Germany’s oil, gas output falls 3 per cent in 2018
Germany produced 10.3 million tonnes of oil and 26.1 billion cubic metres (bcm) of gas in 2018, both down 3 percent year-on-year, industry association BVEG data showed on Tuesday. Producers of hydrocarbons in Germany include DEA, Neptune Energy, Vermilion Energy, Wintershall and a joint venture of ExxonMobil and Royal Dutch Shell. Member firms of BVEG, which is based in Hanover, had turnover of 1.7 billion euros ($1.91 billion) in Germany last year, the same as a year earlier, it said in its annual report. German production accounted for about 7.2 percent of domestic gas needs last year, the report showed. BVEG Managing Director Ludwig Moehring said there was potential to produce more gas from domestic reserves to fill the gap as Germany phases out coal-fired power stations and shifts to renewables. Germany has 21.4 billion cubic metres of underground gas storage capacity, roughly a quarter of total supply to the market which was 86 bcm last year.
Govt defers bid deadline for OALP-II by a month to April 10
The government has deferred by one month the last date for bidding for the 14 oil and gas exploration blocks offered in the second round of Open Acreage Licensing Policy (OALP). Bids for the 14 blocks offered in OALP-II bid round, covering an area of 29,333 square kilometres, were to close Tuesday. “Bid submission closing date for OALP Bid Round-II stands extended up to April 10, 2019,” the Directorate General of Hydrocarbon (DGH) said in a brief notice. It did not give reasons for extending the deadline. The last date of bidding coincides with the bid deadline for the 23 oil and gas and coal-bed methane (CBM) blocks offered in the third round of OALP, which was launched on February 10. OALP-II bid round was delayed at six months and its launch came barely a month before the third round. Officials said OALP-II and OALP-III will run concurrently. Oil Minister Dharmendra Pradhan had at the time of launch of OALP-II bid round on January 7 stated that an investment of about Rs 40,000 crore is expected in the prospecting of oil and gas in blocks offered. In the first round of OALP last year, as much as Rs 60,000 crore was committed in the exploration of oil and gas in 55 blocks or areas. In the third round, the government is expecting up to USD 700 million (about Rs 49,000 crore) of investment that it hopes will help raise domestic output and cut imports. India had in July 2017 allowed companies to carve out blocks of their choice with a view to bringing about 2.8 million sq km of unexplored area in the country under exploration. Under this policy, called open acreage licensing policy or OALP, companies are allowed to put in an expression of interest (EoI) for prospecting of oil and gas in any area that is presently not under any production or exploration licence. The EoIs can be put in at any time of the year but they are accumulated twice annually. The blocks or areas that receive EoIs at the end of a cycle are put up for auction with the originator or the firm that originally selected the area getting a 5-mark advantage. The two window of accumulating EoIs end on May 15 and November 15 every year. EoIs accumulated till May 15 are supposed to be put on auction by June 30 and those in the second window by December 31. The first OALP round was launched in 2017 and bids came in by May 2018. EoIs for second round closed on May 15, 2018, and the blocks were supposed to be put for auction by June but the round was for reasons unknown delayed. OALP-II was finally launched on January 7. In the meanwhile, EoIs in the third window also closed on November 15, 2018 with as many as 18 blocks and five CBM blocks, measuring 31,722 sq km, being sought for. OALP-III bid round was launched on February 10 with April 10 as the last date for bidding. Officials said the 14 blocks in OALP-II are estimated to hold in-place resource of 12,609 million tonne oil and oil equivalent gas. In OALP-1, mining mogul Anil Agarwal-led Vedanta Ltd walked away with 41 out of 55 blocks bid out. State-owned Oil India Ltd won nine blocks while Oil and Natural Gas Corp (ONGC) managed to win just two. State gas utility GAIL, upstream arm of Bharat Petroleum Corp Ltd (BPCL) and Hindustan Oil Exploration Co (HOEC) won one block each. The 55 blocks have a total area of 59,282 sq km. This compares to about 1,02,000 sq km being under exploration prior to OALP. Blocks are awarded to the company which offers the highest share of oil and gas to the government as well as commits to doing maximum exploration work by way of shooting 2D and 3D seismic survey and drilling exploration wells. Increased exploration will lead to more oil and gas production, helping the world’s third largest oil importer to cut import dependence. Prime Minister Narendra Modi has set a target of cutting oil import bill by 10 per cent to 67 per cent by 2022 and to half by 2030. Import dependence has increased since 2015 when Modi had set the target. India currently imports 83 per cent of its oil needs. The new policy replaced the old system of government carving out areas and bidding them out. It guarantees marketing and pricing freedom and moves away from production sharing model of previous rounds to a revenue-sharing model, where companies offering the maximum share of oil and gas to the government are awarded the block. The government prior to this had been selecting and demarcating areas it feels can be offered for bidding in an exploration licensing round. Under this, 256 blocks had been offered for exploration and production since 2000. The last bid round happened in 2010. Of these, 254 blocks were awarded. But as many as 156 have already been relinquished due to poor prospect.
Serbia’s Gastrans invites binding bids for new gas link
Serbia’s Gastrans has invited binding bids to book capacity at a planned section of Gazprom’s TurkStream pipeline, which will carry Russian natural gas across Serbia to Europe. Firms that placed non-binding offers in the market test of the project last year can place binding bids by March 18 for gas transit between Jan. 1, 2020, and Sept. 30, 2039, Gastrans said. Gastrans is owned by Swiss-based South Stream Serbia, in which Russia’s Gazprom holds a 51 percent stake and Serbia’s gas monopoly Srbijagas the remainder. The TurkStream project is designed to deliver gas to Europe via Turkey, Bulgaria, Serbia and Hungary as part of Russian plans to bypass Ukraine, currently a main transit route for its gas deliveries to Europe. The planned 400-kilometre link through Serbia, which connects the country’s natural gas transmission system to those of Bulgaria and Hungary, is expected to be completed by Dec. 15, with capacity of 13.88 billion cubic metres a year. It is slated to begin commercial operation on Jan. 1, 2020. In last year’s market test, Gastrans received non-binding bids for the import of 9,139 gigawatt hours (GWh) of natural gas per day from Bulgaria and the export of 5,258 GWh of gas per day to Hungary in 2019-2039. The European Union’s energy watchdog said last week the project would hurt competition in the region after Serbia’s energy regulator exempted it from the EU’s Third Energy Package, a 2009 reform to integrate the EU energy market and boost competition.
Pakistan to offer gas fields to foreign explorers, investors: Official
Pakistan plans to offers dozens of gas field concessions in the coming year to fill in a fuel shortage, a senior official said, with Islamabad hoping a sharp drop in militant violence and changes to exploration policy will attract foreign investors. Much of the mineral-rich South Asian nation remains unexplored despite gas discoveries dating back to the 1950s. Conventional gas reserves are estimated at 20 trillion cubic feet (tcf), or 560 billion cubic meters, and shale gas reserves, which are untouched, at more than 100 tcf. Italy’s ENI and U.S. oil major Exxon Mobil are jointly drilling for gas offshore in Pakistan’s Arabian Sea, but many other Western companies have not returned after leaving more than a decade ago because of Islamist militant violence. Nadeem Babar, head of Prime Minister Imran Khan’s Task Force on Energy Reforms, told Reuters the government was amending its natural gas regulation and drawing up its first-ever shale gas policy, with licensing rounds to follow later this year. The government hopes improving security in recent years and the country’s extensive pipeline network will attract investors. More than 30 onshore gas blocks have been identified and the government plans to auction a large chunk of them in one or two licensing rounds by the end of 2019, Babar said in his office in the capital Islamabad. “I expect in the second half of this year we will be auctioning at least 10, if not 20 blocks for exploration.” Pakistan’s domestic gas output has plateaued in the last five years, falling to 1.46 trillion cubic feet in 2017/18, from 1.51 trillion cubic feet in 2012/2013, according to an annual report from the Petroleum Ministry. This has led to severe gas shortages as Pakistan’s population, now at 208 million people, has risen sharply over the same period, driving fuel demand from industries and new power plants higher. Gas demand was estimated at 6.9 billion cubic feet per day for 2017/18, according to Pakistan’s Oil & Gas Regulatory Authority, nearly 3 billion cubic feet more than daily output. To help plug the deficit, Pakistan has built two liquefied natural gas (LNG) import terminals, and demand is expected to hit 6.97 billion cubic feet a day for 2018/19, and 7.06 billion cubic feet a day in 2019/20. But LNG is expensive, so Islamabad wants foreign companies to ramp up domestic exploration. Babar said Pakistan was also drafting its first shale gas policy and it should be finished this year, with a licensing round in the first half of 2020. One recent study by the U.S. Agency for International Development (USAID) put Pakistan’s shale gas reserves at more than 100 tcf in the Lower Indus Region alone, enough to meet current demand for at least a few decades. One of the keys to developing natural gas production is to give investors affordable and reliable access to a pipeline network, Babar said, and such a plan is being drafted. “The entire mechanism of how the pipeline system is working today is being is being re-looked at, to make it more deregulated, make it more open access,” Babar said. PROLIFIC BLOCKS & GOOD DATA Babar said the blocks for auction were “prolific and … (had) good data”, with interested companies including Saudi Arabia’s Aramco, Exxon Mobil and Russia’s Gazprom. Only about 4 percent of Pakistan’s landmass has been explored, and the success rate, with one out of three wells making a find, is above the international average, he said. Babar said at least three more offshore blocks have also been carved out near where Eni and Exxon are searching for gas. “We will be auctioning those … probably next year.” To address security concerns, Babar said a military or a paramilitary unit will be created to guard companies that are exploring in the riskier parts of Pakistan, with the companies paying the costs. “A mechanism like what was done in CPEC will be developed,” Babar said, referring to a 15,000-strong army division set up to safeguard Beijing-funded infrastructure projects in the China-Pakistan Economic Corridor (CPEC). Pakistan also plans to introduce measures that ensure auction rights are unaffected by government or policy changes, to give investors greater regulatory certainty.
Serbia’s Gastrans invites binding bids for new gas link
Serbia’s Gastrans has invited binding bids to book capacity at a planned section of Gazprom’s TurkStream pipeline, which will carry Russian natural gas across Serbia to Europe. Firms that placed non-binding offers in the market test of the project last year can place binding bids by March 18 for gas transit between Jan. 1, 2020, and Sept. 30, 2039, Gastrans said. Gastrans is owned by Swiss-based South Stream Serbia, in which Russia’s Gazprom holds a 51 percent stake and Serbia’s gas monopoly Srbijagas the remainder. The TurkStream project is designed to deliver gas to Europe via Turkey, Bulgaria, Serbia and Hungary as part of Russian plans to bypass Ukraine, currently a main transit route for its gas deliveries to Europe. The planned 400-kilometre link through Serbia, which connects the country’s natural gas transmission system to those of Bulgaria and Hungary, is expected to be completed by Dec. 15, with capacity of 13.88 billion cubic metres a year. It is slated to begin commercial operation on Jan. 1, 2020. In last year’s market test, Gastrans received non-binding bids for the import of 9,139 gigawatt hours (GWh) of natural gas per day from Bulgaria and the export of 5,258 GWh of gas per day to Hungary in 2019-2039. The European Union’s energy watchdog said last week the project would hurt competition in the region after Serbia’s energy regulator exempted it from the EU’s Third Energy Package, a 2009 reform to integrate the EU energy market and boost competition.
NGT order could fire up Gujarat Gas earnings
Gujarat Gas is likely to see up to 20 per cent earnings boost in earnings as a result of National Green Tribunal’s order to shut all coal-operated units of ceramic companies in Morbi, Gujarat, said analysts. Shares of Gujarat Gas continued its positive trend due to the recent order and ended up 4 percent at Rs 141 on the BSE on Monday. Morgan Stanley said the NGT order is one of the most stringent seen in the country, with a two-month deadline to shut existing coal infrastructure and significant penalties after that. “Gujarat Gas is only supplier of gas in the area and its F20/F21 earnings could get a 12-15 percent boost,” said Morgan Stanley, retaining ‘outperform’ rating with a target price of Rs 231.60. Deutsche Bank expects as much as over one million metric standard cubic metres (mmscmd) of new demand from the Morbi area for Gujarat Gas if and when the NGT order is implemented. “Every 1 mmscmd additional gas sales volume leads to a 20 percent increase in Gujarat Gas’s earnings,” said Deutsche Bank, which has a buy rating and target price of Rs 160 on the stock. Shares of Gujarat Gas have gained 0.7 percent in the last six months compared to Indraprastha Gas and Mahanagar Gas which have gained 12.6 percent and 7 percent respectively, in the same period. However, analysts have a bullish view on the stock. Bloomberg data shows that 22 of the 26 analysts tracking the stock have a buy rating on it while three have a hold rating and one analyst has a sell recommendation. The consensus target price of Rs 161.03 implies a potential upside of 14.2 percent from current levels. Antique Stock Broking believes that Gujarat gas has immense potential for growth. “In addition to additional growth potential from Morbi, company has connected several new GAs (geographical areas Dahej, Panchmahal, Silvasa and Thane) over past few quarters, where the gas sale has started picking up. We accordingly estimate a gas sales CAGR of 10 per cent (FY18-FY21), leading to an earnings CAGR of 29 per cent over the period,” said Antique. Gujarat Gas had reported a 130 per cent rise in standalone net profit for the December quarter to Rs 138 crore while total income rose 34.7 per cent to Rs 2,187.3 crore.
China’s CNOOC explores opening up LNG terminals under reform pressure
CNOOC, China’s biggest operator of liquefied natural gas (LNG) import terminals, is talking to independent companies about access to its facilities after short trial leases last year, three sources with knowledge of the discussions said. The initiative, begun earlier this year, comes amid Beijing plans to form a national pipeline company by combining assets from state energy companies, in a reform of the sector that’s intended to spur private investment and boost use of cleaner-burning natural gas. Gas terminals and storage tanks, in which China National Offshore Oil Corp, parent of CNOOC Ltd, is among the top investors, could be the next assets to be transferred to the pipeline group that is likely to be launched this year, industry sources following the reform plan said. CNOOC is offering pipeline developers such as ENN Energy and LNG distributors such as Longkou Shengtong Energy the chance to use its LNG terminals on China’s east coast over a 10-year period, with a specified number of slots each year. The business could reap state-run CNOOC tens of millions of dollars a year in relatively risk-free revenue. Broader access to its 20 or so receiving terminals – all built by state majors except for a few by private firms including ENN – would likely boost LNG imports into China. China has been the world’s second-biggest buyer of LNG since 2017, with its intake growing more than 40 percent a year in each of the past two years. As an option to terminal access, CNOOC has also asked companies to offtake some of its import cargoes signed under term agreements with global suppliers, said two of the sources. “The discussions about opening terminals … is compatible with the broad state policy to connect LNG import facilities with main gas pipelines such as the West-to-East project,” said a state oil LNG executive based in the southern city of Shenzhen. The executive declined to be named as he’s not authorized to speak to press. CNOOC did not respond to Reuters’ request for comment. CNOOC sold two five-day terminal slots late last year via open tenders, gaining 63 million yuan ($9.39 million) out of the sales. In one of the deals, private firm Shengtong teamed up with state-owned Zhenhua Oil. The second deal was done by private LNG distributor Zhejiang Panergy. The sales encouraged CNOOC to broaden the openings, and the latest initiative of offering long-term terminal access would also make CNOOC appear supportive of Beijing’s push to open state infrastructure to third parties, the sources said. Private firms, however, remained cautious. “The prices paid for the access need to be regulated. Companies will need to think carefully whether they could pass on that cost to their consumers,” said an executive with a city-gas distributor approached by CNOOC. If CNOOC ties pipeline access to its term cargoes, which tend to be more pricey than the spot market, CNOOC’s initiative could be a hard sell, said a second official with knowledge of CNOOC’s plan.
IGL partners with XGEPL to convert diesel-based power gensets to gas
City gas distributor Indraprastha Gas Ltd (IGL) today announced it has partnered with a local firm XGEPL for converting the diesel power generator sets of its existing PNG consumers in the Delhi-NCR region into gas-based generator sets. “In the pilot phase, the company has converted in-use 3 diesel generators in institutions using Euro IV technology and have been made operational. Apart from contributing to the environment, these gas-based gensets would reduce the operational cost by around 40 per cent as compared to diesel-run gensets,” IGL said in a statement. As part of the company’s green drive, IGL Managing Director E S Ranganathan today inaugurated a gas-based 125 Kilo Volt Ampere genset here.
BP, Exxon to help advance Alaska LNG export project: Alaska Gasline
Alaska Gasline Development Corp (AGDC) said it signed an agreement with BP PLC and Exxon Mobil Corp to help advance the state-owned company’s proposed $43.4 billion Alaska liquefied natural gas (LNG) project: * “Our respective organizations share an interest in the successful commercialization of Alaska’s stranded North Slope natural gas,” AGDC Interim President Joe Dubler said in a statement late Friday. * BP and Exxon Mobil produce massive amounts of oil in Alaska and have discovered huge gas resources that are stranded in the North Slope. * The Alaska LNG project is designed to liquefy 3.5 billion cubic feet per day of gas for sale to customers in the Asia-Pacific region from a facility to be built in Nikiski on the Kenai Peninsula south of Anchorage. It includes an 807-mile (1,300-km) pipeline from the North Slope. * U.S. energy regulators recently delayed the date they expect to decide on the LNG project to June 2020 from February 2020. * Officials at AGDC have said the company is reviewing the timeline to get the project built. * At the same time, AGDC said it is continuing negotiations with several parties interested in the project, including a joint development agreement with Chinese oil and gas company Sinopec, China’s sovereign wealth fund China Investment Corp’s CIC Capital Corp and the state-owned Bank of China.
Govt overhauls oil, gas exploration policy; no profit to be charged on output in less explored areas
In a major overhaul of oil and gas exploration permits, the government will not charge any share of profit on hydrocarbons produced from less explored areas as it looks to attract the elusive private and foreign investment to raise domestic output. Breaking from the two-and-a-half decade-old practice of having a uniform contractual regime for all sedimentary basins in the country, the new policy provides for different rules for areas that already have producing fields and ones where commercial production of oil and gas is yet to be established. Irrespective of the basins, producers will get complete marketing and pricing freedom for oil and gas in future bid rounds, said an official notification detailing rule changes approved by the Union Cabinet on February 28. Oil and gas acreage or blocks in all future bid rounds will be awarded primarily on the basis of exploration work commitment, it said. While companies will have to pay a share of revenue from oil and gas produced in Category-I sedimentary basins such as Krishna Godavari, Mumbai Offshore, Rajasthan or Assam where commercial production has already been established, they will be charged only prevalent royalty rates on oil and natural gas in the less explored Category-II and III basins. “To expedite production, concessional royalty rates will be applicable if production is commenced within four years for onland and shallow water blocks, and five years for deep water and Ultra-deepwater blocks from the effective date of the contract,” it said. India began bidding out oil and gas exploration acreage in 1999 under New Exploration Licensing Policy (NELP) that awarded blocks to companies offering maximum work commitment. But companies were obliged to share with the government profits made after recovery of cost. Two years back, the BJP-government brought in Hydrocarbon Exploration and Licensing Policy (HELP) that provided for blocks being awarded to companies offering maximum revenue at different levels of prices and production. HELP failed to either raise output or attract new players. The notification said the new policy was being formulated “to increase exploration activities, attract domestic and foreign investment in unexplored/unallocated areas of sedimentary basins, and enhance domestic production of oil and gas”. While blocks in Category-1 basins would be awarded on basis bided exploration work and revenue share in the ratio of 70:30, those “in Category-II and Category-III Basins will be awarded on the basis of international competitive bids based exclusively on the exploration work programme.” “The contractor will have full marketing and pricing freedom to sell on arm’s length basis. Discovery of prices will be on the basis of transparent and competitive bidding. No exports will be allowed. There will be no allocation by Government,” the notification said. The Contractor will have liberal freedom to transfer/exit the block provided work programme has been adhered to. However, a suitable penalty mechanism will be devised for non-completion of the work programme. The notification said that in case of the existing contracts, marketing and pricing freedom to sell on arm’s length basis through competitive bidding will be permitted to those new gas discoveries whose Field Development Plan (FDP) will be approved for the first time after the date of issuance of the new policy. In case of nomination fields given to national oil companies, marketing and pricing freedom will be provided subject to the condition that FDP for new gas discoveries is approved by DGH. “To incentivise additional gas production from Administered Price Mechanism (APM) fields, reduction in royalty by 10 per cent of the applicable royalty will be granted on the additional production over and above Business As Usual (BAU) scenario. BAU scenario will be approved by DGH on third-party evaluation,” it said. Existing contracts already having marketing and pricing freedom would continue on the existing terms.