bluuebunny/crossref_metadata_2025_split huggingface dataset:
Employees Perceptions of Health, Safety and the Environment in an Australian Oil and Gas Producer: A Comparison with the North Sea
Authors: Freeman Melanie L. , Smeeton Rachel , Flin Rhona , Mearns Kathryn , Rachail Gordon 
Published: December 2007

Abstract
The primary objectives of the 1997 Woodside Health, Safety and Environment (HSE) Perception Survey were to establish the perceptions and experiences of employees with regard to health, safety and environment, to generate a baseline series of data on the HSE culture of Woodside and to benchmark Woodside with the perceptions of employees working for six companies in the UK sector of the North Sea. The aim was to identify what HSE initiatives are perceived to be in place within the company, to determine what management is seen to be doing with regards to HSE within Woodside, and to identify what other HSE initiatives or alternatives are perceived to be needed. When benchmarked to the North Sea (n=722), employees on Woodside's offshore facilities (n=l33) had more positive attitudes and beliefs about the communication in their job, their attitudes to safety, their supervisors commitment to safety and their lack of willingness to break the rules than offshore workers in the North Sea. This is despite the fact that they perceive more work pressure in their jobs than employees in the North Sea. The HSE culture of Woodside was defined by employees in a much broader context than that of the North Sea. The Woodside employee concerns revolving around management, contractors and employee attitudes whereas the North Sea concerns revolved around management, employee attitudes and being able to speak up about safety. Overall there appeared to be a good stable safety culture within Woodside (n=682), however the health and environment cultures were not as developed within the company. Individual locations and groups of employees indicated there were specific HSE issues that needed targeting. This paper focuses on these issues and how they are being addressed within Woodside.
P. 431
The Management of Contractor HSE
Authors: Foster David L. 
Published: December 2007

Abstract
Contractor performance with respect to the management of HSE is a constant challenge for any company. Woodside Energy Ltd has over recent years been improving the process applied to contracted work, from prequalification to close out. This process incorporates the application of a number of tools and requirements that give a comprehensive picture of potential contractors and their ability to effectively manage HSE.
The elements that make up the process are as follows: Prequalification of potential contractorsInvitation to tender to prequalified contractorsTender evaluationContract award and pre-startContract monitoringCloseout report
Woodside focus throughout this entire process is on that of influencing the contractor. The purpose of this is to actively encourage the alignment of our HSE cultures in a climate of continuous improvement. This is an area in which a large part of our effort is applied. It is not uncommon for us to actively assist an individual contractor both pre and post award, due to the overall standard of all tenderers not being seen as high as we would wish.
The basis of our contractor evaluation is to determine how effectively they both identify and manage hazards. We look for a robust systematic approach that addresses such issues as documentation, audit, accident/hazard reporting, training identification and delivery and the concept of continuous improvement. This should all be supported by a top down demonstration of leadership and commitment from all management levels.
The evaluation process looks not only at documented responses to questionnaires, but presentations from contractors on how they intend to carry out the contract scope.
The bottom line is that good HSE management is a moral obligation as well as good business. We need contractors to assist us in achieving our business vision, so the investment of time, effort and money up front is one that has a very real potential for high returns, ensuring the safety of those who work with us, integrity of our assets and minimal environmental impact.
Optimised Float-out of Concrete Offshore Platforms Towards Increasing Construction Potential in Australia
Authors: Hill A.B. , Ronalds B.F. 
Published: December 2007

Abstract
With the increasing number of significant oil and gas discoveries in Western Australia and the Northern Territory, there is a predicted demand for a range of concrete gravity structures (CGSs) from the Carnarvon to the Browse Basins and the Timor Sea.
Shallow founded CGSs may be installed in soft or hard seabed conditions, with the softer conditions typically found in deeper water and requiring protruding skirt structures to penetrate the seabed to improve stability and provide scour resistance.
Such open bottom structures are floated by displacing water inside the skirted compartments with compressed air. Where construction and float-out are done in shallow water, small underkeel clearance (UKC) is likely. Wave induced motions of both the structure and the water plug inside the skirted compartments have to be accommodated to ensure that the structure does not touch the seabed and that the water plug motions do not promote the escape of air from compartments.
Pilot research into the dynamics of CGSs with small UKC has been completed and this has identified some very important parameters for inclusion in the design loop of CGSs. The research also identified parameters worthy of more thorough research and with the potential to advance the knowledge base in this area and thus provide local industry with a competitive advantage.
P. 471
Laminaria/Corallina - An Integrated Field Development Planning Approach
Authors: Shaw M.N. , Fowles J.D. , Abernethy S. , Hamp R. 
Published: December 2007

Abstract
The Laminaria and Corallina Fields were discovered in 1994 and 1995, within permit AC/P8 in the Timor Sea, and are currently being developed using subsea wells, manifolds, flowlines and a large Floating Production, Storage and Offloading (FPSO) vessel. Expected reserves for the combined fields ranges from 130 to 250 MMbbl and production is planned to commence in October 1999, five years after field discovery.
In order to achieve this, subsurface development studies have been conducted in parallel with facility concept and engineering design studies. Due to the large range of reserves associated with the two fields, leading edge technology and rigorous uncertainty management techniques have been used to produce a robust development plan. Seismic imaging in this area is particularly difficult and has been enhanced by using Prestack Depth Migration. Even so, structural mapping remains the largest factor contributing to reserves uncertainty.
P. 497
Application of New Generation Technology to Horizontal Well Production Logging - Examples from the North West Shelf of Australia
Authors: Carnegie A. , Roberts N. , Clyne I. 
Published: December 2007

Abstract
The main measurement objectives in production logging are to diagnose well production problems such as the inflow rates and entries of unwanted fluids, supply information for reservoir modeling and provide data to optimize the productivity of future and existing wells. Another important objective is to perform the measurements cost effectively.
In a horizontal well fluid density cannot be measured by the gradiomanometer. Other sensors, such as the nuclear fluid densimeter which rely on a decaying radioactive source, are inaccurate (especially in heavy oil/water regimes), environmentally hazardous and only measure within the liner. Undulations in horizontal well trajectories can cause traps of gas and water to be created at the high and low points, and large changes in fluid holdup and velocity with changes in deviation as small as one degree. Such effects can confuse or even completely invalidate the spinner for flow rates. Fluid entries, including those which are unwanted, often occur over much longer sections than those usually found in vertical wells. Consequently, the temperature effects of such entries are often insignificant, thereby decreasing the value of the thermometer. The fluid flow regimes in horizontal wells can be one or a combination of stratified, bubbly and slug flow. This often invalidates the application of models developed for vertical wells. Hence the measurement objectives in horizontal wells frequently prove difficult or impossible to achieve by using traditional tool strings and interpretation techniques. The traditional mode of conveyance of production logging tool strings in a horizontal well is by coiled tubing, which can often be very expensive and make the costs prohibitive.
The solution to the measurement problems is to employ technology which has recently been developed specifically to deal with the inadequacies of traditional sensors and interpretation techniques. The cost from rig time of employing such technology have been reduced by ensuring that all sensors are conveyed on just one tool string, thereby minimizing rig up and rig down tasks, and eliminating the necessity to pull out of the hole between logging runs. By employing tractors instead of coiled tubing the costs of conveying these sensors have been reduced further.
This paper discusses the problems mentioned above, describes a methodology for solving them, and shows how this has been done successfully in wells in the North West Shelf of Australia.
P. 511
Automated Steering Systems Applied to Complex Horizontal Well in South Italy
Authors: Calderoni A. , Oppelt J. , Ligrone A. , Trampini A. , Gauld S. 
Published: December 2007

Abstract
Automated directional drilling systems were amongst the key deliverables in a recently concluded joint development program between an oil company and an oilfield service provider. The two automated directional drilling systems as developed in the project have a certain degree of commonalty, however, there are also major differences in the way they work. The field experience described here was the first opportunity to run both tools together in the same well. Each of them was able to demonstrate it's specific and unique capabilities. The drilling strategy for Monte Enoc 9 required the use of a straighthole drilling system, SDD, in the upper hole sections and the rotary steering system, AutoTrak, in the 8 ½" hole size. By synergistically using the new automated tools, Monte Enoc 9 was drilled in a much more efficiently than offset wells, producing substantial time savings, a smoother hole trajectory, and less friction. The concluding 6" hole section of the well could be drilled and steered in a much easier fashion than expected because of the good conditions created in the vertical and curved hole sections. The drilling strategy as practiced in ME9OR will be further optimized to allow for even greater savings.
The Brimmond Reservoir Extending the Forties Field Into The Millennium By Maximising Profits Without Expensive Rig Upgrades
Authors: Smith L. , Perras L. 
Published: December 2007

Abstract
How to drill a technically ambitious horizontal well with a minimum facilities workover rig? By careful planning, good drilling practices and the help of some state of the art technology.
The drilling programme was initiated to further develop the Brimmond Field which overlies the Forties Reservoir. The Eocene reservoir was first produced through an 13ft cased hole gravel pack in a previous Palaeocene (Forties) production well. As a result of this success a development phase was instigated, commencing with an 8550ft MD horizontal appraisal and development well.
Feasibility studies had indicated that a significant rig upgrade would be required to facilitate the drilling of a horizontal well within recognised industry parameters. However, upgrading the drilling package would have delayed the project by several months and potentially made the project uneconomical. The challenge was to accelerate the programme by utilising the available minimum facility workover rig. The main limiting factors within the drilling package were: 1x 800hp mud pump, 1 shale shaker, no bulk barite or cement storage, 425 bbls of working mud pit capacity, a kelly and restricted deck space. To compound these limitations, there is no accommodation available and the drilling personnel shuttle daily from other North Sea Platforms.
A number of critical operations were identified which led to the introduction of ‘new technology’ – premixed cement, leading edge LWD tools and hole clean up techniques. After assessing all the challenges, the team embarked on the most technically ambitious well to date for the Forties Field.
Feasibility of Oil Recovery by Chemical Flooding through Horizontal Wells
Authors: El-Abbas A. M. , El-Sallaly M. E. , Sayyouh M. H. , El-Batanony M. H. , Darwich T. M. , Desouky S. M. 
Published: December 2007

Abstract
A laboratory and economic study on Badri crude oil production by polymer, surfactant and surfactant/polymer flooding from a horizontal well in a scaled five-spot sandpacked model was conducted. Crude oil from Gupco* Badri Field was used in the displacement tests. The grain size distributions of the used sand are similar to those of the Badri formation. Surfactant and polymer slug concentrations were 1.0% by weight and 500 PPM, respectively. Physical properties of the surfactant and polymer solutions were experimentally determined to select those most suited for the displacement runs. The suitability of the enhanced oil recovery predictive models**, developed by the department of energy (U.S.A), to predict the experimental data and assess the feasibility of oil recovery by chemical flooding was investigated. Results show that the maximum oil recovery is obtained from the sandpack model by polymer flooding with a slug size equal to 30% of the pore volume. A good agreement exists between the experimental data and values calculated from the software. The economic study revealed the feasibility of oil recovery from Badri oil field by polymer flooding through a horizontal well configuration.
The Model Coupling Fluid Flow in Reservoir with Flow in Horizontal Wellbore
Authors: Liu Xiangping , Jiang Zhixiang 
Published: December 2007

Abstract
In this paper, the 3D steady-state pressure distributions are derived of oil flow in a reservoir due to a horizontal well for several kinds of reservoirs, And based on the principle of conservation of matter and momentum theorem a new formula is also derived to calculate pressure drop along the horizontal wellbore. This formula considers the effect of influx into the horizontal wellbore from the reservoir on pressure drop in the wellbore. A mathematical model is presented to couple fluid flow in the reservoir with the flow in the horizontal wellbore. Example calculations showed that prediction results using the proposed model are in good agreement with test or experimental data. The pressure drop in wellbore has influence on performance of well. Because of the pressure loss in horizontal wellbore IPR curve for single-phase liquid flow in wellbore is not straight line, and production rate does not increase with increasing wellbore length when the length exceeds a certain value. The productivity indices per unit length for all segments along horizontal wellbore are not the same.
Past & Future Contribution of Rock Mechanics Research to Petroleum Engineering
Authors: Kenter C. J. , Currie P. K. 
Published: December 2007

Abstract
A brief historical review is given of the benefits of research and development in Rock Mechanics as applied within Petroleum Engineering. It is concluded that the major challenge for the coming decade is the acquisition of reliable data for input to the existing theoretical models. Successful application in the field of Rock Mechanics research depends not only on having an identified business need and the right technology to fulfill that need, but also requires a committment to dialogue between the researchers and the field.
Experimental and Numerical Upscaling of Two-Phase Flow in Homogeneous and Heterogeneous Porous Media
Authors: Abtahi M. , Torsaeter O. 
Published: December 2007

Abstract
The main purpose of this paper is to present some results of visual two-dimensional model experiments performed to study upscaling methods in both homogeneous and heterogeneous porous media. Well-defined heterogeneous models and fluid systems have been systematically varied to capture the effects of heterogeneity on flow behaviour in small-scale (10x40 cm2) and large-grid block (1.6x6.4 m2) models by three steps.
Heterogeneous and layered models are fabricated using packing of glass beads with four different sizes. Each one of the homogeneous models is packed with one type of glass beads. In order to simulate the immisicible displacement process, a light oil was injected into the models at three different constant rates. The interfacial tensions (IFT) of the system were reduced from 37 to 9.2 and 2.2 mN/m using two types of surfactants. The changes in flow rates and IFT are performed to reproduce the situations that match the capillary and/or viscous-dominated regimes. Totally 24 successful experiments were performed.
The capillary-dominated model represents the small-scale (a typical core laboratory condition) and the viscous- dominated model represents the large block (a typical grid size) where the capillary force is neglected. A three-step scaling-up process is used to capture the effect of the small- scale heterogeneities to medium-scale and finally to the large- grid which can be used in field reservoir simulation. The scaling-up from the small- to medium-scale matches perfectly the experimental data (pressure difference over the model and water cut) for homogeneous, layered and heterogeneous models. The final step, the scaling-up from the medium- to large-grid did not match the experimental results well. The results show that setting the relative permeabilities obtained at low 1FF directly to the large-grid block gives better results than scaling-up of the small-scale (rock curve) using three-step pseudo functions. The low IFT system relative permeability curves can be set directly to the large-grid block provided that corresponding dimensionless number values are equal.
P. 45
Critical Requirements for Successful Fluid Engineering in HPHT Wells: Modeling Tools, Design Procedures & Bottom Hole Pressure Management in the Field
Authors: Gao Erhu , Estensen Odin , MacDonald Colin , Castle Stephen 
Published: December 2007

Abstract
This paper presents developments in the management of drilling fluids for use in high-pressure, high-temperature (HPHT) wells, especially a process that includes both a methodology for the management of bottom hole mud pressure and the use of modeling software that enables it, The developments have contributed to the success of four HPHT wells in the UKCS Central Graben. This paper discusses three essential elements for successful fluid engineering during HPHT drilling operations.–an accurate hydraulics program coupled with a temperature simulator–procedures for design and planning–bottom-hole pressure management in the field
P. 147
Hole Cleaning During Deviated Drilling - The Effects of Pump Rate and Rheology
Authors: Saasen A. 
Published: December 2007

Abstract
In the present paper it is shown that the frictional pressure loss in the annulus is the major contributing part to hole cleaning in deviated wells. A sufficiently large annular frictional pressure loss is required to obtain proper hole cleaning regardless of the drilling fluid design. It is shown that cuttings bed consolidation is the next item to be addressed. A very high frictional pressure loss may be necessary to remove cuttings from the bed if the bed is well consolidated. It is also illustrated how important it is to design a drilling fluid regarding hole cleaning performance at the correct annular frictional pressure loss.
P. 161
Experimental and Theoretical Investigations Into New Invert Emulsion Scale Squeeze Technology
Authors: Lawless T.A. , Smith R.N. 
Published: December 2007

Abstract
The potential to utilise invert emulsion technology (say, brine dispersed in kerosene) with the aqueous phase containing a scale inhibitor in solution is presented as an attractive alternative to conventional scale squeeze technology. Such new technology can combat current deficiencies associated with lost and deferred oil and deliver a stepped change to the whole process of scale control. It is important for squeeze operations, however, that the emulsion can be injected safely downhole and encouraged to "break" during shut-in, thus allowing the aqueous inhibitor to be released and contact the rock structure promoting effective retention. The "broken" oil phase maintains continuity between pore spaces and promotes rapid oil productivity to return, post-squeeze, as result of relative permeability effects. Economic benefits are identified and detailed considerations relating to the appropriate physico-chemical and environmental characteristics of target emulsions are presented. Experimental evaluation exercises on more than 50 specialist surfactants and formulations, obtained from major chemical companies have been undertaken and are reviewed.
Emulsifier chemistry selection, structural requirements and mechanism of (de)stabilisation are recorded to yield systems triggered to operate at 90 C. The impact of brine/oleic phase ratios, surfactant loading and method of manufacture are described in detail. Phase mapping techniques to elucidate controlled breakage, rheology and field fluids compatibility are recorded to quantify performance. Emulsion droplet size and distribution are key parameters influencing flow and (in) stability under practical scenarios, and optical microscopy investigations on systems as a function of time and temperature are presented. A move from largely monodisperse droplets, of circa 1 m, to an evolving size distribution, via coalescence is reviewed from an experimental and theoretical assessment.
P. 195
Enhancement of Liquid Flow Through a Porous Medium by Ultrasonic Radiation
Authors: Aarts A.C.T. , Ooms G. , Bil K.J. , Bot E.T.G. 
Published: December 2007

Abstract
A new method to enhance the oil production rate is irradiation of the near-wellbore region by an ultrasonic source. The limited success for the application of ultrasound in well stimulation to date, however, is due to the lack of understanding of the physical mechanisms between an acoustic wave field and a porous medium. In this paper the mechanism in which ultrasonic radiation deforms the walls of the pores in the shape of travelling transversal waves, is studied. A quantitative description of the mechanism indicates that these waves induce a net flow of the liquid inside the pores, identical to peristaltic transport. Numerical calculations show a damping effect of liquid compressibility and a strong influence of pore wall hardness and power output on the net flow rate induced.
The occurrence of a flow induced by ultrasound has been confirmed by laboratory experiments. In these experiments a water velocity of almost 1 cm/s through a rubber capillary of 0.15 mm radius could be induced by an ultrasonic source of frequency of 20 kHz. By a comparison between the trends observed in the experiments and the theoretically predicted trends, the role of the peristaltic transport mechanism in acoustic well stimulation is discussed.
P. 239
Hydrate Concept for Capturing Associated Gas
Authors: Gudmundsson J.S. , Andersson V. , Levik O.I. , Parlaktuna M. 
Published: December 2007

Abstract
Natural gas hydrate (NGH) technology is an attractive alternative to capture associated gas on FPSO's to solve the stranded and marginal gas problem in the oil industry. Based on estimates for land-based plants, the capital cost of hydrate technology is considerably lower than LNG, methanol and syncrude technologies. Offshore-based hydrate plants are also expected to be lower in costs. Crude/hydrate slurry processes are being developed for use on FPSO's. NGH technology is safe, environmentally friendly and easily scaleable.
P. 247