NYC-based PIRA Energy Group reports that Brent crude prices have moved higher and are likely to stay strong. On the week, U.S. commercial stocks increased. In Japan, crude imports rose sufficiently to produce a moderate stock build. Specifically, PIRA’s analysis of the oil market fundamentals has revealed the following:

Bullish Oil Prices

It is hard not to be bullish oil prices with the global economy gradually improving, tight physical oil markets and MENA turmoil, which is already substantially reducing global oil supplies and has the potential to reduce supplies further. Current positioning and likely September deflationary type headlines, due in part to a challenging calendar, but also the startup of Iranian nuclear negotiations, pose downside risks to oil prices. Yet, the burgeoning momentum to own oil seems poised to push oil prices higher for now with SPR chatter somewhat limiting the upside.

Slight U.S. Commercial Stock Build

Commercial inventories increased for the week ending August 30 as product stocks swung from a draw the week before to a build. Added supply resulted from reported product demand weakening and product output increasing. This more than offset a product import decline. Last year for the same week, product stocks declined as refinery operations were curtailed by Hurricane Isaac. Hence the year on year product stock excess widened with the bulk of the excess in gasoline and other products.

Japanese Crude Runs Decline as Turnarounds Gear Up

Crude runs began to decline as turnarounds started to gear up and crude imports rose sufficiently to produce a moderate crude stock build. Gasoline demand eased modestly, while gasoil demand remained strong. Stocks of both posted only modest changes on the week. Kerosene demand perked up and with a lower yield the stock build rate slowed. Refinery margins remain very poor.

Saudi Formula Crude Prices for October Tightens for Asia, Less Aggressive in Europe

Saudi’s formula prices for October were recently released. In Asia, differentials were raised most aggressively on lighter grades, but the differential for Arab heavy was left unchanged. While the price adjustment was termed "less aggressive" than market expectations, refiners still cannot be too pleased given the woefully weak refining margins, particularly for topping configurations.

Cushing Stocks Drop 15 Million Barrels in Last 9 Weeks

Crude stocks at Cushing, Oklahoma have fallen for nine consecutive weeks – a total of 15 million barrels since late June. Southern price spreads remained tight, with WTI discounts to Atlantic Basin light crudes averaging $4-5/Bbl in August. Northern spreads were mixed, as oil sands upgrader maintenance restricted synthetic crude supplies while raising bitumen production.

Slow Stock Building in U.S.

Propane building season continues but at a slow pace, despite the latest week's surge, in the U.S. as exports remain quite high, petchem feed usage is ongoing and the crop drying season is just weeks away. Europe is starting to attract cargoes as North Sea maintenance continues and petchem feedstock usage is quite favorable. The Northern Hemisphere needs to start preparing for the upcoming heating season.

U.S. Ethanol Prices Soar

U.S. ethanol prices rose to a two-month the week ending August 30. The jump was primarily due to the scarcity of corn in the Midwest, causing ethanol production to drop to a 21-week low. Also providing support were petroleum prices which rose to a two-year high.

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.

Statoil ASA (OSE: STL, NYSE: STO) has signed an agreement to divest minority interests in the Gullfaks and Gudrun fields offshore Norway and exit the non-core, non-operated Schiehallion and Rosebank fields, West of Shetlands.

In addition to the cash consideration of USD 2.65 billion, the transaction with Austrian oil and gas company OMV includes a contingent payment and involves a partnership between the two companies. Statoil reduces its ownership share in Gullfaks from 70% to 51% and from 75% to 51% in Gudrun, and retains its operatorships on both fields. 

"Through this transaction, Statoil captures value created through asset development and unlocks capital for investment in high return projects in core areas. This includes our recent discoveries on the Norwegian continental shelf. We continue to deliver on our strategy to create value through active portfolio management and to further increase our financial flexibility," says Helge Lund, Statoil's president and chief executive officer.

Statoil expects to recognize a gain from the transaction estimated to be between USD 1.3-1.5 billion, to be adjusted for activity between the effective date 1 January 2013 and the closing date.

The transaction will enable Statoil to redeploy around USD 7 billion of capital expenditure, around USD 5.5 billion of which is pre-2020 (excluding potential investments in the recent Shetland/Lista discovery at Gullfaks).

Entering partnership

OMV is an established company on both the Norwegian (NCS) and the UK (UKCS) continental shelves. Statoil and OMV enter into a partnership including potential cooperation on exploration opportunities across Norway, the UK and the Faroese Islands as well as the development of enhanced oil recovery (EOR) technologies.

"Statoil is pleased to strengthen the partnership with OMV on the Norwegian continental shelf. OMV is already a valued partner in Edvard Grieg and Aasta Hansteen, and this agreement enables our companies to develop the cooperation further," says Lund.

"I believe this is a win-win deal for Statoil and OMV. Apart from the assets, I am especially proud that we can partner with a world-class leader in offshore and EOR technology," says Gerhard Roiss, chief executive officer of OMV.

Demonstrating value of Statoil's NCS and UKCS portfolio

The transaction builds on Statoil's offshore competence and experience, and track record of realising value through asset development and portfolio management.

As operator of the Gullfaks field, Statoil has added substantial value through successful efforts to maximise oil recovery and recently announced a new discovery in the Shetland/Lista formation. As part of the transaction, Statoil captures upside from this discovery through a contingent payment of 6 USD per barrel of oil equivalent of reserves developed.

Gudrun is on track for production start-up in the first quarter of 2014. As the operator, Statoil is executing the development on time and below original cost estimates. Today's transaction demonstrates the value of efficient project execution in an asset where Statoil increased its ownership in 2010.

Statoil remains committed to growing its business on the UKCS and is the operator of large field developments including the Mariner project and exploration licenses. By divesting non-core, non-operated developments in the West of Shetlands, Statoil further focuses its UK portfolio.

Statoil's production from the divested assets in the first half of 2013 was approximately 26,000 barrels of oil equivalent per day from Gullfaks. Production impact for Statoil from the transaction is estimated to around 40,000 barrels of equity oil equivalent per day in 2014 and 60,000 per day in 2016.

The effective date for the transaction is 1 January 2013. Closing is expected around year end 2013, pending government and partner approvals.

Total proceeds of around USD 15 billion have been realised through divestments by Statoil since 2010, enabling the company to redeploy resources to core, high-return upstream projects.

Bank of America Merrill Lynch and Lambert Energy Advisory Limited were financial advisors to Statoil on this transaction.

ConocoPhillips (NYSE: COP) has announced that it has closed a transaction with the National Gas Company of Trinidad and Tobago Limited (NGC) for the sale of its wholly owned subsidiary, Trinidad and Tobago Holdings LLC, for a total consideration of $600 million plus customary adjustments.

Trinidad and Tobago Holdings LLC holds a 39 percent interest in Phoenix Park Gas Processors Limited (PPGPL). PPGPL operates a gas processing and natural gas liquids fractionation facility located at Point Lisas, Trinidad.

“The sale of this noncore, midstream asset represents further progress in strengthening and focusing the ConocoPhillips portfolio, and advances the strategic interests of both NGC and ConocoPhillips,” said Don Wallette, executive vice president, Commercial, Business Development and Corporate Planning. “We appreciate the long and productive relationship we have had with NGC.”

ConocoPhillips expects to recognize an after-tax gain of approximately $290 million for the sale.

Including this transaction, ConocoPhillips has announced expected proceeds of approximately $14.1 billion from the sale of nonstrategic assets as part of its 2012-13 asset disposition program. Through June 30, 2013, the company has received $3.8 billion in proceeds from completed sales, with the remainder expected by year-end 2013. These proceeds will be available for general corporate purposes and allow the company to advance existing growth programs.

Cal Dive International, Inc. (NYSE: DVR) reported a second quarter 2013 loss of $1.7 million, or $0.02 per diluted share, on revenues of $121.0 million. Included in the loss is a $4.0 million after-tax gain related to the final marked-to-market adjustment of the derivative liability on the Company’s convertible debt. This compares to a loss of $5.7 million, or $0.06 per diluted share, on revenues of $120.3 million for the second quarter 2012. For the second quarter 2013, the Company reported EBITDA of $10.2 million compared to $10.7 million for the second quarter 2012.

Cal Dive also announced that it was awarded a contract on August 6, 2013, from Pemex Exploración y Producción that is expected to generate revenue of approximately $40 million. This award is in addition to the three Pemex awards already announced in 2013 for approximately $250 million. This most recent award brings the total expected revenue from contracts awarded by Pemex to Cal Dive this year to approximately $290 million. This latest contract is for the procurement, installation and commissioning of 3.5 kilometers of 20 inch subsea pipeline and associated tie-ins to an existing platform. The offshore construction is expected to commence toward the end of the fourth quarter 2013 with the remainder of the work expected to be performed during the first quarter 2014.

Commenting on the results and the contract award, Cal Dive’s Chairman, President and Chief Executive Officer, Quinn Hébert, stated, “The second quarter saw increased revenue and profitability from all of our international regions. For the quarter our international revenues increased by over 60% when compared to the second quarter 2012 and accounted for 65% of our total consolidated revenues. We continue to focus on our strategy of expanding our international operations, and expect that approximately 70% of our total 2013 annual consolidated revenues will come from international locations, led by work in Mexico.

“The U.S. Gulf of Mexico shallow water market overall continued to be sluggish during the second quarter and the work season had a late start due to weather during April and into May. Furthermore, we experienced a decline in the profitability of our two derrick barges year-over-year. The Pacific was in drydock much of the quarter but was fully utilized during second quarter last year on a large decommissioning project, and the Atlantic had low utilization in the quarter due to permitting delays for salvage and decommissioning projects and inclement weather at the very end of June. However, the outlook for the salvage and decommissioning market remains steady and these two assets are expected to have good utilization during the third quarter.”

Mr. Hébert continued, “We are very pleased to have just been awarded our fourth contract from Pemex this year. Looking ahead to the second half of the year, we will commence offshore operations in Mexico later in the third quarter. Our offshore schedule is always subject to change, but currently we expect to complete more work in Mexico during the fourth quarter than the third quarter. Therefore we expect the fourth quarter financial results to be comparable with the third quarter as the Mexico activity will offset the start of the typical winter season in the Gulf of Mexico. The remainder of the Mexico work will be completed during the first half of 2014 giving us better than usual utilization during the typically slow winter season. We will continue to actively bid more projects in Mexico over the remainder of 2013 for work in 2014.”

NYC-based PIRA Energy Group believes that burgeoning momentum to own oil seems poised to push oil prices higher for now. On the week, U.S commercial stocks built led by crude, while Japanese crude stocks drew strongly. Specifically, PIRA’s analysis of the oil market fundamentals has revealed the following:

Bullish Oil Prices

It is hard not to be bullish oil prices with the global economy gradually improving, tight physical oil markets and MENA turmoil, which is already substantially reducing global oil supplies and has the potential to reduce supplies further. Current positioning and likely September deflationary type headlines, due in part to a challenging calendar, but also the startup of Iranian nuclear negotiations, pose downside risks to oil prices. Yet, the burgeoning momentum to own oil seems poised to push oil prices higher for now with SPR chatter somewhat limiting the upside.

U.S. Commercial Stocks Build Led by Crude

Overall U.S. commercial oil inventories increased for the week ending August 23 according to the latest weekly DOE data with the entire build occurring in crude, while product inventories declined. Overall U.S. oil inventories are in the upper end of their historic range, in part because of high "other" products. Crude and the four major products stocks (gasoline, distillate, jet and resid) are at the average of their historic range, although crude stocks are indeed relatively high. The stock increase for the same week last year was higher, thereby narrowing the year-on-year stock excess. Nearly the entire excess is in gasoline.  

Strong Crude Stock Draw in Japan, Refinery Margins Very Weak

Crude runs were little changed, but a very low crude import figure drew stocks strongly. Gasoline demand remained strong and gasoil demand rebounded from abnormally low levels. The kerosene stock build rate moderated. Refinery margins collapsed to very weak levels as all cracks gave ground. While cracking margins are weak, topping margins are even worse. 

Withdrawal of Half of Libya’s Oil From the Market

Crude oil trade flows have been significantly altered in 3Q13 by the withdrawal of nearly half of Libya’s 1.4 MMB/D of oil from the market and the subsequent increase in production from Saudi Arabia to record levels to compensate for these losses and to accommodate growing global demand over the second half of the year. Tanker markets are adjusting with more West African crude staying in the Atlantic Basin, which is shifting tonnage demand to smaller vessels. More sour crude production has also benefited ship operators by lowering bunker prices, which have risen less than crude. 

LPG Market Appears Tight

The slow pace of propane stock building has pushed prices higher and will keep prices supported as crop drying and winter heating demand are approaching.  Gasoline blending season is starting, increasing the pull on butanes. Prompt European LPG markets are relatively tight given low arrivals in August and North Sea maintenance. More imports will be attracted from the USGC and West Africa.

Ethanol Output Drops to 21-Week Low

Ethanol output fell to a 21-week low of 820 MB/D the week ending August 30 from 844 MB/D in the preceding week, while imports dropped to 4 MB/D from 19 MB/D over the same period.  Inventories decreased by 232 thousand barrels to 16.3 million barrels as PADD II stocks fell below 5.0 million barrels for the first time since the DOE began reporting weekly ethanol data in June 2010. 

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.

NYC-based PIRA Energy Group believes that the China GDP slowdown is underway. On the week, U.S. commercial stocks drew. Specifically, PIRA’s analysis of the oil market fundamentals has revealed the following:

 Difficult Transitions Underway

The China GDP slowdown is underway. It is still unclear whether the long-predicted transition to slower, domestic led growth will be successful and smooth. While this may represent a vulnerability to demand growth (for all fuels), the increasingly volatile political transition in MENA could prove to represent a far more important vulnerability to oil and gas supply growth. The shale revolution continues to spread from the natural gas supply to the demand side of the balance as new markets emerge to take advantage of the growth of low cost North American production. 

U.S. Stocks Drew Last Week

Total commercial stocks decreased for the week ending August 9, largely offsetting the modest builds seen in the prior two weeks. Products increased despite lower refinery runs and lower product imports due to weaker reported demand. Crude stocks drew, with Cushing crude stock draws accounting for half of the total draw. Cushing crude stocks are now down from the all-time high this year and at the lowest level since 1Q12. Despite this week’s decline, the stock excess to last year widened as there was a draw in this week last year. 

U.S. Sees Low Propane Stock Build

A surprisingly low stock build was indicated for the latest reporting week. The U.S. is experiencing a widening deficit to last year. The storage deficit relative to last season is expected to widen as the pace of exports picks up and with a likely favorable crop drying season ahead. 

EPA Finalizes 2013 Biofuel Standards and Will Reduce 2014 Mandates

U.S. ethanol prices and margins fell last week because of rising production, inventories and imports. Sharply lower RIN prices also put downside pressure on prices. The EPA finalized the renewable fuel standards for 2013 and stated that it will reduce the 2014 mandates in order for them to be achievable. 

Ethanol Stocks Draw; Production Higher

Ethanol stocks were drawn by 291 thousand barrels to 16.4 million barrels for the week ending August 9, erasing the build from the previous week. U.S. ethanol production rose for the second straight week, reaching 857 MB/D from 853 MB/D the prior week as several manufacturers maximized output prior to extended turnarounds planned for later this month and during September. 

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.

Pomerantz Grossman Hufford Dahlstrom & Gross LLP has filed a class action lawsuit against McDermott International, Inc.  ("McDermott" or the "Company") (NYSE: MDR) and certain of its officers.  The class action, filed in United States District Court, Southern District of Texas, and docketed under 13-cv-2442, is on behalf of a class consisting of all persons or entities who purchased or otherwise acquired securities of McDermott between November 6, 2012 and August 5, 2013 both dates inclusive (the "Class Period"). This class action seeks to recover damages against the Company and certain of its officers and directors as a result of alleged violations of the federal securities laws pursuant to Sections 10(b) and 20(a) of the Securities Exchange Act of 1934 and Rule 10b-5 promulgated thereunder.

McDermott is an engineering, procurement, construction and installation ("EPCI") company focused on executing complex offshore oil and gas projects worldwide.  The Company provides integrated EPCI services for upstream field developments including, fixed and floating production facilities, pipelines and subsea systems from concepts to commissioning.  McDermott operates in approximately 20 countries across the Atlantic, Middle East and Asia Pacific area.  

The Complaint alleges that throughout the Class Period, Defendants made false and misleading statements and/or failed to disclose that: (a) the Company was experiencing weakness in its project bidding and execution; (b) the Company was engaging in poor risk evaluation; (c) the Company had been experiencing poor project management; (d) the Company was experiencing material losses in its Middle East, Asia Pacific and Atlantic segments; and (e) based upon the above, the Defendants lacked a reasonable basis for their positive statements about the Company during the Class Period.

On August 5, 2013 the Company issued a press release, reporting the Company's second quarter financial and operating results for the quarter ending June 30, 2013, stating a substantial decrease in the Company's year-over-year financial results which the Company attributed to poor performance of several significant projects in the Middle East and Asia Pacific segment along with underutilization of assets in the Company's Atlantic segment.  The Company additionally disclosed that it was taking immediate action to correct "weaknesses" in its "project bidding and execution" and that management was putting in place four initiatives in order to create a "more disciplined culture within the Company" to deliver adequate return on the Company's investors' capital.  On this news, McDermott shares declined $1.80 per share or over 19%, to close at $6.93 per share on August 6, 2013.

As part of its recent initiative to provide the data behind its widely followed market analysis and price forecasts, PIRA Energy Group has launched the World Oil Supply Data Portal, (WOS) Available only via PIRA’s client site, WOS reflects the 30-plus years of PIRA forecast modeling of country-by-country and, at times, field-by-field supply data.  The results of this bottom-up analysis, when combined with PIRA’s similarly detailed work for by-country and by-sector demand, provides the foundation for PIRA’s oil balances and price forecasts that are relied on by more the 500 client companies worldwide.

With the world now in the midst of a major evolution in oil supply, the timing of the WOS’s launch is particularly important. Markets in North America will increasingly be supplied by new local sources, and oil previously destined for North America from abroad will be seeking new markets in Asia and elsewhere. For instance, U.S. liquids production has grown from 9.5 MMB/D in the second quarter of 2010 to 12 MMB/D currently, with 1.8 MMB/D of that increase coming from relatively light, sweet shale crude production and the remainder primarily from shale NGLs. This higher production has led to a reduction in imports of 2 MMB/D, with largest portion of the reduction to date in African grades. PIRA anticipates that the growth in U.S. crude production will continue, albeit at a slowing rate, changing the global crude mix to one that is both lighter on average and less dependent on OPEC.  Understanding the specifics of how this will evolve makes a resource like WOS critical to commercial success in refining, crude transport and maximizing the value of crude sales.

The Portal’s customized interface allows users to quickly access PIRA's latest world liquids supply forecast (annually to 2030 and monthly to end 2014), including assumptions on disruptions, maintenance, and spare capacity.  The data can be viewed and organized for any geographical split, from world or regional totals all the way to U.S. states and Canadian provinces, and even to specific plays where available.

“What makes the Portal truly special is that it goes beyond understanding and displaying volumes,” notes Gary Ross, PIRA’s CEO. “Its critical advantage is how it allows users to delve quickly into specific components of liquids supply — conventional, nonconventional; onshore or offshore; shale or non-shale. WOS enables the user to drill down, so to speak, to specific types of liquids, not just crude or condensates. Details on NGLs, biodiesel and ethanol, GTLs and CTLs, syncrude and so on are all just a click or two away.”

Another unique aspect of the Portal is the ability to view crude and condensate production forecasts by quality (light sweet, medium sweet, heavy sweet, light sour, medium sour, heavy sour).  Users are further empowered to customize their output by establishing specific value ranges for API, sulfur, TAN, and 650+ content in order to generate a report that contains only the specific grade of crude they need. This could be particularly valuable to a refiner seeking the best source of supply or a producer assessing its most direct competition.

Dr. Ross adds, “As a reflection of PIRA itself, where all of its information services come with high degree of value-added analysis, WOS is more than a collection of data presented in an easy-to-access interface. It comes with our team of seasoned analysts who understand the limitations of source data and work to normalize the various streams. Anticipating and quantifying disruptions is another key element of accurately forecasting supply.  WOS inputs take into account all types of disruptions in production, including weather, technical problems, sabotage, sanctions, and other politically driven outages.”

Field start-ups are equally important to gauging future production. WOS’s “Production by Vintage” reports reveal which projects are scheduled to begin production in a particular year (or range of years) and show the behavior of those fields over time in PIRA’s forecast.

PIRA Energy Group, founded in 1976, is a preeminent energy information provider specializing in global energy markets research, analysis, and intelligence. PIRA offers primarily Retainer Client Services, but also can perform customized consulting, on a broad range of subjects in the international crude oil (and NGLs), refined products, natural gas (and LNG), electricity, coal, biofuels, shipping and emissions markets. Currently, more than 500 entities spread across some 60 countries — including international and national integrated oil and gas companies, independent producers, refiners, marketers, oil and gas pipelines, electric and gas utilities, industrials, trading companies, financial institutions and government agencies — use PIRA’s research and price forecasting services.

Anadarko Petroleum Corporation (NYSE: APC) has announced it has entered into a definitive agreement with ONGC Videsh Ltd. (OVL), a wholly owned subsidiary of Oil and Natural Gas Corporation Limited, to sell a 10-percent interest in Mozambique's Offshore Area 1 (Area 1) for $2.64 billion in cash. Anadarko will remain the operator of Area 1 with a working interest of 26.5 percent.

"This transaction demonstrates our continuing ability to create substantial value through exploration and to again accelerate the value of our longer-dated projects through attractive monetizations and third-party capital," Anadarko Chairman, President and CEO Al Walker said. "Mozambique LNG is a premier global energy project, and we look forward to working with our partners and the government to advance this world-class development.

"As the operator of Area 1, we are very pleased to have reached this agreement with OVL, which values our pre-transaction interest at more than $9.6 billion. We expect to use the net proceeds from this transaction to further accelerate the short- and intermediate-term oil and liquids opportunities we have in the Wattenberg field, Eagleford Shale, Permian and Powder River basins, as well as the Gulf of Mexico and other evolving plays in our portfolio. Our objective with this allocation of capital will be to further increase our cash-flow growth with attractive wellhead margins, while providing additional value to our shareholders as evidenced by our recent dividend increase and continued portfolio-management activities."

The transaction is expected to close around the end of 2013, and is subject to existing preferential rights, governmental approvals and other customary closing conditions.

Area 1 is operated by Anadarko Moçambique Area 1 Limitada (a wholly owned indirect subsidiary of Anadarko) and is located in Mozambique's deepwater Rovuma Basin. The block contains the Prosperidade and Golfinho/Atum natural gas complexes that combined hold an estimated 35 to 65-plus trillion cubic feet (Tcf) of recoverable natural gas resources. In cooperation with the Government of Mozambique, Anadarko, its partners, and Eni (as the operator of the adjacent Area 4 block) continue to advance the development of an LNG park with first LNG cargoes expected in 2018.

Anadarko's partners in Area 1 include Mitsui E&P Mozambique Area 1, Limited (20 percent), BPRL Ventures Mozambique B.V. (10 percent), Videocon Mozambique Rovuma 1 Limited (10 percent) and PTT Exploration & Production Plc (8.5 percent). Empresa Nacional de Hidrocarbonetos, E.P.'s (ENH) 15-percent interest is carried through the exploration phase.

At a meeting held on August 16 , Petrobras' Board of Directors approved the following asset sale transactions totaling US$ 2.1 billion:

1. Sale of a 100% interest in Petroquímica Innova S.A. (Innova) to Videolar S.A. and its majority shareholder for R$ 870 million (approximately US$ 372 million1), the buyer to take on debt of approximately R$ 23 million.

The transaction will be put to a vote at an Extraordinary Shareholders' Meeting to be convened in due course and, based on the opinion of the Brazilian Securities Commission, will not involve any preemptive rights for the acquisition of Innova shares by Petrobras shareholders.

Innova is a second-generation petrochemical company sited in the Petrochemical Zone of Triunfo, in the state of Rio Grande do Sul. It produces ethylbenzene, styrene and polystyrene, used in the manufacture of home appliances, disposables, elastomers, packaging, paints and fiberglass.

Completion of the transaction is subject to certain standard pre-conditions, including approval by the Brazilian Antitrust Authority (Cade).

2. Sale of the 35% stake held by Petrobras in block BC-10, known as Parque das Conchas, to the Sinochem Group for US$ 1.54 billion.

Block BC-10 is located in the Campos Basin, some 100 km off the south coast of the state of Espírito Santo, and partners include Shell, the operator with a 50% stake, and ONGC with 15%. These partners have preemptive rights which can be exercised within 30 days after notification.

Completion of the transaction is subject to the certain standard pre-conditions, including approval by the Brazilian Antitrust Authority (Cade), Brazil's National Petroleum, Natural Gasand Biofuels Agency (ANP) and China's National Development and Reform Commission (NDRC).

3. Signing of farm-out contracts amounting to US$ 185 million related to 100% of the Petrobras stake in blocks MC 613 (Coulomb), GB 244 (Cottonwood) and EW 910, all in production and located in the US Gulf of Mexico.

Petrobras has a 33% stake in the Coulomb field; the remaining 67% is held by Shell, which is the operator. The field is located in Mississippi Canyon Block 613 (MC 613), some 130 km off the coast of Louisiana.

Petrobras has a 100% stake in the Cottonwood field located in the Garden Banks Block 244 (GB 244), some 220 km off the coast of Texas.

Petrobras has a 60% stake in the EW910 asset; the remaining 40% is held by W&T Offshore, which is the operator.

The transaction is subject to third party preemptive rights and approval by the Bureau of Ocean Energy Management (BOEM).

- Net Income Improves 60% to $1.0 million

 - Modified EBITDA Increases 22% to $1.7 million

 - Revenues Increase 16% to $9.2 million

Deep Down, Inc. (OTCQX: DPDW) ("Deep Down")(the "Company"), an oilfield services company specializing in complex deepwater and ultra-deepwater oil production distribution system support services, has reported net income of$1.0 million, or $0.10 per diluted share, for the second quarter of 2013, an improvement of $0.4 million from the second quarter of 2012.   

OPERATING RESULTS

Revenues increased by $1.3 million in the second quarter of 2013 compared to the prior-year quarter. The increase of 16 percent in revenues occurred primarily due to increased demand by our customers for our technologically innovative solutions as a result of our consistently successful project execution.

Gross profit increased by $0.6 million to $3.5 million, or 38 percent of revenues, in the second quarter of 2013 compared to the prior-year quarter. Gross profit of 38 percent of revenues is consistent with our expectations for the second quarter of 2013.

Operating expenses increased by $0.2 million in the second quarter of 2013 compared to the prior-year quarter. The slight increase was due primarily to increased lease costs associated with our new facility.

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 increased by $0.3 million to $1.7 million in the second quarter of 2013 compared to the prior-year quarter. The increase in Modified EBITDA is due primarily to increased gross profit before depreciation expense of $0.7 million, partially offset by increased selling, general and administrative expenses before amortization of share-based compensation of $0.4 million.

WORKING CAPITAL

At June 30, 2013, we had working capital of $7.5 million. Additionally, in the first quarter of 2013, we entered into the fifth amendment of our bank credit agreement, which among other things, increased the committed amount under our revolving credit facility to $5 million from $2 million. Because of these factors, and because of cash we expect to generate from operations, we believe that we will have adequate liquidity to meet our future operating requirements.

EXECUTIVE MANAGEMENT

Ronald E. Smith, Chief Executive Officer, stated, "We are pleased with our results for the second quarter of 2013. Our backlog has reached $26 million and our business is increasing.  To accommodate this increase, we entered into a long-term facility lease in June 2013, which enables us to expand our capacity and take on much larger jobs."    

Petrobras announces that the oil output (oil plus natural gas liquids - NGL) of all of Petrobras' fields in Brazil was 1,979 thousand barrels per day (bpd), volume 4.6% higher than May (1,892 thousand bpd). Including the share operated by the company for its partners, oil output in Brazil reached 2,043 thousand bpd, indicating a 5.2% rise compared to May.


In June, Petrobras' total output (oil and natural gas) in Brazil averaged 2,378 thousand barrels of oil equivalent per day (boed), 4.8% higher than May. Including the share operated by Petrobras for partner companies, total production in June was 2,489 thousand boed, 5.5% higher than the previous month.



The increase in production was due to the startup of new wells connected to platforms FPSO Cidade de Itajaí, in Baúna field, Santos Basin, and FPSO Brasil, in Roncador field, Campos Basin, in addition to the startup of FPSO Cidade de Paraty, in the Lula NE Pilot Project, in the Santos Basin pre-salt. The production increase was also aided by the return into operation of platforms P-25 and P-31, in Albacora field, Campos Basin; and of FPSO Cidade de Angra dos Reis, which operates in the Lula field pilot project, in the Santos Basin pre-salt. These production units were undergoing planned shutdowns in May. According to the schedule, in June, platforms P-20 and Pampo-1 (PPM-1), both in Campos Basin, were stoped for maintenance.



Moreover, it is important to highlight the pre-salt's rising contribution to total volume. In June, a new record was set with the daily average of 310.2 thousand bpd, including the share operated by the company for its partners.

Total oil and natural gas production in June, including the company's production abroad, averaged 2,612 thousand boed, 4.2% higher than May.



Natural Gas Production



In June, Petrobras' non-liquefied natural gas output in Brazil was 63,430 thousand cubic meters per day, 6.2% higher than May. Total gas production in Brazil, including the share operated by the company for its partners, was 70,834 thousand cubic meters per day, a 6.8% rise compared to the previous month.


International Production



In June, total oil and natural gas production abroad was 234,885 boed, which corresponds to a 0.7% rise against May. Of this total, 144,131 bpd of oil were produced, stable when compared to the previous month. International natural gas output was 15,419 thousand cubic meters per day, 1.9% higher than the volume produced in May.



The rise in international output was primarily due to higher demand for Bolivian gas by the Brazilian market.


Information to the Brazilian National Agency for Oil, Natural Gas and Biofuels (ANP)

Total output reported to Brazil's National Petroleum, Natural Gas and Biofuels Agency (ANP) in June 2013 was 9,191,902.60 m³ of oil and 2,234,271.65 thousand m³ of gas.

This output corresponds to the total output from concessions where Petrobras is the operator. It does not include shale, NGL volumes and partners' output where Petrobras is not the operator.


NYC-based PIRA Energy Group reports that global Asian oil markets remain supported on a global basis. On the week, U.S. stocks fell, split about equally between crude and products.  In Japan, crude stocks drew on higher runs and contained imports. Specifically, PIRA’s analysis of the oil market fundamentals has revealed the following: 

Asian Oil Markets Remain Supported on a Global Basis

Oil prices remain at the top of their trading range with firmness being supported by tightened crude balances which are being fueled by supply losses from producers such as Libya and Iraq and ongoing outages from Syria and Nigeria. All told, the market is currently at its maximum point of physical strength, with high runs, supply losses and crude stock declines. 

Overall Commercial Inventories Decline

U.S. stocks fell for the week ending August 16, split about equally between crude and products and matching last year's inventory decline for the same week. This left the inventory excess 1.9% above year ago levels. The bulk of the excess inventory is in gasoline. Overall adjusted oil demand growth is now running just 0.9% above year ago levels. This is the second week in a row that demand growth was no higher than 1% after three earlier weeks of near 3% growth. Some of PIRA's other energy indicators of economic growth (e.g. electricity demand) have also been weakening, which is not a good sign for the economy. 

Two Weeks of Japanese S/D Data

Two weeks of data were reported this past week due to the mid-August hiatus. Crude stocks drew on higher runs and contained imports. Gasoline demand was expectedly strong. Conversely, gasoil demand eased sharply due to the typical mid-August vacation impacts and stocks built, even with higher exports. Kerosene stocks continued to build seasonally, with the average build rate over the last two weeks being relatively high. 

Slow U.S. Stock Building

U.S. propane storage is building rather slowly pushing its price higher going into the crop drying and heating seasons. Butane demand will gain for gasoline blending while ethane continues to be impacted by steam cracker outages. 

Ethanol Prices Advance

U.S. ethanol prices rose the week ending August 16 due to higher corn costs and a tighter market with lower inventories. Prices were also supported by concerns that output will decrease prior to the next harvest because of plant maintenance and corn shortages. RIN prices rebounded after falling to a three-month low in the previous week.

Ethanol Output Decreases

U.S. ethanol production declined to 844 MB/D the week ending August 16, the second lowest level since April, and down from 857 MB/D in the preceding week. Due to dwindling supplies, some ethanol producers have contracted to barge in corn from as far south as Louisiana, where the 2013/2014 harvest has already started. 

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.

Apache Corporation (NYSE, Nasdaq: APA) has announced it has agreed to sell oil and gas producing properties in the Nevis, North Grant Lands and South Grant Lands areas of western Alberta, Canada, to Ember Resources Inc., a private Canadian company, for US$214 million (CAN$220 million).

"Going forward, Apache is focused on growing our liquids production from a deep inventory of crude oil- and liquids-rich opportunities that generate attractive rates of return on our extensive remaining acreage in Canada's Western Sedimentary Basin," said Rodney J. Eichler, president and chief operating officer. "We also remain focused on advancing the Kitimat LNG project to monetize large unconventional resources in the Liard and Horn River basins in northern British Columbia.

"This transaction is one element of a comprehensive review of Apache's portfolio to determine which assets make the most sense for Apache to own given our growth and return objectives and which assets are better owned by others," Eichler said. "The Nevis, North Grant Lands and South Grant Lands assets fit in the latter category."

Apache's Nevis, North Grant Lands and South Grant Lands assets

The assets comprise 621,000 gross acres (530,000 net acres) and more than 2,700 wells that had average net production of 67 million cubic feet of gas and 237 barrels of liquid hydrocarbons per day from late Cretaceous sands and coal seams during the second quarter of 2013. Apache will retain 100 percent working interest in horizons below the Cretaceous, such as potential Duvernay and Nisku, in Nevis and North Grant Lands.

The effective date of the transaction is April 1, 2013, and it is expected to be completed during the third quarter, subject to customary regulatory approvals and other closing conditions.

"I commend the employees who have worked these assets for many years of safe and environmentally responsible operations," Eichler said.

Portfolio Rebalancing

Apache previously announced plans to divest $4 billion in assets by year-end 2013. The company intends to use proceeds from the asset divestitures to reduce debt and enhance financial flexibility and to repurchase Apache common shares under a 30- million-share repurchase program authorized by the Board of Directors earlier this year.

In July, Apache announced an agreement to sell its Gulf of Mexico Shelf operations and properties to Fieldwood Energy LLC (Fieldwood), an affiliate of Riverstone Holdings, for cash proceeds of $3.75 billion. In addition, Fieldwood will assume all asset retirement obligations for these properties, which, as of June 30, 2013, Apache estimated at a discounted value of approximately $1.5 billion.

The Ferguson Group, global specialists in the provision of offshore DNV 2.7-1/EN12079 containers and accommodation solutions, has posted its 2012 results, which show continuing growth, with worldwide sales increasing by over 10% to £57.6m and pre tax profits up to £16.2m from £15.6m in 2011.



Commenting on the results, Richard Smith, Group Finance Director, said: “2012 was another successful year for the Ferguson Group, which saw the company increase profits during a year of continuing investment in our global infrastructure and asset base. The last two years have seen a substantial investment in infrastructure, strengthening our management team and continuing to build the rental fleet. We expect to see the benefits of this investment reflected in the result for 2013 and are ahead of plan at the half year.



The majority of our sales come from outside the UK and increasing our global presence is a key part of our business plan. The Middle East has been a region of accelerated growth for us, particularly following the launch of two new bases in Dubai and Abu Dhabi.  We also moved to larger facilities in Singapore at the beginning of 2013 to enable us to develop our business further in the Asia Pacific region and we are very optimistic about future prospects for the Group in all regions.


Our focused growth strategy continues to incorporate customer feedback, where operational safety and asset availability are key themes. We aim to put resources into those regions where our customers are at their busiest. Global expansion will continue to be a top priority for the Group over the next 12 months, as we move into other regions where clients require access to our extensive fleet of DNV 2.7-1/EN 12079 certified containers, tanks, baskets, accommodation and workspace modules.



During 2012 we began rebranding the group’s companies under a single “Ferguson Group”, starting with our businesses in Australia and Singapore, which were renamed Ferguson Group Australia Pty Ltd and Ferguson Group Singapore Pte. Ltd respectively. The rebranding exercise continues throughout 2013.”

Oceaneering International, Inc. (NYSE: OII) has reported record quarterly earnings for the second quarter ended June 30, 2013. On revenue of $820.4 million, Oceaneering generated net income of $98.8 million, or $0.91 per share.  During the corresponding period in 2012, Oceaneering reported revenue of $672.5 million and net income of $72.6 million, or $0.67 per share.

  Year over year and sequentially, quarterly EPS increased as all business segments achieved higher operating income, led by Subsea Products and Subsea Projects. 

M. Kevin McEvoy, President and Chief Executive Officer, stated, "Our quarterly EPS was above our guidance range, and was up 32% over the first quarter of this year and up 36% compared to the second quarter of 2012.  Our above-guidance performance was attributable to sales of subsea hardware, demand for asset integrity services offshore Norway, and early completion of a theme park project.  We achieved record quarterly operating income from Remotely Operated Vehicles (ROV), Subsea Products, Asset Integrity, and Advanced Technologies.

"Our outlook for the second half of this year remains very positive and essentially unchanged from last quarter.  Given this outlook and our year-to-date performance, we are raising our 2013 EPS guidance range to $3.20 to $3.35 from $3.10 to $3.30.  Compared to 2012, we continue to forecast income growth for all of our operating segments in 2013.  Relative to the first half of 2013, we expect to generate higher operating income during the second half led by ROV and Subsea Projects. 

"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 $902 million, up from our March backlog of $776 million and $621 million one year ago.  The sequential and year-over-year increases in backlog were predominantly attributable to umbilical awards.  During the quarter we announced two large umbilical contracts, one for offshore Egypt and one for the U.S. Gulf of Mexico (GOM).

"Subsea Projects operating income increased due to a seasonal uptick in GOM demand for deepwater intervention and an escalation of work under our field support vessel services contract offshore Angola.  The work offshore Angola included the provision of another chartered vessel, the Maersk Attender, for half of the quarter.  The charter term on the Maersk Attender runs through September 2013, followed by two 45-day renewal options, subject to our customer's work program.