bluuebunny/crossref_metadata_2025_split huggingface dataset:
Impact des activités touristiques en forêt de Fontainebleau : de la dégradation à la restauration
Authors: Hotyat Micheline 
Published: March 2018

La forêt de Fontainebleau connait depuis le XIXe siècle une fréquentation touristique importante grâce à sa proximité avec la capitale et à sa diversité paysagère qui a attiré autant les peintres de Barbizon que les parisiens avides de plein air. Cette fréquentation de la forêt a été facilitée par l’arrivée du train à Avon dès 1849. Fréquentation touristique qui s’accroit considérablement dès le début du XXème siècle car de plus en plus de visiteurs viennent consommer de l’espace forestier. Mais, une telle fréquentation, dans un milieu si fragile, entraine une érosion intense en certains lieux qui deviennent dangereux et perdent leurs caractéristiques paysagères du XIXème siècle, comme c’est le cas de la platière d’Apremont. Quels sont les effets de cette fréquentation touristique ? Comment restaurer et sauvegarder ces milieux et ces paysages qui ont fait la réputation de cette forêt ?
Earthquake Analysis Requirement for Fixed Offshore Structures, Offshore Malaysia
Authors: Razak Zahari A. , Sha'ari Fatimah Az-Zahra , Liew Prof. Ir. Dr. Shahir 
Published: March 2018

Abstract
Malaysia has always been considered as a non-earthquake zone. For offshore Malaysia, the only guidance document on earthquake is ISO 19901-2 which put Malaysia as a Zone 0. However, this perception changes after the big earthquake in Acheh, Indonesia (2004), and recently in Sabah, Malaysia (2015). To ensure the safety of its offshore facilities, PETRONAS has appointed D'Appolonia to conduct a Probabilistic Site Hazard Assessment, PSHA study post Acheh earthquake to determine the earthquake spectral response value to be used for its offshore structures design. Due to the perception that D'Appolonia PSHA spectral response value is on the high side, Universiti Teknologi PETRONAS, UTP was later tasked to conduct another round of PSHA study to complement D'Appolonia findings. The spectral response values from ISO 19901-2 and results from D'Appolonia and UTP PSHA studies were then compared and validated. This paper discusses the process on how PETRONAS developed the design requirement due to earthquake for structures located offshore Malaysia, starting with Probabilistic Site Hazard Assessment, PSHA based on historical data of seismic events in South East Asia and mapping of all relevant crustal faults, and later map the seismic contours to the local soil condition offshore Malaysia to develop the spectral response map, and later the response spectrum for shallow and deep foundations to be used for the earthquake analysis for its facilities offshore Malaysia.
Major Controlling Factors of Overpressure Generation in West Baram Delta, Offshore Sarawak Basin: An Overview on Disequlibirum Compaction and Thermal Analysis Causing Overpressure Interval
Authors: Yusoff Wan Ismail Wan , Adha Kurniawan , Hanapiah Nurhajeerah Mhd , Ghosh Deva Prasad 
Published: March 2018

Abstract
Pore pressure data at well location is one of the requirements for exploitation of oil and gas resources. The accurate pore pressure can be determined optimally when the overpressure mechanisms are well established. In general this paper is focusing on the determining of overpressure mechanisms and also characterizing the pore pressure. The origin of overpressure in the study area was firstly determined by using wireline log responses. In general, there were two prominent types of overpressure mechanisms, the disequilibrium compaction and fluid expansion in the study area. Overpressure mechanism typing was enhanced by integrating thermophysical parameters in the analysis. The relationship between pressure-temperature gradient with depth enable to discriminate the overpressure mechanisms. The high heat flow anomalies are unique to the fluid expansion zone and hence could be used as an indicator for the fluid expansion mechanism. A new workflow has been established and designed for overpressure mechanism determination which complements the existing technique with incorporating the thermophysical analysis.
Powering the World's First Floating LNG Plant
Authors: Su Pantaleon 
Published: March 2018

Abstract
An onboard, autonomous power system was required to supply electricity to a floating LNG (FLNG) plant anchored offshore the state of Sarawak in Malaysia. The power system together with its ancillaries were designed to be reliable and robust enough to operate an LNG plant located 180km offshore while sustaining a crew of 140 people.
The design of the power system started by estimating the amount of power required by the plant. The distribution of loads was then decided and system voltages were selected. The voltage of power generators was then matched with the selected system voltage either through direct connection or via unit transformers. This resulted in different design options which when combined with a plant constrained by limited space and weight as in the case of FLNG, presented unique design challenges.
System studies were carried out together with protection coordination to ensure system stability. The results concluded that the power system will remain stable during a three-phase fault at the highest system voltage. In the event of a total power outage, the electrical system was designed to safely shutdown the plant and then restart it to resume production.
The power generation system at the topside was installed on the floater at the dockyard. All electrical systems were tested prior to sail-away. The load-testing of the GTG's at the dockyard would have incurred substantial cost in terms of the fuel, load bank rental and supporting services. After careful consideration, it was decided to carry out the load tests offshore at the production location.
The unique design of the electrical system for the Floating LNG plant will provide a reference for future, similar projects. The lessons learned will serve to improve future designs in this niche technology.
An Investigation of the Relationship Between the Time-Dependent Wellbore Stability and the Related Operational Practices
Authors: AlBahrani Hussain I. , Al-Qahtani Adel , Hamid Osman , Al-Hassan Zuhair 
Published: March 2018

Abstract
Published numerical and analytical solutions for wellbore stability predict certain trends in the behavior of hole geometry as a function of time. In general, shear failure is expected to increase in severity with time to produce over-gauged hole sections. However, these solutions do not take into account many aspects of the disturbances produced throughout the drilling process. An investigation of the behavior of hole geometry of a diverse group of wells is conducted to uncover the different relationships between the time-dependent wellbore stability and the related operational practices. The highlighted relationships are then reconciled with published wellbore stability solutions.
The disturbances produced throughout the drilling process can include heat transfer between the drilling fluid and the wellbore wall, chemical interactions with the drilling fluid, and mechanical forces working on the wellbore wall. A diverse group of wells in terms of drilling fluid used, drilling practices employed, lithology of formations drilled, and time of exposure experienced is used to highlight the relationships between these disturbances and the time-dependent stability. To aid in illustrating these relationships, the mechanical properties and the stresses are estimated from open-hole wireline logging data.
The relationship between time and wellbore stability was observed to reverse from the norm in some cases. It is believed that the anticipated charging of the local pore pressure due to the hydrostatic head overbalance and the heat transfer between the drilling fluid and the formation both combined with different operational practices and drilling events to produce this reversal in the relationship. The drilling events considered include long exposure times due to logging runs and troubles, well control events, lost circulation events, and reaming operations. The observed relationship is then compared with published time-dependent wellbore stability solutions where a form of reconciliation is produced.
The presented change in the time-dependency relationships can open new doors for a more sophisticated computational modeling of wellbore stability.
Conical Diamond Element CDE Bit Served as a Drilling Optimization Tool for High-Impact Carbonates and Interbedded Formation in Offshore Mahakam Field
Authors: Noviasta Bonar , Fidiansyah Ardho 
Published: March 2018

Abstract
Offshore Mahakam is one of the fields developed by Total E&P Indonesie. Some of the areas in this field have challenging drilling conditions consisting of hard and thick carbonates as well as interbedded carbonates, sandstone, and shale, which naturally pose a risk of high-impact damange to cutters, especially PDC cutters. These challenging zones were encountered in 12.25-in or 8.5-in hole sections, where multiple bit runs were normally required to drill to the section total depth (TD) due to a low penetration rate as a result of worn or broken bit cutters. This situation reduced the drilling efficiency in those specific areas.
The conical diamond element (CDE) bit was proposed as a means of more efficient drilling in these challenging carbonates and interbedded formations. The unique 3D geometry of the conical diamond elements, which were placed across the bit blade, provided not only a superior impact and wear resistance, but also a concentrated point load onto the formation, which failed and fractureed the hard-to-drill rock more efficiently. The CDE also featured a diamond layer that is twice as thick as that of a conventional PDC cutter, enhancing impact strength and improving overall bit durability. For the specific high-impact formation in offshore Mahakam field, the presence of the CDE would give an ultimate protection to the conventional PDC cutters and therefore preserve the bit cutter sharpness in order to maintain the performance until end of the run.
CDE bits were utilized in three (3) different areas: M, P, and J in Offshore Mahakam. One well was drilled in M and P area, while five (5) wells were drilled in J area. Most of them were used to penetrate hard and high-impact carbonates in 12.25-in section. The performance was excellent, with an ROP improvement of 101.4% in M, 82% in P, and up to 41.3% in J area (compared with offset wells). Various CDE bit designs were implemented in J area, and each design had a specific benefit which continuously improved the ROP from one well to another. In J area 8.5-in section—which has interbedding carbonates, sandstones, and shales layers—the CDE bit performed very well, drilling the section to TD in one run, eliminating two unnecessary bit trips that the offset well had experienced. Compared with the offset well, there was up to a 60% ROP improvement in the 8.5-in section.
Innovative Lay Analysis to Assure Integrity and Minimise the Cost of Laying on Highly Irregular Seabed
Authors: Shahyarfar S. , Hariraj S. J. , Zulkepli M. I. Z. , Zukir S. N. M. 
Published: March 2018

Abstract
Management of geohazard risks and lowering the costs can only be achieved by adopting an out-of-the box thinking for the development of novel techniques. To meet the expectations innovative lay analysis has been developed for laying of umbilical and flexible flowlines of Jangkrik Complex Project. The complex comprises subsea wellheads in water depths down to 430m, tied back to the FPU via 9 flowlines and 7 umbilical's resting on a seabed along routes including major escarpment areas with undulous terrain while descending mountains at angle up to 50 degrees, seabed surface varying from soft clay & silty sands to weak coral area, and passing through large boulders area.
The new approach is based on dynamic continuous lay method used in installation analysis. This method is an improvement to the normal static steps lay analysis method that produces unrealistic results in steep slopes. The discrepancies occur as by laying of product and moving of vessel forward in each static step, software solves for the static equilibrium position by iterating to achieve zero out of balance force thus affecting the friction force in equilibrium and residual tension at TDP. This new method remembers line motion history to capture the correct frictional effects and residual tension at TDP.
The most significant benefit of this novel technique is in reducing the overall cost of the project by reducing the offshore installation complexity by minimising seabed intervention work and speeding up the operational time. This method has significantly reduced the required length of protection such as the Uraguard™ and VIV strakes along the span section by identifying only the critical free spans. This paper introduces the dynamic continuous lay method and compares it with the conventional method, and further validates the accuracy level of this technique by comparison of obtained results with offshore survey data. High accuracy level in defining of residual lay tensions leading to predict correct free spans on uneven seabed and has proven to be vital cost saving for similar projects.
Successful Application of Hardfacing on BHA Components While Drilling in Abrasive Formation
Authors: Wan Nor Afiqah W. A. , M Khairol Affendy A. R. , Amirul A. , Hafidz A. R. , Ludovic Mohr , Sinasi Eren 
Published: March 2018

Abstract
The paper discusses the successful application of HF6000 hardfacing on the drilling bottom-hole assembly (BHA) in TT development wells in offshore Sarawak, Malaysia to overcome tool wear and high vibrations while drilling hard and abrasive formation.
HF6000 is a hardfacing application on downhole drilling tools that uses a combination of diamond and tungsten carbide inserts to increase wear resistance. In the offset wells, including TT exploration/appraisal wells drilled between 2000 and 2012, harsh drilling environment was encountered resulting in BHA wear, and consequently excessive vibrations as well as premature tool failure. In anticipation of similar drilling conditions in the development drilling campaign in 2016, the drilling BHAs were protected with HF6000 before use.
Following the application of HF6000 on the drilling BHA and combined with other mitigation measures to handle the challenging drilling environment, BHA wear and downhole vibration issues managed to be minimized. Further, no major downhole tool damage was reported, saving PETRONAS Carigali Sdn. Bhd. from damage and Lost in Hole (LIH) claims by the directional drilling contractor, as well as unplanned BHA trips.
From the result of the observations in TT drilling campaign, the paper concludes hardfacing on drilling BHA components may be considered for wear protection in abrasive drilling environment to reduce downhole drilling problems and premature failure of drilling tools.
Maximizing More Barrels in Brownfield Rejuvenation through Integrated Collaboration
Authors: Sharir Nurul Aida Jamiah Mohd , Nordin Norintan Farina Mohamad , Latif Azzad Hafiz Abdul , Khairul Wan Mohd Anas Wan , Mohamed Tatmimiddin Al Hasani , Johar Zurita 
Published: March 2018

Abstract
In today's business paradigm, early monetization of resources is a key competitive edge. This requires an effective development plan fostered via sound cost-benefit analysis followed by the systematic and timely implementation of said plan. The drive to obtain faster oil has led to a comprehensive collaboration between PETRONAS and PSC Contractors in one of its biggest oil fields.
Daisy Field is situated 170km off the coast of Terengganu, Malaysia and the first oil was discovered in 1991. The field reached its peak production in 1999 (90,000 bopd) and has undergone steep decline since then, with current average production of ~25,000 bopd. Using extensive historical surveillance and production data, an initiative was taken to identify and unlock remaining reserves.
A new approach to an existing engineering technique called Locating the Remaining Oil (LTRO) has been applied in Daisy Field as an alternative to time consuming static-dynamic modelling. This new approach integrates cased hole log information, production data and decline curve analysis in order to identify bypassed or undrained oil that can be monetized through behind casing or infill drilling.
This paper is a case study on the utilisation of LTRO for brownfield rejuvenation. LTRO is a low-cost but effective solution for idle well reactivation; it may accelerate identification of opportunities, which could be exploitable even during low oil prices, as prevailing currently. Following its deployment within the collaboration, reserves addition has been realized, value created and the cycle time for brown field development plan approval was reduced significantly. This paper will also demonstrate how integrated collaboration between host government, operator and service provider can be a good synergy for effective brownfield rejuvenation.
Realizing Cost Optimization of Offshore Welding Using Automated Ultrasonic AUT Testing and Engineering Critical Assessment ECA
Authors: Zin Ghazali Md , Ibrahim Kamal Azam , Chik Hambali 
Published: March 2018

Abstract
In the past, the use of RT and workmanship criteria for pipelaying is the preferred method due to smaller capital expenditure and relatively easier to implement. The dependency on RT personnel and welder's skill and efficiency are the key factors in ensuring weld integrity and improved cost savings. This method have been proven in terms of weld integrity and also cost saving to the company.
Over the years, there are increasing concerns over the weld integrity, weld repair cost due number of weld repairs and decreased in productivity. Typical weld defects are incomplete penetration (IP) due to manual fit up, incomplete fusion (IF) and porosity. These defects are viewed and measured from a 2D perspective based on RT interpretation. The actual defect size (width) and its distance from the pipeline wall is unknown. In comparison, the utilization of AUT is able to size the defects based on its length, width and height. This will essentially detect all the defects in the weldment and eliminate all the missed out defects by RT.
By embarking on the use of AUT and ECA approach, less downtime and reduced weld repair rates is expected. This leads to enhancement of weld integrity and reduction of the overall cost of the projects as well. The use of Gas Metal Arc Welding (GMAW) process with minimum repair rate has increased the productivity and layrate of pipelaying barges. The overall weld repair rate has been to a minimum i.e. 2% lesser than company's target which leads to less downtime. These improvements allow for the reduction on the number of days required to install the pipeline, allowing immense cost savings on the barge daily rental.
In 2014, the AUT and ECA have realised more than RM20million cost savings based on the reduction of weld repairs. The pipeline was later hydrotested and commissioned prior to gas in. No anomalies were observed. The use of AUT and ECA has proven to be cost effective and enhance pipeline integrity in comparison to the conventional RT and workmanship criteria.
New Inflow Performance Relationship for a Horizontal Well in a Naturally Fractured Solution Gas Drive Reservoirs using Artificial Intelligence Technique.
Authors: Tariq Zeeshan , Abdulraheem Abdulazeez , Khan Mohammad Rasheed , Sadeed Ahmed 
Published: March 2018

Abstract
The idea of continuous assessment of individual well performance is imperative globally to E&P organizations when it comes to production optimization regimes and increasing profitability from each barrel of oil present. One of the most effective ways to assess this performance is through the use of Inflow-Performance Relationship (IPR) & Outflow-Performance Relationship (OPR) curves. Consequently, the use of the pertinent IPR which is representative of the performance is essential.
Vogel's IPR has been employed in the industry more like a standard when it comes to conventional reservoirs well performance. Moreover, Vogel's IPR model can successfully model IPR for vertical wells in a homogeneous reservoir producing from solution gas drive mechanism. However, current IPR models for horizontal wells are only valid for single porosity reservoirs, and their applicability to dual porosity/dual permeability reservoirs is questionable. The complexity in such reservoirs arise due to the combined flow between the distinct systems of the matrix and fracture, and as a result, it is imperative to develop a new IPR model that incorporates the impact of the fracture parameters.
This work focuses to inspect effects of the complex flow behavior on the inflow curves, concentrating on horizontal wells in NFR's. Foundation of this work is based on the development of a base case black oil computational model incorporating typical reservoir and PVT properties. Finite number of data points linking oil rate to flowing bottom-hole pressures were used to generate the dimensionless IPR curves. Wide-ranging PVT and particular reservoir properties concerning two systems of porosity and permeability were used which included; Inter-porosity flow co-efficient, storativity ratio, normalized horizontal well length, reservoir thickness and saturation pressure. As expected, it was concluded that the NFR parameters of storativity and inter-porosity flow coefficient, along with the normalized horizontal well length had substantial control on dimensionless IPR curve. To further augment the results, effort is expended to congregate outcomes into one unpretentious model using a combination of support vector machine and non-linear regression techniques along with the particle swarm optimizer to formulate a new empirical IPR equation.
The newly suggested pragmatic IPR model produces results within acceptable absolute error range of 2%, when compared with the actual data. Accordingly, this proves that the developed correlation is very accurate and can prove to be a vital tool for production/reservoir engineers concerned with the production optimization/enhancement of horizontal wells in naturally fractured dual porosity-dual permeability reservoirs.
Rejuvenation of a Matured Oil Field: Getting Ready for EOR
Authors: Mahbob I. N. , Ooi Raymond E. H. , Jaidi M. Z. , Ahmed S. R. 
Published: March 2018

Abstract
An oil platform located offshore Sarawak, Malaysia consist of 16 platforms and has been in operation since 1972. To sustain its production, PETRONAS have embarked on a plan further develop the field through the introduction of Enhanced Oil Recovery (EOR) by adopting Immiscible Water-Alternating Gas (iWAG) injection technology.
This paper reviews the approach adopted in preparing the existing facilities for EOR with consideration on process debottlenecking, asset integrity and life extension. Discussion also includes offshore execution strategies that was applied by the project to manage key risks as well the challenges faced since commencement of the project. Scope identification, prioritisation, optimisation and detailing were carried out during the Front End Loading phases. Four (4) case studies specific to modifications to meet new process envelope requirement is presented in this paper to demonstrate the approach adopted in meeting both EOR requirements and extending the life of the facility. This includes replacement of wellhead flowlines, crude oil transfer pump upgrade, selection of bulk desander and separator debottlenecking.