S. Goodarzi, A. Settari, S. Ghaderi, C. Hawkes, Y. Leonenko
Geological storage of CO2 is an option for mitigating global climate change resulting from greenhouse gas emissions. Effective selection, design, and operation of storage sites require reliable models for predicting the response to CO2 injection. This paper revisits preliminary studies of CO2 storage in the Nisku saline aquifer in Alberta, Canada, which were conducted to assess CO2 injectivity, plume migration, and geomechanical response during 50 yr of injection, using model input parameters estimated from data available at the time. The new work presented here involved modeling of CO2 injection using the same tools but with input parameters obtained from data acquired in an evaluation well. The first series of new simulations modeled fluid flow using a commercial black-oil simulator and predicted a lower maximum injection rate (0.80 million t [Mt]/yr [0.88 million tons (Mtons)/yr] compared to 1.0 Mt/yr [1.1 Mtons/yr]) but a CO2 plume width nearly identical with the preliminary prediction (as a consequence of increases in some parameters that offset decreases in other parameters). The second series of new simulations was undertaken using a coupled thermo–hydro–mechanical simulator and predicted ground surface uplift approximately four times less than the preliminary study and (when injecting above the fracture pressure) fracture dimensions several times greater. As before, thermal effects resulting from cool CO2 injection were observed to promote lateral fracture growth in the aquifer and reduce (but not prevent) vertical growth into the cap rock. Use of the evaluation well data in this study enabled a more confident conclusion that injection above the fracturing pressure is not feasible for this site.
{"title":"The effect of site characterization data on injection capacity and cap rock integrity modeling during carbon dioxide storage in the Nisku saline aquifer at the Wabamun Lake area, Canada","authors":"S. Goodarzi, A. Settari, S. Ghaderi, C. Hawkes, Y. Leonenko","doi":"10.1306/eg.06201919005","DOIUrl":"https://doi.org/10.1306/eg.06201919005","url":null,"abstract":"Geological storage of CO2 is an option for mitigating global climate change resulting from greenhouse gas emissions. Effective selection, design, and operation of storage sites require reliable models for predicting the response to CO2 injection. This paper revisits preliminary studies of CO2 storage in the Nisku saline aquifer in Alberta, Canada, which were conducted to assess CO2 injectivity, plume migration, and geomechanical response during 50 yr of injection, using model input parameters estimated from data available at the time. The new work presented here involved modeling of CO2 injection using the same tools but with input parameters obtained from data acquired in an evaluation well. The first series of new simulations modeled fluid flow using a commercial black-oil simulator and predicted a lower maximum injection rate (0.80 million t [Mt]/yr [0.88 million tons (Mtons)/yr] compared to 1.0 Mt/yr [1.1 Mtons/yr]) but a CO2 plume width nearly identical with the preliminary prediction (as a consequence of increases in some parameters that offset decreases in other parameters). The second series of new simulations was undertaken using a coupled thermo–hydro–mechanical simulator and predicted ground surface uplift approximately four times less than the preliminary study and (when injecting above the fracture pressure) fracture dimensions several times greater. As before, thermal effects resulting from cool CO2 injection were observed to promote lateral fracture growth in the aquifer and reduce (but not prevent) vertical growth into the cap rock. Use of the evaluation well data in this study enabled a more confident conclusion that injection above the fracturing pressure is not feasible for this site.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2020-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1306/eg.06201919005","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"44447269","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}
M. Ciotta, D. Peyerl, L. Barrozo, Lucy Gomes Sant´Anna, E. M. Santos, C. Bermann, C. Grohmann, E. Moretto, C. Tassinari
Recent concerns about climate change and greenhouse gas emissions have a clear effect on the energy sector, directly affecting the use of fossil fuels. Companies and countries that depend on these sources of energy (so-called not clean) take actions to search for palliative solutions. The production of atlases of carbon capture and storage (CCS) is one of the collaborative actions that seeks to systematize and organize several aspects involving the use of CCS technologies. This paper focuses on an analytical overview of approaches addressed by five different CCS atlases published by Brazil, the United States, Canada, Mexico, Norway, and South Africa. The five atlases are available for public access; an analytical overview could substantiate the academic and technical decisions related to the future publication of a new atlas for any country and suggests the inclusion of new topics such as social and environmental issues.
{"title":"An overview of carbon capture and storage atlases around the world","authors":"M. Ciotta, D. Peyerl, L. Barrozo, Lucy Gomes Sant´Anna, E. M. Santos, C. Bermann, C. Grohmann, E. Moretto, C. Tassinari","doi":"10.1306/eg.10221919015","DOIUrl":"https://doi.org/10.1306/eg.10221919015","url":null,"abstract":"Recent concerns about climate change and greenhouse gas emissions have a clear effect on the energy sector, directly affecting the use of fossil fuels. Companies and countries that depend on these sources of energy (so-called not clean) take actions to search for palliative solutions. The production of atlases of carbon capture and storage (CCS) is one of the collaborative actions that seeks to systematize and organize several aspects involving the use of CCS technologies. This paper focuses on an analytical overview of approaches addressed by five different CCS atlases published by Brazil, the United States, Canada, Mexico, Norway, and South Africa. The five atlases are available for public access; an analytical overview could substantiate the academic and technical decisions related to the future publication of a new atlas for any country and suggests the inclusion of new topics such as social and environmental issues.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2020-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1306/eg.10221919015","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"48772880","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}
I. Fukai, Laura Keister, P. Ganesh, L. Cumming, W. Fortin, N. Gupta
Carbon capture and storage is a critical technology for ensuring a range of clean energy options are available to meet future energy demand in the United States and abroad. A total of 1079 industrial CO2 emission sources are located in the northeastern United States, where challenging surface and subsurface conditions limit onshore CO2 storage potential. A systematic resource assessment was conducted using industry-standard resource classification methods established by the Society of Petroleum Engineers’ Storage Resources Management System to characterize CO2 storage resources in the middle–northern Atlantic offshore region along the eastern United States. Storable CO2 quantities and storage efficiencies were estimated for Cretaceous- and Jurassic-age sandstone sequences. Regional data integration and analysis were conducted to estimate storable quantities and storage efficiencies using probabilistic methods with static volumetric calculations and dynamic simulations. Offshore storage efficiencies range from 1% to 13%, with regional-scale estimates of 37–403 billion t (Gt) of CO2 classified as prospective storage resources. Dynamic CO2 injection simulation in a middle Cretaceous sequence on the eastern flank of the Great Stone Dome suggests 30–51 million t of CO2 can be stored and contained within the time and pressure constraints assumed for a commercial storage project. The regional Cretaceous and Jurassic plays identified in the offshore study region have prospective storage resources sufficient for long-term storage of CO2 from nearby industrial sources onshore. Continued resource discovery efforts are recommended to assess the development and commerciality of the potential storage identified near the Great Stone Dome.
碳捕获和储存是确保提供一系列清洁能源选择以满足美国和国外未来能源需求的关键技术。美国东北部共有1079个工业二氧化碳排放源，具有挑战性的地表和地下条件限制了陆上二氧化碳储存的潜力。使用石油工程师学会存储资源管理系统建立的行业标准资源分类方法进行了系统的资源评估，以确定沿美国东部大西洋中北部近海地区的二氧化碳存储资源。估计了白垩纪和侏罗纪砂岩序列的可储存二氧化碳量和储存效率。进行了区域数据整合和分析，以使用静态体积计算和动态模拟的概率方法来估计可储存数量和储存效率。海上储存效率从1%到13%不等，区域规模估计有37-4030亿吨二氧化碳被归类为潜在储存资源。Great Stone Dome东侧白垩纪中期序列的动态CO2注入模拟表明，在商业储存项目假设的时间和压力限制内，可以储存和控制3000万至5100万吨CO2。海上研究区域中确定的区域白垩纪和侏罗纪区块具有足够的潜在储存资源，可长期储存陆上附近工业来源的二氧化碳。建议继续进行资源发现工作，以评估在大石穹附近发现的潜在储量的开发和商业性。
{"title":"Carbon dioxide storage resource assessment of Cretaceous- and Jurassic-age sandstones in the Atlantic offshore region of the northeastern United States","authors":"I. Fukai, Laura Keister, P. Ganesh, L. Cumming, W. Fortin, N. Gupta","doi":"10.1306/eg.09261919016","DOIUrl":"https://doi.org/10.1306/eg.09261919016","url":null,"abstract":"Carbon capture and storage is a critical technology for ensuring a range of clean energy options are available to meet future energy demand in the United States and abroad. A total of 1079 industrial CO2 emission sources are located in the northeastern United States, where challenging surface and subsurface conditions limit onshore CO2 storage potential. A systematic resource assessment was conducted using industry-standard resource classification methods established by the Society of Petroleum Engineers’ Storage Resources Management System to characterize CO2 storage resources in the middle–northern Atlantic offshore region along the eastern United States. Storable CO2 quantities and storage efficiencies were estimated for Cretaceous- and Jurassic-age sandstone sequences. Regional data integration and analysis were conducted to estimate storable quantities and storage efficiencies using probabilistic methods with static volumetric calculations and dynamic simulations. Offshore storage efficiencies range from 1% to 13%, with regional-scale estimates of 37–403 billion t (Gt) of CO2 classified as prospective storage resources. Dynamic CO2 injection simulation in a middle Cretaceous sequence on the eastern flank of the Great Stone Dome suggests 30–51 million t of CO2 can be stored and contained within the time and pressure constraints assumed for a commercial storage project. The regional Cretaceous and Jurassic plays identified in the offshore study region have prospective storage resources sufficient for long-term storage of CO2 from nearby industrial sources onshore. Continued resource discovery efforts are recommended to assess the development and commerciality of the potential storage identified near the Great Stone Dome.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2020-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1306/eg.09261919016","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"48930569","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}
Casee Lemons, G. McDaid, K. Smye, J. Acevedo, P. Hennings, D. A. Banerji, B. Scanlon
Subsurface disposal of salt water coproduced with oil and gas has become a critical issue in the United States because of linkages with induced seismicity, as seen in Oklahoma and northcentral Texas. Here, we assess the spatiotemporal and stratigraphic variations of salt-water disposal (SWD) volumes in the Permian Basin. The results of this analysis provide critical input into integrated assessments needed for handling of produced water and for emerging concerns, such as induced seismicity. Wellbore architecture, permits, and disposal volumes were compiled, interpreted for disposal intervals and geologic targets, and summarized at formation, subregion, a 100-mi2 (260-km2) area, and monthly volumes for the years 1978–2016. Geologic targets were interpreted by intersecting the disposal intervals with gridded stratigraphic horizons and by reviewing well logs where available. A total of 30 billion bbl (∼5 trillion L) were disposed into 73 geologic units within 6 subregions via 8201 active SWD wells for 39 yr. Most disposal occurred in the Midland Basin and Central Basin Platform (CBP) over the first 34 yr but shifted from the CBP to the Delaware Basin over the last 5 yr (2011–2016) with the expansion of unconventional oil and gas production. Approximately half of the salt water is disposed above the major unconventional reservoirs into Guadalupian-aged formations, raising concerns of overpressuring and interference with production. Operators are exploring deeper SWD targets; however, proximity to crystalline basement poses concerns for high drilling costs and the potential for induced seismicity by reactivation of deep-seated faults.
{"title":"Spatiotemporal and stratigraphic trends in salt-water disposal practices of the Permian Basin, Texas and New Mexico, United States","authors":"Casee Lemons, G. McDaid, K. Smye, J. Acevedo, P. Hennings, D. A. Banerji, B. Scanlon","doi":"10.1306/eg.06201919002","DOIUrl":"https://doi.org/10.1306/eg.06201919002","url":null,"abstract":"Subsurface disposal of salt water coproduced with oil and gas has become a critical issue in the United States because of linkages with induced seismicity, as seen in Oklahoma and northcentral Texas. Here, we assess the spatiotemporal and stratigraphic variations of salt-water disposal (SWD) volumes in the Permian Basin. The results of this analysis provide critical input into integrated assessments needed for handling of produced water and for emerging concerns, such as induced seismicity. Wellbore architecture, permits, and disposal volumes were compiled, interpreted for disposal intervals and geologic targets, and summarized at formation, subregion, a 100-mi2 (260-km2) area, and monthly volumes for the years 1978–2016. Geologic targets were interpreted by intersecting the disposal intervals with gridded stratigraphic horizons and by reviewing well logs where available. A total of 30 billion bbl (∼5 trillion L) were disposed into 73 geologic units within 6 subregions via 8201 active SWD wells for 39 yr. Most disposal occurred in the Midland Basin and Central Basin Platform (CBP) over the first 34 yr but shifted from the CBP to the Delaware Basin over the last 5 yr (2011–2016) with the expansion of unconventional oil and gas production. Approximately half of the salt water is disposed above the major unconventional reservoirs into Guadalupian-aged formations, raising concerns of overpressuring and interference with production. Operators are exploring deeper SWD targets; however, proximity to crystalline basement poses concerns for high drilling costs and the potential for induced seismicity by reactivation of deep-seated faults.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1306/eg.06201919002","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"42131593","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}
{"title":"A new landslide inventory and improved susceptibility model for northeastern Pennsylvania","authors":"B. Karimi, Michael Yanchuck, Joshua Foust","doi":"10.1306/eg.09191919008","DOIUrl":"https://doi.org/10.1306/eg.09191919008","url":null,"abstract":"","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1306/eg.09191919008","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"46010097","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}
{"title":"Key technologies for green development of the Fuling shale gas field","authors":"Zang Yan-bin, Liu Yaowen","doi":"10.1306/eg.03261919001","DOIUrl":"https://doi.org/10.1306/eg.03261919001","url":null,"abstract":"","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1306/eg.03261919001","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"44939764","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}
J. Gillespie, T. A. Davis, M. Stephens, L. Ball, M. K. Landon
Increased oil and gas production in many areas has led to concerns over the effects these activities may be having on nearby groundwater quality. In this study, we determine the lateral and vertical extent of groundwater with less than 10,000 mg/L total dissolved solids near the Lost Hills–Belridge oil fields in northwestern Kern County, California, and document evidence of impacts by produced water disposal within the Tulare aquifer and overlying alluvium, the primary protected aquifers in the area. The depth at which groundwater salinity surpasses 10,000 mg/L ranges from150m (500 ft) in the northwestern part of the study area to 490–550 m (1600–1800 ft) in the south and east, respectively, as determined by geophysical log analysis and lab analysis of produced water samples. Comparison of logs from replacement wells with logs from their older counterparts shows relatively higher-resistivity intervals representing the vadose zone or fresher groundwater being replaced by intervals with much lower resistivity because of infiltration of brines from surface disposal ponds and injection of brines into disposal wells. The effect of the surface ponds is confined to the alluvial aquifer—the underlying Tulare aquifer is largely protected by a regional clay layer at the base of the alluvium. Sand layers affected by injection of produced waters in nearby disposal wells commonly exhibit log resistivity profiles that change from high resistivity in their upper parts to low resistivity near the base because of stratification by gravity segregation of the denser brines within each affected sand. The effects of produced water injection are mainly evident within the Tulare Formation and can be noted as far as 550 m (1800 ft) from the main group of disposal wells located along the east flank of South Belridge. AUTHORS Janice M. Gillespie ~ California Water Science Center, US Geological Survey (USGS), Sacramento, California; jmgillespie@usgs.gov Jan Gillespie received her B.S. degree in geology from Bemidji State University, Minnesota, her M.S. from South Dakota School of Mines and Technology, and her Ph.D. from the University of Wyoming. Formerly a petroleum and hydrogeology professor in the Department of Geosciences at California State University, Bakersfield, and a petroleum geologist in the San Joaquin Valley of California, she is now a research scientist for the USGS’s regional aquifer monitoring project for California SB4 (the Well Stimulation Bill) delineating protected aquifers near oil producing areas. Tracy A. Davis ~ California Water Science Center, USGS, San Diego, California; tadavis@usgs.gov Tracy Davis received her B.S. degree in earth sciences with emphasis on geochemistry from the University of California, San Diego. She began her career in hydrology at the USGS in 2007 studying groundwater quality of aquifers used for public supply. Her current research focuses on areas of oil and gas development and characterizing risks to California’s groundwate
{"title":"Groundwater salinity and the effects of produced water disposal in the Lost Hills–Belridge oil fields, Kern County, California","authors":"J. Gillespie, T. A. Davis, M. Stephens, L. Ball, M. K. Landon","doi":"10.1306/eg.02271918009","DOIUrl":"https://doi.org/10.1306/eg.02271918009","url":null,"abstract":"Increased oil and gas production in many areas has led to concerns over the effects these activities may be having on nearby groundwater quality. In this study, we determine the lateral and vertical extent of groundwater with less than 10,000 mg/L total dissolved solids near the Lost Hills–Belridge oil fields in northwestern Kern County, California, and document evidence of impacts by produced water disposal within the Tulare aquifer and overlying alluvium, the primary protected aquifers in the area. The depth at which groundwater salinity surpasses 10,000 mg/L ranges from150m (500 ft) in the northwestern part of the study area to 490–550 m (1600–1800 ft) in the south and east, respectively, as determined by geophysical log analysis and lab analysis of produced water samples. Comparison of logs from replacement wells with logs from their older counterparts shows relatively higher-resistivity intervals representing the vadose zone or fresher groundwater being replaced by intervals with much lower resistivity because of infiltration of brines from surface disposal ponds and injection of brines into disposal wells. The effect of the surface ponds is confined to the alluvial aquifer—the underlying Tulare aquifer is largely protected by a regional clay layer at the base of the alluvium. Sand layers affected by injection of produced waters in nearby disposal wells commonly exhibit log resistivity profiles that change from high resistivity in their upper parts to low resistivity near the base because of stratification by gravity segregation of the denser brines within each affected sand. The effects of produced water injection are mainly evident within the Tulare Formation and can be noted as far as 550 m (1800 ft) from the main group of disposal wells located along the east flank of South Belridge. AUTHORS Janice M. Gillespie ~ California Water Science Center, US Geological Survey (USGS), Sacramento, California; jmgillespie@usgs.gov Jan Gillespie received her B.S. degree in geology from Bemidji State University, Minnesota, her M.S. from South Dakota School of Mines and Technology, and her Ph.D. from the University of Wyoming. Formerly a petroleum and hydrogeology professor in the Department of Geosciences at California State University, Bakersfield, and a petroleum geologist in the San Joaquin Valley of California, she is now a research scientist for the USGS’s regional aquifer monitoring project for California SB4 (the Well Stimulation Bill) delineating protected aquifers near oil producing areas. Tracy A. Davis ~ California Water Science Center, USGS, San Diego, California; tadavis@usgs.gov Tracy Davis received her B.S. degree in earth sciences with emphasis on geochemistry from the University of California, San Diego. She began her career in hydrology at the USGS in 2007 studying groundwater quality of aquifers used for public supply. Her current research focuses on areas of oil and gas development and characterizing risks to California’s groundwate","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1306/eg.02271918009","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49551906","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}
{"title":"Interpretation of storage and retrieval major-ion chemistry, with emphasis on significant sulfate and sodium concentrations in the White River watershed, northwestern Nebraska, United States","authors":"J. C. Atkinson","doi":"10.1306/EG.01091918007","DOIUrl":"https://doi.org/10.1306/EG.01091918007","url":null,"abstract":"","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-06-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"41460881","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}
Groundwater is the major source of drinking water in both urban and rural India. Estimation of natural groundwater recharge is essential for the sustainable development of groundwater. Natural recharge was estimated by various methods, such as the water level fluctuation method, water balance method, linear regression model, and nonlinear regression model. The recharge estimates by the water balance method was compared with the recharge obtained from the water level fluctuation method for the study area and found to be in good agreement. Estimation of recharge by the water level fluctuation method is laborious, and envisaging the difficulties in the availability and reliability of data, the water balance method is taken as the standard for developing regression equations in the present study. Simpler linear and nonlinear regression models were developed for the study area to estimate natural recharge by correlating with the water balance model. The models were calibrated with 10-yr data and validated with 5-yr data. The statistical analysis showed that no significant difference exists between the recharge estimate by the water balance method and the two estimates of natural recharges, such as linear regression and nonlinear regression models. The average recharge percentages from the water level fluctuation method, water balance method, linear regression model, and nonlinear regression model are 15.09%, 14.92%, 14.62%, and 14.57%, respectively, for the watershed during the study period. The study proves that regression equations can be efficiently used in recharge computation with proper calibration for ungauged basins, and laborious data-intensive computation methods can be eliminated.
{"title":"Assessment of natural groundwater recharge: A case study of North Chennai Aquifer","authors":"T. Subramanian, M. Abraham","doi":"10.1306/EG.01091918005","DOIUrl":"https://doi.org/10.1306/EG.01091918005","url":null,"abstract":"Groundwater is the major source of drinking water in both urban and rural India. Estimation of natural groundwater recharge is essential for the sustainable development of groundwater. Natural recharge was estimated by various methods, such as the water level fluctuation method, water balance method, linear regression model, and nonlinear regression model. The recharge estimates by the water balance method was compared with the recharge obtained from the water level fluctuation method for the study area and found to be in good agreement. Estimation of recharge by the water level fluctuation method is laborious, and envisaging the difficulties in the availability and reliability of data, the water balance method is taken as the standard for developing regression equations in the present study. Simpler linear and nonlinear regression models were developed for the study area to estimate natural recharge by correlating with the water balance model. The models were calibrated with 10-yr data and validated with 5-yr data. The statistical analysis showed that no significant difference exists between the recharge estimate by the water balance method and the two estimates of natural recharges, such as linear regression and nonlinear regression models. The average recharge percentages from the water level fluctuation method, water balance method, linear regression model, and nonlinear regression model are 15.09%, 14.92%, 14.62%, and 14.57%, respectively, for the watershed during the study period. The study proves that regression equations can be efficiently used in recharge computation with proper calibration for ungauged basins, and laborious data-intensive computation methods can be eliminated.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-06-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1306/EG.01091918005","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"46062192","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 middle Cambrian Maryville–Basal sands in the interval of 4600–4720 ft (1402.1–1438.7 m) in the Kentucky Geological Survey 1 Hanson Aggregates well (i.e., muddy sandstones separated by sandy mudstones) were evaluated to determine effective porosity (φe), clay volume (Vc), and supercritical CO2 storage capacity. Average porosity and permeability measured in core plugs were 8.71% porosity and 2.17 md permeability in the Maryville sand and 10.61% porosity and 15.79 md permeability in the Basal sand. The φe and Vc were calculated from the density log using a multiple-matrix shaly sand model to identify four formation lithologies: muddy sandstone, sandy mudstone, dolomitic mudstone, and dolomitic claystone. Average φe and Vc calculated in the Maryville sand were 8.9% and 35.3%, respectively, and an average of 8.7% and 41.2% in the Basal sand, respectively. Calculated φe exhibits a good match with porosity measured in core plugs. Prior to step-rate testing, static reservoir pressure was 2020 psi (13.9 MPa), representing a 0.435 psi/ft (9.8 kPa/m) hydrostatic gradient, which is consistent with other underpressured reservoirs in Kentucky. The interval fractured at 2698 psi (18.0 MPa), yielding a fracture gradient of 0.581 psi/ft (12.7 kPa/m). Pressure falloff analysis suggests a dual-porosity/dual-permeability reservoir consistent with core data. Estimated 50th percentile supercritical CO2 storage volume supercritical CO2 storage volume, using 7% porosity cutoff for determining net reservoir volume, is 0.538 tons/ac (1.33 t/ha). Thin reservoir sands, low porosity and permeability, and low fracture gradient, however, preclude the Maryville–Basal sands as large-volume deep-saline CO2 storage reservoirs in this area.
{"title":"Porosity and carbon dioxide storage capacity of the Maryville–Basal sands section (middle Cambrian), Southern Appalachian Basin, Kentucky","authors":"J. Bowersox, S. Greb, D. C. Harris","doi":"10.1306/EG.06181818004","DOIUrl":"https://doi.org/10.1306/EG.06181818004","url":null,"abstract":"The middle Cambrian Maryville–Basal sands in the interval of 4600–4720 ft (1402.1–1438.7 m) in the Kentucky Geological Survey 1 Hanson Aggregates well (i.e., muddy sandstones separated by sandy mudstones) were evaluated to determine effective porosity (φe), clay volume (Vc), and supercritical CO2 storage capacity. Average porosity and permeability measured in core plugs were 8.71% porosity and 2.17 md permeability in the Maryville sand and 10.61% porosity and 15.79 md permeability in the Basal sand. The φe and Vc were calculated from the density log using a multiple-matrix shaly sand model to identify four formation lithologies: muddy sandstone, sandy mudstone, dolomitic mudstone, and dolomitic claystone. Average φe and Vc calculated in the Maryville sand were 8.9% and 35.3%, respectively, and an average of 8.7% and 41.2% in the Basal sand, respectively. Calculated φe exhibits a good match with porosity measured in core plugs. Prior to step-rate testing, static reservoir pressure was 2020 psi (13.9 MPa), representing a 0.435 psi/ft (9.8 kPa/m) hydrostatic gradient, which is consistent with other underpressured reservoirs in Kentucky. The interval fractured at 2698 psi (18.0 MPa), yielding a fracture gradient of 0.581 psi/ft (12.7 kPa/m). Pressure falloff analysis suggests a dual-porosity/dual-permeability reservoir consistent with core data. Estimated 50th percentile supercritical CO2 storage volume supercritical CO2 storage volume, using 7% porosity cutoff for determining net reservoir volume, is 0.538 tons/ac (1.33 t/ha). Thin reservoir sands, low porosity and permeability, and low fracture gradient, however, preclude the Maryville–Basal sands as large-volume deep-saline CO2 storage reservoirs in this area.","PeriodicalId":11706,"journal":{"name":"Environmental Geosciences","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"46732588","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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