. PIRA is not currently building in additional 2016 policy support, but constructive negotiations ahead of ENVI’s vote can push prices upward. Neither the supply nor the demand side support 2017 price gains, at a time when Brexit negotiations add policy risk.
At its Annual Client Seminar, October 6-7 in New York, PIRA tackled the subject of a challenging farm economy. Here is the presentation.
The information above is part of PIRA Energy Group's weekly Energy Market Recap - which alerts readers to PIRA’s current analysis of energy markets around the world as well as the key economic and political factors driving those markets.
In a move to increase foreign investment amid the nation’s worsening economic position, Brazil’s Congress has approved legislation that will remove state-controlled Petrobras’ obligation as sole operator on the country’s pre-salt developments. Discovered in 2007, these ultra-deepwater fields represent a huge opportunity – they are the largest group of offshore reserves discovered this century.
Financial difficulties resulting from the ongoing low oil price environment, combined with the crippling impact from the “Operation Car Wash” corruption scandal, have slowed development in the prolific pre-salt fields, as mounting financial pressure has led the NOC to cut Capex plans and production targets. The opening of these deepwater assets to foreign investors is intended to increase development and production from the pre-salt fields, whilst allowing Petrobras to shift focus to more developed plays with existing infrastructure and lower Capex requirements.
Due to the significant potential the pre-salt fields offer, many international E&P companies can be expected to vie for a slice of the substantial pie – Shell has previously commented on the nation’s need to open up to foreign investment. However, E&P activities in Brazil are largely controlled by Petrobras – the few internationals currently active in deepwater Brazil, namely Shell and Anadarko, may see themselves tied to commitments elsewhere. Shell’s recent acquisition of BG sees the company bound to projects inherited through the deal; and Anadarko has the large Shenandoah discovery in the GoM, as well as advancing developments in Mozambique.
As such, the impact from last week’s legislation change may not be as significant as the nation’s government hopes. The current oil price environment has the potential to deter some operators from the huge Capex required for ultra-deepwater developments, particularly if not already present in the nation. However, if OPEC’s recent announcement to cut production results in a significant oil price rally next year, it may become somewhat of a moot point, increasing the attractiveness of the pre-salt fields to international investors.
Kathryn Symes, Douglas-Westwood London
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