bluuebunny/crossref_metadata_2025_split huggingface dataset:
How EHS Auditing Programs Will Evolve for the New Millennium
Authors: Johnstone J. E. , Moore D. W. , Wouch M. L. 
Published: December 2007

Abstract
Over the past 25 years, oil companies have been implementing environmental, health and safety (EHS) auditing and review programs which have resulted in positive benefits, but have required continual revisions to adapt to changing needs. Industry's EHS parameters and major incidents have been trending positively since these programs were initiated. These programs have resulted in an increased level of safety and environmental performance for most companies. However, the programs have undergone continual changes to meet the needs of the corporation, operating groups and stakeholders.
Audit programs have continued to change and evolve as regulations, demands of the public, technology and management philosophies have changed. Often, programs have been modified after major events, such as the Bhopal incident, or to conform to changes in governmental policies. Although the strategic goals have remained constant throughout time, the programs have continued to evolve to reflect both internal and external forces.
The key goals for the EHS auditing programs have been to: Manage risks effectively,Improve compliance,Increase awareness and understanding of EHS hazards,Improve public image,Provide assurance to executive management andAssist the facility manager to operate efficiently and safely.
This paper will explore the evolution of these different programs over the past twenty-five years and what we can expect in the new millennium. Management system audits have evolved from an informal internal review process to one, which in some countries, is now stipulated by international bodies. Compliance audits were once the domain of outside auditing firms, but are now successfully managed by facility personnel. Numerous non-government organizations (NGOs) are pressing for more accountability to the public. Several forms of audits have disappeared while other methods have come into widespread use. International organizations are now requiring accredited environmental auditors. These and other changes are explored in this paper.
The paper will review case histories of several companies’ EHS audit programs as they strive to determine the best type of program to enact for their circumstance. Examining past programs and their measure of success, which they enjoyed, can help plan future programs with a high probability of success. Audit programs appear to pass through five distinct phases. The phases are not always linear as companies try to constantly improve their programs. Recommendations for successful programs are presented.
Audits and related reviews for this new century are discussed in this paper. Corporations and their partners will find it necessary to continue to improve and update their programs to meet the demands from governments, partners, corporate management and outside stakeholders.
A Management Trend: Towards Special Remedial Organizations
Authors: Skaggs M. M. , Harris M. A. 
Published: December 2007

Abstract
Corporations are managing their environmental remediation responsibilities using a variety of organizational strategies. Applicable recent literature and several recent benchmarking surveys were reviewed to gain an understanding of these strategies. Among 31 major corporations included in two recent benchmarking efforts, centralized remediation groups are currently the dominant management structure, outnumbering decentralized organizations twenty-fold. Remedial staff sizes, normalized for spending levels and portfolio size, average one remediation professional for every $ 1.7 million of current year spending and for every $ 11 million in accrued ("reserved") money. A trend exists towards the creation of "special remedial organizations" (SROs). SROs allow a management focus on remediation activities, often provide significant tax benefits to the parent corporation, and also provide an excellent vehicle for creating partnership opportunities with remedial service providers.
An Environmental Information Management Suite for U.S. Oil and Gas Wells
Authors: Belieu S. D. , Paque M. J. , Simmers R. J. 
Published: December 2007

Abstract
The Ground Water Protection Council (GWPC), working with agencies that represent the oil and gas producing states, has developed a comprehensive system titled Environmental In-formation Management Suite (EIMS) to manage data from oil, gas and injection well operations.
The EIMS program offers flexible integration of highly customizable data solution tools, including the Risk Based Data Management System (RBDMS), an oil and gas production module, a stand-alone geographic information system (GIS) module, an internet reporting module, a runtime version, a wellbore schematic package, and an economic and engineering module. RBDMS is a complete well database system and has a built-in environmental risk assessment com-ponent that is used for injection wells.
The cooperative funding for the development of the system has been provided by the U.S. Department of Energy (DOE) and from 17 EIMS user states.
EIMS is designed to run on stand-alone and net-worked PC's that run the Windows 95, 98, 2000, or NT oper-ating systems. Microsoft Access was chosen as the database development tool. EIMS can also attach to backend database management systems such as SQL Server, Oracle, or Sybase. Like Access, EIMS uses the familiar Windows graphical user interface.
An important aspect of this project is the cooperative approach used by the team of designers. Personnel from vari-ous state agencies, GWPC, and database design consultants have developed this system to be easily customized to meet the varying needs that exist among state environmental regu-lations. State agency database administrators communicate with each other to solve the problems associated with main-taining the system. This paper describes the EIMS program and some of its applications.
New modules are currently being developed that will increase this system's usefulness to the industry and regulatory agencies. EIMS is distributed cost free.
Creation of an Integrated Management System
Authors: Abernathy S. E. , Knode T. L. 
Published: December 2007

Abstract
One of the keys to implementing structural controls that guarantee continual improvement is a comprehensive management system. Health, safety, and environmental management systems have historically been separate from main-stay processes of a company. This distinction may hinder full implementation of the system because operations personnel do not consider HSE to be integral to their function.
The Halliburton Management System is an integrated management system that provides a structure covering HSE and Quality within the framework of each activity. Elements of the E&P Forum, ISO 9000, and ISO 14001 provided the framework for development of this management system. Processes are mapped within HMS and HSE risks are identified within the processes, with appropriate controls or countermeasures established. Competencies are easily identified and managed through this process focus. Feedback is captured with the Correction Prevention Improvement system and appropriate changes to the processes can be made.
HMS is designed to focus on performance rather than compliance. By focusing on the process as a whole we keep our purpose, as defined in the mission statement, within sight. This paper will describe how the HMS was developed, and will serve as a guide to those interested in furthering their organization's process improvements and HSE performance.
The Impact of Rate-Limited Release on the Aqueous Leaching Characteristics of Polyaromatic Hydrocarbons From Soils
Authors: Kim S. , Rixey W. G. 
Published: December 2007

Abstract
The purpose of this research was to characterize the rate limited release of polyaromatic hydrocarbons (PAHs) from soils to an aqueous phase. Experimental results were obtained for the aqueous release of naphthalene, C1-naphthalenes, C2-naphthalenes, fluorene, and phenanthrene from field soils obtained from manufactured gas plant sites. To characterize rate-limited release of compounds from soils, fixed-bed rate of release (ROR) experiments were used. A two-site equilibrium/rate-limited model was used to interpret the slow rate of release of a fraction of each compound initially in the soil. The model was used to analyze the experimental data and obtain the following key parameters: Kd, F, and k2 (day-1), where Kd is the equilibrium partition coefficient for contaminant, F is the fraction available for equilibrium release, and k2 is the mass transfer rate constant for the slowly released fraction. The Kd values were also independently measured in batch partitioning experiments.
It was observed that the partition coefficients determined from the fixed-bed experiments for most of the soils tested were very consistent with the batch partitioning results. This result is also consistent with the values of F that were generally observed, which indicated that large fractions of the various PAHs for these soils were readily available for transport to the aqueous phase.
Rate constants for the slowly released fractions, k2, were measured to be of the order of 0.001?0.01 day-1 for the five different PAHs in the various soils. Values within this range are significant with respect to establishing environmentally acceptable endpoints, since these values are lower or of the same magnitude as those for other loss processes that can occur in soil such as biodegradation.
Analytical Solutions for Free-Hydrocarbon Recovery using Skimmer and Dual-Pump Wells
Authors: Obigbesan A. B. , Johns R. T. , Lake L. W. , Bermudez L. , Hassan M. R. , Charbeneau R. J. 
Published: December 2007

Abstract
Accidental release of petroleum hydrocarbons to the subsurface may occur through spills around refineries, leaking pipelines, storage tanks or other sources. If the spill is large, the hydrocarbon liquids may eventually reach a water table and spread laterally in a pancake-like lens. Hydrocarbons in the aquifer that exist as a separate phase are termed free product or light nonaqueous phase liquids (LNAPL).
This paper presents new analytical solutions for the effective design of long-term free-product recovery from aquifers with skimmer-, single- and dual-pump wells. The solutions are derived for steady-state flow based on the assumption of vertical equilibrium, and include the effect of coning of LNAPL, air, and water on flow.
The results show how to estimate the maximum rate of inflow of LNAPL for skimmer wells, i.e. wells in which LNAPL is recovered with little or no water production. The paper also shows how to calculate the increase in LNAPL recovery when water is pumped by single or dual-pump wells. A simple equation is given that can be used to adjust the water rate to avoid smearing of the LNAPL below the water table.
Evaluation of a pH-Sensitive Polymer for Gravel-Packing Operations
Authors: Al-Anazi H. A. , Sharma M. M. 
Published: December 2007

Abstract
Anionic polymers such as polyacrylic acid, polymethacrylic acid, and their derivatives are known to show pH sensitive rheology. Rheological data is presented for a polyacrylic acid type polymer as a function of polymer concentration, pH, shear rate, and temperature. The effects of monovalent and divalent ions on the rheology are also presented. Core flow experiments were conducted on Berea sandstone cores. Fluid loss and filter cake stability was investigated at an overbalance pressure of 100 psi. Its effectiveness was compared with that of a conventional carrier fluid (HEC) used for gravel packing. It was found that the viscosity of the polymer is strongly dependent upon the pH of the solution. At higher pH values (&gt;6), the polymer viscosity reached a high value that is sufficient to suspend most gravel. Hydrochloric acid breaks this high viscosity to a low value (&lt;5 cp) at pH values below 2. The thickening and thinning with pH was found to be reversible. The effect of temperature on the rheological properties was not significant. Compatibility tests showed that the polymer was compatible with most brines (NaCl, NH4Cl, and KCl) used for field applications. Core flow results indicated that the filtration rate was low (&lt;9 ml/hr) compared to that of HEC (106 ml/hr), at an overbalance pressure of 100 psi. The retained permeability of the core was found to be 80% and 40% after using the polymer and HEC, respectively. The invasion depth is also shorter than that of HEC due to the formation of a stable filter cake. Our evaluation study shows that this anionic polymer would be an excellent non-damaging carrier fluid for gravel packing. It has excellent rheological and suspension properties and is easily broken down with a mild acid wash before flowback.
Production Optimization and Practical Reservoir Management of Coal Bed Methane Reservoirs
Authors: Manrique J. F. , Poe B. D. , England K. 
Published: December 2007

Abstract
A systematic and focused engineering approach for production optimization and reservoir management of Coal Bed Methane field developments is discussed. Such an approach constitutes a decision making tool for production optimization of CBM fields.
The paper briefly discusses the dynamics of the reservoir/production mechanisms, dewatering, desorption, fracturing mechanics and damage mechanisms affecting fracture conductivity and methane production. We present a set of best completion practices for CBM field ranging from reservoir behavior of CBM reservoirs, formation evaluation applications, reservoir modeling, production analysis, perforating for fracturing and completion design and optimization.
An integrated reservoir description is incorporated into the completion strategies by the development and use of a Geomechanical model that accounts for the reservoir characterization and mechanical properties (pore pressures, k, ϕ, saturations, coal quality, stress gradients, stress contrast, Young's modulus, Poisson's ratios). The approach results in an efficient design and optimum placement of hydraulic fracture stimulation treatments and provides the strategy for high grading the coal quality and selective stimulation of the coal seams.
A robust methodology for analysis of commingled production data is performed using historical production data and advanced diagnostic procedures that match and predict performance to accurately estimate reservoir potential, well deliverability and completion efficiency. The unique procedures combine superposition-in-time with rate-transient analytic solutions for finite-conductivity vertically fractured and non-fractured wells to accurately determine effective properties. Simulation scenarios are created using a CBM simulator and used for optimizing reservoir/field development scenarios to accelerate the dewatering process and increase production by selective stimulation / completion criteria.
The optimization process can effectively improve field performance and economics and can be continuously improved according to the evolving needs of the economics of the reservoir development.
Status of the Section 26C Steamflood Midway-Sunset Field, California
Authors: Duerksen John H. , Gomaa E.E. 
Published: December 2007

Abstract
This paper describes the status of a 23-acre, six-pattern steamflood pilot in the thick (300 ft) steeply-dipping (10 °) Monarch sand, Section 26-C, Midway-Sunset Field after 18 months of steam injection.
The steamflood response shows a significant increase in oil production (520 B/D) relative to cyclic stimulation response. The response is significantly affected by preferential permeability, areal confinement and localized barriers to vertical flow. The observation well temperature profiles confirm that the low permeability zone just above the steam injection interval is at least a local barrier to vertical steam flow.
Differences between steamflood performance and previous simulator predictions were due to reservoir heterogeneities not accounted for in the simulator study.

Introduction
A six-pattern steamflood pilot was initiated in November 1975 in the thick Monarch sand of the Midway-Sunset field. The main objective of the pilot was to demonstrate that a very thick, dipping, heavy oil reservoir can be steamflooded successfully. The design and simulation of the pilot are described in a previous paper.
Based on log data obtained prior to the coring of the pilot observation wells, the Monarch sand was thought to be reasonably homogeneous. Examination and analysis of the cores showed that this was not the case. These results were used to develop a geologic model which is described in a companion publication. This model and References and illustrations at end of paper.
Subsea Re-Injection of Drilled Cuttings - Operational Experience
Authors: Saasen A. , Tran T. N. , Jøranson H. , Meyer E. , Gabrielsen G. , Tronstad A. E. 
Published: December 2007

Abstract
Subsea re-injection of drilled cuttings has been applied on the Åsgard field to handle oil wet cuttings. For various reasons, oil based drilling fluids have been used in all 12 ¼" and 8 ½" sections at Åsgard. Discharge of oil wet cuttings is not permitted. Cuttings have to be re-injected to the formation or sent onshore for treatment. Onshore treatment and logistics, are expensive and involve a large emission of CO2. If re-injection can be performed, big bag handling operations are significantly reduced. Furthermore, it is difficult to have reliable logistics to bring cuttings onshore. Therefore, cuttings re-injection is the optimum solution for this operation, where the preferred injection point is below the 20" casing shoe.
Re-injection is straightforward if cuttings can be re-injected into a formation underneath a large sand formation where the liquid phase of the slurry can leak off. At Åsgard there are no such large sands. Therefore, cuttings have to be re-injected into shale formations. Since the fluid does not leak off sufficiently fast in shale there is a danger that the annulus may be exposed to a too high pressure for a long time. If too large a fluid volume is injected at a time, there is a danger that the fluid may propagate as a fluid bubble to the surface.
Leakage to surface has been observed four times at Åsgard. It has been recognized that the cementing results must be better than normal to hinder leakage to surface if cuttings are re-injected into shale formations without sand layers. This paper describes the leakages in detail. It focuses on the necessary improved drilling and cementing precautions to hinder leakage. The paper also describes a technique with alternating re-injection and static periods to make the liquid phase leak off into minor sands and shale, preventing the formation of too high an annulus pressure and hindering the formation of a fluid bubble propagating to the surface.
Coiled Tubing Seismic While Drilling
Authors: Jackson T. S. , Gorrara A. J. 
Published: December 2007

Abstract
The efficient exploitation of hydrocarbon resources is strongly dependent on the drillers’ ability to position wells accurately. This is particularly challenging for smaller targets and on long reach or horizontal wells. Conventional wireline VSP’s can provide valuable assistance but such operations require either the drill string to be removed from the hole or the pumping of the geophone tool through the drill string. Both of these methods add time to the well construction. In long sections of open hole wireline operations may present risks, in the form of sticking and potential fishing operations, which prevent VSP surveys being acquired in lookahead mode. Ideally, VSP data would be acquired at several stages of the drilling process to enable corrective action to be taken to assist accurate bit placement. The costs in terms of rig time alone generally make this option prohibitive.
Ongoing developments for cost effective exploitation of mature and pressure-depleted reservoirs have led to wider applications for coiled tubing drilling. The combination of a seismic tool with the coiled tubing drill string therefore provides an ideal configuration to reduce drilling costs and optimise well placement. This paper discusses the conventional methods available for geosteering of the bit, the additional benefits of incorporating a seismic tool into the drill string and describes the development of a seismic while drilling tool (SMWD) for coiled tubing drilling.
Chemically-Enhanced Drilling with Coiled Tubing in Carbonate Reservoirs
Authors: Rae Phil , Di Lullo Gino 
Published: December 2007

Abstract
There has been a dramatic increase in the use of continuous reeled tubing (coiled tubing) for drilling operations. Much of this increase can be attributed to improvements in the quality and dimensions of coiled tubing itself – pipe sizes have steadily increased over the years from 1 inch OD to 3 ½ inch OD and bigger. Other developments have included improved downhole motors and, for directional work, sophisticated survey and orienting tools that can be controlled, in real time, from surface.
Despite these developments, CT drilling is still applied to very few wells, or a tiny percentage of the total drilling market. There are many reasons for this including high equipment and personnel costs, low rates of penetration (ROP), and issues related to the reliability of high-cost "smart" bottom hole assemblies (BHA's) needed for directional work. The idea that CT drilling would offer a cheap alternative to conventional rigs is, and probably will remain, an unfulfilled pipe-dream. However, CT drilling certainly has its place, particularly for vertical well deepening and for slimhole multilateral work. The method presented here provides the opportunity to improve the efficiency and lower the cost of such operations. This paper describes a technique that we call Stimulation While Drilling (SWD), a drilling method that is particularly applicable to the use of coiled tubing. In particular, the method is intended for use in the drilling of multiple short, lateral drainage holes originating in the main borehole and extending outward radially through the reservoir, at one or several depths. However, any hole, including the main borehole itself, can be created using this technique, depending on the lithology. This ability to make large multilateral conduits, at high speed, in underbalanced conditions, if desired, and with no drilling damage offers significant advantages for well construction and completion, particularly in hard carbonate reservoirs.
Assessment of Residual Oil Saturation in a Large Carbonate Reservoir
Authors: Pham Tony R. , Al-Shahri Ali M. 
Published: December 2007

Abstract
This paper discusses the assessment of Residual Oil Saturation (ROS) in a large, prolific, water flood carbonate Arab-D reservoir in the Middle East. The determination of Residual Oil Saturation is very important since it is a crucial step in the accurate evaluation of sweep efficiency, reservoir management strategy, EOR feasibility, and oil recovery factors. Recovery in a water flood reservoir is the function of economic limit, and displacement and sweep efficiency (in both areal and vertical direction).
The reservoir carbonates were grouped into different reservoir classifications from cores extracted from nearly 500 wells. Numerous laboratory water flood tests using centrifuge, unsteady state and steady state methods were performed on these cores. The results from these laboratory tests were screened, tabulated and evaluated against one another for different rock types as well as against the field test results. The advantages and disadvantages of each laboratory test method are also highlighted. The paper will discuss which type of laboratory tests are required to properly model the reservoir sweep mechanism, how the reservoir rock types could be classified, and how reservoir simulation models could be used to arrive at a credible ROS estimate for the whole reservoir.