bluuebunny/crossref_metadata_2025_split huggingface dataset:
Communicating Best Environmental Practice Throughout an Organization A Web Site Based Example
Authors: Cranmer G. J. 
Published: December 2007

Abstract
For the past three years BP Amoco have been compiling, as part of their Drilling Environmental Awareness Programme, an Intranet based web site on current best environmental practice in drilling operations. The aim of the site is to provide a single point resource for BP Amoco related environmental guidelines and strategies, to ensure information and technology transfer and enable knowledge sharing. It allows drilling engineers anywhere in the organisation to: access relevant information for their current operation, including: regulatory information, key environmental aspects and the best practices for fluid design, rig design, waste management etc. in order to comply with the legislation;compare their current or proposed operating practices with those from other similar areas in order to provide assurance and to generate possible new options for improvement.
The site contains information on a range of BP Amoco operating areas (Business Units). To allow for easy comparison of similar operating areas, the site has been divided into key environmental habitats, e.g. marine, land, polar. Typically each operating area contains an overview on the operation (from a drilling perspective) together with sections on legislation, well planning (including mud/rig and site selection) and well operations (including waste management). All information has been formatted into an easy-to-understand layout, containing, where appropriate, hyperlinks to relevant web sites, documents and key personnel (via e-mail).
Business Model for Implementing Health Care in International E&P Operations
Authors: Grice Kevin J. , Thomas Melissa L. 
Published: December 2007

Rationale for Developing a Business Model for Health Care
With the decentralization of corporate services in 1997, the worldwide exploration and production business unit assumed complete ownership for all support services in 1998. Occupational Health Services was decentralized from the corporate model that has one medical director responsible for all domestic and international programs. The responsibilities were transferred to an internal medical group to manage both domestic and international services for E&P Operations.
The new Occupational Health group was now challenged to provide medical services overseas that addresses these three fundamental questions:Are we providing the appropriate services to all affected personnel in all parts of business?Does the level of service compliment the operations business plan?What knowledge transfer occurred to help raise the level of awareness within the business units?
A series of international health reviews was conducted to characterize the state of health care internationally. The reviews identified that there was no consistent level of health care provided. Each operation would independently arrange medical services to cover personnel and dependents. The corporate health reviews were interpreted by the operations as an audit. The findings and recommendation lacked specific business solutions. The recommendations would set medical priorities; however, they did not provide service cost comparisons or implementation timelines.
As a result, the business units were unable to either complete or take appropriate action on the listed recommendations. By identifying these deficiencies within our international occupational health system, the group was able to set the realignment objectives for our new organization.
The worldwide exploration and production group was challenged to develop a business model for managing health care that is aligned with the project lifecycle. The group formulated objectives based on the following objectives and philosophy:Establish a minimum standard of careCustomize the standards to each operating countryClose gaps with any noted deficiencies by providing business solutions, costs proposals, priorities, and implementation schedulesTransfer ownership of medical services to the country operation or business unitContinuously improve upon the existing medical services and infrastructureAllow for strategically managing medical services within the local community via alliances and establishing appropriate relationships with the National Governmental Organizations
Reduction of Emissions to Air Through Energy Optimisation on Offshore Installations
Authors: Kloster Pål 
Published: December 2007

Abstract
Increasing fuel cost and concern regarding emissions have incurred focus on energy conservation on offshore oil and gas installations. On the Norwegian continental shelf there has been an increased commercial value of natural gas and a CO2- tax on fuel consumption the last 10 years. For the time being the alternative value of natural gas is in the range 0 to 0.06 EUR/Sm3 and consumption of fuel is taxed with approx. 0.09 EUR/Sm3 burned. This has brought forward significant changes in operational procedures and technology development on the Norwegian oil and gas installations compared to installations in other oil and gas regions throughout the world. Focus has increased on keeping the power requirement down, avoiding unnecessary fuel consumption and designing more energy efficient systems. The most efficient way of achieving this is by installing cold process flares and steam cycles on existing or new gas turbines to form Combined Cycles (CC). In Norway three steam cycle plants fueled by gas turbine exhaust are under completion on offshore oil and gas installations. The overall electrical efficiency of these plants is around 50%. When steam is extracted for process heat the overall thermal efficiency is higher. Compared to conventional simple cycles the combined cycle reduces consumption of fuel gas and emissions of CO2 and NOX with minimum 25%. When designed as alternative to conventional simple cycle solutions, a combined cycle represents an alternative investment reducing the size and/or the number of gas turbines needed. This gives a good contribution to the overall Life Cycle evaluation in favor of the combined cycle option when compared to the simple cycle option.
Waste Inventory and Tracking in SPDC
Authors: Benebo T. E. T. , Adesida A. A. , Oyebanji A. R. , Okonkwo N. M. T. , Balogun T. G. 
Published: December 2007

Abstract
That generation of waste is a daily occurrence in all human activities cannot be challenged, however that cannot be said of effective management of such waste. With increasing global concern on environmental management, there are increasing challenges to waste management in the industry. Stringent regulatory measures are being put in place to ensure that waste generated during industrial and domestic activities are effectively managed and accounted for. The first line of actions in waste management is the identification, characterisation and the quantification of waste generated and disposed. How well is the waste quantified? How effectively is it tracked? How accessible are waste information? These and many more are the issues the Waste Management System Software(WMSS) is designed to address.
Horizontal Open Hole Well Displacement Practices: Effect of Various Techniques on Well Productivity, Operational Complexity, and Overall Project Economics
Authors: Mathis Stephen P. , McCarter Michael L. , Schottle Gary , Upchurch Eric R. , Gleason Mike 
Published: December 2007

Abstract
Open hole gravel pack completions can have many advantages over comparable cased hole completions. This is especially true for horizontal well applications. However, because no perforations are present to penetrate the filtercake, borehole conditioning prior to gravel packing is critical to ensure good well productivity. To address this issue various borehole cleanup techniques have been developed. These different techniques have been adopted to address specific reservoir and economic conditions. Various levels of success have been realized for these techniques, with their development leading to an improved understanding as to which steps are critical for success under any circumstance.
This paper reports performance results from gravel packed horizontal wells completed in the East Wilmington Field. In addition, techniques applied elsewhere are reviewed. The conditions that must be met in all displacement techniques to ensure a successful completion are outlined, as will the benefits and drawbacks of each of the commonly applied methods. Guidelines for selecting a wellbore cleaning procedure to employ in specific situations are provided.
Performance of Horizontal Wells in Gas Condensate Reservoirs, Djebel Bissa Field, Algeria
Authors: Dehane A. , Tiab D. 
Published: December 2007

Abstract
Properties of gas condensate reservoirs are particularly difficult to study due to the composition and phase changes of light components that occur during the reservoir depletion. At the first stage of their discovery, these reservoirs behave like gas reservoirs during depletion. Once the dew point pressure is reached at reservoir conditions of pressure and temperature a retrograde condensation phase develops in the reservoir. Liquid condensation in the formation can result in severe loss of well deliverability and therefore of gas and condensate recovery, which will certainly lead to a loss of income.
In this study, the performance of horizontal wells and vertical wells in Gas condensate reservoirs is investigated under various depletion schemes. The expected low horizontal well drawdown pressure, compared to vertical well for the same flow rate, considerably reduces retrograde condensation. A reservoir simulator is used to compare liquid saturation profiles in the case of horizontal and vertical wells in Gas condensate reservoirs. The influence of the horizontal well length section and reservoir thickness on horizontal well productivity, and condensate recovery were also simulated. Another factor investigated in this study is the effect of drilling a horizontal well in a Gas condensate reservoir that has already been developed by vertical wells.
To illustrate the productivity increase due to the use of horizontal wells in gas condensate reservoirs, Djebel Bissa field data are presented and discussed using a compositional single well model (VIP simulator). The main results of this investigation are:
Because pressure drawdown is smaller for a horizontal well than that for a vertical well, the problems related to the liquid deposit can be reduced by the use of horizontal wells. Layers of value of kh contains the most liquid accumulations.
Use of MASTER Web to Improve History Matching
Authors: Chang Shih-Hsien , Grigg Reid B. , Sung Andrew H. 
Published: December 2007

Abstract
History matching is a long-standing problem in reservoir simulation. Although automatic history matching is a difficult process due to the large number of variables and high degrees of uncertainty, it is possible to develop methodologies to improve the matching process. This paper presents MASTER Web, a software tool for configuring a web-based parallel computing system on a cluster of PCs to support a new approach for history matching. A simple, Java-based software has been implemented to connect/communicate heterogeneous (different hardware and operating system) PCs for carrying out the matching process. MASTER Web, a loosely coupled parallel system (with no shared memory) configured in a master-slaves fashion, is sufficient for history matching since there is no need for inter-slave-processor communication. Utilizing parallel computing across the network (the Web), this novel technique not only aims to improve history matching, but does it economically on clusters of ordinary PCs, making it affordable for smaller oil companies. There are a great number of applications of this technique in reservoir simulation. Every application that requires a large number of repeated simulation runs can be improved with MASTER Web. The results we obtained are highly encouraging and indicate the great potential of our approach. Our experiments, carried out with a small cluster of PCs, have achieved a significant practical speedup in terms of wall clock time.
Innovative Drilling Fluid Design and Rigorous Pre-Well Planning Enable Success in an Extreme HTHP Well
Authors: Oakley D. J. , Morton K. , Eunson A. , Gilmour A. , Pritchard D. , Valentine A. 
Published: December 2007

Abstract
Drilling in the Qiongdongnan Basin, offshore China's Hainan Island Province, has often resulted in failure to reach desired objectives. Bottomhole temperatures up to 475°F, and pressures requiring mud weights up to 19.5 lbm/gal equivalent, place severe limitations on the performance of drilling fluids and often contribute in failure to reach the desired drilling objectives.
Well Yacheng 21-1-4 was drilled in this basin with the COSDC semi-submersible rig Nanhai V and was spudded on 27th November 1998. TD of 5,250 meters was attained on 20th May 1999 where the bottomhole static temperature was 414°F and the pore pressure was 18.5 lbm/gal equivalent. Logs were run to bottom without incident with no significant drilling fluid related problems and the primary drilling objectives achieved. The success is attributed to innovative, fit-for-purpose drilling fluids and rigorous pre-well planning over a 2-year period prior to the well commencing.
The paper describes the holistic approach to drilling fluid engineering for extreme well conditions. The development of innovative drilling fluids specific to these well conditions, and the rigorous laboratory testing necessary to generate detailed engineering guidelines, are described. Large-scale abrasion and pressure tests were also conducted. Modifications made to the rig design facilitated the management of drilling fluid properties at high density with high flow line temperatures. A portable drilling fluids laboratory, staffed with trained technicians, was installed on the rig to continually pilot test drilling fluid samples and treatments under simulated down-hole conditions. The importance of good communications and global technical support networks proved invaluable during the pre-well planning and for the execution phase of extreme high temperature and high pressure wells drilling.
Successful Isolation of an Overpressured Gas Zone Using an Expandable Drilling Liner
Authors: Metcalfe Paul , Martyn Kevin , Aitken Scott 
Published: December 2007

Abstract
This paper describes how an expandable drilling liner was used to isolate an overpressured gas zone in a well at a depth of over 13700ft. The liner was deployed for a Venezuelan operator in an onshore field. The liner was run below 9-5/8" casing and expanded from 6-5/8" to 9-5/8" thereby retaining hole size and allowing the well to be drilled to TD without a change in the original casing design.
The paper describes the planning involved in preparing the programme and how several new techniques were developed to ensure success in the field. Described in this paper is the selection of under-reaming parameters, development of cement placement techniques for expandable liners, expandable liner burst and collapse calculations and new milling & dressing techniques.
The application of expandable drilling liners to operations in the Asia-Pacific region could be considerable. Several applications have been considered, including offshore Vietnam, Sarawak and offshore Australia. The aim of this paper is to educate the region on the recent improvements that have taken place in other areas.
New Additive for Improving Shearbond Strength in High Temperature and Pressure Cement
Authors: Rudi Rubiandini R. S. 
Published: December 2007

Abstract
The quality of oil well cement is very important in maximizing the rate of production from an oil well. Good bonding between cement and casing also between cement and rock formation are essential for effective zone isolation, hence usually the additive should be added in order to improve the characteristics of standard cement.
The purposes of this research are to find the effect of adding expanding material, burnt pure-MgO, on the value of compressive strength and shear bond strength of API class G in high pressure and high temperature condition.
The method that has been used in this research is evaluating data from simulator, which was set up similar to field condition, 100 – 200 °C and 2000 psi.
According to the research, some conclusion can be drawn: adding expanding additives, in fact, will increase shear bond strength but will reduce compressive strength although generally still higher than recommended minimum value. The Appearance of mud cake will decrease shear bond strength. For compositions without expanding additives, shear bond strength was dropped drastically. MgO shows excellent performance, as expanding additive, in increasing the shear bond strength.
For low conditioning temperature, 100 – 135 °C, MgO that are burnt at 1000 °C are reliable, whereas for higher conditioning temperature up to 200 °C, the pure MgO which are burnt at 1200 °C, are more convenient. The concentration of expanding additives, which could be used to increase the shearbond strength of cements, are around 5%.
Development of a Casing/Drilling System Improves the Drilling Process
Authors: Skinazi E. , Deady R. , Robson D. , Konschuh C. 
Published: December 2007

Abstract
Drilling technologies continue to be driven by — and developed in spite of — the fluctuations in the price of crude oil. In an effort to further optimize the drilling process, especially for deep-water exploration, a system has been developed that allows casing to be run during drilling of a well.
The Casing/Drilling System ("CDS") will save rig time by altering the traditional drilling process. This system has been designed primarily for multi-well offshore platforms, multiwell operations on land, deep-water operations, and for situations requiring operators to drill through and place casing across problem formations quickly. This technology uses a combination of traditional components — bits, mud motors, MWD/LWD tools — as well as some newly developed components that allow drilling of most hole sizes from any drilling unit, with the ability to recover the drilling assembly using wireline or drill pipe.
This paper will describe the physical components and operational aspects of the casing drilling system. Actual well data will demonstrate the value of the system and the lessons learned during initial field use.
NMR T1 and T2 Relaxation in Oil-Based Mud Filtrates at Reservoir Temperatures
Authors: Kumar Nitesh , Jacob James , Davis Lorne A. 
Published: December 2007

Abstract
Knowledge of the nuclear magnetic resonance (NMR) properties of the near-wellbore fluids at reservoir temperature is needed for planning and interpretation of an NMR logging program. If the oil-based mud filtrate (OBMF) is the nonwetting pore phase, it will exhibit long, bulk fluid-like relaxations that can strongly affect the NMR response of the flushed zone. Knowledge of the NMR T1 and T2 relaxations at reservoir temperature is needed, since these parameters have significant temperature dependences. In this work, the bulk-fluid NMR T1 and T2 responses of six oil-based mud filtrates and three drilling fluid base oil samples were measured over a range of elevated temperatures. The present work also has application to NMR lab measurements on core taken with low invasion oil-based coring fluids.
All samples were degassed using a standard helium sparging technique, since dissolved paramagnetic oxygen can greatly reduce the NMR relaxations of refined oil products. The experimental temperature range was approximately 30100 C (546-670 °R). The temperature dependence of the bulk viscosity of each sample was measured using a rolling ball viscometer. The NMR relaxation data was collected on a 2 MHz permanent magnet spectrometer.
There were no important NMR relaxation differences between base oils and their derived mud filtrates. Sample viscosity had an approximately linear inverse relationship with temperature. The sample relaxations varied approximately as the inverse cube power of viscosity, steeper than has been observed in dead crude oils. For all samples, T1 and T2 increased approximately linearly with temperature, tripling from 30 to 100 C (546-670 °R).
Integrated study of Vatyogan oil field, West-Siberian region of Russia
Authors: Sharma R. , Bondarev A. , Sharry J. , Shelepov V. , Greensmith M. , Gavura A. , Kataev O. 
Published: December 2007

Abstract
The western Siberian basin contains some of the largest oil fields in Russia and the former Soviet Union. In early 2000, LUKOil, in cooperation with PetroAlliance, completed the largest integrated reservoir study ever undertaken in the region. The project spanning nearly four years culminated in an enhanced 3D geological and reservoir models of the giant Vatyogan oil field, which holds over 1 billion tons of calculated oil reserves.
The major technical objective was to utilize state-of-the-art technology to create a new 3D geological model of Vatyogan’s six major producing zones, which range in age from Upper Jurassic to Upper Cretaceous and cover a wide range of depositional environments. The new geologic model would form the basis for reservoir simulation models which would guide further operational and development activities in the field. Specific tasks to be accomplished with the new model include: In undeveloped areas: Estimate reserves and prepare a drilling programIn developed areas: Identify areas of by-passed oil and develop an optimum infill drilling and enhanced recovery program to improve production.
A multi-disciplinary team of 25 specialists was involved in various stages of the project. The study began with the creation of a digital database of 3,800 wells from paper records. Newly acquired data such as: 2D and 3D seismic, log data, and high precision gyroscopic surveys were incorporated into the revised models.
This paper describes the processes employed in the project and highlights some of the stumbling blocks. Details are provided describing data management, geological modeling, upscaling and history matching of thousand of wells. Conclusions illustrate how data from the specialized logs and high precision gyroscopic surveys resolved numerous questions and contradictions in the existing data, providing improved reservoir structure analysis and more accurate fluid-contact depths--data which significantly impacted both the models and the simulation forecasts.