The fuel for dynamic change in the United State’s energy relationship with Canada lies in immense deposits of tar sands beneath the boreal forests of Alberta province. Unconventional production of oil from this resource has accelerated in recent years and remains poised for continued expansion, facilitated, in part, by plans to import tar sands crude through new pipelines to refineries in the United States. However, the development of this resource carries uniquely heavy environmental burdens, and U.S. environmental groups have challenged the process by which the United States authorizes cross-border oil pipelines. This thesis analyzes the presidential permitting process and concludes that executive or legislative action is necessary to eliminate legal uncertainties and improve the transparency and public acceptability of determinations that new cross-border pipelines are warranted. / text

No description available.

Research Project (M.R.M.) - Simon Fraser University, 2005. / Research Project (School of Resource and Environmental Management) / Simon Fraser University.

This report offers a comparative valuation of two bitumen production technologies, using real options analysis (ROA) techniques to incorporate strategic flexibility into the investment scenario. By integrating a probabilistic cost model into a real options framework, the value of an oil recovery facility is modeled to reflect the realistic alternatives available to decision-makers, where the course of the investment can be altered as new information becomes available. This approach represents a distinct advantage to traditional discounted cash flow (DCF) estimation, which is unable to capture operational adaptability, including the ability to expand, delay, or abandon a project. The analysis focuses on the energy inputs required for the recovery of heavy oil bitumen from Alberta, Canada, and examines both natural gas and nuclear steam plants as heat sources. The ACR-1000 reactor is highlighted as a substitute for conventional natural gas-fueled means of production, in light of the recent volatility of natural gas prices and the potential for emissions compliance charges. The methodology includes a levelized cost assessment per barrel of bitumen and estimation of cost ranges for each component. A mean-reversion stochastic price model was also derived for the both natural gas and oil price. By incorporating cost ranges into a ROA framework, the benefit of retaining project flexibility is included in its valuation. Formulated as a decision tree, built-in options include the initial selection to pursue nuclear or natural gas, site selection and licensing, the ability to switch heat source in the planning stage, and the final commitment to construct. Each decision is influenced by uncertainties, including the course of bitumen and natural gas price, as well as emissions policy. By structuring the investment scenario to include these options, the overall value of the project increases by over $150 million. The ability to switch technology type allows for an assessment of the viability of nuclear steam, which becomes economically favorable given high natural gas prices or high emissions taxes. Given an initial selection of natural gas SAGD, there is a 25% probability that a switch to nuclear steam will occur, as evolving financial conditions make nuclear the optimal technology. / text

Reclaimed oil sands landscapes are perceived to be low in plant diversity compared with naturally occurring plant communities. Approximately 66 Carex species inhabit the oil sand region. This thesis is unique and represents the first large scale study of Carex establishment on reclaimed oil sands landscapes. Research compared diversity and habitat variables between natural ecosystems and reclaimed landscapes, and examined the colonization mechanism for Carex establishment on reclaimed landscapes (i.e., ingress from adjacent natural ecosystems or emergence from the soil seed bank). Low positive associations between the presence of Carex in natural and reclaimed landscapes, and the presence of species on reclaimed landscapes not accounted for in either the forest or edge plots, suggests Carex established from the soil seed bank and less so from natural ingress. Carex share the same seed dispersal mechanisms as many plants, so the implications may apply to a broader range of plant species.

Neste trabalho, algumas caracterizações químicas foram realizadas em arenitos asfálticos da região de Piracicaba-SP, Formação Piramboia da Bacia do Paraná, para verificar seu potencial de produção de óleo. Para isso, as amostras obtidas da região foram submetidas a avaliação por termogravimetria, teor de umidade, teor de cinzas, teor de material orgânico por extração, pirólise, análise elementar e fracionamento em coluna. Por TGA observou-se que a 500 C praticamente todo material orgânico presente sofreu pirólise. A extração colaborou para se obter a classificação das amostras quanto ao teor de material orgânico, apresentando entre 4 e 13%, sendo que pelos teores encontrados a amostra AM06 é considerada de alto potencial produtivo, as amostras AM05, AM08 e AM09 são de médio, as amostras AM01, AM02, AM03 e AM07 possuem baixo, mas ainda atrativo, e a AM04 não possui atratividade. Pela avaliação elementar, a relação H/C e O/C dos extratos evidenciaram que algumas amostras estão no processo final da diagênese e outras no início da catagênese, indicando que elas estão no processo inicial de maturação. A avaliação cromatográfica dos extratos revelou que houve perdas de óleo por intemperismo restando majoritariamente compostos de alto peso molecular. O fracionamento permitiu verificar que as amostras AM01, AM06 e AM09 possuem maior quantidade de hidrocarbonetos livres e as amostras AM06 e AM07 e AM09 apresentaram maior teor de óleo. O procedimento de pirólise evidenciou que as amostras AM01, AM05, AM06 e AM09 apresentam maior potencial de geração de óleo, sendo que a faixa encontrada de óleo pirolítico ficou entre 2 e 8%, e através de avaliação por CGAR e CGAR-EM observou-se que ela promove a liberação de quantidades consideráveis de substâncias mais leves do que quando comparados aos extratos obtidos diretamente nas amostras originais. Além de produzir uma série homóloga de hidrocarbonetos parafínicos e olefínicos. A comparação dos produtos de pirólise dos arenitos com os produtos de pirólise de um resíduo de vácuo por CGAR-EM permitiu observar que existe similaridade entre suas composições, onde o processo de pirólise do resíduo de vácuo gera uma série homóloga de hidrocarbonetos entre C10 a C32, similar aos produtos de pirólise da amostra AM09, porém com menor variedade de tipos de hidrocarbonetos. A pré-avaliação da co-pirólise dos arenitos com resíduos plásticos indicou que é possível aumentar a geração de líquidos, porém é necessário mais estudo para afirmações inequívocas. Com base nos resultados das avaliações realizadas podemos concluir que a região apresenta na sua maioria potencial interessante para produção de óleo utilizando pirólise / In this work, some chemical characterizations were held on tar sands in the region of Piracicaba-SP, the South American Piramboia Formation from Paraná basin, to check its oil production potential. For this purpose, samples obtained in the region have undergone through evaluation by thermogravimetry, moisture content, ash content, content of organic material using extraction, pyrolysis process, elemental analysis and fractionation on open chromatography column. By TGA was noted that 500 C almost all-organic material present suffered pyrolysis. Extraction procedure collaborated to achieve the classification of samples regarding the content of organic material, from 4 to 13%, and by levels found at the sample AM06 is considered of high productive potential, the samples AM05, AM08 and AM09 have medium potential, the samples AM01, AM02, AM03 and AM07 have low potential, but still attractive, and the AM04 does not have any potential. By evaluating the atomic relationship between H/C and O/C of the extracts was possible to build up the Van Krevelen diagram and see that some samples are in the final process of diagenesis and other early catagenesis, indicating that they are in the early maturation process. Chromatographic evaluation of the extracts revealed that there were losses of oil by weathering process because it remains mostly high molecular weight compounds on the rocks. The fractionation has shown that samples AM01, AM06 and AM09 have higher free hydrocarbon amount and samples AM06, AM07 and AM09 presented a higher level of oil content. The pyrolysis procedure showed that the samples AM01, AM05, AM06 and AM09 presented greater oil generation potential, pyrolytic oil released from 2 to 8%, and through their evaluation by HRGC and HRGC-MS it was observed that it promotes the release of significant quantities of substances that are lighter than related to the extracts obtained directly in the original samples. In addition, it also promotes a production of homologous series of paraffinic and olefinic hydrocarbons. Comparison of pyrolysis products of sandstones with pyrolysis products of vacuum residue by HRGC-MS allowed to observe that there is similarity between their compositions, which pyrolysis process of vacuum residue generates a homologous series of hydrocarbons between C10 the C32, similar to AM09s pyrolysis products, however with minor variety of types of hydrocarbons. The pre-evaluation of co-pyrolysis of sandstones with plastic waste has indicated that it is possible to increase the liquid generation, but more study is needed for clear statements. Based on the results of the evaluations it can be concluded that the region has an interesting potential for producing oil using pyrolysis process

Neste trabalho, algumas caracterizações químicas foram realizadas em arenitos asfálticos da região de Piracicaba-SP, Formação Piramboia da Bacia do Paraná, para verificar seu potencial de produção de óleo. Para isso, as amostras obtidas da região foram submetidas a avaliação por termogravimetria, teor de umidade, teor de cinzas, teor de material orgânico por extração, pirólise, análise elementar e fracionamento em coluna. Por TGA observou-se que a 500 C praticamente todo material orgânico presente sofreu pirólise. A extração colaborou para se obter a classificação das amostras quanto ao teor de material orgânico, apresentando entre 4 e 13%, sendo que pelos teores encontrados a amostra AM06 é considerada de alto potencial produtivo, as amostras AM05, AM08 e AM09 são de médio, as amostras AM01, AM02, AM03 e AM07 possuem baixo, mas ainda atrativo, e a AM04 não possui atratividade. Pela avaliação elementar, a relação H/C e O/C dos extratos evidenciaram que algumas amostras estão no processo final da diagênese e outras no início da catagênese, indicando que elas estão no processo inicial de maturação. A avaliação cromatográfica dos extratos revelou que houve perdas de óleo por intemperismo restando majoritariamente compostos de alto peso molecular. O fracionamento permitiu verificar que as amostras AM01, AM06 e AM09 possuem maior quantidade de hidrocarbonetos livres e as amostras AM06 e AM07 e AM09 apresentaram maior teor de óleo. O procedimento de pirólise evidenciou que as amostras AM01, AM05, AM06 e AM09 apresentam maior potencial de geração de óleo, sendo que a faixa encontrada de óleo pirolítico ficou entre 2 e 8%, e através de avaliação por CGAR e CGAR-EM observou-se que ela promove a liberação de quantidades consideráveis de substâncias mais leves do que quando comparados aos extratos obtidos diretamente nas amostras originais. Além de produzir uma série homóloga de hidrocarbonetos parafínicos e olefínicos. A comparação dos produtos de pirólise dos arenitos com os produtos de pirólise de um resíduo de vácuo por CGAR-EM permitiu observar que existe similaridade entre suas composições, onde o processo de pirólise do resíduo de vácuo gera uma série homóloga de hidrocarbonetos entre C10 a C32, similar aos produtos de pirólise da amostra AM09, porém com menor variedade de tipos de hidrocarbonetos. A pré-avaliação da co-pirólise dos arenitos com resíduos plásticos indicou que é possível aumentar a geração de líquidos, porém é necessário mais estudo para afirmações inequívocas. Com base nos resultados das avaliações realizadas podemos concluir que a região apresenta na sua maioria potencial interessante para produção de óleo utilizando pirólise / In this work, some chemical characterizations were held on tar sands in the region of Piracicaba-SP, the South American Piramboia Formation from Paraná basin, to check its oil production potential. For this purpose, samples obtained in the region have undergone through evaluation by thermogravimetry, moisture content, ash content, content of organic material using extraction, pyrolysis process, elemental analysis and fractionation on open chromatography column. By TGA was noted that 500 C almost all-organic material present suffered pyrolysis. Extraction procedure collaborated to achieve the classification of samples regarding the content of organic material, from 4 to 13%, and by levels found at the sample AM06 is considered of high productive potential, the samples AM05, AM08 and AM09 have medium potential, the samples AM01, AM02, AM03 and AM07 have low potential, but still attractive, and the AM04 does not have any potential. By evaluating the atomic relationship between H/C and O/C of the extracts was possible to build up the Van Krevelen diagram and see that some samples are in the final process of diagenesis and other early catagenesis, indicating that they are in the early maturation process. Chromatographic evaluation of the extracts revealed that there were losses of oil by weathering process because it remains mostly high molecular weight compounds on the rocks. The fractionation has shown that samples AM01, AM06 and AM09 have higher free hydrocarbon amount and samples AM06, AM07 and AM09 presented a higher level of oil content. The pyrolysis procedure showed that the samples AM01, AM05, AM06 and AM09 presented greater oil generation potential, pyrolytic oil released from 2 to 8%, and through their evaluation by HRGC and HRGC-MS it was observed that it promotes the release of significant quantities of substances that are lighter than related to the extracts obtained directly in the original samples. In addition, it also promotes a production of homologous series of paraffinic and olefinic hydrocarbons. Comparison of pyrolysis products of sandstones with pyrolysis products of vacuum residue by HRGC-MS allowed to observe that there is similarity between their compositions, which pyrolysis process of vacuum residue generates a homologous series of hydrocarbons between C10 the C32, similar to AM09s pyrolysis products, however with minor variety of types of hydrocarbons. The pre-evaluation of co-pyrolysis of sandstones with plastic waste has indicated that it is possible to increase the liquid generation, but more study is needed for clear statements. Based on the results of the evaluations it can be concluded that the region has an interesting potential for producing oil using pyrolysis process

This interdisciplinary project offers new insights into the reclamation history of two of the most controversial and contaminated sites in Canadian history: the Sydney tar ponds and coke ovens and the Athabasca oil sands. It argues that Canada’s natural resource-dependent economy, combined with jurisdictional uncertainty, created a hesitant, fragmentary site cleanup regime, one that left room for different ideas about landscapes to shape and even distort reclamation’s goals and processes. In the absence of substantive reclamation standards and legislation, researchers struggled to accommodate the unique challenges of the oil sands during the 1960s and 1970s. Ambitious goals for reclamation faltered, and even the most successful examples of oil sands reclamation differed significantly from the pre-extraction environment; reclamation was not restoration. Planners envisioned transforming northeastern Alberta into a managed wilderness and recreation nirvana, but few of these plans were realised. The Sydney tar ponds experience suggests that truly successful reclamation cannot exist unless past injustices are fully acknowledged, reparations made, and a more complete narrative of contamination and reclamation constructed through open deliberation. Reclamation, after all, does not repair history; nor can it erase the past. Effective oil sands reclamation, then, requires a reconsideration of the site’s past and an acknowledgement of the perpetuated vulnerabilities and injustices wrought by development and reclamation.

Canada has the second largest proven oil reserves next to Saudi Arabia which is mostly located in Alberta and Saskatchewan but is unconventional heavy oil and bitumen. The tar sands are found at the surface and are mined, yet 80% of the 173 billion barrels of heavy oil and bitumen exist in-situ according to the Canadian Association of Petroleum Producers (CAPP). Two factors inhibit the economic extraction and processing of Canadian heavy oil; its enormous viscosity ranging from 1000 to over 1 million mPa.s and the asphaltene content (high molecular weight molecules containing heavy metals and sulphur). Heavy oil and bitumen were only included in the reserves estimates through the efforts of Canadian enhanced oil recovery (EOR) research. Viscosity reduction is the one common element of in-situ methods of heavy oil recovery with the exception of cold production. Currently, steam assisted gravity drainage (SAGD) and cyclic steam stimulation (CSS) are being used commercially in the field where the oil’s viscosity is reduced by injecting steam. Thermal methods are energy intensive requiring vast volumes of water such that any improvement would be beneficial. Solvent extraction is one alternative requiring no water, the solvent is recoverable and reusable, and depending on the mode of operation the heavy oil is upgraded in-situ. Vapour Extraction (VAPEX) and enhanced solvent extraction (N-SolvTM) are two such methods. VAPEX and N-Solv reduce the bitumen’s viscosity via mass transfer and a combination of mass and heat transfer, respectively. A light hydrocarbon solvent (instead of steam) is injected into an upper horizontal well where the solvent mixes with the heavy oil, reduces its viscosity and allows the oil to drain under gravity to a bottom production well. The idea of using solvents for heavy oil extraction has been around since the 1970s and both VAPEX and N-Solv are patented processes. However, there is still much to be learned about how these processes physically work. Research to date has focused on varying system parameters (including model dimensions, permeability, heavy oil viscosity, solvent type and injection rate, etc.) to observe the effect on oil production from laboratory scale models. Based on an early mass balance model by Butler and Mokrys (1989) and an improvement by Das (1995), molecular diffusion alone cannot account for the produced oil rates observed from laboratory models. Until recently, very little progress had been made towards qualifying and quantifying the mass transfer mechanisms with the exception of the diffusivity of light hydrocarbons in heavy oil. Mass transfer can only be by diffusion and convection. Differentiating and quantifying the contribution of each is complex due to the nature and viscosity of the oil. The goal of this thesis is to investigate the mass transfer mechanisms during the solvent recovery of heavy oil. Quantifying the diffusion of light hydrocarbon solvents has been an active topic of research with limited success since the mid 1990’s. The experimental approach presented here focused on capturing the rate of solvent mass transfer into the bitumen by measuring the bitumen swelling and the butane uptake independently. Unlike early pressure decay methods, the pressure is held constant to not violate the assumed equilibrium solvent concentration at the interfacial boundary condition. The high solubility of solvent in heavy oil complicates the physical modeling because simplifying assumptions of a constant diffusion coefficient, constant density and a quiescent liquid should not be used. The model was developed from first principles to predict the bitumen swelling. The form of the concentration dependent diffusivity was assumed and the diffusivity coefficients initially guessed. The swelling (moving boundary) was fixed by defining a new dimensionless space coordinate and the set of partial differential equations solved using the method of lines. Using the non-linear regression (lsqnonlin) function in MATLAB®, optimising for the difference in predicted and experimentally found bitumen heights and independently validating the result using the solvent uptake, the diffusivity of butane in heavy oil (at 25oC) was found to be Dsb = 4.78 x 10-6ωs + 4.91 x 10-6 cm2/s where ωs is the solvent mass fraction. Diffusion alone has proven inadequate in predicting oil recovery rates from laboratory scale models. It is logical to assume that convective mass transfer plays a role at mixing the solvent and bitumen while draining via gravity through the reservoir porous matrix. Solvent extraction experiments were conducted in etched glass micromodels to observe the pore scale phenomena. The pore scale mechanisms were found to differ depending on how the solvent extraction was operated, with non-condensing (VAPEX) or condensing (N-SolvTM) solvent. Observations show increased convective mixing and an increased rate of interface advancement when the solvent condenses on the bitumen surface. Evidence of trapped butane vapour being mobilised with the draining live oil and a technique of observing solvent extraction using UV light confirm that the draining live oil is on average one pore deep. While the interface appears from a distance to be uniform, at the pore scale it is not. Live oil can drain from one to two pores via capillary displacement mechanisms in one section of the interface and via film flow only in another area (James and Chatzis 2004; James et al. 2008). This work also shows the detrimental impact of having a non-condensable gas present during solvent extraction (James and Chatzis 2008). In summary, this work emphasises the mass transfer and drainage displacement mechanisms of non-condensing (VAPEX) and condensing (N-Solv) solvent extraction methods of heavy oil recovery.

Canada has the second largest proven oil reserves next to Saudi Arabia which is mostly located in Alberta and Saskatchewan but is unconventional heavy oil and bitumen. The tar sands are found at the surface and are mined, yet 80% of the 173 billion barrels of heavy oil and bitumen exist in-situ according to the Canadian Association of Petroleum Producers (CAPP). Two factors inhibit the economic extraction and processing of Canadian heavy oil; its enormous viscosity ranging from 1000 to over 1 million mPa.s and the asphaltene content (high molecular weight molecules containing heavy metals and sulphur). Heavy oil and bitumen were only included in the reserves estimates through the efforts of Canadian enhanced oil recovery (EOR) research. Viscosity reduction is the one common element of in-situ methods of heavy oil recovery with the exception of cold production. Currently, steam assisted gravity drainage (SAGD) and cyclic steam stimulation (CSS) are being used commercially in the field where the oil’s viscosity is reduced by injecting steam. Thermal methods are energy intensive requiring vast volumes of water such that any improvement would be beneficial. Solvent extraction is one alternative requiring no water, the solvent is recoverable and reusable, and depending on the mode of operation the heavy oil is upgraded in-situ. Vapour Extraction (VAPEX) and enhanced solvent extraction (N-SolvTM) are two such methods. VAPEX and N-Solv reduce the bitumen’s viscosity via mass transfer and a combination of mass and heat transfer, respectively. A light hydrocarbon solvent (instead of steam) is injected into an upper horizontal well where the solvent mixes with the heavy oil, reduces its viscosity and allows the oil to drain under gravity to a bottom production well. The idea of using solvents for heavy oil extraction has been around since the 1970s and both VAPEX and N-Solv are patented processes. However, there is still much to be learned about how these processes physically work. Research to date has focused on varying system parameters (including model dimensions, permeability, heavy oil viscosity, solvent type and injection rate, etc.) to observe the effect on oil production from laboratory scale models. Based on an early mass balance model by Butler and Mokrys (1989) and an improvement by Das (1995), molecular diffusion alone cannot account for the produced oil rates observed from laboratory models. Until recently, very little progress had been made towards qualifying and quantifying the mass transfer mechanisms with the exception of the diffusivity of light hydrocarbons in heavy oil. Mass transfer can only be by diffusion and convection. Differentiating and quantifying the contribution of each is complex due to the nature and viscosity of the oil. The goal of this thesis is to investigate the mass transfer mechanisms during the solvent recovery of heavy oil. Quantifying the diffusion of light hydrocarbon solvents has been an active topic of research with limited success since the mid 1990’s. The experimental approach presented here focused on capturing the rate of solvent mass transfer into the bitumen by measuring the bitumen swelling and the butane uptake independently. Unlike early pressure decay methods, the pressure is held constant to not violate the assumed equilibrium solvent concentration at the interfacial boundary condition. The high solubility of solvent in heavy oil complicates the physical modeling because simplifying assumptions of a constant diffusion coefficient, constant density and a quiescent liquid should not be used. The model was developed from first principles to predict the bitumen swelling. The form of the concentration dependent diffusivity was assumed and the diffusivity coefficients initially guessed. The swelling (moving boundary) was fixed by defining a new dimensionless space coordinate and the set of partial differential equations solved using the method of lines. Using the non-linear regression (lsqnonlin) function in MATLAB®, optimising for the difference in predicted and experimentally found bitumen heights and independently validating the result using the solvent uptake, the diffusivity of butane in heavy oil (at 25oC) was found to be Dsb = 4.78 x 10-6ωs + 4.91 x 10-6 cm2/s where ωs is the solvent mass fraction. Diffusion alone has proven inadequate in predicting oil recovery rates from laboratory scale models. It is logical to assume that convective mass transfer plays a role at mixing the solvent and bitumen while draining via gravity through the reservoir porous matrix. Solvent extraction experiments were conducted in etched glass micromodels to observe the pore scale phenomena. The pore scale mechanisms were found to differ depending on how the solvent extraction was operated, with non-condensing (VAPEX) or condensing (N-SolvTM) solvent. Observations show increased convective mixing and an increased rate of interface advancement when the solvent condenses on the bitumen surface. Evidence of trapped butane vapour being mobilised with the draining live oil and a technique of observing solvent extraction using UV light confirm that the draining live oil is on average one pore deep. While the interface appears from a distance to be uniform, at the pore scale it is not. Live oil can drain from one to two pores via capillary displacement mechanisms in one section of the interface and via film flow only in another area (James and Chatzis 2004; James et al. 2008). This work also shows the detrimental impact of having a non-condensable gas present during solvent extraction (James and Chatzis 2008). In summary, this work emphasises the mass transfer and drainage displacement mechanisms of non-condensing (VAPEX) and condensing (N-Solv) solvent extraction methods of heavy oil recovery.