bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Impact of Dynamic Filtration on Formation Testing in Low Mobility Carbonate Formations. Case Study: Lower Cretaceous Carbonate Reservoir in the UAE
Authors: Kuliyev Myrat , Lyonga Molua Sammy , Cig Koksal , Sepehri Siavash 
Published: November 2019

Abstract
Formation pressure and sampling measurements in low mobility formations under dynamic filtration can lead to measurements influenced by continuous mud circulation. Generally, active mud circulation inhibits mud cake growth, promoting filtration and invasion of mud filtrate into the reservoir. The resulting invasion adds its own pressure to the actual formation pressure. This is more pronounced in low mobility formations where pressure or sampling measurements made with mud circulation show higher than expected reservoir pressures and/or extended clean up times as a result of dynamic filtration and invasion.
We focus on formation pressure acquisition and present data sets where pressure acquisition was done with active mud circulation. The data is then compared with measurements acquired in a pseudo-static and static mud column.
The measured near wellbore formation pressures acquired with active mud filtration are significantly higher (in some cases, &gt; 400psi) compared to those obtained with a static mud column (assumed to be reading closer to the true formation pressure). The additional pressure is often referred to as supercharging, i.e., the excess pressure superimposed on the original formation pressure by the viscous flow of mud filtrate. The difference depends amongst other factors primarily on the formation mobility and surface pump flow rate during the pressure acquisition. For higher mobilities, there is generally little appreciable difference between active mud circulation and zero mud circulation. Secondary factors like pipe movement, pipe diameter, mud composition and reservoir wettability also influence the degree of the extra pressure measured.
Best practices for formation testing while drilling in low mobility carbonates are discussed. Lessons are drawn from experience where ignoring such best practices result in questionable data.
Application of Cryogenic Spill Control Techniques in Floating LNG
Authors: Mulè Giampiero , Luciano Valentina , Pastorello Antonino , Whymant Alan 
Published: November 2019

Abstract
Coral Sul FLNG is designed to produce, liquefy, store and transfer LNG and condensates directly at the offshore reservoir. Over 430 meters long, Coral Sul will be the first FLNG ever built to operate in ultra-deep waters, its wells are located 2000 meters below sea level. The vessel is currently under construction by Technip, JGC, Samsung Consortium (TJS) in South Korea for a joint venture led by Eni as operator and partners (ExxonMobil, ENH, GALP, KOGAS and CNPC).
The main safety challenges for the FLNG technology, relate to the management of cryogenic spills on board and the protection of people and assets in a very congested environment.
FLNG technology is introducing a set of new safety rules for the industry which are still under development by main international certification bodies. Today, the lack of industry standards regarding FLNG technology, and the congested nature of the installation, make the Risk Based Approach an essential step to validate the design and identify fit for purpose reduction measures.
Coral project carried out several actions for Cryogenic Risk Management with the aim to: ensure safety of all the Personnel on Boardminimize the potential for escalation and maintain asset integrity.
This Paper describes the Risk Based Approach followed for Coral FLNG project and describes some of the most important design safety measures implemented on board to manage cryogenic spills: Design of Drainage System and Overboard dischargeDesigned against the Risk of Rapid Phase TransitionActive Protection Methods: Water Curtains to protect hull sideImproved Coating Materials (combined effect Cryogenic Spill Protection + Passive Fire Protection)
Suitable design of drainage system is a key safety aspect for the design of the FLNG, since it is essential to minimize the vaporization which can create dangerous flammable gas clouds on board.
The solution proposed for Coral Sul FLNG is a combination of open gutters, sloped open channels and vertical pipes which allow the quick discharge overboard of accidental spills, minimizing the vaporization in congested areas. In proximity of overboard spillage points, water curtains are implemented to protect the hull side, and the effect of discharge is evaluated for rapid phase transition.
Steel decks and structures must be protected against fractures that can follow accidental cryogenic spillages and lead to structural failures which put at risk lives and assets. Specific coating materials have been developed for the protection of decks, piping and equipment to avoid the escalation of any incident. These coatings provide combined protection against embrittlement and fire. Application of coating is done used RBA approach.
Design of drainage system and coatings have been identified as technical novelties. A technology validation program has been put in place for Coral Project in order to assess the maturity of the new technologies.
Successful Management of Collision Risk in an Extended Reach Well
Authors: Naknaka Manchukarn , Prasertamporn Praisont , Ledroz Adrian , Naranasamy Jayaneethe , Ramasamy Kesavan 
Published: November 2019

Abstract
Mubadala Petroleum planned to drill a complex Extended Reach Well (ERD) from an existing platform. To reach the required geological targets, the preferred wellpath was required to pass within close proximity of an adjacent oil producer that had a resultant separation factor (SF) of 0.70. A SF of less than 1.0 presents a mathematical possibility of well collision due to overlapping Elipses of Uncertainties (EOU). As such there was the likelihood of the inability to drill the well with a consequencial impact to the Mubadala business plan. A novel solution was by implemented by utilizing High Inclination Drilling with Gyro (HIDWG) tool to safely manage and mitigate the risk of well collision.
The Jasmine field is a mature, complex oil field containing multiple stacked sandstone reservoirs, largely having individual oil and gas water contacts that have been on production since 2005. One of the major challenges is safely and economically accessing the remaining bypassed oil. Wellpath collision is an ever increasing risk as the ageing assets become more congested, which could lead to property damage and losses of production. Collision avoidance is gauged with a SF that takes into account the well depth, toolface, and the error model of the electronic survey tool.
A conventional Bottom hole Assembly (BHA) with Measurement While Drilling (MWD) tool was initially considered, however the proximity calcuations yielded a SF of 0.7, and the well could not be drilled according to the company's drilling standard. To manage the risk and safely drill the well, the survey error uncertainty needed improvement. Instead of a conventional MWD, a High Inclination Drilling with Gyro (HIDWG) tool was utilized to reduce the survey error uncertainty to yield higher precision drilling control at depth in excess of 10,000 feet and at an inclination higher than 70 degrees.
As a result of the BHA upgrade, the SF was instantly improved from 0.70 to 1.0, the collision risk was reduced to an acceptable level, and the well design was compliant with the drilling standard. Furthermore, the HIDWG was utilized for the first time in the Gulf of Thailand.
Mubadala Petroleum successfully executed the ERD well utilizing the HIDWG, in combination with an Advance Hybrid Rotary Steerable System (RSS). The HIDWG tool provided an all-inclusive real-time surveying solution that delivered highly accurate surveys and with the Advance Hybrid Rotary Steerable System (RSS)'s precise drilling control throughout the intervals of close proximity with other wells.
This paper explains how the HIDWG tool provided an inclusive surveying solution that could deliver both high accuracy surveys and precision drilling control throughout the zones of anti-collision concern of the ERD well. The chosen solution enabled the ERD well to be drilled to the required target successfully and allowed production to be established as planned.
Monitoring of Volatile Organic Compounds to Sustain Safe Laboratory Working Environment
Authors: Yonebayashi Hideharu , Sasaya Kazuyo , Watanabe Takumi , Inamura Takashi , Kobayashi Atsushi , Iwata Takao 
Published: November 2019

Abstract
As a part of laboratory Health, Safety and Environment (HSE) management system, the working environment control is applied to eliminate exposure hazards for workers. This control is a continuous effort in our laboratory as the working environment management system. Volatile organic compounds (VOC)s are ones of very common exposure hazardous factors in petroleum R&D laboratory. To better working environment control, the working environment measurement additionally to the chemical risk assessments is conducted at first to assess the concentration of VOCs in accordance with the guideline of domestic act. The measurement design is optimized on the basis of actual chemical use in the monitoring objective laboratories. The chemical records has been tracked in the chemical inventory management system. The measurement is conducted by two methods to assess both of average and the maximum VOC concentrations in the objective laboratory. Based on the measurement results, the objective laboratories are classified into three ranks. If necessary, counter actions will be taken: for instance, ventilation system improvement as building management, and consideration of substitute. Furthermore, the working record what types of chemical used and how long hours to handle them are linked to the health management system in which the workers who handle solvents must take a semi-annual special medical check. Further potential improvements were debated by adopting the process safety management in laboratory phase, and installing flexible exhaust system.
The working environment management is important for protecting employee's health. The system is not independent and linked to other HSE management systems. Therefore, a well-organized grand design is worthy as total management system which includes each management system for waste, inventory, procurement, building maintenance, and so on. Because this paper discussed a practical example of HSE management system from both of detailed and high level. The discussion should be useful for considering HSE in laboratory.
Success Story of Utilizing Real Time Drilling Data to Remotely Support Drilling Operations and Identifying the Areas of Drilling Performance Improvement
Authors: Mohamad Abdul Salam , Al Dhanhani Omar , Joshi Ashish , Hussein Ahmad , Alsawwafi Khadija , Clergier Alberic , Dubey Anurag , Pausin Wiliem , Al Fardan Firas , Jradat Amin 
Published: November 2019

Abstract
Upstream Oil & Gas industry has been continuously focusing on reducing the operating cost, while targeting higher operational efficiencies. To that extent we are seeing a continuous move towards remote operations with efficient utilization of available data to identify operational issues and provide benchmarks for improving drilling performance. The industry is putting significant efforts into using instrumentation and software to optimize operations in all domains for exploration and production (E&P) to move towards the Digital Oil field of the future.
With a similar vision, ADNOC Onshore have implemented Real Time Data Management project in partnership with Schlumberger for enabling remote real-time drilling operations and performance reporting across its entire active rig fleet. The objective is to provide a single platform to users for: Technological solution enabling real-time data transmission from all rigs to ADNOC Onshore Headquarters and enabling real-time visualizations of the drilling data.Engineering solution to transform real-time data into information to easily identify the areas of operational improvement allowing to implement specific measures to reduce ILT and NPT which can help in reducing costs and risk.
This project has also provided an automated Drill Well on Paper (DWOP) process where high frequency real-time data is utilized along with low frequency Daily Drilling report data to provide better insights for well planning and generate ideas for improving performance and reducing costs.
A Novel Low-Cost Process for Sour Gas Sweetening and NGL Recovery
Authors: Rafati Navid 
Published: November 2019

Abstract
Greater than 40% of global natural gas reserves are sour, with hydrogen sulfide concentrations that make processing that gas uneconomic in most cases. Furthermore, it is desirable to economically sequester acid gas contaminants from these resources due to growing environmental concerns. Current conventional technologies such as amine, cryogenic, and membrane systems typically fail to achieve the aforementioned objectives. Thus, there is a need to develop new technologies for sour gas processing.
In this work, a new low temperature process for sweetening and fractionation of highly-sour natural gas is presented. The process, called "TarT", is capable of separating CO2 and H2S contaminants from the sales gas as high-purity, high-pressure streams while also recovering the NGL content of the feed gas.
It is shown that the TarT process consumes about 37% less energy as compared to conventional MDEA sweetening and NGL recovery processes to produce sales gas, C4, C4+ NGL blend and high-pressure CO2 and H2S contaminant streams. The TarT process introduces a new and highly economically advantaged approach to fractionate highly-sour natural gas and sequester the resulting acidic gases.
Managed Pressure Drilling Tackles Pore Pressure Uncertainty While Drilling, Running Liner, and Cementing Across Multiple and Heterogonic Layered Reservoirs for the First Time in the United Arab Emirates
Authors: Al Shehhi Maha , Al Ameri Saleh , Hadj-Moussa Ayoub , Saleh Mujahed 
Published: November 2019

Abstract
This paper presents the novel approach used in drilling, running liner and cementing a development well across multiple reservoir with high pore pressure heterogeneity that has historically caused drilling hazards like differential stuck pipe, losses, well control and slow rate of penetrations.
Having depleted reservoirs and high-pressure reservoirs in the same hole section of well-A dictates that the mud weight must be higher than the higher reservoir pressure, which puts high differential pressure on the depleted reservoir and causes differential stuck pipe and losses. The uncertainty in determining the pore pressure adds another challenge as the mud weight must be higher than the expected pore pressure. Managed Pressure Drilling (MPD) addresses these challenges by enabling determining the pore pressure while drilling and adjusting the Equivalent Circulation Density (ECD) to be with the minimum overbalance.
MPD allowed drilling the section with (12.0 ppg) mud weight instead of the conventional mud weight (15.7 ppg). This has reduced the differential pressure between the depleted formation and the other formations significantly and enhanced the rate of penetration while balancing the well. It also proved that verifying the well's prognosis for pressure is essential in avoiding drilling hazards. Constant Bottom Hole Pressure (CBHP) mode of MPD was used to maintain the same ECD while drilling and connection to avoid well influx during pumps off events by compensating the annular friction pressure loss by surface back pressure. MPD was utilized too in running the 7″ liner and cementing it as a guarantee if the mud weight was too low to stabilize the well. The operation was carried out without safety or quality issue. The MPD system performance was with zero nonproductive time and the hole section was drilled shoe-to-shoe without any change the Rotating Control Device (RCD). This application showed an alternative preventive solution to differentially stuck pipe instead of the reactive one.
The approach explained in this paper is the first of its kind in ADNOC Onshore field. It involved altering the mud weight program strategically for more adaptive approach in dealing with drilling hazards like differential stuck pipe, losses and well control. The scheme involving MPD for running liner and cementing is the first ever in United Arab Emirates.
Acquisition of an Ultra High Density 3d Seismic Survey Using New Nimble Nodes, Onshore Abu Dhabi
Authors: Nehaid Hani , Ourabah Amine , Cowell James , Brooks Chris , Stone Johnathan , Dieulangard Damien , Crosby Alistair , Naranjo John , Mahgoub Mohamed , Al Mesaabi Saif , Ablyazina Dinara , Manning Edward , Popham Mike , Tough Kenneth , Vasile Cosmin , Quigley John , O'Connell Kevin 
Published: November 2019

Abstract
The benefits of using autonomous nodes in a desert environment to efficiently achieve very high trace density seismic surveys with reduced HSSE risk and improved operational efficiency are increasingly being recognised by the industry. ADNOC, in partnership with BP, Rosneft and WesternGeco recently deployed 50,000 newly-developed ultra-light nodes (Manning et al, 2018) with simultaneous vibroseis source technology to acquire the densest ever seismic survey on land. The survey covered an area of 81km2 containing significant surface infrastructure and sand dunes.
The field trial had two main goals: first demonstrate the readiness of this new nodal system to acquire high quality seismic at full scale in a production-like setting; and second, to compare the data recorded by this new system to legacy data acquired by a conventional array geophone system and demonstrate the benefits of the former in terms of safety, operational efficiency and ability to image fine stratigraphic details at the reservoir.
The Digital Directional Drilling Evolution
Authors: Stepnov Alexey , Chatar Crispin , El Hawy Ahmed , Cassel Justin , Abouassi Basem , Khader Celine 
Published: November 2019

Abstract
Digital technologies are changing the way we work and are empowering the world. The oilfield is no different. Directional drilling is no longer challenged by distance or harsh environments. One oilfield service company began an innovative digital approach to directional drilling and logging while drilling (LWD) over a decade ago. Recently, technology and infrastructure enabled the industry to drill directional wells without engineers physically at the wellsite and independent of technical complexity. Digitalization is a complicated task for any service company. It requires a complete change of all workflows and implementation of cutting-edge technologies to drive the change. The current infrastructure includes a worldwide network of digitally connected operation centers (DCOCs) that provide advanced services to ensure operations are delivered efficiently and can be easily implemented. Even in the case of unforeseen circumstances when field engineers cannot go physically to the wellsite, operations can continue normally with some management of the change. As a result, multiple locations are currently drilling various well types, including horizontal wells with zero or minimal personnel at the wellsite.
It is evident, with ongoing digitalization in many forward-thinking industries that eventually drilling will take the neccessary steps. This is understandable due to the cost and operational norms of the industry but applying the technology in an efficient and cost-effective manner will yield gains for even the most discerning high-volume markets and, at the same time, improving key performance indicators. Directional drilling digitalization is still not a widely accepted concept for drilling everywhere on the planet. Companies continue work with full crews on location in most operations. The conservative approach of delivering directional and LWD services with the engineering teams located at the wellsite was restricting operators, so complicated well profiles in many areas, including some areas in the Middle East, were avoided. This paper is intended to lift the veil of uncertainty from digital directional drilling and show what is possible today and in the future. This paper will highlight the history of digital directional drilling operations, measurable benefits, lessons learned, and what is done today, and finally focus on the next steps in the digital evolution of drilling. Several new enabling technologies, innovative processes, and analysis of results will be discussed in the context of this new way of working.
Deepwater Pipelines Installation Risks and Challenges
Authors: Sinha Nitesh , Kumar Singh Nawin 
Published: November 2019

Abstract
With the advent of next cycle of stabilization and steady increment of oil and gas prices, the deepwater blocks which were marginalized due to high development cost, are beginning to appear as a lucrative proposition again. Globally new oil and gas production is focused in remote locations which are also challenging to operate. Deepwater, ultra-deepwater, tight oil and shale gas are great examples of this. In last two decades, exploration & production players have made rapid progress in pushing the depth of subsea production. The on-going development of new hydrocarbon discoveries in different deepwater regions creates significant opportunities for the pipeline industry. Also, the need of the ‘oil & gas markets’ to get well connected with the ‘oil & gas producers’ is leading its way to the announcements of long distance deepwater pipelines in a record water depth of up to 3500 m in the recent past.
Gearing up for this challenge, this paper broadly elucidates the deepwater pipeline installation risks and challenges, such as selection of the line pipe to sustain high external over-pressure and tensile stresses generated due to installation forces, selection of external coating system, capability requirement of installation vessels with high tensioner capacity to hold the long catenary of thick-walled pipe, pipeline configuration control and prevention against accidental flooding while laying, challenges in touch-down point monitoring and buckle detection, seabed intervention requirement & methodologies and new evolving testing & commissioning philosophies required for ensuring the integrity of the deepwater pipelines after installation. This paper also covers the findings of installation analysis, for S-lay configuration, performed for deepwater pipelines with varying water depths.
This paper intends to bring awareness among the "oil and gas fraternity" regarding challenges involved in ultra-deepwater pipelines and discusses the technical advancements made in this segment and the need of further works for bringing the installation of pipelines in ultra-deepwater one step closer.