bluuebunny/crossref_metadata_2025_split huggingface dataset:
Can Safety Improvement Increase Drilling Efficiency?
Authors: Boutalbi S. M. , Pavel D. A. , Grayson M. B. 
Published: March 2011

Abstract
The number one operational safety risk during the drilling and completion of a well is the risk of a kick and the danger that this can place on people, assets and environment. The second is the potential misdiagnosis of a kick or a limited ability, to quickly and efficiently identify downhole anomalies. Is it a kick, or is the well breathing when making a connection? Are we experiencing losses, or is the well ballooning when the mud pumps are turned back on after a connection is made? If a wrong decision is made based on a misdiagnosed situation, the results can range from costing millions of dollars in nonproductive time to loss of life and rig.
There are numerous key technology elements in the industry today that can greatly mitigate these risks and create a substantially safer drilling and completion operation and environment. These elements are field-proven over 40 plus years, are readily available from many vendors and are relatively economical. Surprisingly, these elements are not used on the most critical, risk-laden and expensive wells being drilled globally. These risk-mitigating elements include such systems as rotating control devices, flow-metering technologies, automated drilling choke systems and downhole isolation valves. Individually these elements add incremental benefits and increase the overall safety of the drilling and completion operations. When these systems are paired or used in combination with each other to create a closed and pressurizable mud-returns system, the benefits escalate exponentially when compared to cost or perceived inconveniences of these elements. Furthermore, when the closed-loop system is designed as such – a system – as opposed to being piecemealed together, the operational benefits of the system are maximized.
This paper describes how a few of these basic elements greatly enhance operational safety and efficiency. A closed mud-returns system enables the quick and accurate identification of kicks and thereby minimizes risk without sacrificing other operational elements.
A New Safety Arena: The Safety Challenges of New Floating Structure Applications
Authors: Bower-White Graham 
Published: March 2011

Abstract
Recent developments in technology and application has seen the emergence of new floating development applications ranging from large scale gas condensate FPSOs, FLNG, semi-submersibles supporting mega sized gas condensate topsides through to dynamically positioned drill ships.
Traditional safety engineering FPSO approaches developed over the past twenty years that apply to oil developments often do not automatically apply to these new floating applications. Inherent safety risks fundamental to the new application and the associated practical solutions needs to be understood and worked using a first principles approach, and may often result in the implementation of solutions involving counter intuitive philosophies and safety in design practices.
These safety challenges of new floating applications involve engineers, fabricators, operators and certifying agencies and apply across all phases of project implementation.
This paper maps out some of the key challenges and risks associated with the new floating structure applications. It also lays out the need for different thinking not only in the design process, but also in fabrication, testing and certification phases.
Also addressed is the requirement for industry participation, as the ever increasing pressure for fast track project implementation continues in a situation where the oil and gas industry will be solving many first of a kind applications.
Management of Water Extracted From Carbon Sequestration Projects: Parallels to Produced Water Management
Authors: Veil J. A. , Harto C. B. , McNemar A. T. 
Published: March 2011

Abstract
Throughout the past decade, much discussion and debate have centered on geological sequestration of carbon dioxide (CO2). In order for sequestration to have a reasonably positive impact on atmospheric carbon levels, the anticipated volume of CO2 that would need to be injected is very large. The plume of injected CO2 could potentially extend for many kilometers from the injection well, and formation pressure could be elevated following extended injection of CO2.
In the past two years, there has been growing discussion of a new issue concerning withdrawal of water from formations that would receive injected CO2. The concept is that by removing water already residing in the receiving formations (referred to as "extracted water" to distinguish it from "oil and gas produced water"), the pressure gradients caused by injection could be reduced, and additional pore space could be freed up to sequester CO2.
Produced water is typically salty ground water. The potential extracted water is also salty ground water. Therefore, many of the same management practices may be applicable. This paper describes the probable composition of the extracted water, options for managing the extracted water that is removed from the formations, the pros and cons of those options, and some opportunities for beneficial use of the water.
Counting for Nothing? The Importance of Quantifying Social Risks in Major Capital Projects
Authors: Calcut T. D. , Wall C. R. 
Published: March 2011

Abstract
Major Capital Projects (MCPs) face a wide range of operational, regulatory, and reputational risks. Each of these issues has a strong element of "social risk." Despite progress in the quantification of delays on MCPs in terms of cost and schedule implications after-the-fact, little attention has been paid to quantifying social risk.
This paper focuses on the potential implications that social risk, in its various forms, can have on MCPs. Then, taking existing knowledge on the quantification of budget overruns and schedule delays, it examines the case for more thorough quantification of social risk, early in the MCP planning process.
Examining a series of recent MCPs, this paper makes the case that there is a strong rationale for systematic management and mitigation of social risk. Applying experiences from MCPs worldwide, this paper explores tools for effective social risk management, including social and community health impact assessments, targeted stakeholder engagement, and strategic community investment.
The potential cost of delays and budget overruns on MCPs today is immense. With a significant percentage of the world’s largest MCPs experiencing adverse effects from social risk, there is a strong economic rationale for robust social risk identification. If identified and quantified early in MCP planning, effective social risk mitigation and management is possible.
Too often, however, population surveys, community consultation, and social investment are not applied in a way that is targeted at a MCP’s social risks. Where these mitigation strategies are not implemented in an effective or timely manner, they can "count for nothing." This paper takes the position that MCP sponsors need to adequately quantify, and then manage, these social risks to support successful MCP implementation.
Enhanced Anaerobic Biodegradation of Petroleum Hydrocarbons in Groundwater
Authors: Cuthbertson J. F. 
Published: March 2011

Abstract
At many sites, sulfate reducing bacteria have been demonstrated to be a dominant factor in the natural anaerobic biodegradation of petroleum hydrocarbons dissolved in groundwater. There are many benefits of providing sulfate as a terminal electron acceptor to the subsurface environment. As anaerobic conditions naturally prevail under petroleumimpacted sites, there is less acclimation time necessary for microbial populations, thus sulfate enhancement stimulates processes that are already occurring. The high solubility and stability of sulfate solutions relative to traditional electron acceptors allows for improved subsurface delivery and coverage, and higher concentrations of sulfate (as compared to oxygen) can be added to groundwater due to its high solubility. The lower energy reactions of sulfate reduction require less nutrient supplementation and produces less biomass and secondary precipitates, which can plug an aquifer. There is less nontarget demand on sulfate when compared to oxygen, which provides better utilization efficiencies. Case studies that demonstrate the benefits of enhancing the sulfate concentrations in groundwater to stimulate the biodegradation of petroleum contaminants under field conditions are presented.
Security and Safety Are Sisters
Authors: Simmerman J. 
Published: March 2011

Abstract
Since the 9/11 terrorist attacks on the US, security has been an important element of sustainability in the Petroleum facilities, terminals and refineries. New homeland security regulations have only reinforced this new paradigm. Not surprisingly, Quality Safety Compliance Programs (QSCP) can greatly enhance a facility's security posture. This presentation will include:
A brief introduction of security regulations. The synergy of QSCP and a security program. How QSCP can cut security program costs and liabilities. How a bench-mark QSCP enhances the security and safety of a facility. QSCP recommendations that will provide facility leaders with key facility risk management tools.
China Offshore Anti-Collision Risk Management Standard and Remedial Measures
Authors: Kun Cheng , Zhong Cheng , Yunan Wei , Wenyan Wu , Holditch S. A. 
Published: March 2011

Abstract
With the trend of economic, regulatory and technological changes, demand of a comprehensive standard to systematically evaluate and manage the risks of wellbore collisions has become significant in offshore oil development. Several accidents happened during normal operations at the Bohai Sea oilfield, including boreholes collision and drilling through adjacent casings. Under this situation, the China National Offshore Oil Corporation (CNOOC) adopted new offshore well anti-collision standard and related remedial measures.
As part of the anti-collision safety operation system in CNOOC offshore oil drilling, the standard is designed and established for requirements mainly in four perspectives, including: data and material collection specifications in the early stage of drilling; anti-collision risk analysis in drilling design; anti-collision safety technical measures in drilling operation and operation site; remedial strategies and operations in case of wellbore collision. In this paper, we also describe how the standard has been applied to the several recent cases, and discuss its benefits for the anti-collision risk control of drilling offshore cluster wells and adjustment wells, treatment cost reduction, and marine environment safety.
Application and Use of Standardized Safety Questionnaires for Contractor Management in Upstream Oil and Gas
Authors: Pinheiro A. B. , Kuiper C. 
Published: March 2011

Abstract
Petroleum exploration and production (E&P) operations are inherently hazardous and dictate the need for prudent approaches to job planning and execution. Contractors are used extensively to support drilling, construction, and production activities and diligence should be exercised in their selection, monitoring, and management. Effective contractor selection from a Health, Safety and Environmental (HSE) perspective is predicated upon access to current and reliable information on contractor programs and performance. That need could be partially fulfilled by on-line questionnaires which offer the advantages of convenience, expediency, and cost-effectiveness, compared to conventional information-sourcing methods.
This paper discusses how an integrated oil and gas company (Operator) has successfully used questionnaires for contractor prequalification, evaluation, selection, site management, and auditing. An analysis of the contractor HSE audits, to validate the questionnaire over a two year period, identified limitations in the process and instances of inaccurate reporting by the contractor. Those inaccuracies were attributed to question phrasing, perceived question threat, lack of understanding of HSE management principles and legislation by the respondent and, in some cases, untruthful answers. This study also found that when an online questionnaire is weighted on HSE "management" questions to the detriment of "compliance" questions, its usefulness as an information source gets diminished. Further complications arise when the compliance questions are answered simply by copying appropriate regulations or citations without evidence of implementation. Recommendations, supported by John Maxwell’s laws of leadership, are made to address the areas of concern and increase the validity, reliability, and usefulness of online questionnaires as a valuable information source for contractor HSE risk assessment.
Water Recycling and Purification in the Pinedale Anticline Field: Results from the Anticline Disposal Project
Authors: Shafer L. 
Published: March 2011

Abstract
Recycling produced water and fracture flow back water for hydraulic fracturing can contribute significantly to water supplies for unconventional gas field development. Waste water may also be cleaned to supplement fresh water supplies for drilling and cementing surface pipe, surface construction, and other field development needs.
The Pinedale Anticline field in western Wyoming is an example where recycling water has contributed significantly to supplies for field development. Early in the field development the need to conserve available water supplies and the limitations on waste disposal injection capacity demonstrated the need to recycle water.
The Anticline Disposal Process was designed and constructed to meet the field development needs in two phases. The first phase utilized anaerobic and aerobic biologic treatment followed by clarification and filtration to clean fracture flow back and produced water. The process successfully cleaned and recycled 22,000,000 barrels of "frac water" in the first four years of operation. The second phase was designed to process surplus water to supplement fresh water supplies and also to meet discharge standards for a local river. This requires removing constituents such as methanol, dissolved aromatic compounds, excess dissolved solids, and boron. The process utilizes a membrane bioreactor, reverse osmosis, and ion-exchange process treatment steps. Organic constituents are removed to below detection limits. Inorganic salts are reduced from over 8,000 mg/l in the feed to below 100 mg/l in the product water. Boron is reduced from 15 to 30 mg/l in the feed to less than 0.75 mg/l, the drinking water standard, in the product water. Over 200,000 barrels of processed water has been used locally in the first year of operation with over 1,000,000 surplus barrels discharged to the river.
The results demonstrate feasibility to construct water processing plants to clean fracture flow back water for re-use in well completions and to reclaim water to supplement fresh water supplies. Design considerations, process steps, and lessons learned for consideration in application to other areas will be presented.
Reducing the Risk of Low-Probability High-Consequence Events
Authors: Threadgold I. M. 
Published: March 2011

Abstract
Low-Probability High-Consequence (LPHC) events are accidents that are unexpected, with few similar historical events; however, when they do happen the impact is extreme. With few prior events available to learn from, it can be difficult for a single company or organization to completely understand, manage and fully mitigate the risks involved with LPHC events. This is because they do not have enough learning opportunities to improve their overall risk management performance, and properly address the hazards.
Part of the problem in managing against LPHC events occurring has been the lack of appropriate metrics. While efforts are underway by industry to develop a suite of Process Safety metrics, there is still a gap where Operational Safety is concerned.
The author proposes that the best way to reduce the risks is by working issues at a sector or total industry level, rather than on a company by company basis. At an industry sector level there is greater knowledge and awareness of a larger number of previous events and a broader group of experts to develop industry practices and risk management guidelines.
Examples are given of how successful this concept has been for a specific hazard, then at a national level, and finally in the geophysical sector of the oil and gas industry between the International Association of Geophysical Contractors (IAGC) HSE&S Steering Committee and International Association of Oil and Gas Producers (OGP) Geophysical HSSE Sub-committee, where contractors and operators have worked together on Health, Safety, Security and Environmental (HSSE) issues for a number of years.
The oil and gas industry can improve its overall safety performance for LPHC events by working at a global sector level, or even globally across the industry by better sharing of the right kind of information on incidents. In addition, industry should capture the key aspects and lesson learned in databases that can then be used for several purposes: to drive the development of guidance documents; to help create improved and more consistent risk assessments across industry; to help develop the improved metrics still needed for Operational Safety, and potentially to guide any new regulatory requirements.
To accomplish all of this on a global basis may require the creation of a new industry body. It is worth bearing in mind what occurred in the US after the Three Mile Island nuclear incident. The nuclear power industry was at risk, and it established the Institute of Nuclear Power Operations (INPO) in 1979, with a mission to "promote the highest levels of safety and reliability – to promote excellence – in the operation of commercial nuclear power plants". In the 30 years since INPO was established it has built an excellent safety and reliability record, but they are still cognizant of continuing challenges. The best way forward may be to establish a similar but global body for the world-wide oil and gas industry.
Fundamental Reservoir Engineering Principles Explain Lenses of Shoreline Residual Oil Twenty Years after the Exxon Valdez Oil Spill
Authors: Pope Gary , Gordon Kim , Bragg Jim 
Published: March 2011

Abstract
Twenty years after the Exxon Valdez spill, weathered residual oil is still found in small, isolated lenses of subsurface sediments of a very small fraction of Prince William Sound shorelines. The ecological impact of this remaining oil still causes great concern and has been extensively studied for this reason. Despite this concern and numerous publications on the subject, no papers exist in published literature that have applied the fundamental principles and tools of reservoir engineering to understand and explain how oil entered the subsurface, why most but not all of it was washed out by tides and occasional storms, and why and under what conditions some of it still persists. Potential ecological impacts of the remaining oil are determined by polycyclic aromatic hydrocarbon (PAH) components in the now highly degraded oil. The PAH components dissolve in groundwater (i.e. water within sediment pores) and transport to the surface water (water above sediment) where they could impact biota. Aqueous PAH concentrations in nearshore waters are currently at background levels even along shorelines identified with the most subsurface oil. Three-dimensional simulations of two well-characterized sites representative of locations with the most remaining subsurface oil clearly show both why remaining oil persists where it does, and why PAH concentrations in the surface water are extremely low. The permeability of underlying fine-grained sediments containing oiled lenses is about 1000 times less than overlying boulders, cobbles and gravels. Therefore, the water velocity through these lenses is extremely low. Secondly, the PAH solubility in the pore water within these lenses is extremely low. Thirdly, twice daily, large volumes of seawater flowing through higher permeability surface sediments mix with and dilute any dissolved PAH leached from buried source lenses. Detailed modeling results therefore explain why only background levels of PAH have been measured in numerous surveys of water or sentinel biota such as mussels.
Offshore Safety Through Design: Practical Implementation of Best Practices from the OSHA 1910 Framework
Authors: Laskar S. , Mallinson T. , Aldeeb A. 
Published: March 2011

Abstract
Although not all upstream facilities have been historically obligated to meet the requirements of the federal OSHA PSM standard (29 CFR 1910.119), utilizing this existing set of technical, documentation, and procedural practices can be expected to achieve the same results as in the downstream, chemical, and petrochemical industries. Namely, to ensure the safe operation of a facility, various hazards associated with the facility process and the plant equipment need to be addressed in a systematic manner.
Those working in the oil and gas industry are reminded with depressing regularity of the importance of process safety management, as post-incident investigation invariably points to one or more deficiencies related to process safety as root causes. This paper challenges the predominant notion that upstream facilities can be safely operated without following methods similar to those dictated by OSHA based on technical comparisons of pressure relief system design findings for upstream and downstream facilities. An adequate pressure relief system plays an important role in safe facility operation both through avoidance of catastrophic events and through prevention of incident escalation.
Similarities in relief system design issues for 60 process units of representative upstream and downstream production facilities are presented in a comparative case study. Alignments and points of divergence in typical practice between the example facilities are discussed. Significant similarity in the nature and types of the pressure relief systems deficiencies between upstream and down stream facilities is concluded.
The information presented helps upstream asset owners better understand standard practice for OSHA regulated facilities, align the corporate approach to safety, especially for vertically integrated owners, and demonstrate benefits achieved through proper design and documentation.