Showing posts with label _Canada. Show all posts
Showing posts with label _Canada. Show all posts

Canada's Northwest territories propose new hydraulic fracturing filing regulations for on shore wells

The Northwest Territories (NWT) in Canada's north have released for public comment proposed Hydraulic Fracturing Filing Regulations under the NWT's Oil and Gas Operations Act. If brought into force, the proposed Regulations will require an operator who wants to hydraulically fracture a well to submit to the Ministry of Industry, Tourism and Investment, among other things:
  • a Risk Assessment which identifies the threats and hazards from the proposed hydraulic fracturing operation to safety and the environment and the mitigative measures to manage those threats and hazards;
  • an Environmental Protection Plan prepared in accordance with the Environmental Protection Plan Guidelines and which demonstrates, among other things, that "green completion techniques" will be used to ensure that 90% of the flow back gas and oil vapour is recovered and that 95% of any gas or oil vapour not recovered is incinerated; 
  • surface and ground water information;
  • a description of how suspected seismic events will be monitored and reported; and 
  • a list of the chemicals in the hydraulic fracture fluid and their concentration.
An applicant also must indicate to the Ministry if they are willing to publically disclose certain information in their application, including the chemicals to be used. If they are not willing, they have to explain the reasons for that decision. At this point, it is unclear if the Ministry will agree that the chemical composition of fracturing fluids must not be publicly disclosed if it is confidential business information.


This post was written by Alan Harvie (alan.harvie@nortonrosefulbright.com or +1 403.267.9411) from Norton Rose Fulbright's energy practice group.

Canada's Yukon government paves the way for hydraulic fracturing

The Yukon government has accepted all 21 recommendations made by a Select Committee of the Legislative Assembly Regarding the Rights and Benefits of Hydraulic Fracturing. The Select Committee held public hearings and accepted submissions to help the Yukon Government develop a policy approach to hydraulic fracturing in the Yukon.

The Select Committee's recommendations largely addressed the need to gather more information about fracking and its impact in the Yukon. For instance, it recommended that research be conducted regarding fluid and gas leakage from hydraulic fracturing operations specific to the unique permafrost conditions in the Yukon. It also recommended more baseline data on seismic activity be collected given that parts of the Yukon are seismically active.

The Yukon Government has announced that it is open to shale gas development opportunities in the Yukon but only in the Liard Basin at this time and only if such development has the support of affected First Nations. The Laird Basin borders British Columbia and the B.C. side of the play is considered a world class shale gas deposit containing 176 trillion cubic meters of natural gas.

The Laird Basin is only about 1.3% of the Yukon's land mass, and for now hydraulic fracturing is not being considered in the Peel or Beaufort-Mackenzie Basins, both of which are thought to have high potential for shale oil and gas reserves.


This post was written by Alan Harvie (alan.harvie@nortonrosefulbright.com or +1 403.267.9411) from Norton Rose Fulbright's energy practice group.

New Brunswick announces commission to study hydraulic fracturing

The Canadian province of New Brunswick has appointed a three person Commission to study if the moratorium on hydraulic fracturing should be lifted. In December 2014 the provincial government introduced amendments to the Oil and Gas Act that placed a moratorium on all types of hydraulic fracturing in New Brunswick following wide-spread public protests. The moratorium will not be lifted unless:
  • a social license is in place;
  • there is clear and credible information about the impacts of hydraulic fracturing on public health, the environment and water, allowing the government to develop a country-leading regulatory regime with sufficient enforcement capabilities;
  • a plan is in place that mitigates the impacts on public infrastructure and that addresses issues such as waste water disposal;
  • a process is in place to respect the duty of the provincial government to consult with First Nations; and
  • a mechanism is in place to ensure that benefits are maximized for New Brunswickers, including the development of a proper royalty structure. 
The Commission, consisting of a former Chief Justice and two academics, is to report back to the provincial government with its key findings within one year.

New Brunswick is believed to have approximately 80 TCF of in place gas in the Frederick Brook formation.


This post was written by Alan Harvie (alan.harvie@nortonrosefulbright.com or +1 403.267.9411) from Norton Rose Fulbright's energy practice group.

Alberta Energy Regulator responds to earthquakes possibly linked to fracking

The Alberta Energy Regulator (AER) has issued new rules which create a "traffic light" process in response to earthquakes believed to have been caused by hydraulic fracturing. Subsurface Order No. 2 comes after several seismic events that may be related to hydraulic fracturing were recorded in the Duvernay play near Fox Creek in northwestern Alberta. A 3.8 magnitude earthquake measured on the Richter scale happened on January 214, 2015 and a 4.4 magnitude earthquake was recorded on January 22, 2014. Both were felt by residents of Fox Creek but there were no injuries or damage.

Some researchers believe that these and other recent shallow earthquakes in the area are consistent with being induced by hydraulic fracturing operations although it is impossible to definitely state that they were not naturally occurring earthquakes. The Fox Creek area historically has not had a lot of seismicity until hydraulic fracturing operations started in 2013. Since then, researches have recorded hundreds of very minor earthquakes and aftershocks at depths much shallower than where natural earthquakes typically occur. The Alberta Geological Survey, a part of the AER, regularly monitors seismic activity throughout Alberta through the 53-station Regional Alberta Observatory for Earthquake Studies Network (RAVEN).

Subsurface Order No. 2 requires that effective immediately that every well licensee of a well with a surface or bottom hole located in the Duvernay zone at which any completion operations are contemplated that include hydraulic fracturing must:
  • before beginning any completion operations that include hydraulic fracturing, assess the potential for induced seismicity and establish and implement a plan to monitor for, mitigate and respond to any induced seismicity that may occur or result from its completion operations; 
  • the monitoring must be capable of detecting a 2.0 local magnitude seismic event within 5 kilometres (3.1 miles) of the well; 
  • the licensee must immediately report to the AER all seismic events recorded of 2.0 or greater within 5 kilometres of the well and implement their induced seismicity plan in a manner that eliminates or reduces further seismic events;
  • if a 4.0 or greater seismic event is recorded within 5 km of the well, the licensee must immediately stop hydraulic fracturing operations at the well and return the well to a safe state; and
  • hydraulic fracturing of a well which have been suspended may only be recommenced with the AER's written consent. 


This post was written by Alan Harvie (alan.harvie@nortonrosefulbright.com or +1 403.267.9411) from Norton Rose Fulbright's energy practice group.

Alberta taking steps to protect groundwater from hydraulic fracturing operations

The Government of Alberta has released a Water Conservation Action Plan which includes short and long-term strategic actions to protect groundwater from the risks associated with hydraulic fracturing operations.

The Plan outlines 20 short-term and five long-term actions that are intended to help protect Alberta's groundwater during oil and gas development. With respect to hydraulic fracturing, Environment and Sustainable Resource Development (ESRD) in collaboration with Alberta Energy and the Alberta Energy Regulator (AER) will:
  • expand the water conservation and allocation policy presently in place for oilfield injection to include water conservation measures for hydraulic fracturing, with the new policy to be finalized in early 2015; and 
  • develop and implement science-based standards for baseline water well testing near hydraulic fracturing operations, with the new standards to be in place in early 2015. 
In the long-term, ESRD will develop a regional approach to regulating hydraulic fracturing by considering the surrounding geological conditions of each region, which conditions can vary considerably across the province.

ESRD held 30 community meetings and consulted broadly in 2013 on how Albertans want to enhance groundwater protection. The Action Plan is meant to address some of the concerns raised in the consultations.


This post was written by Alan Harvie (alan.harvie@nortonrosefulbright.com or +1 403.267.9411) from Norton Rose Fulbright's energy practice group.

Alberta extends with "play-based" regulation experiment

The Alberta Energy Regulator ("AER") has extended its pilot project for a "play-based" regulatory framework for unconventional oil and gas development in part of the Duvernay shale play in west-central Alberta.

The Duvernay shale play is a large, developing shale play covering much of western and northern Alberta and eastern British Columbia.  It is particularly rich in light oil and petroleum liquids such as propane and butane.  Hydraulic fracturing has been key in developing the vast underground rock formation that covers an area the size of South Korea.

The Duvernay play is still in its early stages with only about 200 wells drilled to date, with about 60 wells completed and on production.  The average initial production rate is about 2.5 mmcf per well per day.  The Kaybob area in the northwestern portion of the Duvernay is particularly liquids rich, with some wells having condensate yields of 200 - 480 barrels a day.

"Play-based" regulation involves implementing a single application and decision-making process for multiple wells, pipelines and facilities under different pieces of legislation.  It requires all of the operators in the pilot area to collaborate and jointly bring a single application for a single regulatory approval which will be used for regulating all of their  unconventional oil and gas activities in the pilot area. 

Presently, each activity by a company, such as building a road, diverting water, drilling a well, constructing a pipeline and so forth, requires its own separate AER regulatory approval.  This current approach makes it difficult to reduce the cumulative environmental impacts of the additional roads, well pads and pipelines required by each company in the area.  Extracting oil and gas out of shale requires many more wells, more pipelines and much more water usage than conventional oil and gas production.  Area landowners and communities are expected to benefit with play-based regulation as it is hoped that they will get a sense of the full scope of all development in the play area and have earlier input into how the play is developed on the surface.

Area operators have to submit the single application to the AER by January 31, 2015.  The pilot was scheduled to run until March 31, 2015 but has been extended until June 30, 2015 to allow oil and gas operators in the pilot area sufficient time to prepare the application and undertake the required stakeholder engagement.

The Duvernay shale play was chosen for the pilot as it is just starting to be developed and extensive drilling and production is expected over the next several years.

If playbased regulation is successful, the AER may implement it more broadly throughout Alberta in the future.

Review a copy of the AER's Play-Based Regulation Pilot Application Guide


This post was written by Alan Harvie (alan.harvie@nortonrosefulbright.com or +1 403.267.9411) from Norton Rose Fulbright's energy practice group.

Alberta Chief Justice keeps fracking lawsuit against environmental regulator alive

The Honourable Neil Wittman, Alberta's Chief Justice of the Court of Queen's Bench, has ruled that a landowner is entitled to carry on her lawsuit against Alberta's Environment and Sustainable Resource Development Department (ESRD) for allegedly being negligent in monitoring and regulating EnCana Corporation (EnCana) in the hydraulic fracturing of a well, and negligent in investigating the alleged contamination of her water well.

The landowner, Jessica Ernst, originally sued EnCana, ESRD and the Energy Resources Conservation Board (ERCB) in 2007. Recently, the case against the ERCB was thrown out on the grounds that the ERCB did not owe her a private duty of care and that the legislation under which it operates provided statutory immunity.

Please review our previous blog posts on these decisions, including:
The most recent development is that ESRD applied to the Court to strike out parts of Ms. Ernst's pleadings to allegations of negligent administration of a regulatory regime and the relief sought, including damages on the grounds that they failed to disclose a reasonable cause of action. In the alternative, ESRD sought summary judgment dismissing the case against it on the basis that Ms. Ernst's claim has no merit.

The Chief Justice ruled against both motions.

With respect to the application to strike part of the pleadings, the Chief Justice noted that striking the parts of the pleadings requested by ESRD would have the effect of having the entire claim against ESRD struck. ESRD argued that the test for striking an entire claim is whether it is plain and obvious or beyond reasonable doubt that the claim cannot succeed. The Court, however, disagreed and applied a test of whether, assuming the facts pleaded were true, there is a reasonable prospect that the claim will succeed.

The Chief Justice then determined that prima facie there was a private duty of care owed by ESRD to Ms. Ernst as the allegations in the claim, assuming they are true, concern direct contact between ESRD officials and Ms. Ernst and assert that specific representations were made by ESRD to Ms. Ernst. The Chief Justice found that there were no public policy considerations which ought to negate or limit that private duty of care.

ESRD also argued that it had statutory immunity like had previously been found for the ERCB. However, the legislation under which ESRD operated was different than that of the ERCB, and that the provisions granting immunity only applied for acts and omissions of ESRD undertaken in good faith. As Ms. Ernst alleged that the ESRD had acted in bad faith, and as the Court presumed the facts alleged to be true for the purpose of the motion, the Court ruled ESRD did not have statutory immunity.

As for the summary judgment application, the Court applied the rule that a defendant is entitled to summary judgment when there is no merit to the claim against it. The Chief Justice noted that the onus was on ESRD to establish that there was no genuine issue requiring a trial, and that ESRD had failed to satisfy him that there was no merit in Ms. Ernst's claim.

Meanwhile, Ms. Ernst is trying to get the Supreme Court of Canada to hear her appeal of the decision allowing the ERCB to exit the lawsuit as an application for leave to the Supreme Court has been filed by Ms. Ernst.


This post was written by Alan Harvie (alan.harvie@nortonrosefulbright.com or +1 403.267.9411) from Norton Rose Fulbright's energy practice group.

Alberta Court confirms regulatory immunity

The Court of Appeal of Alberta has confirmed that the Energy Resources Conservation Board (now known as the Alberta Energy Regulator) is immune from a negligence lawsuit by a landowner claiming that hydraulic fracturing caused hazardous amounts of methane, ethane and chemicals to contaminate her water well.
 
The appellant, Jessica Ernst, owns land near Rosebud, Alberta. She sued EnCana Corporation for damage to her fresh water supply allegedly caused by EnCana's activities, notably construction, drilling, hydraulic fracturing and related activities in the region. The Energy Resources Conservation Board had regulatory jurisdiction over the activities of EnCana, and the appellant has sued it for what was summarized as "negligent administration of a regulatory regime" related to her claims against EnCana. The appellant also sued the Province of Alberta, alleging that it (through its department Alberta Environment and Sustainable Resource Development) owed her a duty to protect her water supply, and that it failed to respond adequately to her complaints about EnCana's activities. 
 
In addition, Ms. Ernst alleged in her claim that she participated in many of the regulatory proceedings before the Board, and that she was a "vocal and effective critic" of the Board. She alleged that between November 24, 2005 to March 20, 2007 the Board's Compliance Branch refused to accept further communications from her. For this she has advanced a claim for damages for breach of her right to free expression under the Canadian Charter of Rights and Freedoms.
 
The Board applied to strike out certain portions of Ms. Ernst's pleadings for failing to disclose a reasonable cause of action. The case management judge found that the proposed negligence claim against the Board was unsupportable at law. He applied the three-part analysis relating to foreseeablity, proximity and policy considerations. He found no private law duty of care was owed to Ms. Ernst by the Board.
 
In the alternative, the case management judge found that any claim against the Board was barred by s. 43 of the Energy Resources Conservation Act:
 
  • 43 No action or proceeding may be brought against the Board or a member of the Board… in respect of any act or thing done purportedly in pursuance of this Act, or any Act that the Board administers, the regulations under any of those Acts or a decision order or direction of the Board.
The Alberta Court of Appeal agreed with the lower court and dismissed Ms. Ernst's argument that the Board failed to respond "reasonably" to EnCana's activities and held that a tortuous claim alleging an omission to act was barred by section 43 of the Act. The Court of Appeal also held that section 43 barred Ms. Ernst's Charter claim for a "personal remedy". The Court of Appeal concluded that even if the Board effectively breached Ms. Ernst's freedom of expression, that "protecting administrative tribunals and their members from liability for damages is constitutionally legitimate."
 
Ms. Ernst has said in the media she will appeal this latest decision against her to the Supreme Court of Canada.
 

Environmental groups lose court challenge over fracking water use

The British Columbia Supreme Court has dismissed a legal challenge to decisions of the B.C. Oil and Gas Commission (OGC) to grant successive, short-term approvals to EnCana Corporation to withdraw fresh water from B.C.'s lakes, rivers and streams for use in hydraulic fracturing operations. Under B.C.'s Water Act, all surface water is owned by the government and diversions are only allowed pursuant to a two year approval or a long-term license. A two year approval application is subject to less regulatory scrutiny than a long-term license application, and does not require the same public notice requirements.

The OGC granted various two year approvals to EnCana. The Western Canada Wilderness Committee and the Sierra Club filed a petition in the Supreme Court seeking to vacate the OGC's decisions to issue successive, two year approvals for water withdrawals from the same source. The petitioners claimed that although no one approval was for more than two years, multiple approvals were granted back to back over multiple years to EnCana for the same purpose and for diversions at the same locations, thereby effectively violating the two year term limit. The petitioners said that the OGC should have required EnCana to apply for long-term licenses instead of successive two year approvals.
 
The Court found that the Water Act did not prohibit the OGC's practice and deference should be given to the OGC in how it manages the issuance of approvals and licenses. The Court dismissed the claim.


This post was written by Barclay Nicholson (barclay.nicholson@nortonrosefulbright.com or 713 651 3662) and Alan Harvie (alan.harvie@nortonrosefulbright.com or +1 403.267.9411)from Norton Rose Fulbright's Energy Practice Group.

Web seminar: Legal lessons learned in shale plays in North America

With North America leading the way in shale oil and gas production, interest is mounting globally in the unconventional hydrocarbon sector. On Wednesday, September 17th , we will host a web seminar on Legal lessons learned in shale plays in North America, which will look at the key legal issues that have arisen in North America related to shale development, the lessons learned, and the implications for countries where shale development is still in the early stages.

This web seminar will be broadcast in two separate sessions for Asia/Australia audiences (session 1) and Europe/South Africa audiences (session 2) respectively. If you are unable to register for a session, a recording of the web seminar which will be made available after the event.

Session 1: Wednesday, September 17
  • 9:00 am – 10:15 am Hong Kong, Singapore 
  • 11:00 am – 12:15 pm Sydney, Melbourne 
To learn more about the seminar and register please access the following link: Legal lessons learned in shale plays in North America – Session 1

Session 2: Wednesday, September 17, 2014
  • 6:00 am – 7:15 am Los Angeles 
  • 7:00 am – 8:15 am Calgary 
  • 8:00 am – 9:15 am Houston 
  • 9:00 am – 10:15 am New York 
  • 2:00 pm – 3:15 pm London 
  • 3:00 pm – 4:15 pm Cape Town 
To learn more about the seminar and register please access the following link: Legal lessons learned in shale plays in North America - Session 2

Report cites “multitude of factors” for Lac-Megantic train derailment

The Transportation Safety Board of Canada (“TSB”) released an investigation report on August 19 on the Lac-Megantic, Quebec train derailment that resulted in fires and explosions, destroyed much of the town and left 47 people dead. Citing 18 factors that contributed to the incident, TSB is now calling for additional safety measures to prevent runaway trains and more thorough audits of rail companies’ safety management systems.

The report cited Montreal, Maine & Atlantic Railway (“MMA”), the company operating the runaway the Lac-Megantic train, for having a weak safety culture without built-in systems to manage risks. In addition, the report found poor training, employee monitoring, and maintenance practices at MMA; issues with industry guidelines for securing unattended trains; and problems with tank cars used to carry crude oil. Investigators also learned that Canadian transportation authorities did not audit MMA often or thoroughly to address MMA’s safety gaps.

In response to the accident and the report, the Canadian government is passing new safety standards for tank cars carrying crude oil, requiring those that do not meet the new standards to be phased out by 2017. The report provided additional recommendations for the government to ensure that unattended trains are always secured, especially when passing through heavily populated areas.


This post was written by Barclay Nicholson (barclay.nicholson@nortonrosefulbright.com or 713.651.3662) from Norton Rose Fulbright's Energy Practice Group and Kathleen McNearney (katie.mcnearney@nortonrosefulbright.com or 713.651.5698).

Canada’s TSB determines crude oil in train derailment to be unaffected by fracturing fluid additives

On July 6, 2013, shortly before 1:00 am, a Montreal, Maine & Atlantic Railway freight train which was parked for the night on a hill seven miles above Lac Megantic, Quebec started to roll. The unit train carrying approximately 48,000 barrels of crude oil produced from the Bakken oil fields in North Dakota in 78 DOT Class III tank cars reached a speed of 65 mph and 63 of the tank cars derailed in the centre of the Town, spilling approximately 37,000 barrels of crude oil and causing fires and explosions which destroyed 40 buildings, 53 vehicles and killed 47 people, many of whom were relaxing in bars and restaurants in Lac Megantic's scenic downtown on a warm summer evening.

On August 19, 2014, the Transportation Safety Board of Canada (TSB) released its 181 page report of its investigation of the tragedy. The TSB, like the National Transportation Safety Board in the united States, investigates transportation safety. It is not a function of the TSB to assign fault or determine civil or criminal liability.

The TSB found that the accident in Lac Megantic was due to 18 human and mechanical causes, including improper application of the brakes on the parked train, ineffective training and oversight by the rail company and poor regulatory oversight by Transport Canada. In its investigation, the TSB considered the volatility and flammability of the crude oil cargo, including how it was characterized, documented and handled for the purpose of transportation of dangerous goods laws.

Some public commentary after the disaster suggested that as some Bakken crude oil was produced through the hydraulic fracturing of wells, that hydraulic fracturing fluids in the crude oil in the tank cars contributed to the scope of the disaster.

The TSB considered this possibility but dismissed it. The TSB said after examining the properties of the crude oil that: "There was no indication that the crude oil's properties had been affected by contamination from fracturing process fluid additives."

Review a copy of the TSB's report.


This post was written by Alan Harvie (alan.harvie@nortonrosefulbright.com or +1 403.267.9411) from Norton Rose Fulbright's Canadian Energy Practice Group.

Federal regulators propose new rules on oil trains

After a series of accidents involving oil trains in the US and Canada, the US Department of Transportation proposed new safety standards for oil trains on July 23. The proposed standards target older tank cars, requiring companies shipping flammable liquids to replace tank cars prone to rupturing or retrofit them to meet tougher design requirements. New design requirements include thicker steel shells, better brakes and rollover protection, which would make the tank cars safer in the event of an accident.

According to the Department of Transportation, the transportation of oil by rail has increased significantly in the past several years, from 9,500 railcarloads in 2008 to 415,000 in 2013. After the July 6, 2013 derailment in Lac-Megantic, Quebec, which killed dozens of people, concerns grew about the increase in oil transportation by rail. The US proposal is similar to the standards Canadian regulators implemented after the Lac-Megantic accident.

The proposed standards would also impose speed limits of 40 mph on trains with cars that do not meet the new design standards. Newer cars would have 50 mph speed limits. In addition, the proposal includes requirements for carriers to evaluate 27 safety and security issues before selecting a transportation route and to document that liquids have been sampled and tested. The public has 60 days to comment on the proposed standards, and the new rules could go into effect by the fall of 2015.

Read more about the proposal


This post was written by Barclay Nicholson (barclay.nicholson@nortonrosefulbright.com or 713.651.3662) from Norton Rose Fulbright's Energy Practice Group and Kathleen McNearney (katie.mcnearney@nortonrosefulbright.com or 713.651.5698).

Alberta experiments with "play-based" regulation

The Alberta Energy Regulator ("AER") will pilot a "play-based" regulatory framework for unconventional oil and gas development in part of the Duvernay shale play in west-central Alberta this fall.

The Duvernay shale play is a large, developing shale play covering much of western and northern Alberta and eastern British Columbia. It is particularly rich in light oil and petroleum liquids such as propane and butane. Hydraulic fracturing has been key in developing the vast underground rock formation that covers an area the size of South Korea.

"Play-based" regulation involves implementing a single application and decision-making process for multiple wells, pipelines and facilities under different pieces of legislation. It will require all of the operators in the pilot area to collaborate and jointly bring a single application for a single regulatory approval which will be used for regulating all of their unconventional oil and gas activities in the pilot area.

Presently, each activity by a company, such as building a road, diverting water, drilling a well, constructing a pipeline and so forth, requires its own separate AER regulatory approval. This current approach makes it difficult to reduce the cumulative environmental impacts of the additional roads, well pads and pipelines required by each company in the area. Extracting oil and gas out of shale requires many more wells, more pipelines and much more water usage than conventional oil and gas production. Area landowners and communities are expected to benefit with play-based regulation as it is hoped that they will get a sense of the full scope of all development in the play area and have earlier input into how the play is developed on the surface.

Area operators will have to submit the single application to the AER by January 31, 2015. The pilot is scheduled to run until March 31, 2015.

The Duvernay shale play was chosen for the pilot as it is just starting to be developed and extensive drilling and production is expected over the next several years.

The AER intends to implement play-based regulation more broadly throughout Alberta in the future.

Review a copy of the AER's Play-Based Regulation Pilot Application Guide.


This post was written by Alan Harvie (alan.harvie@nortonrosefulbright.com or +1 403.267.9411) from Norton Rose Fulbright's Canadian Energy Practice Group.

Three railroad employees charged with criminal negligence in Quebec train derailment

The prosecutor’s office for the province of Quebec filed criminal negligence charges relating to the July 6, 2013 derailment of an unattended 72-car freight train in the town of Lac-Mégantic. The derailment caused tank cars carrying Bakken crude oil to rupture, explode, and burst into flame, resulting in the deaths of forty-seven people and environmental contamination.

On May 13, 2014, the bankrupt Montreal Maine and Atlantic Railroad, Ltd. (MMAR) and three of its employees (the train engineer, the railway traffic controller, and the train operations manager) were each charged with 47 counts of criminal negligence. In Canada, criminal negligence that results in death is punishable by up to life in prison.

Wrongful death lawsuits for the victims have been filed in US and Canadian courts, with the US lawsuits in the US District Court for Maine to proceed alongside MMAR’s bankruptcy case.

Questioning the safety of tanker cars and the flammability of Bakken oil, US and Canadian authorities have issued safety alerts, emergency orders, and protective directions relating to the testing and classification of crude oil transported by rail, notification to state emergency officials of the movements of trains carrying crude oil within each state, and the phase-out of the least crash-resistant DOT-111 tank cars from transporting oil.


This post was written by Barclay Nicholson (barclay.nicholson@nortonrosefulbright.com or 713.651.3662) from Norton Rose Fulbright's Energy Practice Group.

Canadian Council of Academies releases major research paper of the environmental impacts of shale gas development in Canada

A multi-disciplinary panel of experts assembled by the Canadian Council of Academies has released a major study on the environmental impacts of shale gas development in Canada. The Council is an independent research organization of the Royal Society of Canada, the Canadian Academy of Engineering and the Canadian Academy of Health Sciences. The Council is funded by the Canadian federal government.

The Study was commissioned in 2012 by the federal Environment Minister to provide an evidence-based and authoritative assessment of the following question:

What is the state of knowledge of potential environmental impacts from the exploration, extraction and development of Canada's shale gas resources, and what is the state of knowledge of associated mitigation options?

Further to this question, the Council was also asked:
  • Based on existing research, what new or more significant environmental impacts may result from shale gas extraction relative to conventional gas extraction?
  • What are the science and technology gaps in our understanding of these impacts and possible mitigation measures/strategies, and what research is needed to fill these gaps?
  • What monitoring approaches could inform the effective understanding and mitigation of impacts, what is the current state of the art and state of practice for such monitoring, and what science and technology gaps may act as barriers to effective monitoring?
  • What technical practices exist to mitigate these impacts, and what are international best practices? What science underpins current policy or regulatory practices internationally? 
The Study does not make recommendations, but rather presents observations and conclusions on what is known and not known about the environmental impacts of shale gas development, the options to mitigate them and opportunities for research to fill gaps in monitoring and understanding.

The Study focused on:
  • water (groundwater and surface);
  • greenhouse gas emissions;
  • land impacts and seismic events;
  • human health; and
  • monitoring and research.
The Study calls for more research on the environmental impact of shale gas development in Canada. The Study concludes:
  • In nearly all instances, shale gas extraction has proceeded without important environmental baseline data being collected (e.g. nearby groundwater quality). This makes it difficult to identify and characterize environmental impacts that may be associated with (or incorrectly blamed on) this development.
  • There is a paucity of peer-reviewed articles in the scientific literature. The reasons include the fact that large-scale shale development is a young industry (some 20 years old in the United States and only half that in Canada), that the industry has kept some information proprietary (in part because technologies are evolving rapidly and are still being tested), and that U.S. federal legislation only indirectly regulates the chemical additives used in hydraulic fracturing and therefore industry has not had to monitor their impact.
  • A major environmental concern regarding shale gas development - regional groundwater contamination - hinges on the flow of fluids in low permeability but commonly fractured geological strata. However, because past scientific interest has largely focused on high permeability rocks (aquifers and petroleum reservoirs), fluid flow in low permeability rocks is poorly understood. Thus, the basic scientific knowledge needed to evaluate potential risks to groundwater on the regional scale is largely lacking.
  • In areas where peer-reviewed studies are available, they do not necessarily agree. For example, there is a substantial range of expert opinion on the extent of fugitive methane emissions from shale gas development.
  • Some of the possible environmental effects of shale gas development, such as the creation of sub-surface pathways between the shale horizons being fractured and fresh groundwater, gas seepage from abandoned wells, and cumulative effects on the land and communities, may take decades to become apparent. Similarly, monitoring information, and information on the effectiveness of mitigation measure, take time to acquire and assess. 
  • Much if not most of what can be said about the potential environmental impacts of shale gas development depends on assumptions made about the location, pace, and scale of development, all of which will be influenced by future natural gas prices, government policy, and technological improvements. None of these can be predicted with certainty.
Review a copy of the Study


This post was written by Alan Harvie (alan.harvie@nortonrosefulbright.com or +1 403.267.9411) from Norton Rose Fulbright's Canadian Energy Practice Group.

Canada’s Ministry of Transport orders phase out or retrofitting of DOT-111 tank cars

On April 23, 2014, in response to recommendations made after the Lac-Mégantic train derailment in July 2013, Canada’s Ministry of Transport issued Protective Direction No. 34 requiring the immediate phase out of the least crash-resistant DOT-111 tank cars from dangerous goods service. There are approximately 5,000 DOT-111 tank cars without continuous bottom reinforcement that must be immediately removed from transporting dangerous goods such as crude oil and ethanol.

As for any tank cars on the move on the date of the Direction, these cars must reach their final destination within 30 days and then be immediately removed from service. All tank car owners must ensure that each of their DOT-111 tank cars is “marked with the words ‘Do not load with dangerous goods in Canada/Ne pas charger de marchandises dangereuses au Canada’ or similar words.”

In January 2014, Transport Canada proposed a new standard for “DOT-111 tank cars, including thicker steel and additional top fitting and head shield protection.” Working with U.S. regulatory agencies and other stakeholders, the Ministry plans to formalize updated DOT-111 standards in the summer of 2014. With Protective Direction No. 34, any tank cars built before the proposed standard and used to transport dangerous goods must be now phased out or retrofitted within three years.

In addition to the Protective Direction, the Ministry issued an Emergency Directive and a Ministerial Order outlining further requirements.
  • Trains carrying one or more cars of crude oil or ethanol (“Key Train”) must not exceed 50 mph, which speed may be lowered for some locations after specific risk assessments for particular urban populations and sensitive assets such as water sources.
  • Within six months, all companies must complete a risk assessment to determine the level of risk associated with each route over which Key Trains are operated. The assessment must identify safety and security risks associated with each route, including the volume of goods moved, the class of track, the maintenance schedule for the track, the curvature of the track, environmentally sensitive areas along the route, population density, emergency response capability, and any areas of high consequence along the track. Alternative routes must be identified and compared.
It must be noted that, in Lynchburg, Virginia, on April 30, 2014, at least 13 tank cars of a 105-car tank car train derailed and caught fire, with flames shooting 100 feet into the air. Three of the cars fell into the James River. According to officials, the train was traveling at just 24 miles per hour at the time of the accident. This incident comes just one week after the out-going chairwoman of the National Transportation Safety Board warned that the rail industry was falling behind on its oil shipping safety measures.

For additional information on transporting crude oil by rail, click here, here, and here.


This post was written by Barclay Nicholson (barclay.nicholson@nortonrosefulbright.com or 713.651.3662) from Norton Rose Fulbright's Energy Practice Group.

Environment Canada reviews oil and gas industry reporting

Environment Canada is reviewing the National Pollutant Release Inventory (NPRI) reporting requirements for oil and gas activities in Canada, including the reporting of substances released during hydraulic fracturing.

The NRPI is a legislated, publically accessible inventory of pollutant releases to air, water and land. It captures data on over 300 substances of concern, including many substances declared as toxic under the Canadian Environmental Protection Act, 1999 (CEPA).

Under CEPA, the federal Minister of Environment issues a notice each year to require facilities to report information for the purpose of creating the inventory of data. The data is then made available for free to the public on the internet. The annual notice specifies the chemicals which need to be reported and sets minimum quantities for reporting. As such, the NPRI does not require reporting on all pollutants in Canada or require information from all facilities.

Although some sectors of the oil and gas industry currently report, such as the oil sands sector, many operators of oil and gas batteries, compressor stations and gas gathering systems are not required to report because their emissions are below the NPRI minimum reporting thresholds. Also, exemptions currently exist for oil and gas exploration and drilling, and the NPRI does not require the reporting of certain releases of substances under the ground, such as occurs during hydraulic fracturing or enhanced oil recovery.

Environment Canada has recently announced that it is undertaking a review of the NPRI reporting requirements for the oil and gas industry. The review will look at the perceived gaps within the NPRI data for the oil and gas industry and the factors contributing to those gaps. The review will include consideration of whether the current exemption which does not require the reporting of releases of substances underground during hydraulic fracturing, as well as the broader exemption from reporting releases from oil and gas exploration and drilling, should continue.

Environment Canada has promised to consult with industry and the public during the review. The review is anticipated to be completed in 2015.

Court finds Alberta Regulator has statutory immunity from hydraulic fracturing suit

Alberta's Court of Queen's Bench has ruled that the Energy Resources Conservation Board (ERCB) has statutory immunity to a claim by a landowner that it was negligent in protecting the landowner's water supply from hydraulic fracturing. The ERCB, or the Alberta Energy Regulator as it is now known, is responsible for regulating Alberta's oil and gas industry. 

Jessica Ernst, an activist well known in Canada for opposing hydraulic fracturing, alleged that between 2001 and 2006 oil and gas company undertook shallow drilling to extract coal bed methane and, in doing so, used hydraulic fracturing, which included the use of toxic chemicals resulting in contamination of a local aquifer and Ernst's water well. Ernst brought her suit against the ERCB, the Province of Alberta and the company.

The claim against the ERCB alleges that the ERCB was negligent in that it failed to respond to Ernst's concern about water contamination from the drilling, that it knew that the oil and gas company had drilled into and fractured the aquifer from which she withdrew her drinking water and that it failed to take reasonable steps to protect her water supply. The claim also alleged that, by its conduct, the ERCB breached the Canadian Charter of Rights and Freedoms by barring Ernst from communicating with the ERCB through the usual public channels, and thereafter ignored her for a period of time until she agreed to communicate with the ERCB directly only, and not publically through the media or through communications with other citizens.

The ERCB applied for Summary Judgment dismissing the case against it. 

The Court found that the ERCB did not owe Ernst a private duty of care in the circumstances of this case but did owe her a public duty derived from the Energy Resources Conservation Act (ERC Act). However, as section 43 of the ERC Act expressly provides that no proceedings may be brought against the ERCB in respect of any act or thing done by it under the ERC Act, the Court ordered the allegations of negligence against the ERCB in the Statement of Claim struck out.

Although the Court found Ernst's Charter claim as "novel" and "not necessarily doomed to failure", it felt that the ERC Act also provided immunity to the ERCB from personal claims for damages under the Charter. It felt that otherwise, aggrieved parties would come to the litigation process dressed in their Charter clothes whenever possible.


This post was written by Alan Harvie (alan.harvie@nortonrosefulbright.com or +1 403.267.9411) from Norton Rose Fulbright's Calgary Energy Practice Group.

U.S. Department of Transportation meets with oil and rail industry leaders to discuss transport safety issues

With the recent December 30, 2013 derailment of tanker cars carrying oil in Casselton, North Dakota, as well as other 2013 incidents  in western Minnesota, Baltimore, Alabama, and at three sites in Canada (Gainfield, Landis, and Lac-Mégantic, where 47 people were killed when  an unattended 72-car freight train derailed in the center of town), the U.S. Department of Transportation (DOT) met with representatives from the oil and railroad industries to discuss transport safety issues relating to crude oil. 

At the meeting on January 15, 2014, representatives from the American Petroleum Institute (API) and the Association of American Railroads (AAR) reportedly agreed to take steps to avoid derailments, to work on a speed reduction plan, and to re-route trains around high-risk areas. According to the AAR representative, 27 risk factors, including population density, volume of hazardous materials being transported, and traffic density,  are always considered when routing trains. The API representative stressed the importance of having strong rail cars to transport the crude oil. 

On September 6, 2013, in the Federal Register, the Pipeline and Hazardous Materials Safety Administration (PHMSA) published a proposed rule concerning “Hazardous Materials: Rail Petitions and Recommendations to Improve the Safety of Railroad Tank Car Transportation (RRR).This proposed rule would impose additional requirements  for DOT Specification 111 tank cars used to transport Packing Group (PG) I and II hazardous materials. PHMSA has indicated that the proposed rule relating to the construction of rail tanker cars will not be finalized until at least January 2015.

With the volume of produced oil rising faster than can be moved by pipeline, railroads are being used more and more to transport oil products to processing facilities – and with that increase, come increasing concerns about the safety of transporting crude oil by rail.

In early January,  PHMSA and the Federal Railroad Administration issued a safety alert “to notify the general public, emergency responders, and shippers and carriers that recent derailments and resulting fires indicate that the type of crude oil being transported from the Bakken region may be more flammable than traditional heavy crude oil.”  For additional information, see our prior blog entitled “Safety alert relating to flammability of North Dakota Bakken crude oil transported by rail.”


This post was written by Barclay Nicholson (barclay.nicholson@nortonrosefulbright.com or 713.651.3662) from Norton Rose Fulbright's Energy Practice Group.