May 14

Ireland: Fracking Requires Additional Study

By Curve domestic oil and gas production, Energy, Ireland, shale gas No Comments »

 

The process of hydraulic fracturing (“fracking”) used to release shale gas resources will remain on hold in Ireland until additional “detailed scientific analysis and advice” is available.

The comments were made by Pat Rabbitte, the country’s Minister of Energy, in response to the publication of a report from commissioned on the matter by the Environmental Protection Agency (EPA).

The study, authored by Dr. David Healy from the University of Aberdeen’s School of Geosciences., noted that while risks to water associated with the onland extraction of gas are an “important concern,” it concluded that the available information suggested a low and probably manageable risk to ground water from fracking.

“The current opinion shared by several agencies is that all scientifically documented cases of ground water contamination associated with fracking are related to poor well casings and their cements, or from leakages of fluid at the surface, rather than from the fracking process itself,” Dr Healy commented.

The study titled “Hydraulic Fracturing or ‘Fracking’: A Short Summary of Current Knowledge and Potential Environmental Impacts,” will be used to assist in a more comprehensive study, which the EPA says it expects will be commissioned this year.

Minister Rabbitte ordered the EPA to conduct a review of the effects fracking could have on the environment last October.

To date, three companies have been granted onshore petroleum licensing options from the government, which allows for “shallow geological sampling”. These are Tamboran Resources, Lough Allen Natural Gas Company and Enegi Oil Plc. The licences, granted by the governmental Department of Communications, Energy and Natural Resources (DCENR), are the first step in a three-step process.

Source: Natural Gas Europe

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May 08

Polish Experts: Shale Gas Debate Should Be Based On Fact Rather Than Emotion

By Curve energy market, hydraulic fracturing, natural gas in Europe, Poland, San Leon Energy, shale gas No Comments »

 

The Schuman Foundation conference on “Expectations and Reality: What’s next for Shale Gas ?” took place in the European Parliament Information Office in Warsaw on 16 April 2012. The main theme of the discussion was the future of unconventional gas in Poland and Europe following the recently published Polish PGI shale gas reserve estimates and the European Parliament’s Environment, Public Health and Food Safety Committee (ENVI) report on the environmental impacts of shale gas.

Among the experts invited were MEP Boguslaw Sonik  and MEP Boguslaw Liberadzki,  Professor Jan Lubal and Dr. Piotr Kasza of Polish Oil and Gas Institute, and Chemical Substances Inspector Jerzy Majka.

Referring to the ENVI report,  MEP Boguslaw Sonik, report rapporteur, explained that while the document had no direct legislative power, it was very important for the future of shale gas in the European Union. In his opinion, the unconventional gas debate in Europe, which started two years ago, is based largely on myth and fear, hence the need for the European Parliament to adopt an official stance on the issue.

MEP Boguslaw Liberadzki said that in terms of the energy industry’s needs, there were three key requirements to make the environment competitive in the European Union: sustainable economic development, the cost of energy production and, most importantly, agreement among the EU member states. He suggested that shale gas could bring member states together but appealed for the debate on this issue to be less based on emotion and more based on fact. Poland, he continued, should highlight that without shale gas it would be forced to rely on nuclear energy.

Speaking about the potential problems that may arise during shale gas extraction, Professor Jerzy Majka highlighted that accidents cannot be avoided making it necessary for appropriate safety monitoring systems to be put in place. He added that exploration companies should disclose the chemical used in hydraulic fracturing fluids to authorities.

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May 07

Shale source rocks a game-changer due to 8-to-1 resource potential

By Curve Realm Energy, San Leon Energy, shale gas, shale gas reserves No Comments »

 

One way to get a handle on the enormity of potentially producible hydrocarbons contained in shale formations is to estimate how much recoverable oil and gas remain within the source rocks in which they were generated as compared to how much producible oil migrated into “conventional” reservoirs.

Applying this illustrative methodology indicates that for every barrel of crude oil in conventional reservoirs that constitute the bulk of global crude oil reserves of 1.3 trillion bbl there are 8 bbl of potentially producible oil equivalents remaining in the source rock that generated that 1 bbl of conventional reserves (Table 1).

While this admittedly simplistic illustration could provoke considerable dissent within the petroleum geology community, it should prove directionally correct. As such, one is talking about a world-scale game changer as source rocks are moved into the producible column.

The resulting increase in potentially recoverable global crude oil of 1.3 trillion bbl,1 which constitutes a 40-year supply at current consumption rates,2 could be material.

Speculation as to the extent of the impact of this transformation on alternative energy supplies, the global economy and geopolitics, while certainly warranted, is well beyond the scope of this discussion.

Discussion

It’s worth remembering that up until, say, the mid 1990s, source rocks, principally shale-based formations, were recognized as only generating and expelling the hydrocarbons that, in turn, charged porous, reservoir-quality formations within the migration limits of this expelled oil and gas.

The source rocks themselves were not considered producible by virtue of very low porosities and permeabilities as compared to the far higher values characterizing reservoir-quality formations. So, while shale source rocks were considered a prerequisite for finding hydrocarbon-charged, reservoir-quality formations, they were largely “unstudied” as potential reservoirs due to the prohibitive economics of their low porosities and permeabilities.

Now that the subsequent evolution and exploitation of horizontal (directional) drilling and hydraulic fracturing have “unlocked” this otherwise unrecoverable shale oil, not to mention shale gas, the notion of what constitutes resource potential is in the process of being radically enlarged.

Tools define resources. Put radically improved exploitation tools in the hands of an exploration geologist and he will significantly increase what constitutes a recoverable resource.

Now that there are tools to economically recover shale-locked oil and gas, shale formations, intrinsically widespread throughout the world, are being “discovered” at a game-changing rate. This process has really just begun.

Speculative estimates of just how much generated oil remains in shale source rocks range between 45% and 95% depending on the geology of the formation and the quality of the estimate.

At one extreme is the vast 9-11 million acre Bakken Source System3 from which little or no oil has been expelled due to the overlying Lodgepole carbonate seal and such likely analogs as the Nordegg member of the Fernie formation of the Western Canada basin in Alberta.4-6

At the other extreme might be John Hunt’s estimate of 45% remaining in source rocks (both shale and carbonate) for oil generated in the last 100 million years.7 EOG Resources Inc., active in the two leading US shale oil plays, the Bakken and the Eagle Ford, estimates that “75% of generated oil [is] still in mother (shale) source rocks.”14

The overriding issue here is not the competence of the researchers making these estimates but rather the legacy of lack of economic incentives justifying the requisite study of shale source rocks. Accordingly, the understanding of shale source beds as productive reservoirs still pales in comparison to what is known about the behavior of the “conventional” reservoirs that comprise the bulk of the world’s reserves.

As this void is addressed, as often has been the case of analogous instances in the past, shale-based hydrocarbon resource estimates will increase, probably dramatically. A good example of this process is the US Geological Survey, which increased its estimate of Barnett shale recoverable gas resources from 3 tcf in 19968 to 26 tcf in 20049 principally as a result of the implementation of horizontal drilling and hydraulic fracturing.

The subsequent pioneering use of the same tools in the oil-rich Bakken of Montana and North Dakota expanded the estimate of Bakken resource potential from a USGS researcher’s unofficial finding of 151 million bbl in 199510 to a published 3.7 billion bbl in 2008.11 Industry estimates utilizing recent data now place Bakken ultimate recovery well north of a 2011 estimate of 24 billion bbl.12 13

Inspired by this pioneering success in identifying an oil-rich shale, a wide ranging search for analogs has already come up with the Texas Eagle Ford, which EOG contends will outstrip even the Bakken.15

This search is being repeated on a global scale ranging from California’s Monterey shale to shales in Argentina’s Neuquen basin, Canada’s Nordegg formation, France’s Paris basin, Poland’s Baltic basin, and China’s widespread but still largely uncharted shale formations…and this is just for starters.

Clearly, a key variable going forward in determining shale oil reserve potential will be the degree of improvement in currently low recovery rates. However, given the steady improvements in recovery technologies across widely varying reservoir geologies over the last 60 plus years, recovery rates are likely to experience marked improvement.

When one is talking presently of only 4-6% recovery for shale oil, an increase to 10% and, in turn, a doubling of potential reserves, is ultimately likely if the past is any kind of prologue.

Somewhat simplistically, this has all been distilled down to the observation in Table 1 that for every 1 bbl of oil reserves in a “conventional” reservoir, 8 bbl of recoverable oil equivalent could well remain behind in the shale source rock that generated this 1 bbl of reserves.

This, by any measure, should be a world-scale game changer for the oil and gas industry.

Well beyond the scope of this discussion is what impact this transformation could have on the global economy, alternative fuels, and geopolitics.

Source: Oil & Gas Journal

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May 03

Fracking Does Not Need More Regulation, Report Says

By Curve hydraulic fracturing, natural gas in Europe, San Leon Energy, shale gas No Comments »

 

There is no need for more environmental legislation in the case of shale gas exploration, at least until it reaches commercial scale, says a new study published by the European commission.

The activities relating to exploration of shale gas are already subject to EU and national laws and regulations, says the report, carried out for the European commission by Belgian law firm Philippe & Partners.

Water protection issues, for instance, which have been raised as an issue by shale gas detractors, are already covered by EU legislation under the Water Framework Directive, the Groundwater Directive and the Mining Waste Directive. Meanwhile, the use of chemicals is covered by the REACH regulation, the study says.

“It is a new technology and we do not have a specific legislation on shale gas, because it is so new,” said Marlene Holzner, European commission spokesperson on energy.

“So the study only says that the existing regulations are applicable for shale gas, that the tool is there and has only to be applied,” she told EurActiv, adding that the study was carried out only in four countries – Poland, France, Germany and Sweden. It was released on 27 January.

The law firm said shale gas activities were too small at the moment to justify specific legislation. “Neither on the European level nor on the national level have we noticed significant gaps in the current legislative framework, when it comes to regulating the current level of shale gas activities,” the study says.

This is, however, not a reason for “complacency”, the study says, since the assessment refers only to the current scale of operations in Europe. Shale gas exploitation on a commercial scale would involve bigger maneuvers, it adds.

Europe has less experience in exploring shale gas formations as a new source of natural gas and no commercial scale exploitations have taken place yet, but this “is expected in a few years’ time”, the report says.

Shale gas is an unconventional source of natural gas and studies show different results on how safe the two main methods of extracting it from rock formations.

One is the horizontal drilling in various regions of the rock, which is needed to capture the gas pockets. The other, hydraulic fracturing – or ‘fracking’ – involves a high-pressure injunction of fluids usually mixed with chemicals into shale rock. Both of them require seismic and drilling permits, as well as large amounts of chemicals and water.

Only after conducting consecutive tests for drilling and fracturing does a project reach the stage of planning and acquiring the needed pipeline, followed by the decision to bring the extraction to a commercial scale.

In a few years’ time, investors might find themselves in need of making a decision on the commercial development of their shale gas projects, a situation which is not covered by the EU study published on 27 January.

Poland, which aims to shrug off its dependency on Russian gas, is planning to begin commercial shale gas production from 2014, Prime Minister Donald Tusk said last year. Most of the projects are currently at the phase of seismic surveys and some projects already have entered the drilling phase, which is expected to intensify after 2014.

The natural gas trapped in shale rock in Poland could provide the country with enough fuel to last for 300 years, the US Department of Energy said last year.

However, not everyone is willing to allow drilling operations on their land, despite the economic potential. At the beginning of January, thousands of Bulgarians protested against exploration for shale gas over fears it could poison underground water, trigger earthquakes and pose serious public health hazards.

Source: The Guardian
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Apr 26

Study: Fracking Requires a Minimum Distance from Sensitive Rock Strata

By Curve shale gas No Comments »

The chances of rogue fractures due to shale gas fracking operations extending beyond 0.6 km from the injection source is a fraction of 1%, according to new research led by Durham University.

The analysis is based on data from thousands of fracking operations in the USA and natural rock fractures in Europe and Africa.

It is believed to be the first analysis of its type and could be used across the world as a starting point for setting a minimum distance between the depth of fracking and shallower aquifers used for drinking water.

The new study, published in the journal Marine and Petroleum Geology, shows the probabilities of ‘rogue’ fractures, induced in fracking operations for shale gas extraction, extending beyond 0.6 kilometres from the injection source is exceptionally low. The probability of fractures extending beyond 350 m was found to be 1%.

During fracking operations, fractures are created by drilling and injecting fluid into the rock strata underground to increase oil and gas production from fine-grained, low permeability rocks such as shale. These stimulated fractures can significantly increase the rate of production of oil and gas from such rocks.

Fracking operations in the USA are growing in number and many countries across the world are looking at shale gas as a potential energy resource. The process of fracking has come under increasing scrutiny. A recent test well in the UK near Blackpool, Lancashire, was stopped after some minor earthquakes were felt at the surface. The UK government is allowing the test fracking to resume but critics have also warned of other possible side-effects including the contamination of groundwater.

Researchers from Durham University, Cardiff University and the University of Tromsø looked at thousands of natural and induced fractures from the U.S., Europe and Africa. Of the thousands artificially induced, none were found to exceed 600 m, with the vast majority being much less than 250 m in vertical extent.

Fracture heights are important as fractures have been cited as possible underground pathways for deep sources of methane to contaminate drinking water. But the likelihood of contamination of drinking water in aquifers due to fractures when there is a separation of more than a kilometre is negligible, the scientists say.

Professor Richard Davies, Director of Durham Energy Institute, Durham University, said: “Based on our observations, we believe that it may be prudent to adopt a minimum vertical separation distance for stimulated fracturing in shale reservoirs. Such a distance should be set by regulators; our study shows that for new exploration areas where there is no existing data, it should be significantly in excess of 0.6 km.

“Shale gas exploration is increasing across the world and sediments of different ages are now potential drilling targets. Constraining the maximum vertical extent of hydraulic fractures is important for the safe exploitation of unconventional hydrocarbons such as shale gas and oil, and the data from the USA helps us to understand how fracturing works in practice.

“Minimum vertical separation distances for fracturing operations would help prevent unintentional penetration of shallow rock strata.”

Professor Davies’ team looked at published and unpublished datasets for both natural and stimulated fracture systems in sediment of various ages, from eight different locations in the USA, Europe and Africa.

Professor Richard Davies said: “Sediments of different types and ages are potential future drilling targets and minimum separation depths are an important step towards safer fracturing operations worldwide and tapping into what could be a valuable energy resource.

“We need to keep collecting new data to monitor how far fractures grow in different geological settings.”

The team accepts that predicting the height and behaviour of fractures is difficult. They now hope that the oil and gas industry will continue to provide data from new sites across the globe as it becomes available to further refine the probability analysis.

Analysis of new sites should allow a safe separation distance between fracking operations and sensitive rock layers to be further refined, the scientists say. In the meantime, the researchers hope that governments and shale gas drilling companies will use the analysis when planning new operations.

Source: Natural Gas for Europe

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Apr 18

Shale Gas Fracking Risks Exaggerated, Insurance Broker Claims

By Curve shale gas, shale gas in Europe No Comments »

 

A leading City firm has defended the controversial practice of fracking for shale gas on the day the government received advice to give it the green light in Britain.

“Shale gas is here to stay,” said Neil Smith, chief operating officer of global energy at insurance brokerage Willis. “It’s a very cheap form of extraction.”

Thousands of new shale gas wells could be drilled across the UK as ministers are expected to accept the advice of the first official government report into fracking. It came despite concerns around the safety of fracking in areas of known seismic activity, such as Lancashire where two wells have caused earthquakes which have damaged the integrity of at least one of them.

Friends of the Earth called for a full scientific assessment of all the impacts of fracking. Tony Juniper, the former director of the green group, said the environmental impact of fracking was “comparable to coal.”

An energy report from Willis published on Tuesday looked at the risks posed by fracking – from groundwater and soil contamination to earthquakes – and concluded that as long as shale gas companies adhere to industry best practice, the risks can be significantly reduced.

The casing of the well is crucial, the report said. A well drilled simply with surface and production casing could indeed allow drilling fluid and gas to seep into the water supply, it admitted. But best industry practice is to drill a well with intermediate casing 4,000 feet deep into the layer of rock beneath which lie the vast majority of gas deposits.

“‘A Macondo in the shale is a highly unlikely scenario,” the report said, referring to the BP oil spill in the Gulf of Mexico. The report noted that fracking has been around since the 1950s.

Smith said: “The issues are of a political nature and a lot are born out of ignorance of what the operations are.” He expects that with more information, and “greater insistence on best practice being adopted” – possibly through legislation – the concerns around fracking will diminish over time.

The US Environmental Protection Agency, however, found in December that fracking could be to blame for groundwater pollution.

Willis has drawn up a checklist of questions to ask when dealing with shale gas. “In general the market seems to be happy to write this business,” said Robin Somerville, global communications director at Willis.

Mark Miller, the chief executive of Cuadrilla Resources, the company behind the Lancashire wells, which caused earthquakes of 2.3 magnitude, was cited in the Willis report as saying: “How far is it between a 2.3 and a 7.5, which knocks down buildings? It’s literally millions and millions of times different.”

Dominick Hoare of Watkins Syndicate at the Lloyd’s of London insurance market said the firm, which is managed by Munich Re, is heavily involved in insuring US shale exploration and production. “With a proper assessment it’s a good risk to assume,” he said.

Matt Yeldham, the head of casualty at Aegis’ marine and offshore liability division, echoed Hoare’s comments. “Provided fracking is conducted in an appropriate fashion, it would appear on the whole to present a reasonable risk profile.” But he added: “Underwriters are not there to cover long-term health hazard and other latent issues.”

The coverage provided and the premium charged depends on the nature and extent of the underwriting information, Willis said. This is especially the case in the environmental impairment liability arena, which offers protection for gradual pollution liability risks associated with hydraulic fracturing.

The Willis report also showed that 2011 was the worst ever year for non-windstorm related losses for the energy market, due to unusually large losses in Canadian oil sands and floating offshore platforms. There were close to $9bn (£5.64bn) of insured and uninsured total losses.

Source: The Guardian

Mar 20

French Chemicals Makers Seek Support on Shale Gas, Nuclear Power

By Curve Europe, shale gas No Comments »

French chemicals makers urged President Nicolas Sarkozy and contenders in the election to reconsider their objection to shale gas and preserve nuclear power as energy costs are key to the industry’s competitiveness.

“If we’re told no shale gas and less nuclear, and if we have to pay 50 percent more for energy, that’s a huge or even a life-threatening concern,” Olivier Homolle, who chairs the Union des Industries Chimiques, the French chemicals industry federation, said in a March 16 interview. “Nuclear energy is very useful. It’s one of the rare areas where we have an advantage over Germany, so let’s try to preserve it.”

French chemical production will probably increase 1.8 percent this year as Europe’s economic growth slows after climbing 5.9 percent in volume last year to 86.7 billion euros ($114 billion), according to the group. French production lagged behind China, the U.S., Japan and Germany last year. It’s now on par with Brazil and South Korea, Homolle said.

Socialist candidate Francois Hollande, who’s leading in opinion polls to replace Sarkozy as president, wants to cut the use of nuclear power in electricity production to 50 percent by 2025, down from about three-quarters now. Sarkozy, meantime, aims to extend the lifespan of nuclear plants.

Hollande also has said he plans to maintain a ban introduced by Sarkozy on shale gas exploitation through rock- fracturing techniques that use water and chemicals, saying the method harms the environment.

‘Ball and Chain’
“In a global competition, we can’t be burdened with a bigger and bigger ball and chain,” said Homolle, who also oversees BASF SE’s operations in France. Chemical companies based in France also need stability and a level-playing field with other European countries in terms of tax, technical and environmental rules, he said.

“The cost of gas in Europe is three times the cost of gas in the U.S. because of shale gas,” Thierry Le Henaff, chief executive officer of Arkema SA (AKE), a French maker of industrial chemicals, said on March 8. “Not only is Europe not competitive against the Middle East, it’s now isn’t competitive against the U.S.” and may soon lose ground against Asia in terms of gas prices, he said.

The French economy is also burdened by higher labor costs and the chemicals industry needs better pipelines and harbor infrastructure to compete with neighbors, Le Henaff said.

Arkema put on hold a 70 million-euro investment to expand production of polyvinylidene fluoride, used to make protective coatings, in France as long as unions refuse some productivity gains, according to Le Henaff.

“It would be less expensive and more profitable” to make the investment in the U.S. or China than in France, where Arkema makes 60 percent of its production and just 13 percent of sales, he said. “The ball is in the unions’ camp.”

Source: Bloomberg Businessweek

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Mar 20

ConocoPhillips to take over at 3Legs’ Polish shale gas blocks

By Curve drilling, shale gas No Comments »

The US’ ConocoPhillips has sealed a deal to take over operatorship and a 70% stake in three shale gas concessions in Poland from UK-listed 3Legs Resources, the UK company said Tuesday.

ConocoPhillips’ commitment to the 3Legs concessions is a sign that the potential of the shale gas blocks is sufficient to warrant further investment, and 3Legs share price jumped 15% after the announcement.

By 1130 GMT, 3Legs shares were up 7% at GBP0.72.

In August 2009, 3Legs teamed up with ConocoPhillips, which is funding the initial exploration program of seismic and drilling, to develop shale gas in the Baltic Basin.

The US company agreed to finance initial exploration work, and took a call option for a total of six concessions in the western Baltic Basin dependent on initial exploration results.

“ConocoPhillips has given notice of exercise of its call option over the company’s three western Baltic Basin concessions, thereby acquiring a 70% equity interest in and operatorship of these concessions,” 3Legs said in a statement.

3Legs said it would retain a net 30% interest in the three concessions, which cover an area of approximately 2,049 sq km, as a non-operator.

The US major also retains an option to acquire a 70% interest in 3Legs’ three eastern concessions, exercisable at any time up until September 30, 2012.

“We are very pleased that ConocoPhillips has exercised its call option in respect of our three western concessions in the Baltic Basin,” 3Legs CEO Peter Clutterbuck said.

“Our objective all along has been to see ConocoPhillips exercise this option and this decision represents a very satisfactory conclusion to almost three years of cooperation in the exploration and appraisal of the Baltic Basin shales.”

During the exploration period, 3Legs drilled a total of four wells in the Baltic Basin shale play and tested the first two horizontal shale gas wells in Poland.

MORE DRILLING
3Legs also said it has agreed with ConocoPhillips a plan for one vertical well to be drilled at the Lebork concession in the second half of 2012.

The well will be extensively evaluated and the parties will retain the flexibility, if considered appropriate, to drill a horizontal section to the well at a later date, which may be then be fracture stimulated and tested.

3Legs said it and ConocoPhillips are also giving further consideration to options for additional testing of one or both of its two existing horizontal wells — Lebien LE-2H and Warblino LE-1H — following the end of winter conditions.

3Legs also holds a number of licenses for shale gas exploration in southern Poland.

It said Tuesday that its campaign of 2-D and 3-D seismic acquisition there has been completed and the data processed.

“Interpretation results are expected early in the second quarter of 2012,” it said.

3Legs added that it continues to consider adding other unconventional resource opportunities to its portfolio.

It said its focus will continue to be on shale oil and shale gas in Europe, although it said it would not rule out moving into “other regions of the world.”

Poland is considered Europe’s most prospective country for shale gas, though total resources are expected to be considerably lower than original estimates.

The Polish Geological Institute in cooperation with the US Geological Survey is set to release its new estimate next month, which is expected to be lower than the 5.3 trillion cubic meters of recoverable shale gas reserves estimated by a study for the US Energy Information Agency.

Source: Platts

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Mar 15

Poland May Start Shale Gas Production in 2014

By Curve Poland, shale gas, shale gas in Europe No Comments »

Poland’s treasury minister said Thursday that the country may start producing shale gas for commercial use in 2014, a move that should help the country limit its reliance on neighbouring Russia for a large chunk of its energy needs.

Mikolaj Budzanowski said that commercial production of up to 1 billion cubic meters per year could start in late 2014. He said the deposits could be up to 2 trillion cubic meters, enough to add to Poland’s energy mix for decades.

Poland is seeking to diversify its energy sources to cut dependence on Russian imports and its shale gas deposits are a major element in the plan. Nuclear energy and renewable sources are also to be added to the energy mix.

Poland’s annual gas consumption is 14 billion cubic meters and 70 percent of that comes from Russia, at prices dictated by its Gazprom monopoly.

The nation’s reserves are still being estimated and a state assessment based on geological research done in the 20th century is to be presented on Wednesday. It is expected to be well below the 5.3 trillion cubic meters estimated by the U.S. Energy Information Administration.

Some 20 international companies – many of them American – have obtained licenses to explore for shale gas and some have done some test drilling.

The technology of extracting gas from shale rock through hydraulic fracturing was developed in the United States. The move gave the U.S. a level of independence in the gas sector and led to sharply lower gas prices.

Source: The Seattle Times

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Mar 13

Shale Gas Could Help Refuel US Economy

By Curve shale gas No Comments »

 

A recent study by PriceWaterhouse Coopers says shale gas could give the American economy the boost it needs, by reducing manufacturing costs by billions of dollars.

In this local news story, Bob McCutcheon, managing partner of the PwC in Pittsburgh discusses the some of the studies other finding and how expansions in the chemicals, metals and industrial manufacturing industries are being fueling by the nation’s abundant supply of natural gas.

Watch the story here

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