bluuebunny/crossref_metadata_2025_split huggingface dataset:
Towards 2000: ADNOC's Plans for Health, Safety and Environmental Impact Assessments
Authors: Al Mansouri Majid , Brett Robert , Al Tamimi Yusri , Chatter Jack , Rowe Patrick , Smies Maarten 
Published: December 2007

Abstract
Global awareness and concern over Health, Safety and Environment (HSE) has been rapidly increasing all over the world, particularly over the last decade, attention is focussed more often on the oil Industry and its derivative subsets because fossil fuels is used as its main feed stock. The Abu Dhabi National Oil Company (ADNOC) being the leading oil company in the United Arab Emirates (UAE), has adopted an attentive approach to its future Health, Safety and Environmental Management System, whereby it is mandatory now for all new projects to have Health, Safety and Environmental Impact Assessments (HSEIAs) carried out at the four stages (initial engineering design, construction, operation to eventual decommissioning) of the project life cycle. In order to ensure successful implementation of this strategy, it is essential to understand and fully account for the impacts and risks linked to existing operations and approved future expansion plans. To achieve this goal, ADNOC has embarked on an ambitious project to acquire this knowledge by compiling a baseline HSEIA on all of its existing activities and plans by the year 2000. This paper describes the collective way in which the project was launched, the methodology used to undertake the project and the way that ADNOC interacted with its own Group Companies and international HSE Consultant firms to ensure efficient and cost effective implementation of the plan.
This project although in its early stages of implementation, but the lessons learned so far can be applied to other organisations pursuing similar aims.
Utilization of Gas Turbines in LPG PLANT
Authors: Mousa Hatem 
Published: December 2007

Abstract
Abu Dhabi Gas Industries Ltd. (GASCO) operates in its four LPG plants a large fleet of Aeroderivative and Heavy Industrial Gas Turbines as mechanical drivers for Gas Compression and Electric Power Generation packages. GASCO's turbine fleet accounts for 370,000 installed horsepower in addition to 280,000 KW generating capacity.
This paper summarises GASCO's experience which has been gained over 4 Million accumulated run hours under the Gulf environment.
Importance Of The Operator's Involvement In Project Development
Authors: Coupaud Jean-François , Yahya Amer 
Published: December 2007

Abstract
Large projects in the Petroleum Industry are traditionally handled by a dedicated project team reporting to a "Projects Division". For obvious reasons of stability, planning and cost, the Operator's involvement is usually reduced between the issue of the Pre-Project report and the Commissioning or even Start-up of the facilities.
Outcrop-Behind Outcrop Characterization of Thin-bedded Turbidites for Improved Understanding of Analog Reservoirs: New Zealand and Gulf of Mexico
Authors: Slatt R. M. , Browne G. H. , Davis R. J. , Clemenceau G. R. , Colbert J. R. , Young R. A. , Anxionnaz H. , Spang R. J. 
Published: December 2007

Abstract
Well log, well test, and seismic data provide excellent structural and stratigraphic information on subsurface reservoirs, but may not be able to resolve small-scale vertical and lateral attributes which may control oil or gas production. Outcrops can provide this important information provided they are of sufficient areal extent. In this paper, we demonstrate the application of outcrop and behind-outcrop characterization for improved understanding of thin-bedded turbidite reservoirs in the Gulf of Mexico and elsewhere.
A 200m high by 10km long coastal cliff section of the Late Miocene Mt. Messenger Formation, New Zealand consists of 200+ meters of thick-bedded turbidite fan sands and associated thin-bedded fan-fringe sandstone/siltstone, overlain by 300m of thin-bedded slope fan, levee/overbank sandstone/siltstone. This section was characterized at the ‘seismic’ to individual bed scales. Also, 47 and 105m deep holes were drilled behind the cliff face, cored, and logged through the slope fan facies with Fullbore Formation Micro Imager* and Platform Express* logs. A slope-fan model is presented which differentiates proximal levee facies composed mainly of discontinuous, erosionally-truncated Bouma Tb-c beds from distal levee/overbank facies composed of more continuous, thin-bedded strata owing to fewer truncations. An associated channel-fill facies is composed of sandstone/siltstone interbeds which become muddier upward. These three facies exhibit distinctive dip and borehole image patterns.
The model demonstrates the application of outcrop-behind outcrop characterization for improved understanding of thin-bedded turbidites in analog reservoirs. For example, a permeability vs. lithofacies relationship established for the Mt. Messenger strata is common in Gulf of Mexico thin-bedded turbidites. Also, the thin-bedded levee/overbank reservoir facies of the Ram/Powell Field "L sand" in the Gulf of Mexico exhibits very similar features to those observed in outcrop and behind-outcrop cores and logs. Gas production rates of ~100 MMCFD and 9600 BCPD have been achieved from a horizontal well placed in the "L sand" proximal levee facies.
In the broader sense, interactive workstation analyses of lithology, bed thickness, and dip-set groupings seen in the high resolution, behind-outcrop borehole images were used to identify depositional cycles and facies transitions based upon calibration with core and outcrop patterns. The same image analysis methods have been applied to other exploration and production wells in the Gulf of Mexico; one Neogene turbidite example is illustrated.
Adjustable Stabiliser Drilling: A Demanding North Sea Horizontal Case History Success
Authors: Greener M. , Anderson C. , McLellan W. , Hough S. 
Published: December 2007

Abstract
The placement of an adjustable stabiliser in a near bit rotary application is being used with considerable success to drill the extremely demanding horizontal wells in BP's current North Sea Harding Project. High performance horizontal drilling, allied to optimal reservoir performance, is considered paramount to success and specific reference is made to the technical attributes and benefits of utilising the adjustable stabiliser system. Inclination control of the horizontal rotary assemblies is obviously critical with regard to drilling, but it is also proving to be crucial in relation to the holistic total life- cycle management considerations of these very demanding and challenging wells.
P. 9
Modeling the Properties of Crude Oil and Gas Systems Using RBF Network
Authors: Elsharkawy Adel M. 
Published: December 2007

Abstract
This paper presents a new technique to model the behavior of crude oil and natural gas systems. The proposed technique is using a radial basis function neural network model (RBFNM). The model predicts oil formation volume factor, solution gas- oil ratio, oil viscosity, saturated oil density, undersaturated oil compressibility, and evolved gas gravity. Input data to the RBFNM are reservoir pressure, temperature, stock tank oil gravity, and separator gas gravity. The model is trained using differential PVT analysis of numerous crude oil samples collected from various oil fields. The proposed RBFNM is tested using PVT properties of other samples that has not been used during the training process. Accuracy of the proposed network model to predict PVT properties crude oils and gas systems is compared to the accuracy of numerous published PVT correlations. The physical behavior of the model is also checked against experimentally measured data for the test samples. The results showed that the RBFNM is reliable and has better accuracy than the conventional PVT correlations. The model can be incorporated in reservoir simulators and can also be used to check the accuracy of future dilferential PVT reports. This study also shows that once this model is properly trained it can be used to cut expenses of frequent sampling and laborious differential PVT tests. The RBFN model can also be used to forecast PVT properties needed for reservoir and production engineering calculations such as material balance, reservoir simulation separator design, and vertical performance design.
P. 35
A Dynamic Model and Simulation for Killing of Empty Hole Blowout
Authors: Jun Fan , Tai-He Shi , Zhang-Gui Lian 
Published: December 2007

Abstract
To kill blowout wells from which all drilling mud has blown out needs some specific knowledge and understanding of how to determine and plan relevant parameters related to a successful killing job. A comprehensive mechanistic model is developed to characterize the cocurrent flow of gas/liquid and dynamic pressure response within borehole, and investigate the complete kill procedures and the necessary conditions leading to a successful kill operation under any given blowout conditions. The model is composed of a set of equations with respect to gas/mud transient flow natures, gas influx and pressure balance relationships.
Based on the theoretical model, a computer program was constituted by solution of the appropriate equations with numerical method, which is currently capable of simulating the complete empty hole blowout process and showing the typical values and results for development and variations of the fluids distribution, flow rate, fluid density and pressure profile along wellbore.
Simulation results indicate that for any given empty hole blowout situations, there is a certain parameter combination region associated with the allowed annular pressure, injection rates and kill mud densities. If the planed kill parameter combination does not fall into such a region, a blowing well is impossible to be killed.
P. 47
Recruitment - The Role of the Headhunter
Authors: Mason B. 
Published: December 2007

Abstract
The purpose of this paper is to examine the growing role executive search and recruitment firms play in the recruitment of human resources, with specific reference given to the oil and gas industry. Growth in the South East Asian oil industry in the early to mid nineties, coupled with the flattening of many organisational structures, created a dearth of management, commercial and technical personnel with suitable skills, knowledge and ability to meet demand on a global basis. It is predicted that the availability of experienced and competent people will continue to fall short of demand, particularly at senior management and executive levels and companies will be forced to recruit key personnel from the international marketplace. Changes to the process and standards adopted by search consultants has led to an increasing acceptance and use of their service. By forming an alliance with large, international consultancies, organisations will gain access to a vast pool of potential employees and will recognise the significant advantages of outsourcing the recruitment function. Changing communications technology, legislation and mobility of personnel as they seek to enhance their competence and attain personal satisfaction, will continue to be significant factors affecting human resource management in the future.
A Multidisciplinary Approach to Characterize the Hu-12 Oilfield, East China
Authors: Chen L. , Niu Y. , Wong P.M. , Wang L. 
Published: December 2007

Abstract
Multidisciplinary reservoir characterization is important to the study of complex onshore fault-block reservoirs in China. Hu-12 fault-block reservoir is a very heterogeneous oil reservoir with high water-cut. The major problem for the Hu-l2 development was the use of imprecise geological models provided by qualitative methods, which could not handle the heterogeneities in a quantitative manner. This study employed an integrated reservoir characterization approach to reconstruct the geological models for the above reservoir and to provide further development options. The case study uses a multidisciplinary knowledge from geology, geochemistry, well logging, reservoir engineering and computational intelligence to combine static and dynamic characterization. The final product of the above integrated study is the distributing patterns of remaining oil in the Hu-l2 Oilfield. Further drilling prospects are provided to extract the remaining oil in the potential areas.
P. 91
Difficult Drilling Requires Faster Learning - A Case Study
Authors: Wilson C.A. , James C.M. 
Published: December 2007

Abstract
This paper describes the processes involved in the developing of a learning culture, and implementing organizational learning software as a pilot project. The chosen location for the pilot project was Chevron Niugini's Drilling Department at the Iagifu Ridge Camp in the Southern Highlands of Papua New Guinea. The Pilot was part of a larger joint effort by Mobil, BP, Texaco and Chevron (MoBPTeCh) to understand how to more effectively capture and share experience in well operations.
Over a period of six months, Organizational Learning System software was customized to suit the unique drilling operations in Papua New Guinea. To accommodate the system, a cultural change, relative to "learning", was proposed for the office and the rigsite personnel. It was necessary that the ownership of becoming a learning organization was accepted by all personnel involved. The rigsite is the initial location where an organization will determine if the well plan requires modification. The real- time rigsite understanding, verification and assurance of the plan changes is the driver for continued learning. Subsequently, incorporating lessons into future well planning is essential for anticipated improvement. Both of these actions have been crucial to the success of the implementation of the system. All changes and decisions are documented in the Organizational Learning System, with future well plans, created in the office, reflecting these documented alterations.
This paper examines the keys to obtaining a learning culture both in the office and at the rigsite, as well as highlighting other benefits obtained by implementing the Organizational Learning System software at Chevron Niugmi.
P. 101
Monobores - Making a Difference to the Life Cycle Cost of a Development
Authors: Macfarlane M. S. , Mackey P. A. 
Published: December 2007

Abstract
Monobore completions offer significant full-life cycle cost savings for the future development of the Cooper Basin in Australia. In May 1997 Santos Ltd., established a multidisciplinary Monobore Review Team comprising Reservoir, Drilling and Geoscience personnel to: Review the South Australian Cooper Basin monobore population to identify issues that could promote the wider use of monobores for optimising gas development.Identify cost savings associated with the adoption of monobores as the ‘standard’ wellbore design.Define the Ideal Monobore and the minimum Wellbore (Integrity) requirements.
This paper describes the results of the Review Team’s work. It covers the paradigm shift required to implement monobores as a ‘standard’ wellbore design, the initial operational problems encountered, the cost savings realised and some of the "Blue Sky" potential that monobores offer.
Gas Injection Technique to Develop Rim Oil, Mereenie Field, Australia
Authors: Kabir M. , McKenzie P. , Connell C. , O'Sullivan T. 
Published: December 2007

Abstract
The Mereenie Oil and Gas Field, situated in the Amadeus Basin in Central Australia, is the largest onshore oil field in Australia, containing some 367 million barrels of original oil in-place and 900 billion cubic feet of original gas in-place. Oil is contained in an elongated, anticlinal trap in multilayered reservoirs as rims associated with large gas-caps. Expansion of solution and gas-cap gas is the primary oil recovery mechanism. However, most of the oil is contained in narrow, thin rims in tight reservoirs which are considered marginally economic for development.
The Pacoota Sandstone is the major oil bearing unit The rims have been partially developed by drilling wells at a one kilometre spacing. The Pacoota Sandstone is Cambro-Ordovician in age with six to nine percent porosity and 5 to 50 md permeability. Dedicated production wells have been drilled for the upper and lower reservoirs at an optimum distance from the gas-oil contact to maximise primary recovery. Based on production performance, the average, primary oil recovery factor in the developed rim area is estimated at 28% of the original oil in-place.
A previous reservoir simulation study had indicated that two to three percent incremental oil recovery could be achieved by reinjecting the produced gas into the gas-cap. Recent modelling has shown a 10% to 14% incremental oil recovery by reinjecting gas directly into the oil rims. This innovative rim injection technique provides direct displacement of bypassed and unaccessed oil as well as pressure maintenance. The optimum spacing (between producers) for this gas injection technique is estimated at 1.5 km compared to 1 km for the primary development Simulation modelling shows that, unlike primary oil recovery, this secondary recovery is less dependent on well distance from the GOC.
A pilot test is currently underway. Based on the encouraging results from the pilot test and simulation results, a field development strategy is proposed.
P. 153
Current Plans, Future Prospects and Technology Challenges for Developing Oil Fields in Blocks 01 & 02, Cuu Long Basin Offshore Vietnam
Authors: Ramachandran S. , Thuy V.T.C. 
Published: December 2007

Abstract
This paper describes current plans, future prospects and technology challenges envisaged by Petronas Carigali Vietnam Sdn. Bhd. PC(V)SB in developing the oil fields in Blocks 01 & 02, offshore Vietnam. Following the signing of the Production Sharing Contract (PSC), PC(V)SB as operator and contractor to Vietnam National Oil and Gas Corporation (PetroVietnam), was entrusted to explore and develop any potential commercial discoveries in the Blocks 01 & 02 of the Cuu Long Basin in Vietnam.
The majority of oil discovered to date has been found in Tertiary sandstone and complex Pre-Tertiary age fractured granitic basement reservoirs. The Ruby field, its first commercial discovery will be developed in two stages. The phase I or pilot production phase project development plans are currently underway where first oil is expected to come on stream sometime end of this year. Valuable static and dynamic information obtained from the pilot phase will then be used to formulate the Ruby full field development plan. The other smaller discoveries of Emerald, Pearl and Diamond fields are currently seen as sub-commercial for a standalone development. As such the development of the Ruby field is seen as vital, as it will form the hub for future infrastructure integration and aggregation in order to commercialise the smaller fields.
New and sophisticated technology application will be required for production monitoring, prediction and reservoir management from the fracture granite basement, hydraulic fracturing and drilling extended reach wells to maximise ultimate recovery and to further reduce the overall development cost.
Additionally, in order to minimise flaring and to help recover the associated gas economically, a gas gathering scheme to collect and process the associated gas for the growing Vietnam gas market demand will be looked into as part of the Blocks 0 1 & 02 full field integrated development plan.
P. 185
Planning, Execution and Lessons Learned From the GWA13 Extended Reach Drilling Well - Goodwyn Gas/Condensate Field, NWS, Australia
Authors: Dolan S.P. , Crabtree R.C. , Drury R.F. , Gogan R. , Hattersley G. , Hindle D. , Neufeld B. , Scaife R. 
Published: December 2007

Abstract
GWA13 was the last well during Phase 1 of the development of the Goodwyn field and was drilled to a total depth of 8420m (27620') AHD with a horizontal step out of 7372m (24190') at a TVD of 2866m (9400').
The paper describes the planning processes before spud, and the equipment, techniques and directional control used during the drilling phase. Lessons that can be applied to both our own and other operations will be listed. The team approach to the drilling of Goodwyn wells will be emphasised and the risk assessment measures used both in the office and on the rig will be detailed.
P. 271
Head-hunting - Head-counting : A Perspective On Responsible Recruitment
Authors: Duce Grenville 
Published: December 2007

Abstract
The aim of this paper is to illustrate how the radical changes that have occurred within the global oil and gas industry over the past decade, have impacted on the areas of employment and career development. Like the oil market, Petroleum Engineering is not constrained by boundaries and the changes we have seen in Australia are not unlike those seen elsewhere such as Europe and North America.
A number of influencing factors which brought about change include:
– The collapse of the oil price in 1986 and continued restricted oil price – A decade of limited graduate intake and training – A decrease in the number of experienced professionals – The trend toward higher productivity performance through technology – A new focus on competencies and capabilities
These changes require a fundamental shift in the way in which the industry recruits, selects and ensures the on-going supply of well-trained people. This paper will cover past events and practices, the lessons learned and how those lessons can be translated into "Making a Difference" for the ongoing viability and sustainability of a company's development and potentially, the industry as a whole.
P. 416
A Small Joint Venture Operator's Approach To Intergrated EH & S Management
Authors: Kegg Brian 
Published: December 2007

Abstract
Throughout the mid 1970s, 1980's and early 1990's West Australian Petroleum Pty Limited (WAPET) introduced a number of individual initiatives in an endeavour to better manage its EH&S performance. A number of these initiatives such as STOP For Safety, Contractor Management, Quarantine Procedures, and Incident and Injury Reporting and Investigation etc. have been modified over time to cater for changes within the organisation, but are still in use today. However, it has been the move towards an integrated Environment, Health and Safety Management System (EH&S MS) and Safety Cases for the producing assets that has demonstrated consistent beneficial trends in EH&S Performance.
The development and implementation of WAPET's current EH&S MS, and Safety Cases for its producing assets represents a significant investment in both monetary and personnel resources and the drivers for such changes both internal and external, as well as the impacts and outcomes need to be understood by others contemplating a similar approach to EH&S management.
P. 441
New Completion Techniques Applied to a Deepwater Gulf of Mexico TLP Completion Successfully Gravel Pack an Openhole Horizontal Interval of 2400 Feet
Authors: Duhon Pete , Holley Alan , Gardiner Nick , Grigsby Tommy 
Published: December 2007

Abstract
As the scope of development continues to expand, more instances are being noted in which traditional technologies cannot satisfy job parameters. In deepwater projects, for example, high-rate production and completion reliability present major challenges to operators, and traditional methods of sand control often have not been able to address the changing conditions. In this paper, a solution that combines gravel packing, enhanced downhole tool capability, and advanced fluid technology is used in an offshore environment in which the completion was performed in a horiontal openhole extended-interval wellbore from a deepwater tension leg platform (TLP). New gravel pack tools and procedures were developed to meet the stringent requirements of the proposed scenario and will be discussed. The successful application of the first extended horizontal openhole gravel packs in the Northern Gulf of Mexico has proven that gravel packing can be successfully applied to extended horizontal wellbores.