Publications

Potential Economic Impacts of Developing Quebec's Shale Gas
CERI Study No. 132
March 2013

The profound impact of shale gas cannot be understated, and the impact is truly global. With natural gas being the energy source of choice across various sectors, demand continues to increase. Declines in conventional gas production both in Canada and the US have brought attention to various unconventional natural gas resources, particularly shale gas. In Canada, production from Alberta and British Columbia’s shale and tight gas will likely play a large role in mitigating the effects of declining conventional production on total production. In the past five years, the Utica Shale in Québec has received attention from a number of companies seeking to extract natural gas between Montreal and Québec City. The provincial government in Québec has since placed a moratorium on oil and gas activity, halting development at least until the completion of a Strategic Environmental Assessment, expected in late 2013.

The economic impacts of two hypothetical scenarios are investigated in this study. In the first scenario, drilling takes place to build and maintain a production level of approximately 500 million cubic feet per day (MMCFPD) – Québec’s current consumption of natural gas. In the second scenario, drilling takes place to build and maintain a production level of approximately 1,500 MMCFPD, which would allow for 1,000 MMCFPD of export capacity on top of Québec’s own consumption needs. Each of the scenarios assumes that the moratorium on oil and gas activities is lifted, and makes the assumption that the cost of drilling reflects the cost of field development, rather than exploratory wells. Results for GDP, employment, tax and royalty revenue are calculated using an I/O model and are presented for each province across Canada.

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Global LNG: Now, Never, or Later?
January 2013

Low continental prices and an abundance of natural gas have generated interest both publically and privately to look into exporting liquefied natural gas (LNG). Of particular interest are the Asian markets where North American exporters hope to arbitrage high Asian prices against low continental prices. However, North American LNG exporters are not alone in trying to access the Asian gas premium. Australia has committed to considerable LNG export capacities and other gas producing countries are following suit. Concurrently, the abundance of continental gas supplies has increased domestic natural gas end-user demand within the utility, petrochemical, industrial and transportation sectors as well as sparked a debate on whether the United States should export large amounts of LNG. Thus, exporting LNG has significant challenges and North American exporters face considerable risks. With multiple pressures facing the North American LNG industry, many have been wondering if the window of opportunity for North American exports has vanished. This study summarizes current regasification and liquefaction capacities, explains LNG pricing, and reviews some of the risks for North American LNG exporters. The study concludes with addressing the question of whether there is room for North American LNG exporters in an Asian-Pacific market.

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To download a copy of the charts and tables, click here.

Natural Gas Liquids in North America: Overview and Outlook to 2035
July 2012

Natural gas liquids (NGLs), including ethane, propane, butanes, and pentanes plus are an important part of the North American energy industry. Their sources, including gas processing plants, crude oil refineries, and oil sands upgraders, are as diverse and complex as their final uses which include inputs for value-added petrochemicals, refineries and oil sands operations, as well as applications for fuel and heating across various sectors of the economy.

While is it well known and established that oil and gas production in North America is on the rise, a less explored and discussed matter is that of increasing NGLs volumes. Markets for NGLs are complex by nature and involve the dynamic interaction of various segments of the energy industry and the overall economy. Currently, market dynamics are changing across the continent as traditional markets regions have the potential to become supply sources and/ or self-sufficient, new sources of supply are being tapped, and the necessary infrastructure to accommodate these changes is in a constant state of flux. These changes are creating opportunities for both producers and end users of NGLs across the continent.

After more than ten years from CERI’s latest assessment of NGLs in North America, this is CERI’s comeback to the analysis of this complex and exciting segment of the industry. This report serves as a guideline to understand the natural gas liquids industry with a focus on Canada, as well as to provide an analysis and outlook to 2035 for NGL markets in North America

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Canadian Energy: Pacific Access

As the global oil demand rises, and as Canadian producers look to diversify their energy markets, alternative means to move bitumen to the west coast merit examination. Expansion of the existing Trans Mountain Pipeline and increased rail shipment are being proposed as ways to expand transportation – not only of bitumen but of other hydrocarbons such as LNG and intermediate petrochemicals – to British Columbia ports.

Whether the fluid is bitumen, synthetic crude oil (SCO), natural gas, diluents, refined petroleum products or petrochemical products, they all have one element in common: a constraint of accessing the demand markets outside of North America via Pacific coast in BC. To establish greater transportation access to the BC coast, various options must be weighed. This research project therefore considers not only the feasibility of the new pipelines, but the practicability of the alternatives, including:

Development of a new pipeline access to West Coast tidewater locations. This includes evaluation of Enbridge’s Northern Gateway pipelines, Kinder Morgan’s Trans Mountain expansion and extension, and indirectly TransCanada’s Keystone XL.
Rail transport of hydrocarbons to coastal terminals, including Prince Rupert, Kitimat, and Vancouver.
Expansion of the existing Trans Mountain pipeline to Vancouver.
Liquefaction in Alberta and shipment of LNG by rail to Prince Rupert, Kitimat, or Vancouver.
Increased shipment along existing corridors and liquefaction at Prince Rupert, Kitimat, or Vancouver.

Pacific Access: Part I - Linking Oil Sands Supply to New and Existing Markets
July 2012

As consumption of oil-derived products in North America is dwindling, the demand for crude oil and its products in Asia-Pacific countries is forecast to increase at a significant rate. If Canadian oil producers have access to this region, it is believed that they will be able to secure higher returns on their investments and minimize the risk that growth in Canadian oil production could be inhibited due to US opposition for new pipelines. The production from conventional oil sources in Canada and the US is growing as technology is able to unlock resources that were once thought to be difficult to extract. Nevertheless, oil sands will continue to dominate the future production growth in Canada. This report presents the economic impacts of current and future oil sands development, broken down into four separate cases, which represent the pipeline capacities of existing infrastructure, as well as capacities of pipelines that are not yet operating. The report shows significant economic benefits of oil sands development for Canadian and provincial economies.

This is the first of a series of six reports regarding Pacific Access.

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Pacific Access: Part II - Asia-Directed Oil Pathways and Their Economic Impacts
July 2012

Alternative transportation networks are emerging in the North American market to relieve constraints at Cushing and at rapidly developing shale oil plays. However, these options are more expensive than pipeline alternatives and serve markets that are shrinking. Moreover, these markets have ready access to alternative supplies from either imported or shale oil crudes. As such, it has become increasingly important to find alternative markets for oil sand’s bitumen. A pipeline to tidewater on the Pacific Coast is the most economical way of reaching Asian refineries which are capable of accepting both bitumen and synthetic crude oil (SCO). Part II of CERI’s Pacific Access report examines the available alternative transportation modes in North America and the impacts of accessing the Pacific markets. CERI’s Regional Input-Output (I/O) model is introduced and used to calculate the potential economic impacts of construction and operation of two major proposed crude pipeline projects in Western Canada: the Trans Mountain Pipeline Expansion (TMX) and the Northern Gateway Pipeline.

This is the second of a series of six reports regarding Pacific Access.

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Pacific Access: Part III - Economic Impacts of Exporting Horn River Natural Gas to Asia as LNG
July 2012

Like the changes brought about by unconventional oil production, shale gas has also revolutionized North American natural gas dynamics. With long-term forecasted depressed North American prices, gas producers have started development in infrastructure to access Asian markets in order to obtain more lucrative netbacks. Part III of CERI’s Pacific Access report continues the examination of opening the West Coast for energy exports by focusing on the supply chain of extracting gas at Horn River and exporting it via the Kitimat LNG terminal. CERI’s Regional Input-Output (I/O) model that was introduced in Part II is used to calculate the impacts of developing wells in Horn River, the construction and operation of the Pacific Trail pipeline, and the construction and operation of the Kitimat LNG terminal.

This is the third of a series of six reports regarding Pacific Access.

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Pacific Access: Part IV - Oil Spills and First Nations: Exploring Environmental and Land Issues Surrounding the Northern Gateway Pipeline
February 2012

The Enbridge Northern Gateway pipeline project offers a classic example of the controversy that increasingly attaches itself to energy infrastructure projects: how to balance economic development with environmental conservation. Consequently, discussions surrounding the development of Northern Gateway have become controversial. Many stakeholders claim the economics overwhelmingly favour pipeline construction, while others favour a risk-averse approach towards anything that may potentially contaminate a pristine area. To further complicate matters, British Columbia First Nations land claims are not well established, and it is these lands which the pipeline would traverse; these are the areas that would be damaged if an oil spill were to happen. This report addresses many of the environmental issues, providing insight into Enbridge’s Environmental Impact Assessment; it also explores the recent history of aboriginal land claims and the degree to which First Nations retain traditional land rights in contemporary Canadian society.

This is the fourth of a series of six reports regarding Pacific Access.

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Pacific Access: Part V - Overview of Transportation Options
January 2012

While not a recent concept, oil tankers mooring off British Columbia’s west coast have caused quite a stir. In fact, oil tankers have been loading crude off the west coast since the 1,150 kilometre Trans Mountain Pipeline (TMX) opened in 1957. Thus far, Kinder Morgan’s Westridge Terminal remains the only oil terminal on Canada’s west coast. This, however, may change.

There are currently 3 pipeline proposals and a rail proposal to transport crude oil from Alberta’s oil sands to the west coast. All aforementioned proposals require marine terminals to be built to transport crude oil to energy-hungry Asian markets. As such, these proposals are drawing a lot of attention—from industry, environmental groups, First Nations and various governments. This study explores and investigates oil tanker and marine terminal safety. In addition to providing a background of oil tankers and the international regulatory structure that governs the safety of the shipping industry, various operational and design measures are also discussed. These mandatory measures are discussed from a Canadian perspective, exploring regulations on a national and provincial level, bringing it down to the terminal level. The latter focuses on Port Metro Vancouver (PMV)—Canada’s busiest port and only marine terminal on the west coast to export crude oil—and Enbridge’s proposed Northern Gateway Marine Terminal. Their unique facilities, marine environments and regulations and safety protocols governing the movement of oil tankers are examined, respectively.

This is the fifth of a series of six reports regarding Pacific Access.

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Pacific Access: Part VI - Foreign Investment In the Oil Sands and British Columbia Shale Gas
March 2012

Development of Alberta’s oil sands and shale gas resources in British Columbia will not occur if financial capital is not available to pay for these projects. More recently, this capital is coming in a form of foreign direct investment from various companies around the globe. Countries, such as but not limited to the US, Europe, China and Korea are active either in the merger and acquisitions activity or complete take-overs. This paper gives a detailed overview of all the recent foreign investment deals that took place in the last few years within Alberta oil sands and BC shale gas regions.

This is the sixth of a series of six reports regarding Pacific Access.

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Canadian Oil Sands Supply Costs and Development Projects (2011-2045)
March 2012

In 2011, global economies experienced some growth, albeit not at the rates that were predicted. Prices of oil were in a range where new oil sands projects became economic again. However, producers remained anxious about future oil price estimates and were proceeding at a more balanced pace in order to better control costs. This approach should help them avoid a repeat of the high cost inflation environment that resulted from peak investment spending in 2007 and 2008 associated with the concurrent development of several large oil sands projects.

The industry’s challenge today is to manage this “second boom” more efficiently and in a more sustainable manner than the “first boom”. Costs have to be better managed and environmental performance has to improve continuously. It is the year 2012, and the debate on how the oil sands industry should develop continues to dominate the news. The debate is polarized and emotionally charged. The recent rejection of Keystone XL may seem like the worst and the biggest hit against Canada’s oil sands yet, but it is likely that similar protests will become the new norm. As the hearings continue for Enbridge in its quest to build the Northern Gateway pipeline to start shipping bitumen to the West Coast, industry should prepare itself for a new myriad of attacks. The time has come for the industry to engage in oil sands discussions that are factual and balanced and not sprinkled with exaggerations and/or myths. Collaboration among industry players and with various agencies – government and environmental – is the key to moving forward and breaking the fear and hostility among environmentalists, NGOs and the general public.

This is Canadian Energy Research Institute’s (CERI’s) seventh annual oil sands industry update, examining production, supply costs, and constraining factors for oil sands development. CERI monitors and reviews all the sands projects (used in the unconstrained case), and also develops a more realistic assessment – the CERI Reference Case Scenario – based on likely timing conflicts, contingencies, and project delays and deferrals. From the Reference Case Scenario stem the projections of production, investment, royalties, natural gas requirements, GHG emissions and demand for diluent, as well as supply costs for SAGD, surface mining recovery, and bitumen upgrading.

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To download the charts and tables, click here.

Overview of Eastern and Atlantic Canada's Petroleum Industry
and Economic Impacts of Offshore Atlantic Projects (2010 - 2035)

CERI Study 127
November 2011

There has been a recent renewed interest in onshore hydrocarbon development in the provinces of Quebec, Ontario, New Brunswick, Prince Edward Island, Nova Scotia, and Newfoundland and Labrador due to the region's significant potential. However, a host of issues including regulatory initiatives, public opposition, a lack of large scale commercial projects, and the infancy of the petroleum industry in this region, makes it difficult to establish an outlook for potential development over the long term. Meanwhile, offshore projects in Nova Scotia and Newfoundland and Labrador have become the most relevant developments outside the Western Canada Sedimentary Basin (WCSB) over the last couple of decades and are expected to continue to be the focus of the industry over the coming decades.

This report presents an overview of the petroleum industry in Eastern and Atlantic Canada, while it also presents CERI's outlook for production and investment associated with offshore projects in Nova Scotia and Newfoundland and Labrador over the 2010 to 2035 time period. Finally, this report presents the economic impacts across Canada and the United States associated with continued operations and new developments offshore Atlantic Canada including value added gross domestic product, employment and employment compensation impacts, as well as taxation and royalty revenues.

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To get downloadable copies of selected charts and tables, please click here

Emission Abatement Potential for the Alberta Oil Sands Industry and Carbon Capture
and Storage (CCS) Applicability to Coal-Fired Electricity Generation and Oil Sands

CERI Study 126
October 2011

In an increasingly greenhouse gas (GHG) conscious environment, Alberta has faced criticism for its heavy emissions within the oil sands industry and its utilization of coal-fired generation. Oil sands development is an expanding industry with production expected to approximately triple in the coming decades; consequently, emissions will rise markedly and if left unhindered, the oil sands will be a significant emitter of GHGs in the future. Simultaneously, the higher emissions from coal power generation compared to other forms of electricity generation have incited a largely uncertain future for coal generation. Furthermore, the advent of a carbon tax in Alberta and Canada’s commitment to the Copenhagen Accord, have endorsed the proliferation of lower GHG intensity technologies. Consequently, under the aforementioned pressures, various stakeholders have hastened to devise schemes and promote technologies that reduce emissions in order to avoid significant future costs (both social and financial) that could hinder development. This has resulted in a myriad of technologies which range from improvements in efficiency, to deep-cuts in emissions through sequestration.

CERI has evaluated these emerging technologies to determine applicability, and has attempted to provide context over the advantages and disadvantages of implementing such technologies. Furthermore, a projection of a business-as-usual scenario and emission factors for different technologies were developed in order to determine the potential abatement of emerging technologies. CCS was also examined in detail as a front runner for a potential renaissance of “clean-coal” technologies and applicability within the oil sands.

This study is primarily geared towards readers seeking to understand the sources of GHG emissions in the oil sands industry and the role of emerging technologies. It is also intended to update the reader on the state of CCS, the requirements for implementation, and potential barriers.

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Economic Impacts of Drilling, Completing and Operation of Gas Wells in Western Canada (2010 - 2035)

The exploration and development of natural gas resources within the Western Canada Sedimentary Basin (WCSB) peaked in 2006 with the completion of over 23,000 new wells, a production level of 17,500 mmcf/day and royalties paid to Alberta, British Columbia and Saskatchewan totalling $8.2 billion. This included conventional resources; coalbed methane (CBM) and early developments of shale/tight gas resources (BC Montney area). The worldwide recession of 2008 affected the gas industry in the same fashion as other industries around the world. Demand for gas retracted, gas prices fell and new drilling activity slowed. Between 2007 and 2010, new drilling activity within the WCSB dropped by close to 70 percent. Production started to decline as new wells failed to counter the natural decline from existing wells. In concert with the production decline, prices dropped resulting in provincial royalties of just $2 billion. At the same time, shale gas developments in the US ramped up to the point where gas supply was starting a push back of Canadian imports into the US. The golden age of gas within the WCSB was in trouble and the future is unclear! This report presents a “realistic” development forecast for the WCSB gas industry in the form of drilling activity, both vertical and horizontal wells, production levels and royalty payments. In addition, the capital requirements for development and operation of existing and future wells are calculated and the economic impacts for Canada and the United States are estimated.

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A Decade of Staged Oil Sands Growth (2010 - 2020)

CERI Study 125, Extension A

Canadian Oil production, which includes conventional oil, diluents, bitumen and synthetic crude oil (SCO), from the Western Canada Sedimentary Basin (WCSB), is estimated to exceed 2.9 million barrels per day (bpd) by the end of 2011. In addition after accounting for a resurgence of conventional oil developments and the completion of construction for 3 new oil sands projects, the production capacity out of the WCSB will approach 3.1 million bpd by the middle of 2012 and is forecasted to continue to grow crossing the 3.5 million bpd by 2013. At that point in time production will have exceeded the operational capacity of the export pipeline system leaving the WCSB either west to the port of Vancouver or east/ southeast to the Ontario and US PADD 2 markets? The next tranche of oil sands projects requires additional export capacity either in the form of new pipelines (Keystone XL , Gateway or Kinder Morgan Trans Mountain Northern Leg) or increased rail transport (CN Pipeline on Rail). This study examines the economic impacts of developing these oil sands projects which have been approved by the regulator and are awaiting increased export capacity to access the market. These impacts include the construction and operation of oil sands projects alone and does not include the impacts associated with the construction or operation of the pipelines or rail systems.

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Economic Impacts of Drilling, Completing and Operating Conventional Oil Wells in Western Canada (2010-2035)

June 2011

Conventional oil production from the Western Canada Sedimentary Basin (WCSB) has been declining since the early 1970s after reaching a peak of approximately 2 million barrels per day. In 2010 production from the basin had declined to 0.9 million barrels per day and it appeared that the decline would continue unabated. 2010 can now be viewed as a restart year for the conventional oil industry not just based on the resurgence in the number of wells drilled, driven by oil price, but more importantly based on the number of horizontal wells drilled driven by the success stories in shale gas developments. The industry is returning to old, thought to be depleted, reservoirs equipped with horizontal well drilling techniques to recover more of the resource that remains in the ground. The number of horizontal wells grew from 24 percent of oil wells drilled in 2006 to 62 percent of oil direct wells in 2011 and the future looks like the trend will continue. This report examines the growth potential in drilling activity, the effect of change towards horizontal drilling, and the increased production potential from conventional oil within the WCSB. In addition, the capital requirements for development and operation coupled with the economic impacts both for Canada and the United States are estimated.

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To download the map for Alberta referenced in Appendix A, click here.

To download the map for Saskatchewan referenced in Appendix A, click here.

Economic Impacts of Staged Development of Oil Sands Projects in Alberta (2010-2035)

CERI Study 125

The Alberta oil sands industry is once again expanding with a number of major projects under development and still more proposed for the future, reflecting a considerable growth that was deferred during 2008-2009 recession. New pipelines will be needed to ship bitumen crude to destinations in the United States and/or Canada’s west coast to reach Pacific Rim markets. This report looks at export pipeline proposals, namely TransCanada’s Keystone XL, Enbridge’s Northern Gateway and Kinder Morgan’s Trans Mountain expansion and evaluates the economic impacts of staged development of Alberta’s oil sands projects according to the proposed in-service dates of these pipelines. The report shows that without additional pipeline capacity, the benefits that will be lost in Alberta, Canada and the US are substantial.

This study captures the direct, indirect and induced effects of oil sands infrastructure investments and ongoing operational expenditures in four different scenarios. Using Input/Output economic modeling techniques, the report details the economic impacts in terms of gross domestic product (GDP), employment, employee compensation and government tax revenues.

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Economic Impacts of New Oil Sands Projects in Alberta (2010-2035)

CERI Study 124

Energy is at the core of the US-Canadian bilateral relationship. There is no more secure supplier of oil to the United States than its northern neighbour, and continuation of this secure supply depends in large part on the further development of oil sands projects.

This study focuses directly on the economic impacts of the Alberta oil sands between 2010 and 2035. Using Input-Output (I/O) economic modeling, the report quantifies the economic impacts of the oil sands on GDP, employment, employee compensation, and government revenues. The model incorporates the economic interrelationships between the Canadian federal, US federal, Canadian provincial, and US state economies. Therefore, it is able to capture the direct, indirect, and induced effects of oil sands infrastructure investments and ongoing operational expenditures on all of the above-mentioned economies.

CERI is noted for its expertise in I/O modeling, having completed numerous major studies for government and industry. This study represents yet another advance: the I/O tables have been updated, the trade-flow matrix between provinces and the US has been calibrated to allow for more accurate mapping of trade relations, and the model formulation and approach have been enhanced to capture with increased precision the relations among various sectors and local economies of different regions.

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North American Natural Gas Market Dynamics: Natural Gas Vehicles – A Review

CERI Study 123 - Section IV

This paper explores the possibilities of introducing natural gas vehicles (NGVs) to the North American Transportation sector. Noting that NGV’s have much to offer in terms of reduced greenhouse emissions, increased efficiencies and, in many cases, lower operating costs, the paper nevertheless argues that the place for NGVs in the overall transportation mix will be a small one for years to come. Grandiose visions of an NGV revolution, such as the Pickens Plan, are found to be infeasible over the next decade. Instead, the idea of introducing NGV’s into certain transportation corridors, as recommended by NRCan in their report “Natural Gas Use in the Transportation Sector”, is considered both possible and desireable. However, it will require time, effort, education, incentives, and infrastructure development to establish natural gas as a true alternative to crude-based fuels.

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North American Natural Gas Dynamics: Coal-fired Generation in North America

CERI Study 123 - Section III

Coal power plants conjure up strong images for individuals and groups on both sides of a raging debate about the future of electricity generation and the environment.

Whether they are changes in national legislation and regulation, or state/provincial programs and initiatives promoting reductions in GHGs or increasing the use of various renewables, many jurisdictions are trying to discover the balance between minimizing environmental impacts and maintaining a modern, reliable electricity system. While the province of Ontario is moving steadily to permanently shut down all coal-fired generation by 2014 – as part of the Open Ontario Plan – other jurisdictions suggest that advances in coal technology, such as supercritical coal-fired generation, CO₂/O₂combustion, CO₂ capture and sequestration and Integrated Gasification Combined Cycle (IGCC) offer cleaner coal options.

Amidst the debate and discussions and planning, one thing is abundantly clear; the worlds’ thirst for energy is growing, as is the demand for energy in North America.

This study focuses on North America and the current state of coal-fired generation in the United States and Canada, within a global context. The latter reviews global coal reserves, production and consumption. While not providing a synopsis of who is pulling and pushing in the debate to find a balance over energy production and the environment, this study reviews the current state of coal-fired power generation in North America and explores various elements and statistics of the industry in the US and Canada.

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North American Natural Gas Market Dynamics: Global LNG – A Review

CERI Study 123 - Section II

The global liquefied natural gas (LNG) market has grown significantly over the past decade, with new emerging LNG markets and a growing number of LNG producers. A plethora of new LNG re-gasification and liquefaction projects that are currently under construction will commence operations over the next few years, and construction will begin on many of the proposed LNG projects that are now in the planning phase. According to International Energy Agency (IEA) estimates, annual LNG trade will more than double from 2008 levels to approximately 17.7 TCF, or 48.4 BCFPD, by 2035.

The purpose of this study is to present an overview of existing LNG re-gasification and natural gas liquefaction capabilities around the world and to provide projections of future capacity additions at the regional and global levels. LNG re-gasification and liquefaction capacities in each region are summed by status and by start-up year, and probability factors for cancelling or delaying capacities, based on the status, are applied to produce a projection of future capacities. These probabilities will be adjusted depending on the region, as the likelihood of projects proceeding, or being delayed, will be affected by region-specific factors. The global LNG overview will also provide a brief discussion on existing LNG contracts and potential global LNG spot market supplies.

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North American Natural Gas Dynamics: Shale Gas Plays in North America – A Review

CERI Study 123

If the recent boom is any indication, the future potential of shale gas is nothing short of dramatic.

Given the sheer magnitude of the resource potential of shale gas, it essential to understand shale gas and its potential role in an environment of declines in conventional gas production in both Canada and the US. For the investor, it is important to understand the various players and the various shale gas plays. And for anyone involved in the energy industry—or interested about energy—it is prudent to be aware of this unconventional source of natural gas that is representing an increasingly large and growing share of the recoverable resource base

This purpose of this study is to review shale gas plays in North America, their geological differences, the players involved and future potential of various basins. This study explores the questions of where, who and when versus the what, how and why. Many people are familiar with several, if not all, of the big five shale plays in North America–the Barnett, Fayetteville, Haynesville, Marcellus and Woodford Shales. However, while these plays are basking in the media, there are many other plays that are far less known—that may end up being more productive than the aforementioned. Exploring other less well-known but potentially prolific shale gas plays in North America, this study will also discuss briefly regulatory and environmental issues regarding the development of shale gas.

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