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    BG Group verdient wegen geringerer Flüssiggas-Lieferungen weniger - 500 Beiträge pro Seite | Diskussion im Forum

    eröffnet am 18.07.14 12:16:20 von
    neuester Beitrag 28.06.16 11:27:48 von
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      schrieb am 18.07.14 12:16:20
      Beitrag Nr. 1 ()
      Der britische Öl- und Gaskonzern BG Group hat 2013 aufgrund von Abschreibungen weniger verdient als zuvor erwartet. Neben einer geringer ausgefallenen Ausfuhr von Flüssiggas (LNG) aus Ägypten machten niedrigere US-Gaspreise eine Anpassung …

      Lesen sie den ganzen Artikel: BG Group verdient wegen geringerer Flüssiggas-Lieferungen weniger
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      schrieb am 18.07.14 12:16:20
      Beitrag Nr. 2 ()
      kommt wegen LNG auf die watchlist
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      schrieb am 22.10.14 08:24:58
      Beitrag Nr. 3 ()
      Oversupply pushes Asian spot LNG prices down
      .
      Asian spot prices fell in the first half of October as the region struggled to absorb abundant supply of liquefied natural gas from the Pacific basin amid weak demand fundamentals, reveals the ICIS East Asia Index (EAX).

      The November ’14 East Asia Index (EAX) was assessed at $13.950/MMBtu on 15 October, having shed $0.775/MMBtu from a high point of $14.725/MMBtu on 29 September. This represented a $0.588/MMBtu loss since the contract rolled to become the front month on 16 September. December EAX was assessed at $14.468/MMBtu on 15 October, having fallen by $0.307/MMBtu since 16 September.

      As the new contract month began in mid-September, sellers cited the high cost of marginal supply from the Atlantic basin in pushing to extend the rally that began in late July. FOB (free on board) prices remained around $13.000/MMBtu in the Atlantic basin, while opportunities from the usual sources of Nigeria and Trinidad remained limited.

      Many of Japan’s larger utility buyers remained out of the market because of ample inventories and predictions of mild October weather. South Korea’s Kogas continued its attempts to enter into swap arrangements by offering prompt volumes to the market in return for receiving volumes later in the winter. However, smaller Japanese utilities and a number of Chinese buyers had expressed interest for November deliveries.

      On 26 September, the highest bid for delivery in the second half of November was recorded at $14.600/MMBtu into Japan, while the lowest offer for the same delivery period was heard at $15.100/MMBtu.

      By late September, the emergence of abundant supply from within the Pacific basin acted to cap any price rises. The North West Shelf project in Australia, the ExxonMobil-operated PNG LNG project and Abu Dhabi’s ADGAS opened tenders to sell at least four cargoes for November delivery. Indonesia’s Bontang LNG export plant also closed a tender for the delivery of up to six cargoes on a prompt basis, while the BP-operated Tangguh project on the Indonesian island of West Papua was heard to be marketing four early winter spot cargoes. These cargoes were released to the market because of a delay to the start-up of the Lampung floating terminal off the coast of southern Sumatra.
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      schrieb am 13.11.14 11:13:44
      Beitrag Nr. 4 ()
      Japan: spot LNG contracted in Oct at USD 15.3 per mmBtu
      Japanese Ministry of Economy, Trade and Industry (METI) said in a statement that the average price of spot LNG imported into Japan in October was 15.3 USD per MMBtu on DES basis.

      “The average price of Spot-LNG imported into Japan that arrived in October 2014 is 12.4 USD/MMBtu,” report shows.
      Report only includes spot-LNG imports traded on a cargo to cargo basis, excluding the long, medium or short-term contracts. The report also excludes cargoes linked to a particular price index.

      Japan, the world’s biggest buyer of liquefied natural gas, imported 87.73 million tonnes of LNG in the fiscal year ended in March, up 1 percent compared to the year before.
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      schrieb am 14.11.14 09:11:42
      Beitrag Nr. 5 ()
      PIRA: depressed oil market to push LNG prices downwards
      NYC-based PIRA Energy Group believes that a depressed oil market will be pushing down prices for both spot and contract LNG.

      PIRA notes that, in the U.S., last week’s net build caused by far the largest single week reduction of the year-on-year deficit since the start of the injection season. In Europe, total Norwegian gas exports are running extremely high for this time of year.

      PIRA finds that a depressed oil market will be pushing down prices for both spot and contract LNG. As oil prices fall, it will be important to note the price at which demand growth begins to rise, if it rises at all. The central question becomes whether or not it is a myth or reality that a pool of buyers exists that are price sensitive and have been lying dormant, or whether broader macroeconomic and contractual issues dictate more of the swing. For now, the Asian market is faced with relatively high stocks, and buyers continue to receive multiple offers for either spot volumes or topped-up contract levels.

      Last week’s EIA reported 91 BCF refill to Lower 48 storage left only one day remaining in the official 2014 injection season and brought working gas inventories to 3,571 BCF. Not long ago, such an end-October carryout seemed almost out of reach given the lowest end-March level in more than a decade. A full 8 BCF/D (56 BCF) higher year-on-year, last week’s net build caused by far the largest single week reduction of the year-on-year deficit since the start of the injection season.

      PIRA also reports that total Norwegian gas exports are running extremely high for this time of year at over 320 mmcm/d,. The 40-mmcm/d year-on-year increase is flowing almost exclusively into the German system. The gas demand increase is not coming from Germany, where temperatures are warmer than normal and PIRA’s 10-day outlook for weather-sensitive use shows a 32-mmcm/d loss in gas demand over this period. Part of the reason for this Norwegian jump is tied to the new 25-mmcm/d flow of gas from Slovakia to Ukraine via the new Budince link, which is pulling more gas out of the German system toward the southeast flow through the Czech Republic.

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      schrieb am 20.11.14 11:34:27
      Beitrag Nr. 6 ()
      Platts: December spot LNG prices in Asia drop
      Prices of spot liquefied natural gas for December delivery to Asia plunged 29.4% year over year to average $12.490 per million British thermal units (/MMBtu), according to the latest Platts Japan/Korea Marker for month-ahead delivery.

      At $12.49/MMBtu, the monthly average JKM for December delivery reached levels not seen since 2010, when the December JKM averaged $9.549/MMBtu. In the years following the Fukushima disaster and subsequent loss of nuclear power in Japan, December JKM monthly average prices had been consistently above $13.00/MMBtu.

      The JKM lost $4.425/MMBtu over the assessment period, recording the most volatile month in the history of the marker. After beginning the month at $14.925/MMBtu on October 16, the December JKM closed at $10.50/MMBtu November 14, a new low for 2014, as sentiment became increasingly bearish.

      “The recent uptick in prices lost momentum over the trading month, as the winter contango crunched. Sellers were less keen to take positions, and those holding them, particularly those with floating storage positions, began to undercut,” said Stephanie Wilson, managing editor of Asia LNG at Platts. “With inventories in Japan, South Korea and even India and China at high levels, many buyers have little appetite for incremental volumes and have taken to the sidelines of the market ahead of anticipated reductions.”

      The December JKM showed a 13.4% month-over-month decline as a result, bucking the trend of recent years in the run-up to the traditionally stronger winter demand season.

      Meanwhile, the price of possible competing fuel thermal coal increased 3.0% month over month, while fuel oil fell 13.4% over the October 16 to November 15 assessment period.
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      schrieb am 20.11.14 11:36:12
      Beitrag Nr. 7 ()
      PIRA: Asia needs suitable LNG trading hub
      NYC-based PIRA Energy Group believes that while downward pressure on European natural gas spot prices will eventually emerge, such a downward move in the weeks to come would mean that supply from several sources is overwhelming the market’s ability to consume it.

      PIRA also reports that in North America, U.S. natural gas storage built week-on-week, while in Asia, LNG storage issues moved up on the priority list as supply grows.

      PIRA says very little was seen in the way of storage draws this month around Europe, which implies that further cuts in domestic production (Dutch and U.K.) and imports will need to occur if a balance at current prices is to be struck.

      The holiday-delayed EIA weekly U.S. storage report that revealed a 40 BCF build topped the consensus by a few BCF while more handedly besting both the year-ago and 5-year average builds. Those bearish comparisons fueled additional NYMEX selling that followed the bullish-to-bearish price reversal that had dominated last week’s trading prior to the storage update.

      The quandary regarding the lack of a suitable Asian LNG/gas trading hub is a long standing one and as Asian buyers seek to decouple from oil linkage. It is taking on increasing importance, particularly for Asian and Mideast suppliers with no obvious gas benchmark. Furthermore, as a critical mass of LNG spot transactions migrate to Asia, not just during winter peaking periods but essentially as a year round form of supply, this missing “hub” is becoming increasingly awkward.
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      schrieb am 26.11.14 14:03:43
      Beitrag Nr. 8 ()
      Fitch: US closer to becoming major LNG exporter
      The recent final approvals and construction groundbreakings for several liquid natural gas export facilities along the Gulf Coast will make US LNG exports a reality in the near term, Fitch Ratings says.

      This week the US Department of Energy (DOE) approved Freeport LNG’s Expansion and liquefaction facility. Freeport and Cameron LNG have broken ground on export facilities and Sabine Pass is in advanced construction, moving the US closer to becoming a major exporter of LNG.

      DOE recently stopped reviewing non-Free Trade Agreement export applications. Instead, it will only act on applications after the review required by the National Environmental Policy Act has been completed and suspend its practice of issuing conditional decisions prior to final authorization decisions. While Fitch Ratings believes this may quicken the pace of approvals, the actual timing and the overall number of approvals remain unknown.

      With Freeport LNG, Cameron LNG, and Dominion’s Cove Point LNG projects underway and Cheniere set to finish construction on Sabine Pass and start exporting gas late next year, the US is moving closer to becoming a larger scale energy exporter. Whether or not this will have a meaningful impact on gas price remains unclear as the approved levels of export activity remain a small percentage of total U.S. gas production. The emergence of US LNG exports is contributing to the energy diversification strategy in countries like Japan that have been reliant on nuclear energy. However, the additional LNG capacity from the US is not expected to dramatically affect global pricing, as the projected US volumes are insufficient to materially alter the balance of global supply and demand.

      With final approvals received and construction underway at Cameron and Freeport, there are currently three LNG export projects under construction in the U.S., representing roughly 3.7 billion cubic feet per day (Bcf/d) of liquefaction capacity. Upwards of 28 Bcf/d of capacity remains in the queue for DOE or Federal Energy Regulatory Commission approval before being able to commence construction.

      Fitch believes that these approvals are critical to the success of those facilities as non-FTA countries are the majority of the potential LNG market.
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      schrieb am 28.11.14 11:51:33
      Beitrag Nr. 9 ()
      PIRA: Europe, LNG market’s storage center or dumping ground
      NYC-based PIRA Energy Group believes that Europe’s position in the LNG market in the upcoming months is fast becoming defined as either a storage center or an outright dumping ground.


      While prices in Asia have descended rapidly due to either losses in crude oil values or spot LNG quotes, the stickiness of NBP at current levels has made Europe a much more enticing netback for Atlantic Basin LNG suppliers. PIRA believes the key question will be whether high LNG imports by Europe will translate into higher LNG send out or will the import terminals just be used as a temporary home for storage before even larger reloads emerge in the first quarter?

      Last week’s EIA update on U.S. storage activity revealed that net draws have indeed begun. Most had expected a draw, but the reported decline easily bested the consensus estimate near 10 BCF. The wide “miss” prompted an initial ~10¢ rally in the nearby contract pushing December to ~$4.50 before selling pressures resulted in a steep ~25¢ pullback. But those losses ultimately uncovered enough buyers to lift the December contract back to its earlier high and also within striking distance of the November 10th high.

      Focus on Norwegian production problems seems to be paramount in justifying current gas prices at slightly higher levels. As PIRA has documented over and over again, the supply/demand fundamentals of the European gas market do not support prices at this level, even after factoring in the Norwegian glitch. Even after factoring in the temporary loss of this production capacity – 23-mmcm/d of potential output between Troll and Skarv – Norway is still exporting gas at all time highs for November. Perhaps what the market is saying, by raising day ahead another 3p/th over the past week, is that all time highs for Norwegian exports at this time of year are simply not enough despite record high storage levels and no sign of demand growth before or after adjusting for weather.
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      schrieb am 28.11.14 11:52:16
      Beitrag Nr. 10 ()
      UK’s LNG imports double
      The UK’s imports of liquefied natural gas doubled to 3,681 million cubic meters in the third quarter of 2014, compared to the same period last year.

      Faced with slumping LNG demand in Asian markets, Qatar shipped more cargoes to Britain, deepening the seasonal price drop.

      The monthly average LNG spot price in July was almost half that of July 2013, according to data by the Department of Energy & Climate Change (DECC).

      LNG imports from Qatar comprised 96 percent and 87 percent of total LNG imports for the period in 2014 and 2013, the data said.

      Pipeline imports fell across the board, with Norwegian imports down 17.7 percent, largely due to planned maintenance (on Vesterled and Langeled).

      Total imports of natural gas into the UK increased by 14.4 percent in the third quarter
      Avatar
      schrieb am 01.12.14 08:42:21
      Beitrag Nr. 11 ()
      Asian December spot LNG prices lowest since 2010
      Asian spot LNG prices fell to their lowest December levels since 2010 as a build-up of uncommitted cargoes in the Pacific weighed heavily on the market amid weak economic sentiment, according to the ICIS East Asia Index (EAX).

      The December East Asia Index was last assessed on last Friday at $11.094/MMBtu, marking a $3.269/MMBtu fall since it opened as the front month on 16 October. January ’15 EAX fell by $3.725/MMBtu to $11.263/MMBtu over the same period, reflecting further headwinds for sellers expected in the new year.

      In the second half of October, sellers initially took confidence after Brent crude appeared to find support at the $86.00/bbl level after the recent heavy sell-off. On 16 October, a December DES cargo from the latest PNG LNG cargo was heard to have closed above $14.00/MMBtu while a deal for H2 January was understood to have been closed just below this level.

      Demand from the usual winter sources remained muted as South Korea’s Kogas and most Japanese utilities reported they were unable to absorb further December cargoes. It was left to independent buyers in South Korea and China, as well as China’s state oil companies, to provide some support to the market. As late as 21 October, the highest bid from an East Asian buyer was recorded at $14.00/MMBtu.
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      schrieb am 05.12.14 12:50:10
      Beitrag Nr. 12 ()
      PIRA: Europe central for LNG price formation
      NYC-based PIRA Energy Group believes that Europe temporarily moves into a central role for global LNG price formation.

      It’s still relatively early on in the winter peak, but the near term balances are looking noticeably looser than they did ahead of October, with Asian weather so far offering no support whatsoever on the demand side, though it is starting to emerge in Europe.

      PIRA reports that last week’s day early pre-Thanksgiving U.S. storage update reflected a blockbuster draw rarely seen outside peak heating December through February periods. The “consensus” low-150s outlook could be labeled partly misleading given its unusually wide 130s to 160s range that encompassed large support at both ends, together with a standard deviation more than twice the past month’s weekly norm.

      PIRA also raises the question how long will day-ahead prices continue to minimize the nature of supply/demand fundamentals? It looks like it could be a while, as the weather outlook is turning colder than normal in some key demand markets. When this turn happens prior to the official start of winter, it can have a magnified influence on prices in the short term. PIRA is comfortable with supply availability for the market, but the forward curve reflects a growing lack of conviction and will continue to evoke a mood where a long position is the safest place to be.
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      schrieb am 13.01.15 23:29:48
      Beitrag Nr. 13 ()
      von Wood MacKenzie
      Industry Views 18 Dez 2014
      Low oil price to shake up Asian LNG

      Asian LNG will be affected by the drop in oil prices in a variety of ways – here we assess the future of the market

      As LNG contract prices are typically based on the average of the preceding six to nine months, it will be mid-2015 before suppliers feel the full effects of the low oil price on their cash flow.

      Currently, Asian contract prices sit around US$16/mmbtu - relatively high compared to spot which is trading in the region of US$10/mmbtu. This will provide an incentive to buyers to reduce contract supply and increase demand for spot LNG which could drive the price close to the cap set by oil prices.

      However, that cap has fallen from US$17-19/mmbtu in Q1 2014 to some US$11/mmbtu and, from mid-2015, spot priced LNG could trade at a significant discount. By this time, contract prices will be lower than our forecast of future oil price levels and demand for spot LNG will consequently reduce.

      Whether the drop in oil price will improve buyer appetite for oil indexation over alternative pricing arrangements, including Henry Hub from the US, will depend on whether the oil price shift is perceived as temporary, or a permanent feature of the market. Inevitably a low oil priced environment reduces the relative attractiveness of US LNG.

      Yet there are limitations to a simple comparison of delivered price. Some buyers will continue to perceive additional value in the flexibility of US LNG, whereas others will always prefer equity production offered from the more integrated projects outside the US.

      In addition, buyers and sellers need to agree mutually acceptable oil indexation terms before deals can be struck. They have been unable to reach a consensus for the last two years and the oil price drop could drive them further apart.

      Our existing base case forecast already expects multiple projects not to proceed because of impending oversupply and market competition. The fall in oil prices will likely force some of the less commercially attractive projects to be shelved, enabling companies to shift the blame for project postponements that should have been made 12 to 24 months ago.

      For now, we remain comfortable with our expectation that Asian contract pricing will continue to evolve and that lower oil indexed pricing with s-curves will be a feature. We are also confident in our expectations of new LNG volumes coming from the US and elsewhere which will lead to an over-supplied market where all new supply faces challenges on the road to development.
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      schrieb am 15.01.15 09:52:41
      Beitrag Nr. 14 ()
      Douglas-Westwood: global LNG capex to hit USD 259 billion in next five years
      The global capital expenditure (Capex) in the LNG industry will total nearly USD 259 billion from 2015 to 2019, according to a report by Douglas-Westwood.

      This includes spending on baseload onshore and offshore liquefaction, LNG carriers, and LNG regasification at onshore and offshore fixed terminals, Douglas-Westwood said in its ‘World LNG Market Forecast 2015–2019′.

      Australasia and North America will be the main center of liquefaction development while Asia will lead in installed capacity of import terminals. North America is projected to become a net exporter, transforming from the second largest import region over the past 5 years, to zero over the forecast period, according to the report.

      Key exporting regions of Africa, Australasia, and the Middle East will account for 60% of the total forecast liquefaction capacity. A combined 479.4 MTPA is expected to be introduced globally over the forecast period.

      From 2015 to 2019, Douglas-Westwood expects 178 MTPA of liquefaction capacity to come on stream with 15 expansion projects and 19 new developments. Associated costs for these terminals are expected to total USD 170 billion.

      Capex for the forecast period represents an increase of more than 90% from the previous 5 years. This is largely driven by new projects in North America and Australasia and totals 71% of liquefaction capacity additions in the forecast period.

      Investments in import facilities are expected to total nearly USD 66 billion, or a compound annual growth rate of 7%. The forecast Capex is expected to increase by 112% compared with the past 5 years, the report says.

      The LNG carrier market is expected to show heavy spend throughout the forecast period, increasing by almost one-third. General confidence in the LNG market and the growth in the number of LNG terminals point toward a strong LNG shipbuilding market, according to the report.

      With the anticipated demand, yard capacity at the major shipbuilders such as Daewoo, Samsung, and Mitsubishi may be constrained. Increasing participation of Chinese shipyards is expected in the LNG shipbuilding sector should the demand for LNG carriers continue to grow, Douglas-Westwood added.
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      schrieb am 16.01.15 23:04:35
      Beitrag Nr. 15 ()
      PIRA: LNG supply pace to slow down in 2015
      NYC-based PIRA Energy Group believes that the New Year will be marked by a slowdown in the pace of the new supplies originally set to hit the market in 2015.

      Competing pressure from even lower oil prices will only add to the start-up delays that have long been set in motion in Australia over labor, infrastructure costs and other issues.

      PIRA’s Gas Flash from two weeks ago noted that ongoing NYMEX gas price weakness partly reflected skepticism among traders taking a “show me” attitude toward forecasts of extremely cold near-term weather. Now, consensus forecasts of such frigid conditions through midmonth have materialized. PIRA’s updated Reference Case assumes close to normal readings later in the month, which raises the overall January 2015 GWHDD tally to ~6% above the 10-year normal but still ~6% milder than a year ago. Last week’s report includes an update of PIRA’s Reference Case for 1Q15 and 2015 as a whole.

      The market has finally and vigorously agreed with PIRA’s bearish portrayal of the European gas market over the past few months. While it took a bit longer than PIRA thought it would in the fourth quarter for spot prices to come down, they are now accelerating at a rate that is faster than it was expected. The most rapid rate of weakness is tied to three primary factors: lower oil prices, higher LNG supply, and warmer-than-normal weather in Northern Europe.
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      schrieb am 19.01.15 09:08:40
      Beitrag Nr. 16 ()
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      schrieb am 23.01.15 12:41:12
      Beitrag Nr. 17 ()
      habe mir nach den Guckstücken heute die erste Position gekauft
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      schrieb am 06.02.15 10:29:19
      Beitrag Nr. 18 ()
      Heftige Abschreibung in Q4 => Ganzjahresminus
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      schrieb am 16.02.15 09:34:19
      Beitrag Nr. 19 ()
      Low gas demand sees LNG tankers parked around Singapore
      The slower pace in the gas market has resulted in a number of LNG carriers being parked of idling in and around Singapore.

      It could be an indication that the slowdown in the gas market could be turning into a crisis, Reuters reports.

      An LNG hub like Singapore is a preferred port for shippers. Lower LNG spot prices in Asia, lower demand mean that many of the shipping companies need to park their unused tankers and ports like Singapore provide maintenance capabilities before the vessels get called back into operation.

      According to estimates by ship brokers, one-tenth of the global LNG fleet is not being used due to Asian gas market slow growth.

      According to Javier Moret head of LNG organization at RWE, 30 or 40 oil and gas carriers are located around Singapore with nothing to do.

      Reuters reports that some LNG tankers have been parked for months, and that 15 tankers currently parked in the region have a total capacity of 2.26 million cubic meters of LNG, creating losses of $60,000 in daily charter fees to ship owners.

      Partly influenced by oil slump, it is believed that the weakness in energy markets could put off the emergence of LNG as the pre-eminent energy source, ANZ bank told in its research.

      Besides gas prices, carrier rates have also tumbled according to shipping services company, Clarkson. The rates have drop from $90,000 in 2013 to $60,000, and analysts believe the daily LNG charter rates are about to remain low for whole 2015.
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      schrieb am 24.02.15 10:21:59
      Beitrag Nr. 20 ()
      Asian LNG prices to fall exposing European oil majors
      Weak crude prices and rising liquefaction capacity in 2015-2016 are likely to lead to lower Asian liquefied natural gas prices in the second half of 2015, Fitch Ratings says.

      This will put pressure on the earnings of European oil majors operating in the sector and weaken their credit metrics. Fitch Ratings expect most already approved LNG projects, including those in Australia and the US, will go ahead but others planned may not materialise. Russian projects are also more likely to be put on hold, due to limited access to international financial markets.

      LNG prices under long-term contracts in Asia, the largest LNG market by volume, are mainly oil-linked through the Japan Crude Cocktail price mechanism and follow crude prices with a three-to-six months lag. In January, Japan’s import price averaged USD14.3/mmbtu, down 15% year-on-year, compared with a more than 50% yoy decline for Brent crude. Fitch Ratings believe Japan’s LNG import price could fall below USD10/mmbtu later in 2015 under the base case modelling assumption that Brent will average USD55/bbl this year. This price is lower than break-even prices of Australian LNG plants due to start up in 2015-2017 (on average, USD11-13/mmbtu, including capital costs).

      Most European oil majors have Asian LNG operations, but BG Energy and Total are the most exposed. In 2014 BG sold 11 million tons of LNG, around 5% of global LNG volumes. Its LNG shipping and marketing segment generated an operating profit of USD2.5bn in 2014, 39% of the group’s total. BG guided the segment’s profits will not exceed USD1bn in 2015, reflecting the lower forward commodity price curves and slightly lower Atlantic basin supply. BG brought its Australian QCLNG project on stream in December, which should add 8mtpa of capacity to the market by mid-2016. While Fitch Ratings believe the project’s cash costs would be covered at USD10/mmbtu, its overall economics are questionable if crude prices remain depressed. The company’s LNG segment performance will be an important rating driver for BG in 2015.

      Total’s LNG business represents a smaller share of total profits but is similar to BG’s in absolute terms. It sold 12mt in 2014 and this will increase as two Australian projects, GLNG and Ichthys, come on-stream in 2015 and 2017. Unsatisfactory performance in the LNG business could put pressure on Total’s credit rating in 2015, especially if upstream production stagnates and capex and opex are not reduced.

      Total has a 20% stake in Russia’s Yamal LNG, led by Novatek. Yamal is due to start producing in 2017, but financing is uncertain due to sanctions effectively cutting off access to international debt markets. Falling Asian LNG prices could result in further delays to Yamal and other projects, such as Gazprom’s Vladivostok LNG and Rosneft’s Far East LNG.

      Australian upstream companies have sizeable exposure to LNG. Woodside Petroleum generated approximately 64% of its revenues from LNG in 2014. Its credit profile benefits from revenue and operational diversity and from lower growth capex. But the acquisition of stakes in two LNG projects from Apache reduces its rating headroom and production from the first project is not due to start until 2016. The impact on operating cash generation from the recent fall in oil prices was limited in 2014 given the lag in LNG pricing to crude oil prices and smaller share of oil in total production. However, lower LNG prices expected later in the year would inevitably hit 2015 earnings.

      Gas accounts for over 60% of production for Malaysia’s Petronas. Pricing terms in Asian LNG offtake contracts and low operating costs provide near-term protection. While a sustained deterioration in oil prices will reduce earnings, any credit impact should be limited due to its capex flexibility and strong liquidity.
      3 Antworten
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      schrieb am 27.02.15 14:46:31
      Beitrag Nr. 21 ()
      Antwort auf Beitrag Nr.: 49.156.886 von R-BgO am 24.02.15 10:21:59
      Peakoil und LNG-Zukunft
      SALVE R-BG-O

      Ich interessiere mich seit einiger Zeit für fossile Brennstoffe. Ich halte das Thema "Peakoil" für einen echten Game-Changer! Die momentanen Ölpreise sind der weltweiten Depression geschuldet. Selbst wenn die Wirtschaft weiter so daherplätschert, demnächst wird Öl & Gas wieder knapp. Spätestens, wenn die Shale-Fracking-Ponzi platzt :-)

      Auf BG bin ich wgen der gigantischen Abschreibungen gekommen. ISt doch prima, raus aus der Bilanz.

      Ich kann BG aber noch nicht so richtig einorden.

      a.) Sind die eher ein Gas-Produzent mit eigenen konventionellen Feldern?
      b.) Sind die eher ein Gas-Fracker???
      c.) Sind die eher ein LNG-Logistiker? (Terminals, LNG-Schiffe, Gas-Handel)

      BG leidet doch im Moment doppelt. Produziertes Gas ist billig und bringt daher weniger Kohle. Gleichzeitig ist LNG volumenmässig weniger gefordet wg. Wirtschaftskrise. Dann stehen die Transportschiffe nur im Hafen rum.

      Perspektivisch sehe ich LNG aber nicht so negativ.
      - Sollte die Propaganda gegen Russland funktionieren, müsste LNG-Transportkapazität her
      - Peakoil wird das ausweichen auf andere Energiequellen bewirken. Gas ist noch entwicklungsfähig. Dazu braucht es aber Pipelines oder LNG-Logistik.


      Sollte BG eher eine Fracker-Bude sein, dann würde ich dort niemals investieren.

      Würde mich über deine Sicht freuen.
      By the way...sende dir auch eine Boardmeldung.

      Petronius
      2 Antworten
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      schrieb am 13.03.15 21:49:21
      Beitrag Nr. 22 ()
      Antwort auf Beitrag Nr.: 49.195.889 von Petronius am 27.02.15 14:46:31Wer die Analysen zu BG Group liest, muss sich wie in einem Irrenhaus
      vorkommen. so unterschiedlich sind die Statements unserer Anal-ysten-Guilde.
      Sind da Interessen dahinter, oder können sie es nicht oder sind sie alle
      Dilettanten.
      Avatar
      schrieb am 14.03.15 09:32:39
      Beitrag Nr. 23 ()
      Antwort auf Beitrag Nr.: 49.195.889 von Petronius am 27.02.15 14:46:31
      sorry wegen der verzögerten Antwort
      ich sehe BG als Mischung aus a) und c):

      sowohl E&P -und zwar auch Öl!- als auch LNG-Logistik
      Avatar
      schrieb am 09.04.15 11:51:08
      Beitrag Nr. 24 ()
      BRUMMER!:
      BREAKING Shell, BG forming LNG colossus


      Two of the world’s largest LNG players, Royal Dutch Shell and BG Group of UK, are about to reshape the global LNG industry.

      “The Boards of Shell and BG have reached an agreement on the terms of a recommended cash and share offer to be made by Shell for the entire issued and to be issued share capital of BG,” the two energy giants said in a statement on Wednesday.

      According to the statement, Shell will buy BG Group for approximately £47 billion in cash and stock. The Combination will result in BG Shareholders owning approximately 19% of the Combined Group, the statement said.

      The deal will add some 25% to Shell’s proved oil and gas reserves and 20% to production, each on a 2014 basis, and provide Shell with enhanced positions in competitive new oil and gas projects, particularly in Australia LNG and Brazil deep water.

      “Bold, strategic moves shape our industry. BG and Shell are a great fit. This transaction fits with our strategy and our read on the industry landscape around us.

      BG will accelerate Shell’s financial growth strategy, particularly in deep water and liquefied natural gas: two of Shell’s growth priorities and areas where the company is lready one of the industry leaders. Furthermore, the addition of BG’s competitive natural gas positions makes strategic sense, ahead of the long-term growth in demand we see for this cleaner-burning fuel,” Ben van Beurden, CEO of Shell said.

      “This transaction will be a springboard for a faster rate of portfolio change, particularly in exploration and other long term plays. We will be concentrating on fewer themes, and at a larger scale, to drive profitability and balance risk, and unlock more value from the combined portfolios. Over time, the combination will enhance our free cash flow potential, and our capacity to undertake share buybacks, where I expect to see a substantial increase in pace,” Beurden added.

      BG has a large global LNG portfolio with multiple production sources around the world, including Egypt, Trinidad and Australia. The company has also several projects under development in the US Gulf coast, Canada’s west coast and East Africa. Its fleet includes around 25 owned and leased LNG carriers – one of the largest in the world.

      Shell has more than 40 owned or leased LNG tankers and the energy giant is linked to around one-third of the world’s LNG carrier operations. Among other, Shell is building the giant Prelude floating liquefaction vessel which will be located offshore Western Australia.
      2 Antworten
      Avatar
      schrieb am 15.02.16 13:48:01
      Beitrag Nr. 25 ()
      Antwort auf Beitrag Nr.: 49.524.821 von R-BgO am 09.04.15 11:51:08Shell completes takeover of BG Group

      Feb 15 2016, 05:45 ET | By: Yoel Minkoff, SA News Editor

      The $53B mega deal - creating the world's biggest trader of liquefied natural gas - came into force today after shareholders waved through the tie-up at the end of January despite slumping oil prices.

      "We will now be able to shape a simpler, leaner, more competitive company, focusing on our core expertise in deep water and LNG," CEO Ben Van Beurden declared.

      Shell (RDS.A, RDS.B) has said it will cut more than 10K jobs from the combined group and sell $30B of assets over the next three years in order to finance the deal, buy back shares and support dividends.
      1 Antwort
      Avatar
      schrieb am 19.02.16 09:07:34
      Beitrag Nr. 26 ()
      Antwort auf Beitrag Nr.: 51.749.365 von R-BgO am 15.02.16 13:48:01
      Stücke wurden ausgebucht
      over-and-out
      Avatar
      schrieb am 28.06.16 11:27:48
      Beitrag Nr. 27 ()


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