gaz de schiste-CNRS 2014 · Le Monde Télérama Le Monde diplomatique Le Huffington Post Courrier international La Vie au Jardin S'abonner au Monde à partir de 1 ... Services Le

Coprsident, Commission sur les enjeux nergtique du Qubec, Dpartement de physique, Universit de Montral

CNRS LPTMC, Universit Pierre et Marie Curie

Paris, janvier 2014

Roches mres un tour dhorizon depuis la gologie

jusqu leur exploitation

Normand Mousseau

1 gaz de schiste-CNRS 2014.key - 15 janvier 2014

UNE MISSION DE VULGARISATION SCIENTIFIQUE ANIME PAR NORMAND MOUSSEAU

Diffusion: Jeudi 13h30 Radio Ville-Marie (91,3 FM) Samedi 16h00 (rediffusion)

Disponible en balado-diffusion: http://lagrandeequation.ca

iTunes U (page Universit de Montral)


Pourquoi?


Ressources traditionnelles en dclin

Soutien la recherche et au dveloppement (priv et public) ds 1975

Une industrie gazire trs fragmente

Une structure de proprit de la ressource particulire


Monde Canada tats-Unis

Ptrole

Rserves 212 Gtep 15% 2,2%

Production 3,9 Gtep 4,2% 8,7%

Dure 49 ans 194 ans 12 ans

Gaz naturel

Rserves 169 Gtep 0,9% 4,1%

187 Tm3

Production 2,9 Gtep 5% 19,3%

3,2 Tm3


Charbon

Rserves 415 Gtep 0,8% 28%

Production 3,7 Gtep 0,9% 14,8%



Prix

($/1

000

pied

s cu

bes)

0,00

3,00

6,00

9,00

12,00

Anneavr 1976 avr 1983 avr 1990 avr 1997 avr 2004 avr 2011


Ressources minrales appartiennent gnralement au propritaire de la surface!

Peu de contrle des gouvernement sur le dveloppement!

Permis dexploration: jusqu 28 000 $ / ha!

Redevances: 12 to 25 % (payes au propritaire des ressources)!

Taxes et droits additionnels pays aux gouvernements

Ressources minrales appartiennent ltat!

La plupart des provinces contrlent le dveloppement (sauf le Qubec)!

Dans la plupart des provinces, les droits dexploration sont vendus aux enchres, atteignant jusqu 4000 $/ha !

(sauf au Qubec - taux fixe de 0,10 $/ha)!

Redevances: 12 to 15 % (moins les gnreux remboursement et dductions fiscaux)!

Rien nest pay aux propritaires de la surface ni aux municipalits.


Province/tat Redevances (2009)Texas 7,5 % de la valeur sur le march du gaz produit avec une

rduction de 50 % de ce taux pour des puits cots levs de dveloppement.

Wyoming 6 % de la valeur taxable (prix vendu moins les cots de transport et de transformation).

Alaska 25 50 % des revenus netsPennsylvanie aucuneAlberta 5 % pour le gaz de shale. 5 % autrement, pouvant

atteindre 36 % en fonction du prix et de la production.

Colombie-Britannique 5 % des revenus brutsQubec 10 16 % de la valeur au puits


Origine


a!

)#2!9-,,-#024!)#!9-,,-.0)2!)#!9Z'0#2!$(+#2!\)#2!)-f.-!6%-0#!)#2!$#&'.-!)#!^*-`]!)#!=.f!#&!*,.$#!05*.0'-2!2(0!)#2!$#&'.-!6%-0#!)#2!9-,,-#024!)#!p-,%9Z'0#2!$.0052?!".!)-33-$(,'5!'-#&'!1!,;#>'0.$'-%&!)#!$#!=.f4!!2#0.-'C$#!8(;(!*#'-'#!30.$'-%&!)(!6%,(9#?!

F(2/+%!RD!I89(.$%.!&'J$(8-!*#+$%,%)$!*+-8$/+1.!?+K.!&%!0-!89/$%!S#)$,#+%)8OL!-/!M/1;%8!

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T,!#>-2'#!5=.,#9#&'!)(!=.f!#>'0.-'!)#!2$F-2'#2!F:+0-)#24!%q!,.!+%(#!)5*%25#!1!,;%0-=-!5'.-'!0-$F#!#&!2.+,#!%(!#&!2-,'4!$#!8(-!#>*,-8(#!2.!*,(2!=0.&)#!*#095.+-,-'5!#'!(!*,(2!=0.&)#!6(,&50.+-,-'5!1!,.!30.$'(0.'-%&!F:)0.(,-8(#!\6%-0!$-C)#22%(2]?!P;#2'!,#!$.2!)#!,.!3%09.'-%&!)#!D%&':!)(!^0-.2!#'!)#!,.!3%09.'-%&!)(!M#$%&)!2$F-2'#!.0=-,#(>!)#!dF-'#?!".!3%09.'-%&!)#!D%&':!#2'!'#,,#9#&'!0-$F#!#&!2-,'!#'!#&!2.+,#!8(#!,#2!*(+,-$.'-%&2!)#!,;

LABC du gaz de schistes au Canada, Office national de lnergie, novembre 2009

Le gaz de schiste


Exploitation



12 MIT STUDY ON THE FUTURE OF NATURAL GAS

The new shale plays represent a major contribution to the resource base of the U.S. However, it is important to note that there is considerable variability in the quality of the resources, both within and between shale plays. This variability in performance is

illustrated in the supply curves on the previous page, as well as in Figure 2.5. Figure 2.5a shows initial production and decline data from three major U.S. shale plays, illustrating the substantial differences in average well per for-mance between the plays. Figure 2.5b shows a probability distribution of initial flow rates from the Barnett formation. While many refer to shale development as more of a manufacturing process than the conventional exploration, development and production process, this manufacturing still occurs within the context of a highly variable subsurface environment.

In this section we do not attempt to make independent forecasts of future gas production such forecasts are generated by the Emissions Prediction and Policy Analyses (EPPA) modelling efforts described later. However, in addition to under-standing the resource volumes, it is important to understand the contribution that the new shale resources can make to the overall production capacity within the U.S.

According to PGC data, U.S. natural gas resources have grown by 77% since 1990, illustrating the large uncertainty inherent in all resource estimates.

Figure 2.5a Variation in Production Rates between Shale Plays6

9,000

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HaynesvilleMarcellusBarnett

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Figure 2.5b Variation in IP Rates of 2009 Vintage Barnett Wells7

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The future of natural gaz, an interdisciplinary MIT study, MIT, 2010.

Il faudrait plus de 60 000 puits dun an pour rpondre 20 % de la demande amricaine !1/3 de la superficie du Qubec


Mill

iard

s de

mt

res

cube

s

0255075

100125150175200225

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2011

Antrim (MI, IN et OH)Barnett (TX)Fayetteville (AR)Woodford (OK)Haynesville (LA et TX)Marcellus (PA et WV)Eagle Ford (TX)Bakken (ND)Reste des .-U.

Production de gaz de schiste aux tats-Unis

Energy information agency (2012)

> 35 % de la production gazire totale


Source: J. David Hugues et le Monde

2014-01-10 12:53Gaz de schiste : premiers dclins aux Etats-Unis | Oil Man

Page 1 sur 57http://petrole.blog.lemonde.fr/2013/10/01/gaz-de-schiste-premiers-declins-aux-etats-unis/

BlogsINTERNATIONAL POLITIQUE SOCIT CO CULTURE IDES PLANTE SPORT SCIENCES TECHNO STYLE VOUS DUCATION DITION

ABONNS

01 octobre 2013, par Matthieu Auzanneau

Gaz de schiste : premiers dclins aux Etats-Unis

C'est l que le boom des gaz de schiste a commenc. C'est l aussi que le dclin semble s'amorcer. Leschamps de Barnett et de Haynesville, dans le Sud des Etat-Unis, ont franchi leur pic de productionrespectivement en novembre et dcembre 2011.

Les puits de Barnett et Haynesville ont fourni jusqu'ici prs de la moiti de la production amricaine de gaz deschiste.

Le dveloppement plus tardif du troisime principal champ nord-amricain de gaz de schiste, celui deMarcellus dans les Appalaches, compense jusqu'ici le dclin de ses deux prdcesseurs. La poursuite dudveloppement de Marcellus joue un rle cl pour maintenir sur un plateau la production totale de gaz naturelaux Etats-Unis, stable depuis le dbut de l'anne 2012.

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Services Le Monde


While shale resources and production are found in many U.S. regions, at this time EIA is focusing on the six most prolific areas, which are located in the Lower 48 states. These six regions accounted for nearly 90% of domestic oil production growth and virtually all domestic natural gas production growth during 2011-12.


U. S. Energy Information Administration | Drilling Productivity Report

0

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drilling data through September projected production through November

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EIA 201318 gaz de schiste-CNRS 2014.key - 15 janvier 2014

EIA 2013


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Environnement


Bien peu de donnes pour une industrie qui emploie 650 000 travailleurs investit 35 milliards $ par anne reprsente prs de 100 milliards $ en retombe


Air


Measurements of methane emissions at natural gasproduction sites in the United StatesDavid T. Allena,1, Vincent M. Torresa, James Thomasa, David W. Sullivana, Matthew Harrisonb, Al Hendlerb,Scott C. Herndonc, Charles E. Kolbc, Matthew P. Fraserd, A. Daniel Hille, Brian K. Lambf, Jennifer Miskiminsg,Robert F. Sawyerh, and John H. Seinfeldi

aCenter for Energy and Environmental Resources, University of Texas, Austin, TX 78758; bURS Corporation, Austin, TX 78729; cAerodyne Research, Inc.,Billerica, MA 01821; dSchool of Sustainable Engineering and the Built Environment, Arizona State University, Tempe, AZ 85287; eDepartment of PetroleumEngineering, Texas A&M University, College Station, TX, 77843-3116; fDepartment of Civil and Environmental Engineering, Washington State University,Pullman, WA 99164; gDepartment of Petroleum Engineering, Colorado School of Mines, Golden, CO 80401; hDepartment of Mechanical Engineering,University of California, Berkeley, CA 94720-1740; and iDepartment of Chemical Engineering, California Institute of Technology, Pasadena, CA 91125

Edited by Susan L. Brantley, Pennsylvania State University, University Park, PA, and approved August 19, 2013 (received for review March 20, 2013)

Engineering estimates of methane emissions from natural gasproduction have led to varied projections of national emissions.This work reports direct measurements of methane emissions at190 onshore natural gas sites in the United States (150 productionsites, 27 well completion flowbacks, 9 well unloadings, and 4workovers). For well completion flowbacks, which clear fracturedwells of liquid to allow gas production, methane emissions rangedfrom 0.01 Mg to 17 Mg (mean= 1.7 Mg; 95% confidence bounds of0.673.3 Mg), compared with an average of 81 Mg per event in the2011 EPA national emission inventory from April 2013. Emissionfactors for pneumatic pumps and controllers as well as equipmentleaks were both comparable to and higher than estimates in thenational inventory. Overall, if emission factors from this work forcompletion flowbacks, equipment leaks, and pneumatic pumpsand controllers are assumed to be representative of national pop-ulations and are used to estimate national emissions, total annualemissions from these source categories are calculated to be 957 Ggof methane (with sampling and measurement uncertainties esti-mated at 200 Gg). The estimate for comparable source categoriesin the EPA national inventory is 1,200 Gg. Additional measure-ments of unloadings and workovers are needed to produce na-tional emission estimates for these source categories. The 957Gg in emissions for completion flowbacks, pneumatics, and equip-ment leaks, coupled with EPA national inventory estimates forother categories, leads to an estimated 2,300 Gg of methane emis-sions from natural gas production (0.42% of gross gas production).

greenhouse gas emissions | hydraulic fracturing

Methane is the primary component of natural gas and is alsoa greenhouse gas (GHG). In the US national inventoriesof GHG emissions for 2011, released by the EnvironmentalProtection Agency (EPA) in April 2013 (1), 2,545 Gg of CH4emissions have been attributed to natural gas production activ-ities. These published estimates of CH4 emissions from the USnatural gas industry are primarily based on engineering estimatesalong with average emission factors developed in the early 1990s(2, 3). During the past two decades, however, natural gas pro-duction processes have changed significantly, so the emissionfactors from the 1990s may not reflect current practices. Thiswork presents direct measurements of methane emissions frommultiple sources at onshore natural gas production sites in-corporating operational practices that have been adopted orbecome more prevalent since the 1990s.Horizontal drilling and hydraulic fracturing are among the

practices that have become more widely used over the past twodecades. During hydraulic fracturing, materials that typicallyconsist of water, sand and, additives, are injected at high pressureinto low-permeability formations. The injection of the hydraulicfracturing fluids creates channels for flow in the formations(often shale formations), allowing methane and other hydro-carbon gases and liquids in the formation to migrate to the

production well. The well and formation is partially cleared ofliquids in a process referred to as a completion flowback, afterwhich the well is placed into production. Production of naturalgas from shale formations (shale gas) accounts for 30% of USnatural gas production, and this percentage is projected to growto more than 50% by 2040 (4).Multiple analyses of the environmental implications of gas

production using hydraulic fracturing have been performed, in-cluding assessments of water contamination (58), criteria airpollutant and air toxics releases (911), and greenhouse gasemissions (1118). Greenhouse gas emission analyses havegenerally been based on either engineering estimates of emis-sions or measurements made 100 m to a kilometer downwind ofthe well site. This work reports direct on-site measurements ofmethane emissions from natural gas production in shale gasproduction regions.Methane emissions were measured directly at 190 natural gas

production sites in the Gulf Coast, Midcontinent, Rocky Moun-tain, and Appalachian production regions of the United States.The sites included 150 production sites with 489 wells, all ofwhich were hydraulically fractured. In addition to the 150 pro-duction sites, 27 well completion flowbacks, 9 well unloadings,and 4 well workovers were sampled; the sites were operated bynine different companies. The types of sources that were tar-geted for measurement account for approximately two-thirds of

Significance

This work reports direct measurements of methane emissionsat 190 onshore natural gas sites in the United States. Themeasurements indicate that well completion emissions arelower than previously estimated; the data also show emissionsfrom pneumatic controllers and equipment leaks are higherthan Environmental Protection Agency (EPA) national emissionprojections. Estimates of total emissions are similar to the mostrecent EPA national inventory of methane emissions fromnatural gas production. These measurements will help informpolicymakers, researchers, and industry, providing informationabout some of the sources of methane emissions from theproduction of natural gas, and will better inform and advancenational and international scientific and policy discussions withrespect to natural gas development and use.

Author contributions: D.T.A. and M.H. designed research; D.T.A., V.M.T., J.T., D.W.S.,M.H., A.H., and S.C.H. performed research; C.E.K., M.P.F., A.D.H., B.K.L., J.M., R.F.S., andJ.H.S. analyzed data; and D.T.A. wrote the paper.

The authors declare no conflict of interest.

This article is a PNAS Direct Submission.

Freely available online through the PNAS open access option.1To whom correspondence should be addressed. E-mail: [email protected].

This article contains supporting information online at www.pnas.org/lookup/suppl/doi:10.1073/pnas.1304880110/-/DCSupplemental.

www.pnas.org/cgi/doi/10.1073/pnas.1304880110 PNAS Early Edition | 1 of 6

ENVIRO

NMEN

TAL

SCIENCE

S

This study quantitatively estimates the spatial distribution of anthropogenic methane sources in the United States by combining comprehensive atmospheric methane observations, extensive spatial datasets, and a high-resolution atmospheric transport model. Results show that current inventories from the US Environmental Protection Agency (EPA) and the Emissions Database for Global Atmospheric Research underestimate methane emissions nationally by a factor of 1.5 and 1.7, respectively. Our study indicates that emissions due to ruminants and manure are up to twice the magnitude of existing inventories. In addition, the discrepancy in methane source estimates is particularly pronounced in the south-central United States, where we find total emissions are 2.7 times greater than in most inventories and account for 24 3% of national emissions. The spatial patterns of our emission fluxes and observed methanepropane correlations indicate that fossil fuel extraction and refining are major contributors (45 13%) in the south-central United States. This result suggests that regional methane emissions due to fossil fuel extraction and processing could be 4.9 2.6 times larger than in EDGAR, the most comprehensive global methane inventory. These results cast doubt on the US EPAs recent decision to downscale its estimate of national natural gas emissions by 2530%. Overall, we conclude that methane emissions associated with both the animal husbandry and fossil fuel industries have larger greenhouse gas impacts than indicated by existing inventories.


This work reports direct measurements of methane emissions at 190 onshore natural gas sites in the United States. The measurements indicate that well completion emissions are lower than previously estimated; the data also show emissions from pneumatic controllers and equipment leaks are higher than Environmental Protection Agency (EPA) national emission projections. Estimates of total emissions are similar to the most recent EPA national inventory of methane emissions from natural gas production. These measurements will help inform policymakers, researchers, and industry, providing information about some of the sources of methane emissions from the production of natural gas, and will better inform and advance national and international scientific and policy discussions with respect to natural gas development and use.

Anthropogenic emissions of methane in theUnited StatesScot M. Millera,1, Steven C. Wofsya, Anna M. Michalakb, Eric A. Kortc, Arlyn E. Andrewsd, Sebastien C. Biraude,Edward J. Dlugokenckyd, Janusz Eluszkiewiczf, Marc L. Fischerg, Greet Janssens-Maenhouth, Ben R. Milleri,John B. Milleri, Stephen A. Montzkad, Thomas Nehrkornf, and Colm Sweeneyi

aDepartment of Earth and Planetary Sciences, Harvard University, Cambridge, MA 02138; bDepartment of Global Ecology, Carnegie Institution for Science,Stanford, CA 94305; cDepartment of Atmospheric, Ocean, and Space Sciences, University of Michigan, Ann Arbor, MI 48109; dGlobal Monitoring Division,Earth System Research Laboratory, National Oceanic and Atmospheric Administration, Boulder, CO 80305; eEarth Sciences Division, and gEnvironmentalEnergy Technologies Division, Lawrence Berkeley National Laboratory, Berkeley, CA 94720; fAtmospheric and Environmental Research, Lexington, MA 02421;hInstitute for Environment and Sustainability, European Commission Joint Research Centre, 21027 Ispra, Italy; and iCooperative Institute for Research inEnvironmental Sciences, University of Colorado Boulder, Boulder, CO 80309

Edited by Mark H. Thiemens, University of California, San Diego, La Jolla, CA, and approved October 18, 2013 (received for review August 5, 2013)

This study quantitatively estimates the spatial distribution ofanthropogenic methane sources in the United States by combiningcomprehensive atmospheric methane observations, extensivespatial datasets, and a high-resolution atmospheric transportmodel. Results show that current inventories from the US Envi-ronmental Protection Agency (EPA) and the Emissions Databasefor Global Atmospheric Research underestimate methane emis-sions nationally by a factor of 1.5 and 1.7, respectively. Ourstudy indicates that emissions due to ruminants and manure areup to twice the magnitude of existing inventories. In addition, thediscrepancy in methane source estimates is particularly pro-nounced in the south-central United States, where we find totalemissions are 2.7 times greater than in most inventories andaccount for 24 3% of national emissions. The spatial patternsof our emission fluxes and observed methanepropane correla-tions indicate that fossil fuel extraction and refining are majorcontributors (45 13%) in the south-central United States. Thisresult suggests that regional methane emissions due to fossil fuelextraction and processing could be 4.9 2.6 times larger than inEDGAR, the most comprehensive global methane inventory. Theseresults cast doubt on the US EPAs recent decision to downscale itsestimate of national natural gas emissions by 2530%. Overall, weconclude that methane emissions associated with both the animalhusbandry and fossil fuel industries have larger greenhouse gasimpacts than indicated by existing inventories.

climate change policy | geostatistical inverse modeling

Methane (CH4) is the second most important anthropogenicgreenhouse gas, with approximately one third the totalradiative forcing of carbon dioxide (1). CH4 also enhances theformation of surface ozone in populated areas, and thushigher global concentrations of CH4 may significantly in-crease ground-level ozone in the Northern Hemisphere (2).Furthermore, methane affects the ability of the atmosphere tooxidize other pollutants and plays a role in water formationwithin the stratosphere (3).Atmospheric concentrations of CH4 [1,800 parts per billion

(ppb)] are currently much higher than preindustrial levels(680715 ppb) (1, 4). The global atmospheric burden started torise rapidly in the 18th century and paused in the 1990s. Methanelevels began to increase again more recently, potentially froma combination of increased anthropogenic and/or tropical wet-land emissions (57). Debate continues, however, over the cau-ses behind these recent trends (7, 8).Anthropogenic emissions account for 5065% of the global

CH4 budget of 395427 teragrams of carbon per year (TgCy)1(526569 Tg CH4) (7, 9). The US Environmental ProtectionAgency (EPA) estimates the principal anthropogenic sources inthe United States to be (in order of importance) (i) livestock(enteric fermentation and manure management), (ii) natural gas

production and distribution, (iii) landfills, and (iv) coal mining(10). EPA assesses human-associated emissions in the UnitedStates in 2008 at 22.1 TgC, roughly 5% of global emissions (10).The amount of anthropogenic CH4 emissions in the US and

attributions by sector and region are controversial (Fig. 1).Bottom-up inventories from US EPA and the Emissions Data-base for Global Atmospheric Research (EDGAR) give totalsranging from 19.6 to 30 TgCy1 (10, 11). The most recent EPAand EDGAR inventories report lower US anthropogenic emis-sions compared with previous versions (decreased by 10% and35%, respectively) (10, 12); this change primarily reflects lower,revised emissions estimates from natural gas and coal productionFig. S1. However, recent analysis of CH4 data from aircraft esti-mates a higher budget of 32.4 4.5 TgCy1 for 2004 (13). Fur-thermore, atmospheric observations indicate higher emissions innatural gas production areas (1416); a steady 20-y increase in thenumber of US wells and newly-adopted horizontal drilling techni-ques may have further increased emissions in these regions (17, 18).These disparities among bottom-up and top-down studies

suggest much greater uncertainty in emissions than typicallyreported. For example, EPA cites an uncertainty of only 13%for the for United States (10). Independent assessments of bot-tom-up inventories give error ranges of 50100% (19, 20), and

Significance

Successful regulation of greenhouse gas emissions requiresknowledge of current methane emission sources. Existing stateregulations in California and Massachusetts require 15%greenhouse gas emissions reductions from current levels by2020. However, government estimates for total US methaneemissions may be biased by 50%, and estimates of individualsource sectors are even more uncertain. This study uses at-mospheric methane observations to reduce this level of un-certainty. We find greenhouse gas emissions from agricultureand fossil fuel extraction and processing (i.e., oil and/or naturalgas) are likely a factor of two or greater than cited in existingstudies. Effective national and state greenhouse gas reductionstrategies may be difficult to develop without appropriateestimates of methane emissions from these source sectors.

Author contributions: S.M.M., S.C.W., and A.M.M. designed research; S.M.M., A.E.A., S.C.B.,E.J.D., J.E., M.L.F., G.J.-M., B.R.M., J.B.M., S.A.M., T.N., and C.S. performed research; S.M.M.analyzed data; S.M.M., S.C.W., A.M.M., and E.A.K. wrote the paper; A.E.A., S.C.B., E.J.D.,M.L.F., B.R.M., J.B.M., S.A.M., and C.S. collected atmospheric methane data; and J.E. and T.N.developed meteorological simulations using the Weather Research and Forecasting model.

The authors declare no conflict of interest.

This article is a PNAS Direct Submission.1To whom correspondence should be addressed. E-mail: [email protected].

This article contains supporting information online at www.pnas.org/lookup/suppl/doi:10.1073/pnas.1314392110/-/DCSupplemental.

2001820022 | PNAS | December 10, 2013 | vol. 110 | no. 50 www.pnas.org/cgi/doi/10.1073/pnas.1314392110


Human health risk assessment of air emissions from development of unconventionalnatural gas resources,

Lisa M. McKenzie , Roxana Z. Witter, Lee S. Newman, John L. AdgateColorado School of Public Health, University of Colorado, Anschutz Medical Campus, Aurora, Colorado, USA

a b s t r a c ta r t i c l e i n f o

Article history:Received 15 September 2011Received in revised form 10 February 2012Accepted 10 February 2012Available online 22 March 2012

Keywords:Natural gas developmentRisk assessmentAir pollutionHydrocarbon emissions

Background: Technological advances (e.g. directional drilling, hydraulic fracturing), have led to increases inunconventional natural gas development (NGD), raising questions about health impacts.Objectives: We estimated health risks for exposures to air emissions from a NGD project in GarfieldCounty, Colorado with the objective of supporting risk prevention recommendations in a health impactassessment (HIA).Methods: We used EPA guidance to estimate chronic and subchronic non-cancer hazard indices and can-cer risks from exposure to hydrocarbons for two populations: (1) residents living > mile fromwells and(2) residents living mile from wells.Results: Residents living mile from wells are at greater risk for health effects from NGD than are res-idents living > mile from wells. Subchronic exposures to air pollutants during well completion activ-ities present the greatest potential for health effects. The subchronic non-cancer hazard index (HI) of5 for residents mile from wells was driven primarily by exposure to trimethylbenzenes, xylenes,and aliphatic hydrocarbons. Chronic HIs were 1 and 0.4. for residents mile from wells and> mile from wells, respectively. Cumulative cancer risks were 10 in a million and 6 in a million for res-idents living mile and > mile from wells, respectively, with benzene as the major contributor tothe risk.Conclusions: Risk assessment can be used in HIAs to direct health risk prevention strategies. Risk man-agement approaches should focus on reducing exposures to emissions during well completions. Thesepreliminary results indicate that health effects resulting from air emissions during unconventionalNGD warrant further study. Prospective studies should focus on health effects associated with airpollution.

2012 Elsevier B.V. All rights reserved.

1. Introduction

The United States (US) holds large reserves of unconventional nat-ural gas resources in coalbeds, shale, and tight sands. Technologicaladvances, such as directional drilling and hydraulic fracturing, haveled to a rapid increase in the development of these resources. For ex-ample, shale gas production had an average annual growth rate of48% over the 2006 to 2010 period and is projected to grow almostfourfold from 2009 to 2035 (US EIA, 2011). The number of

unconventional natural gas wells in the US rose from 18,485 in2004 to 25,145 in 2007 and is expected to continue increasingthrough at least 2020 (Vidas and Hugman, 2008). With this expan-sion, it is becoming increasingly common for unconventional naturalgas development (NGD) to occur near where people live, work, andplay. People living near these development sites are raising publichealth concerns, as rapid NGD exposes more people to various poten-tial stressors (COGCC, 2009a).

The process of unconventional NGD is typically divided into twophases: well development and production (US EPA, 2010a; US DOE,2009). Well development involves pad preparation, well drilling,and well completion. The well completion process has three primarystages: 1) completion transitions (concrete well plugs are installed inwells to separate fracturing stages and then drilled out to release gasfor production); 2) hydraulic fracturing (fracking: the high pressureinjection of water, chemicals, and propants into the drilled well to re-lease the natural gas); and 3) flowback, the return of fracking andgeologic fluids, liquid hydrocarbons (condensate) and natural gasto the surface (US EPA, 2010a; US DOE, 2009). Once development is

Science of the Total Environment 424 (2012) 7987

Abbreviations: BTEX, benzene, toluene, ethylbenzene, and xylenes; COGCC,Colorardo Oil and Gas Conservation Commission; HAP, hazardous air pollutant;HI, hazard index; HIA, health impact assessment; HQ, hazard quotient; NATA, Na-tional Air Toxics Assessment; NGD, natural gas development. This study was supported by the Garfield County Board of County Commissionersand the Colorado School of Public Health. The authors declare they have no competing financial interests. Corresponding author at: Colorado School of Public Health, 13001 East 17th Place,

Mail Stop B119, Aurora, CO 80045, USA. Tel.: +1 303 724 5557; fax: +1 303 724 4617.E-mail address: [email protected] (L.M. McKenzie).

0048-9697/$ see front matter 2012 Elsevier B.V. All rights reserved.doi:10.1016/j.scitotenv.2012.02.018

Contents lists available at SciVerse ScienceDirect

Science of the Total Environment

j ourna l homepage: www.e lsev ie r .com/ locate /sc i totenv


Photo Annick MH de Carufel

Eau



Gisement Profondeur du shale (m)

Profondeur des eaux souterraines (m)

Barnett 2000 2500 360

Marcellus 1200 2500 250

Haynesville 3200 4000 120

Utica 500 - 3500 100


Concentration Typique

Type dadditif Compos principal

But Commentaires (NM)

96,26% Eau Eau Utilise pour accrotre la fracturation et introduire un aent de soulvement

Au Qubec, leau utilise pour la fracturation hydraulique provient des cours deau et nest pas extraite des nappes phratiques.

0,62% Agent de soutnement

Sable de silice flexible

Maintien les fracturations ouvertes pour permettre au gaz de schapper

Cet ingrdient ne pose visiblement pas de problme.

0,048% Rducteur de friction

Polyacrylamide Ajout aux fluides de fracturation

Bien que la molcule non polymrise, lacrylamide, soit neurotoxique, le polymre lui-mme est scuritaire et est couramment utilis dans les processus de traitement des eaux uses.

0,038% Surfactant glifiant

Isopropanol Trimthyloctadcylammonium!Xylne!Sulfanate de sodium

Utilis pour rduire la tension de surface des fluides de fracturation afin damliorer la rcupration du liquide du puits aprs la fracturation

Lisopropanol est un solvant utilis, par exemple, pour nettoyer des dispositifs lectroniques. Le sulfanate de sodium est utilis dans de nombreux procds industriel.

0,016% Brisant Hypochlorite de sodium

Brise le glifiant afin de permettre leau et au sable de s'couler plus

De leau de javel une concentration 500 fois infrieure celle utilise dans la lessive.

0,012% Glifiant deau Gomme de guar Huile de base faible toxicite

Rend leau plus visqueuse et apte maintenir le sable en suspension

La gomme de guar se retrouve de nos jours dans toutes les crmes laitires vendues en magasin. Malheureusement pour le got, mais sans rel danger, me semble-til.

0,005% Contrle de largile

Amine quaternaire

vite le gonflement et la Dsinfectants, produits assouplissants et agents migration de largile

0,002% Contrle du fer Monohydrate de Prvient la prcipitation des Encore un produit quon ne devrait pas avaler,

Source: Questerre


Increased stray gas abundance in a subset of drinkingwater wells near Marcellus shale gas extractionRobert B. Jacksona,b,1, Avner Vengosha, Thomas H. Darraha, Nathaniel R. Warnera, Adrian Downa,b, Robert J. Poredac,Stephen G. Osbornd, Kaiguang Zhaoa,b, and Jonathan D. Karra,b

aDivision of Earth and Ocean Sciences, Nicholas School of the Environment and bCenter on Global Change, Duke University, Durham, NC 27708; cDepartmentof Earth and Environmental Sciences, University of Rochester, Rochester, NY 14627; and dGeological Sciences Department, California State PolytechnicUniversity, Pomona, CA 91768

Edited by Susan E. Trumbore, Max Planck Institute for Biogeochemistry, Jena, Germany, and approved June 3, 2013 (received for review December 17, 2012)

Horizontal drilling and hydraulic fracturing are transforming energyproduction, but their potential environmental effects remain contro-versial.We analyzed141drinkingwaterwells across theAppalachianPlateaus physiographic province of northeastern Pennsylvania, ex-amining natural gas concentrations and isotopic signatures withproximity to shale gas wells. Methane was detected in 82% ofdrinking water samples, with average concentrations six timeshigher for homes

Marc Durand, prof. sciences de la terre, UQAM

Risques gologiques long terme

8

The other factor is the shale/s internal pressure. Overpressured shales develop during the

generation of natural gas: because of the low permeability, much of the gas cannot escape and

builds in place, increasing the internal pressure of the rock. Therefore, the artificially created

fracture network can penetrate further into the formation because the shale is already closer to

the breaking point than in normally pressured shales. The Horn River, Montney, and Utica shales

are all considered to be overpressured. The Colorado Shale is underpressured.

Furthermore, by isolating sections along the horizontal portion of the well, segments of the

borehole can be fracced one at a time in a technique called multi-stage fraccing (Figure 5). By

listening at the surface and in neighbouring wells, it can be determined how far, how extensively,

and in what directions the shale has cracked from the induced pressure (Figure 6). Finally, shales

can be re-fracced years later, after production has declined. This may allow the well to access

more of the reservoir that may have been missed during the initial hydraulic fracturing or to re-

open fractures that may have closed due to the decrease in pressure as the reservoir was drained.

Figure 6: Microseismic Imaging of a Multi-stage Frac

Each color represents a single staged frac. Source: Schlumberger, 2007.

Even with hydraulic fracturing, wells drilled into low-permeability reservoirs have difficulty

ScommunicatingT far into the formation. As a result, additional wells must be drilled to access as

much gas as possible, typically three or four, but up to eight, horizontal wells per section12

. In

comparison, only one well per section is typically drilled for conventional natural gas reservoirs

in western Canada. However, this does not necessarily mean that there will be a heavier land use

footprint versus conventional drilling. Several shale gas wells with horizontal lengths of up to

12 A section is based on the Dominion Land Survey (township-range grid system) for dispensing land in western Canada

during settlement. One section is equal to one square mile.

On extrait seulement 20 % du gaz durant lexploitation


12 MIT STUDY ON THE FUTURE OF NATURAL GAS

The new shale plays represent a major contribution to the resource base of the U.S. However, it is important to note that there is considerable variability in the quality of the resources, both within and between shale plays. This variability in performance is

illustrated in the supply curves on the previous page, as well as in Figure 2.5. Figure 2.5a shows initial production and decline data from three major U.S. shale plays, illustrating the substantial differences in average well per for-mance between the plays. Figure 2.5b shows a probability distribution of initial flow rates from the Barnett formation. While many refer to shale development as more of a manufacturing process than the conventional exploration, development and production process, this manufacturing still occurs within the context of a highly variable subsurface environment.

In this section we do not attempt to make independent forecasts of future gas production such forecasts are generated by the Emissions Prediction and Policy Analyses (EPPA) modelling efforts described later. However, in addition to under-standing the resource volumes, it is important to understand the contribution that the new shale resources can make to the overall production capacity within the U.S.

According to PGC data, U.S. natural gas resources have grown by 77% since 1990, illustrating the large uncertainty inherent in all resource estimates.

Figure 2.5a Variation in Production Rates between Shale Plays6

9,000

8,000

7,000

6,000

5,000

4,000

3,000

2,000

1,000

0

Production RateMcf/day

Year

HaynesvilleMarcellusBarnett

0 1 2 3 4 5

0

500

1000

1500

2000

2500

3000

0.0

0.2

0.4

0.6

0.8

1.0

0

2000

4000

6000

8000

10000

Figure 2.5b Variation in IP Rates of 2009 Vintage Barnett Wells7

0.12

0.10

0.08

0.06

0.04

0.02

0

IP Rate Probability

IP RateMcf/day

(30-day avg)

0 1,000 2,000 3,000 4,000 5,000 9,000

IP Rate Probability(Barnett 09 Well Vintage)

0

500

1000

1500

2000

2500

3000

0.0

0.2

0.4

0.6

0.8

1.0

0.00

0.02

0.04

0.06

0.08

0.10

0.12

1,000 Mcf/day

250 Mcf/day

The future of natural gaz, an interdisciplinary MIT study, MIT, 2010.32 gaz de schiste-CNRS 2014.key - 15 janvier 2014

Le reste du monde



Source: Energy Information Agency (2013)

Rang Pays Gaz de schiste Gaz conventionnelTm3 Gtep Tm3

1 Chine 32 282 Argentine 23 20

3 Algrie 20 18

4 tats-Unis 19 17

5 Canada 16 14

6 Mexique 15 14

7 Australie 12 11

8 Afrique du Sud 11 10

9 Russie 8 7

10 Brsil 7 6

Total 163 144 187

Gaz naturel


Source: Energy Information Agency (2013)

Rang Pays!! Ptrole de schiste! Ptrole conventionnelGbarils Gtep Gtep

1 Russie 75 102 tats-Unis 58 83 Chine 32 44 Argentine 27 45 Libye 26 46 Australie 18 27 Venezuela 13 29 Mexique 13 29 Pakistan 9 1

10 Canada 9 1

Total! 345 38 236

Ptrole


Le ptrole de schiste


Energy Policy Research Foundation, Inc. 1031 31st Street, NW Washington, DC 20007 202.944.3339 eprinc.org 4

Figure 1. Map of Williston Basin with Bakken and Three Forks Formations

Source: EPRINC

Shale oil has historically been difficult and costly to produce because it is found in formations characterized by both low porosity and low permeability. Large and sustained investment in oil production has not taken place in North Dakota until recently because traditional vertical well technology and production methods touched only a portion of the producible rock. This left the wellbore (the drilled hole exposed to the producing rock) exposed to only a small portion of the tight oil formation, preventing it from being produced to its full potential. Attempts to access the resource using horizontal drilling6 technology had been tried in the past, but had not advanced to longer laterals and multiple hydraulic fracturing stages7 in the right layer or rock. Studies and papers dating back to the 6 Horizontal drilling or directional drilling refers to a vertical well departing into a horizontal well at roughly 90 degrees and drilling along the rock formation horizontally allowing, exposing the wellbore a greater portion of the producing rock. 7 Schlumberger Oilfield Glossary: Hydraulic Fracturing: A stimulation treatment routinely performed on oil and gas wells in low-permeability reservoirs. Specially engineered fluids are pumped at high pressure and rate into the reservoir interval to be treated, causing a vertical fracture to open. The wings of the fracture extend away from the wellbore in opposing directions according to the natural stresses within the formation. Proppant, such as grains of sand of a particular size, is mixed with the treatment fluid to keep the fracture open when the treatment is complete. Hydraulic fracturing creates high-conductivity communication with a large area of formation and bypasses any damage that may exist in the near-wellbore area.

Ptrole de schiste


2009 (rel)

2035 (faible)

2035 (probable)

2035 (lev)

Sables bitumineux 67,3!1,35150!3,0

225!4,5

300!6,0

Schistes bitumineux 0 0 12,5!0,2550!1

Roches tanches 13,5!0,2730!0,6

100!2,0

150!3,0

Traditionnel 0,75 5

Ptrole en place Ressources

Potentiel ultime

Schistes bitumineux !(Formation de Green River)

205 0 110

Sables bitumineux canadiens 246 23 42

Sables bitumineux amricains 9 0

Ptrole de roches tanches 0,75 5

Total >450 >25 >150

Production en Amrique du Nord (Mtp par anne / Mbpj)

Rserves (Gtp)


O

ECD

/IEA

, 201

2

106 World Energy Outlook 2012 | Global Energy Trends

the economics of such plants. Output from coal-to-liquids (CTL) plants also increases, with most of this coming from China (which, outside South Africa, is the only commercial CTL

area of the United States.

of the decline in crude oil output.

Figure 3.18 United States oil production by type in the New Policies Scenario

0

2

4

6

8

10

12

1980 1990 2000 2010 2020 2030 2035

mb/

d Light !ght oilOther unconven!onal oilNGLs

Fields yet-to-be found Fields yet-to-be developedCurrently producing

Crude oil:

081-124_Chapitre 3_weo_11 .indd 106 18/10/2012 16:50:34

Prvision de production de ptrole - tats-Unis

World Energy Outlook 2012, Agence internationale de lnergie


Schistes bitumineux

5

In addition to these active OS operations, Southern Pacific Petroleum and Suncor Energy Inc. performed

tests to develop a commercial SO plant 10 km north of Gladstone in Queensland (Australia). The oil shales

would be mined from the Stuart deposit by open pit, and the shale oil would be extracted by the Alberta-

Taciuk Processor retort technology. In 2003 - 2004, production tests were run, which resulted in a

production of 702,000 barrels of SO with a peak production of 3,700 barrels per day (Johnson et al,

2004b). The operation was shut down in July 2004. After an evaluation period, in December 2004,

Queensland Energy Resources advised Australian officials that it wished to discontinue the environmental

impact statement process for the proposed Stage 2 development because it was not economically viable.

The plant had three phases, with the first stage at 4000 barrels/day (b/d) and the third stage at 200 000

b/d (reduced at 65 000 b/d). The plant was unable to reach the 4000 b/d level. Suncor left in 2000

(claiming that they have better areas to invest, but admitting in 2005 that it was not commercially viable),

writing off the plant investment. Although it is possible that this project could be resurrected, it is now

suspended. (Johnson et al, 2004b; Snyder, 2004)

Dyni (2002) compiled a figure showing the oil shale production from several countries over the past

120 years (Figure 3, overleaf). World production peaked in 1980 when 47 Mt of OS were mined. During

the last decades, more than 70% of the global OS production took place in Estonia. Besides, significant

amounts of OS were produced in China (Moaming and Fushun deposits) and Brazil (Irati oil shale).

Figure 3 Production of oil shale in million metric tons from selected oil shale deposits from 1880

to 2000 (Dyni, 2003)

US Geological Survey, 2002

Mill

ions

de

tonn

e de

sch

istes


210 World Energy Outlook 2008 - OIL AND GAS PRODUCTION PROSPECTS

Geological factors:!# The delineation of additional reserves through new seismic

acquisition, appraisal drilling or the identification (using well-bore measurements),

of reservoirs that had been previously bypassed.

Technological factors:!# An increase in the share of oil in place that can be recovered

through the application of new technologies, such as increased reservoir contact,

improved secondary recovery and enhanced oil recovery.

Definitional factors:!# Economic, logistical and political/regulatory/fiscal changes in

the operating environment.

The Weyburn field in Canada provides a good illustration of how reserves can grow over

time (Figure 9.8). Production started in the mid-1950s with conventional vertical wells.

Initial proven reserves at that time were estimated at 260 million barrels. Infill drilling of

wells in the mid-1980s added a producible wedge of 20 million barrels. Horizontal wells

drilled in the 1990s added a second, additional wedge of reserves of around 60 million

barrels. At the end of the 1990s, an enhanced oil recovery scheme using anthropogenic

CO2 piped in from a coal-gasification plant in North Dakota in the United States added

120 million barrels more, or one-third, taking initial reserves to 460 million barrels.

Figure 9.8 " A case study of oil reserves growth: the impact of technology on oil production from the Weyburn field in Canada

1950 1960 1970 1980 1990 2000 2010 2020 2030

Thou

sand

bar

rels

per d

ay CO2 injection

Infill - horizontal wells

Infill - vertical wells

Original vertical wells

50

40

30

20

10

0

Source: PTRC Weyburn-Midale website (www.ptrc.ca).

The USGS has undertaken a comprehensive analysis of the main factors in reserves

growth, based on production series for 186 giant fields outside the United States (133 in

OPEC countries) with more than 0.5 billion barrels of reserves for the period 1981 to

2003 (Klett, 2004). Reserves in the OPEC fields increased by 80% in aggregate and in

non-OPEC fields by around 30% over this period.

Reserves growth in any given field automatically raises the recovery factor, which

is defined as total recoverable reserves (including the oil or gas already produced)

expressed as a percentage share of the original hydrocarbons in place. As estimates

of both the volume of hydrocarbons in place and how much is recoverable vary as a

field is developed and produced, the estimated recovery factor inevitably fluctuates.

O

EC

D/I

EA

, 2

00

8

Gisement de Weyburn, Saskatchewan. Tire du World Energy Report 2008 de lAgence

internationale de lnergie.


O

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/IEA

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104 World Energy Outlook 2012 | Global Energy Trends

investment in upgraders for the heavier crudes and raw bitumen and in condensate and

Figure 3.16 World oil production by type in the New Policies Scenario

0 10 20 30 40 50 60 70

Crude oil

NGLs

Light !ght oil

CTL and GTL

Other*

mb/d

20112035

Extra-heavy oiland oil sands

Output of oil sands in Canada grows rapidly, from 1.6 mb/d in 2011 to 4.3 mb/d in 2035, on

Figure 3.17 World oil production by quality in the New Policies Scenario

0

5

10

15

20

25

30

35

40

45

NGLs Crude oil: light*

Crude oil:medium

Crude oil:heavy

Extra-heavyoil**

mb/

d 20112035

081-124_Chapitre 3_weo_11 .indd 104 18/10/2012 16:50:34

AI, 201243 gaz de schiste-CNRS 2014.key - 15 janvier 2014

00


U.S. Energy Information Administration, 2011.

Ratio du prix du GJ de ptrole sur celui du gaz naturel

Ratio

0,0

1,5

3,0

4,5

6,0

Anne

1987 1993 1999 2005 2011



Section 1 | The Golden Age of Gas Scenario 19

Primary demand In the GAS Scenario, global primary energy demand is projected to rise from around

12 300 million tonnes of oil equivalent (Mtoe) in 2008 to 16 800 Mtoe in 2035 an increase

of over 35%. This is slightly higher than in the New Policies Scenario, largely because of the

assumed lower price of gas. The average rate of growth in energy demand slows during the

Outlook period, from 1.5% per year in the period 2008-2020 to 0.9% per year in 2020-2035. The demand for all energy sources increases over the Outlook period. Fossil fuels (oil, coal and natural gas) account for more than half of the increase and remain the dominant

energy sources in 2035 (Figure 1.1). However, the share of fossil fuels in the overall primary

energy mix decreases from 81% in 2008 to just over 74% in 2035, marginally higher than in

the New Policies Scenario. The rest of the increase in global energy demand through to

2035 is accounted for by renewables and nuclear power.

Figure 1.1 World primary energy demand by fuel in the GAS Scenario

In the GAS Scenario, global primary natural gas demand is around 600 bcm higher than in

the New Policies Scenario in 2035. It increases from 3.1 tcm in 2008 to 5.1 tcm in 2035 an

increase of 62% the average rate of increase in gas demand being nearly 2% per year.

Unsurprisingly, natural gas sees the strongest demand growth of all energy sources in

absolute terms in the GAS Scenario.

Natural gas increases from 21% of the worlds fuel mix in 2008 to 25% in 2035, compared

with 22% in the New Policies Scenario. The combined effect of a strong increase in natural

gas demand throughout the Outlook period and a decline in global coal demand from around 2020 onwards results in global demand for natural gas overtaking coal before 2030,

to become the second-largest fuel in the primary energy mix. The GAS Scenario also sees

demand for natural gas narrowing significantly the gap with oil by the end of the Outlook period.

While oil continues to be the dominant fuel in the primary energy mix (Figure 1.2), with

demand increasing from 4 060 Mtoe in 2008 (85 million barrels per day [mb/d]) to just

under 4 550 Mtoe in 2035 (97 mb/d), its share of the mix drops from 33% in 2008 to 27% in

2035. High prices promote further switching away from oil in the industrial sector and

opportunities emerge to substitute other fuels for oil products in road-transport.

0

1 000

2 000

3 000

4 000

5 000

1980 1990 2000 2010 2020 2030

Mto

e Oil

Gas

Coal

Biomass

Nuclear

Other renewables

Hydro

2035

O

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/IEA

, 20

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36 World Energy Outlook 2011 | Special Report

Figure 1.13 World natural gas production by source in the GAS Scenario

To meet the higher natural gas demand in the GAS Scenario the cumulative investment

required in supply infrastructure is around $8 trillion 12% higher than in the New Policies

Scenario. This increase is slightly offset by the reduced levels of investment required for

other fuels (Figure 1.14). The net additional energy-supply infrastructure investment

required in the GAS Scenario over the Outlook period is more than $700 billion higher than the New Policies Scenario.

Figure 1.14 Incremental investment in energy-supply infrastructure by fuel and region in the GAS Scenario relative to the WEO-2010 New Policies Scenario

While the majority of the net additional investment in the GAS Scenario is in gas-supply

infrastructure, some is also required in the power sector. Lower gas prices translate into

lower electricity prices, which increase electricity demand. This increase in electricity

demand nearly 1% higher than in the New Policies Scenario translates into a

requirement for cumulative additional investment of $12 billion in power generation

capacity. This is considerably lower than it would be if the additional electricity demand

were met using the same power generation mix as in the New Policies Scenario. The

increase in electricity demand in the GAS Scenario also drives a need for additional

cumulative investment of $140 billion in transmission and distribution networks.

-100 -50 0 50 100 150 200 250 300

Rest of world

Latin America

Middle East

Other Asia

E. Europe/Eurasia

OECD Pacific

OECD North America

China

Billion dollars (2009)

Gas

Power

Oil

Coal

0

750

1 500

2 250

3 000

3 750

4 500

5 250

2005 2010 2015 2020 2025 2030 2035

bcm

Shale

Coalbed methane

Tight

Conventional: fields yet to be found

Conventional: fields yet to be developed

Conventional: currently producing fields

O

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11


volution de la production de ptrole et du gaz (1965-2012)

Prod

uctio

n (M

tp)

500

1142,857

1785,714

2428,571

3071,429

3714,286

4357,143

5000

Anne1965 1970 9175 1980 1985 1990 1995 2000 2005 2010

Source: BP World Statistical Report 2013

ptrole

gaz naturel

charbon


nergies renouvelables 9%

Nuclaire 6%

Charbon 25%

Gaz naturel 23%

Ptrole 37%

2008Source: BP World Statistical Report 2012


Renouvelable 2%

Hydro-lectricit 7%

Nuclaire 5% Charbon

30%

Gaz naturel 24%

Ptrole 33%

2012Source: BP World Statistical Report 2013


NORMAND MOUSSEAU

LAVENIR DU QUBEC PASSE PAR

lindpendancenergtique

MERCI !

schistedeGazLA RVOLUTION DES

LA R

VO

LUTI

ON

DES

GA

Z D

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Normand Mousseau

Nor

man

d M

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AU-DEL DE LA CONTROVERSE

J usqu prsent, le dbat sur les gaz de schiste au Qubec a t domin, avec raison, par la question environnementale. Cependant, on ignore encore beaucoup de choses au sujet des risques et de limpact court, moyen et long terme de la fracturation hydraulique. Malgr ces rserves bien relles, lindustrie continue de se dvelopper un rythme acclr dans le reste de lAmrique du Nord. Elle est en voie dexploser galement en Europe et en Asie, surtout en Chine.

Pour comprendre la situation, il faut regarder au-del de nos frontires. Voil pourquoi La rvolution des gaz de schiste prsente une description du panorama nergtique mondial actuel. Il sattarde aussi laspect plus scientifique de lexploitation de cette ressource, de la gologie aux risques environnementaux, et dcrit les activits dexploration et dexploitation de cette ressource travers le monde. Enfin, il fait tat des diffrents modles conomiques qui encadrent lexploitation des hydrocarbures dans le monde dvelopp et des particularits qui devraient tre appliques dans le cas des gaz de schiste.

Pour les opposants limplantation des gazires au Qubec, cette dernire section semblera prmature. Lauteur pense, quau contraire, il faut discuter au plus vite du modle conomique que le Qubec veut suivre. Plus on attendra, plus son implantation risque de coter cher, car les gazires auront alors eu tout le temps dtablir un rapport de forces lgal et politique, bas sur une valuation encore plus prcise des ressources disponibles.

Voil donc le propos de ce livre prpar par un expert indpendant, le physicien et universitaire Normand Mousseau dont les deux premiers livres parus au cours des dernires annes ont connu un rayonnement important.

NORMAND MOUSSEAU est professeur de physique lUniver-sit de Montral et chercheur de renomme internationale. Il nourrit une grande passion pour la vulgarisation scientifique. Il est lauteur de Au bout du ptrole, tout ce que vous devez savoir sur la crise nergtique et Lavenir du Qubec passe par lindpen-dance nergtique.

ISBN 978-2-89544-173-1

Normand Mousseau

des ressources miniresLe dfi


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