bluuebunny/crossref_metadata_2025_split huggingface dataset:
Resilience Control Room Operator During Pandemic Covid-19
Authors: All Dhanhani Salem , Novendri Ivan 
Published: December 2021

Abstract
The control room acts as a central nervous system facility. This is where important decisions, using complex systems, are made every day. The actions of control room operators have a direct impact on uptime, production yields, quality, and industrial plant safety. In addition, long working hours per shift result in fatigue, irregularity of circadian rhythms and sleep cycles, and decreased cognitive performance at the end of day and night shifts. Fatigue causes decreased alertness, attention span, poor memory, and concentration and affect other mental factors.
ADNOC Gas Processing established Fatigue Risk Management Taskforce (FRMT) to adapt practices to the specific conditions and create a safer working environment, leading to happier and healthier employees and an overall community. In industries that run continuous and heavy-duty plants such as Oil, gas, and petrochemical, shift work ensures production flow. After the outbreak of Covid-19, business needs to adapt quickly so that their activities can run. The finding suggests that the workers' cognitive performance is reduced, shown by the increase of triggered alarm by the average of 14.39% higher than before the outbreak of Covid-19. However, with the ability to adapt and implement control and monitoring measures, the number of alarm rate gradually decreased. The study framework was proven to be a valuable tool that decision-makers can use, especially to measure the performance of control room workers and their psychological fatigue affected by the Covid-19 pandemic.
Laboratory Evaluation Experiment for Adaptability Analysis of Nitrogen Injection in Yanchang Oil Field
Authors: Gao Jiaxi , Yao Yuedong , Bao He , Shen Jinjiang 
Published: December 2021

Abstract:
Yanchang Oilfield conducts systematic research on nitrogen injection to enhance oil recovery. Through the research of this project, the energy supplement method of horizontal wells suitable for the study area is determined, and its injection system and process parameters are optimized and determined.
The optimal energy replenishment method selected by the mine field test achieves the following economic and technical indicators: Provide a nitrogen suitability evaluation plan; Complete the nitrogen flooding matching process design of the target well; Complete the design of the injection-production plan for the target well; Compare with other energy supplement methods.
Through the analysis of two supplementary energy methods of water injection and gas injection in indoor and similar reservoirs, the following understandings have been obtained: (1) Nitrogen is insoluble in water, slightly soluble in oil, good swelling, large elastic energy, is an inert gas, exists widely in the atmosphere, inexhaustible, inexhaustible, has a wide range of sources. (2) the recovery rate of nitrogen flooding is significantly higher than that of water flooding. (3) The field test results of water injection and nitrogen test in similar reservoirs show that the supplementary formation energy of nitrogen injection is suitable for the later development of Chang 64 and Chang 71 in the Haobasi oil field. (4) Compared with deep ultra-low permeability reservoirs, it is more economical to use nitrogen to supplement formation energy and change oil. The rate is higher.
From the above analysis, it can be seen that the supplementary energy of Chang 64 and Chang 71 reservoirs in the Haobasi oil area should be nitrogen injection as the main supplement, and water injection as a supplement. Gas/water alternate injection is used to adjust the gas injection profile to slow down the escape of injected nitrogen. . Although water injection supplements the formation energy with greater uncertainty, it can be used as a technical means of fluidity control in the gas injection process and is relatively economical.
Multihazard Risk Aggregation Approach for Quantitative Risk Assessment of Upstream Oil and Gas Facilities
Authors: Decarli Luca , Crivellari Anna , La Rosa Laura , Zio Enrico , Di Maio Francesco , Scapinello Oscar , Martinoia Luca 
Published: December 2021

Abstract
For the design and operation of Oil and Gas (O&G) facilities, a Quantitative Risk Assessment (QRA) should be performed to quantify the risk of major accidents due to multiple hazards and sources at the plant level, thus allowing the effective identification and allocation of safety barriers. In this work, a novel approach for the multi-hazard and multi-source aggregation of risks is proposed, accounting for the uncertainties typically unexpressed in a conventional QRA (both on the frequency and severity of the accidental scenarios). The multi-hazard risk assessment framework proposed is applied to assess the Location-Specific Individual Risk (LSIR) for a representative Upstream O&G plant (case study), using a model based on multistate Bayesian Networks (BNs) for different functional units, each one undergoing an initiating event of Loss Of Primary Containment (LOPC). Estimates of frequency and severity for each possible accident scenario are aggregated to eventually calculate the overall LSIR. Moreover, LSIR's confidence intervals are provided to describe the uncertainty associated to the estimates, and the frequency and severity contributions to risk are derived for targeted prioritization of the safety barriers in view of the risk reduction.
Drilling Efficiently, Durably and Consistently Through Cherts and Conglomerates with PDC Bits is Possible
Authors: Reboul Sebastien , Elabassi Emad Ahmed , Tejedor Miguel Angel , Hafez Kareem , Cuillier Bruno , Addae Daniel , Yari Nina , Kapitaniak Marcin , Vaziri Hamaneh Seyed Vahid , Wiercigroch Marian 
Published: December 2021

Abstract
Drilling into harsh environment with heterogeneous formations including chert or conglomerate is usually a boundary that can't be crossed with standard PDC bit technology. This paper will show how an innovative PDC cutter shape combined with a novel 3D approach of cutting structure design have withstood this challenge and successfully replaced 16-in. traditional roller cone application in United Arab Emirates by the latest PDC technology delivering an average 35% improvement on Rate Of Penetration (ROP) while continuously drilling to Total Depth (TD) on each section.
When drilling chert or conglomerate type of formation with a PDC drill bit, uneven load per cutters is detrimental to their integrity and results in short runs or brutal stop in the drilling operation triggering a trip for drill bit change. The new technology shown in this paper includes a unique hybrid combination of cutter shapes with a design arrangement of the cutting structure to allow for the pre-fracturing of any hard formation heterogeneity by 3D shaped cutters while standard cutters ensure a high level of cutting efficiency through their shearing action. This innovative concept has been intensively tested in the lab through single cutter and full bit scale drilling testing. In addition, in-house 3D bit simulation software has been used to optimize the cutting structure and assure performance within a wide range of drilling scenarios.
Based on these simulations, an optimized design was manufactured for 16-in. directional applications usually tackled by roller cone drill bits and known for having heterogeneous cherty formations to drill throughout the end of the 5,000 ft section. Simulation results helped to validate the unique shaped cutters placement on the cutting structure to maximize the pre-fracturing effect. This design was run on Rotary Steerable System (RSS) and Positive Displacement Motor (PDM) assemblies and successfully drilled 5 wells in a challenging field of the United Arab Emirates offshore operations. 100% successful rate to reach TD in one run was achieved while increasing drastically the average ROP of the section by at least 35%. Moreover, the unique design configuration allowed to better control the directional behavior of the drill string, which resulted in a significant reduction in the overall cost per foot.
A new boundary has been breached in several wells of a complex 16-in. chert and conglomerate application in the United Arab Emirates thanks to a years-long effort combining an innovative cutter technology, an optimized bit design process including a state-of-the-art 3D simulation software with lab and field experimental testing campaigns. By looking at the micro level structure of the rock destruction mechanism, a huge improvement has been obtained at the macro level of drilling operation economics.
Protective Gripping Layer by Metal Additive Manufacturing for Corrosion Resistant Alloy Pipes Applied in Well Completion Operations
Authors: Antunes Ronaldo de Faria , Besse Jean-Guillaume Louis Marc Xavier , Fonseca Antonio Sergio Medeiros , Bouchart Nicolas Pierre Philippe , Ferhi Reda Abderrzak Mohamed , Lima Luciana Iglesias Lourenco 
Published: December 2021

Abstract
Evaluating Efficiency of Surfactant-Polymer Flooding with Single Well Chemical Tracer Tests at Kholmogorskoye Field
Authors: Bondar Mikhail , Osipov Andrey , Groman Andrey , Koltsov Igor , Shcherbakov Georgy , Milchakov Sergey 
Published: December 2021

Abstract
EOR technologies in general and surfactant-polymer flooding (SP) in particular is considered as a tertiary method for redevelopment of mature oil fields in Western Siberia, with potential to increase oil recovery to 60-70% OOIP. The selection of effective surfactant blend and a polymer for SP flooding a complex and multi-stage process. The selected SP compositions were tested at Kholmogorskoye oilfield in September-December 2020. Two single well tests with partitioning chemical tracers (SWCTT) and the injectivity test were performed.
The surfactant and the polymer for chemical EOR were selecting during laboratory studies. Thermal stability, phase behavior, interfacial tension and rheology of SP formulation were investigated, then a prospective chemical design was developed. Filtration experiments were carried out for optimization of slugs and concentrations. Then SWCTT was used to evaluated residual oil saturation after water flooding and after implementation of chemical EOR in the near wellbore areas. The difference between the obtained values is a measure of the efficiency of surfactant-polymer flooding. Pandemic restriction shifted SWCTT to the period when temperature dropped below zero and suitable for winter conditions equipment was required.
Two SWCTT were conducted with same surfactant, but different design of slugs in order to prove technical and economic models of SP-flooding. Long-term polymer injectivity was accessed at the third well. Oil saturation of sandstone reservoir after the injection of a surfactant-polymer solution was reduced about 10% points which is around one third of the residual oil after water flooding. Results were compared with other available data such as well logging, lab core flooding experiments, and hydrodynamic simulation. Modeling of SWCTT is ongoing, current interpretation confirms the increase the oil recovery factor after SP-flooding up to 20-25%, which is a promising result.
Temperature model of the bottom hole zone was created and verified. The model predicts that temperature of those zones essentially below that average in the reservoir, which is important for interpretation of tracer test and surfactant efficiency. The tested surfactant showed an acceptable efficiency at under-optimum conditions, which is favorable for application of the SP formulation for neighboring field and layers with different reservoir temperatures, but similar water composition. In general, the results of the conducted field tests correlate with the results of the core experiments for the selected surfactant
Digital Integration, Success Story of Accelerating Business Integration of Two Biggest Midstream-Downstream Natural Gas Company in Indonesia
Authors: Mujiyanto Arief , Wicaksono Agung , Adhi Fonny Prasmono , Missuari Muhammad Subhan 
Published: December 2021

Abstract
To achieve 24% portion of natural gas in targeted national energy mix in 2050, Indonesia government has integrated Pertagas, biggest transmission company into PGN, biggest distribution company under Oil & Gas Holding Pertamina. But survey from PWC in 2004 resulted that around 75% post-merger companies reported integration difficulties, especially both companies have long history of competition. Even more, government mandated 6 USD gas price policy at plant gate, which create enormous urgency to accelerate pipeline and digital integration in the most efficient way. Especially, in this pandemic era, midstream industry needs to foster digital transformation by rethinking outdated business models and strategically applying technology to change rather than focusing on simply cutting costs.
From this integration, Pertagas with more than 2,418 km pipeline in 12 provinces spread from Sumatra, Java and Kalimantan has a big potency to be synergized with PGN, as Sub Holding Gas with the total of 10,169 km of pipeline which represent 96% of national gas infrastructure. During 2020. Both companies resulted more than 1.255 MMSCFD of transported gas and 828 BBTUD of sales gas to more than 460 thousand customers. So, PGN and Pertagas management has high expectation on this digital integration to transform from previous fragmented pipeline to be interconnected network to give flexibility in reaching unmet growing demand of strategic industry like refinery, fertilizer, electricity, steel and petrochemical in post-COVID recovery.
In this paper, will be described the challenges and its solutions as a success story in digital integration. The important steps start from strategy development, digital assessment, creating coalition, culture acculturation, and change management are explained as guiding pathway for sustainable implementation. It will also portray the measured benefit and value from investment cost efficiency, time effectiveness from the initiation until launched, billing improvement, product development, and up to developed real-time integrated management dashboard for better decision making and part of the milestone for future National Dispatching Center for optimizing Sub Holding Gas portfolio of gas supply and subsidiary's infrastructure to meet growing Indonesia's demand.
Blockchain and 6G-Based Supply Chain Management Framework for Oil and Gas Shipment
Authors: Rahman Md Abdur , Belal Syed M. 
Published: December 2021

Abstract
Keeping track of the oil and gas supply chain is challenging task as the route and transportation requires sophisticated security environment - both physical systems’ and IT systems’ security. Thanks to the recent advancement in IoT, specialized sensors can keep track of the required supply chain environment. With the help of blockchain, the supply chain data can be immutably saved for further sharing with stakeholders. Due to the introduction of AI as an embedded element within 6G networks, the end-to-end supply chain process can now be automated for safety, security, and efficiency purposes. By leveraging 6G, AI, blockchain, and IoT, the supply chain data during the transportation or at rest can be monitored for any changed environment during the movement of the ship through national or international routes. In this paper, we study the requirements of such intelligent and secure supply chain management system conducive to the oil and gas industry. We also show our proof-of-concept implementation and initial test results. Our obtained results show promising prospect of the current system to be deployed to safeguard the oil and gas supply chain.
Infinite Water: Implementation of Nanofiltration for Optimization of Vessel Stimulation Operations in the Offshore Greater Ekofisk Area, North Sea
Authors: Kusumawati Irma , Edward Bremner Samuel , McIntosh Neil , Nylend Ingrid , Rajkovic Tanja 
Published: December 2021

Abstract
The incorporation of a sulfate removal system onto a stimulation vessel has been shown to positively affect vessel utilization, increase efficiency in field development, and reduce freshwater consumption.
Stimulation vessels have fixed storage and transportation volumes as well as a fixed total mass that can be loaded. Fresh water occupies the highest proportion of space and mass in most stimulation treatments, which imposes limitations on all other products that can be loaded out. Particularly for acid stimulation treatments, a compromise between the volumes of raw acid and fresh water must be made in order to achieve the best operational efficiency possible.
Any method that can reduce, eliminate, or replace fresh water as a component in stimulation fluids will have a significant impact on vessel efficiency. One option is the use of seawater as the base fluid. However, seawater can cause problems for well production due to the high sulfate content in the water leading to the formation of mineral scale. The solution to this problem has been the installation of a sulfate removal system on the stimulation vessel. Driven by membrane nanofiltration, this system can produce up to 100 m3/hr of low sulfate water from seawater for well stimulation operations. By removing the scaling risk from seawater, this system enables the stimulation vessel to maximize the products it loads with the ability to produce low sulfate water as and when it is needed.
The sulfate removal system can reduce SO4 content to 4.3 mg/l and reduce other ions present in seawater. With an output of 100 m3/hr and being installed independently from stimulation systems, the unit is able to produce water regardless of ongoing activities. In stimulation jobs, multistage ball drop operations are the most time-critical operations. In the analysis of hundreds of stages stimulated with water from the new nanofiltration system, the average stage completion time was 6 hours, which included ball loading, dropping, and displacement; diagnostic injection testing; and the main treatment. With an average water requirement of 600 m3, the vessel can keep up with water demand and remove water capacity from the utilization equation.
The use of a compact nanofiltration system for SO4 removal has improved stimulation vessel operations where scale production is a key concern for operators. In addition to increasing vessel utilization and intervention efficiency, the system will lead to the elimination of approximately 68,000 m3 of fresh water being pumped every year for stimulation operations in the North Sea.
GRE Lined OCTG as a Cost-Effective Solution for Water Disposal Wells
Authors: Pimenta Gervasio , Ahmad Mohamad Hussain , Mizukami Akio , Andres Bogdan 
Published: December 2021

Abstract
Glass Reinforced Epoxy (GRE), lining systems for API 5CT tubing have gained prominence in O&G industry, essentially due to the fact that GRE constitutes a physical barrier protecting the OCTG pipe from corrosive environment, and minimizing issues with scale deposition.
ADNOC group companies have been building experience on the implementation of GRE Lined L-80 tubing by successfully using it in produced water disposal wells.
Produced water is a highly corrosive medium due to dissolved CO2, H2S high to very high chloride content, high TDS, eventually containing bacteria. The corrosiveness of the fluid increases as the temperature increase from temperatures in the range of 30 – 50 degC at surface to reservoir temperature. The aggressiveness of this medium towards API 5CT L-80 or 13Cr / modified 13Cr increases with its contamination with oxygen. Dissolved oxygen is a strong depolarizer leading to high pitting rates if dissolved O2 content in the water is above 10 or 20ppb.
Conventional completion of WDW in ADNOC Onshore is based on API 5CT L-80, and short life of the completion strings has been attributed to deficient water treatment (lack of oxygen scavenger, corrosion inhibitor unsuitable for downhole conditions.
A life cycle cost analysis suggests that GRE lined OCTG could be a cost-effective solution for water injection. For this life cycle cost assessment, CAPEX (cost of L-80 completion string, combo corrosion inhibitor & oxygen scavenger skid and OPEX: cost of Combo chemical and monitoring activities for design life were considered, while achieving the required level of well integrity and lower operational safety risks (e.g. handling hazardous chemicals, monitoring activities)
3D Multi-Level Facies Constrained Geostatistical Inversion for Predicting Carbonate Thin Reservoirs
Authors: Guo Tongcui , Dou Lirong , Wang Guihai , He Dongbo , Wang Hongjun , Zhang Jian , Liu Weiliang 
Published: December 2021

Abstract
Carbonate reservoirs are highly heterogeneous and poor in interwell connectivity. Therefore, it is difficult to predict the thin oil layers and water layers inside the carbonate reservoir with thickness less than 10 ft by seismic data. Based on the petrophysical analysis with core and well logging data, the carbonate target layers can be divided into two first level lithofacies (reservoir and non-reservoir) and three second-level lithofacies (oil, water and non-reservoir) by fluids. In this study, the 3D lithofacies probabilistic cubes of the first level and second-level level lithofacies were constructed by using the simulation method of well-seismic cooperative waveform indication. Afterwards, constrained by these probability cubes, the prestack geostatistical inversion was carried out to predict the spatial distribution of thin oil layers and water layers inside the thin reservoir. The major steps include: (1) Conduct rock physics analysis and lithofacies classification on carbonate reservoirs; (2) Construct the models constrained by two-level lithofacies; (3) Predict thin reservoirs in carbonates by prestack geostatistical inversion under the constraint of two-level lithofacies probability cubes. The prediction results show that through the two-level lithofacies-controlled prestack geostatistical inversion, the vertical and horizontal resolution of thin oil layers and water layers in carbonate reservoirs has been improved significantly, and the accuracy of thin oil reservoir prediction and the analyzing results of interwell oil layer connectivity have been improved significantly. Compared with the actual drilling results, the prediction results by 3D multi-level lithofacies-controlled inversion are consistent with the drilling results, and the details of thin carbonate reservoirs can be predicted. It has been proved that this method is reasonable and feasible. With this method, the prediction accuracy on thin reservoirs can be improved greatly. Compared with the conventional geostatistical inversion results, the 3D multi-level lithofacies-controlled inversion can improve significantly the vertical and horizontal resolution of prediction results of thin reservoirs and thin oil layers, and improve the reliability of interwell prediction results. For the prediction of thin carbonate reservoirs with serious heterogeneity, the 3D multi-level lithofacies-controlled inversion is an effective prediction method.