bluuebunny/crossref_metadata_2025_split huggingface dataset:
Optimal Practices To Remediate and Control Fines Migration in Inland-Water Wells in the Maracaibo Basin, West Venezuela
Authors: Chávez N. , Colmenares O. , Peña A. , Fuenmayor A. , de Sousa V. , Miquilena E. , Maiz O. , Escobar J. 
Published: December 2007

Abstract
This paper summarizes the following aspects of a comprehensive program intended to develop optimal practices for the stimulation of wells in the Ceuta field, a developing area located in Lake Maracaibo, West Venezuela: lab testing to diagnose formation damage mechanisms and to qualify proposed treatments; operational practices including injection sequence, treating volumes for optimal radial penetration and diversion techniques for uniform placement; recommended safety and environmental practices.
Also, detailed examples of treatments performed in six inland-water wells in the Ceuta, Area 8 South Central area within this field are provided. The average production rate for these wells before the implementation of these practices was 419 BOPD. The implementation of the guidelines provided in this paper resulted in an average post-production rate of 2100 BOPD with a twelve-month average decline rate of 1.6 BOPD.
The enhanced methodology has been implemented with success in other fields in the Maracaibo Lake area known as CentroLago, Lagotreco and Lagocinco. Results from treatments in these areas are also summarized and discussed.
A Study of Normal Slug Flow in an Offshore Production Facility With a Large-Diameter Flowline
Authors: Vázquez E. Guzmán , Fairuzov Y. V. 
Published: December 2007

Abstract
A theoretical and experimental study of a normal (hydrodynamic) slug flow in a pipeline-riser pipe system is presented in this paper. Experimental flow visualization revealed that long hydrodynamic slugs generated in the pipeline do not dissipate in the riser pipe. It was shown that slug dynamics in the riser pipe is controlled by two phenomena: the gravitational forces and the compression of gas in the trailing bubble. It was found that slugs can accelerate in the riser to a velocity more than five times exceeding the average slug front velocity in the flowline. The results obtained can be used to define operating strategies for offshore production facilities with large diameter flowlines.
Solid Expandables Repair Prolific Subsea Gas Producer
Authors: Velden Mark Van De , Funiss Tony , Stewart Kevin A. 
Published: December 2007

Abstract
A working window of opportunity only presents itself from April to mid-September in the turbulent Atlantic waters off the northwest coast of Ireland. When this window opened in Spring 2006, Shell E & P Ireland Ltd began operations to evaluate newly acquired assets in the Corrib fielddry-gas subsea development. Prior to acquisition, five wells had been placed in suspension, pending construction of the necessary subsea and onshore infrastructure. Shell had previously determined that only three wells were viable candidates for completion during the current season and commenced operations when the S711 semi-submersible arrived on location in April. The clock started ticking on favorable weather and time quickly became a crucial constraint issue. The project hit a critical mark when a leak was discovered in the 9-5/8 in. production casing on one of the early wells entered.
With time running out, Shell approached Enventure to engineer a practical solution that was required within a period of six weeks. Possible solutions for recovery were identified and analyzed before the project management team decided on using solid expandable technology. The solution for this well needed to deliver a production casing string that effectively sealed off the hole. To accomplish this requirement with expandable tubulars, Shell decided to use the Enventure system elastomers for the gas-tight integrity, which required qualification. In approximately six weeks, Enventure and Shell planned and implemented the appropriate tests, coordinated logistical maneuvers to expedite expansions to create the test specimen for qualification and successfully installed the actual system in the production well.
This paper will discuss the process used to bring the project to fruition within a tight timeframe. Details will include issues considered, ramifications of possible options, challenges of the operating conditions and circumstances and content and results of the qualification program. This paper will also discuss the philosophical approach of generating a workflow to successfully achieve the stated goals in a short amount of time.
History Matching With an Ensemble Kalman Filter and Discrete Cosine Parameterization
Authors: Jafarpour B. , McLaughlin D. B. 
Published: December 2007

Abstract
History matching of large hydrocarbon reservoirs is challenging due to several reasons including: 1) Scarcity of available measurements relative to the number of unknowns, leading to an ill-posed inverse problem; 2) Computational effort required for large reservoir problems; 3) The need to insure that solutions are geologically realistic. All of these problems can be helped by using algorithms that rely on efficient and parsimonious descriptions (or parameterizations) of reservoir properties. This paper combines a novel parameterization approach, the discrete cosine transform, with a recursive history matching technique, the ensemble Kalman filter, to provide efficient estimation of unknown geological properties in large reservoirs. The application and generality of this approach is demonstrated using two waterflooding experiments characterized by different types of geological variability.
Modeling a Finite-Length Sucker Rod Using the Semi-Infinite Wave Equation and a Proof to Gibbs’ Conjecture
Authors: DaCunha J. J. , Gibbs S. G. 
Published: December 2007

Abstract
In this paper, we study semi-infinite spatial domain wave equations modeling the real world problem of longitudinal waves propagating along a finite length long slender homogeneous elastic rod. To conclude, we provide a rigorous, yet elegant proof to Gibbs’ Theorem and illustrate its validity with an existing well.
Optimization of Fractured-Well Performance of Horizontal Gas Wells
Authors: Magalhaes Fellipe , Zhu D. , Amini Shahram , Valko P. 
Published: December 2007

Abstract
Horizontal well technology has been widely used in developing gas fields. Very commonly, these wells are hydraulically fractured to improve productivity in low permeability reservoirs. A previously developed method, the Distributed Volumetric Source method (DVS), was applied to horizontal gas wells with or without fractures to predict well performance. The method is flexible and can be easily applied. The method provides an effective tool to evaluate horizontal well design and well stimulation design for gas wells.
In this paper, we conducted a well performance study by applying the DVS method to typical gas formations in East Texas Basin, San Juan Basin, and Appalachian Basin.. The objective is to determine the best practice to produce from horizontal gas wells. With the transient flow feature of the DVS method, well placement for multiple horizontal wells in a defined drainage area can be studied, and the limit of well spacing and wellbore length is identified. For fractured wells, well performance of a single fracture and multiple fractures are compared, and the effect of the number of fractures on productivity of the well is presented. Realizing that reservoir permeability and anisotropy ratio are the critical parameters in developing low-permeability gas fields, the effect of permeability on well performance, well placement and fracture treatment design is addressed in the paper.
Strategy for Managing Environmental Liabilities in an Onshore Oil Field
Authors: Austin D. G. 
Published: December 2007

Abstract
Environmental liabilities for an onshore oil field include facility abandonment, well plug and abandonment, environmental investigation and remediation, and land restoration. Having a systematic approach for discharging these liabilities offers prudent fiscal management and business planning, environmental compliance assurance, improvement of company image, minimization of legal claims, and ability to secure resources to implement work.
In 2003, Chevron began to develop a strategy to manage the liability associated with their CPI Sumatra Operations. The first step was to understand the magnitude of the liability by conducting a Liability Inventory. Next, the liabilities were prioritized based on safety, environmental, security, and operational considerations. Cost estimates were completed and an annual plan developed to discharge the liabilities over a selected time period. For larger remediation projects, decision and risk analysis was employed to determine the preferred timing for execution accounting for the time value of money, likelihood of incidents and the consequences if those incidents occurred. Management of liability for facility abandonment also involves asset write off so that integration of this financial process is required.
Technologies and procedures were developed for implementation, focusing on safety and cost effectiveness through standardization. Methods were developed for management of wastes generated which included liquid hydrocarbon wastes, contaminated soils, insulation waste, scrap equipment and piping, and concrete foundations.
Management of environmental liability is an evergreen process. At CPI, we have found that review is necessary twice per year to keep up with all the changes due to new information from environmental site assessments, schedule adjustments usually due to resource limitations, and priority changes due to public pressure or claims.
The paper will describe the strategy, processes, and methods in more detail. This approach may be applied at almost any on-plot facility or off-plot well field to plan for management of liability.
Reconciling Subsurface Uncertainty With the Appropriate Well Design Using the Mechanical Earth Model (MEM) Approach
Authors: Goodman H. E. , Connolly P. 
Published: December 2007

Abstract
The involvement of the well engineer (WE) competency from the earliest phases of exploration is reaping economic benefit for major capital projects (single wells costing at least $25,000,000 US). As the geological and geophysical modeling work of the Explorationists matures and the subsurface picture becomes clearer, the appropriate well design flexibility is being achieved using Mechanical Earth Model (MEM) technology. This approach to well planning is particularly beneficial for deepwater exploration.
For deepwater subsalt plays, the capital outlays are immense, with single wells costing up to $100,000,000 US. For these projects, MEM technology has been found to be extremely valuable, particularly in characterizing drilling risks associated with well exit points below salt where in-situ stress perturbations can occur. These stress perturbations are being reliably mapped using MEM techniques and the consequences to borehole stability addressed. An example of principal stress rotation gleaned from a deepwater MEM and the consequences to borehole stability is summarized in this paper.
Operationalising HSE Cases in Asia Pacific
Authors: Peake D. M. , Sahari Y. 
Published: December 2007

Abstract
Implemented post Piper Alpha, HSE Cases have become a crucial document for demonstrating the adequacy of the management of Major Accident Hazards (MAH). However whilst serving the needs of Regulators and Company Auditors, there has been increasing dissatisfaction with the value they add to Operations personnel even when translated from "Design Cases" to "Operations Cases".
A survey amongst Asia Pacific OIM's yielded common concerns with the current Cases, independent of asset type and operating area (including Regulatory environment), among them:Lack of transparency between daily operations and a Case that "sits on a shelf".Change management.Difficulty in easily understanding/comprehending major hazards.Unwieldy documents that are a "catch-all" for any Health, Safety, or Environmental related issue.Remedial actions that are seldom closed.
A closely related issue is Technical Integrity on aging platforms and the tolerability of equipment state with HSE Cases that dont provide any tangible/practical guidance on ‘acceptability’ of barriers.
To address these concerns Shell Exploration & Production Asia-Pacific (Shell EPA) is implementing a program to "Operationalise" HSE Cases. At the core of the program is the objective to refocus HSE Cases on Major Hazards and provide a roadmap to Company systems (centered on Technical Integrity) that will provide effective barriers during the operational phase.
No element of the program is ‘revolutionary’ but in its entirety provides a cohesive and transparent means of communicating Major Hazards to Operations personnel and providing them a tool to demonstrate that they have the right systems in place to maintain barriers. The Cases are highly focused on Operator's needs, and draws in global best practice from within the Company and Industry.
This paper outlines the issues leading up to revamp of Cases, framing of the program and core issues, selected way forward on Case content, elements required for success, and roll-out/accountability requirements.
Building a Sustainable Proactive Intervention Culture among Workforce—I Care for Your Safety: The Journey by Shell E&P in Asia Pacific
Authors: Koh Richard , King Kai Hii 
Published: December 2007

Abstract
This paper describes Shell EPA (Shell Exploration & Production in Asia Pacific) efforts and strategies to achieve a step change in safety performance by building a sustainable "Proactive Intervention Culture" (PIC) among her workforce, which will intrinsically motivate people to intervene in unsafe acts and situations because they believe in it, rather than because they are being forced or told to.
The paper details the planning and development of the PIC training programme, implementation plan and progress to date by Shell EPA to build a sustainable proactive safety culture among staff and contractors.
Use of a computer simulation to assess Hazard and Risk perception
Authors: Lang Kenneth , Breitsprecher Kathryn , McGrath Tim 
Published: December 2007

Abstract
Hazard identification and risk assessment are at the core of an effective health and safety system. Despite this fundamental, during incident and accident investigation risk assessment processes are sometimes not used effectively and found to be deficient.
The challenge facing both individuals and organizations is that individual risk tolerance and perception of hazards varies significantly according to a host of factors including social and personal values as well as prior experience and beliefs. To truly drive a reduction in incidents a variety of methods need to be used to ensure that workers are aware of the hazards, the risks and the consequences of action/inaction. This will also enable individuals to become aware of their own risk perception and how other factors can affect ones acceptance of risk thereby changing their risk taking behaviour.
This paper presents an innovative method measuring task based risk perception in the form of a computer virtual reality simulation. While not widely used in the oil and gas industry the application of a computer simulation has been valuable in other contexts, such as testing of risk perception in drivers and pilots. This simulation is based on the physical location of a marine based rig during routine rig operations. This simulation therefore gives an important insight into the hazard identification, risk evaluation and risk awareness in the offshore context. Experiences from the application of the simulator are shared and some of the methods of reinforcing the lessons learnt are also discussed.
Possible further developments are considered and in particular how this simulation can be used in the context of both new employees with lack of experience, and experienced staff who may be complacent, as the both groups are vulnerable.
Detecting Ultra-small Leaks With Ultrasonic Leak Detection-Case Histories From the North Slope, Alaska
Authors: Julian J. Y. , King G. E. , Johns J. E. , Sack J. K. , Robertson D. B. 
Published: December 2007

Abstract
A new ultrasonic leak detection logging tool conveyed on electric line, and recently on wireline in memory mode, has been introduced which can detect leaks as small as 1/2 cup per minute. This revolutionary tool has been used to accurately identify leaks in tubing and behind pipe. Wells that otherwise would immediately be slated for a rig workover (RWO) have been repaired with non-rig solutions.
Ultrasound energy has very rapid attenuation and the ability to transmit through various media and behind pipe. These attributes allow pinpoint accuracy for leaks as small as 0.0024 gallons per minute (gpm). The tool incorporates data acquisition equipment and filtering algorithms which allow continuous logging. The technology is far superior to old-style noise logs which require time consuming stationary counts.
To date, BP has run 21 ultrasonic leak detection logs in Alaska fields with an 81% success rate. The recent ability of this tool to be conveyed in memory mode has opened up additional logging opportunities. This has led to the development of a new technique using nitrogen to identify wells that leak only to gas.
Application of this tool has great significance for any operator concerned with well integrity, and particularly, in areas where rig workovers are expensive including remote, offshore, and arctic locations.
Environmental Due Diligence for International Finance of Major Oil and Gas Projects
Authors: Jeter J. L. 
Published: December 2007

Abstract
The European Bank for Reconstruction and Development was founded in 1991 to assist transition in the former communist countries of Central and Eastern Europe towards a free market economy. In line with EBRD Natural Resources Operations Policy (1), over the last few years we have been involved on several large oil and gas development projects in our region of operations. The environmental due diligence on these projects is a significant task, requiring extensive resources by the project sponsor as well as the potential lenders. Complexities in the process are highlighted when there are multiple potential lenders involved with different mandates, internal standards and policy requirements. The EBRD is required to promote in the full range of its activities environmentally sound and sustainable development. As such, our Environmental Policy (2) requires that our projects meet good international environmental practice. This includes applicable national environmental standards and pertinent environmental standards of the European Union.
In our recent experience, project sponsors typically first complete their Environmental Impact Assessment (EIA) required for local permitting/project approval. Once this document has been approved locally and the project has been approved by pertinent authorities, the project sponsor typically uses some form of this document (or data contained therein) as the EIA for financing. While there is merit in this approach, recent experience highlights a number of issues that could be considered to streamline this process in the future. These issues can be grouped under the following headings:Scoping and EIA ProcessLender Engagement and Document CompletionDisclosure ProcessPost Signing and Monitoring
This paper presents a review of the lessons learned based on EBRD involvement on the due diligence of two recent "mega" projects in the oil and gas sector. While this paper clearly will not identify all potential problematic issues that could arise during environmental due diligence for finance, consideration of these factors could help streamline future project finance deals.
Environmentally Safe Waste Disposal: The Integration of Cuttings Collection, Transport, and Reinjection
Authors: Alba A. , Fragachan F. , Ovalle A. , Shokanov T. 
Published: December 2007

Abstract
The development of new oilfield technologies to explore such remote areas as deep waters and environmentally sensitive locations brings with it increased emphasis on protecting the natural resources of the drilling area. Accordingly, many regulatory agencies demanding zero discharge policies require all generated wastes to be disposed in a responsible manner. Such process requires the adequate management of wastes generated during drilling operations including cuttings, excess drilling fluid, contaminated rainwater, produced water, scale, produced sand, and even production and cleanup waste. Old practices involve temporary box storage and hauling of the waste products to a final disposal site. Often, these sites are several kilometers away from the generation source, creating not only liabilities for the operating company but also environmental risks such as accidental spills, gas emissions and eventually high operating costs.
Over the years, waste management technologies have evolved to address environmental solutions in the most efficient and cost-effective processes. As such, Cutting Re-Injection (CRI) nowadays is considered top-of-the line technology for the final disposal of drilling wastes through sub-surface injection into an engineered-designated formation where wastes are permanently contained. Transporting the wastes to the final disposal well poses a challenge in large development fields, where the most cost-effective solution is often to drill a dedicated injector and convey all produced wastes to the site.
This paper addresses the success of integrating methodologies for containing, handling, and transporting drill cuttings from several drill sites to a unique CRI well, where wastes are injected for final and responsible disposal. Case histories of several sites around the world are presented as they used different process configurations to achieve the common final objective: a cost-effective and environmentally friendly solution for waste management.
Marine Subcontractor Safety Management
Authors: Charusalaipong P. , Yimkijboriharn T. 
Published: December 2007

Abstract
Historically, marine vessel support has played an important role in the offshore E & P industries. Especially, present increased of E & P activities but less number of ships in the market. The increased activity has an added on effect to marine vessel workload i.e. more frequent cargo trips with less time in port. Also marine vessel stay out longer at sea, subsequently, crew has less relaxation time and ship has less maintenance time. This will eventually resulted in a breakdown of ship and degradation of crew morale. As a consequence, the marine operation near miss incident trends has been increasing. To counteract this trend, it requires a close scrutiny and well-manage program to divert this marine vessel operating degradation.
Marine Subcontractor management is considered a paramount in achieving Health, Safety and Environment Objective and ensuring safe marine operation. To achieve these goals, a recent company standard was implemented to ensure marine operation safety and manage marine vessels as per the contractual terms and conditions and some satisfactory outcome has initially materialized i.e. less marine near miss incidents.