bluuebunny/crossref_metadata_2025_split huggingface dataset:
Characterization and Wax Mass Flux Analysis of Bakrol Field India Crude Oil
Authors: Agarwal J. R. , Kumar S. , Shah S. N. , Sircar A. 
Published: March 2018

Abstract
Wax deposition is one of the most expensive flow assurance issues encountered in crude oil production and transportation. It can lead to drastic production loss and ultimately heavy economic losses to E&P companies. Thus, precise prediction for field case is necessary to avoid this issue. Generally, two basic models, Film Mass Transfer (FMT) and Equilibrium Model (EM) are utilized to determine wax mass deposition in the crude oil pipelines. In this study, theoretical wax mass flux is computed based on these methods and compared with a field data point of wax mass deposited in 1.7 km long buried gathering line at Bakrol field, Gujarat, India. For a field flow rate of 100 m3/day in 4 in. pipe (ID = 3.765 in.), the fluid is in laminar flow regime. This contradicts the presumption that only turbulent flow condition prevails in the field. In addition to this, the analysis revealed that actual field wax mass flux for Bakrol field gathering line is close to the estimated value using FMT model and not EM. This agreement of the field data with laboratory flow loop data might be due to the closeness of field pipe ID (3.76 in.) with flow loop pipe ID (0.5 to 2 in.). Therefore, for Bakrol field, it is suggested to use FMT model for the calculation of wax mass flux rather than the EM model. However, previous researchers have reported predictions from FMT model also holds true for turbulent flow conditions in field case, which is in contradiction with the observation and explanation available in the literature for laboratory scale flow loop data. Thus, field data with larger diameter pipe and different waxy crude oils are required to make a robust conclusion.
Flow Assurance Challenges for FLNG Project
Authors: Hashim Wan Mahsuri Wan , Johar Juhaida M , Norpiah Rohaizad M 
Published: March 2018

Abstract
Floating LNG (FLNG) plant is one of the options to monetize remote and marginal gas field. A robust upstream facility design requirement should include flow a assurance assessment in order to achieve stable operations and protect the integrity of the LNG facility. In this case study for a specific FLNG project, flow assurance issues associated with the FLNG receiving dehydrated gas from a processing platform are explained. The aspects include hydrate management, flow stability and location of the pressure control system. For FLNG, the producing wells normally produced as wet gas to the processing facility via a relatively short pipeline.
A LNG plant requires constant pressure, flowrates and compositions to operate in a stable manner because most equipment such as refrigerant loops, compressor and distillation columns are sensitive to changes in inlet conditions. Consequently the location of the pressure control valve (PCV) and the impact of transient operations on the dehydrated gas were studies including the effect of the gas dehydration unit offline. For the pipeline, the location of the PCV at the upstream facility and FLNG facility affect the pipeline survival time in term of seconds versus minutes.
During normal operating condition, the dehydrated gas poses no major threat to operations as the inlet facility had been designed for, except for low temperature during the initial start-up and the gas turndown requirement during pigging operation. Sensitivity cases indicated that when the dehydration unit is offline, hydrate inhibition is required for shutdown, restart and depressurisation operations. The hydrate inhibition requirement depended on the mode of inhibition required i.e. continuous vs. intermittent or the availability of inhibition for the existing field. An integrated flow assurance study between departing upstream and inlet receiving facilities of FLNG enabled the design of a robust inlet facility suitable for the FLNG process.
Quantitative Seismic Reservoir Modeling – Optimizing Field Development Value through Early and Continuous Data Integration
Authors: Zirczy Helena , Hwang Yong Keun , Gelinsky Stephan 
Published: March 2018

Abstract
Field development costs continue to face tremendous downward pressure. Value preservation in a lowprice environment requires optimum placement of a minimum number of development wells that safely produce the maximum possible amount hydrocarbon resources. To achieve this ambitious goal, all relevant data need to be integrated earlier and faster to provide a solid basis for a realistic base case reservoir model to underpin the field development plan and to sketch out low and high case scenarios to ensure plan robustness and capture possible upside.
Experience with Chemical Sand Consolidation: Case Studies from West Africa
Authors: Kumar Pankaj , Affeld C. J. 
Published: March 2018

Abstract
This paper presents experiences gained from several Chemical sand consolidation treatments performed in one of the field in West Africa. Success rate was 60% and there were learnings from failures. Case studies for several wells are provided to highlight the key aspect and learnings which are essential to improve the chances of any sand consolidation treatment.
Chemical Sand consolidation (SCON) treatment provides in situ sand influx control by treating the incompetent formation around the wellbore itself. The treatment consists of injecting the immediate near wellbore area of the reservoir with a fluid containing an adhesive or epoxy resins, which increases the strength of the formation without significant loss of permeability. The ideal sand consolidation system provides the highest possible resistance to sand production at the lowest impairment. However, there are many factors which generally not thought of could lead to potential job failure. Several SCON treatments have been done in the field. Of the total number of jobs conducted over time, there were some failures reported as well therefore a detailed after action review was conducted which highlighted some important factors responsible for failure. The factors responsible for the failure of these wells were found non-associated with each other. Key areas like candidate selection, well preparation prior to SCON treatment, design and modeling, SCON chemical validation and testing, job execution, well start-up post treatment were looked into details to summarize the findings. For successful SCON treatment, well preparation is very important. Well preparation conveyance method is typically coil tubing unit, bullheading or workover. Especially well preparation via either means requires extra considerations therefore some important learning will also be discussed apart from SCON treatment aspect.
The findings and learnings from these jobs were incorporated into future campaigns to maximize the success. Sand consolidation proved to be a successful means to add production gains in a low cost environment.
Analysis of a Fixed Yaw Weathervane Offshore Wind Turbine Having Single Point Mooring
Authors: Nathanial C. W. , Vijay K. G. , Sarkar A. 
Published: March 2018

Abstract
In the recent years, offshore wind energy has gained much importance owing to its viability and technical advances in the performance predictions. The thirst for steady energy supply from wind has pushed the wind turbine industry to offshore waters requiring floaters as the only possible and feasible solution. The floater along with wind turbine sets up the basis for any offshore floating wind turbines. The costs and the complexity involved in yaw mechanism are very high. To tackle this issue, a weathervane wind turbine system is proposed to eliminate the use of turbine yaw mechanism. In the concept of weathervane wind turbines, the floating wind turbine is connected to a single point mooring (SPM) about which it weathervanes. To better understand and to make practical decisions in real scenarios, performance analysis is carried out for a weathervane wind turbine system of a semisubmersible type. For present study, NREL 1.5 MW wind turbine is chosen as it is readily available and is widely preferred for preliminary studies. The numerical simulations are carried out using effective coupling of FAST code with OrcaFlex. The responses of the floating wind turbine systems not only depend on the floater but also on the coupled motions of wind turbine with SPM subjected to turbulence wind loadings. This non-linear coupling is analyzed in the time domain combining the effects of floater hydrodynamics, wind turbine system and mooring system. Numerical results along with discussions are presented. This preliminary global performance analysis gives a vision on its capability to better suit offshore, meeting the global standards.
Fracturing Methane Hydrate in Sand: A Review of the Current Status
Authors: Too Jun Lin , Cheng Arthur , Linga Praveen 
Published: March 2018

AbstractNatural occurring methane hydrate (MH) is found abundantly in sediments and rocks under stable thermodynamic conditions. The majority of this resource is located under the permafrost layer and in the shallow depths of the seafloor in the deepwater regions. Over the past two decades, a variety of efforts were dedicated in laboratory researches and field production tests using different methods to examine the best production strategy that is economically viable for commercialization. In order to produce gas, the solid methane hydrate in pores of sediment or rock will need to be dissociated either by reducing the pore pressure, increasing the temperature, injection of inhibitors, or undergo gas exchange using carbon dioxide. It is possible to have a combination of these options in the gas production. Currently, the depressurization method is deemed the most efficient way to produce gas.The key controlling factor in dissociating, exchanging or producing gas from methane hydrate is the flow conductivity through the pores of the hydrate-bearing layer. Larger contact exposure area between solid methane hydrate to the fluid pore pressure enables more dissociation to occur using the methods above. In this aspect, the creation of artificial fracture in hydrate-bearing layers is thought to promote a better dissociation process. This idea has surfaced with numerous efforts from the research community to explore its feasibility. There are multiple technical challenges and uncertainties to address if methane hydrate in sand can be fractured artificially. These challenges and the recent progressions in identifying/determining its fracture properties are discussed with some future considerations required to move towards the prospect of introducing artificial fractures for gas production purposes.
Valuable Improvements of Data Preparation and Controlling Operational Regime Practices at Mature Field as A Basic Part of a Smart Field Concept Usage Case Study
Authors: Kyrnaev D. , Fomin V. , Maslanov A. , Karpov V. , Amirov A. , Sleptsov D. , Batilov I. , Ratanov K. , Kozhin A. , Klemba A. , Rybalko A. , Guletzskiy M. 
Published: March 2018

Abstract
In introduction, will be given the short history of maturity field from 1976 year, main challenges, road map of implementing Smart Field (SF), current raediness. The main difficulties of implementing SF are depended on two factors: 1) Accuracy of tuning the components of integrated asset model-reservoir, wells and gathering networks by utilizing real-time data from SCADA systems, 2) Accuracy of execution the plan of injection and production at a field by field staff, subcontractors.
This paper is focused on the two very crucial workflows which are helped to connect the integrated asset model with reality and increase helpful of usage model based approach: 1) real-time data preparation for executing the well model matching procedure and 2) maintaining operational regime for production and injection wells which is calculated by integrated asset model. Each workflow is organized as a sequence of steps which can be executed manually especially for the very complex well behavior or in an automated mode in simple case.
The novelty of that experience includes the usage schemes and principals for mentioned routines: 1) special order of preparing data for further matching procedure of well/net/reservoir models, and readiness additional sets of transient data for further interpretation procedures 2) controlling execution process of maintaining the operational parameters at a field, generating some complex indicators show what to need to adjust models, measurement devices or submersible equipments.
Lessons Learnt in Executing Human Factors Engineering in FLNG Projects
Authors: Chandrasegaran D. , Al Sharifi H. , Mohd Noor M. H. , Abdullah M. K. 
Published: March 2018

Abstract
Human Factor Engineering (HFE) addresses interactions in the work environment between people, a facility and its management. FLNG projects bring new HFE challenges with more equipment items that are often larger and often more sophisticated than previously deployed offshore. Deployment of HFE is most cost efficient when started in the early design stages. Timely application of HFE can bring many benefits such as:Designing to allow operation and maintenance throughout the facility’s life considering every single task requiring handling of mechanical components and verification of the FLNG operation and maintenance teams’ resources.Holistic material handling system designBetter construction planning
This paper will present the findings and lessons learned from engineering and construction of recent offshore LNG facilities by TechnipFMC. The perspective of operation and maintenance teams is considered in the HFE process to ensure that experiences and needs are incorporated in the new design. The findings and lessons learned are summarized under keywords for further discussion and recommendation.
Codes, standards and guidelines that are relevant to HFE and material handling are discussed to establish if there is adequate coverage of the requirements for the design, construction and operation of FLNG. Although the discussions of human factors are based on case studies from offshore facilities such as FLNG and large gas processing platforms, the observations and recommendations could be extended to other types of oil and gas facilities.
Predicting Hydrate Blockage Formation in Gas-Dominant Systems
Authors: Charlton Thomas B. , Zerpa Luis E. , Koh Carolyn A. , May Eric F. , Aman Zach M. 
Published: March 2018

Abstract
We present the development of a new model to predict hydrate growth and transport in gas-dominant systems, based on experimental observations of hydrate film growth and particle deposition. Incorporated as a user-defined plugin in a transient flow simulator, we present predictions of hydrate blockage formation using this tool for three of eight Tommeliten field trials: (i) depressurized restart; (ii) thermodynamic inhibitor injection failure and; (iii) pressurized restart. Deposition plays a key role in these predictions, and the new model predicts significant hydrate stenosis occurring in the same timescale as blockage formation in the field trials. The mechanism of sloughing, a key precursor to the formation of hydrate plugs, is not incorporated in a transient simulation environment. However, shear stress predictions as a deposit develops may exceed the threshold previously reported in literature to generate a sloughing event. This represents a key way forward in the development of a comprehensive hydrate prediction tool for oil and gas flowlines.
Optimisation of a Wet Insulation Coating for Shallow-Water Pipelines
Authors: Rattenbury P. D. , Grodziski L. 
Published: March 2018

Abstract
Conventional technologies used for insulation of flowlines in shallow-water fields, based on thermoplastic foams, are over-specified for the conditions. This has driven development of a low-cost alternative based on a low-density polyurethane thermoset foam.
This paper will trace the methodology of an active collaboration between Logstor and TechnipFMC to develop and optimize this alternative coating. It will show the evolution of the developments and progress made over the last two years.
The coating resembles a pipe-in-pipe system, however the outer steel pipe is replaced with a polyolefin casing. The coating is designed with a tapered end chamfer so that the casing meets the anti-corrosion coating at the pipe ends. Seals here compartmentalize the coating, making the coating on each pipe individually watertight and make the coating compatible with conventional field joint coatings.
The development process has been based on critical examination of the pre-existing insulation coating, using FMEA and study of previous project experience, combined with trial manufacture and full-scale testing to simulate all stages of the life-cycle of the coating. Using this approach, it was possible to closely characterize both the manufacturing process and the coating system itself, which in turn enabled the investigators to identify and reduce inefficiencies in the coating design and also identify other areas where improvements would increase reliability.
The insulation coating system described in this paper is an alternative to conventional multilayer polypropylene wet insulation technologies for pipelines situated in shallow water with several key advantages that may be of use to the specifying engineer or designer when designing a flowline that requires insulation.
Awakening A Sleeping Dragon - Semi Submersible Tender Assist Rig Start Up
Authors: Wong J. , Wong K. , Yeap F. 
Published: March 2018

Abstract
The rig start-up process that was used for the semi submersible tender assist rig was successful in mitigating schedule and cost risks associated with readiness of the rig and the complex interface with other contractors located around the world. The Malaysian team successfully delivered the rig start up from 1 year cold stack mode change of ownership, turned around the rig into a fully functional one, on cost, schedule and incident free.
It was an extremely challenging timeline from contract award to securing rig modification, interface upgrades and equipment delivery to meet the operators’ "First Oil" date. Multiple stakeholders were engaged to identify & build up a credible rig start action plan to deliver the required upgrades, reactivation and repairs in a timely manner. A technical queries process was used to manage the information exchange, captured decision and way forward. The successful rig start-up required Integrating new team members from various parties onshore & offshore integration, and familiarised the team with operators’ ways of working on safety including managing parties with limited rig start-up experience. The process needed an intensive interface management with multiple organizations within country and outside.
The rig start-up was successfully completion on schedule, below planned budget and most importantly safely. The modification was aimed at allowing a coupled body action between the semi sub tender assisted rig and tension leg platform, allowing for drilling, completion, hook up and commissioning and production to be carried out simultaneously. Ultimately it allowed for a safe and efficient well delivery campaign and meeting the production targets from a new facility.
With the action plan in place, the operator and contractor successfully closed out on audit findings & action items (&gt; 1700 audit actions) from various aspects of HSE Technical safety, Rig Startup Audits, Marine, Aviation, Lifting & Hoisting, Health, Dropped Objects Prevention Scheme (DROPS), 3rd party commissioning & project interfaces to sail away from shipyard on time. A structured systems integration test was carried out in shipyard to qualify and commissioning new and existing drilling rig systems. Well control systems were also confirmed functional and a blowout preventer shear test was carried out using the original equipment manufacturer (OEM) and operator guidelines.
Once the rig was sailed to location and set up alongside the tension leg platform, the remainder of the systems integration test was completed on site. The result of this was a flawless startup and transition into drilling and completion operations with minimal downtime to the operator and rig contractor.
Pragmatic and Consistent Approach to Life Extension of Floating Structures
Authors: Morandini Cedric , Floury Jerome 
Published: March 2018

Abstract
Life extension of offshore assets is a popular and hot topic as Operators are willing to maximize the operation of their platforms in order to increase their economical returns while maintaining satisfactory level of safety and integrity of their asset.
The paper will propose a pragmatic, fit for purpose and consistent approach in establishing the baselines for life extension of any type of floating structures: FSO, FPSO, FSRU, FSU, FLNG and FPU.
What will be covered by the proposed approach are as follow:Hull structure as a whole,Critical hull structure detailsMain marine systems including cargo, boiler, steam, seawater and freshwater systemsMooring system as a whole including anchoring system, mooring hardware, turret mechanical and structural components.
The proposed methodology will cover the overall Life Extension process in several steps with toll gate at the end of each step in order to facilitate and streamline the decision process.
The first steps are rather easy to be implemented and are mainly based on desktop studies with the review of the various reports supporting and detailing the design of the specific floating structure. They will be complemented by review of existing inspection reports covering the main systems as detailed above, and may trigger additional inspection campaigns and systems testing to enable proper understanding of their conditions.
In addition the benefits in using proper and efficient Asset Integrity Management Systems from day one to support the overall integrity of the floating structure while enabling Life extension plan will be highlighted and discussed.
Such approach will be based on experiences gained throughout several life extension projects conducted by Bureau Veritas for various floating structures operating in different modes and located in various environmental sites.
Transient Fully Coupled Hydrodynamic-Hydrate Model for Deepwater Kick Simulation
Authors: Sun Xiaohui , Sun Baojiang , Gao Yonghai , Wang Zhiyuan , Liao Youqiang , Yu Xiaodong 
Published: March 2018

Abstract
A new kick simulator that incorporates a fully coupled hydrodynamic-hydrate model to describe the interaction of hydrate growth characteristics and wellbore multiphase flow behaviors, has been developed considering the unsteady multiphase mass transfer process. In this study, a series of numerical experiments are conducted to analyze the kick development process with various reservoir properties and construction parameters. Furthermore, a close discussion shows that gas dissolution and hydrate formation can significantly suppress the kick development process, especially at a low influx rate. Because the hydrate growth characteristics lead to the kick gas converting from vapor state to solid hydrate phase and then back to vapor state. Compared to vertical drilling, the kick development rate in horizontal drilling is considerably slower. Last, a special kick process that can be "hidden" and "abrupt" successively, is demonstrated in deepwater extended reach drilling.