bluuebunny/crossref_metadata_2025_split huggingface dataset:
Do You Know About Vibration In Static Equipment?
Authors: Mashjari Khoula Al , Awadhi Ibrahim Al , Sharma Ashok 
Published: November 2017

Abstract
High vibrations were observed in one of the largest incinerator (6m diameter and 44m long) of recently commissioned all four SRU in GASCO plant (Fig. 1) which could lead to integrity concern and increase inspection and maintenance of the unit. Some damage of refractory, insulation and nozzle weld were also observed. This paper presents state of the art analysis and approach followed to not only identify the root cause but also provide solutions to mitigate the vibration.
The high vibration posed a challenge, as unlike rotating equipment/piping, no industry standard defines acceptable vibration for static-equipment. Actual vibration measurement across complete length of the incinerator were performed for various operating condition. Operating data were analysed for these condition. In order to study the acoustic response, natural frequencies of the system and identify source of vibration, 3D models of not only burner, but incinerator, superheater, stack and air and process gas ducting was also build. Further, instead of conventional CFD, specialized thermo-acoustic CFD analysis for numerous operating cases and FE/Fatigue analysis were performed to address this complex combustion issue.
Vibration measurement concluded that even though frequency of vibration is same throughout the incinerator, high amplitude upto 38rms with 11Hz frequency is in superheater and frequency drops by a decrease in temperature. As conventional CFD analysis could not identify the source of the vibration, a specialized complex thermo-acoustic analysis was carried out. Analysis concluded that vortices are formed in burner region due to improper mixing of combustion gases which created pressure fluctuations causing vibrations at frequencies correlating with field measurements. Hence improper burner design was identified as the root cause of vibration. FEA and fatigue analysis indicated potential premature nozzle failure in superheater region. Although conventional approach of replacing complete burner with new burner and ducting would have resolved the vibration and ensured integrity, however it would have costed 4MUSD. Instead, several options to eliminate the root cause were explored and provision of choke ring inside the incinerator was identified as optimum solution ($1.2M). To "Deliver More for Less" alternate solution of installation of a stiffener-ring ($80K) in super-heater region was recommended to change the natural frequency and reduce vibration to acceptable limits.
Vibration issues in the incinerator package may not only be due to flow but can also be related to combustion. Such issues are more complex especially for such a large incinerator and difficult to resolve with a conventional approach. This specialized study not only helped to identify root cause or source of vibration but also address the same in most economical way and success of analysis is supported by proper technical analysis and justification.
Application of UBD and MPD Improved Discovery of Fractured Granitic Basement Hydrocarbon Reservoirs
Authors: Chen Peng , Wang Xi , Chen Lei 
Published: November 2017

Abstract
Extensive discoveries of basement hydrocarbon reservoirs have been made in many places of fractured granite and carbonate basement in the world. Important hydrocarbon findings were achieved in fractured granitic basement in Chad and Indonesia by means of UBD and MPD technologies.
The granitic basement in Chad and Indonesia featured with hydrostatic pore pressure gradient with narrow density windows and well developed fractures. The pore pressure coefficient of the basement of Chad was predicted in between 1.02-1.06, and an underbalanced drilling (UBD) technology with a micro-foam drilling fluid was used to make an attempt on reducing drilling fluid losses; the pore pressure coefficient of the basement of Indonesia was estimated to be 1.04, and an underbalanced managed pressure drilling (UB-MPD) technology with a synthetic based drilling fluid was utilized to avoid drilling fluid losses and in favor of hydrocarbon discovery.
Different drilling technologies or modes received different results although drilling in same fractured granitic basement with similar pore pressure. Losses and kicks continued almost all the time during drilling, coring and wireline logging in some wells during UBD in Chad. Losses happened as soon as the rig pump started while overflow occurred no sooner than the rig pump stopped. However, the potential problem of losses and kicks was completely controlled by utilization of UB-MPD technology in Indonesia. No losses were found during underbalanced managed pressure drilling, tripping, connection, and circulation. Nevertheless, both basement hydrocarbon reservoirs in Chad and Indonesia have been obtained important discovery. Crude oil returned to the surface during UBD in Chad and abundant natural gas produced during UB-MPD in Indonesia.
Both UBD and UB-MPD technologies are effective to gain the discovery of fractured granitic basement reservoirs. The underbalanced MPD technology, a precisely pressure controlled drilling system, is able to accurately control the annular pressure profile throughout the wellbore, therefore it could effectively achieve safe drilling in narrow density window and cut non-productive time. It is proved to be more effective and safer in drilling of fractured granitic basement.
Human Factors Engineering HFE: A Review of Human Elements that have Contributed in the Occurrence of Major Accidents in Process Industries and Total Abu Al Bukhoosh TABK Means of Engineering Effective Mitigations
Authors: Viramuthu Vijai Ananth 
Published: November 2017

Abstract
Major accidents happen in the process industries with relatively low frequencies coinciding with extremely severe consequences. The harm to workers and the public, resulting from a loss of company property and other assets, business interruptions, and environmental degradations are all possible outcomes of such events. This paper explores the human factors in occurrence of major process accidents within the last decade and offers suggestions for their prevention via process safety management (PSM) principles, risk assessment and engineering philosophies to prevent and mitigate the occurrence of major accidents.
In the process industries, a major accident is an incident that typically results in numerous severe injuries and possible fatalities. In seeking to prevent these outcomes, a series of barriers in combination of human and engineering elements have been integrated into the process system designs. This study will review the broken human factors and barriers leading to the development of these events, while also highlighting key aspects of the Total Abu Al Bukhoosh (TABK) Technological Risk Assessment (TRA) processes. These assessments seek to ensure similar major accident hazards and threats are arrested through proper evaluation and systematic installment of human specific barriers.
Extensive Miscible Water Alternating Gas WAG Simulation Study for a Giant Offshore Oil Field
Authors: Kohata Akihiro , Willingham Thomas , Yunus Khan Mohammad , Al Sowaidi Alunood 
Published: November 2017

Abstract
The subject field is a giant offshore reservoir with light oil and a planned long production life extending beyond 100 years. In order to sustain oil production, EOR will be implemented at the appropriate time. As a result of EOR screening, miscible water-alternating-gas (WAG) injection was identified as one of the suitable methods. In order to evaluate miscible WAG potential, extensive WAG simulation studies were conducted in each step including 1D, 2D and 3D simulation.
First, 1D simulations were conducted for tuning the equation of state (EOS). Second, 2D conceptual model simulations were carried out for the preliminary evaluation of WAG. Then, 3D conceptual models for two typical geological areas of the subject reservoir, the "Homogeneous" and "Heterogeneous" geologic areas were generated and findings from the 2D simulation study were validated. Finally, 3D sector model simulations were conducted using the history-matched simulation model to evaluate the miscible WAG potential for full field implementation and its economics. In all simulation studies, CO2 and hydrocarbon (HC) gas were evaluated as miscible injectants.
1D simulations replicated a slimtube test and EOS parameters were tuned to match the minimum miscible pressure (MMP) of CO2 and HC gas. As a result of 2D simulations, "Tapered" WAG appears the most attractive WAG injection scheme in terms of gas utilization and oil recovery. In the Tapered WAG concept, the durations of gas injection varies where longer gas injection cycles are completed initially progressing towards shorter gas injection cycles with progressive WAG sequences. The Tapered WAG concept was also tested using the 3D conceptual model and similar findings were obtained. To evaluate miscible EOR WAG for the full field, due to the size of our field, the high resolution gridding required to capture fluid transport and the 9 component tuned EOS, the required computing resources exceed typical computing capacity; hence, two sector models which represent the Homogeneous and Heterogeneous areas were generated. Based on simulation results, normalized type curves for the hydrocarbon pore volume injected (HCPVI) with incremental recovery factor were generated for each geological area. A production and injection profile for full field WAG implementation was generated by applying these type curves to each pattern and incremental oil production was estimated.
The potential incremental oil production for WAG application for a giant offshore oil field was successfully assessed utilizing extensive simulation scenarios from a preliminary concept using simplified models to a detailed full field analysis using complex models. Through this step-by-step analysis, we were able to efficiently identify the key criteria impacting full field recovery including Tapered WAG, impact of injectant and impact of multi-scale heterogeneity (e.g. 2D-3D).
Success Through Continuous Innovation to Achieve Better Zonal Isolation in Extended Reach Wells in a UAE Field
Authors: Mahamat Habib Abdelkerim Doutoum , Al Katheeri Yousif Saleh , Seales Sheldon , Ramdeen Rayaz Evans , Bermudez Romulo Francisco , Navas Luis Eduardo , Kapoor Saurabh , Pallapothu Surya , El Hassan Azza , Jain Bipin 
Published: November 2017

Abstract
Achieving well integrity relies on achieving zonal isolation among narrowly separated sublayers of the reservoir throughout a long openhole section. This requires flawless primary cementation with a perfect match of optimized fluid design and placement.
In a UAE field, there are several challenges experienced while cementing production sections, predominantly due to long open holes with high deviation, use of nonaqueous fluids (NAF) for shale stability, and loss circulation issues while drilling and cementing. The need to pressure-test casing at high pressures after the cement is set and the change in downhole pressures and temperatures during well completion / production phases result in additional stresses that can further endanger the integrity of the cement. Breaking of the cement sheath would lead to sustained annular pressure and compromise the needed zonal isolation. Hence, the mechanical properties for cement systems must be thoroughly tested and tailored to withstand the downhole stresses.
A systematic approach was applied that used standard cementing best practices as a starting point and then identified the key factors in overcoming operation-specific challenges. In addition to the use of engineered trimodal slurry systems, NAF-compatible spacers, and loss-curing fibers, an advanced cement placement software was used to model prejob circulation rates, bottomhole circulating temperatures, centralizer placement, and mud removal. To enhance conventional chemistry-based mud cleaning and to significantly improve cleaning efficiency, an engineered fiber-based scrubbing additive was used in spacers with microemulsion based surfactant. Furthermore, a real-time monitoring software was used to compute and monitor equivalent circulating density (ECD) during the cementing operation and to evaluate cement placement in real time. Results of cement jobs were analyzed to define the minimum standards/criteria and then to verify the efficiency of the applied solutions.
The 9 5/8-in. casing / liners were successfully cemented using this methodological approach, and lessons learned were progressively used to improve on subsequent jobs. Advanced ultrasonic cement bond logging tools along with advanced processing and interpretation techniques facilitated making reliable, conclusive, and representative zonal isolation evaluation. The cement bond logs showed significant improvement and increased the confidence level towards well integrity.
After establishing field-specific guidelines over 2.5 years, continuous success was replicated in every well for all the rigs operating in this UAE field.
Sour Service Challenges
Authors: Bruschi Roberto , Gentile Manuela , Torselletti Enrico 
Published: November 2017

Abstract
Material selection for sour service is generally based on International Standards. Sometimes there are project conditions that are not properly covered, therefore additional investigations are needed. This fact can arise conflictual discussions between the lay contractor and the field operator, regarding first the selection of the laboratory, and then the method and extent of the weld qualification campaign: disagreements may impact the installation schedule as well as significantly affect the operational requirements. The subject is crucial in field development projects, in both shallow and deep waters, when performance requirements are particularly demanding. In the meantime, field experience shows failure conditions in sour service due to erroneous design choices, inaccuracies during construction, unexpectedly severer flow conditions and/or poor mechanical performance of both line pipe and welds.
Therefore, the upstream community is currently involved in joint industry initiatives that aim to establish international consensus on updating guidelines, aiming to include the lesson learnt from recent project outcomes. The challenges of sour service mainly regard material selection in case of long distance export pipelines from offshore fields, as well as the allowance of functional and environmental load effects on flowlines, i.e., the permissible number and entity of either few high stress cycles on high temperature high pressure flowlines or many small stress cycles on risers and free spans.
In this paper an outline of sour service in offshore projects will be given, with comments on the state of the art from the designer and laying contractor's viewpoint. In particular, lessons learnt from recent experiences are discussed, in relation with the efforts for standardization currently undertaken by international certification bodies.
Deepest Horizontal Well Drilled to TD Using an Underbalanced Nitrified Foam System in a Depleted Limestone Formation in Pakistan: An Analysis of the Design, Execution, and Results
Authors: Khalid Ali , Ashraf Qasim , Luqman Khurram , Takla Elie , Nabi Agha Ghulam , Ashraf Sajjad , Hasan Naveed , Ali Muhammad 
Published: November 2017

Abstract
Located in Sindh on the right bank of the Indus River, the Kandhkot Gas Field was discovered in 1959 and was estimated to contain up to 680 Bcf of gas reserves. The field contains three producing formations: Habib Rahi Limstone, Sui Upper Limestone, and Sui Main Limestone. The Sui Main Limestone formation has been depleted because of extensive production, and it currently exhibits a very low pressure of approximately 3.5 lb/gal (419 kg/m3) equivalent mud weight (EMW).
An operator drilling with a conventional mud system encountered total losses and resorted to heavy lost-circulation material (LCM) pills and cement plugs to cure them. All bridging materials pumped in the hole to cure losses invaded the reservoir formation. As a result, the completed well required excessive cleanup operations to bring it into production. Therefore, the operator faced costs of loss curing materials, damage to the reservoir formation, and a substantial amount of time for drilling and cleanup operations.
The operator sought a solution to not only reduce the costs associated with drilling this highly depleted reservoir formation, but also mitigate invasion damage that inevitably affects overall production volumes. Although underbalanced drilling had been used in similar situations, the operator considered the challenges of this well before execution. The horizontal well design contained a vertical section of about 1,640 ft (500 m). Challenges to account for while drilling the horizontal leg included designing appropriate directional drilling equipment for use with a multiphase fluid, cleaning the hole in the horizontal leg, maintaining underbalanced wellbore pressures in the presence of high annular pressure loss, and achieving drilling performance to offset the cost incurred by underbalanced drilling.
For the given reservoir pressure of 3.5 lb/gal (419 kg/m3) EMW, a nitrified foam system was designed to achieve an equivalent circulating density (ECD) below 3.5 lb/gal (419 kg/m3) EMW. The foam system used a specially formulated polymer system to yield a high foam quality for suspension and cutting carrying capacity. The directional drilling equipment consisted of a special mud motor and extended range electromagnetic measurement-while-drilling (MWD) system to enable drilling with a multiphase fluid system. In addition, a downhole isolation valve deployed inside the casing string enabled isolating the live well while tripping. Using the custom underbalanced system, the operator drilled the well to total depth (TD) in just 3 days and achieved an ROP average of 49 ft/hr (15 m/hr). The paper outlines the planning and design of the underbalanced drilling package, the wellsite execution, and the achieved results.
Security of Critical Infrastructure Using Marine Radar Surveillance
Authors: Johnston Brian 
Published: November 2017

Abstract
The protection of the critical national infrastructure involving oil, gas, water and electricity is vital for the functioning of every country's societal and economic well-being. The selection of high performance and cost effective monitoring solutions for the safety and security of both the people working on offshore platforms as well as locations of national critical importance is crucial. Marine radar surveillance systems can provide early and rapid detection and notification of marine hazards or threats. Trends in various threats to critical infrastructure, such as from terrorist and criminal activities, have created a shift towards a stronger perimeter security model with a focus on countering irregular, asymmetrical threats within a nation's coastal security zone or a localized offshore platform security zone. This has necessitated a change towards smaller, integrated surveillance platforms with associated technologies that serve multiple operational profiles. Separating cooperative targets, using technologies such as AIS, from uncooperative or unidentified targets, has become a priority for many who operate in the maritime environment.
Sensor systems that provide an enhanced 24 hour level of detection and tracking capability in littoral environments that also are cost effective and can be configured across a wide number and range of platforms and locations provide exceptional value in both performance and cost.
Rutter Technologies has developed an enhanced radar processor system, the sigma S6, which provides a superior detection and tracking capability through the implementation of scan averaging and signal processing, making it ideally suited for small patrol vessels, other enforcement platforms, commercial shipping vessels, oil & gas platform operators, and coastal/port security applications.
Identification and Modeling of Inter-Reservoir Communication Using an Integrated Multi-Disciplinary Structural Framework in a Giant Offshore Carbonate Field, UAE
Authors: Shekhar Ravi , Almazrouei Khulood A. , Wendland Corey , Obeta Chukwudi , Al Zinati Osama , Omura Taihei , Bengharbia Mourad , Al Neyadi Abdulla , Khouri Naeema , Al Shehhi Budoor Hasan 
Published: November 2017

Abstract
The challenges to effectively manage a field with stacked reservoirs that are in known hydraulic communication are enormous. Conventional management of such fields can result in many undesired outcomes such as premature water production caused by cross-communication from different reservoirs, inefficient pressure support to some of the individual reservoirs, or large volumes of bypassed oil. The major challenge is to identify the reasons and magnitude of inter-reservoir communication, and accurately capture these in the models which are utilized for optimized well placement and efficient field development.
This paper discusses an integrated multi-disciplinary approach to identify and model inter-reservoir communication in a giant offshore carbonate field from UAE. Tracer study conducted for several years combined with detailed seismic interpretation suggest that the cross-flow of reservoirs due to fault juxtapositions is the major cause of inter-reservoir communication. This observation is further supported by pressure-transient analysis, logs, cores, drilling reports and regional structural studies. Hence, it becomes absolutely essential to build a robust static and dynamic model that can accurately capture the communication between different reservoirs. This paper proposes a novel approach to build a full-field integrated framework that allows coupling of multiple reservoirs that have been previously modeled independently. The methodology includes; detailed reinterpretation of faults and key chronostratigraphic surfaces, qualitative/ quantitative attribute analysis using reprocessed 3D seismic (post-stack time migrated) data, interpretation of pressure transit analysis, logs, surveillance data and regional structural history studies. The updated framework ensures accurate fault throw and fault extension in order to capture fault juxtapositions.
The ability of the new model to allow inter-reservoir communication has been tested and confirmed in dynamic simulation model. This was achieved through series of simulation sensitivities where tracers injected in wells targeting specific reservoirs were successfully sampled from different reservoirs due to inter-reservoir communication through fault juxtaposition. Based on the results of sensitivity test, it is expected that the new integrated framework will provide a much improved history match in faulted areas where cross-communication across reservoir is very prominent. The improved model will lead to a better understanding of field and possibly will be used as guidance for field development plan.