• 2 days U.S. On Track To Unseat Saudi Arabia As No.2 Oil Producer In the World
  • 2 days Senior Interior Dept. Official Says Florida Still On Trump’s Draft Drilling Plan
  • 2 days Schlumberger Optimistic In 2018 For Oilfield Services Businesses
  • 3 days Only 1/3 Of Oil Patch Jobs To Return To Canada After Downturn Ends
  • 3 days Statoil, YPF Finalize Joint Vaca Muerta Development Deal
  • 3 days TransCanada Boasts Long-Term Commitments For Keystone XL
  • 3 days Nigeria Files Suit Against JP Morgan Over Oil Field Sale
  • 3 days Chinese Oil Ships Found Violating UN Sanctions On North Korea
  • 3 days Oil Slick From Iranian Tanker Explosion Is Now The Size Of Paris
  • 3 days Nigeria Approves Petroleum Industry Bill After 17 Long Years
  • 4 days Venezuelan Output Drops To 28-Year Low In 2017
  • 4 days OPEC Revises Up Non-OPEC Production Estimates For 2018
  • 4 days Iraq Ready To Sign Deal With BP For Kirkuk Fields
  • 4 days Kinder Morgan Delays Trans Mountain Launch Again
  • 4 days Shell Inks Another Solar Deal
  • 5 days API Reports Seventh Large Crude Draw In Seven Weeks
  • 5 days Maduro’s Advisors Recommend Selling Petro At Steep 60% Discount
  • 5 days EIA: Shale Oil Output To Rise By 1.8 Million Bpd Through Q1 2019
  • 5 days IEA: Don’t Expect Much Oil From Arctic National Wildlife Refuge Before 2030
  • 5 days Minister Says Norway Must Prepare For Arctic Oil Race With Russia
  • 5 days Eight Years Late—UK Hinkley Point C To Be In Service By 2025
  • 5 days Sunk Iranian Oil Tanker Leave Behind Two Slicks
  • 5 days Saudi Arabia Shuns UBS, BofA As Aramco IPO Coordinators
  • 5 days WCS-WTI Spread Narrows As Exports-By-Rail Pick Up
  • 5 days Norway Grants Record 75 New Offshore Exploration Leases
  • 5 days China’s Growing Appetite For Renewables
  • 6 days Chevron To Resume Drilling In Kurdistan
  • 6 days India Boosts Oil, Gas Resource Estimate Ahead Of Bidding Round
  • 6 days India’s Reliance Boosts Export Refinery Capacity By 30%
  • 6 days Nigeria Among Worst Performers In Electricity Supply
  • 6 days ELN Attacks Another Colombian Pipeline As Ceasefire Ceases
  • 6 days Shell Buys 43.8% Stake In Silicon Ranch Solar
  • 6 days Saudis To Award Nuclear Power Contracts In December
  • 7 days Shell Approves Its First North Sea Oil Project In Six Years
  • 7 days China Unlikely To Maintain Record Oil Product Exports
  • 7 days Australia Solar Power Additions Hit Record In 2017
  • 7 days Morocco Prepares $4.6B Gas Project Tender
  • 7 days Iranian Oil Tanker Sinks After Second Explosion
  • 9 days Russia To Discuss Possible Exit From OPEC Deal
  • 9 days Iranian Oil Tanker Drifts Into Japanese Waters As Fires Rage On
Alt Text

A Rare High-Profile Utility Takeover

Dominion Energy, Virginia’s largest utility…

Alt Text

The Key To Profiting In 2018’s Energy Market

The rise of renewable sources…

Alt Text

The Labor Shortage In The Shale Boom

Shale drillers are set to…

Viktor Katona

Viktor Katona

Viktor Katona is an Group Physical Trader at MOL Group and Expert at the Russian International Affairs Council, currently based in Budapest.

More Info

The Beginning Of The End For Norwegian Oil

Norway

The demise of the North Sea doesn’t necessarily mean the end of Norway’s petroleum era—far from it. Still, despite significant reserves in the Barents Sea, Norway is about to embark upon a long period of structural decline as its benchmark fields inch closer to depletion and its reserves taper before our very eyes.

The average Norwegian might not even perceive the difference between an oil-rich Norway and one that is past its prime. The nation’s massive external and fiscal net position, as well as its complete energy independence thanks to hydropower, allows for great flexibility regarding future policies. Yet its oil workers must prepare for a future that is much more Arctic, smaller-scale and gas-based.

There’s ample evidence to conclude that all the sweet spots of Norway’s continental shelf have been found. The latest shelf licensing round (24) elicited a weak response, with only 11 companies applying for production licenses. There was plenty to bid for—102 blocks were up for grabs (never before did the Norwegian Petroleum Directorate offer so much, with an overwhelming majority of them in the Barents Sea), but due to their remoteness from formations deemed to be the most hydrocarbon-rich, bidders were only half as numerous as they were during the previous licensing round in 2015.

Other factors also contributed, including ongoing legal disputes whether drilling in the Arctic breaches Point 112 of Norway’s constitution (“natural resources should be managed based on long-term considerations, safeguarded for future generations”) and questions over the admissibility of drilling in Russia-disputed Svalbard waters (10 blocks) might have scared away an investor or two.

Graph 1. Norway’s Leading Oil Fields Production 1971-2016.

(Click to enlarge)

Source: Norwegian Petroleum Directorate.

Related: This OPEC Member Aims To Boost Oil Output By 40 percent

The vicissitudes of oil production have also soured Norway’s outlook for 2017. Its producers have underperformed this year (Jan-Oct data indicate an average of 1.605 mbpd against NPD’s forecast of 1.621 mbpd). This was largely due to Goliat’s travails, the first Norwegian field in the Barents Sea to be brought on-stream. Goliat was shut down for a month in September 2017 for maintenance works; however, October witnessed another unplanned layoff as Norwegian authorities ordered ENI (the operator) to halt activities in view of serious deficiencies in the platform’s electrical system. Plagued by false alarms and power outages, the platform’s future hung thick in the air as Norwegian authorities conducted a thorough analysis before production could be restarted once again, for the eighth time since it started producing in early 2016.

Graph 2. Norway’s Oil Production in 2011-2017.

(Click to enlarge)

Source: Norwegian Petroleum Directorate.

Taking into account the doubling of the Barents Sea reserves estimate, Norway’s continental shelf still holds up to 12.4 BBbl of undiscovered oil reserves. This means that two-thirds of Norway’s untapped oil is located in the Barents Sea, which is likely to become subject to much more meticulous public scrutiny.

Claims by Greenpeace and other campaigners that offshore Arctic drilling breaches the Norwegian constitution is a risky one for the State—almost 200 000 jobs are at stake if the court acknowledges even partially the legality of the environmentalists’ demands. All the more so now that pretty much all new promising oil projects are located in the northernmost Barents Sea.

After 2001, Norwegian oil output recorded 12 consecutive years of falling production. The current phase might best be described as a lull before the (presumably) last long-term production increase in its history, expected to happen in the early 2020s. Much will depend on the two “Johans” Norway will bring online in the early 2020s: Johan Sverdrup (recoverable reserves worth 2-3 BBbl) and Johan Castberg (0.5 BBbl).

Much has been done to render Johan Castberg profitable at current price levels—from an initial level of 80 USD/bbl, Statoil and the other shareholders have brought it to an alleged 35 USD/bbl. Against the background of falling oil services costs, this has entailed several cost-cutting measures, most notably scrapping any sort of semi-submersible vessel variant coupled with pipeline construction from the oilfield to the mainland (an option preferred by the government, as this would allow to provide smaller fields in the Barents Sea with a sure transport route) in favor of a FPSO. Related: Nuclear Power's Resurgence In The Middle East

It’s by no means an easy decision. The development of Johan Castberg—as of today the largest field in Norway’s Barents Sea zone—was given priority over smaller projects. Johan Sverdrup’s first-phase production will start in late 2019, with full nameplate capacity (660 000 barrels per day) expected to be reached by 2022. Coupled with Castberg’s 200,000 bpd peak output, the two fields alone will account for roughly half of Norway’s production by 2022.

Graph 3. Norway’s oil and gas production 1970-2021.

(Click to enlarge)

Source: Norwegian Petroleum Directorate.

Interestingly enough, gas’ peak production is yet to come in Norway (oil’s peak plateau was reached in 1999-2000). Since most oil fields on the Norwegian Continental Shelf are gas-bearing and recent years have seen steady inflows from new projects (Skirne, the major Snøhvit, Gjøa, Gina Krog and now Maria), gas output has been on a relatively stable plateau of 115 BCm per year. Approximately 40 percent of hydrocarbon reserves found in the Barents Sea are gaseous, therefore one might expect a gradual migration of development towards the Arctic, similar to what happened within the oil sector.

For oil itself, the next decade will represent the beginning of an end, which, albeit gradual, seems inevitable. As a consequence, Norway’s share of the global oil market will decline from the current two percent and drift closer to one percent in the 2020s.

By Viktor Katona for Oilprice.com

More Top Reads From Oilprice.com:




Back to homepage


Leave a comment
  • Vishwas on December 18 2017 said:
    Oil prices cannot sustain above $40 making it unviable for new blocks. Demand from India, China, Japan, USA for 2017 is almost flat and may decline for 2018. As against, Gulf countries and Venezuela will be forced to sell more to sustain its infra and imported military hardware. Russia, though insulated by oil-treaty with China, will be forced to sell more to Europe to sustain itself. Time has come to move from oil today.

Leave a comment




Oilprice - The No. 1 Source for Oil & Energy News