New base 999 special 12 february 2017 energy news

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NewBase 12 February 2017 - Issue No. 999 Senior Editor Eng. Khaled Al Awadi

NewBase For discussion or further details on the news below you may contact us on +971504822502, Dubai, UAE

UAE:DNO reports 2016 interim results and announces 'stepped up drilling campaign' in Kurdistan and Oman..Source: DNO DNO, the Norwegian oil and gas operator, has announced a stepped up drilling campaign in the Kurdistan region of Iraq and the Sultanate of Oman on the back of 2016 operating profits and improved payments for exports from its flagship Tawke field in Kurdistan. The Company also released its annual reserves report which showed an increase in combined proven and probable reserves (2P) and contingent resources (2C) following the new oil discovery at the Peshkabir field in Kurdistan.

DNO reported interim 2016 operating profits of USD 6 million, reversing an operating loss of USD 174 million in 2015. Following two years of cost cutting and asset rationalization, the Company is restarting investments to replenish its oil and gas reserves and restore production across its portfolio.

Planned 2017 capital investments are estimated at USD 100 million, and include four new production wells at Tawke. Elsewhere in Kurdistan, the Company plans to drill a third well at Peshkabir and an appraisal/production well at the Benenan field in the Erbil license. In Oman, two wells will be brought back onstream at Block 8 offshore with plans to nearly double output at the West Bukha and Bukha fields.




The Company is considering three additional wells at Tawke to raise production above current levels of around 115,000 barrels of oil per day (bopd) contingent on regular and predictable export payments from the Kurdistan Regional Government.

During 2016, DNO received ten payments totaling USD 210 million net to the Company for Tawke exports and outstanding receivables. Three additional payments totaling USD 59 million net to DNO have been received to date in the first quarter. 'These payments create momentum as we move into 2017,' said DNO's Executive Chairman Bijan Mossavar-Rahmani.

Early production from Peshkabir and transport of oil to the Company's gathering, processing and export facilities at Fish Khabur 12 kms away is under assessment.

"The Peshkabir field positions us for production and reserves growth in our Kurdistan portfolio," said Mr. Mossavar-Rahmani, indicating that the Cretaceous discovery added 47.9 million barrels of oil equivalent (MMboe) of gross 2C resources.

As of 31 December 2016, DNO's Company Working Interest (CWI) 2P reserves and 2C resources were estimated at 529.6 MMboe, up from 523.1 MMboe at year-end 2015. CWI 2P reserves were estimated at 368.3 MMboe, down from 391.5 MMboe at year-end 2015 after adjusting for CWI production of 25.3 MMboe during the year and a positive technical revision of 2.1 MMboe. CWI 2C resources were estimated at 161.3 MMboe, up from 131.6 MMboe at year-end 2015.

At Tawke, 2P reserves and 2C resources stood at 604.0 million barrels (MMbbls) at year-end 2016, down from 643.2 MMbbls at year-end 2015. Gross proven (1P) reserves stood at 347.7 MMbbls, down from 387.0 MMbbls at year-end 2015. Gross 2P reserves stood at 503.8 MMbbls, down from 543.0 MMbbls at year-end 2015. The reduction in each category reflected total production of 39.3 MMbbls from the field during the year. International petroleum consultants DeGolyer and MacNaughton carried out the annual independent assessment of the Tawke field. DNO internally evaluated the remaining assets.




UAE Masdar's wind farm JV starts UK power supply ABU DHABi Trade Arabis

Dudgeon Offshore Wind Farm, a joint venture company of UAE's leading renewable energy group Masdar, said the first turbine at its 402MW wind farm off the Norfolk coast has begun supplying electricity to the UK grid. Masdar and Norwegian multinational oil and gas company Statoil each own a 35 per cent share in the venture along with Statkraft, Norway’s state-owned electricity company, which has the rest of the stake.

Located 32 km off the coast of North Norfolk in North Sea, England, the Dudgeon Offshore Wind

Farm is Masdar’s latest investment in the United Kingdom’s renewable energy sector. Some 67 foundations, plus cables and the ofshore substatoin, on the wind park were installed last year and the first full wind turbine was installed in early January, said the cmpaany in a staatement. The 6MW Siemens machine has begun delivering power, stated the project developer Statoil. When fully operational this year, the 67-turbine offshore wind farm will provide electricity to over 400,000 homes, said Masdar. This project will bring the UAE renewable energy firm’s gross installed cumulative capacity in the UK renewable energy sector to more than 1,000 MW.-




Oman: Oxy welcomes OOCEP’s 45 per cent interest in Block 9 Oman Observer - Conrad Prabhu

US-based international oil and gas producer Occidental Petroleum Corporation (Oxy) says it is optimistic about growth prospects across its substantial operations in the Sultanate, most notably in Block 9 where state-owned Oman Oil Company Exploration & Production (OOCEP) recently acquired a 45 per cent participating interest.

Block 9, also known as the Suneinah block in north Oman, is a key source of hydrocarbons where output from the Safah and Wadi Latham fields averaged around 100,000 barrels of oil equivalent per day (boepd) in 2015.

Under a revised Exploration & Production Sharing Agreement (EPSA) signed in Muscat last month, OOCEP — the upstream energy arm of wholly government owned investment vehicle Oman Oil Company — acquired a 45 per cent participating interest in the Oxy-operated block.

Oman’s Oil & Gas Minister Dr Mohammed bin Hamad al Rumhy, inked the agreement on behalf of the government, while OOCEP was represented by Eng Isam al Zadjaly, CEO of Oman Oil Company. Mitsui E&P is also a partner in the block.

In remarks to analysts over the weekend, Ken Dillon, President of International Operations at Occidental Petroleum Corporation, described the new Block 9 contract as promising. “That’s a 15-year contract where we see substantial growth opportunities, both in oil and gas and in exploration. We think there are other opportunities in Oman that are a good fit long-term for us. So overall very positive,” he said.

Over the 30 years of its operations in the Sultanate, Oxy Oman has emerged as the largest independent oil producer with a black oil contribution averaging 233,000 barrels per day in 2015. More than half this volume came from Oxy’s Mukhaizna in Block 53, home to one of the world’s largest steamflood projects. The company also operates Blocks 27 and 62 in north Oman.

Earlier, in the same conference call to discuss the group’s 2016 Q4 earnings, top Oxy officials also underlined the growing importance of the Houston-based international company’s Oman operations.

Vicki Hollub, President and CEO — Occidental Petroleum Corporation, said: “We have lots of opportunities (…) especially in Oman, where we just recently obtained some seismic over Block 9, so we are doing infill drilling that’s very successful. We’ve got Block 62 gas development. We also see opportunities above and below our current steam flood interval in Mukhaizna, and so we have a lot of potential there…”

In particular, rising output from Oxy’s Block 62 has continued to buoy the group’s worldwide operational performance. Two new gas fields — Fushaigah and Maradi Huraymah — have been brought online in Block 62, also known as Habiba Block. A gas plant was also successfully brought on stream at Maradi Huraymah.

While Oxy’s Permian Basin in the United States is the group’s main growth engine, its international operations, most notably in Oman, will contribute to its free cash flow swing in 2017. The Block 9 contract re-signed last month will account for two-thirds of an estimated $400 million in additional free cash flow coming from the Group’s international operations, Occidental Petroleum Corporation’s Vicki Hollub noted




Oman : DNO to revive two wells in Block 8 offshore © Oman Daily Observer 2017

Muscat - DNO, the Norwegian oil and gas firm that operates Oman’s only producing offshore fields, has announced a “stepped up drilling campaign” targeting its Block 8 concession in the far north of the Sultanate. Announcing its interim 2016 results over the weekend, the Oslo-based operator said it plans to bring two wells into production in its Bukha and West Bukha assets within the Block 8 licence off

Musandam Governorate.

“During the first quarter of 2017, DNO initiated a 100 per cent sole risk re-drill of the West Bukha-5 well and was planning the reinstatement of the Bukha-1 well,” the company said. Funding for both initiatives will be part of an estimated $100 million capital investment pledged by DNO during 2017 across its portfolio of operations encompassing not only Oman, but also its production and exploration assets in Kurdistan, Tunisia, Somaliland and the United Arab Emirates. The company’s total operational spend is projected at $185 million this year. The new investments planned in Block 8 are expected to bolster output from the Bukha and West Bukha fields, which have been on a downtrend in recent years. Gross production from the fields totalled 5,325 barrels of oil equivalent per day (boepd) in 2016, with output split equally between oil and gas. This compares with an output of 8,193 boepd in 2015, down from 15,678 boepd a year earlier. Produced volumes from Block 8 totalled 1.9 MMboe (5,325 boepd) in 2016, with cumulative field production through end-2016 of 87.9 MMboe, the company said.

Gross 2P reserves (the sum of proved and probable reserves) in the Block are currently estimated at 4.1 million barrels of oil equivalent (MMboe), of which 2.6 MMbbls comprise oil, condensate and other liquids and 1.5 MMboe (equivalent to 8.9 billion cubic feet) is gas.




Over the past two years, DNO has seen its once considerable portfolio of exploration assets in the Sultanate whittle down from four in 2014 to just one presently, viz Block 8. Previous licenses Block 30 and 31 were relinquished in 2015 as part of the company’s “consolidation and rationalization” strategy. Also under relinquishment is Block 36 in the southwest of the Sultanate. Hayah-1, an exploratory well drilled on the block early in 2016, reached a total depth of 3,010 metres but failed to “encounter hydrocarbons other than minor gas shows”, the company said. “The well has been plugged and abandoned and the licence is under relinquishment,” DNO stated. Importantly, hydrocarbons from DNO’s Block 8 license are of strategic significance for the Sultanate because the associated gas and liquids in particular are channeled to the Musandam Gas Plant, currently in operation at Tibat in Musandam Governorate. Wholly owned by Oman Oil Company Exploration & Production (OOCEP), a subsidiary of Oman Oil Company, the facility has earmarked part of the gas output for the governorate’s first Independent Power Project (IPP), which has been developed jointly by Oman Oil Company and LG International. The plant is expected to come into operation shortly.




Saudi Aramco, Rowan joint venture impact the Middle Eastern offshore rig market? The joint venture between Saudi Aramco and Rowan is very significant, and will

undoubtedly have implications in all of the Middle East.

By David Carter Shinn

The Middle East is one of the most important offshore drilling rig markets in the world. For jackups, it’s the center of the universe: out of a total of around 530 jackup rigs, 174 are in this region. Shallow waters, cheap development costs, and a lot of oil make the Middle East key for any owner of benign environment jackup rigs.

Saudi Arabia plays an integral role in this vast offshore oil and gas empire. With 43 jackups currently on contract, Saudi Aramco is the largest jackup operator in the Middle East – and in the world.

So what happens when Saudi Aramco announces that they have entered into an exclusive joint venture agreement with Rowan for the ownership, management, and construction of rigs for Saudi Arabia?

The answer may seem simple: for Rowan it’s great; for the rest of the rig owners, it’s not. But it’s the uncertainty the deal creates which is the real issue at the moment.

Why did SA do it?

In December, Saudi Aramco announced that they had entered into “landmark” joint venture agreements with Nabors and Rowan “to create two new national champions focused on onshore and offshore drilling.” CEO Amin H. Nasser stated that “these initiatives represent an unprecedented new large scale model of collaboration, with substantial value creation for both

A Rowan jack-up rig (For illustration only)




Saudi Aramco and its partners through a closer working relationship. These investments are part of a wider program to leverage our core activities, to help enable the sustainable development of the Kingdom’s economy through diversification, and the development of an internationally competitive and dynamic local energy sector, supported by national champions.”

The joint venture with Rowan will initially own seven rigs (two from Aramco and five from Rowan). Four additional Rowan rigs will be managed by the joint venture, bringing the total to 11 rigs. There is also a plan to build 20 jackups in the Kingdom over the next ten years. Saudi Aramco (and Saudi Arabia) will, through the joint venture, have a center of competence within the offshore drilling sector which should provide a boost to the local economy and realize efficiencies in their supply chain.

Why did Rowan do it?

Why wouldn’t they? Although Rowan might not have cornered the entire Middle Eastern jackup market, they secured a long term commitment for a meaningful number of rigs with a major national oil company. The deal strengthens Rowan’s position in the region and should be considered a significant opportunity and platform for growth.

What’s the outlook for everyone else?

The joint venture isn’t immediately closing off all of Saudi Arabia to everyone except for Rowan; instead, it’s appropriating a designated number of Rowan rigs to work there long term. The key here is the number: only 11 of the 43 rigs working for Saudi Aramco are part of the joint venture (as of today) – and these rigs would have likely stayed in the Saudi market anyway.

On the face of it, the joint venture may seem like a contained threat, but 43 out of the 105 jackups in the Middle East are working for Saudi Aramco. That’s over 40% of the market, and if it becomes less accessible to other contractors, it will have far reaching effects.

The problem for the other drilling contractors is that there

is risk that the joint venture will grow and more rigs will be pushed out of the Kingdom. In addition, and assuming the Saudi rig market only grows modestly, the prospect of 20 newbuild rigs being phased in over 10 years could contribute to a steady outpouring of rigs from Saudi into other Middle Eastern countries which already have an oversupply of jackups. In effect, the joint venture will make the largest jackup market in the world smaller for everyone else but Rowan.

While the deal will eventually be mostly negative for other drilling contractors, there are two factors that will determine just how negative it is: time to fully implement the joint venture and incremental demand increases in other Middle Eastern countries.

If demand in the Middle East does strengthen over the medium term, excess ex-Saudi rigs may be able to be absorbed and the effect of the joint venture could be less significant. For now, however, the joint venture presents an impending damper on demand which could – to a yet unknown extent – evolve into a material one.

The views and opinions expressed in this article are those of the author and do not necessarily reflect the official policy or position of Offshore Energy Today.




U.S. energy trade with Mexico: U.S. export value more than twice import value in 2016..: U.S. Energy Information Administration, based on U.S. Census Bureau Energy trade between Mexico and the United States has historically been driven by Mexico’s sales of crude oil to the United States and by U.S. net exports of refined petroleum products to Mexico.

Through 2014, Mexico’s exports of crude oil to the United States were the most valuable component of bilateral energy trade, with the overall value of Mexico’s U.S. crude oil sales far exceeding the value of U.S. net sales of petroleum products, primarily gasoline and diesel fuel, to Mexico. From 2006 through 2010, for example, the value of U.S. energy imports from Mexico were two to three times greater than the value of U.S. energy exports to Mexico.

The bilateral energy trade situation with Mexico has changed significantly in recent years. In 2015 and 2016, the value of U.S. energy exports to Mexico, including rapidly growing volumes of both petroleum products and natural gas, exceeded the value of U.S. energy imports from Mexico as volumes of Mexican crude oil sold in the United States continued to decline. For 2016, the value of U.S. energy exports to Mexico was $20.2 billion, while the value of U.S. energy imports from that country was $8.7 billion.

Import and export values each reflect commodity volumes and their prices. Monthly trends in volumes through 2016 showed increasing U.S. petroleum product and natural gas exports to Mexico, with a generally declining trend in U.S. crude oil imports from Mexico.

Mexico is second only to Canada in energy trade with the United States. Based on the latest annual data from the U.S. Census Bureau, energy accounted for about 9% of all U.S. exports to Mexico and 3% of all U.S. imports from Mexico in 2016.




Source: U.S. Energy Information Administration, based on U.S. Census Bureau

Crude oil makes up most of the energy imports from Mexico, averaging 688,000 barrels per day (b/d) in 2015 and 588,000 b/d in the first 11 months of 2016. In 2015, Mexico was the source of 9% of crude oil imported by the United States, providing the fourth-largest share behind Canada, Saudi Arabia, and Venezuela.

From 2006 through 2014, U.S. crude oil imports from Mexico were valued at an annual average of about $30 billion, but more recently, as both the volume of crude oil imports from Mexico and world oil prices declined, U.S. crude oil imports from Mexico were valued at $12.5 billion in 2015 and $7.6 billion in 2016.

Mexico’s total crude oil exports have been declining as its oil production falls. Because Mexico has been sending more oil to countries in Europe and Asia, crude oil exports to the United States have been declining more rapidly than overall crude oil exports.

Petroleum products account for most of the value of energy exports from the United States to Mexico. In 2015, Mexico was the destination for 690,000 b/d of petroleum products, or 16% of all petroleum products exported from the United States.

These exports were valued at more than $16 billion. In 2015, even though the United States exported more petroleum products to Mexico than in 2014, the value of those products was lower because of lower prices for fuels such as gasoline, distillate fuel oil, and liquefied petroleum gases.

In the first 11 months of 2016, petroleum product exports rose in both volume (averaging 849,000 b/d) and value relative to the first 11 months of 2015. Changes in Mexico’s utilization of petroleum refineries have created a widening gap between its domestic supply and demand, and U.S. gasoline exports now make up more than half of Mexico’s gasoline consumption.




Compared with petroleum product exports, 2016 petroleum product imports from Mexico to the United States were relatively small, accounting for about 87,000 b/d and valued at $0.9 billion through November.

Bilateral natural gas trade is dominated by pipeline shipments between the United States and Mexico. U.S. natural gas exports to Mexico totaled nearly 2.9 billion cubic feet per day (Bcf/d) in 2015, or almost 60% of all U.S. natural gas exports, and are growing rapidly. Based on data through November, U.S. natural gas exports to Mexico averaged 3.8 Bcf/d in 2016, and reports indicate that daily flows during early 2017 are already exceeding 4.2 Bcf/d.

In 2017 and 2018, natural gas pipelines currently under construction or in the planning stages are expected to nearly double the pipeline natural gas exporting capacity from the United States to Mexico. Much of this natural gas will likely be used to generate electricity, as Mexico’s energy ministry expects to add significant natural gas-fired electricity generating capacity through 2029.




NewBase 12 February 2017 Khaled Al Awadi

NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE

Oil Prices settle WTI-$53.86, Brent-$85.71, as OPEC deal compliance Reuters + NewBase Oil prices rose on Friday after reports that OPEC members delivered more than 90 percent of the output cuts they pledged in a landmark deal that took effect in January. Supply from the 11 members of the Organization of the Petroleum Exporting Countries with production targets under the deal fell to 29.92 million barrels per day, according to the average assessments of the six secondary sources OPEC uses to monitor output, or a 92 percent compliance. The International Energy Agency (IEA) - one of OPEC's six sources - said the cuts in January equated to 90 percent of the agreed reductions in output, far higher than the initial 60 percent compliance with a 2009 OPEC deal. "Some producers, notably Saudi Arabia, (are) appearing to cut by more than required," the agency said in a report. U.S. West Texas Intermediate (WTI) crude futures settled 86 cents, or 1.6 percent, at $53.86. Global benchmark Brent crude was up $1, or 1.8 percent, at $56.63 a barrel by 2:36 p.m. (1936 GMT), touching a session high of $56.39 shortly after the IEA report's publication.

Brent was on track for its first weekly drop in four weeks while U.S. crude eked out its fourth straight week of gains. Crude has benefited from recent strength in gasoline prices as a glut seems to be gradually eroding. Gasoline futures were trading up about 0.9 percent on Friday. Another increase in U.S. oil rigs held down gains in the afternoon. Drillers added eight oil rigs in the week to Feb. 10, bringing the total count up to 591, the most since October 2015, energy services firm Baker Hughes Inc said on Friday.

Oil price special

coverage




NewBase Special Coverage

News Agencies News Release 12 Feb. 2017

“Qatar petroleum” An Energy Giant Bigger Than Exxon in the Shadow of Saudi Aramco Bloomberg - Mohammed Sergie

Qatar Petroleum is the hidden giant of the global energy industry, overshadowed by its neighbor Saudi Aramco. Yet, the country’s colossal natural gas resources allow the state-run company to pump more oil and gas than Rosneft PJSC or Exxon Mobil Corp. After almost two decades of breakneck growth, the company needs to change tack. QP plans to expand abroad as domestic crude output declines and the government bars new drilling in the offshore North Field, home to the gas that made Qatar the world’s leading supplier of liquefied natural gas. QP will have no problem paying for overseas expansion. Qatar’s energy minister, Mohammed Al Sada, said this week that almost all the country’s domestic LNG terminals have been paid for. And despite a near-term glut, he said the commodity will be in short supply by 2021. What follows is a portrait of QP and its weight in world energy markets.




Natural Gas

Qatar’s energy story, as with its peers in the Persian Gulf, began with oil. The desert nation of 2.6 million residents started drilling wells in 1939 and exported its first oil 10 years later. In 1971, Royal Dutch Shell Plc discovered the offshore North Field, which, together with the connected South Pars deposit in Iran, is the world’s biggest reservoir of non-associated gas. The find was a disappointment at the time because it showed no crude. It took more than twenty years for Qatar Petroleum to partner with Exxon Mobil, Shell, Total SA and ConocoPhillips -- as well as with Japanese customers Mitsui & Co. and Marubeni Corp. -- to start building 14 plants that chill gas into a liquid for shipment to Asia and Europe. By 2006, Qatar was the biggest exporter of liquefied natural gas, and it shipped 78 million tons in 2015, or 32 percent of global supply that year, according to the International Group of Liquefied Natural Gas Importers. By more than doubling gas and oil production since 2006, Qatar has become the world’s fourth-biggest energy supplier and wealthiest country by per capita income. Qatar Petroleum has overtaken Rosneft and Exxon in total output, according to data compiled by Bloomberg, and the company makes and sells more LNG than any other. QP ranks behind Saudi Arabian Oil Co., Gazprom PJSC and National Iranian Oil Co. for energy production.

Qatar Petroleum, through its LNG-producing divisions Qatargas and RasGas and other investments in related businesses, holds stakes in the companies that extract, process, ship and receive gas. This integrated supply chain helps make Qatari LNG the cheapest in the world to produce, an advantage QP plans to exploit as competitors in Australia and the U.S. dethrone it as the top producer by volume.




Helium

Qatar doesn’t have a space program, but one molecule trapped in the North Field is used by NASA. Helium has given Qatar Petroleum more to brag about as the world’s biggest exporter. RasGas, QP’s joint venture with Exxon that will be merged with Qatargas this year, has two plants with capacity of 2 billion cubic feet per year, and it’s building a third facility. Oil

Aging oil fields and a dearth of large discoveries have weighed on QP’s crude output. Qatar pumped 615,000 barrels a day of crude in January, down from a peak of 880,000 in June 2008, data compiled by Bloomberg show. Condensate and other natural gas liquids surpassed Qatar’s oil production in 2010 and by 2015 had risen to almost double the amount of crude it was pumping, according to the data. These gains -- in addition to LNG, pipeline exports of gas to the United Arab Emirates and Oman, and gas-to-liquids fuels produced in partnership with Shell and Sasol Ltd. -- far exceeded the decline in crude output and have generated financial surpluses that make Qatar one of the world’s top global investors.

Electricity

Qatar Petroleum owns a minority stake in Nebras Power QSC, the international investment division of a local power company. Nebras, which backs wind, solar and potentially also coal projects, isn’t primarily focused on using Qatar-produced fuel to generate electricity. But its November agreement with Japan LNG buyer Jera Co. points to a strategy of building gas-fired power plants to help soak up the current glut of LNG and keep a price floor beneath QP’s main exports. Qatar Petroleum also has majority holdings in domestic refineries, petrochemicals and aluminum companies.




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Khaled Malallah Al Awadi, Energy Consultant MS & BS Mechanical Engineering (HON), USA Emarat member since 1990 ASME member since 1995 Hawk Energy member 2010

Mobile: +97150-4822502 [email protected] [email protected]

Khaled Al Awadi is a UAE National with a total of 25 years of experience in the Oil & Gas sector. Currently working as Technical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation for the GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were spent as the Gas Operations Manager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years, he has developed great experiences in the designing & constructing of gas pipelines, gas metering &

regulating stations and in the engineering of supply routes. Many years were spent drafting, & compiling gas transportation, operation & maintenance agreements along with many MOUs for the local authorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE and Energy program broadcasted internationally, via GCC leading satellite Channels.

NewBase : For discussion or further details on the news above you may contact us on +971504822502 , Dubai , UAE

NewBase February 2017 K. Al Awadi




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New base 999 special 12 february 2017 energy news