Flow and Heat Transfer Analysis of Natural Gas Hydrate in Metal-Reinforced Composite Insulated Vertical Pipes

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Natural gas extraction activities, including the use of horizontal drilling and hydraulic fracturing, may pose potential health risks to both human and animal populations in close proximity to sites of extraction activity. Because animals may have increased exposure to contaminated water and air as well as increased susceptibility to contaminant exposures compared to nearby humans, animal disease events in communities living near natural gas extraction may provide “sentinel” information useful for human health risk assessment. Community health evaluations as well as health impact assessments (HIAs) of natural gas exploration should therefore consider the inclusion of animal health metrics in their assessment process. We report on a community environmental health survey conducted in an area of active natural gas drilling, which included the collection of health data on 2452 companion and backyard animals residing in 157 randomly-selected households of Washington County, Pennsylvania (USA). There were a total of 127 reported health conditions, most commonly among dogs. When reports from all animals were considered, there were no significant associations between reported health condition and household proximity to natural gas wells. When dogs were analyzed separately, we found an elevated risk of ‘any’ reported health condition in households less than 1km from the nearest gas well (OR = 3.2, 95% CI 1.07–9.7), with dermal conditions being the most common of canine disorders. While these results should be considered hypothesis generating and preliminary, they suggest value in ongoing assessments of pet dogs as well as other animals to better elucidate the health impacts of natural gas extraction on nearby communities.

Concern over natural gas extraction across the U.S. and particularly from the Marcellus Shale formation, which underlies approximately two-thirds of the state of Pennsylvania, has been growing in recent years as natural gas drilling activity has increased. Identifying sources of concern and risk from shale gas development, particularly form the hydraulic fracturing process, is an important step in better understanding sources of uncertainty within the industry. Hydraulic fracturing is a well stimulation technique used in the production of natural gas from shale. While hydraulic fracturing has been in use for decades as a method for oil and gas recovery, recent advances in horizontal drilling techniques and fracturing fluid production have made previously unattainable natural gas reservoirs accessible and economically recoverable. In the years after hydraulic fracturing came into widespread use in Pennsylvania, a large amount of data on flowback characteristics became available due to public and regulatory attention to the process. Chapter 3 examines and analyzes the constituents that make up flowback waters collected from drilling sites in the states of Pennsylvania, New York, and West Virginia. Flowback sampling data were collected from four different sources and compiled into one database with a total of 35,000 entries. Descriptive statistical analysis revealed high concentrations of chlorinated solvents, disinfectants, dissolved metals, organic compounds, radionuclides and TDS. Relative prioritization scores were developed for 58 constituents by dividing observed mean concentrations by the Maximum Contamination Level (MCL) guidelines for drinking water. The following constituents were found to have mean concentrations over 10 times greater than the MCL: Barium, Benzene, Benzo(a)pyrene, Chloride, Dibromochloromethane, Radium, and Thallium. Regulatory inspection and violation reports also provide insight into the impact of natural gas extraction on the surrounding environment, human health, and public safety. Inspection reports for natural gas wells in Pennsylvania were collected from the Pennsylvania DEP Compliance Report from 2000 to 2014. Logistic regression analysis of 215,444 inspection records for 70,043 conventional and unconventional wells was conducted in order to compare the odds of violations occurring under different circumstances. The results in Chapter 4 revealed that, when inspected, conventional wells had 40% higher odds of having a violation, but unconventional wells had higher odds for environmental violations related to waste discharge as well as cementing and casing failures. From there, a list of twelve failure scenarios of concern was developed focusing on specific events that may occur during the shale gas extraction process involving an operational failure or a violation of regulations to identify and prioritize potential failure scenarios for natural gas drilling operations through an elicitation of people who work in the industry. Illegal dumping of flowback water, while rated as the least frequently occurring scenario, was considered the scenario least protected by safety controls and the one of most concern to the general public. In terms of worker safety, the highest concern came from improper or inadequate use of personal protective equipment. While safety guidelines appear to be highly protective regarding PPE usage, inadequate PPE is the most directly witnessed failure scenario. Spills of flowback water due to equipment failure are of concern both in regards to the welfare of the general public and worker safety as they occur more frequently than any other scenario examined in this study. In Chapter 6 of this study, the flowback data collected and the violation and failure scenario analyses conducted are used to develop potential exposure scenarios to wastewater from shale gas development. A risk assessment of occupational and residential exposure pathways to flowback water as carried out. Constituents of concern in flowback water were identified from the previous prioritization. The occupational cancer risk estimate for median concentrations did not exceed the target lifetime cancer risk of 10-6 except for benzo(a)pyrene, which exceeds the target risk level even at the 2.5 percentile value. The upper limit of cancer risk form exposure to heptachlor also exceeds 10-6 in this model. Hazard quotient for barium in the same model exceeds 1 (1.7) and results in a total hazard index of 2. The residential risk assessment revealed that several carcinogenic compounds found in flowback water exceed target limits and significantly increase the risk of an individual developing cancer following chronic exposure. In general, exposure from the dermal pathway posed the greatest risk to human health. Considering non-carcinogenic effects, only barium and thallium exceed target limits, where the ingestion pathway seems to be of greater concern than dermal exposure. Exposure to radionuclides in flowback water, particularly through the inhalation pathway as they volatilize from the water to the air, poses a greater threat to human health than other contaminants examined in this assessment.

Natural gas, as a kind of clean energy, has attracted significant attention in the global market. However, how to ensure the safety and high efficiency in natural gas production becomes a hot research problem in the gas industry. The real-time abnormal status detection of the natural gas well empowers the decision-maker to prevent potentially catastrophic damage and correct unexpected situations. In this paper, we systematically evaluate the 9 state-of-the-art machine learning methods to detect such anomalous status on large sensor data collected from 4 natural gas wells. In addition, we have identified the most important features that can improve anomaly detection performance. The challenges and potential research directions have been discussed. This is the first work to investigate different types of anomaly detection methods on natural gas well sensor data. Our research results provide valuable insights for developing specific anomaly detection systems in the natural gas industry.

ABSTRACTCultivation of native prairie was likely the primary cause of historical declines of grassland bird populations in North America, but the increase in natural gas development may be exacerbating those declines through habitat loss and degradation. We quantified the abundance of grassland songbirds and vegetation structure across a gradient of natural gas well densities to determine the extent to which density and proximity of gas wells influence songbird abundance. In 2008 and 2009, we conducted 1,258 point counts on 105 native grassland parcels (1.6 km2/parcel) at varying distances from natural gas wells and with varying gas well densities (0–25 per 1.6 km2). We found that vegetation structure influenced bird abundance more strongly than natural gas well proximity or density for all but 1 species and that the response of grassland songbirds to natural gas well density and proximity varied among species and regions. Sprague's pipit (Anthus spragueii) and Baird's sparrow (Ammodramus bairdii) abundance was not influenced by natural gas well proximity or density. Grasshopper sparrow (Ammodramus savannarum), McCown's longspur (Rhynchophanes mccownii), and chestnut‐collared longspur (Calcarius ornatus) abundance was lower near gas wells, but both longspur species were also more abundant in areas with greater densities of gas wells. Horned lark (Eremophilus alpestris) abundance increased with well density in our northern study site. Savannah sparrow (Passerculus sandwichensis) abundance was higher near gas wells, but only in areas where well density was ≤9 wells/1.6 km2. We suggest that land managers and industry implement remediation activities that encourage vegetative re‐growth, thus reducing the potential interactive relationship between natural gas development and changes in vegetation structure. © 2014 The Wildlife Society.

More than 15 million Americans are now estimated to live within one mile of a natural gas well drilled since 2000.1 Research has demonstrated that natural gas development results in the emission of pollutants that include suspected developmental toxicants, such as benzene, toluene, and xylenes,2 although few studies have investigated the public health impact of these emissions. In this issue of EHP, researchers report preliminary evidence of an association between two birth defects and a mother’s residential proximity to natural gas wells at the time of birth.3 “Studies like this underscore the need for more representative and comprehensive research on workers and communities to understand their exposures and potential health risks,” says Aubrey Miller, a senior medical advisor at the National Institute of Environmental Health Sciences. Researchers led by Lisa McKenzie at the Colorado School of Public Health estimated exposure to natural gas development for nearly 125,000 Colorado women. They used an “inverse distance weighting” method in which they determined the density of natural gas wells within a 10-mile radius of each mother’s home at the time she gave birth, with greater weighting for wells nearer the home. Then they compared proximity to gas wells between mothers who had adverse birth outcomes—including three types of birth defects, preterm birth, and term low birth weight—and those who did not. Future studies should assess exposure to benzene (inset) among people living near gas wells. Among 59 cases of neural tube defects, prevalence was twice as high among babies of mothers in the highest exposure group—a group of 19 women with more than 125 wells per mile within a 10-mile radius of the home—compared with babies of unexposed mothers. However, there was no evidence that neural tube defects were increased among the 13 babies of mothers classified as having low or medium exposure. Among 1,823 cases of congenital heart defects, prevalence was 30% higher among babies of mothers in the highest exposure group, compared with babies born to unexposed mothers. In contrast to neural tube defects, however, the likelihood of a congenital heart defect increased steadily with increasing exposure. Congenital heart defects are the most common type of birth defect, affecting about 8 of every 1,000 newborns in the United States.4 There was no association observed between proximity to natural gas development and having babies with an oral cleft. In addition, babies whose mothers experienced the highest exposures to natural gas wells were slightly less likely to be born prematurely or at a low birth weight. However, the association between proximity to gas wells and improving birth weights diminished when the researchers accounted for elevation. “Higher elevations are associated with lower birth weights, while most natural gas drilling in Colorado occurs at low elevations,” McKenzie explains. Although low levels of maternal folic acid—a B vitamin found in green leafy vegetables—is an established risk factor for neural tube defects,5 little is known about other environmental factors that may contribute to these birth defects. Two previous studies suggested that maternal exposure to benzene could increase congenital heart defects and neural tube defects.6,7 Another study reported associations between several birth defects in California and increased ambient concentrations of carbon monoxide and ozone.8 “The study certainly raises legitimate concerns, given that there are plausible mechanisms for many of the chemicals that are used in natural gas development,” says Kenneth Spaeth, medical director of the Occupational and Environmental Medicine Center at North Shore University Hospital inNew York, who was not involved in the study. The authors suggest that exposure to benzene from the wells is one such plausible explanation for their findings. However, they did not identify or measure specific pollutants that may have been present at natural gas wells or specific activities occurring at the sites, so it is not possible to know which chemicals and/or other environmental stressors—if any—explain the associations. It’s also possible that some other risk factor not associated with wells, such as mothers’ folic acid consumption or level of prenatal care, could have influenced the results. “Our findings are far from representing a causal effect,” says McKenzie. Her plans for future research include interviews with study mothers to get more information about their pregnancy and place of residence during the first trimester, a critical period for birth defect formation. She also plans to obtain more detailed information on specific activities taking place at well sites during the first trimester.

Natural gas is one of the main fossil fuels, and it is widely used in residential and industrial applications. The demand for natural gas is constantly increasing. However, due to the complex and diverse production environment for gas production, abnormal events that occur during the production of natural gas wells will reduce the gas production of gas wells with sufficient gas reservoirs. At present, detecting abnormal event in gas production mainly relies on engineers according to their own experience. This method is unreliable and requires a lot of manpower. In this paper, the first unsupervised framework for detecting anomalies in natural gas production is proposed. In this framework, a novel data convention method using a time window is proposed to enable the capture of the contextual anomaly. Besides, a low time-complexity and a small memory-requirement method called Isolation Forest is used to build a detector. Moreover, the maximum information coefficient (MIC) based feature selection mechanism reduces the high dimension caused by data convention in order to solve the increasing complexity of natural gas data sets. We apply our framework to several real natural gas well production data set labeled manually. Observations show that this framework increases the accuracy of the detection in the actual gas well production.KeywordsNatural gasAnomaly detectionIsolation forest

Natural gas comprises almost one-fourth of all energy used in the U.S. with growing importance in the global energy mix. New production techniques, including those involving hydraulic fracturing, have enabled access to expanded energy resources and to increased natural gas based power generation, which has been credited with reducing greenhouse gas emissions in the U.S. However, in 2011, the U.S. Environmental Protection Agency introduced new calculation methods for gas wells - based on limited data - causing calculated emissions from natural gas systems to more than double in the U.S. national greenhouse gas inventories for 2009 and 2010 (submitted to the United Nations in 2011 and 2012 respectively). To provide better data about natural gas systems, the American Petroleum Institute (API), in collaboration with America’s Natural Gas Alliance (ANGA), undertook a survey of U.S. natural gas production companies resulting in a rich data base from over 90,000 natural gas wells widely distributed among different producing regions in the U.S. This paper analyzes key findings of the API/ANGA study regarding methane sources pivotal to EPA’s assessment, including completions, workovers and gas well liquids unloading operations. While the API/ANGA findings indicate significant potential overestimations in EPA’s assessment, they also confirm the importance of understanding the key activities and conversion factors that impact the estimation of methane emissions from natural gas production. Although improving the greenhouse gas emission estimation methods may take time, a more nuanced analysis is essential for informing public debate and facilitating decisions on natural gas use and its role in mitigating overall greenhouse gas emissions.

The US natural gas production and consumption has increased 85.5% since 2005 primarily due to the unconventional production methods of horizontal drilling and hydraulic fracturing. Natural gas used as a fuel has a lower greenhouse gas (GHG) footprint than coal and petroleum due to lower Carbon Dioxide (CO2) emissions when combusted. However, the “greener” benefit to natural gas may be consumed by leaks in production and transmission systems. Methane (CH4), the primary hydrocarbon in natural gas, has an estimated Global Warming Potential (GWP) of 28-36 over 100 years, meaning it can absorb 28-36 more energy than CO2 which has a GWP of 1.0. Natural gas well sites are prone to methane emissions, or leaks and irregular gas releases, vented to atmosphere throughout production and transmission. The U.S. Department of Energy (DOE) and the National Energy Technology Laboratory (NETL) has recently granted West Virginia University (WVU) funding under agreement DE-FOA-0002005, to “Advance technologies to mitigate methane emissions and increase the efficiency of the natural gas transportation infrastructure”. As part of this funding WVU was tasked with identifying and quantifying sources of methane emission at unconventional well sites, processing this data, and developing a system to recapture these emissions. A 0-D Simulink model was developed, utilizing standardized methodologies, data from previously conducted studies, as well as collected data from well sites in the Marcellus shale play region. The model was developed to predict emission rates from various components at natural gas well sites as well as the potential to utilize these emissions as fuel for the natural gas powered compressor engines on-site. This model was utilized to run high medium and low cases for 4 identified emission sources, engine size, pneumatic controller count, liquid level production which dictates tank emissions, and compressor packing vent emissions. Due to discrepancies in transient tank emission data, a high and low emission factor for tanks was used, resulting in two sets of 81 executed cases, and 162 unique cases of total site emissions and potential for fuel consumption. Each of the cases were run over 86,400 seconds at a 1 Hz, representative of a full 24 hour day. The fuel consumption offset an average of 557% of fuel consumption on an energy density basis across all 81 cases with the high tank emission factor with a maximum offset of 2334%. The fuel consumption offset was an average of 82.9% for all 81 cases with the low tank emission factor with a maximum offset of 337%. This study highlights flaws in the use of publicly available methane number calculations to determine natural gas’s suitability as an engine fuel as well as the lack of public data for transient liquid storage tank emissions. Research Advisor: Dr. Andrew Nix Committee Chair: Dr. Andrew Nix Committee Members: Dr. Wade Huebsch, Dr. Derek Johnson

Performance analysis of artificial lift systems deployed in natural gas wells: A time-series analytics approach

Background: Little is known about the environmental and public health impact of unconventional natural gas extraction activities, including hydraulic fracturing, that occur near residential areas.Objectives: Our aim was to assess the relationship between household proximity to natural gas wells and reported health symptoms.Methods: We conducted a hypothesis-generating health symptom survey of 492 persons in 180 randomly selected households with ground-fed wells in an area of active natural gas drilling. Gas well proximity for each household was compared with the prevalence and frequency of reported dermal, respiratory, gastrointestinal, cardiovascular, and neurological symptoms.Results: The number of reported health symptoms per person was higher among residents living < 1 km (mean ± SD, 3.27 ± 3.72) compared with > 2 km from the nearest gas well (mean ± SD, 1.60 ± 2.14; p = 0.0002). In a model that adjusted for age, sex, household education, smoking, awareness of environmental risk, work type, and animals in house, reported skin conditions were more common in households < 1 km compared with > 2 km from the nearest gas well (odds ratio = 4.1; 95% CI: 1.4, 12.3; p = 0.01). Upper respiratory symptoms were also more frequently reported in persons living in households < 1 km from gas wells (39%) compared with households 1–2 km or > 2 km from the nearest well (31 and 18%, respectively) (p = 0.004). No equivalent correlation was found between well proximity and other reported groups of respiratory, neurological, cardiovascular, or gastrointestinal conditions.Conclusion: Although these results should be viewed as hypothesis generating, and the population studied was limited to households with a ground-fed water supply, proximity of natural gas wells may be associated with the prevalence of health symptoms including dermal and respiratory conditions in residents living near natural gas extraction activities. Further study of these associations, including the role of specific air and water exposures, is warranted.Citation: Rabinowitz PM, Slizovskiy IB, Lamers V, Trufan SJ, Holford TR, Dziura JD, Peduzzi PN, Kane MJ, Reif JS, Weiss TR, Stowe MH. 2015. Proximity to natural gas wells and reported health status: results of a household survey in Washington County, Pennsylvania. Environ Health Perspect 123:21–26; http://dx.doi.org/10.1289/ehp.1307732

The recent proliferation of oil and natural gas energy development in the Greater Green River Basin of southwest Wyoming has accentuated the need to understand wildlife responses to this development. The location and extent of surface disturbance that is created by oil and natural gas well pad scars are key pieces of information used to assess the effects of energy infrastructure on wildlife populations and habitat. A digital database of oil and natural gas pad scars had previously been generated from 1-meter (m) National Agriculture Imagery Program imagery (NAIP) acquired in 2009 for a 7.7million hectare (ha) (19,026,700 acres) region of southwest Wyoming. Scars included the pad area where wellheads, pumps, and storage facilities reside and the surrounding area that was scraped and denuded of vegetation during the establishment of the pad. Scars containing tanks, compressors, the storage of oil and gas related equipment, and produced-water ponds were also collected on occasion. This report updates the digital database for the five counties of southwest Wyoming (Carbon, Lincoln, Sublette, Sweetwater, Uinta) within the Wyoming Landscape Conservation Initiative (WLCI) study area and for a limited portion of Fremont, Natrona, and Albany Counties using 2012 1-m NAIP imagery and 2012 oil and natural gas well permit information. This report adds pad scars created since 2009, and updates attributes of all pad scars using the 2012 well permit information. These attributes include the origination year of the pad scar, the number of active and inactive wells on or near each pad scar in 2012, and the overall status of the pad scar (active or inactive). The new 2012 database contains 17,404 pad scars of which 15,532 are attributed as oil and natural gas well pads. Digital data are stored as shapefiles projected to the Universal Transverse Mercator (zones 12 and 13) coordinate system. These data are available from the U.S. Geological Survey (USGS) at http://dx.doi.org/10.3133/ds934. 1 Garman, S.L., and McBeth, J.L., 2014, Digital representation of oil and natural gas well pad scars in southwest Wyoming: U.S. Geological Survey Data Series 800, 7 p., http://dx.doi.org/10.3133/ds800. 2 Biewick, L.R.H., and Wilson, A.B., 2014, Energy map of southwestern Wyoming, Part B—Oil and gas, oil shale, uranium, and solar: U.S. Geological Survey Data Series 843, 20 p., 4 pls., http://dx.doi.org/10.3133/ds843. Suggested citation: Garman, S.L., McBeth, J.L., 2015, Digital representation of oil and natural gas well pad scars in southwest Wyoming—2012 update [abs.]: U.S. Geological Survey Data Series 934, http://dx.doi.org/10.3133/ds934. For more information concerning this publication, contact: Center Director, USGS Geosciences and Environmental Change Science Center Box 25046, Mail Stop 980 Denver, CO 80225 (303) 236‒5344 Or visit the Geosciences and Environmental Change Science Center Web site at: http://gec.cr.usgs.gov/

This work aims to explore the overflow characteristics of a vertical H2S‐containing natural gas well. A two‐phase flow model for H2S‐containing natural gas well combining with a transient temperature prediction model was established to simulate the overflow process of a vertical H2S‐containing natural gas well. The model was validated by reproducing the field data of Well Longhui #2. The effects of H2S content, mud displacement, drilling fluid density, geothermal gradient, and reservoir permeability on the overflow characteristics of a vertical H2S‐containing natural gas well were studied and analyzed in this work. Results indicate that bubble, slug, and churn flows constitute the main flow patterns in the whole overflow process. The higher the H2S content is, the more obviously the gas void fraction increases. The phase change position of H2S is closer to the wellhead at lower H2S content. An increase in mud displacement indicates the decreases in overflow time. As drilling fluid density increases, the release position of H2S moves up, and the overflow time and shut‐in casing pressure increase. The initial gas void fraction is higher and the gas invasion volume will be larger in gas reservoirs with higher permeability. As the reservoir permeability increases, the shut‐in casing pressure rises while the overflow time declines. With higher geothermal gradient, the wellbore temperature tends to be higher at the same depth, leading to an increase in the H2S solubility. The gasification starting position is further away from the wellhead at higher geothermal gradient. The results of this work could provide important theoretical basis and technical guidance for drilling engineers to reduce a blowout risk during drilling of H2S‐containing natural gas well.

Tight sandstone gas reservoirs have poor physical properties and percolation capacity, and it takes a long time for gas well pressure change to reach the seepage boundary, which results in large errors in gas well control dynamic reserves calculation and gas production capacity evaluation. Therefore, it is especially important to identify whether the gas well pressure change of tight sandstone reaches the seepage boundary and its exact time. In this paper, a typical single well in the Sulige gas field is taken as the research object. Based on the Blasingame theory for advanced production decline analysis, considering the variable production and pressure of gas well, the material balance pseudo-time is introduced. Through the dimensionless formula conversion, the calculation formula of the time when the pressure change reaches the seepage boundary is derived, and the time curves of different types of gas wells are established, as well as the main control factors affecting the time to reach the boundary of gas wells are analyzed. The result shows that the time to reach the seepage boundary in different types of gas wells in the Sulige gas field is different, which is 200–257 days in Type I gas wells, 446–497 days in Type II and 685–796 days in Type III. The time for gas well to reach the boundary is related to the reservoir porosity, permeability, comprehensive compression coefficient, single well control area, and fluid viscosity. Among which the change of the control area and permeability have a greater impact. The research result lays the foundation for accurately and reasonably evaluating the dynamic reserves and productivity of gas wells in tight sandstone gas reservoirs.KeywordsTight sandstoneGas wellSeepage boundaryPressure changeCalculation method

Natural gas has become a leading source of alternative energy with the advent of techniques to economically extract gas reserves from deep shale formations. Here, we present an assessment of private well water quality in aquifers overlying the Barnett Shale formation of North Texas. We evaluated samples from 100 private drinking water wells using analytical chemistry techniques. Analyses revealed that arsenic, selenium, strontium and total dissolved solids (TDS) exceeded the Environmental Protection Agency's Drinking Water Maximum Contaminant Limit (MCL) in some samples from private water wells located within 3 km of active natural gas wells. Lower levels of arsenic, selenium, strontium, and barium were detected at reference sites outside the Barnett Shale region as well as sites within the Barnett Shale region located more than 3 km from active natural gas wells. Methanol and ethanol were also detected in 29% of samples. Samples exceeding MCL levels were randomly distributed within areas of active natural gas extraction, and the spatial patterns in our data suggest that elevated constituent levels could be due to a variety of factors including mobilization of natural constituents, hydrogeochemical changes from lowering of the water table, or industrial accidents such as faulty gas well casings.