bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Importance of Leadership in Developing and Maintaining an Effective Safety Culture Within an Organisation
Authors: Barrett J. P. , Cram R. S. 
Published: December 2007

Proposal
It has been said that leaders are born, not made. To a certain extent, this is true. Many corporate heads are undoubtedly possessed with a degree of leadership skills. In most cases though, these leadership skills are centred on their ability to lead and manage a business from an economic perspective. Economics, finance, law, market sectors, corporate growth, mergers and acquisitions, business strategy etc.
Throughout their careers, business leaders often attend numerous seminars and training courses designed to improve their skill sets in these and many other similar disciplines with the focus, quite understandably on improvements to the performance of the business. Few spend much time in the business of safety and few have been lucky enough to survive the "eye opening event" which has befallen many a corporate chief; sometimes with disastrous consequences.
The safety culture of an organization is a direct consequence of the attitudes of the chief executive officer. It percolates from the board of directors, through the senior executive all the way to the workforce. His approach becomes the organisation's approach. His attitude, the attitude of everyone down the line.
This paper examines the essentials of being an effective leader in the field of HSE. It considers what factors go to make up a good safety leader and presents suggestions about how today's corporate bosses can instil a culture of safety first at every level in the organization.
The Perfect Wellbore!
Authors: Mason C. J. , Chen D. C-K 
Published: December 2007

Abstract
Wellbore quality is a term frequently used in the drilling community; however its meaning is not well understood, its context frequently confused and its value underestimated. For most drilling engineers, a quality wellbore is one associated with a directionally drilled borehole that is smooth, in-gauge, and has minimal spiralling. The claimed benefits of such a wellbore includes improved drilling performance, ease of running casing, better logging tool response, and highly competent cement jobs. To date it has been too difficult or too complex to relate such benefits to wellbore quality in a meaningful and measurable way. In order to reduce existing subjectivity, a procedure has been devised whereby wellbore quality can be measured in a practicable way. This resulting process is embedded in what is called the Wellbore Quality Scorecard (WQS). The system works by individually scoring drilling, tripping-out and casing running responses for any drilled hole section. A total score ranging from 0 to 20 is computed, where 20 is considered to be "The Perfect Wellbore". This represents significantly better than expected torque and drag responses from drilling, tripping-out of hole and casing running. Practical applications of the WQS are demonstrated on both horizontal and extended-reach wells.
Modelling the gas well liquid loading process
Authors: Dousi N. , Veeken C. A. M. , Currie P. K. 
Published: December 2007

Abstract
Liquid loading is a serious problem in areas where gas fields are maturing. An analysis is provided of the production behaviour over time of liquid-loaded wells. This shows clearly that these wells can operate at two different rates, a stable rate at which full production is taking place and a lower metastable rate at which liquid loading effects play a role.
A model has been constructed which enhances the understanding of the process of water build up and drainage in gas wells. It assumes a single gas and water co-production point and a single water re-injection point. As expected a water column is built up in the well as soon as production takes place below the critical rate. As observed in the field, for good inflow performance a metastable flowrate can be observed. At this state the water re-injection and water coproduction rate are equal to one another and the water column height stabilizes.
A sensitivity analysis has been carried out to determine how well parameters influence the metastable flowrate, the time required to reach this metastable rate, the corresponding water column height and the shut-in time required to drain this water column. The results of the analysis indicate that significant metastable flow rates occur in wells which have good inflow performance, a low water gas ratio and a large distance between injection and production point.
Furthermore a steady state analytical solution has been derived for the metastable rate and stabilized water column height confirming the numerical analysis results.
Measurement of Proppant Transport of Frac Fluids
Authors: Harris P. C. , Morgan R. G. , Heath S. J. 
Published: December 2007

Abstract
The object of hydraulic fracturing is to produce a propped fracture extending from the wellbore. Extensive time and effort are expended in measuring rheological properties of crosslinked fluids (without proppant) under simulated downhole temperature and shear-history conditions. Normally, it is assumed that if a fluid meets certain minimum viscosity conditions, it will transport proppant successfully. Measurements of actual proppant transport under dynamic simulated downhole conditions have been attempted and described, but such measurements have been very cumbersome and require significant equipment and expense to execute. Such measurements are well beyond the scope of routine QA/QC analyses.
A proppant viscometer recently constructed can measure fracturing fluids containing propping agents across a wide range of concentrations. The device was designed to work as a conventional Fann Model 50-type viscometer. This unique viscometer has been used to measure typical fracturing fluids containing realistic concentrations of proppants, at temperatures and times up to several hours, representative of actual fracturing treatments. The measurements show regions of elastic transport typical of viscoelastic fracturing fluids where proppant is transported efficiently, usually followed by regions of purely viscous transport where proppant slowly settles.
The advantage of the new proppant viscometer is that all components of a fracturing fluid, including proppant, can be tested. Shear-history effects of proppants on frac fluids are usually unknown or ignored, but such effects were observed in this work. Breakers were usually added to the fluids, showing reasonable times when the crosslinked fluid no longer transported proppant efficiently and proppant began to settle.
This paper shows how different types of fracturing fluids can support proppant based on their chemical type, i.e. metal and borate crosslinked fluids, linear gel fluids, and surfactant gel fluids. Proppant concentrations are also considered. The physical characteristics of the proppant viscometer are also addressed.
Crude Oil Contaminated Soil Clean Up With Bioremediation: A Case Study and Implementations in Minas Field, Indonesia
Authors: Rumbiyant E. , Hermiani F. , Aji B. S. , Nugraha S. 
Published: December 2007

Abstract
PT. Caltex Pacific Indonesia (CPI) is strongly committed to maintaining a clean environment for nearby communities while providing safe and healthy working conditions for its workers and business partners. While operational standards and regulations have improved since operations began in 1952, a variety of incidents over the years have caused soil in some of the surrounding areas to be contaminated with crude oil. CPI is applying bioremediation techniques to mitigate this impact.
Bioremediation is a batch process utilizing microbial digestion of hydrocarbons to clean up soil contaminated with crude oil. Bioremediation land farming was selected because it is a cost effective method, it complies with Government of Indonesia (GOI) regulatory requirements and it is a technology with proven success for producing an end product which is safe to be utilized for re-vegetation and landfill within certain restrictions for areas within Minas Field. The process involves excavation of the soil, hauling the material to Soil Bioremediation Facilities (SBFs) where it is spread and processed (land farmed) by tilling (aeration), irrigated, fertilized with nutrients (fertilizer), monitored regularly by analyzing soil samples for Total Petroleum Hydrocarbon (TPH). Once the TPH meets levels within acceptable concentrations stated in GOI regulation, the soil is removed from the sites and redistributed in predetermined areas based on specific criteria. The average cycle time of this complete process is 5 months.
In CPI's Minas field alone, 5 bioremediation sites are operated continuously providingfor a processing capacity of 45,000 cubic meters of soil per year resulting in approximately 150,000 m3 of soil being processed between 1997 to today. During this time CPI made great strides in improving the process through creating more sites, trying different equipment and operating methods. However, CPI continues to seek new innovations and research to increase efficiency, reduce overall cycle time and increase capacity.
North Sea Hannay Field Case History: Perforating through a cased-hole gravel pack to significantly increase oil production
Authors: Peggs J. K. , Duncan B. S. , Weatherstone P. M. , Webster C. McK. 
Published: December 2007

Abstract
The Hannay field is located in Block 20/5c of the North Sea, approximately 150 km Northeast of Aberdeen. The development consists of two subsea producers tied back to Buchan via a 13.5 km pipeline. The production mechanism at Hannay is depletion with significant aquifer pressure support.
The Hannay Field commenced production from a horizontal subsea well (Hannay 1) at an initial rate of 18,000 stb/day. However, the initial months saw approximately 9 tonnes of sand production transported into the production separators.
In an attempt to mitigate sand production, the well was flowed below 10,000 BFPD. Reduced flow rates from the Hannay 1 well provided economic justification for a second producer. Hannay 2 was drilled approximately 1 year after field start-up. Due to sand production from the Hannay 1 well and sensitivity to water-based gravel pack fluid, it was necessary to complete the well with a cased-hole gravel pack. The installation of the gravel pack resulted in a large skin of 100. Acid was used to reduce this skin to approximately 50; however, the Hannay 2 productivity still remained significantly impaired.
This paper presents the engineering studies conducted to evaluate and justify the perforation of the gravel pack in the Hannay 2 well to reduce well damage. These include rock mechanics, sand prediction analyses, and reservoir simulation work to evaluate the potential benefit and optimum interval to perforate to maximise oil recovery.
Detailed well intervention planning was undertaken and successful operations conducted to increase oil production from the well by 3,000 BOPD. Incremental reserves of 1.0 mmstb will be realised for a cost of under £2 million. This shows the importance of a long clean-up period for wells that initially produce sand before adopting a conservative sand control strategy.
Marco Polo Deepwater TLP: Completion Implementation and Performance
Authors: Burman J. , Renfro K. , Conrad M. 
Published: December 2007

Abstract
Novel well completion techniques and exceptional field execution allowed the six well completions on the Anadarko operated Marco Polo Deepwater TLP project in Green Canyon 608 to be accomplished in world-class fashion. All six wells (seventeen frac packs) were placed on production in only 168 days, including 14 days lost due to storms, after riser tie-back operations were complete. An operational efficiency of 85%, with weather downtime accounting for 9% and other lost time accounting for 6%, was obtained during the completion campaign.
This paper will focus on how the implementation challenges of completing seventeen zones in six deepwater dry-tree wells with a 1000 hp rig were met, and will highlight a number of concepts and technical firsts that can be applied to other deepwater development projects.
Effect of EOS Characterization on Predicted Miscibility Pressure
Authors: Stalkup F. , Yuan H. 
Published: December 2007

AbstractAn equation of state (EOS) is not a unique representation of the PVT behavior against which it is tuned. Two equations of state with different parameters may appear to predict the same experimental PVT data about equally well. However, they may give very different simulated slim-tube recovery as well as analytical predictions of minimum miscibility pressure. In addition to PVT data, tuning the EOS against slim-tube data is advisable.This paper illustrates the above remarks for three different reservoir fluids that have different amounts of PVT data to tune the EOS against. These examples show that what appear to be equally acceptable EOS characterizations with regard to PVT data predictions can predict differences in miscibility pressure as much as 500 to 1000 psia. In an example simulation in a heterogeneous reservoir cross section, these differences in EOS characterization caused 7 to 22% differences in predicted incremental recovery.
EIA Study to Identify Effect of Gas Flaring on Rice Cultivation in Oil Fields of Assam
Authors: Bose C. , Sharma K. K. 
Published: December 2007

ABSTRACT
Oilfield in Assam are located in and around the rice fields. Rice crop in the vicinity of flare pits near oil collecting stations (OCS) get illuminated throughout and high spikelet sterility is caused. In the present study, attempt is being made to determine the response of some traditional and modern cultivars of different duration groups under prolonged photoperiod near the pit. Photoperiod insensitive medium duration variety like Jaya was least affected the light intensity. Due to prolong light hours, days to 50% flowering were affected in traditional long duration variety. Amongst the yield attributing characters, ear bearing tillers/hill, sterility (%), panicle length and grains/panicle were effected due to prolonged light hours; while light period had little effect or no effect on plant height, total number of tillers/hill and test weight.
An Enduring Commitment to Sustainable Community Development in Myanmar: The Yetagun Socio-Eco Development Program
Authors: Musa A. G. , Tarnoff A. 
Published: December 2007

Abstract
In 1997, three years before the production of gas and condensate went on-line in the Yetagun Field of the Andaman Sea in territorial waters of the Union of Myanmar, the start of the Yetagun Socio-Economic Development Program represented the collective commitment and vision of Yetagun Joint Venture Partners. The objective is to improve the social and economic condition of local residents in the onshore pipeline corridor of operations and the country as a whole.
The Yetagun Socio-Economic Development Program has been implementing a series of complementary programs to address the most essential health, education and income generating needs of disadvantaged communities, especially women and children.
The Yetagun Socio-Economic Development Program has reached over 150,000 beneficiaries. Immediate and measurable improvements in the quality of life for thousands of beneficiaries have also strengthened the capacity and empowered communities with the knowledge, skills and tools to achieve long-term and sustainable impact for generations to come.
Revisiting Reservoir Flood-Surveillance Methods Using Streamlines
Authors: Batycky R. P. , Thiele M. R. , Baker R. O. , Chung S. H. 
Published: December 2007

Abstract
This paper revisits classic flood surveillance methods applied to injection-production data, and how such methods can be improved using modern streamline-based calculations. Classic surveillance relied on fixed patterns and geometric based well-rate allocation factors (WAF's). Here we compare conclusions about pattern performance from classic surveillance calculations against surveillance results using flow-based WAF's as computed from a streamline surveillance model. We show that very different conclusions on pattern performance can be reached. Rather then fixed patterns, we also introduce injector centered patterns as the elementary surveillance unit with offset producers being those that an injector is connected to at any time event. Injector centered varying patterns give a better measure of an injector's true effectiveness since all offset oil it is responsible for is counted, rather than just production within a pre-defined pattern. Here too we show that decisions about how to manage a flood can be quite different than decisions reached using a fixed pattern analysis.
In the second part of this paper we illustrate how much data is required to build a relevant surveillance model. We compare WAF's and offset oil production as computed from full history-matched flow simulation models against surveillance models for several field cases. Our comparisons show that as long as offset well rates are a function of neighboring well rates, as is typical in waterfloods, then only first order flow effects are required in a surveillance model. First order flow effects required would include, well locations, historical rates, gross geological bodies and major flow barriers. In other words, because well rates are already a reflection of geology, simply setting up a surveillance model with the proper geological connectedness will lead to streamline models that give similar inter-well fluxes, as more complex history matched simulation models.
Optimized Well Location by Combination of Multiple Realization Approach and Quality Map Methods
Authors: Cottini-Loureiro A. , Araujo M. 
Published: December 2007

Abstract
The determination of the location of new wells in an oil reservoir is a complex problem that depends on reservoir and fluid properties, well and surface equipment specifications, geographical conditions and economic criteria. The final method to be used for field development should be based on the use of a reliable method for well location, oriented to reduce uncertainty, minimize costs and maximize the asset value. Reservoir simulation is recognised as one of the most reliable tools for defining the optimum production strategy. However, forecasting by reservoir simulation techniques bears risk as result of the uncertainty in the input data. The conventional approach to plan the number of production wells and their locations is by a tedious and costly trial and error process, where the final result depends on the ability of the reservoir engineer to fully understand the reservoir behaviour and the operational limits.
Here, we present a new approach for optimal well location that was developed by combination of multiple realization and quality map methods. The proposed methodology starts from the static reservoir model in which main parameters are identified to reduce the number of simulation runs required for an optimized dynamic reservoir model by using the multiple realization approach. The study continues by determining the quality map for the reservoir, which is aimed to identify areas from where the hydrocarbon production is expected to reach a field maximum. This is performed by evaluating each possible well position at different locations up to finding the maximum production, without well interference or unphysical behaviour in well response.
This approach was tested on the Maureen field, a North Sea reservoir, finding optimal well placement with an improved production. Numerical results obtained by applying the combined methodology provided larger hydrocarbon recovery from the field those results obtained by just using the two involved methods separately in 20 years of production. Predicted production values were significantly larger that those reported in actual field production. The methodology found spots where the forecasted production might be significantly larger if wells were located in coordinates other than some of the actual wells._Thus, the proposed method could be used as a tool to reduce uncertainty in development fields and an important technique towards an optimal asset management.
The Application of Cutoffs in Integrated Reservoir Studies
Authors: Worthington P. F. 
Published: December 2007

Abstract
Methodologies have been developed for applying net reservoir and thence net pay cut-offs in cases of primary and waterflood depletion. The cut-offs are dynamically-conditioned to be reservoir-specific, i.e. they are tied back to a reference permeability parameter in a way that is driven by the reservoir data themselves. They also honor scale, where feasible, and are conformable with any pertinent rock-typing. For primary depletion, the Leverett equivalent circular pore diameter has been used to distinguish between reservoir and non-reservoir rock. This composite parameter can incorporate mobility for multiphase work. It is linked to a discrete core porosity under simulated reservoir conditions, so the adopted net-reservoir cut-off is expressed as a limiting porosity. For waterflood depletion, an extrapolated end-point relative permeability has proved effective for the same purpose. Here, the zero endpoint relative permeability is linked to a conventional "absolute" core permeability corrected to reservoir conditions. Porosity is tied back to this limiting absolute permeability so that the net-reservoir cut-off is again expressed in terms of porosity. Consequently, in both cases, the discrete porosity cut-offs have a dynamic significance. Other cut-off parameters, such as shale volume fraction and water saturation, can be tied back to these. A proposed workflow for applying dynamically-conditioned cut-offs allows data character to drive their use in integrated reservoir studies. The workflow constitutes a basis for greater technical consistency in the estimation of ultimate hydrocarbon recovery. The treatment is not exclusive, and other approaches to the determination of net pay will emerge as more reservoirs are considered.
Deploying Common Process Across Global Wells Teams—Integrating an Online Project Management Application with Effective Behaviours to Enable High Performance
Authors: Sawaryn S. , Dressler D. , Been K. , Bailey T. 
Published: December 2007

Abstract
BP has successfully deployed a web based project management application across the global wells teams to support common processes used in well delivery. Widespread use of the application is now made in drilling and completions activities and other planning functions within the wells community. This is just one of the tools that have contributed to the 19% drilling and completions performance improvement recorded in BP during 2003.
The project's goal is to standardise the use of proven common processes, creating a shared repository for critical knowledge, reducing time for project initiation and planning, managing risk and supporting the stage gate decision making. An extensive management reporting capability also reduces the administrative burden.
Positive results include quicker start-up of new teams and improved planning. The keys to success are organisational commitment to the common processes and the use of proven project management practices in drilling and completions activities. Behaviours have also been addressed. Over 90% of the application was based on established, commercially available software, increasing reliability, reducing implementation risk and enabling the developers to focus on the key functionality and user interface. The application's process templates are regularly reviewed and are updated periodically to ensure continuous improvement and long term sustainability.
This paper contains a summary of the common processes and presents a case study of the project, its goals, results, critical success factors, challenges and lessons learned, supported by several examples. The paper will be of interest to both managers and engineers.