bluuebunny/crossref_metadata_2025_split huggingface dataset:
An ANN-Based Model to Artificially Transform a Floating Vessel into a Wave Monitoring Buoy
Authors: Sidarta Djoni Eka , Tcherniguin Nicolas , Tan Jaime HuiChoo , Teng YihJeng 
Published: November 2020

Abstract
Floating platform offshore operations, such as load transfer from a supply boat and hydrocarbon offloading operations, are often limited by sea conditions. Access to sea condition information from a nearby wave/environmental monitoring buoy is not always available or there may be delays in data transmission. In the absence of reliable and accurate data from a nearby wave buoy, the motions of a floating platform/vessel may be used to estimate the sea conditions.
This paper presents a method in using Artificial Neural Network (ANN) models to map the motions of a floating vessel to the wave elevations and to eventually estimate the significant wave heights of the sea the floating vessel is in. The ANN models can be trained using either: (1) measured data in the form of measured vessel motions and data from a nearby wave buoy, or (2) simulated data, i.e. vessel motions computed using numerical simulations. In this paper, demonstration of the ANN method uses simulated data under various sea conditions.
The trained ANN models are tested for sea conditions that are not part of the training data, and the ANN predictions are found to be very close to the results calculated using numerical simulations. This is an important step to show that the trained ANN models have learned the presented information and can generalize the knowledge. The methodology presented in this paper may be used to establish an ANN model for estimation of the significant wave heights based on the measured motions of a floating vessel.
Avoidance of Leak/Rupture through Implementation of Digital Integrated Pipeline Integrity Assurance System i-PIMS
Authors: Mat Tuselim Ahmad Sirwan , Mohd Ali Napiah Mohd Nazmi , Abu Bakar Mohd Hisham 
Published: November 2020

Abstract
In PETRONAS, there are on-going initiatives at petrochemical plants, gas processing plants, Upstream's well engineering and retail business in pursuing the digitilisation in line with the Industrial Revolution (IR) 4. The aim of the initiatives is basically to improve the efficiency of critical processes thus at the end will reduce overall cost and improve production margin and revenue/profitability.
This paper will present the initiative of PETRONAS' Pipeline fraternity consisting of pipeline experts, managers and engineers in the development of intelligent and integrated pipeline integrity management system. The system is designed to have minimal people intervention as data will be automatically uploaded by Inspection & Maintenance (I & M) vendors and field technicians through interface software and utilising artificial intelligence/ machine learning for descriptive, predictive and prescriptive analytics. It is envisaged that by having the system, critical decision-making pertaining to integrity, safety and reliability of pipeline system could be done in ‘split seconds’ extending the asset's life and eliminating unwanted incidents i.e. leak/rupture.
Furthermore, standardisation of pipeline risk and integrity software/tools among Operating PETRONAS Units (OPU)/regions will provide cost savings in the long term compared to current practice of having off-the-shelf software/tools. Integration of relevant corporate software/tools and the intended software/ tools will further provide cost savings in terms of database management and enhanced efficiency.
There are few other initiatives running in parallel with the i-PIMS i.e. using advanced acoustic emission technology to detect corrosion anomalies using new developed sensors and also establishing algorithms/analytics for corrosion's growth, location and position throughout pipeline length; formation of dynamic free spanning for offshore pipeline; and predicting/monitoring 3rd party impact occurrence.
Development of pipeline predictive analytics is to gain significant improvement in PIMS for better integrity status verification, faster decision making and optimization for I&M activities. The overall outcome/results/algorithms will be integrated into i-PIMS as part of final assessment.
It is PETRONAS' aspiration that eventually, descriptive analytic of i-PIMS i.e. critical pipeline integrity performance indicators and critical processes can eventually able to be accessed via mobile apps which will be a ‘pace-setter’ in overall pipeline integrity management scheme i.e. ‘effectively managing pipeline at fingertips’.
The Effect of Mercury to Carbon Steel in CO2 and H2S Environment
Authors: Jaafar Rohana , Mohammed Nor Azmi , M Surday Amir Sharifudin , Ahmad Rusli Ahmad Mustaza , Rikan Noor Laila , Md Aris Noraina Suyanti , Suhor M. Firdaus , Abas Ahmad Zaki , Hasan M. Hawari 
Published: November 2020

Abstract

Objectives/Scope
This paper is about a study on the impact(s) of elemental and ionic mercury (Hg) to carbon steel corrosion in sweet and sour environments with and without Corrosion Inhibitor(CI) injection.

Methods, Procedures, Process
Evaluation on the effect of Hg deposition and the corrosion behavior via Corrosion rate using Linear Polarization Resistance (LPR), solution properties, surface profile and corrosion product analysis are performed. Low pressure bubble test and autoclaves test are conducted under multiple variables to study the corrosion rate behavior. Fluid Analysis is performed using ICP-OES and XRD to analyse the chemical reaction of the fluid. Surface analysis is conducted using Visual inspection and XRF.

Results, Observations, Conclusions
The bubble test analysis shows that elemental and ionic Hg does not affect the corrosion rates under CO2 environment. Likewise, in H2S-containing environment, elemental Hg do not effect H2S corrosion evidence by the low pre-corroding corrosion rate. However, ionic Hg is observed to influence H2S corrosion where higher corrosion rate is measured. This is potentially due to the reaction between ionic Hg and H2S lead to the formation of HgS, depriving carbon steel inhibitive effect by H2S. The addition of Corrosion Inhibitors is observed does not reduce the corrosion rate probably due to the reaction between the ionic Hg and the sulphide element from the CI resulted into decreasing of filming tendency. HPRCE Autoclave result shows that CI had successfully reduce the corrosion rate to the targeted corrosion rate provided higher CI injection dosing is introduced.Significant HgS spectrum observed during XRD analysis reflecting ionic Hg mighthave reacted with H2S and CI. This supported that the presence of ionic Hg might have interfered the inhibitive mechanism of the CI and delayed the formation of passive layer on the metal. ICP-OES and XRF indicated Hg traces potentially due to high reaction rate between ionic Hg and injected CI thus accelerated the formation of HgS.

Novel/Additive Information
CI formulation without any sulphide composition should be used if ionic Hg is present in order to ensure the CI effectiveness and it consumption during operation. In the event where the CI formulation cannot be changed, an enhanced pre-qualification evaluation as conducted in this study is to be carried out if ionic Hg is detected in the system to ensure the CI is effective and compatible to be injected.
Numerical Well Testing Interpretation Method and Application Under Interference from Adjacent Well in Polymer Flooding Reservoir
Authors: Kang Xiaodong , Zeng Yang , Zhang Jian , Tang Engao , Cheng Shiqing 
Published: November 2020

Abstract
The offshore polymer flooding reservoirs are mostly in the middle and late stages of oilfield development, and there are multi-well systems. At present, most of the well testing methods for polymer flooding reservoirs are based on single well system, which leads to the fact that the actual data fitting effect is not ideal. By considering the influence of adjacent production well or polymer injection well and the physical and chemical effects of polymer solution such as shear, diffusion and convection, the well test interpretation method of polymer injection well considering adjacent well interference is established, type curves were plotted and its influencing factors were discussed by the numerical inversion method. The result showed that the type curves have five regimes, the pressure derivative curves show obvious upward warping under interference from production well, while the pressure derivative curves first decrease and then continue to rise under interference from polymer injection wells. Polymer injection well test curves show obvious non-Newtonian fluid characteristics when considering adjacent well interference, and can not be analyzed by conventional adjacent well interference test method. The example application proves the correctness and reliability of this method, which provides a theoretical basis for dynamic adjustment of polymer flooding reservoir.
Customer and Design Engineer Interaction Process Enhances Drilling Efficiency for the Operator in Offshore Malaysia
Authors: Mohamed Sabri , Che Ismail Mohd Hauzi , Nordin Mohd Haikal , Mohd Affandi Abd Razak , Mohd Zurhan Mohd Syahmi 
Published: November 2020

Abstract
In general, the formation in offshore East Malaysia is more challenging than the formation in offshore West Malaysia. One reason is primarily because of the highly interbedded soft and hard formation throughout the well. What is even more challenging is the nature of polycrystalline diamond compact (PDC) cutters, which are prone to breakingbecause of the impact from those highly interbedded formations.
Field T is a fieldwithin the area that is well known for using a significant amount of drill bits to drill a well. Most PDC bits exhibited bad dulls and cutting structure conditions, particularly in the shoulder area. Broken and chipped cutters have resulted in the bits being pulled out of hole prematurely, unable to continue drilling to well total depth (TD). In the early days during the exploration phase, the PDC bits used in this field ended up mostly with ring out (RO) dulls regardless of the number of blades being used.
This bad dull condition improved significantly during Phase 1A development drilling in Field T compared to drilling during exploration. However, it has being recognized that further improvements could still be made during Phase 1B development drilling in terms of rate of penetration (ROP) without compromising bit durability.
To address the challenge, the approach should be a different bit design modifications rather than just a taking an off-the-shelf bit.Collaboration between the drilling project team and drill bit design engineers began months before the project was scheduled to start. This began the continuous interaction process between both parties to enhance drilling efficiency for the operator.
After several meetings, discussions and presentations, the drilling project team and drill bit design engineers developed the optimum bit design solution for this application. Several design iterations were performed to obtain the most efficient cutting structure layout before finalizing and manufacturing the bit specifically designed for this field T.
As a result, the entire 8.5 inch section was drilled using one specifically designed bit with an outstanding rate of penetration improvement, which was the objective of the 8.5 inch holesection. The successful result reflects a great team effort attained by thorough planning and execution process by both drilling project team and drill bit design engineers.
Geohazard-Seismic: Gas Cloud Characterization Through Seismic Attributes
Authors: Hasni Norazif Anuar , Shahman Nur Shafiqah , Talib Jasmi Ab , Ghosh Deva Prasad 
Published: November 2020

Abstract
In general, offshore geohazards consist of variety in geological features that contribute potential risks to human health, safety and the environment due to consequences of long or short period of geological processes. A geohazard can be defined as a geological state that may lead to widespread damage or risk. Geohazards are geological and environmental factors and involve long-term or short- term geological processes. Geohazards may have relatively small features, but they can also spread out to huge dimension so as to affect local and regional socio-economy to a large extent (Wikipedia, 2019). From the viewpoint of the oil and gas industry, geohazards mean either geological processes or factors to cause such processes that may provoke damage to the industry to risk human health, safety and the environment no matter where they are caused. Geohazards could also risk the suspension of the oil and gas production for a certain period of time. There are many type of geohazards related to offshore oil and gas developments such as "mud diapirs and volcanoes", "fault ruptures", "shallow gas", "seabed gas hydrates", "debris flow run out", "unstable slopes", "landslides", "pockmarks", "liquefaction", "turbidity current and rock outcrops" and "Methane-Derived Authigenic Carbonate (MDAC)". The geohazards can occur in the form of combination between various types of geohazards. It may cause huge damage and complicated problem to be solved. Each geohazards type has different problems solving due to different period of occurrence in geological processes. Generally, this paper will explain about the identification of gas cloud by applying several seismic attributes on specific parameter.
A Systematic Approach to Deploy a Novel Nondamaging Fracturing Fluid to Field
Authors: Karadkar Prasad , Alabdrabalnabi Mohammed , Liang Feng , Buenrostro Adrian 
Published: November 2020

Abstract
Guar gum and its derivatives based fracturing fluids are most commonly used in hydraulic fracturing. For high temperature wells, guar-based fracturing fluids need to be formulated with higher polymer loading and at a high pH that leaves insoluble residue and tendency to form scales with divalent ions. In this paper, a systematic approach to field deploy a novel low-polymer loading, nondamaging acrylamide basedfracturing fluid system is presented.
Thermally stable acrylamide-based polymer with reduced polymer loading of 30-40% less than guar-based fracturing fluid was considered to minimize formation damage concerns. For successful field deployment, a novel nondamaging fracturing fluid was evaluated in following sequence: chemical management and quality control, optimization of fracturing fluid formulations with field water, field mixing procedure, onsite QA/QC, friction analysis, leakoff analysis, data frac analysis and execution of main fracturing treatment. In both scenarios, batch mixing and on-the-fly mixing of linear gel were evaluated. The friction of crosslinked fluid was analyzed by using bottomhole gauge and fluid efficiency was evaluated during data frac analysis.
This paper presents rheological studies at bottomhole static temperature (BHST) and cool down temperatures of selected well candidates that demonstrate superior thermal stability of this novel fracturing fluid. With polymer loading of 25 lb/1000 gal, the fluid viscosity stayed above 300 cP at 100 1/s shear rate for 2 hours at 290°F. The fracturing fluid formulations were optimized using both live and encapsulated breakers with high pressure and high temperature (HPHT) rheometer. Due to the fast hydration of the base polymer, the linear gel was mixed both in batches and on-the-flying during the main fracturing treatment. Slightly higher friction at higher pumping rate was observed by the down hole gauge during data frac for this novel fracturing fluid as compared to guar-based fracturing fluid. The main fracturing treatment was successfully executed with 45-50 barrels per minute (bbl/min) pumping rate with increased proppant concentration up to 5 pounds per gallon (ppa) using 30/50 high strength proppant (HSP) proppant.
The fracturing fluid system based on the novel acrylamide copolymer offers advantages over guar-based fracturing fluid such as low polymer loading, excellent high temperature stability and less formation damage. This paper presents a systematic approach and lesson learnt during novel fracturing fluid deployment.
A Case Study on the Largest Exploration Survey in Asia: Unlocking the Hydrocarbon Potential of Frontier Areas, Offshore Sabah, Malaysia
Authors: Chakraborty Rupam , Tham Michelle , Sazykin Artem , Menzel-Jones Gavin , Miller Paul , Tu Ching , Barlass David , Adelman Natalie 
Published: November 2020

Abstract
Deep-water (1000 m+) Sabah, Malaysia, is a frontier exploration province proximal to successful exploration trends within the Sabah thrusts zone and Luconia carbonate shelf. The basin is on trend with numerous proven petroleum systems; however, it remains underexplored with minimal drilling activities targeting the deep-water hydrocarbon plays. The need to build reliable regional interpretation over large prospective areas led to a broadband multimeasurement towed-streamer acquisition over 19,500 km2 in offshore Sabah. In this work, we illustrate an integrated workflow that incorporates contemporary broadband processing, interpretation-guided earth model building, and multiphysics input to interpretation to generate a high-resolution seismic image that will accelerate exploration in the region.
Experimental Study on Enhanced Shale Gas Recovery by Competitive Adsorption of CO2-CH4 Under High-Temperature, High-Pressure Conditions
Authors: Wang Jinjie , Ng Qi Hua , Lau Hon Chung , Stubbs Ludger Paul 
Published: November 2020

Abstract
Experiments were carried out to study the effectiveness of CO2 injection to enhance the recovery of CH4 in a shale core sample. Two types of experiments were performed. The first was the adsorption isotherm of CH4 on the core at 30°C. The second was a series of coreflooding experiments where the core was initially saturated with CH4 at 30°C and 100 bar. CH4 recovery by depressurization to 80 bar and that by N2 or CO2 injection to 140 bar followed by depressurization to 80 bar were compared. Results showed that depressurization alone gave a recovery factor of 27%. However, N2 injection followed by depressurization gave an additional 17% in CH4 recovery due to reduction in partial pressure of CH4 during depressurization. CO2 injection followed by depressurization gave a further 4% in CH4 recovery compared to N2 injection followed by depressurization due to competitive adsorption of CO2-CH4. However, the CH4 recovery due to competitive adsorption would have been significantly higher had the dead volume in the apparatus been eliminated. Our experiments suggest that CO2 injection followed by depressurization may be an effective enhanced gas recovery method for shale reservoirs due to the combined effect of partial pressure reduction and competitive adsorption. Therefore, more research in this area is warranted.
Application of Thixotropic Cement Slurry to Cure Losses in Depleted Zones in Coal Seam Gas Wells
Authors: Zaman Mohammad , Shaban Alex , Iyer Venkat , Wuthayavanich Ekkalak , Saunders Troy 
Published: November 2020

Abstract
Complete to intermittent dynamic losses during drilling operations in the Early Permian reservoirs of the Bowen Basin are common because of depleted zones, particularly in the Bandana Coal Measures. The losses encountered while attempting to drill to total depth (TD) result in notable setbacks in time, remediation costs, and zonal isolation integrity. Operators have access to a large portfolio of loss circulation (LC) treatments depending on the loss type, rate, and nature of losses. This paper presents a low-solids, highly thixotropic (LSHT) cement system that can help cure losses without incurring costly nonproductive time (NPT).
During the recent Springwater campaign, which consisted of 12 wells targeting the Cattle Creek Coal Measures, three of the wells experienced significant to total losses. A number of conventional lost circulation materials (LCMs), including particulate materials, reticulated foams, and fibers, were unsuccessful in curing the losses. As an alternative to a conventional LC cement plug, an LSHT cement system was deployed.
The low-solids content and avoidance of any traditional LCMsenable the LSHT system to be pumped through the bottomhole assembly (BHA), which allows for continued drilling. The LSHT cement system is shear-rate dependent, yielding to thin rheologies on application of shear to easily penetrate into the loss zone. When shear is reduced, the slurry gels rapidly to arrest the rate of flow. Additionally, the quick early compressive strength development at shallow depths allows operations to continue without incurring significant loss of operating hours. The solutions provided were pumped through open-ended pipe in one case and through the BHA with a drilling bit in another; both performed in the same manner without hampering equipment capability.
Successful application of the LSHT cement technology helps minimize time lost using conventional cement plugs because the LSHT cement can be pumped through the BHA, saving time associated with tripping in and out of the hole to change the BHA. Additionally, the system's early compressive strength development yields time savings, along with savings in otherwise lost fluids, and achieves drilling efficiencies to help manage drilling operations costs.
Offshore Renewable Power to Hydrogen Provides a New Technical Solution for the Utilization of Offshore CO2-Rich Natural Gas
Authors: Song Pengfei , Shan Tongwen , Hou Jianguo , Chang Le , Li Youwu , Wang Xiulin 
Published: November 2020

Abstract
China now is the largest natural gas importer in the world, with the dependency on foreign countries has reached to 45.3%.On the other hand, China has a huge amount of natural gas resources in the South China Sea to be developed, but most of them are CO2-rich gas which contains 15%~80% CO2 located in the deep sea. How to develop these valuable offshore gas resources economically, efficiently, sustainably and environmental friendly, without causing greenhouse gas emission, has always been one of the biggest challenges in the offshore petroleum industry.
Power-to-Hydrogen (PTH) from offshore renewables and CO2 methanation are expected to provide a new technical solution for the utilization of offshore CO2-rich gas. This method can improve the composition of CH4 to meet the requirements of economic pipeline transportation, and even the requirements of liquefaction to LNG.
However, this technology is still under development. Regardless of the technology itself, the bottleneck exists in the balance between the costs of hydrogen and natural gas production and the economy condition for the whole life cycle of gas field development. But this technology still has the potential to provide a new solution for the development of CO2-rich natural gas resources. It is preliminary estimated that when the costs of offshore power are less than ¥0.3 / kWh, the project can be commercialized.
Big Data and Machine Learning: Effective Tools for Ensuring Well Integrity
Authors: Savini Marcus Blane , Domec Brennan Scott 
Published: November 2020

Abstract
The application of big data analytics, artificial intelligence, and machine learning to solving challenging problems is ever-increasing in the oil and gas industry. These techniques have already been proven to be powerful tools that can not only improve safety and reliability but can also provide more consistent and accurate decision-making capabilities as compared to conventional methods. This paper will detail a real-world application of big data analytics and machine learning to the tubular connection make-up process, realizing significant benefits over traditional human-evaluated methods. While the focus of the paper will be on a single application, similar approaches may be beneficial to other applications and other industries, achieving similar benefits.