Pub Date : 2014-08-28DOI: 10.15530/URTEC-2014-1870621
S. Saraji, M. Piri
Summary The ever-growing demand for energy, relatively high price of hydrocarbons, and recent advances in production technologies have brought tight hydrocarbon-bearing reservoirs into attention as a potential source of energy. However, the displacement physics at nano and micro scales and their impact on fluid flow in these rocks is poorly understood. The unconventional rocks, such as shale rocks, are highly heterogeneous, fine-grained, and their representative elementary volume is uncertain. In order to identify flow pathways in the pore network of these rocks, it is essential to characterize nanopores and their connectivity. This can be achieved using high-resolution 3D imaging technique provided by Focused Ion Beam milling and Scanning Electron Microscopy (FIB-SEM). In this technique, a sequence of 2D cross sectional images, spaced evenly through a region of bulk specimen, is acquired. The stack of 2D images is then re-constructed into a 3D digital gray-scale representation of the sample volume. In this study, a reservoir rock sample from a major shale oil reservoir is selected for high-resolution imaging and statistical analysis. Rock specimens, 1 to 2 cm in dimensions, are cut from different locations of the reservoir core from which a high-resolution 2D map and multiple 3D FIB-SEM images are obtained. The digital images are then visualized, segmented, and analyzed to obtain porosity, pore size distribution, pore aspect ratios, spatial distribution of organic/total porosity, and total organic content. We find that the majority of the pores are below 100 nm in radius for this rock. In addition, the total visible porosity and total organic content are in the range of 1 to 2% and 8 to 14 vol.%, respectively. Chemical composition and mineralogy of the samples are also evaluated by Energy Dispersive X-Ray Spectroscopy (EDS) analysis. Furthermore, 3D pore networks are extracted from the FIB-SEM images; pore connectivities are examined; and permeabilies are calculated by solving the Stokes equation numerically using the finite volume method. It is observed that the pore connectivity for these rocks is poor, resulting in low permeabilities ranging from 1 to 6 µD. Finally, the impact of calculated parameters on fluid flow in unconventional rocks is discussed.
{"title":"High-Resolution Three-Dimensional Characterization of Pore Networks in Shale Reservoir Rocks","authors":"S. Saraji, M. Piri","doi":"10.15530/URTEC-2014-1870621","DOIUrl":"https://doi.org/10.15530/URTEC-2014-1870621","url":null,"abstract":"Summary The ever-growing demand for energy, relatively high price of hydrocarbons, and recent advances in production technologies have brought tight hydrocarbon-bearing reservoirs into attention as a potential source of energy. However, the displacement physics at nano and micro scales and their impact on fluid flow in these rocks is poorly understood. The unconventional rocks, such as shale rocks, are highly heterogeneous, fine-grained, and their representative elementary volume is uncertain. In order to identify flow pathways in the pore network of these rocks, it is essential to characterize nanopores and their connectivity. This can be achieved using high-resolution 3D imaging technique provided by Focused Ion Beam milling and Scanning Electron Microscopy (FIB-SEM). In this technique, a sequence of 2D cross sectional images, spaced evenly through a region of bulk specimen, is acquired. The stack of 2D images is then re-constructed into a 3D digital gray-scale representation of the sample volume. In this study, a reservoir rock sample from a major shale oil reservoir is selected for high-resolution imaging and statistical analysis. Rock specimens, 1 to 2 cm in dimensions, are cut from different locations of the reservoir core from which a high-resolution 2D map and multiple 3D FIB-SEM images are obtained. The digital images are then visualized, segmented, and analyzed to obtain porosity, pore size distribution, pore aspect ratios, spatial distribution of organic/total porosity, and total organic content. We find that the majority of the pores are below 100 nm in radius for this rock. In addition, the total visible porosity and total organic content are in the range of 1 to 2% and 8 to 14 vol.%, respectively. Chemical composition and mineralogy of the samples are also evaluated by Energy Dispersive X-Ray Spectroscopy (EDS) analysis. Furthermore, 3D pore networks are extracted from the FIB-SEM images; pore connectivities are examined; and permeabilies are calculated by solving the Stokes equation numerically using the finite volume method. It is observed that the pore connectivity for these rocks is poor, resulting in low permeabilities ranging from 1 to 6 µD. Finally, the impact of calculated parameters on fluid flow in unconventional rocks is discussed.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2014-08-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.15530/URTEC-2014-1870621","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"67382920","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
A. Swift, L. Anovitz, J. Sheets, D. Cole, Susan P Welch, G. Rother
Porosity and permeability are key petrophysical variables that link the thermal, hydrological, geochemical, and geomechanical properties of subsurface formations. The size, shape, distribution, and connectivity of rock pores dictate how fluids migrate into and through micro- and nano-environments, then wet and react with accessible solids. Three representative samples of cap rock from the Eau Claire Formation, the prospective sealing unit that overlies the Mount Simon Sandstone, a potential CO2 storage formation, were interrogated with an array of complementary methods. neutron scattering, backscattered-electron imaging, energy-dispersive spectroscopy, and mercury porosimetry. Results are presented that detail variations between lithologic types in total and connected nano- to microporosity across more than five orders of magnitude. Pore types are identified and then characterized according to presence in each rock type, relative abundance, and surface area of adjacent minerals, pore and pore-throat diameters, and degree of connectivity. We observe a bimodal distribution of porosity as a function of both pore diameter and pore-throat diameter. The contribution of pores at the nano- and microscales to the total and the connected porosity is a distinguishing feature of each lithology observed. Pore:pore-throat ratios at each of these two scales diverge markedly, being almost unity at the nanoscale regime (dominated by illitic clay and micas), and varying by one and a half orders of magnitude at the microscale within a clastic mudstone. Individual minerals, primarily illite and glauconite, have unmistakable pore and pore-throat signatures and contribute disproportionately to connected reactive surface area. The pore types created or evolved during diagenesis mediate profound differences between bulk and pore-network-accessible mineral associations in the mudstones. Results of this study can ultimately be used to inform reactive-transport simulations of effective reactive surface area.
{"title":"Relationship between mineralogy and porosity in seals relevant to geologic CO2 sequestration","authors":"A. Swift, L. Anovitz, J. Sheets, D. Cole, Susan P Welch, G. Rother","doi":"10.1306/EG.03031413012","DOIUrl":"https://doi.org/10.1306/EG.03031413012","url":null,"abstract":"Porosity and permeability are key petrophysical variables that link the thermal, hydrological, geochemical, and geomechanical properties of subsurface formations. The size, shape, distribution, and connectivity of rock pores dictate how fluids migrate into and through micro- and nano-environments, then wet and react with accessible solids. Three representative samples of cap rock from the Eau Claire Formation, the prospective sealing unit that overlies the Mount Simon Sandstone, a potential CO2 storage formation, were interrogated with an array of complementary methods. neutron scattering, backscattered-electron imaging, energy-dispersive spectroscopy, and mercury porosimetry. Results are presented that detail variations between lithologic types in total and connected nano- to microporosity across more than five orders of magnitude. Pore types are identified and then characterized according to presence in each rock type, relative abundance, and surface area of adjacent minerals, pore and pore-throat diameters, and degree of connectivity. We observe a bimodal distribution of porosity as a function of both pore diameter and pore-throat diameter. The contribution of pores at the nano- and microscales to the total and the connected porosity is a distinguishing feature of each lithology observed. Pore:pore-throat ratios at each of these two scales diverge markedly, being almost unity at the nanoscale regime (dominated by illitic clay and micas), and varying by one and a half orders of magnitude at the microscale within a clastic mudstone. Individual minerals, primarily illite and glauconite, have unmistakable pore and pore-throat signatures and contribute disproportionately to connected reactive surface area. The pore types created or evolved during diagenesis mediate profound differences between bulk and pore-network-accessible mineral associations in the mudstones. Results of this study can ultimately be used to inform reactive-transport simulations of effective reactive surface area.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2014-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1306/EG.03031413012","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"66163439","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
geologic sequestration has been recognized as a potential greenhouse gas mitigation strategy. Regional geologic storage in deep saline formations will likely involve the injection of to 100 million metric tons (11 to 110 million tons) of per year using a network of to 50 wells over an area covering sq. miles (). Some of the wells will be injecting into closed volumes because of symmetry, thus providing the bounding case in terms of pressurization and brine efflux. This study describes a parametric analysis of the problem using characteristics typical of the Arches Province in the United States Midwest where Paleozoic rocks form broad arch and platform structures. Two-dimensional radial-cylindrical models developed with the numerical simulator STOMP (Subsurface Transport Over Multiple Phases) are utilized to investigate the impact of well spacing, injection depth, and reservoir characteristics of the injection zone (Mount Simon) and cap rock (Eau Claire) on system performance. Multiple linear regression analysis is then used to develop correlation equations between these design variables and performance metrics, such as cumulative -mass injected and -plume extent. The correlations are tested on new synthetic test sites, and are found to predict the performance metrics quite accurately. These results serve as a proxy simulator to quickly evaluate various design options, instead of having to run time-consuming numerical simulations, and can therefore be applied for developing optimal injection strategies for regional storage in the Arches Province.
地质封存已被认为是一种潜在的温室气体减缓战略。深层盐碱层的区域地质储存可能涉及每年注入1亿公吨(11至1.1亿吨)的天然气，在占地面积为平方英尺的区域内使用50口井组成的网络。英里()。由于对称性，一些井将注入到封闭的体积中，从而提供了加压和盐水射流方面的边界情况。本文利用美国中西部拱省的典型特征对该问题进行了参数化分析，该地区古生代岩石形成了宽阔的拱台结构。利用数值模拟器STOMP (Subsurface Transport Over Multiple Phases)开发的二维径向-圆柱形模型，研究井距、注入深度、注入区(Mount Simon)和盖层(Eau Claire)的储层特征对系统性能的影响。然后使用多元线性回归分析来建立这些设计变量与性能指标(如累积注入质量和烟羽范围)之间的相关方程。相关性在新的合成测试站点上进行了测试，并且发现可以相当准确地预测性能指标。这些结果可以作为代理模拟器来快速评估各种设计方案，而不必进行耗时的数值模拟，因此可以应用于开发arch省区域存储的最佳注入策略。
{"title":"Parametric analysis of CO2 geologic sequestration in closed volumes","authors":"Srikanta Mishra, Y. Oruganti, J. Sminchak","doi":"10.1306/EG.03101413009","DOIUrl":"https://doi.org/10.1306/EG.03101413009","url":null,"abstract":"geologic sequestration has been recognized as a potential greenhouse gas mitigation strategy. Regional geologic storage in deep saline formations will likely involve the injection of to 100 million metric tons (11 to 110 million tons) of per year using a network of to 50 wells over an area covering sq. miles (). Some of the wells will be injecting into closed volumes because of symmetry, thus providing the bounding case in terms of pressurization and brine efflux. This study describes a parametric analysis of the problem using characteristics typical of the Arches Province in the United States Midwest where Paleozoic rocks form broad arch and platform structures. Two-dimensional radial-cylindrical models developed with the numerical simulator STOMP (Subsurface Transport Over Multiple Phases) are utilized to investigate the impact of well spacing, injection depth, and reservoir characteristics of the injection zone (Mount Simon) and cap rock (Eau Claire) on system performance. Multiple linear regression analysis is then used to develop correlation equations between these design variables and performance metrics, such as cumulative -mass injected and -plume extent. The correlations are tested on new synthetic test sites, and are found to predict the performance metrics quite accurately. These results serve as a proxy simulator to quickly evaluate various design options, instead of having to run time-consuming numerical simulations, and can therefore be applied for developing optimal injection strategies for regional storage in the Arches Province.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2014-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"66163619","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
SONAR, historical and aerial photographs, and vibracoring were used to assess the type and thickness distribution of sediments impounded by Gold Ray Dam on the Rogue River in southern Oregon. From these data, a volume of about 400,000 cubic yards () of sediment was determined for the inundated area of the reservoir. Overall, sediment volumes in the impounded part of the reservoir were less than expected. There are three possibilities that may explain the perceived absence of sediment: (1) the gradient of the Rogue River in this stretch is less, and therefore sediment yields are less; (2) the extraction of gravels and/or other impediments upstream decreased the availability of sediments delivered into the reservoir; and/or (3) sediment was deposited by a prograding delta that filled in the inundated area of the floodplain upstream from Gold Ray Dam. The amount of sediment deposited on this inundated floodplain may have been as much as 1,800,000 cubic yards (), bringing the total amount of sediment impounded by Gold Ray Dam to yards (). Applied sedimentology is not only vital to developing a depositional model for the filling of a reservoir, but also providing insights into depositional and erosional changes that will occur upon the removal of a dam. In particular, the processes of delta formation, reoccupation of abandoned channels, and avulsion are paramount in determining sediment accumulation and distribution in reservoirs.
{"title":"Sediment study and removal of Gold Ray Dam on the Rogue River, Jackson County, Oregon","authors":"William S. Elliott, Eric Dittmer, C. L. Lane","doi":"10.1306/EG.07311313006","DOIUrl":"https://doi.org/10.1306/EG.07311313006","url":null,"abstract":"SONAR, historical and aerial photographs, and vibracoring were used to assess the type and thickness distribution of sediments impounded by Gold Ray Dam on the Rogue River in southern Oregon. From these data, a volume of about 400,000 cubic yards () of sediment was determined for the inundated area of the reservoir. Overall, sediment volumes in the impounded part of the reservoir were less than expected. There are three possibilities that may explain the perceived absence of sediment: (1) the gradient of the Rogue River in this stretch is less, and therefore sediment yields are less; (2) the extraction of gravels and/or other impediments upstream decreased the availability of sediments delivered into the reservoir; and/or (3) sediment was deposited by a prograding delta that filled in the inundated area of the floodplain upstream from Gold Ray Dam. The amount of sediment deposited on this inundated floodplain may have been as much as 1,800,000 cubic yards (), bringing the total amount of sediment impounded by Gold Ray Dam to yards (). Applied sedimentology is not only vital to developing a depositional model for the filling of a reservoir, but also providing insights into depositional and erosional changes that will occur upon the removal of a dam. In particular, the processes of delta formation, reoccupation of abandoned channels, and avulsion are paramount in determining sediment accumulation and distribution in reservoirs.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2014-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"66166401","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
We use sediment ages and mercury (Hg) concentrations to estimate past and future concentrations in the South River, Virginia, where Hg was released between 1930 and 1950 from a manufacturing process related to nylon production. In a previous study, along a 40 km (25 mi) reach, samples were collected from 26 of 54 fine-grained deposits that formed in the lee of large wood obstructions in the channel and analyzed for grain size, Hg concentration, and organic content. We also obtained radiometric dates from six deposits. To create a history that reflects the full concentration distribution (which contains concentrations as high as 900 mg/kg [900 ppm]), here, we treat the deposits as a single reservoir exchanging contaminated sediments with the overlying water column, and assume that the total sediment mass in storage and the distribution of sediment ages are time invariant. We use reservoir theory to reconstruct the annual history of Hg concentration on suspended sediment using data from our previous study and new results presented here. Many different reconstructed histories fit our data. To constrain results, we use information from a well-preserved core (and our estimate of the total mass of Hg stored in 2007) to specify the years associated with the peak concentration of 900 mg/kg. Our results indicate that around 850 kg (1874 lb) of Hg was stored in the deposits between 1955 and 1961, compared to only 80 kg (176 lb) today. Simulations of future Hg remediation suggest that 100-yr timescales will be needed for the South River to remove Hg-contaminated sediments from the channel perimeter through natural processes.
{"title":"Reconstructing suspended sediment mercury contamination of a steep, gravel-bed river using reservoir theory","authors":"K. Skalak, J. Pizzuto","doi":"10.1306/EG.08151313007","DOIUrl":"https://doi.org/10.1306/EG.08151313007","url":null,"abstract":"We use sediment ages and mercury (Hg) concentrations to estimate past and future concentrations in the South River, Virginia, where Hg was released between 1930 and 1950 from a manufacturing process related to nylon production. In a previous study, along a 40 km (25 mi) reach, samples were collected from 26 of 54 fine-grained deposits that formed in the lee of large wood obstructions in the channel and analyzed for grain size, Hg concentration, and organic content. We also obtained radiometric dates from six deposits. To create a history that reflects the full concentration distribution (which contains concentrations as high as 900 mg/kg [900 ppm]), here, we treat the deposits as a single reservoir exchanging contaminated sediments with the overlying water column, and assume that the total sediment mass in storage and the distribution of sediment ages are time invariant. We use reservoir theory to reconstruct the annual history of Hg concentration on suspended sediment using data from our previous study and new results presented here. Many different reconstructed histories fit our data. To constrain results, we use information from a well-preserved core (and our estimate of the total mass of Hg stored in 2007) to specify the years associated with the peak concentration of 900 mg/kg. Our results indicate that around 850 kg (1874 lb) of Hg was stored in the deposits between 1955 and 1961, compared to only 80 kg (176 lb) today. Simulations of future Hg remediation suggest that 100-yr timescales will be needed for the South River to remove Hg-contaminated sediments from the channel perimeter through natural processes.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2014-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1306/EG.08151313007","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"66166496","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
P. Meakin, Hai Huang, A. Malthe‐Sørenssen, K. Thøgersen
Shales are becoming the most important source of natural gas in North America, and replacement of coal by natural gas is reducing CO2 emissions and improving air quality. Nevertheless, shale gas is facing strong opposition from environmental nongovernmental organizations. Although these organizations have greatly exaggerated the potential negative environmental impacts of shale gas and shale oil, methane leakage and contamination of groundwater and surface water by flowback and produced waters are serious concerns. These contamination pathways are not unique to shale gas and shale oil, and they are manageable.
{"title":"Shale gas: Opportunities and challenges","authors":"P. Meakin, Hai Huang, A. Malthe‐Sørenssen, K. Thøgersen","doi":"10.1306/EG.05311313005","DOIUrl":"https://doi.org/10.1306/EG.05311313005","url":null,"abstract":"Shales are becoming the most important source of natural gas in North America, and replacement of coal by natural gas is reducing CO2 emissions and improving air quality. Nevertheless, shale gas is facing strong opposition from environmental nongovernmental organizations. Although these organizations have greatly exaggerated the potential negative environmental impacts of shale gas and shale oil, methane leakage and contamination of groundwater and surface water by flowback and produced waters are serious concerns. These contamination pathways are not unique to shale gas and shale oil, and they are manageable.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2013-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1306/EG.05311313005","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"66165010","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
The West Virginia Division of Energy is currently evaluating several deep saline formations in the Appalachian Basin of West Virginia that may be potential carbon dioxide (CO 2) sequestration targets. The Silurian Newburg Sandstone play, developed in the 1960s and 1970s, primarily involved natural-gas production from reservoir rock with well-developed porosity and permeability. High initial pressures encountered in early wells in the Newburg indicated that the overlying Silurian Salina Formation provides a competent seal. Because of the large number of CO 2 point sources in the region and the favorable reservoir properties of the formation (including an estimated 300 bcf of natural-gas production), the Newburg Sandstone was evaluated for the potential geologic storage of CO 2. Within the Newburg play, there are several primary fields separated geographically and geologically by saltwater contacts and dry holes. Previous studies have determined the storage potential within these individual fields. This study shows that the Newburg is more suitable for small-scale injection tests instead of large-scale regional storage operations.
{"title":"Evaluation of the Newburg Sandstone of the Appalachian Basin as a CO2 Geologic Storage Resource","authors":"J. Lewis","doi":"10.1306/EG.08151313008","DOIUrl":"https://doi.org/10.1306/EG.08151313008","url":null,"abstract":"The West Virginia Division of Energy is currently evaluating several deep saline formations in the Appalachian Basin of West Virginia that may be potential carbon dioxide (CO 2) sequestration targets. The Silurian Newburg Sandstone play, developed in the 1960s and 1970s, primarily involved natural-gas production from reservoir rock with well-developed porosity and permeability. High initial pressures encountered in early wells in the Newburg indicated that the overlying Silurian Salina Formation provides a competent seal. Because of the large number of CO 2 point sources in the region and the favorable reservoir properties of the formation (including an estimated 300 bcf of natural-gas production), the Newburg Sandstone was evaluated for the potential geologic storage of CO 2. Within the Newburg play, there are several primary fields separated geographically and geologically by saltwater contacts and dry holes. Previous studies have determined the storage potential within these individual fields. This study shows that the Newburg is more suitable for small-scale injection tests instead of large-scale regional storage operations.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2013-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1306/EG.08151313008","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"66166506","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Geochemical reactions that may occur on CO2 injection into a sandstone formation in Missouri (MO) were investigated by means of geochemical modeling. Five possible injection sites were considered: two in the northwestern part of the state, two in the northeastearn part, and one in the southwestern part. The Geochemist Workbench software was used to investigate solubility trapping and mineral precipitation. Modeling was performed for two periods: an injection period of 10 yr and a postinjection period where the reactions proceeded to equilibrium. The work presented substantial challenges. Among them are uncertainty in kinetic constants for the dissolution and precipitation of minerals on CO2 injection. Model results include equilibrium values for CO2 stored via solubility trapping ranging from 49-g CO2/kg free formation water in Northeast MO to 78-g CO2/kg free formation water for Southwest MO. Mineral trapping is significantly lower, between 2.6- and 18.4-g CO2/kg free formation water. The model shows siderite and dawsonite as the major carbonate minerals formed, in this order. On a volumetric basis, northwest MO sequestration values were slightly greater than those obtained for northeast MO because of the somewhat greater depth and higher injection pressure at the injection target (Lamotte Sandstone) at the northwestern sites. However, the greater thickness of the aquifer for the northeastern sites provided overall greater sequestration capacity. Greene County was altogether unfit for sequestration because of the low total dissolved solids value of the formation water.
采用地球化学模拟的方法研究了美国密苏里州砂岩地层注入二氧化碳后可能发生的地球化学反应。考虑了五个可能的注射地点:两个在该州的西北部，两个在东北部，一个在西南部。利用地球化学工作台软件研究溶解度捕获和矿物沉淀。建模分为两个阶段:注射期为10年，注射后反应达到平衡。这项工作提出了巨大的挑战。其中包括CO2注入过程中矿物溶解和沉淀动力学常数的不确定性。模型结果显示，通过溶解度捕集储存的二氧化碳平衡值从东北地区的49 g CO2/kg游离地层水到西南地区的78 g CO2/kg游离地层水不等。矿物捕集的二氧化碳含量明显较低，在2.6- 18.4 g CO2/kg游离地层水之间。模型显示，菱铁矿和钙镁石是主要的碳酸盐矿物形成顺序。从体积上看，由于注入靶区(拉莫特砂岩)的注入深度和注入压力较大，西北地区的MO固存值略高于东北地区。然而，东北地区的含水层厚度越大，总体上的封存能力就越大。由于地层水的总溶解固形物值较低，格林县完全不适合封存。
{"title":"Geochemical sequestration reactions within the Lamotte Sandstone at five different locations in Missouri","authors":"N. Rono, R. Biagioni, C. Rovey, M. Gutiérrez","doi":"10.1306/EG.01141312010","DOIUrl":"https://doi.org/10.1306/EG.01141312010","url":null,"abstract":"Geochemical reactions that may occur on CO2 injection into a sandstone formation in Missouri (MO) were investigated by means of geochemical modeling. Five possible injection sites were considered: two in the northwestern part of the state, two in the northeastearn part, and one in the southwestern part. The Geochemist Workbench software was used to investigate solubility trapping and mineral precipitation. Modeling was performed for two periods: an injection period of 10 yr and a postinjection period where the reactions proceeded to equilibrium. The work presented substantial challenges. Among them are uncertainty in kinetic constants for the dissolution and precipitation of minerals on CO2 injection. Model results include equilibrium values for CO2 stored via solubility trapping ranging from 49-g CO2/kg free formation water in Northeast MO to 78-g CO2/kg free formation water for Southwest MO. Mineral trapping is significantly lower, between 2.6- and 18.4-g CO2/kg free formation water. The model shows siderite and dawsonite as the major carbonate minerals formed, in this order. On a volumetric basis, northwest MO sequestration values were slightly greater than those obtained for northeast MO because of the somewhat greater depth and higher injection pressure at the injection target (Lamotte Sandstone) at the northwestern sites. However, the greater thickness of the aquifer for the northeastern sites provided overall greater sequestration capacity. Greene County was altogether unfit for sequestration because of the low total dissolved solids value of the formation water.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2013-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"66163413","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Tina L. Roberts-Ashby, M. Stewart, Brandon N. Ashby
The Cretaceous rocks of Florida have been recognized as potentially suitable reservoirs for geologic carbon dioxide (CO2) sequestration. Specifically, the upper member of the Upper Cretaceous Lawson Formation, together with the lower part of the Paleocene Cedar Keys Formation, is presented here as a potential composite CO2 storage reservoir that is mainly composed of porous dolostone sealed by thick anhydrites of the overlying middle Cedar Keys Formation. Many of the porous intervals within the Cedar Keys-Lawson storage reservoir display lateral continuity and have an average porosity range of 20%–30%. The estimated CO2 storage capacity for the reservoir is approximately 97 billion t of CO2, which means the Lawson and Cedar Keys Formations composite reservoir could potentially support CO2 sequestration for hundreds of large-scale power plants in the southeastern United States for their entire 40-yr lifespan. Because most of the previous research on the Lawson Formation is concentrated in north-central and northeastern Florida and southern Georgia, this study further characterizes the formation and its CO2 sequestration potential in south-central and southern Florida.
{"title":"An evaluation of porosity and potential use for carbon dioxide storage in the Upper Cretaceous Lawson Formation and Paleocene Cedar Keys Formation of south-central and southern Florida","authors":"Tina L. Roberts-Ashby, M. Stewart, Brandon N. Ashby","doi":"10.1306/EG.06101313003","DOIUrl":"https://doi.org/10.1306/EG.06101313003","url":null,"abstract":"The Cretaceous rocks of Florida have been recognized as potentially suitable reservoirs for geologic carbon dioxide (CO2) sequestration. Specifically, the upper member of the Upper Cretaceous Lawson Formation, together with the lower part of the Paleocene Cedar Keys Formation, is presented here as a potential composite CO2 storage reservoir that is mainly composed of porous dolostone sealed by thick anhydrites of the overlying middle Cedar Keys Formation. Many of the porous intervals within the Cedar Keys-Lawson storage reservoir display lateral continuity and have an average porosity range of 20%–30%. The estimated CO2 storage capacity for the reservoir is approximately 97 billion t of CO2, which means the Lawson and Cedar Keys Formations composite reservoir could potentially support CO2 sequestration for hundreds of large-scale power plants in the southeastern United States for their entire 40-yr lifespan. Because most of the previous research on the Lawson Formation is concentrated in north-central and northeastern Florida and southern Georgia, this study further characterizes the formation and its CO2 sequestration potential in south-central and southern Florida.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2013-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"66165291","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Dave Goerman, Russell F. Krauss, D. Jayakumar, M. Bernstein
With the exploration and the production of the Marcellus Shale come inevitable unavoidable environmental impacts to the surface of the Earth and associated waters of the United States including wetlands and streams. Environmental impact assessment includes measurement of impacts to aquatic resources, much of which is associated with the production and transportation of Marcellus Shale gas to market. The Commonwealth of Pennsylvania has prepared a rapid resource condition assessment protocol that will be applied to determine the existing quality of Pennsylvania streams to assess impacts to those streams and to quantify appropriate compensatory mitigation for impacts to these water resources. This protocol, advanced by the Bureau of Waterways Engineering and Wetlands of the Pennsylvania Department of Environmental Protection, builds on prior work of the U.S. Army Corps of Engineers Norfolk District and the Unified Stream Methodology of the Virginia Department of Environmental Quality to provide a consistent and rapid condition assessment for projects to obtain water obstruction and encroachment permits, for water quality certifications, as well as general permits that affect waterways, floodways, and/or floodplains.
{"title":"Wetland and stream mitigation: Application of a resource condition assessment protocol in the Pennsylvania Marcellus Shale","authors":"Dave Goerman, Russell F. Krauss, D. Jayakumar, M. Bernstein","doi":"10.1306/EG.01211312012","DOIUrl":"https://doi.org/10.1306/EG.01211312012","url":null,"abstract":"With the exploration and the production of the Marcellus Shale come inevitable unavoidable environmental impacts to the surface of the Earth and associated waters of the United States including wetlands and streams. Environmental impact assessment includes measurement of impacts to aquatic resources, much of which is associated with the production and transportation of Marcellus Shale gas to market. The Commonwealth of Pennsylvania has prepared a rapid resource condition assessment protocol that will be applied to determine the existing quality of Pennsylvania streams to assess impacts to those streams and to quantify appropriate compensatory mitigation for impacts to these water resources. This protocol, advanced by the Bureau of Waterways Engineering and Wetlands of the Pennsylvania Department of Environmental Protection, builds on prior work of the U.S. Army Corps of Engineers Norfolk District and the Unified Stream Methodology of the Virginia Department of Environmental Quality to provide a consistent and rapid condition assessment for projects to obtain water obstruction and encroachment permits, for water quality certifications, as well as general permits that affect waterways, floodways, and/or floodplains.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2013-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1306/EG.01211312012","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"66163467","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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