Gibsonia, United States
Gibsonia, United States

Time filter

Source Type

Azzolina N.A.,CETER Group Inc. | Kreitinger J.P.,U.S. Army | Skorobogatov Y.,Consolidated Edison Company of New York | Shaw R.K.,U.S. Department of Agriculture
Environmental Forensics | Year: 2016

This article summarizes the results from a survey of polycyclic aromatic hydrocarbon (PAH) and metal concentrations measured in surface and subsurface soil samples that were collected from background locations throughout Manhattan, New York, between August 2005 and May 2006. The 95th percentile total 16 US EPA Priority Pollutant PAH concentrations in surface and subsurface soils were 24.8 and 53.1 mg/kg, respectively. Diagnostic PAH source ratios for surface and subsurface soils are presented, which provide plausible bounds for where these ratios would and would not be able to confidently differentiate background soils from soil samples that are impacted by PAH contamination. The 95th percentile concentrations for lead in surface and subsurface soils were 891 and 2,540 mg/kg, respectively, and the 95th percentile concentrations for mercury in surface and subsurface soils were 1.9 and 2.7 mg/kg, respectively. A not-unexpected finding of the study was that most surface soils and all subsurface soils contained a relatively high fraction of anthropogenic carbon, in addition to the presence of historic fill materials such as glass, brick, coal, and slag from more than 400 years of human activity on Manhattan Island. The concentration ranges for PAHs and metals measured in these background soil samples, coupled with the visual observations of historic fill materials in nearly all soil samples, emphasize that soils in Manhattan are altogether different from rural soils and thus warrant a different framework for site management decisions than rural soils. © 2016 Taylor & Francis.


Azzolina N.A.,CETER Group Inc. | Peck W.D.,Energy and Environmental Research Center | Hamling J.A.,Energy and Environmental Research Center | Gorecki C.D.,Energy and Environmental Research Center | And 4 more authors.
International Journal of Greenhouse Gas Control | Year: 2016

This study presents the results of a detailed life cycle analysis of greenhouse gas (GHG) emissions associated with carbon dioxide-enhanced oil recovery (CO2-EOR) where the CO2 is sourced from a coal-fired power plant. This work builds upon previous investigations and integrates new information to provide more plausible ranges for CO2 storage in the reservoir during CO2-EOR. The system model includes three segments: upstream, gate-to-gate, and downstream processes. Our base case model using Ryan-Holmes gas separation technology for the CO2-EOR site determined the emissions from upstream, gate-to-gate, and downstream processes to be 117, 98, and 470 kg CO2e/bbl (CO2 equivalents per barrel of incremental oil produced), respectively, for total emissions of 685 kg CO2e/bbl. However, these emissions are offset by CO2 storage in the reservoir and the resulting displacement credit of U.S. grid electricity, which results in a net life cycle emission factor of 438 kg CO2e/bbl. Therefore, CO2-EOR produces oil with a lower emission factor than conventional oil (~500 kg CO2e/bbl). Optimization scenarios are presented that define a performance envelope based on the CO2 capture rate and net CO2 utilization and suggest that lower emission factors below 300 kg CO2e/bbl are achievable. Based on these results, CO2-EOR where the CO2 is sourced from a coal-fired power plant provides one potential means for addressing the energy demand-climate change conundrum, by simultaneously producing electricity and oil to meet growing energy demand and reducing GHG emissions to abate global warming. © 2016.


Azzolina N.A.,CETER Group Inc. | Neuhauser E.F.,GEI Consultants Inc. | Finn J.T.,GEI Consultants Inc. | Crawford T.R.,New York State Department of Health | And 5 more authors.
Environmental Forensics | Year: 2014

This study characterized organic compounds found in New York State manufactured gas plant (MGP) coal tar vapors using controlled laboratory experiments from four separate MGP sites. In addition, a limited number of deep (0.3-1.2 m above coal tar) and shallow (1.2-2.4 m above coal tar) soil vapor samples were collected above the in situ coal tar source at three of these sites. A total of 29 compounds were consistently detected in the laboratory-generated coal tar vapors at 50°C, whereas 24 compounds were detected at 10°C. The compounds detected in the field sample results were inconsistent with the compounds found in the laboratory-generated samples. Concentrations of compounds in the shallow soil vapor sample were either non-detectable or substantially lower than those found in deeper samples, suggesting attenuation in the vadose zone. Laboratory-generated data at 50°C compared the (% non-aromatic)/(% aromatic) ratio and indicated that this ratio may provide good discrimination between coal tar vapor and common petroleum distillates. © 2014 Copyright © Taylor & Francis Group, LLC.


Azzolina N.A.,CETER Group Inc. | Neuhauser E.F.,GEI Consultants Inc. | Coulombe B.D.,GEI Consultants Inc.
Soil and Sediment Contamination | Year: 2015

The sediment quality triad (SQT) assumes that three measurements (sediment chemistry, laboratory bioassay, and benthic macroinvertebrate counts) comprise an independent assessment of impact, which when integrated using a weight-of-evidence approach provides a comprehensive assessment of risk. An SQT assessment was conducted on 41 sediment samples collected adjacent to a manufactured gas plant site on the freshwater reach of the Hudson River in New York State. The assessment shows that the benthic macroinvertebrate data did not correlate with either sediment or pore water polycyclic aromatic hydrocarbon (PAH) concentrations, nor did these data show consistent relationships to the results of laboratory bioassay testing (Hyalella azteca 28-day survival or biomass). The benthic community across the site and reference areas was comprised of few taxa, all of which were pollution-tolerant organisms with tolerance values greater than or equal to five. Only in significantly impacted sediment samples with PAH concentrations in the thousands of milligrams per kilogram, pore water concentrations above 100 toxic units, and visible non-aqueous phase liquid present in the sample did the benthic macroinvertebrate data show a response. In contrast, sediment and pore water PAH measurements and H. azteca toxicity testing provided consistent interpretation of impact. These results illustrate that benthic macroinvertebrate data may contain less information value and be a more challenging line of evidence to interpret in triad studies conducted in certain ecological settings; in this case, a large-order river with a relatively depauperate benthic community dominated by species tolerant of PAHs. © 2015, Taylor & Francis Group, LLC.


Klapperich R.J.,Energy and Environmental Research Center | Liu G.,Energy and Environmental Research Center | Stepan D.J.,Energy and Environmental Research Center | Jensen M.D.,Energy and Environmental Research Center | And 4 more authors.
Energy Procedia | Year: 2014

The Energy & Environmental Research Center analyzed formation water extraction from carbon dioxide (CO2) storage reservoirs under a project jointly sponsored by the IEA Greenhouse Gas R&D Programme and the U.S. Department of Energy. This paper presents some of the results of this project, which included a study of the impacts of formation water extraction on CO2 storage as well as the potential for the beneficial use of the extracted water. This paper also identifies several beneficial use options for the extracted water and candidate treatment technologies to achieve the water quality required by these end uses.


Azzolina N.A.,CETER Group Inc. | Azzolina N.A.,Carnegie Mellon University | Nakles D.V.,CETER Group Inc. | Nakles D.V.,Carnegie Mellon University | And 5 more authors.
International Journal of Greenhouse Gas Control | Year: 2015

This work analyzes a database of 31 existing CO2 enhanced oil recovery (EOR) projects that was compiled for the estimation of oil reserves to better understand the CO2 retention, incremental oil recovery, and net CO2 utilization for these oil fields. The measured data begin at the start date of the CO2 flood and extend through the year 2007. Cumulative CO2 retention (in the formation), incremental oil recovery factors, and net CO2 utilization factors were calculated for each of the sites. To express all site data on a common dimensionless scale, the data were extrapolated to 300% cumulative hydrocarbon pore volume (HCPV) by fitting nonlinear functions. Summary statistics were then calculated from 0% to 300% HCPV. Across all 31 sites, the 10th, 50th (median), and 90th percentile values for the three factors at 300% HCPV were: CO2 retention: 23.1%, 48.3%, and 61.8% retained; incremental oil recovery: 5.3%, 12.2%, and 21.5% of OOIP (original oil in place); and net CO2 utilization: 4.8, 8.7, and 10.5 Mscf/STB (stock-tank barrel). This work employs a novel approach that incorporates nonlinear functions to quantify uncertainty in the estimated values as a function of HCPV and to describe the shape of the CO2 retention or incremental oil recovery response with a handful of parameters, providing insight into the behavior of the reservoir across the entire timeline of the CO2 flood. These nonlinear curve fits are focused on statistical inference - i.e., what is the likely outcome and uncertainty ranges for CO2 retention, incremental oil recovery, and net CO2 utilization given the historical data from the 31 CO2 EOR sites? However, the approach described in this work also provides useful information for prediction - i.e., given a set of inputs from another site with similar geology, what are plausible ranges in outcomes for each of these factors? Consequently, the results of this work can be used to estimate the potential range of expected performance for similar candidate oil fields that are not currently undergoing CO2 injection, including estimates of the associated CO2 storage potential of these candidate fields. The results of this work allow estimation of CO2 storage capacity in CO2-EOR operations with various degrees of confidence. The sites in the dataset reflect water - alternating gas CO2 floods - all within the continental United States and heavily dominated by the West Texas carbonate floods. Other floods outside of this region, where the data were available, are also included in this study (i.e., the Rocky Mountain region and the State of Oklahoma). © 2015 Elsevier Ltd.


Siegel D.I.,Syracuse University | Azzolina N.A.,CETER Group Inc. | Smith B.J.,United Road Services | Perry A.E.,AECOM Technology Corporation | Bothun R.L.,AECOM Technology Corporation
Environmental Science and Technology | Year: 2015

Recent studies in northeastern Pennsylvania report higher concentrations of dissolved methane in domestic water wells associated with proximity to nearby gas-producing wells [ Osborn et al. Proc. Natl. Acad. Sci. U. S. A. 2011, 108, 8172 ] and [ Jackson et al. Proc. Natl. Acad. Sci. U. S. A., 2013, 110, 11250 ]. We test this possible association by using Chesapeake Energys baseline data set of over 11,300 dissolved methane analyses from domestic water wells, densely arrayed in Bradford and nearby counties (Pennsylvania), and near 661 pre-existing oil and gas wells. The majority of these, 92%, were unconventional wells, drilled with horizontal legs and hydraulically fractured. Our data set is hundreds of times larger than data sets used in prior studies. In contrast to prior findings, we found no statistically significant relationship between dissolved methane concentrations in groundwater from domestic water wells and proximity to pre-existing oil or gas wells. Previous analyses used small sample sets compared to the population of domestic wells available, which may explain the difference in prior findings compared to ours. © 2015 American Chemical Society.


PubMed | Syracuse University, AECOM Technology Corporation, CETER Group Inc. and United Road Services
Type: Journal Article | Journal: Environmental science & technology | Year: 2015

Recent studies in northeastern Pennsylvania report higher concentrations of dissolved methane in domestic water wells associated with proximity to nearby gas-producing wells [ Osborn et al. Proc. Natl. Acad. Sci. U. S. A. 2011 , 108 , 8172 ] and [ Jackson et al. Proc. Natl. Acad. Sci. U. S. A. , 2013 , 110 , 11250 ]. We test this possible association by using Chesapeake Energys baseline data set of over 11,300 dissolved methane analyses from domestic water wells, densely arrayed in Bradford and nearby counties (Pennsylvania), and near 661 pre-existing oil and gas wells. The majority of these, 92%, were unconventional wells, drilled with horizontal legs and hydraulically fractured. Our data set is hundreds of times larger than data sets used in prior studies. In contrast to prior findings, we found no statistically significant relationship between dissolved methane concentrations in groundwater from domestic water wells and proximity to pre-existing oil or gas wells. Previous analyses used small sample sets compared to the population of domestic wells available, which may explain the difference in prior findings compared to ours.

Loading CETER Group Inc. collaborators
Loading CETER Group Inc. collaborators