bluuebunny/crossref_metadata_2025_split huggingface dataset:
Novel Survey Method Using a Rotary Steerable System Significantly Improves the Dynamic Inclination and Azimuth Measurement
Authors: Lowdon Ross , Sugiura Junichi , Bowler Adam 
Published: September 2013

Abstract
When kicking off at low inclination, static measurement-while-drilling (MWD) surveys are used to confirm the kickoff direction when free of magnetic interference from offset wells. However, as MWD continuous azimuth and inclination measurements have limited accuracy, the directional driller will not have confidence in the kickoff direction with continuous (dynamic) survey while drilling, thus requiring additional static surveys to be made, taking up precious rig time.
In a novel continuous survey method used in a particular rotary steerable system (RSS), a six-axis survey was taken continuously, both while drilling and when static, with the survey sensors being housed in the RSS. This algorithm was first verified in a software simulator, and it was subsequently implemented and tested in hardware. The effectiveness of the new measurement method was field tested and compared against MWD static survey points. The field test result from multiple wells shows that the new near-bit continuous azimuth and inclination from the RSS is considerably more accurate than that of the axial MWD continuous measurements at very low inclinations of between 1 and 5 degrees.
This unique measurement method has valuable applications, such as low-angle kickoff without using multiple static surveys as the directional driller can use the real-time continuous azimuth and/or toolface to accurately steer the well through crowded offshore platform environments. When drilling out of the shoe, this survey method will allow an accurate kickoff approximately 50 ft earlier than would normally be expected as magnetic interference is cleared, and thus saving the precious rig time needed to kick off. Additionally, the use of a continuous gravity toolface is possible without the need for static surveys, allowing accurate low-side sidetracks to be performed even in areas of high magnetic interference.
Understanding of Fire Induced Progressive Collapse of Offshore Structures as a Tool for Reducing the PFP Requirements
Authors: Munoz-Garcia Enrique 
Published: September 2013

Abstract
Passive fire protection (PFP) has been used in the Oil & Gas industry for many years as a method to avoid/delay global collapse of offshore installations. However location of PFP has normally been based on simplistic assumptions, standards, guidance and methods that do not always consider the real response of the structure to fire. The resulting PFP schemes can be conservative leading to unnecessary cost to the Operator in terms of application and maintenance costs. More importantly, there is the potential for the PFP scheme to be insufficient for the actual fire hazards which will increase the level of risk for the personnel on board.
Fire induced progressive collapse is a function of the level of redundancy of a structure, it is for this reason that redundancy analyses have sometimes been used as a simplistic method to calculate the level of PFP required. However this method does not take into account the size of the fire threat against which the PFP is designed and could lead to less than conservative results as it only considers removing one member of the structure at a time, without considering reduction in the strength of the surrounding members as they are also being heated by the fire.
Performance based fire collapse analysis provides an understanding of the response of the individual members as well as the entire structural system to fire. Understanding the failure mechanisms, susceptibility to progressive collapse of the structure, and key members that must remain in place during an accident situation allows for the optimisation of the PFP scheme, protecting only the required members while allowing for local failure of redundant members.
The present paper provides a comparison between the different methods, and provides case studies that have resulted in optimum PFP schemes linked to design fires based on acceptable risk levels.
Reservoir Management: Preparing for Field Redevelopment and Restart
Authors: Rees Hugh , Parke Jeff 
Published: September 2013

Abstract
The Schiehallion and Loyal oil fields located in Quad 204, and neighbouring Foinaven, all west of the Shetland Isles, are the first group of North Sea deep-water fields to be developed and together form a huge subsea development. As part of the Quad204 Project Schiehallion and Loyal are being re-developed to extend field life and this requires infill drilling, replacement of some subsea infrastructure and replacement of the Floating Production, Storage and Offloading vessel (FPSO) to service the extended scope. The reservoirs will remain shut-in for a period of up to three years whilst the FPSO Schiehallion is disconnected, the site is prepared and the new FPSO is hooked-up.
There are fifty-two wells (25 producers and 27 injectors) and this is the first time that bp has shut-in a field for so long at such scale. Many wells access mature, water-flooded, multi-layer reservoirs which have been flowing for 15 years. The infill drilling programme will be providing additional well-stock and production for the new FPSO but the majority of the rate at restart will be supplied by the existing wells so it is essential that the fields are prepared carefully and left in a healthy and predictable state for the shut-in and subsequent restart.
Fifteen years of production has created differential oil depletion both areally and vertically between layers. Factors to be considered include: minimising hydrogen sulphide development in the reservoir, maintaining the Christmas trees that reside within the hydrate-forming envelope, existing well issues and corrosion treatments for preservation. The shut-in of the fields is complicated by the requirement for continued low-levels of production for the purposes of cleaning the FPSO cargo tanks – and continued injection support whilst cleaning.
This paper discusses the preparation and planning for the reservoir activities and the coordination of reservoir management with facilities requirements during the shut-in of the wells.
Following The Safe Evacuation of All Offshore Personnel…the Environmental Response Takes Primacy: Learning From The Elgin G4 Well Major Incident
Authors: Dale Michael , Keown Rachel , Wilson Gordon 
Published: September 2013

Abstract
The learning from incidents and subsequent improvements made for the protection of people and integrity of offshore installations over the last 25 years has no doubt saved numerous lives. Places of refuge, blast protection, rapid isolation processes, offshore survival training and improved evacuation systems have all proved themselves in the prevention of harm either in actual or potential major accidents offshore.
Today, when emergency situations arise offshore we consistently witness immediate and efficient activation of tested incident response processes to ensure the safety of personnel through rapid shut down and evacuation.
But what about after all personnel offshore are ‘safe’?
When the safety of personnel is addressed during a serious ongoing release of oil and gas, operators can be faced with a longer-term, large-scale environmental response. What can we learn from previous incidents to respond effectively to incidents that potentially threaten the environment?
It is well known that environmental impacts from the oil & gas industry readily capture public interest, with environmental images remaining at the forefront of media and public attention for many months.
This paper examines the environmental response to the G4 well control incident which commenced on 25th March 2012 at the Elgin installation well head platform in the Central North Sea. This is one of the largest North Sea gas/condensate releases in recent history and continued for 51 days until the leak was stopped on 15 May 2012.
In the first 24 hours of the incident, all 238 personnel on board the Elgin platform and Rowan Viking jack-up drilling rig which was working over the Elgin well head platform were safely evacuated without any injury. Within the first 24 hours also, TOTAL’s Environment group was activated to implement immediate actions to address and monitor the significant ongoing condensate spill to sea.
The presentation of this paper will discuss: Spill combat options mobilisedConcurrent implementation of both medium and long-term response strategiesEnvironmental monitoring approaches and resultsStakeholder interactions (including the regulator, media and other interested parties)Learning and recommendations to industry
10 Years Experience of North Sea FPSO Moorings Repair, Renewal and Life Extension Work
Authors: Brown Martin G. 
Published: September 2013

Abstract
This paper summarises 10 years of experience gained during the repair/renewal/life extension of several North Sea FPSO mooring systems. This includes reference to Phases 1 and 2 of GL Noble Denton’s Mooring Integrity Joint Industry Project (JIP) plus recent North Sea mooring system repair and replacement operations. Issues encountered and typical mooring degradation mechanisms are reviewed making reference to the age of the components. The paper discusses how issues have been addressed in practice taking into account the risk of failure, offshore conditions and equipment availability.
Brief descriptions are included of the various mooring intervention campaigns including actual offshore schedules, selected vessels, required additional equipment and ROV spreads. Positive and negative lessons learnt during the intervention campaigns are included. The importance of allowing sufficient time for planning and preparation of the intervention campaigns is stressed.
A Guide to Better Wells: Environmental Life-Cycle Assessment Of Historical, Current And Future Best Practice in Drilling
Authors: Pettersen Johan Berg , Hung Christine , Solli Christian , Steeneveldt Rosetta , Kerr Scott , Aas Nina 
Published: September 2013

Abstract
The general focus in environmental evaluation of offshore drilling is the discharge of cuttings and chemicals to local marine environment, in some cases including emissions to air from offshore turbines and engines. However, significant impacts occur as a result of processes upstream and downstream from drilling operations, in the manufacture of chemicals and materials, in supply and transport operations, and in treatment of drilling wastes.
Life-cycle assessment (LCA) is the structuring, aggregation and evaluation of environmental impacts in a cradle-to-grave scope. We present an LCA model developed through a series of case studies for offshore drilling operations. Model components include a fleet of drilling rigs and supply vessels, a library of drilling fluids and chemical products, various cuttings treatment technologies, top-hole abatement techniques and well operations.
The LCA model is used to evaluate technologies in historical, current and future best practice for offshore drilling. One measure under evaluation for the future is the development of smaller, fit-for-purpose vessels (Cat B), which are shown to potentially reduce emissions from the drilling vessel itself by 50 %.
Slim-hole drilling is another technology with several potential benefits, including time savings, reductions in steel and concrete in installing and cementing casings, less drilling fluid required, and less cuttings waste logistics and treatment. In all, these provide 30-50 % reduction when compared with conventional well designs, in greenhouse gas emissions and other air emissions, and in harmful releases from manufacture of materials and chemicals and treatment of wastes.
Relevant for operations outside European waters, the LCA shows that production and waste treatment of drilling fluid may pose a significant source for impacts unless fluids are managed properly by reuse of drilling fluid and recycling of oil from cuttings waste. These measures provide a reduction of 30 % of the total environmental footprint, illustrating the benefits from current best practice.
Real Time Velocity and Pore Pressure Model Calibration in Exploration Drilling
Authors: Kemper Julia , Richards Martin , Taylor Matthew , Kelsall Neil , Turner Marcus , Puech Jean Claude 
Published: September 2013

Abstract
When drilling in remote areas, in the absence of offset data, pore pressure is determined as a function of seismic rock velocity. The velocity model and corresponding pore pressure model form the basis for exploration well planning. These models directly impact the casing design, number of sections, and mud weight plan. For frontier exploration drilling, the relationship is not well established; this reliance is high risk and can benefit from a high-technology approach to reduce this risk.
This study examines how velocity and pressure models updated using real-time measurements from a high-tech logging-while-drilling suite can enable key drilling decisions to be made, reducing risk and the time taken to drill the well.
Seismic-while-drilling technology provides checkshot data while drilling, which is used to update the velocity model. The velocity model updates in the shallow sections allow modification to the forward trajectory to ensure targets are intercepted. Furthermore, real-time updates enable geostopping by refining the predicted depths of targets or marker horizons and ensuring no accidental penetration of bright seismic amplitudes that may be associated with potential pore pressure abnormalities.
In addition, formation-pressure-while-drilling technology can be added to the seismic and sonic technologies to calibrate the predrill pore pressure model. The acquired formation pressures, coupled with the while-drilling petrophysical data, allow for the velocity to pore pressure transform and normal compaction trend lines to be calibrated and reduce the uncertainty of the pore pressure model ahead of the bit.
The calibrated models permit the operator to confidently make decisions and continue drilling in a single section to intercept key targets, potentially eliminating casing strings, with the assurance that the kick tolerance and safe overbalance are maintained at an optimal level to reduce the risk of mud losses or kicks.
Relative Permeability Characterization for Water-Alternating-Gas (WAG) Injection in Oil Reservoirs
Authors: Shahverdi H. , Sohrabi M. , Fatemi S. M. 
Published: September 2013

Abstract
Large quantities of oil usually remain in oil reservoirs after conventional water floods. A significant part of this remaining oil can still be economically recovered by Water- Alternating-Gas (WAG) injection. WAG injection involves drainage and imbibition processes taking place sequentially, hence the numerical simulation of the WAG process requires reliable knowledge of three-phase relative permeability (kr) accounting for cyclic hysteresis effects.
In this study, the results of a series of unsteady-state two-phase displacements and WAG coreflood experiments were employed to investigate the behaviour of three-phase kr and hysteresis effects in the WAG process. The experiments were carried out on two different cores with different characteristics and wettability conditions.
An in-house coreflood simulator was developed in order to obtain three-phase relative permeability values directly from unsteady-state WAG experiments by history matching the measured recovery and differential pressure profiles. The results show that three-phase gas relative permeability is reduced in consecutive gas injection cycles and consequently the gas mobility and injectivity drops significantly with successive gas injections during the WAG process, under different rock conditions. The trend of hysteresis in krg partly contradicts the existing hysteresis models available in the literature. The three-phase water relative permeability (krw) of the water-wet core does not exhibit considerable hysteresis effect during different water injections, whereas the mixed-wet core shows slight cyclic hysteresis. This may indicate a slight increase of the water injectivity in the subsequent water injections in the WAG process under mixed-wet conditions. Insignificant hysteresis is observed in the oil relative permeability (kro) during different gas injection cycles, for both water-wet and mixed-wet rocks. However, a considerable cyclic hysteresis effect in kro is observed during water injection cycles of WAG, which is attributed to the reduction of the residual oil saturation during successive water injections. kro of the water-wet core exhibits much more cyclic hysteresis effect than that of the mixed wet core. No models currently exist in reservoir simulators that can capture the observed cyclic hysteresis effect in oil relative permeability for the WAG process.
Investigation of relative permeability data obtained from these displacement tests at different rock conditions reavealed that there is a significant discrepancy between two-phase and three-phase relative permeability of all fluids. This highlights that not only the three-phase relative permeability of the intermiate phase (oil), the three-phase kr of the wetting phase (water) and non-wetting phase (gas) are also functions of two independent saturations.
Successful Approach to Push ERD Limit, Optimize Production, and Optimize Reserve Recovery of an Extended Reach Oil Field
Authors: Zou Xiaoping , Huang Yingshi , Zeng Youliang , Li Xiuying , Yu Guoda , Tran Thanh , Halomoan Palindungan Monris , Bisain Amarjit Singh , Denichou Jeanmi 
Published: September 2013

Abstract
An operator in offshore South China planned to develop a new oil field comprising multiple thin oil-bearing zones. It was decided to develop the field by upgrading an existing drilling rig on a platform rig 6 km away to drill extended reach horizontal wells. The objective was to place long lateral drains in a thin-pay reservoir. However, the foreseen risk of high drilling torque against the backdrop of the drilling rig that has maximum 42,000 ft-lbf drilling torque capacity limited this option. In addition, subsurface challenges constrained the ability to access the target reservoir optimally for production and reserve recovery optimization.
The latest fit for purpose logging-while-drilling applications were used to overcome the drilling challenges—limited rig capacity and subsurface challenges—in these extended reach horizontal wells and to optimize ultimate recovery and the economics of each additional well drilled. The efforts were performed in real time while drilling and aimed to place the well optimally within the thin pay zone by delineating and mapping the top and bottom pay zone boundaries simultaneously. With this ability, the lateral could be placed accurately without making unnecessary trajectory adjustment that can result in additional drilling torque.
Two wells were completed successfully. Application of the technology resulted in significantly higher production compared to the set target. The reserve recovery was optimized by placing the well 0.5 m below the top. The drilling torque was minimized, thus increasing the ability to drill farther and capture additional reserves. Significant savings in total drilling cost were attained by ensuring smooth drilling operations free from unnecessary adjustment and sidetracks. A similar approach could address the challenges in other, similar complex and hard to reach reservoirs targeted in exploration and development activities in offshore operations.
Baseline survey of progress by veterinary medical colleges in implementing recommendations from the North American Veterinary Medical Education Consortium
Authors: Andrews Ken , Chaddock Mike , Osburn Bennie I. 
Published: September 2013

Abstract
A survey was conducted to assess progress by accredited veterinary medical colleges in the United States and Canada with regard to implementation of recommendations from the North American Veterinary Medical Education Consortium (NAVMEC). Results indicated broad support for many of the recommendations and a willingness among stakeholders in veterinary medical education to accelerate their implementation. Respondents also expressed a desire for evidence-based decisions and detailed implementation planning. Many colleges of veterinary medicine reported progress on initiatives started prior to the meetings of the NAVMEC that closely aligned with NAVMEC recommendations. Only isolated progress toward implementation of system-wide recommendations that required coordination among multiple colleges of veterinary medicine and other stakeholders was identified. Survey results confirmed the need for changes to the current veterinary medical education paradigm and a commitment among many stakeholders to work together to effect these changes.
Use of vacuum-assisted closure to maintain viability of a skin flap in a dog
Authors: Bristow Poppy C. , Perry Karen L. , Halfacree Zoe J. , Lipscomb Vicky J. 
Published: September 2013

Abstract
Case Description—A 4-year-old sexually intact male Labrador Retriever-Poodle mix was admitted to the hospital for treatment of a wound in the left thoracic region. The wound had been debrided and primary closure had been performed by the referring veterinarian 4 days previously.
Clinical Findings—The dog had a 20-cm-long wound covered by a large flap of skin that extended caudally from the scapula over the left side of the thorax. A 3-cm defect was evident at the cranioventral aspect of the wound, from which purulent material was being discharged. The skin flap was necrotic, and the skin surrounding the flap was bruised. Signs of pain were elicited when the wound and surrounding region were palpated. Other findings, including those of thoracic radiography, were unremarkable.
Treatment and Outcome—The wound was debrided, and vacuum-assisted closure (VAC) was initiated for 3 days until a healthy bed of granulation tissue developed. A reconstructive procedure was performed with a rotation flap 3 days after VAC dressing removal. The VAC process was reinitiated 2 days following reconstruction because of an apparent failing of the skin flap viability. After 5 days of VAC, the flap had markedly improved in color and consistency and VAC was discontinued. Successful healing of the flap occurred without the need for debridement or additional intervention.
Clinical Relevance—Use of VAC led to a good overall outcome for the dog, with complete healing achieved. Additional evaluation of this technique for salvaging failing skin flaps is warranted in dogs, particularly considering that no reliable method for flap salvage in veterinary species has been reported to date. (J Am Vet Med Assoc 2013;243:863–868)