bluuebunny/crossref_metadata_2025_split huggingface dataset:
Risk Based Determination of Pipeline Safety System Using Quantitative Pipeline Risk Assessment Approach
Authors: Mohd Ali Napiah Mohd Nazmi , Morad Halimi B , M Rashid M Nizam , Abdullah Nur Asiah , Idris Naila Rusma 
Published: November 2020

Abstract
Pipeline Leak Detection System (PLDS) is a hardware and/or software-based monitoring tools that is utilized to indicate a leak or hydrocarbon release along the pipeline. However, it is noted that most pipelines are not equipped with PLDS as risks associated with the pipeline are mitigated by other means or deemed low. Another issue is that the current leak detection technology is not a full proof system i.e. it may still be giving false leak alarms or inaccuracies in the leak location.
PETRONAS Procedures and Guidelines for Upstream Activities (PPGUA) calls for installation of Subsea Safety Isolation Valve (SSIV) for protection and risk mitigation measures to the new pipeline installed, particularly for gas pipelines or where pipelines are connected into major trunk pipeline systems with large connected inventories. A justification shall be provided if SSIV are not installed.
A risk assessment study and cost benefit analysis should be performed to justify the use of PLDS and installation of SSIV. High risk pipelines such as those transporting volatile, corrosive, flammable or toxic fluids in significant volume in high consequence areas may benefit from the use of PLDS and SSIV in limiting the inventory leaked to the environment and the resulting consequence.
PETRONAS Technical Standard (PTS) specifies that the requirement for PLDS and SSIV for new pipelines is to be determined via a semi-quantitative Risk Assessment or a fully Quantitative Risk Assessment (QRA).
Tender Assisted Drilling: A World First Approach to Reactivate an Idle Platform Rig in Deepwater Angola
Authors: Le Guen Jean-Christophe 
Published: November 2020

Abstract
The objective of this paper is to present the novel approach that the drilling contractor implemented for an operator in West Africa confronted with significant reactivation/recertification costs for one of its idle integrated platform rig.
The drilling contractor proposed to couple the platform rig to one of their existing tender vessel, that is usually used to assist its own drilling rig, creating the first ever hybrid platform rig assisted by a tender vessel. The tender vessel was mobilized alongside the platform during the reactivation phase, offering ample POB capacity and avoiding the hiring of accommodation vessel, then the power and fluid system were hooked up to platform equipments that were to be used.
This approach avoided the refurbishment/overhaul/recertification of the main and emergengy engine, the mud pumps and the mud pits and all the auxiliary systems that support the rig equipement. For the operator' s eighteen month workover and drilling campaign, the drilling contractor also proposed a cost-effective approach, looking into their available capital equipment inventory for compatible equipment still under certification. Once identified, the equipment were simply swapped so no additional recertification cost was required.
The drilling contractor took the opportunity of this major reactivation to review completely the working flow of the rig and proposed a new offline pipe handling system and upgrade the online one, to improve the rig overall performance compare to the original design.
All these novel approaches are reducing the overall project cost by 20% compare to a refurbishment of existing rig by OEM and introduce the offline pipe handling bringing an additional minimum 5% of operation time saving, making the project viable.
The use of a tender vessel along a platform, feeding the platform rig equipment with power and fluids to extend the platform life is a novel approach in the industry that offer significant cost saving for operator suffering prohibitive reactivation/recertification costs of an idle fixed platform rig or any operator looking to reduce equipment weight on aging platforms. This paper will describe the major modifications that were required to make this world first attempt a success.
Advances in Applying Continuous Pack-off Inflow Control Device for a Water and Sand Control Reservoir in South China Sea
Authors: Xiong Shuquan , Li Fan , Cheng Chuchuan , Wu Sijia , Pei Bailin , Dai Chaoyong 
Published: November 2020

Abstract
The production in oilfield "A" in South China Sea is reducing dramatically, with known fine-grain migration into the near-wellbore area. The heavy oil inunconsolidated sandstone is water drive reservoir. It featured high content of clay (&gt;10%). Gravel packing and screen are used to prevent the sand production.Oil recovery is low due to the water-break through (WBT) in this field.
Continuous Pack-off Inflow Control Devices (CPI) is a proprietary water controltechnique including two operational steps: first run ICD strings,and theninject special designed proppants into the wellbore annulus. The results show this technique iscost-effective, and reliable oil recovery method.
This paper presents a method of using ICD and CPI particles to maximize oil recovery in sandstones.Compared with other water control methods, the CPI advanced them by delaying/reducing water invasion. The case stuy in the well showntheproductionis stablein 12 months without sanding issue. wellswith ICD andswellable packers often lost production because of the accumulation of the fine- grain and plugging around the screens. The wellwith gravel packing reached water cut of 70 % at a cumulative oil of 6000 cubic meters whilethe well with CPI technique shown water cut of 10 %when produced 6000 cubic meters oil.
Integrate Surface Facilities with Reservoir Resources to Make the Small Offshore Oil Field Fruitful
Authors: Su Yanchun , Shi Hongfu , He Yifan 
Published: November 2020

Abstract
Marginal oilfields refer to the development of oilfields with insufficient economic benefits by conventional methods under current economic conditions due to objective reasons (geological reserves, geographical location, development technology, engineering investment and taxation, etc.). In China, after nearly 30 years of large-scale offshore oil exploration and development, a large number of high-quality large and medium oilfields have been proven in offshore areas such as the Bohai Bay, South China Sea, and East China Sea. With the deepening of exploration and development, newly discovered oil fields belong to small marginal oil fields. Generally, the oil or gas reserves are limited, the structure is broken and complicated or they are located in remote areas. It has poor economic benefits with conventional development technology due to low output, large one-time investment in the construction of production platforms and the laying of subsea pipelines, and a long period of capital return. It is not attractive for cooperative development with foreign investors. Offshore marginal oil fields often lose commercial exploitation value due to mismatches in reserves and production with development costs.
Evaluation of Different Well Converting Patterns with the Distribution of Streamlines on Ultra High Water Cut Reservoir
Authors: Wang Huiyu , Hou Jian , Guo Zhenhai , He Sixian , Du Qingjun , Li Cheng 
Published: November 2020

Abstract
The mutual converting between production and injection well can be applied to change the directions of streamlines to improve the sweep efficiency of zone with high residual oil. How to improve the oil recovery by efficiently developing the remaining oil is a key issue for ultra-high water-cut reservoir. Therefore, based on a realistic reservoir selected from Shengli Oil-field, a model is presented to investigate the effects of different converting patterns on ultra-high water cut reservoir.
In this work, we built the model in Eclipse of Schlumberger according to the real well pattern and reservoir conditions. The residual oil distribution after water-flooding under ultra-high water cut was studied. Then, to obtain the optimal oil recovery, we investigated four well converting patterns, including the distribution of modified streamlines and final oil recovery. Moreover, we investigated the effects of water cut which is the time to convert and permeability ratio on residual oil recovery. All patterns and the model is described in detail to permit readers to replicate all results.
According to the simulation results, the shape of residual oil distribution of traditional five-point pattern is like a cross which is around the production well. Comparisons of oil recovery of four converting patterns are presented. The optimal case is the pattern which applies well converting in an interval way, arranging one injection well between two production wells. This interval way is able to let streamlines sweep more areas with high oil saturation. Whether high oil recovery can be received also depends on two significant parameters-water cut and permeability ratio. For water cut, there is an optimal number when applying this method. In this study, the converting should be applied when water cut is 93%. For permeability ratio, the higher it is, the higher oil recovery we can have after applying the converting. Both two parameters are combined to obtain the best water cut to convert with different permeability ratios.
Due to high cost of many EORs like chemical flooding, the novelty of this work is in the ability to provide a more cost-effective and convenient method to address the low oil recovery of high water cut oil-fields.
Introducing New Drone-Based Inspection Technologies to Safely and Consistently Deliver High Value Results
Authors: Moonen A. J. , Sufian Bin Ahmad 
Published: November 2020

Abstract
Over the past few years ‘Drones’ (or Unmanned Aerial Systems as they are offcially called) have become an accepted part of the inspection ‘toolkit’ in upstream and downstream oil & gas. Yet, at the moment, their application in the oil & gas industry is still largely limited to pure visual inspection of tall structures (e.g., flares, communication towers and offshore jacket structures) or visual surveying of pipelines and construction sites with some occasional use of thermography as well. As drone technology is becoming more and more common, the call to expand their use with other inspection and surveying techniques is also becoming louder. Fortunately, developments are now underway to add capabilities, e.g. (i) ultrasonic thickness gauging (UTG), (ii) ultrasonic defect detection, (iii) detection of hydrocarbon leaks by Optical Gas Imaging (OGI), (iv) internal inspection of membrane LNG cargo tanks, (v) 3D mapping of structures through either LiDAR or photogrammetry, and (iv) ultra long range operations (5 hours flight time and above) to survey unmanned offshore facilities.
By definition the oil & gas environment is challenging and high-risk. Thus, to introduce these technologies, it is not sufficient to ‘slap a new probe or sensor on a drone’ or to buy a new, more capable drone and then perform a few proof-of-concept flights for a successful operational introduction. The successful ‘hardening’ of new technologies for drone inspections or surveillance in a real-life operational environment requires the integration of equipment, crew capabilities, procedures and data management. Therefore, for every new step, a full development cycle has to be organised and managed. A bespoke safety case underpins cycle by generating the key elements from which (additional) training as well as operational procedures and data management tools/processes can be developed. Extensive trialing and milestone reviews are part of the process.
Only if the young but growing ‘drone services’ industry and asset owners follow such a systematic development approach in a disciplined manner will it be possible to ensure the safety, consistency and quality of ‘drone-based inspections’. Without this, the outcomes will at best be disappointing. This paper presents the first comprehensive description of such an approach. Drone-based ultrasonic inspections are used as a real-life example.
Winning Over the Production Threat: An Innovative Petrophysical Approach for Sand Grain Size Prediction and Rock Strength Evaluation
Authors: Zulkipli Siti Najmi , Johar Zurita 
Published: November 2020

Abstract
Majority of producing reservoirs in Malaysia come from sandstone accumulation with varying properties, rock fabrics and qualities. Being one of the major culprits in development and production spectrum, failure to take proactive measures for early prevention and detection of sanding issue has proved to be an expensive lesson learned especially during the mature production stage and late field life. High cost, increasing risk and intervention complexity and massive revenue loss are among the consequences due to this failure. This paper will highlight the challenges faced in sand prediction and monitoring and the proposed solutions at various field stages incorporating subsurface analysis, technology and brilliance at basics. The same approach will be used in rock strength evaluation for field subsidence analysis.
Subsurface data such as logs, cores, drill cuttings and downhole well configuration can offer a tremendous insight at early stage of sanding issue. During field exploration and appraisal phase, information on reservoir compaction, barrier and heterogeneity, grain size, clay types and fines accumulation are usually investigated to give the overall reservoir potential and productivity overview. More comprehensive study could be conducted if core is available such as compressive strength, pore volume compressibility, elastic properties and even flooding test to simulate formation damage and factors affecting sand production. In area where limited core data is available, logs can be used to predict and generate sanding parameters such as grain size and other rock strength properties, hence driving the completion optimisation efforts and sand production preventive measures. Once production commences, sand count and particle size mapping should be updated frequently to complement the monitoring program.
Leveraging on technology and collaboration, downhole logging acquisition to locate sand producing interval, chemical based sand consolidation treatment and core-driven sand screen selection and gravel size design are among the common scenarios taking place to help with production revival. Results generated from subsurface study will be input to the early formulation of field development plan and production strategy especially for downhole as well as surface sand control mechanism. In addition, integrated grain size and rock strength prediction workflow had been formulated based on logs to provide a competitive framework for time and cost optimization.
Case studies presented in this paper will demonstrate a holistic and integrated approach at each stage of field life to win over the sand production hurdle as well as minimizing threat to production sustainability. Banishing the emerging threat through comprehensive subsurface study, strategic planning, execution and monitoring become the main agenda to protect well integrity as well as safeguarding the production.
Influence of Microwave Irradiated Plantain Peel Starch on its Performance as Water-Based Mud Fluid Loss Control
Authors: Awel Ferreira Ashley , Momeni Mohammadsadegh , Liew Hui Ling Jacklyn , Ghomali Raoof , Safari Mehdi 
Published: November 2020

Abstract
This research studies the potential of microwave irradiated plantain peels starch as additive to minimize the filtrate in water-based drilling fluids. The fact of agro-waste rapid growth has become centre of this research. Also, problem induced by filtration loss into the formation encourages research in this study. The formulation for the mud were prepared by using the standard mixture and added with different concentration of plantain peel starch. The novelty of this study is the investigation on the effect of microwave treatment on the properties of plantain peels starch which affects the performance of the drilling fluid.
The influence of the non-ionizing microwave effect on starch changed the physical and chemical properties by the disintegrated intermolecular bonding of the starch particles. Microwave heating reduced the moisture content of the starch by 81% due to rapid heat transfer within the starch granule. The water binding capacity of the starch has increased by 42.4% as compared to the non-microwaved starch. The swelling power curve increased to the factor of 3 and as temperature reaching 80?C the factor reduced to 1.5. Solubility curve of microwaved starch is on the other hand lays below the non-microwaved curve shows that microwave irradiation decreased the solubility of the starch.
Next, the performance of mud is evaluated with the presence of different concentration of native and microwave irradiated starch. Plantain peel starch did not affect the mud weight. The starch additives did not alter the pH and the mud pH is in the accepted alkali range. The starch concentration is directly affecting the viscosity of the mud. The presence of the starch in the mud enhanced the viscosity of the mud and also the yield point which favours the drilling operation as yield point indicates the ability of mud to transport cutting to the surface. Simultaneously, gel strength of the mud also improved with the presence of plantain peel starch and further enhanced with the presence of microwaved irradiated starch. In addition, plantain peel starch improved the fluid loss volume and further ameliorated the fluid loss when the microwave-treated starch added in the mixtures.
Waterflood Evaluation and Optimisation Through Rapid InterwellConnectivity Modelling in a Complex Reservoir
Authors: A. Salam Irzie Hani , Hendraningrat Luky , Idris Nurul Nadhira , Yakup Muhammad Hamzi , Rinadi Muhammad , Sedaralit Mohammad Faizal 
Published: November 2020

Abstract
Waterflood is well-known as the cost effective secondary recovery mechanism to improve oil recovery. With current challenging oil price environment, waterflood continues to be one of the main candidate of choice. Hence, it is very important to maximize by optimizing the process. The objective of this paper is to propose a rapid technique to evaluate and optimize current matured waterflooding project in an offshore brown field with complex stacked reservoirs and production system through dynamic data analyses.
Interwell connectivity evaluation can assist in reservoir characterization, well placement, and evaluate waterflooding performance. Therefore, dynamic data analytics workflow applying interwell connectivity evaluation and Streamline as implicit approach are proposed. The importance of clustering each area become important to raise particular issues such as poor properties and connectivity. The production and injection points are evaluated and unswept area can be identified. Therefore, waterflood can be optimized.
This study resulted if current waterflooding can be optimized and new potential well placement can be identified to increase oil recovery. Compared with no further action case, oil recovery can be potentially improved 3-4% based on numerical full-field modelling prediction.
The technique will be very useful to have business decision rapidly in weeks. With current oil price situation, it can be as a cost-effective technique, especially for brown fields with mature waterflood projects and have complexity in geological and production system that commonly time consumption. The proposed workflow can be deployed to other neighbor mature fields.
Methodology of Simulating Spread-Moored FPSO Green Water Using CFD-Based Numerical Wave Basin
Authors: Teng YihJeng , Tan Jaime HuiChoo , Kim Jang , Jang Hyunchul , Lim Ho-Joon , Kyoung Johyun , Tcherniguin Nicolas 
Published: November 2020

Abstract
This paper presents the methodology of simulating green water events of a spread-moored FPSO platform using a CFD-based Numerical Wave Basin (NWB) with an optimized CFD model. Previous work done on the assessment of the motions of the spread-moored FPSO platform in irregular waves has demonstrated excellent agreement between CFD calculation and model test measurement (Baquet et al., 2019). This study further investigates the CFD methodology to efficiently simulate highly non-linear/breaking waves to extend the NWB applications to include prediction of green water occurrence on FPSO platforms.
In this study, a CFD model is developed to enable efficient and direct simulation of green water events identified from global motion analysis of the FPSO platform. Smaller time-steps are used, and mesh refinement is applied at the regions which are potentially subjected to green water to ensure more accurate prediction of the green water elevations could be achieved compared to the global motion analysis model. The computing resources required to run the CFD model are maintained below the practical limits for use during typical FPSO project engineering phase. CFD model simulation results for green water events of the FPSO platform are compared against available model test data and good agreement is observed.
This paper demonstrates an application of CFD-based NWB for green water prediction for a spread-moored FPSO platform based on an optimized CFD model which is developed to enable fast simulation of green water events. To evaluate the susceptibility of a FPSO platform to green water, large numbers of green water event simulations will be required to obtain reliable statistical data.
Effect of Thermal/Shear Conditioning and Aging on the Effectiveness of Synthesized Nanocomposite PPD on Waxy Crude Oil
Authors: Sharma Rohit , Mahto Vikas , Vuthaluru Hari , Li Chun-Zhu 
Published: November 2020

Abstract
Wax deposition is a serious issue during the pipeline transportation of crude oil. This research work has investigated the effects of some important parameters on the flow characteristic of crude oil during the pipeline transportation in offshore and onshore field environments.i.e. effects of thermal/shear conditioning and aging on the flow properties of virgin crude oil and additive-treated crude oil. Polymeric nanocomposites are a new and improved family of pour point depressants that can enhance the performance of polymeric additives. This work is in continuation of our previous work of Sharma et al. 2019c, where polymeric nanocomposites based on graphene oxide were synthesized, namely poly (methyl methacrylate)-graphene oxide [PMMA-GO] with different concentrations of graphene oxide (0.5, 1 wt. %), and were subsequently evaluated as potential pour point depressants for a waxy Indian crude oil possessing substantial wax deposition and gelation issues. The effectiveness of the PMMA-GO was examined in this work based on its pour point depression, flow performance, and enduring thermal conditioning, shear conditioning and aging phenomenon in the PMMA-GO treated crude oil. Its performance was compared to that of polymer PMMA-treated crude oil, and a PPD-wax interaction mechanism was proposed. The effects of thermal conditioning on the performance of PPDs were evaluated by determining the gelation points at cooling rates of 0.5, 1 and 1.5°C/min. Also, the pour points of additive-treated crude samples were calculated after repetitive heating at temperatures 60°C, 55°C, 50°C and 45°C. The effects of aging on the flow behaviour of crude oil were determined by obtaining the rheological properties and pour point values on the 1st and 15th day of its storage. For evaluation under shear conditioning, apparent viscosities were measured over shear rates of 0.1-500 s-1 at temperatures 30°C, 40°C and 50°C below and near wax appearance temperature (WAT). This study complements the benefits of the PMMA-GO as a flow improver obtained in our previous study and details its effectiveness under more practical applications.