bluuebunny/crossref_metadata_2025_split huggingface dataset:
Achieve Zero Shutdown by Optimizing Design and Tie-In of Compressors in Brown Field Projects
Authors: Kumar Sampath , Gupta Kapil Kumar , Al Wahedi Faisal 
Published: April 2024

Abstract
As part of Define stage study of new oil producing facilities, it was recommended by Asset owners to reduce CAPEX (Capital Expenditure) and OPEX (Operating Expenditure) by
Designing new facilities to have maximum synergy with existing oil trains. Utilize the spare capacity of existing oil and gas processing trains. Achieve ZERO / minimize shutdown of the existing facilities.
Adequacy study for existing facilities was carried out and it was concluded that spare capacity of Oil processing trains are adequate however existing LP (Low Pressure) /MP (Medium Pressure) Compressor trains (3 × 50%, 2 operating + 1 standby) had bottlenecks. Therefore, it was recommended to add the new LP / MP (2 × 100%, 1 operating + 1 standby) train parallel to the existing LP/MP Compressor trains.
Further Define stage Adequacy Report also recommends addressing existing issues during Execute stage:
Issues related to load sharing controller of existing compressors along with new load sharing required for new compressors. For major modification required in piping network, Tie-ins, and pipe routing. Address design, safety & constructability constraints.
All the above are triggers for escalation of shutdown durations, project cost and major loss of revenue for Asset owners.
Challenges to Opportunities; Water Management Journey from Oman South
Authors: Al-Hajri A. , Al-kindi S. S. , Harrasi A. 
Published: April 2024

Abstract
Efficient management of produced water presents an ongoing challenge in the oil and gas industry due to continuously increasing produced water volumes and the challenges related to handling, treatment & disposal as well as the associated energy consumption and emissions. Proper water management is especially important when produced water volume starts to affect the Oil production. This paper focuses on a specific cluster located in southern Oman, exploring the techniques employed to address these challenges and transform them into opportunities. The study highlights the importance of restricting the volume of water produced from the reservoir while maintaining optimal oil production levels, leading to the deployment of Autonomous Inflow Control Valves (AICVs), which are currently in use within the cluster. Furthermore, the paper delves into common methods for surface-level produced water handling and treatment, such as Deep-Water Disposal (DWD) and Water Injection (WI) wells. This paper showcases how DWD wells presented an untapped potential for a nearby field. Moreover, in line with energy consumption and emissions reduction requirements, and with a commitment to environmental sustainability, the paper showcases the company's environmental sustainability approach by utilizing Water Treatment Project (WTP) that significantly reduces energy footprint by relying on mechanical and biological processes, eliminating the need for pumps. This paper illustrates the efficacy of these subsurface control techniques and their substantial contributions to sustainable produced water management within the region, along with the surface-level handling and treatment approaches employed.
Vibroacoustic Technology for Real Time Leak Detection and Pig Tracking on Offshore and Onshore Pipelines
Authors: Marino M. , Gomes A. P. , Rota M. , Cesari S. 
Published: April 2024

Abstract
The primary objective of this paper is to present and assess the effectiveness of Vibroacoustic Technology as a reliable and robust asset integrity monitoring system for offshore and onshore pipelines by analysing data from actual leakages and pigging. Specifically, the focus will be on its capability to detect leaks and track Pipeline Inspection Gauges (PIGs) in real-time.
Vibroacoustic Technology is a robust detection system employed in pipeline networks to identify leakages, deforming impacts, PIGs location and various types of third-party interferences (TPI). By strategically placing specialized sensors at regular intervals along the pipeline, this technology can effectively capture vibroacoustic waves generated by these activities as they propagate through the pipeline structure and transported fluid. The data collected for leakage detection and localization is also utilized for real-time tracking of PIGs to determine their precise location.
Following the installation of vibroacoustic sensors on the pipeline, comprehensive test campaigns were conducted to simulate various spillage scenarios. These test campaigns not only assessed the performance of the detection system but also evaluated its response time. After collecting data for approximately one month, the system was calibrated and officially deployed. With the introduction of Vibroacoustic Technology, the tracking of PIGs became possible using the same data collected by the sensors, providing real-time updates on the PIG's position and traveling velocity. Significant research and testing have been carried out worldwide on the application of VT in pipelines, yielding exceptional results on both transferring and shut-in conditions. This paper presents the outcomes of a spill test campaign conducted on a pipeline in Italy, focusing on the system's sensitivity and the statistical data obtained during the passage of a PIG.
Vibroacoustic Technology is a reliable detection system designed to meet the demands of complex pipeline operations, cost-effective, non-invasive and easy retrofitting. By strategically placing sensors every tens of kilometres apart along the pipeline, it can detect even small leakages caused by corrosion or illegal tapping. Real time monitoring of pipeline integrity helps prevent severe environmental contaminations associated with leakages, making the system indispensable in ensuring the safety and efficiency of pipeline networks. Furthermore, the system provides the added benefit of accurate PIG tracking.
Implementing Business Analytics Tool to Optimize Deep Shale Gas Drilling Operations: A Visualization Approach to Analyze Drilling Performance
Authors: Chen Lu , Yan Juntao , Liu Jie , Liang Yanchao , Li Wei , Qi Peng , Baojian Hao , Guangzhi Shi , Tian Peng , Yang Bo , Liu Bingqi , Xu Ziyuan , Yang Zhigang 
Published: April 2024

Abstract
Our work combines a business analytics intelligence tool with advanced big data management techniques, and applied the tool to drilling performance analysis and decision-making processes for deep shale gas operations.
An advanced data processing workflow including transforming and mapping data was designed and implemented to unify current and historical drilling operations data into a unique dataset. The latest operations information is regularly collected and updated through an automated data querying process, which saves the effort of repeating data wrangling manually and eliminates the risk of human error. A business intelligence (BI) tool is used to promote the engineering of the data analytics process, create relevant key performance indicators, design data models, and establish a tracking and evaluation system. Finally, the BI visualization tool is used to generate and publish comprehensive cloud-based dashboards and reports.
The BI visualization dashboard enables oilfield companies to perform efficient and accurate analysis of drilling performance. The BI tool allows
Effective identification of rotary steerable system (RSS) utilization, drilling efficiency, failures, and downhole applicable conditions on basis of real job data, thereby enabling informed RSS management decisions Clarification of high performance of the RSS for making strategic decisions for high profile jobs Classification of rotary steerable tool failures, nonproductive time trends and monitoring maintenance strategies to reduce failures that have a major impact on drilling operations performance Incorporation of real-time operational data and detection of record-breaking jobs Development of custom drilling operations performance reports Reducing the workload for data collection and chart making with faster acquisition of more accurate data than with previous methods Customized and accurate documentation of drilling performance data in a consistent and standardized fashion Publishing of specific guidelines for RSS applications in deep shale gas drilling Performing technical analysis for operators
The integration of BI tools in drilling operations is a step change in how service companies and oilfield companies are analyzing and monitoring operation performance (efficiency and quality) to optimize drilling and minimize costs. BI analysis using existing techniques and resources was conducted for a dataset from more than 100 wells with over 1,000 runs in a Sichuan basin deep shale gas field.
Study on Production Improvement with Multi-Scale Geomechanical Modelling for Horizontal Wells in Unconventional Resources
Authors: Zhang Jie , Zhou Wei , Wang Peng , Wu Yiming , Wang Peng , Liu Zhiliang , Li Guohui , Tian Lei , Zhan Qigui , Mu Xingyu , Huang Xingning 
Published: April 2024

Abstract
To address the difficulty of increasing production in tight and naturally fractured reservoirs in the Tarim Basin oilfield, a study was conducted to maximize the volume of reservoir transformation through close-spaced fracturing. The parameters of close-spaced fracturing were optimized, reducing the average cluster spacing to 7m and the average stage spacing to 52m, significantly improving the degree of fracture control in the reservoir. This study developed key technologies for large-scale volume fracturing in horizontal wells, including high-rate horizontal wells with a flow rate of 16-20m3/min, freezing gel for creating main fractures, slickwater for creating complex fracture networks, small particle-size proppants in quartz sand, and high-strength proppants, which effectively supported main fractures and various level discontinuity fractures. Field trials have demonstrated that this technology significantly improves the effectiveness of fracturing in horizontal wells, with a cumulative oil production of 10,969.3m3 in 18 months, more than triple the production of previous horizontal wells. The results of this study indicate that large-scale close-spaced volume fracturing in horizontal wells can effectively address the challenge of low reservoir productivity in the Tarim Basin, providing strong technical support for the efficient development of deep oil and gas resources in the region.
Effects of Structural Parameters of Flow Tube on Flow Characteristics Near a Blowout Well
Authors: Li Yiming , Yang Qishuang , Wang Ning , Ahmad Sheraz , Liu Yiying , Lv Zhongjin 
Published: April 2024

Abstract
Well blowouts are likely to cause fires and wellhead damage. The flow tube is a necessary device to raise the flame to reduce the temperature around the wellhead and provide suitable conditions to reset the wellhead device. The effect of flow tube structure and posture parameters on the flow field near the wellhead have been investigated and parameter optimization of the flow tube designing has been carried out.
In this study, the well blowout jet interacting with the flow tube has been simulated using the most practical k-e turbulence model. We investigated the effects of the ratio of the inlet and outlet diameter ranges (1:1-2.4:1) and the length of the lower section ranges (1.5m-3m) on the distribution of the velocity and pressure of the two-section flow tube. The drainage effectiveness and flow control capability were analyzed. The effect of changes in height and angle on the forces affecting the flow tube during buckling-up-installation was examined. For evaluation purposes, the design parameters of the flow tube were optimized.
For verification of model accuracy, the numerical simulation results were compared with the classical solution of the free jet. In the results section, it can be observed that the diameter ratio affects the inlet pressure, velocity, and entrainment of the flow tube. A strong negative pressure profile is witnessed in the straight flow tube and for every 12.5% increase in the diameter ratio, the negative pressure values at the inlet near the wall decrease by nearly 40% while the diameter ratio is increased by 12.5 percent approximately with the volume of entrainment diminished by 8%. When the diameter ratio of 2:1 is considered, the pressure at the center of the inlet changes from negative to positive. Therefore, we believe that increasing the diameter ratio can effectively reduce the negative pressure and entrainment volume. The length of the lower section also influences the inlet velocity and pressure distribution. With the increasing length of the lower section, the inlet velocity and entrainment decrease with a convergence profile. The results of the flow field when flow tubes inclined from 5° to 15° demonstrate that strong vortices are generated in the lower section. During this the overflow velocity increases by increasing the inclination angle.
This study provides a better understanding of the mechanism of how the flow tube controls the jet flow and provides a theoretical foundation for the design of the flow tube. It concludes that the diameter ratio of the flow tube and the length of the lower section are the key parameters. It also provides a deeper insight into hazards near the wellhead, which can reduce operational risks for field operators.
Co-Injection EOR Technology Increases Recovery and Reduces GHG Emissions
Authors: Wasylchuk G. 
Published: April 2024

Abstract
Oil demand continues to rise and is not projected to peak until at least 2030, according to the International Energy Agency, or possibly even later as per OPEC. Despite this, many publicly listed oil companies have announced aggressive emissions reduction targets. For instance, Canadian companies Cenovus and CNRL have committed to achieving net zero by 2050. Cenovus aims for a 35% absolute reduction of GHGs by 2035, and CNRL targets a significant reduction from oil sands operations by 2030.
CEOs often cite the challenge of generating acceptable returns on emissions reduction projects as a major barrier to decarbonization, as reported by the Boston Consulting Group in 2023. Abatement technologies such as Carbon Capture, Usage, and Storage (CCUS) require substantial investment and are unlikely to yield positive returns for several years. Furthermore, they are expected to remain relatively small in scale and impact in the near to mid-term future, according to the World Economic Forum in 2023.
The traditional and conventional method of heavy oil extraction in Alberta and Saskatchewan has been marked by inefficiencies, primarily due to low recovery rates that leave upwards of 90% of the resource untapped. The process is characterized by high emissions and significant capital investment, rendering the development of smaller deposits economically unfeasible. Heavy oil production typically necessitates a substantial upfront capital investment in large, permanent central facilities, leading to a planning horizon of five to ten years for the optimization of a steam plant and production installation. Additionally, securing regulatory approvals for land disturbance and water supply requires considerable time and effort.
Intelligent Metering and Automated Gas Lift Control System with EDGE
Authors: Liu Lulu , Pinyan Liu , Fangfang Wei , Xingyu Jiao , qi Wei , Chaodong Tan 
Published: April 2024

Abstract
In order to optimize gas lift rates and maximize production profitability for gas lift wells, a ‘cloud-edge-end’ intelligent control system is developed. By leveraging an ensemble of artificial intelligence (AI) agent at the edge, the system is able to consume real time data and provide automatic gas lift control.
Flow meters is integrated with machine learning models to ensure measurement accuracy. Machine learning (ML) is used to build the AI agent which embedded in the wellhead edge after fine tuning. Real time data from sensors and meters are sent to the AI agent. It calculates the optimum flow rates with edge analytics capabilities and compares with the flow values detected by flow meters. When the detected value is inconsistent with the calculated one, the AI agent will take actions (rewards or penalties) automatically by regulating the gas lift injection valve and production choke, until meeting the optimization goal. The solution is able to automatically control the gas injection rate and liquid production rate in a close loop system with edge architecture. Compared with manual control, the constant flow rate is maintained and flow fluctuations are avoided.
Production Enhancement & Cost Effective of Deep Gas Wells by Using Cluster Perforation Technique of Carbonate Reservoirs in Kuwait: Case Studies
Authors: Al-Saeed A. , Al-Salali Y. 
Published: April 2024

Abstract
North Kuwait Jurassic Gas (NKJG) fields are challenging HPHT wells with near-critical fluids in reservoir conditions. These wells are deep and sour with 2-8 % H2S and 1-3 % CO2 with average reservoir pressure ranging from 10,000 – 4,000 psi and average reservoir temperature of ~275oF. Best practices in terms of developing these fields by using the best technologies in drilling, completion, and production are essential to maximize the reserve recovery in order to deliver hydrocarbon to the market.
Due to anhydrite presence and existing high variation of natural fracture distribution along the wellbore with different lithology and reservoir properties. There is differential pressure depletion happens within the entire reservoir, so these reservoirs have been divided into different flow units based on stratigraphy and pressure differential. These layers have different productivity index based on production logging records and calibrated well production models due to existence of dual-porosity tight matrix with natural fracture system which require proper pinpoint activation protocol by treating these layers separately.
During the early development stages of these fields, these wells were completed with tapered type of completion with 3.5″ production tubing, which was used as the optimum flow rate for virgin or slightly depleted reservoirs. Nowadays, Monobore completion has been deployed so that these flow zones can be perforated, activated, stimulated, tested and isolated using plug and perf technique which provide proper stimulation fluids propagation into the target reservoir. In addition, the cluster perforation leads to better effective stimulation fracturing by bypassing formation damage due to drilling, completion & perforation debris from the illustrated case studies.
This paper aims to illustrate the successful story of the cluster perforation technique in tight carbonate reservoir layers, and share its impact on pinpoint stimulation and hydraulic fracturing treatment by comparing the production performance of the studied wells with offset wells.
As an additional achievement, the cluster perforation leads to cost reduction by reducing the perforation gun length, volumes of pumped treatment/wellbore diverters fluids and accelerating the well hookup to the production facility beside the sustainability of the production during the LTT. Also, that technique is better in terms of reservoir management as it supports depleting the reservoir layers uniformly. The success of this approach was proven by calibrated nodal analysis assessment and sustainability of well production at a stabilized rate, which supports reaching "optimal inflow distribution" along the different flow zones, which become a best practice approach in the newly completed wells aiming to maximize the gas recovery.
Water/Gas Control Mechanism of Unique Autonomous Inflow Control Device: A Case Study of Selection Parameters and Performance of AICD in Multi-Layer Oil Reservoirs
Authors: Chen Yanhong , Khan Javed Akbar 
Published: April 2024

Abstract
This paper presents intelligent water control technology advancement and effectiveness that can control water influx, enhance oil recovery, and manage pressure in multi-layer reservoirs. The water control completion mechanism is explored, automatically identifying fluids according to physical properties such as viscosity and density. The innovative design of the inflow channel structure restricts water. Secondly, the device's performance and critical control tools are elaborated; the core tool of the technology is an intelligent water control screen; it can automatically adjust pressure drop, has no moving parts, has an integrated design, and can function throughout the entire life cycle of the oil well. Finally, the application cases in a whole oilfield block were introduced; the technology had been installed in more than 200 wells globally and, out of which five wells in Chad oilfield, a good application result was achieved, daily oil production increased more than 30% on average, daily water production decreased more than 35% on average. Until now, those five wells have remarkably affected water control and oil increase. A case is presented in which AICD has improved oil production, reduced water content, and controlled water breakthroughs. It has been applied in vertical, directional, and horizontal wells to EOR of oil and gas wells. Before this unique AICD installation, daily oil was 107bbl/d, and daily water was 992bbl/d, which heavily occupied surface water treatment. After the AICD, daily oil was 350bbl/d, and daily water was 52bbl/d. This AICD completion has optimized the water control solution and increased production. After the AICD's completion, daily oil production increased by 2.08 times on average, and daily treated water decreased by 92.8%. Up to Nov 2nd, 2023, cum increased oil is above 420,000 bbl, cum and water decrease is over 1,230,000 bbl. Production after AICD is still stable after 1500 days.
Overcoming Geological Uncertainty Through Enhanced Drilling and Completion Techniques in Sabah Deepwater, Malaysia
Authors: Nopsiri Noppanan , Tattawasart Purin , Samuel Elvy , How Lee Choon , Amperanto Henrikus , Wee Low Kok , Mohd Aris Mohd Azri B , Zainal Mohamed Zamrud , Meng Tan Kiang , Sangvaree Thakerngchai 
Published: April 2024

Abstract
Deep-water and ultra-deep water drilling presents various challenges that demand intensive planning and innovative solutions to ensure successful well delivery where meeting well objective in the target reservoir. Geological uncertainties in these environments are rather complicated, thus, require meticulous planning across all aspects.
This paper aims to discuss & elaborate what has been done in each phase starting from planning phase for drilling and completion with inputs on subsurface matters throughout the phase of operation and contingency execution. The main focus on the execution phase will be utilization of cutting-edge monitoring tools combined with good drilling and completion practices and managing unexpected high pore pressures. At the end of discussion, we will include a walkthrough on how this well has been drilled and completed, highlighting the implementation of special plans and techniques to allow successful delivery of the well for production.