Finance News

piraNYC-based PIRA Energy Group reports that oil inventories are higher and crude demand is lower.  In the U.S., stock surplus to last year is roughly flat. In Japan, crude stocks draw amid peak run rates.  Specifically, PIRA’s analysis of the oil market fundamentals has revealed the following:

World Oil Market Forecast

Oil inventories are higher, crude demand is lower and PIRA is beginning to question the expected 2H 2014 and 2015 lift off in economic activity. Also, add in unrelenting upward revisions to U.S. oil supply growth with non-OPEC supply additions continuing to substantially outpace demand growth and you have a combination of factors pointing to lower prices.

Stock Surplus to Last Year Roughly Flat

This past week’s inventory increase kept the year-on-year overall stock surplus to around 4 million barrels. The crude inventory decline took crude stocks slightly below last year, and at current high run rates crude stocks are still relatively tight, which was reflected in September relative prices. The product stock change reflected lower product imports (to a new low for the year) being offset by weaker reported demand and higher product output.

Japanese Crude Stocks Draw Amid Peak Run Rates, Finished Product Stocks Continue Building

Runs rose fractionally on the week and lower crude imports led to a crude stock draw. Finished products, however, have continued rising amid peak runs. Gasoline demand was higher but is still seen as underperforming seasonal expectations. Gasoil demand rebounded from very low levels. Kerosene stocks continued to build along seasonal norms. All the product cracks improved on the week and our indicative margin indicator rose, but remains rather weak.

Impact of Russian Gas Flow Interruption on Oil Demand

In the low probability event of a complete Russian gas flow stoppage to Europe, oil demand could potentially increase 600 MB/D. In the more likely scenario, still just 30% probability, of a stoppage of flows through Ukraine to Europe, the impact on oil demand would not be material.

U.S. Refinery Turnarounds, September 2014 – December 2015

There was a relatively high level of crude unit downtime during August and the level of both planned turnarounds and other outages carrying over from the current month is expected to increase over the next couple of months.

Freight Market Outlook

A glut of crude oil in the Atlantic Basin has caused the flat price of crude to fall and regional grade differentials with Asia to narrow substantially. The Brent-Dubai spread has narrowed to its lowest value in four years, prompting a significant increase in the number of West African cargoes headed to Asia in August. In addition, the Dubai price structure is now in contango, with forward prices higher than those for the prompt month, making it easier to hedge cargoes on the long voyages from the Atlantic. This is a good omen for VLCC operators as more vessels are tied up on long voyages around the horn of Africa from the Atlantic to Asia. The flip side, of course, is that Mideast liftings to Asia in the fourth quarter will have to decline to make room for the added Atlantic Basin supplies.

Asian LPG Prices to Benefit from Lower Saudi CPs

LPG prices in Asia held steady this week, prior to this weekend’s imminent release of Saudi contract prices for Sept tons. CP futures prices indicate that the propane CP could fall while Asian destination markets show that the butane CP could remain flat or perhaps drop by $10/MT.

Ethanol Demand Soars

U.S. ethanol-blended gasoline manufacture soared to 8,904 MB/D the week ended August 22, up from 8,667 MB/D during the prior week and very close to the record 8,980 MB/D set in May. Ethanol output dropped to 913 MB/D, the second lowest rate of production since April.

U.S. Ethanol Prices Rise in August

Ethanol prices rose in August, after falling during the prior three months. The market tightened as stocks drew by the largest amount since March 2013.

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.

piraNYC-based PIRA Energy Group reports that there was the largest 2Q stock build in the last 10 years. In the U.S., there was a modest U.S. stock build. Specifically, PIRA’s analysis of the oil market fundamentals has revealed the following:

Largest 2Q Stock Build in Last 10 Years

Last week’s release of IEA stock data, combined with weekly data in the United States and Japan, show that commercial oil inventories in the three major OECD markets increased in the second quarter. Weak economic activity has undermined oil demand, forcing supplies into inventory. Higher inventories are undercutting PIRA’s confidence in its most recent oil price forecast. In contrast to Brent, front-month WTI remains well supported relative to further-out contracts by extraordinarily low inventories and strong September refinery demand.

Modest U.S. Stock Build

Overall commercial inventories increased this past week, keeping stocks relatively flat to last year’s level. The inventories of the four major products are 22 million barrels below last year, while crude is 6 million barrels higher.

PIRA Lowers Price Outlook

While we have not formally updated our detailed supply/demand balances, which will be done later this month, it is becoming clear that, because of weaker demand, inventories will be much higher than last month’s forecast. We should note that some of today’s downward price pressure could be coming from producer hedging.

2Q14 Tight Oil Operator Review

Second quarter results were positive across the board. There were no lingering effects from the harsh winter with considerable production gains in the Bakken, the Eagle Ford, the Niobrara and the Permian. Many operators cited renewed gains in completion efficiencies in mature plays, as well as growing success in smaller plays like the Powder River. Bakken and Eagle Ford operators increased frac sizes and laterals, leading to higher IPs and EURs. Yet the focus of the industry was centered on the delineation and development of the Permian basin, where the production potential continues to grow with the identification of further productive layers.

U.S. Ethanol Output Tumbles

For the week ending August 8, most U.S. ethanol prices rebounded from the lowest level in several months after the DOE reported production had plummeted and inventories decreased during the week ending August 1. Manufacturing margins declined slightly as the lower average price for ethanol and co-product DDG outweighed the fall in corn costs. U.S. Ethanol Inventories Fell to a 11-Week Low 17.8 Million Barrels Ethanol-blended gasoline production soared to a seven-week high 8,902 MB/D the week ending August 8, fairly close to the record 8,980 MB/D set earlier this year. As ethanol demand rose, inventories fell to an 11-week low of 17.8 million barrels, down 500 thousand barrels from the previous week.

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.

*Increase in Non-OPEC production to exceed growth in Global Oil Demand in 2014, reducing call on OPEC productionGlobaldatabluelogoGlobal oil demand in 2014 is forecast to increase by about 1.2 million barrels per day (mmbd) compared to 2013 levels, while non-Organization of the Petroleum Exporting Countries (OPEC) members' production will grow by approximately 1.6 mmbd, reducing the call for OPEC production, according to research and consulting firm GlobalData.

The company's report* states that a significant increase in non-OPEC production is forecast to occur, particularly in North America, where crude oil and condensate production will increase by about 1.3 mmbd.

Carmine Rositano, GlobalData's Managing Analyst covering Downstream Oil & Gas, says: "Crude oil production increases are also expected in South America, the Former Soviet Union and from the greater use of biofuels. This will more than offset slightly lower production anticipated in the North Sea and Mexico.

"The growth in US oil production of just over 1 mmbd, combined with the expansion of Canadian production, will continue to reduce imports into North America. These could then flow into Asia, where the rise in oil demand will greatly exceed the slight increase forecast in local production."

Venezuelan crudes are now more likely to end up in Asia than North America, as Asia imported just under 1 mmbd of Venezuelan crudes in 2013. This has increased tonne-mile demand in the tanker industry for Very Large Crude Carriers, while decreasing the need for shorter-haul tanker movements into North America, according to the analyst.

Rositano continues: "Crude oil supply patterns and pricing differentials, along with marine freight rates and refining margins, will continue to be impacted by North America's higher forecast production levels, especially if the current ban on exporting US crude oil remains in place.

"It will be interesting to see which OPEC member will reduce its production should Iraq's output continue to increase and when Libyan production comes back online. It also remains to be seen whether Iran's export level will increase, should it reach an agreement over the nuclear issue with the West.

 *Increase in Non-OPEC production to exceed growth in Global Oil Demand in 2014, reducing call on OPEC production

This report provides a comparison of global oil demand and supply for 2014 versus 2013, detailing the increases in non-OPEC oil production and its effect on the supply of OPEC crude oil. It includes an evaluation of geopolitical risks and details of demand levels by product (gasoline, diesel/gasoil and aviation jet fuel) in both regional and global terms.

This report was built using data and information sourced from proprietary databases, primary and secondary research, and in-house analysis conducted by GlobalData's team of industry experts.

oceaneeringlogoOceaneering International, Inc. (NYSE: OII) has reported record quarterly earnings for the second quarter ended June 30, 2014.

On revenue of $927.4 million, Oceaneering generated net income of $110.3 million, or $1.02 per share. During the corresponding period in 2013, Oceaneering reported revenue of $820.4 million and net income of $98.8 million, or $0.91 per share.

Summary of Results
(in thousands, except per share amounts)

                             Three Months Ended                                                   Six Months Ended
                                   June 30,                         March 31,                              June 30,

                           2014             2013                     2014                           2014              2013

Revenue           $ 927,407      $ 820,372             $ 840,201                 $ 1,767,608      $ 1,538,924

Gross Margin       218,215        201,864                 189,491                      407,706           362,239

Income from Ops. 161,311       146,337              132,862                         294,173           254,627

Net Income         $ 110,295     $ 98,811              $ 91,225                     $ 201,520        $ 173,660

Diluted Earnings

Per Share (EPS)         $1.02         $0.91                    $0.84                            $1.86             $1.60


Year over year, quarterly EPS increased on profit improvements from Subsea Products, Remotely Operated Vehicles (ROV), and Subsea Projects. Sequentially, quarterly EPS rose on higher operating income principally from Subsea Products and Subsea Projects.

M. Kevin McEvoy, President and Chief Executive Officer, stated, "Our quarterly EPS was slightly above our guidance, and was up 21% over the first quarter of this year and 12% over the second quarter of 2013. EPS for the first half of 2014 was 16% higher than the first half of 2013. We achieved record quarterly operating income from Subsea Products, and for the first time Subsea Products operating income exceeded that of ROV.

"Our outlook for the second half of this year remains positive and unchanged overall from last quarter. Given this outlook and our year-to-date performance, we are narrowing our 2014 EPS guidance range to $3.95 to $4.05 from $3.90 to $4.10. Relative to the first half of 2014, we expect to generate higher income from each of our operating segments during the second half, led by ROV and Subsea Projects. We continue to forecast year-over-year operating income growth for all of our oilfield segments in 2014.

"Compared to the first quarter, Subsea Products operating income rose on the strength of increased revenue and profitability from tooling and subsea hardware. Subsea Products backlog at quarter end was $850 million, compared to our March 31 backlog of $894 million and $902 million one year ago. During the quarter we announced one large umbilical contract for offshore Indonesia.

"ROV operating income was essentially flat, as operating margin declined due to higher repair and maintenance expenses, unanticipated startup costs associated with placing new systems in service, and lower fleet utilization. Revenue grew on increases in days on hire and revenue per day on hire. During the quarter we put 13 new ROVs into service and retired 4. At the end of June we had 323 vehicles in our fleet, compared to 296 one year ago.
"During the second half of this year, we expect to place at least 13 new ROVs into service, and we have contracts for all of these. When these new vehicles are placed into service depends upon the actual commencement dates of new drilling rig and vessel project work. We now anticipate adding 40 or more new systems to our ROV fleet in 2014.

"Sequentially, Subsea Projects operating income increased largely as a result of adding a vessel, the Bourbon Evolution 803, to our Field Support Vessel Services contract with BP for work offshore Angola and a higher profit contribution from the Ocean Alliance in the U.S. Gulf of Mexico. The Ocean Alliance was out of service for much of the first quarter undergoing a regulatory drydock inspection. Asset Integrity operating income improved slightly due to a seasonal increase in activity in Europe and the Caspian Sea area. Advanced Technologies operating income declined due to execution issues on certain U.S. Navy and industrial projects.

"For the third quarter of 2014, we are projecting EPS of $1.10 to $1.15. We expect sequential improvements in income from all of our operating business segments, led by ROVs.

"Our liquidity and projected cash flow provide us with ample resources to invest in Oceaneering's growth. At the end of the quarter, our balance sheet reflected $103 million of cash, $80 million of debt, and $2.2 billion of equity. During the quarter we generated EBITDA of $217 million, $403 million year to date, and for 2014 we anticipate generating at least $855 million.

"In June we increased our regular quarterly cash dividend by 23% to $0.27 from $0.22 per share. This underscores our continued confidence in Oceaneering's financial strength and future business prospects.

"Looking beyond 2014, we believe that the oil and gas industry will continue its investment in deepwater projects. Deepwater remains one of the best frontiers for adding large hydrocarbon reserves with high production flow rates at relatively low finding and development costs. With our existing assets and opportunities to add new assets, we are well positioned to supply a wide range of services and products to safely support the deepwater efforts of our customers."

GlobaldatabluelogoA Chinese company with both the capital and ambition to strategically expand its influence is the most likely suitor for Citgo Petroleum Corporation (CITGO), which state-owned Petróleos de Venezuela, S. A. (PDVSA) is looking to sell for at least $10 billion, with a Canadian bid also possible, says an analyst with research and consulting firm GlobalData.

Carmine Rositano, GlobalData's Managing Analyst covering Downstream Oil & Gas, states that Chinese companies, such as Sinopec and China National Offshore Oil Corporation, have already invested billions of dollars in Canadian oil sands projects and could use their equity production to supply heavy sour crude oil to the CITGO refineries.

GlobalData asserts that while the assets on offer are strategic to the US energy complex, a Chinese bid would be more flexible in terms of structuring a deal that meets PDVSA and Venezuela's requirements.

Rositano says: "Venezuela currently exports 500 thousand barrels per day (mbd) of crude to China to pay off its $17 billion debts, but additional loans now require a further 100 mbd. Despite extensive reserves, PDVSA has struggled to meet production targets as the government has allocated increasingly less funding to upstream development.

"As such, freeing up crude that would otherwise be sold to CITGO would enable Venezuela to meet its obligations with China."

Another possibility is that a Canadian oil company will bid for CITGO's assets. Suncor and Husky Oil own refineries in the US, with Suncor processing Canadian crudes at its facilities and Husky Oil upgrading its refinery to increase the running of Canadian oil sand crudes.

Rositano explains: "Canadian oil sands crude production is forecast to increase steadily, and the status of proposed pipelines to transport crudes to Canada's west coast for exports is now uncertain, with lawsuits against the proposals pending.
"Purchasing the three CITGO refineries, which are already geared to run heavy sour oil sand crudes, would appear to be a good option for a Canadian oil company."

Although PDVSA has long considered selling CITGO, Rositano believes the timing is now better than ever, and says that reasonable offers are not only likely to be considered, but previous deals suggest that they will be lower than the reported $10 billion asking price.

Successful Transformation from an Oil Trading, Transportation and Storage Company to a Resource-based Energy Enterprise

BrightoilBrightoil Petroleum (Holdings) Limited ("Brightoil Petroleum" or the "Group"; stock code: 933.HK) announced the closing of a stock purchase agreement (the "Agreement") with Anadarko China Holdings 2 Company Limited ("Anadarko China"), a wholly-owned subsidiary of Anadarko Petroleum Corporation ("Anadarko Petroleum"), to acquire a participating interest in two oil producing blocks in Bohai Bay (Contract Area 04/36 and Unit Area 05/36) at a consideration of USD
1.046 billion.

Following the signing of the agreement on 18 February, the acquisition was successfully completed on
8 August after six months of efforts put together by both parties. After the closing of the Agreement, the Group now holds a 40.09% participating interest in the 124km2 offshore block (Contract Area 04/36) and a 29.18% participating interest in the 88 km2 offshore block (Unit Area 05/36). The operator of both blocks is CNOOC China Limited ("CCL").

As a result of this, the Company's oil and natural gas resources extend from the ground to offshore, and the Company's oil and natural gas storage and production will increase immensely. Together with its originally owned Dina1 and Tuzi natural gas field, the Company's interest in 2P storage is expected to reach approximately 86 million boe. When all these three areas are in operation, Dina1 and Tuzi and Bohai will reach a daily net production of approximately 25,000 boe, and an annual net production of approximately 9 million boe. Upon this successful Closing, the Company will reach a solid step-out and broaden its activities into energy resources supply and operation.

Dr. Sit Kwong Lam, Chairman of Brightoil Petroleum, said, "We believe that the closing of the acquisition marks the successful transformation of the Group in its aim to become a resource-based energy enterprise. The Group will continue to strengthen its development in the upstream business, aiming to achieve sustainable growth of its reserves, production volume and revenue in the long run. This will accelerate the Group's development into an international integrated oil & gas conglomerate and at the same time enhance our returns to investors and create further shareholders' value. "

About Brightoil Petroleum
Brightoil Petroleum (Holdings) Limited is a resource-based energy enterprise focusing on upstream oil and gas resources exploration, along with further developments downstream. The Group is principally engaged in the Exploitation and Production of Upstream Oil and Gas Fields, Marine Transportation, Oil Storage and Terminal Facilities and International Trading and Bunkering Business.

The Group has three oil and gas field projects in its portfolio, including Dina1 Gas Field, Tuzi Gas Field and Caofeidian Field in Bohai Bay. The Company's interest in 2P storage is expected to reach approximately 86 million boe. When all these three areas are in operation, Dina1 and Tuzi and Bohai will reach a daily net production of approximately 25,000 boe, and an annual net production of approximately 9 million boe.

The Group currently operates four Aframax Oil Tankers and five VLCCs, and has a marine transportation capacity that will exceed 2 million tons.

The Group's oil storage facility on Waidiao Island in Zhoushan, with a total capacity of 3.16 million cubic meters, is under construction. The facility will be equipped with 13 berths which can accommodate vessels from 1,000 to 300,000 DWT. Meanwhile, the Group's oil storage facility on Changxing Island in Dalian, with a total capacity of 7.19 million cubic meters, is also under construction. The facility will be equipped with 13 berths to accommodate vessels from 1,000 to 300,000 DWT.

The Group is one of the largest marine bunkering service providers in China with services expanded to global ports. The Group's tradable range of products is diversified into fuel oil, crude oil, gas oil, as well as petrochemical and the related petroleum products. The annual trading and supplying volume has reached approximately 20 million tons.

The Group will continue to develop its upstream business by stretching its tentacles into the exploration, exploitation and production of oil fields with a view to becoming one of the leading resources-based energy conglomerates in the world.

douglas-westwoodThe downing of flight MA17 has prompted calls for further sanctions on Russia targeted at its energy sector. Russia is the world's largest exporter of natural gas and second largest exporter of oil which together account for near 60% of its export earnings. Gazprom supplies 30% of Europe's gas - some 15% via Ukraine - and has warned exports will be affected if sanctions are expanded. But in its payments row with Ukraine Gazprom has already stated that it will "only be supplying the exact amount of gas requested by our European partners to the Russia-Ukraine border". Considering that Ukraine itself needs to draw gas supplies from the same pipelines, Europe is already threatened with gas shortages.

But Russia itself also faces challenges, namely in maintaining – let alone growing – production as existing fields deplete. In 2000, it drilled 3,770 wells and production was some 17 million boe/day. By 2013 it was drilling some 7,500 wells and achieved a production of 23 million boe/day – well numbers up 99% for a production gain of 35%. On this basis at DW we forecast it will need to be drilling over 8,800 wells in 2020 and in increasingly more difficult areas, hence the Exxon rig sailing to location in the Russian arctic (much to the embarrassment of some on Capitol Hill).

The Russian economy is already in a mess and to maintain its oil & gas production it increasingly needs to access western capital markets and advanced oilfield technologies. Sanctions that severely hit its energy production will indeed work and cripple the Russian economy, but could cause oil prices to soar and thereby impact the still fragile global economy.

But the real lesson of this whole affair is for Europe – it is far too reliant on imported energy. No single type of energy source or supplier is immune from problems and Douglas-Westwood have long warned that Europe is sleep walking into an energy crisis due to lack of investment in both 'home grown' base-load energy sources such as nuclear power and shale gas, in energy storage and Europe-wide integrated transmission networks.

Asset-Guardian-Logo-Transparent-Background-Large-PNGAsset Guardian Solutions Ltd (AGSL), which specializes in protecting companies' process critical software assets, announced that it has been awarded a key contract by a major North Sea operator in Aberdeen, Scotland.

The contract requires AGSL to provide Asset Guardian, a process software management tool that helps to secure the integrity of process software and the mission critical processes that it controls.

Protecting integrity of process critical software on North Sea assets

AGSL will install Asset Guardian software on all of the operator's assets in the North Sea. Asset Guardian software provides a multifaceted, single point solution to manage the process control software it uses to operate these assets. It also ensures that the company complies with all relevant regulatory standards and government directives on process critical systems, such as IEC61508, 61511, ISO 9001, CPNI and HSE KP4 among others.

By using Asset Guardian, the operator will operate with a single secure repository in which all software and data for its North Sea assets is stored. By doing so, critical information is centralized, providing authorized personnel – both onshore and offshore - with access to one source of data, dramatically enhancing workflow.

In addition to preventing unauthorized access to process software, Asset Guardian makes it possible to retrieve back-up files and data required to update or replace system software that has been corrupted or failed, quickly and efficiently. As a result, negative impact upon production is dramatically reduced.

Improving communications enhances operations

Because these assets operate in the rugged, often stormy North Sea, communication links between the assets and onshore cannot always be relied upon. "To address this, we are also providing AGSync, a software solution that we developed especially for the oil and gas industry that makes it possible to synchronize data and files between locations," said Sam Mackay, Managing Director of AGSL.

In addition to providing Asset Guardian software, AGSL will also assist this customer with the migration of files and data from existing systems into Asset Guardian and provide full training to both Users and system Administrators using the recently launched Asset Guardian Computer Based Training (CBT) program.

Since 2007, AGSL has been supplying the oil and gas industry with the Asset Guardian toolset. The award of this contract follows on the heels of several others, including those from Woodside, Inpex, Stena Drilling, BP, Marathon, and nuclear energy provider EDF Energy

piraNYC-based PIRA Energy Group reports that there is potential for Iceland volcano eruption to disrupt North Atlantic air traffic and jet fuel demand.  In the U.S., crude stocks draw larger than the product stock build. In Japan, low demand builds product stocks.  Specifically, PIRA’s analysis of the oil market fundamentals has revealed the following:

Potential for Iceland Volcano Eruption to Disrupt North Atlantic Air Traffic and Jet Fuel Demand

Iceland’s Met Office warned that the country’s largest volcano might erupt, potentially posing a threat to air traffic in the North Atlantic. This is reminiscent of 2010’s eruption of Iceland’s Eyjafjallajökull volcano, which disrupted air traffic in the North Atlantic and Europe for about a week cutting oil demand.

U.S. Crude Stocks Draw Larger than Product Stock Build

The August 15 commercial stock draw was less than last year’s draw, widening the year-over-year stock excess. The crude draw exceeded last year’s, narrowing the crude excess versus last year. The four major refined product stocks built a collective 1.4 million barrels, and with a draw last year, their collective deficit narrowed. All other product stocks built less than last year so their excess narrowed. We remain in the pattern of the major refined products being in deficit, all other products being excess, and the crude stock position osculating from looser to tighter, especially when considering stocks required for crude infrastructure expansion.

Low Demand in Japan Builds Product Stocks

Two weeks of data were reported this past week due to the annual mid-August hiatus. Crude stocks rose over the last two weeks, but more troubling was a large build in finished stocks, much of it gasoil, but to a lesser extent kerosene (seasonal), and fuel oil. Demand in the latest week was extraordinarily low.

Asian LPG Prices Stronger

Recent strength in local South China prices helped lift LPG more than 2% in Asia this week. Propane cargoes for October delivery were called $18.50 higher at $836.50 while butane rose by the same amount to $876.50/MT. The October Propane FEI settled $6 higher than the cash market. Lower imports into China, in part due to a change in tax invoicing, has led to inventory draws – prompting a $32/MT rally in local prices last week. Strong discounts to naphtha and improved seasonal demand should support prices next week while recent price strength leaves room for a correction.

U.S. Ethanol Output and Stocks Rise

U.S. ethanol production reached 937 MB/D the week ending August 15, up from 931 MB/D during the previous week as more plants are operating near capacity. Stocks built 491 thousand barrels to 18.3 million barrels.

U.S. Ethanol Prices and Margins Increased

Ethanol prices soared the week ending August 15 as the market tightened. Demand in the domestic and export markets were strong, while production remained significantly below the June peak.

Global Political Risk - Political Risk Scorecard

Growing Libyan exports, continued U.S. intervention in Iraq, and reduced tensions in Ukraine will weigh on prices next week.

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.

douglas-westwoodRecent news headlines on the LNG sector in Australia seem to be centered around its unsustainable rising costs. Woodside Petroleum had to ditch plans last year for its Browse LNG plant, which had gone way over budget at an estimated cost of US$80bn. In the interest of continuing the development, Woodside and its partners have now turned to FLNG vessels as a practicable alternative. More recently, Santos and GDF Suez have also scrapped plans to build gas plants off the Northern Territory Coast of Australia. Projects that have gone ahead have seen significantly increased costs. At approximately 80% completion, the Gorgon LNG project is now estimated to cost US$54bn – a sharp contrast to the original budget of US$37bn (46% over-budget).

In the meantime, despite Australia's LNG cost challenges, the United States is moving forward with the possibility of bringing onstream an LNG plant that would cost between US$2.2bn and US$3.7bn. Magnolia LNG in Louisiana is expected to come onstream in 2018, potentially the nation's first LNG export plant with the capability of processing 8 million metric tons per annum. This shows the feasibility of constructing similar infrastructure at that price, but outside Australia!

Australia's Woodside is, at the same time, looking to make a move overseas in search of better economics. The country stands to lose US$97 billion of potential LNG projects to East Africa and North America unless radical cost reduction is applied. Furthermore, Russia and China's $400bn gas deal could possibly undermine several of Australia's gas projects.

Australia has actively been finding ways of implementing reforms in an attempt to reduce operating costs. Even with the recent Russia-China deal, pipeline gas from Russia will only be supporting 6% of China's gas demand by 2030. China cannot avoid seeking diversity in its energy sources. New technologies and innovations, such as the much-anticipated FLNG vessels, will present themselves as potential solutions. With these cost-reducing opportunities/ challenges, it proves to be interesting how the scenario will play out for Australia, new LNG producer entrants elsewhere and the potential for new gas pipeline suppliers to China.

piraNYC-based PIRA Energy Group believes that the global economy will expand at above trend pace in the second half of 2014. In the U.S., products increased and crude stock declined.  In Japan, crude stocks built as imports rebounded from storm impacts. Specifically, PIRA’s analysis of the oil market fundamentals has revealed the following:

World Oil Market Forecast

After a sub-par first half, the global economy will expand at above trend pace in the second half of 2014, led by manufacturing. First half weakness in the economy undermined global oil balances with inventories building back to year ago levels. The U.S. crude inventory situation is quite tight while Europe is very long, although the worst of the European prompt crude price weakness has likely passed. The sharp decline in financial net length is supportive for nominal oil prices.

Again, a Product Increase and Crude Stock Decline

Overall U.S. commercial oil inventories increased compared to last year’s decline for the same week, expanding the year on year inventory excess. The product stock increase was roughly the same compared to the week earlier, as crude runs, product imports and reported demand did not change much. The crude inventory gap narrowed by 3.5 million barrels - to a still large 4 million barrels.

Japanese Crude Stocks Build as Imports Rebound from Storm Impacts

Runs continued to rise as turnarounds wind down. Crude imports jumped higher following typhoon disruptions and crude stocks built. Gasoline demand was only slightly higher, despite the upcoming holiday and stocks built from record lows. Gasoil demand was higher with a big surge in exports such that stocks drew 1 MMBbls. Kerosene demand remained low and stocks continued building.

Profitability of U.S. Shale Oil Plays: The Paradox of Company vs. Well Results

It is possible that individual shale wells may have breakevens well below current oil prices while the companies that are drilling those wells are struggling against cash flow limitations. The inability of companies to turn cash flows positive has raised the question of whether the shale industry is really viable financially in the long-term, or just supported by cheap money. An in-depth analysis of the play economics shows that negative cash flows are mostly a result of aggressive drilling behavior that should eventually reward investors.

LPG Scorecard

U.S LPG prices remained stable despite large increases in domestic inventories. The promise of increased exports has the bears on the sidelines, for now. Mt Belvieu propane settled at 104¢/gal, up marginally on the week. August/February contango in the propane forward curve increased by 0.6¢ in the week, to 5.2¢. Butane prices were flat. Ethane at Mt Belvieu fell with Henry Hub natural gas. Ethane’s fractionation margin remains negative, albeit by only 1¢/gal, reflecting the lack of outlets and high inventories currently facing the cracker feedstock. High and rising inventories will contain prices while the prospect of higher exports and the nearing end of summer will be supportive for U.S. LPG prices next week.

U.S. Ethanol Manufacturing Margins Lower

Chicago and Gulf Coast ethanol prices were stable the week ending July 18, but values in Southern California rose while prices in New York fell. Ethanol manufacturing cash margins were down slightly, as falling DDG values outweighed lower corn costs.

U.S. Ethanol Output Rises

U.S. ethanol production increased to 959 MB/D the week ending July 18, the second highest output of the year. Inventories were relatively flat, declining by only 5 thousand barrels to a five-week low 17.9 million.


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.


logoThe board of directors of Aker Solutions ASA ("Aker Solutions") has in accordance with the strategy disclosed April 30 resolved to propose to the company's shareholders that Aker Solutions be split into two companies. The board has also determined to write down the value of some assets in the Aker Oilfield Services unit of Akastor, one of two companies that will emerge from the separation.

Aker Solutions Holding ASA ("New Aker Solutions") - a subsidiary of Aker Solutions ASA established for the purposes of the demerger and which will apply for listing of its shares on the Oslo Stock Exchange - will through the proposed demerger assume Aker Solutions' activities in the following areas of operation: Subsea (SUB), Umbilicals (UMB), Maintenance, Modifications and Operations (MMO) and Engineering (ENG). New Aker Solutions will operate under the Aker Solutions name from the first day of listing.

From the first day of listing of New Aker Solutions, the existing Aker Solutions ASA will change its name to Akastor ASA to form the Akastor Group together with the other subsidiaries that have not been transferred to New Aker Solutions. The Akastor Group will, among other things, continue Aker Solutions' activities mainly related to Drilling Technologies, Process Systems, Surface Products and Aker Oilfield Services, as well as Business Solutions, some financial assets and real estate.

On completion of the demerger, consideration shares in New Aker Solutions will be issued to the shareholders of Aker Solutions. Each share in Aker Solutions will give the right to one consideration share in New Aker Solutions. The consideration shares will constitute 100 percent of the outstanding shares in New Aker Solutions as of completion of the demerger.

The demerger is subject to approval by the shareholders of Aker Solutions at the Extraordinary General Meeting to be held on August 12, 2014, and depends, among other things, on the approval of the application to list New Aker Solutions shares on the Oslo Stock Exchange.

Based on external and internal valuations, the board of Aker Solutions determined an allocation of Aker Solutions' share capital so that 35.2 percent of the share capital would be allocated to Aker Solutions (to be renamed Akastor) and 64.8 percent to New Aker Solutions. This is in accordance with the allocation of net values between the two companies as a consequence of the demerger. The allocation is mainly based on internal and external evaluations of future cash flow and also takes into account the businesses' risks and prospects. Aker Solutions has as part of the demerger plan adopted an interim balance sheet that is included in the demerger plan.

The board determined to recognize impairments and a provision, which are reflected in the above-mentioned valuation, of about NOK 1.6 billion on some assets and goodwill of the Aker Oilfield Services unit of Akastor. The value of Aker Oilfield Services' investments in the Skandi Aker and Aker Wayfarer vessels will be written down and a provision will be made on future leasing commitments for the Aker Wayfarer vessel. The goodwill value of the business area Oilfield Services and Marine Assets (OMA), which Aker Oilfield Services belongs to, will also be written down.

The impairments and provision are based on revised business cases after the cancelation in June by Total in Angola of a two-year contract for the Skandi Aker vessel, as well as a generally weaker market that has created uncertainty about the value of the vessel and the goodwill value of OMA. An impairment charge of NOK 664 million will be taken on the Skandi Aker and NOK 306 million on the goodwill value of OMA. An impairment charge and onerous lease provision totaling NOK 662 million will also be taken on the Aker Wayfarer as some prior investments in the vessel have little or no value based on recently revised business cases and the current market outlook.

The after-tax effect of the impairments and provision is expected to be about NOK 1.3 billion. Most of the Aker Wayfarer impairment and provision will impact earnings before interest, taxes, depreciation and amortization (EBITDA). The Skandi Aker and OMA goodwill impairments will impact earnings before interest and taxes (EBIT). The impairments and provision, as well as other financial consequences of the demerger, will be incorporated in the second-quarter 2014 results disclosed July 17 by Aker Solutions.

The impairments and provision will have no effect on the new Aker Solutions since OMA will become part of Akastor. There will be no cash effect, no adverse impact on future funding through covenants and no consequences for the separation of Aker Solutions.

Indicative key dates for the demerger and the listing of New Aker Solutions shares on the Oslo Stock Exchange are as follows:

• Extraordinary General Meeting of Aker Solutions where the demerger proposal will be considered: August 12, 2014
• Application for listing of New Aker Solutions' shares on the Oslo Stock Exchange: on or about August 27, 2014
• Last day of trading of the Aker Solutions' share inclusive of the right to consideration shares in New Aker Solutions: on or about September 26, 2014
• Registration of the demerger with the Norwegian Register of Business Enterprises: on or about September 26, 2014
• First day of trading in Akastor shares exclusive of the right to consideration shares in New Aker Solutions: on or about September 29, 2014
• First day of trading in New Aker Solutions shares on the Oslo Stock Exchange: on or about September 29, 2014

ABG Sundal Collier, Barclays and Carnegie will act as joint lead managers for the listing process.

As part of the process, a listing prospectus for New Aker Solutions will be prepared and published in accordance with applicable laws and regulations.

DeepDownlogoHOUSTON, Aug. 14, 2014 /PRNewswire/ -- Deep Down, Inc. (OTCQX: DPDW) ("Deep Down" or the "Company"), an oilfield services company specializing in complex deepwater and ultra-deepwater oil production distribution system support services, reported financial results for the quarter ended June 30, 2014.


For the second quarter of 2014, Deep Down reported a net loss of $1.2 million, or $0.08 loss per diluted share, compared to net income of $1.0 million, or $0.10 income per diluted share, for the second quarter of 2013.

Revenues for the second quarter of 2014 and 2013 were $5.8 million and $9.2 million, respectively. The $3.4 million decrease (37 percent) is the result of the 2013 period being unusually high. Additionally, projects valued in excess of $17.0 million were delayed during the second quarter of 2014, resulting in lower revenues of approximately $7.0 million.

Gross profit as a percentage of revenues for the second quarter of 2014 and 2013 was 29 percent and 38 percent, respectively. The nine percentage point decrease in gross profit was due primarily to the delay of several lump sum projects just discussed. The delay of these projects negatively impacted the gross margin by approximately $2.6 million.

Selling, general and administrative expenses ("SG&A") for the second quarter of 2014 was $2.8 million, or 48 percent of revenues. SG&A for the second quarter of 2013 was $2.4 million, or 26 percent of revenues.

The $0.4 million increase in SG&A is due primarily to quality, project management, engineering, shop improvements related to safety systems, increased security costs and an increase in bad debt expense.

A significant portion of the increase was due to the impact of the decision to delay a Latin America regional operation in Panama, which included a $0.2 million accrual of all related costs, and an increase in security costs at the new facility of $0.1 million.

The Company's management evaluates its financial performance based on a non-GAAP measure, Modified EBITDA, which consists of earnings (net income or loss) available to common shareholders before net interest expense, income taxes, depreciation and amortization, and other non-cash and non-recurring charges. Modified EBITDA was $(0.3) million for the second quarter of 2014 vs. $1.7 million for the second quarter of 2013. The $2.0 million decrease in Modified EBITDA was due to a $1.8 million decrease in gross profit before depreciation due to reasons previously discussed, and a $0.2 million increase in SG&A before Panama exit costs and share-based compensation expense, also due to reasons previously discussed.

For more information, please visit: Deep Down, Inc.

piraNYC-based PIRA Energy Group reports that the July stock decline at Cushing strengthens WTI.  In the U.S., there was largest weekly stock draw since January.  In Japan, crude runs and stocks rose. Specifically, PIRA’s analysis of the oil market fundamentals has revealed the following:

July Stock Decline at Cushing Strengthens WTI

Stock levels for crude oil at Cushing dropped below 20 million barrels last month, for the first time since 2008. With logistical constraints still in place throughout much of the Midcontinent, most crude grades weakened relative to WTI, and even the Dated Brent premium shrank. However, the LLS premium strengthened, as Gulf Coast crude stocks dropped due to higher refinery runs.

Largest Weekly Stock Draw Since January

Overall U.S. commercial oil inventories fell this past week with a large product stock decline (the first since March) and a crude inventory decline. Crude stocks have fallen for six consecutive weeks. The large product inventory decline was supported by the strongest reported demand of the year. Overall inventories are now back below last year by 1.3 million barrels, with gasoline and distillate down roughly 10 and 2 million barrels, respectively.

Japanese Crude Runs and Crude Stocks Rise

Runs continued to rise in line with declining maintenance activity. Crude imports increased and crude stocks posted a modest build. Finished product stocks rose slightly. Gasoline demand fell back but lower yield allowed for a small stock draw. Gasoil demand was higher, but stocks still built on higher yield. Refining margins remain quite weak with the gasoline crack posting another sharp decline.

A Statistical Analysis of Cushing Crude Stocks and Storage Capacity Utilization

Different expressions of Cushing fundamentals, such a percent of storage capacity utilized, can have better relationships to WTI 1st – 2nd spreads than outright Cushing stocks. Over time, the strength in the correlation between Cushing fundamentals and WTI spreads has changed. Cushing fill ratios at either extreme of the historical range drive non-linear spread behavior.

Aramco Announces Crude Price Differentials for September

Saudi Arabia's formula prices for September were just released. Prices into the U.S. were cut, against the ASCI benchmark, across the board after two straight months at record highs. Pricing into Europe and the Med against the Bwave benchmark was raised. In Asia, not surprisingly, terms were made more generous.

BULLETIN: Market Dynamics Reflecting a New Reality

There is currently a crude surplus in the Atlantic Basin which has weighed on relative prices and narrowed light-sweet crude premiums. The development of this surplus during peak season Atlantic Basin runs and North Sea maintenance has caught a market by surprise typically conditioned for tightness at this time. Many people trade off historical relationships and expect them to continue. But supply/demand changes transform markets, even though it takes time for these markets to fully absorb the new reality.

Mt Belvieu Prices Stay Strong

The U.S. LPG complex remained strong in the face of falling energy prices worldwide. Cash propane at Mt Belvieu strengthened by over 2% to 102.4¢/gal. Propane prices dipped below $1 early in the weak, falling in sympathy with oil prices. Prices have rallied since Wednesday’s stocks report, as inventory increases have been decreasing in size. The prospect of a large crop drying season is also acting as a tailwind for prices.

Ethanol Prices Plunge

U.S. ethanol prices fell sharply the week ending August 1 after the DOE’s latest supply report showed that inventories had risen to a 16-month high the prior week. As a result, ethanol manufacturing margins were slightly lower.

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.

piraNYC-based PIRA Energy Group believes that with both the physical market and financial length bottoming, oil prices are at or near their lows. In the U.S., sharp crude stock reduction is offset by a product build.  In Japan, crude stocks posted a large draw. Specifically, PIRA’s analysis of the oil market fundamentals has revealed the following:

Sharp U.S. Crude Stock Reduction Offset by Product Build

Crude stocks fell for the week ending July 11, 2014 while product inventories built, causing an overall inventory build. This inventory pattern fits with record crude runs. Last year for the same week, inventories were down slightly so the year-on-year inventory excess widened. Crude oil and other products are up on last year while the four major product inventories are down.

Japanese Crude Runs Rise, Crude Stocks Post a Large Draw

Despite typhoon Neoguri hitting Japan the last week, runs still posted a sizable gain, while imports dropped and crude stocks drew. Product balances for gasoline and gasoil were little changed, while kerosene stocks resumed building. Both gasoline and naphtha stocks drew to record lows. Refining margins remained good with cracks little changed.

Freight Market Outlook

Crude markets have been whipsawed recently by the sectarian civil war in Iraq and changing perceptions on the return of Libyan supplies to the market. Dated Brent prices increased by $6/B to $115/B following the June 10th fall of Mosul to ISIS insurgents. But as it became apparent that exports from Basrah were unlikely to be impacted while prospects for the return of Libyan supplies increased, the price of Dated Brent fell by more than $12 per barrel to $103/B with a steep contango structure at the front end of the forward price curve. This has prompted the opportunistic storage of crude on tankers and increased incentives for the movement of additional long-haul volumes out of the Atlantic Basin to Asia, causing a counter-seasonal rise in crude tanker rates in the Atlantic. For tanker operators there are double benefits with higher spot tanker rates and lower bunker prices, at least for the moment.

Strong Week for International LPG

Tightness in LPG supplies in Europe, particularly in butane, had prices bid up this week. European supply has tightened considerably on lower export volumes out of Russia, and refinery maintenance in Antwerp and the UK. Russian maintenance at gas processing plants has lowered prompt Russian output. Coaster sized parcels of butane in NWE ended the week 4% higher at $838/MT. Asian prices were also higher on strong demand -- as soaring VLGC freight rates have industrial consumers worried that supply will be impacted.

Ethanol Prices Decline

U.S. ethanol prices showed some strength early in the week ending July 11, but then resumed their recent descent, weighed down by rising inventories. Ethanol manufacturing cash margins improved for the second consecutive week, largely due to plunging corn costs.

Ethanol Output Up, but Inventories Down

U.S. ethanol output rebounded to 943 MB/D the week ending July 11, up from 927 MB/D during the holiday-shortened week ending July 4. Inventories declined by 341 thousand barrels to a four-week low 17.9 million.

Political Risk Scorecard

Concerns about potential further sanctions on Russia, along with Iraqi instability, will support prices next week.

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.

douglas-westwoodDeclining North Sea production and increasingly mature assets are expected to drive demand for offshore accommodation support, with the attributed maintenance, refurbishment and shutdown work requiring additional personnel-on-board and workshop capacity. However, the harsh met ocean conditions of the northern North Sea (NNS) ultimately limit Operator choice to two types of accommodation - jackup barges and semisubs – due to the greater stability and safety offered.

Despite growing demand for semisub units, the sector is plagued by constrained global supply and limited availability, placing upward pressure on day rates. This is having a significant impact on contract costs in the NNS, with day rates typically ranging from $200-350k. Additionally, Operators are placing contracts several years in advance to ensure maintenance or construction schedules are satisfied. This is forcing Operators to seek more efficient contracting practices, either through unit sharing agreements or securing units on an annual basis.

Notably; although costs continue to rise, a key emerging trend in the floating accommodation sector is employee welfare. IOCs are using their global footprints to help drive the adoption of the 'quality equals efficiency' concept. This is now being mirrored in the NNS, where several large Operators and service contractors have identified a trend between 'spanner time' – hours worked by offshore personnel – and the quality of worker accommodation. While this may incur greater costs in terms of unit day rates, the cost advantages gained from reduced downtime and improved worker efficiency could make this increased expenditure worthwhile.

The industry is screaming for offshore accommodation capable of working in harsh conditions. Although the market will see 11 new units delivered between 2015-2016, continued growth in demand for accommodation semisubs, intensified by unit retirement, will further constrain supply. We are already seeing the market respond with new orders; however, will this be enough to offset growing demand pressures?

Murray Dormer, Douglas-Westwood London
+44 1795 574736 or This email address is being protected from spambots. You need JavaScript enabled to view it.


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