bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Sustainability Assessment Model (SAM): Measuring Sustainable Development Performance
Authors: Baxter Tom , Bebbington Jan , Cutteridge David , Harvey Gordon 
Published: December 2007

Abstract
Business has a fundamental role to play in delivering Sustainable Development - the process needed to achieve a sustainable society. Sustainable Development is becoming increasingly recognised as a critical issue for the oil and gas industry to address, and act upon. This paper outlines a practical tool (The Sustainability Assessment Model - SAM) which has been developed to analyse, compare and rank Sustainable Development performance.
The SAM assesses the social, environmental, economic, and resource usage impacts of a project over its full life cycle including product use. It also helps address the remediation and restoration options.
The SAM monetises all the impacts so that they can be compared on a like-for-like basis. This also allows the impacts to be combined into a single measure which reflects the overall Sustainable Development performance of a project. This paper will show how SAM has been used to assess the performance of several energy projects.
A project focus was initially adopted in the belief that greater control over impacts can be influenced and achieved at this level. However this paper will also show how the tool has been used to:
Aid specific design decisions such as concept selection Assess the overall holistic Sustainable Development performance of an industry sector.
The Role of Trust in Safety Culture
Authors: Burns Calvin 
Published: December 2007

Abstract
Since the Piper Alpha disaster, the oil and gas industry has taken steps to develop a more positive safety culture. Safety climate surveys have been used to provide a snapshot of the state of safety by measuring the workforce's explicit attitudes and perceptions about safety at a point in time. Organisational theorists have argued that climate is only a surface manifestation of culture and that culture manifests itself in deeper levels of unconscious assumptions. Psychologists have shown that an individual is able to hold different evaluations of the same object (a conscious, explicit attitude and an unconscious, implicit attitude) and that an individual's explicit and implicit attitudes to something do not have to be the same. This paper investigates the explicit and implicit attitudes held by the workforce at a UK gas plant about the trustworthiness of their workmates, supervisors and the plant leadership. A short questionnaire was used to measure explicit attitudes and implicit attitudes were measured using a computerised task. The main finding was that a different pattern of results emerged for explicit and implicit attitudes about trust. The paper concludes by proposing a model of dual attitudes about trust in safety culture.
The Use of Multilateral Technology to Arrest Production Decline in a West-Texas Gas Field
Authors: Owodunni Adeyinka , Travis Tim , Dunk Gary 
Published: December 2007

Abstract
ExxonMobil successfully drilled, completed, and produced the first selectively, high-pressure (rated for 8,000 psi) stimulated multilateral well in the world - the Arch Benge #1. This use of multilateral technology is part of an initiative to use step-out and fit-for-purpose technologies to arrest production decline in the Parks Field Unit, West Texas. The well was designed to produce gas and retrograde condensate from the upper and lower porosity lenses of a geologically constrained Devonian limestone.
The Arch Benge #1 well is a good example of how to use multilaterals as a fit-for-purpose technology to capture maximum reserves at minimal incremental cost. The well drilled a total 6,600-ft of Devonian formation that would have been otherwise impossible to fully access due to current lease line restrictions and field rules. The Arch Benge #1 was designed and implemented as a Technical Advancement for Multilaterals′ (TAML) level 2 dual-lateral well that successfully utilized a temporary, high-pressure TAML level 5 completion architecture for selective stimulation. This novel completion design and flexibility resulted in to significant cost savings and ensured the successful stimulation, test, and production of each lateral.
Other challenges included creating two separate lateral junctions within a 100-ft interval of geologically constrained Devonian limestone and isolating these lateral junctions during the high-pressure acid fracture treatments. Selective isolation was essential to test each lateral independently and maximize production from these tight carbonate reservoirs.
The Arch Benge #1 multilateral well is a good illustration of how to integrate proven and existing field practices with multilateral technology to achieve optimum value. The result is a 20% drilling cost savings over that of two separate wells. In this paper the multilateral selection process, planning, operational procedures, and result comparison with conventional wells will be discussed. The well is currently producing commingled gas and condensate from both laterals through a single string of tubing into a field gathering system.
An Assessment of Subsea Production Systems
Authors: Devegowda D. , Scott S. L. 
Published: December 2007

Abstract
The rapidly accelerating shift to subsea production systems represents a significant departure from conventional operations. Historically, subsea wells have had a good track record. However, complex subsea systems are now being deployed in ways rarely encountered in previous development schemes. These increasingly complex systems present a number of technical challenges. This paper presents an assessment of subsea production systems, considering the technical, operations and safety issues associated with this development modality.
This assessment considers the following general areas: 1) subsea processing; 2) flow assurance; 3) long-term well monitoring and, 4) safety & environmental concerns. A review of the state-of-the-art in each of these areas is presented and several technical and operational gaps are identified. One of the most striking findings is the low ultimate recovery anticipated from many subsea wells. Two new technologies that can have a positive impact on recoveries are subsea multiphase pumping and subsea separation/processing. This assessment found, however, that the safety systems seem to be absent from current subsea processing plans. Other concerns include the inability to monitor subsea wells for sustained casing pressure, a widespread problem in the GOM. With regard to flow assurance, much work has been done to develop design tools for flow assurance, little has been done in the area of monitoring subsea production systems to detect and locate these materials. As more subsea systems are placed in operation, the monitoring and operation needs (rather than the design needs) will likely emerge as the top priority.
Nonlinear Multivariate Optimization of Production Systems Using a Mechanistic Model
Authors: Del Río-H. J. , Camacho-V. R. , Robles A. , González-T. F. , Santamaría N. 
Published: December 2007

AbstractThis work presents results on the optimization of production systems performance for oil and gas reservoirs. Genetic and Polytope algorithms are used for the nonlinear optimization problem considering appropriate values of several variables like tubing string and wellhead choke diameters, separator pressure and surface pipeline diameter.The model considers several components and different methods to evaluate the pressure drop in each component. The sensitivity of each component of the system can be evaluated. This model includes a mechanistic model to predict the pressure drop due to multiphase flow for any tubing angle with upward and downward flow. The method of splines is used to eliminate the presence of pressure gradient discontinuities in flow pattern boundaries. This property of the model allows us to use optimization algorithms in an efficient manner.Several examples are presented to illustrate the methodology proposed in this work.
Ecosystem-Based Approaches to Offshore Oil and Gas Operation: An Alternative Environmental Management Technique
Authors: Khan Ibrahim M. , Islam M. Rafiqul 
Published: December 2007

Abstract
The oil and gas sector is one of the most lucrative sectors in business but reducing its environmental impact is one of the most pressing issues today. Practically all activities of hydrocarbons operations are accompanied by undesirable discharges of liquid, solid, and gaseous wastes, which have enormous impacts, especially in the marine environment. There is clearly a need to develop a management approach in oil and gas operations, which ensures minimization of adverse environmental impacts. Unfortunately, in trying to achieve this goal, the oil and gas industry has adopted some major misconceptions in it "environmentally correct" approaches, which are causing further damage to environment.
This presentation will address the present environmental misconceptions common in oil and gas development. Some innovative solutions are proposed to solve the problems caused by oil and gas development activities in the marine environment. These solutions are based on the holistic environmental approach, which takes into account the complexity of natural processes and which takes advantage of these processes, rather than working against them. Some of the proposed models are: marine protected area in oil sites (MPAOS), iron fertilization and CO2 utilization (IFCU), integrated coastal pollution balancing (ICPB), artificial recruitment in fisheries (ARFS), and artificial rigs from oil rigs (AROR). The main goal of the proposed approaches is to maintain and restore ecological sustainability and ecosystem integrity. As a result, each solution will not only stop destruction of the environment but also improve the productivity, biodiversity and fisheries in the marine ecosystem. The existing solutions to these problems involves focusing on the individual problems without integrating the total ecosystem, which might benefit one sector but is harmful to the whole ecosystem overall.
The proposed approaches can be applied to the marine environment, which environmentalists report is the most abused by the oil and gas sector. These approaches have great significance in utilizing oil and gas operations related pollution, fisheries improvement and ecosystem restoration.
Drilling High-Angle Wells in an Amazonia Natural Life Reserve
Authors: Casalis Daniel , Malfetana Omar , Fausto Jara 
Published: December 2007

Abstract
The Ishpingo-4 and Ishpingo-3 wells were drilled by Petroecuador—Ecuador's state-owned company—in the ITT (Ishpingo-Tiputini-Tambococha) field. This field is located in the Yasuní National Park in the Ecuadorian Amazon region, which was declared a World Biosphere Reserve by UNESCO in 1989.
The Ishpingo wells were drilled primarily to delineate oil reserves, and the project was managed by Petroecuador and PETROBRAS ENERGIA S.A. (PE) professionals. PE contributed recent experience gained from drilling two appraisal wells, Apaika 1x and Obe 1x, across the lease line. These wells were drilled and tested within the same natural life reserve area with similar heliborne equipment, materials and personnel.
To operate in this highly sensitive area, PE and Petroecuador developed a specific Environmental Management Program (EMP) that actively involved environmental authorities and representatives from native communities. The EMP was prepared using the PE Integrated HSE Management System certified by ISO 14001 and OHSAS 18001. To assess the results, audits were jointly conducted by the Ecuadorian government, the native communities and the company.
In 1992, two vertical wells—Ishpingo-1 and Ishpingo-2— were drilled in the Ishpingo field. The additional appraisal wells were planned with extended reach trajectories from existing well locations to minimize environmental impact. The logistics, drilling and testing of the two high-angle wells were operationally successful, and the geological target was reached to confirm hydrocarbon occurrence and reserve size. Ishpingo-3 set records in Ecuador as the steepest dip well drilled in a 16-in. section and the steepest dip well out of all high-angle wells drilled in that country.
The high-viscosity crude oil—12° API—as well as the high-deviation angle of the wells prevented the use of conventional testing techniques. Therefore, special methods, together with state-of-the-art directional equipment, were employed to determine both deliverability and reservoir boundaries. The effective application of these technologies, with optimum allocation of the resources and good terrestrial-fluvial-aerial logistics, resulted in a highly successful operation overall.
Development and Installation of an Inline Deliquidiser
Authors: Chin R. W. , Stanbridge D. I , Schook R. 
Published: December 2007

Abstract
Cyclonic separation technology, over the past few years, has received increasing attention because of weight and space savings for topsides and subsea applications. In addition to new builds, the cyclonic technology plays a major role in debottlenecking and upgrading. This paper will present the development and installation of an inline cyclonic deliquidiser.
The inline deliquidiser is new technology that has been developed and qualified with a major oil company and in mid 2002, was installed on one of their platforms in the North Sea. The need for such a device arose because high liquid loading of a scrubber was causing carryover to the downstream equipment. With little space, if any, to implement solutions as well as a desire to minimize downtime, an inline cyclonic separator in addition to scrubber modifications was deemed the best solution. During laboratory tests, and now offshore tests, the inline deliquidiser was shown to knock out 90-95%+ of the liquid upstream of the vessel. Design, laboratory tests, and field results will be presented. Potential applications of the inline deliquidiser will also be given.
Rediscovering Non-Darcy Flow Effect In Gas Reservoir
Authors: Armenta M. , Wojtanowicz A. K. 
Published: December 2007

Abstract
The paper demonstrates and explains the importance of global inclusion (i.e. throughout the reservoir) of Non-Darcy (N-D) flow component for better prediction of well performance in gas reservoirs with bottom water drive by using a numerical simulator. Traditionally, Non-Darcy flow effect in gas reservoirs has been attributed only to high gas flow rates, and considered locally around the wellbore. Consequently, most numerical simulators have the N-D component assigned to the well rather than distributed throughout the reservoir. Also, the common judgment is that the effect is insignificant at gas rates lower than 10 MMscf/d, so it would not affect gas recovery in the low-rate wells.
In this project, we used an analytical model, field data, and a numerical simulator with global and local N-D component to study sensitivity of final recovery and gas rate to N-D flow for a variety of reservoir properties. The results show that disregarding the N-D flow globally leads to overestimation of cumulative gas recovery by up to 42.2 percent. Moreover, this overestimated recovery is the same when N-D is ignored, or assigned locally to the wellbore.
It is also shown that N-D effect is significant at low production rates. Shown is the range of reservoir properties where gas wells producing only 9.8 MMscf/D would have total pressure draw-down comprising 70% contribution of N-D flow effect.
Analysis and Interpretation of Gas Diffusion in Quiescent Reservoir, Drilling, and Completion Fluids: Equilibrium vs. Non-equilibrium Models
Authors: Faruk Civan , Rasmussen Maurice L. 
Published: December 2007

AbstractThis paper presents physically and mathematically rigorous transient-state equilibrium and non-equilibrium diffusion models for practical determination of the gas diffusion coefficient from experimental measurements of the gas pressure decline in a closed tank by dissolution of gas in a quiescent liquid (oil, brine, drilling mud, and completion fluids).The short- and long-time solutions of this model for equilibrium and nonequilibrium transfer processes are developed analytically. These solutions are reformulated to enable direct determination of the best estimate of the diffusion coefficient by regression of the resultant analytical expressions to experimental data. These analytic expressions are used to establish the significance of the equilibrium vs. nonequilibrium gas dissolution in liquids under in situ conditions. The experimental data given in previous studies are analyzed by means of the present improved methods and the diffusion coefficients obtained are compared with the reported values.The results developed in this paper can be utilized for determination of the gas diffusivity, the interface mass-transfer coefficient, and the rate of dissolution of the injection gases in oil during secondary recovery, and the rate of dissolution and separation of light gases in reservoir oil and brine, drilling mud, and completion fluids.
Compositional Simulation of WAG Processes for a Viscous Oil
Authors: Li Dacun , Kumar Kamlesh , Mohanty Kishore K. 
Published: December 2007

Abstract
The goal of this work is to develop a compositional model for WAG injection in a medium-viscosity oil, low-temperature reservoir like Schrader Bluff Pool in the Milne Point Unit, Alaska. Compositional simulation of WAG displacement with CO2-NGL and Prudhoe Bay gas-NGL mixtures shows that three-hydrocarbon phases form in situ because of low temperature. A four-phase relative permeability formulation has been developed by considering the mixed-wettability of the formation and the saturation paths. The simulation results are compared with the laboratory experimental results from the literature. The sensitivity of the laboratory-scale oil recovery to relative permeability, pressure and solvent composition is studied. The sensitivity of oil recovery in a 2D quarter five-spot pattern to relative permeability, WAG ratio, slug size is also studied. CO2 – NGL mixture is a very effective solvent for this reservoir. The minimum miscibility enrichment is more sensitive to pressure for Prudhoe Bay gas – NGL mixtures than in the case of CO2 – NGL mixtures. The oil production rate is sensitive to relative permeability formulation. Oil recovery is faster at lower WAG ratio and higher slug size.
Detection and Reuse of the Produced Chemicals in Alkaline-Surfactant-Polymer Floods
Authors: Wang Wei , Gu Yongan 
Published: December 2007

AbstractAlkaline-Surfactant-Polymer (ASP) flood processes have been increasingly applied in the oil fields due to their high ultimate oil recovery. However, a major technical challenge is how to significantly reduce the amount and the cost of chemicals used such that ASP floods can become cost-effective as well. On the other hand, field applications show that the concentrations of alkali, surfactant and polymer remain relatively high in the produced fluids of ASP floods. Thus, successful detection and reuse of these chemicals can substantially reduce the capital cost and the environmental impact. In this paper, several methods are applied to detect each chemical and quantify its concentration in the produced fluids. Also re-injection of the produced chemicals is conducted for further enhancing oil recovery. More specifically, first, the total interactions of each chemical with the oil-brine-rock system are studied. With the developed detection techniques for each individual chemical used in ASP floods, the total loss of each chemical is measured. The chemical loss is caused by its chemical reactions with the crude oil and the reservoir brine, as well as its adsorption onto the rock surface. Secondly, coreflood tests are performed for alkaline floods, surfactant floods, alkaline-surfactant (AS) floods, and ASP floods to determine their respective tertiary oil recovery. Hence, a better understanding of how each chemical contributes to enhanced oil recovery (EOR) is achieved. Thirdly, typical chemical concentrations in the produced fluids are measured and compared with those in the injected slugs so as to determine the potential of reusing these chemicals in practice. The follow-up coreflood tests of reusing these produced chemicals are carried out by directly re-injecting the produced fluids. The test results show that the produced chemicals can still effectively enhance oil recovery by up to 19.7%. It is anticipated that the detection and reuse techniques studied in this work should facilitate the design, optimization and implementation of ASP flood projects.
WAG Pilot Design and Observation Well Data Analysis for Hassi Berkine South Field
Authors: Lo L. L. , McGregor D. S. , Wang P. , Boucedra S. , Bakhoukhe C. 
Published: December 2007

Abstract
The Hassi Berkine South field (HBNS) is an undersaturated, low-viscosity, moderate permeability oil field within the center of the Berkine Basin in Algeria (Fig. 1). Discovered in January 1995, the HBNS field had first oil production in 1998 from the Trias Argilo-Greseux Inferieur (TAGI) reservoir with a reservoir development plan (RDP) of crestal, miscible gas injection and peripheral waterflood. Full-field WAG, as a secondary recovery process, is currently under investigation for the potential increased oil recovery and higher oil rate. This paper describes the design of the miscible water alternating gas (MWAG) pilot test and presents novel techniques for correcting observation well log data to reflect the miscible displacement process.
A simulator sector model for the pilot area was used to design the MW AG pilot parameters (e.g., solvent/water volume, WAG ratio, timing). Next, measurements from the first WAG cycle were used to calibrate key parameters in the sector model, and to define WAG parameters for subsequent cycles.
For the initial pilot design analysis, the fine areal gridding and vertical layering were taken from the Prudhoe Bay pilot simulation experience1,2. The objective of the pilot design is to collect optimal data from the observation well in the shortest possible time. The initial simulation work defined solvent injection rates, slug sizes, cycle lengths, and WAG ratios to achieve these goals.
Subsequently, reservoir calibration with surveillance measurements from the first WAG cycle allowed for fine-tuning of key MWAG parameters. This work required correcting hydrocarbon saturations from the surveillance tools to be representative of the miscible displacement process. A method has been developed to correct log-derived immiscible saturations to reflect the miscible process occurring in the reservoir and simulated in the sector model.
A Quick Method to Determine Permeability-Anisotropy Orientation from interference Testing
Authors: Chen Her-Yuan , Teufel Lawrence W. 
Published: December 2007

Abstract
This study provides a quick method to estimate the orientations of permeability/flow anisotropy from pressure interference responses only. The method can identify a 90-degree range of the anisotropy orientation from two observation-well responses and a range approximately 45-degree (or less under favorable conditions) from three observation-well responses. Formal analysis (such as type-curve or simulation matching) and information of reservoir-fluid properties are not required.
Significances of the developed method are: (1) It provides solution bound that contains the unique solution (if exists). (2) It may be the only solution obtainable if the adopted formal method (such as Papadopulos-Ramey procedure) fails (which is not known a priori). (3) It provides the most desirable information, namely, the anisotropy orientation, from a timeconsuming and expensive (e.g., lost production) interference test. (4) It can be implemented for two observation wells.
The validity of the developed method is demonstrated by one ideal and two field examples. We strongly recommend the developed method as part of "diagnosis" prior to any formal interference-testing analysis.