bluuebunny/crossref_metadata_2025_split huggingface dataset:
Partition Behavior of Polycyclic Aromatic Hydrocarbons Between Aged Coal Tar and Water
Authors: Liu Lihua , Endo Satoshi , Eberhardt Christina , Grathwohl Peter , Schmidt Torsten C. 
Published: March 2009

Abstract
Coal tar aged in a large-scale, artificial aquifer experiment for five years was subsequently investigated for leaching behavior of polycyclic aromatic hydrocarbons (PAHs). After five years, the initially liquid coal tar had solidified and formed segregated particles with a grain size similar to that of the sandy aquifer material. The composition of the aged coal tar (ACT) with regard to PAHs was remarkably different from that of the original bulk coal tar (BCT), because most of the low-molecular-weight compounds had been depleted. Equilibrium aqueous-phase concentrations of 17 PAHs leaching from the aquifer material containing the ACT were measured from consecutive equilibration steps at increasing temperatures of between 25 and 100C using accelerated solvent extraction. The results showed 2-to 5,000-fold lower concentrations than those from BCT, indicating dramatic changes of dissolution behavior of PAHs from coal tar after the five-year aging period. Predictions based on Raoult's law with the subcooled liquid solubilities substantially overestimated the equilibrium aqueous-phase concentrations of the PAHs from ACT, whereas the estimations were reasonable if the solid solubilities were employed instead. The enthalpies of phase transfer from ACT to water were determined based on the van't Hoff equation. The resulting values agreed with the dissolution enthalpies of pure solid rather than subcooled liquid PAHs.
Skimmer Capacity for Viscous Oil Spills
Authors: Moxness Vidar Weidemann , Gåseidnes Knut , Asheim Harald 
Published: March 2009

Abstract
The classical formulae for oil skimmer capacity consider inertia but neglects viscosity. The current paper includes viscous losses and distinguishes between inertial, intermediate and viscid regimes. The distinction is based on a dimensionless number; called the Goose number.
Experiments have been performed using viscous gear-oil floating on tap water. Measured skimmer rates corresponded reasonably to numerical estimates, and to the analytical approximation valid within the viscid regime. Classical formulae were found to be valid within the inertial regime, but were much off for the experimental conditions considered.
Air Quality Requirements on Oil and Gas Exploration and Production Operations in a Highly Regulated Area: A Southern California E&P Operator's Story
Authors: Shemaria Mark , Yorke Judy 
Published: March 2009

Abstract
There is growing concern throughout the world regarding the impact of oil and gas operations on air quality at both the global and local levels. In Southern California, Oil and Gas Exploration and Production Operators face a number of challenges to be able to manage their production operations and comply in a highly controlled regulatory climate. Some of the most stringent requirements are rules that limit emissions to the atmosphere. Source specific rules require operators to monitor and control both point source (stack/vents) and fugitive sources of emissions. Permitting, rule requirements, and recording keeping all mold the way operators conduct their production operations.
This paper provides an overview of the requirements on operators that control the sources of emissions from stationary sources in Southern California. Discussion on emissions, control devices, permitting requirements and quantification are also covered in this paper. We shall review how one operator responded to changes in the regulations and operating conditions, and was able to modify their process to greatly reduce emissions.
Engineered Wetland Design for Produced-Water Treatment
Authors: Davis Brian M. , Wallace Scott D. , Wilson Roberta 
Published: March 2009

Abstract
Engineered wetlands are a promising technology for treatment of oil field and gas field produced water. The engineering optimization of natural treatment processes, adapted from chemical engineering reactor design principles, shows that engineered wetlands are a viable alternative to mechanical produced water treatment systems.
Engineered wetlands incorporate a subsurface flow gravel bed reactor, lined with an impermeable liner and equipped with an aeration system to enhance oxygen delivery. Design parameters include biodegradation rate coefficients for BOD and individual organic compounds, produced water flowrate, temperature, and influent and required effluent concentrations.
An oil and gas company in the Caspian region is seeking to utilize engineered wetlands for treatment of oil field and gas field produced water. The oil field produced water concentrations are high in total dissolved solids (43,048 mg/L), BOD (14,693 mg/L), and oil and grease (1,213 mg/L) and moderately high in total BTEX (benzene, toluene, ethylbenzene, and xylenes; 3.067 mg/L). The gas field produced water concentrations are moderately high in total dissolved solids (16,110 mg/L), BOD (9,910 mg/L), and oil and grease (557 mg/L) and high in total BTEX (12.393 mg/L). Pilot-scale engineered wetland treatment systems have been designed on a flowrate basis of 100 cubic meters per day using the first-order kinetic mass reaction model recently published by Kadlec and Wallace (2008). This model utilizes a modified tanks-in-series number that accounts for both hydraulic effects and weathering effects in the biodegradation rate. Hydraulic effects are due to dispersion in the saturated gravel bed. Variation in the biodegradation rate is due to rapid biodegradation at the upgradient portion of the engineered wetland, where short chain/low molecular weight organics are oxidized at rapid rates, and slower biodegradation at the downgradient portion of the engineered wetland, where long chain/higher molecular weight organics are oxidized at lower rates. This advanced design process, combined with BOD surface area loading criteria, enables the optimization of engineered wetland design for produced water treatment.
H2S: A Survivor's Story
Authors: Simpson Charles A. 
Published: March 2009

Abstract
The author tells the story of his near fatal exposure to hydrogen sulfide (H2S) while stimulating an oil well in Waynesboro, Mississippi. He describes how poor management decisions, inadequate training, and failure to exercise Stop Work Authority factored into the accident. Lessoned Learned include:
Assure all personnel are committed to working safely. Provide detailed safety training. Advise personnel of all hazards associated with a job. Follow established safe work practices. Provide adequate equipment to deal with hazards. Develop a job site–specific emergency response plan. Support and use Stop Work Authority.
Systems Approach and Quantitative Decision Tools for Technology Selection in Environmentally Friendly Drilling
Authors: Yu O.-Y. , Guikema S. D. , Bickel J. E. , Briaud J.-L. , Burnett D. B. 
Published: March 2009

Abstract
One of the petroleum industry's goals is to reduce the environmental impact of oil and gas operations in environmentally sensitive areas. To achieve this, a number of Environmentally Friendly Drilling (EFD) technologies have been developed to varying degrees but few have been integrated into a field demonstrable drilling system (i.e., combination of technologies) compatible with ecologically sensitive or off-limits areas.
The main purpose of this paper is to present a decision-analytic technology selection process. The proposed method is based on a systems analysis that can be used for integrating current and new EFD technologies into an optimal EFD system. The system draws upon a large number of technologies (more than 100) identified by a government-industry joint venture studying low impact operations in sensitive ecological areas. In order to provide flexibility to the user, a small number of systems (1~5) are proposed for a given site, instead of a single best system. An optimization scheme is suggested based on a combination of multi-attribute utility theory and exhaustively enumerating all possible technology combinations to provide a quantitative rationale and suggest the best set of systems according to a set of criteria, with the relative importance of the different criteria defined by the decision-maker. This methodology is designed to help decision-makers select an optimal drilling system for a given site in order to minimize environmental impact and maximize profit at that specific site.
An application of the proposed approach is described by conducting a case study in Green Lake at McFaddin, TX; some of the difficulties in using this approach in practice are also discussed. This paper describes the results of the case study which provided a more logical and comprehensive approach that maximized the economic and environmental goals of both the landowner and the oil company leaseholder.
Quantifying Process Safety with Expert Judgment
Authors: Sutton Ian 
Published: March 2009

Abstract
One of the most effective means of improving process safety management (PSM) performance on offshore and onshore processing facilities is to identify the plausible hazards, and then to either remove those hazards, or to engineer the system such that it is inherently safe. Unfortunately, the disciplines of safety and environmental engineering are not as objective or rigorous as other types of engineering because the identification of hazards, along with estimates as to their consequences and likelihoods, relies largely on experience and expert judgment. Moreover, other subjective factors - such as whether a release affects members of the public - come into play; yet such factors cannot be easily incorporated into an engineering or operations policy.
For example, an assessment of the risk to do with a potential fire requires judgment regarding:
The location of a leak; Its size; Its likelihood; Its duration; The effectiveness of operator response; and The rigor with which local regulations are enforced.
The responses provided to each of the above factors will dramatically affect the nature of the risk analysis and the resulting recommendations. Yet each answer relies heavily on judgment and experience.
This paper demonstrates how a very large system of spreadsheets can be used to organize expert knowledge around the well-established categories of process safety management such as management of change, incident investigation and employee culture. Each spreadsheet contains multiple questions, each of which is scored from 0 (bad) to 4 (excellent). In this regard, the system goes beyond the traditional checklist audit approach to assessing PSM — it allows for judgment, not just simple "Yes/No" answers. Supplementing the questions are guidance statements written by the appropriate expert(s). The scores roll up to provide management with an objective assessment as to the status of their process safety management program. The system also identifies which specific management areas are functioning well, and which are not.
These results thus help managers improve safety and environmental results in an objective manner by moving away from hunches, un-substantiated opinions and also from quantitative assessments that are built on questionable failure rate data. The results also provide management with guidance as to where to invest resources in order to improve performance most effectively.
Integrating Social Responsibility into the Health, Environment, and Safety Management System (HESMS)
Authors: Ortega Carolina , Ravishankar Krish , Fernando de Angulo Luis 
Published: March 2009

Abstract
Integrating Social Responsibility (SR) into an established management system helps to overcome commonly faced challenges in the SR field: especially those related to accountability, measurement and long-term sustainability of SR programs. This paper presents Occidental Petroleum Corporation's approach to implementing SR in its oil and gas business units. It addresses the development of a SR Standard and utilization of a Health, Environment and Safety (HES) management system to efficiently manage and continuously improve the SR program.
Increased Operational Safety and Efficiency with Managed Pressure Drilling
Authors: Grayson Brian 
Published: March 2009

ABSTRACT
Planning has always been essential to create and maintain a safe drilling environment. Safety and environmental concerns are now a larger concern than ever before with the increasing difficulty in drilling projects and the more sensitive environmental areas that wells are being constructed and produced from. This is increasingly becoming a bigger concern with the potential opening of new offshore and onshore areas that have been until recently not accessible to exploration and production primarily from an environmental aspect or proximity to large population centers.
Using an open-to-the-atmosphere fluids returns system when drilling with hazardous, or any, drilling fluids or into formations that could potentially have high concentrations of toxic gases or unknown shallow geo hazards, raises significant health, safety and environmental concerns. These hazards along with the complex wells with tight margins between pore pressure and fracture gradient increase risk to an intolerable level. Of course these issues have to be considered while still maintaining the same constraints of minimizing cost and enhancing drilling performance.
Managed Pressure Drilling (MPD) is a methodology that has been developed and practiced over the past few years with great success to aid in the mitigation of known and unknown drilling hazards. MPD utilizes conventional techniques and technologies to create a closed and pressurizable drilling fluids returns system that works to better predict and control the reactions of the formation to the drilling program. Planning a well with MPD as an option will preserve the same conventional drilling methods and controls but give knowledge and the technology to better mitigate against hazards and more securely maintain well control.
This paper will describe the processes and variations, and the technologies used with MPD. It will further detail how MPD techniques are applied to a variety of operations to increase both drilling efficiencies and the overall safety of the operation.
Best Management Practices for Blasting and Painting Offshore Facilities
Authors: Satterlee Kent , Kuehn Robert B. , Guy Carl A. , Johnson Carliane D. 
Published: March 2009

Abstract
Offshore oil and gas facilities must be periodically inspected and maintained to assure structural integrity and minimize pollution and safety risks. This involves periodic surface preparation and coating activities. In U.S. waters, the United States Coast Guard (USCG) prohibits the discharge of garbage from any fixed or floating platform (33 Code of Federal Regulations 151.73), including discharges related to maintenance activities. In 2007, the American Petroleum Institute prepared Bulletin 91 Planning and Conducting Surface Preparations and Coating Operations for Oil and Natural Gas Drilling and Production Facilities in the Marine Environment to meet the intent of MARPOL 73/78 (International Convention for the Prevention of Pollution from Ships), specifically Annex V, which regulates the discharge of garbage. USCG has specifically requested, however, that industry develop performance-based practices and quantifiable measurements for discharges related to surface preparation and coating activities.
In late 2007, offshore companies began using a Best Management Practices plan template that allows companies to establish—within a consistent framework—practices and procedures to minimize the discharge of spent abrasives and paint overspray to the surrounding waters to the maximum extent practicable. Plans that are developed based on this template meet the requirements of the U.S. Environmental Protection Agency Region 6 National Pollutant Discharge Elimination System Offshore general permit.
In May 2008, the Offshore Operators Committee hosted a workshop to better understand current practices conducted on offshore facilities. The workshop was the first step of a "due diligence" process to ensure that USCG concerns do not adversely affect ongoing operations in the Gulf of Mexico. Subsequent steps will build upon this by obtaining information about abrasives and coatings currently being used by industry and then developing a recommended practice to prevent their discharges into surrounding waters to the maximum extent practicable.
This paper describes the development of practices at Shell that are intended to meet the intent of MARPOL from a regulatory and industry standpoint. It provides information on surface preparation methods and coating types that have been used to reduce discharges, emissions, and wastes, as well as reduce costs and enhance the safety of offshore workers.
Injury Risk Among Oil and Gas Extraction Workers by Company Type and Size
Authors: Hill R. D. , Conway G. A. , Somervell P. D. 
Published: March 2009

Abstract

Introduction
The oil and gas extraction industry employs 400,000 workers. During 2003-2007, the fatality rate among oil and gas extraction workers was nearly eight times that for all U.S. workers (30.0 vs. 4.0 per 100,000 workers). Occupational fatality rates among these workers are high, and vary with the level of drilling activity. In addition, injury risk may be associated with other factors, such as company type and size. The purpose of this study was to characterize the differences in risk of fatal injury according to company type and size during 2003–2007.

Methods
Data from the Bureau of Labor Statistics, Census of Fatal Occupational Injuries were utilized for this study. Company size was defined as small (fewer than 20 workers); medium (20–99 workers), and large (100 or more). For company type, companies were characterized as operators, drilling contractors and service companies. Relative risks were calculated to compare occupational fatality rates among different groups of companies.

Results
Workers employed by small companies were three and five times as likely to suffer a fatal injury compared with workers from medium and large companies, respectively. There were also substantial differences between company types, independent of company size. Workers employed by drilling contractors were most at risk of fatal injury. The fatality rate in drilling companies was three times that for operators, and 1.5 times the rate among service companies. The size effect held true within each company type; the company type effect held true among small companies.

Conclusions
The workers at highest risk were those employed by small companies, particularly small drilling contractors. These findings may help safety professionals develop workplace solutions and conduct outreach and training for the industry's most at-risk workers.
Microbial Degradation of Benzyldimethyl Hexadecylammonium Chloride (BDHAC) Used in Oilfield Chemical Formulations
Authors: Bassey D. E. , Grigson S. J. W. , Mitchell W. J. 
Published: March 2009

Abstract
Following enrichment in its presence, four strains of bacteria, isolated from marine sediments, were shown to degrade the quaternary ammonium surfactant Benzyldimethyl Hexadecylammonium Chloride (BDHAC) in a minimal salts medium. The bacteria were identified by 16S rDNA sequencing, were shown to belong to several genera and were identified as Bacillus niabensis, Bacillus subtilis, Thalassospira sp, and Sporosarcina sp. Initial investigations have shown that the bacteria are capable of degrading BDHAC when it is present at concentrations in the range 2 – 4 mg/ml. In media containing BDHAC, up to 90% was degraded within 7 days, but this supported only limited growth of the bacteria. Preliminary analysis of samples after degradation experiment by ESI-MS/MS produced a peak with a parent-daughter ion transition of 136.0→91.0, corresponding to N, N-dimethylbenzylamine. The presence of this potential metabolite suggests the cleavage of the C alkyl-N bond as a step in BDHAC catabolism.
Process Check: What Is Driving Alternatives Analysis in Environmental-Impact Assessment for Major Capital Projects?
Authors: Khalsa A. S. , Boyd H. , Slocum D. 
Published: March 2009

Abstract
Application of a companywide environmental management system (EMS) and guidelines is a best practice for environmental performance assurance in the oil and gas industry because it helps to institutionalize environmental protection efforts. While implementation of these systems and guidelines is a very positive step toward promoting sustainability and environmental stewardship, it sometimes fall short of fulfilling this goal with regards to designing and developing the most sustainable new projects possible. A key to this shortcoming is the alternatives analysis element of the Environmental Impact Assessment (EIA) process. The EIA process is typically a company's first in-depth look at environmental components of a project and proper application can make the difference in defining the sustainability of development projects.
EIA is most valuable when used not only to help identify, predict, evaluate and mitigate potential impacts of proposed developments upstream in the decision-making process, but to support a robust decision-making process about the basic design and scope of the project. Environmental and social impacts of projects tend to be readily predictable, but unfortunately not readily quantifiable. Therefore, decision making tools used in alternatives analysis may not adequately reflect the external environmental and social costs associated with a given project. For this reason, economic and technological considerations are often unintentionally prioritized in the decision making process and become the true driving force of early project decision making. Environmental and social concerns are less often addressed up front, and are more often addressed in the EIA's Environmental Management Plan (EMP) where they are managed over the life of the project and sometimes beyond.
While EMPs are vital to minimizing and mitigating environmental and social impacts, there are risks to allowing environmental and social concerns to be addressed only after most technical and design planning has been largely finalized. This paper will demonstrate the importance of addressing environmental and social considerations through EIA alternatives analysis early in the project decision-making process, review cases in which this has or has not been accomplished and review tools that can be used by decision makers to support alternatives analysis in EIA. The tools explored, sustainability appraisal, true cost accounting, scenario planning and modeling software, take into consideration the true costs of environmental and social impacts. Their application in EIA alternatives analysis can help assure more sustainable projects.