bluuebunny/crossref_metadata_2025_split huggingface dataset:
Fully Automated Wellhead Choke & Flow Line Calibration on a Daily Basis for a Complex Surface Network with Over 1200 Active Producers: A KOC North Kuwait Case Study
Authors: Gabriel Irinel , Mohamed Walid , Rashedi Hamad Salem Al , Roopal Allen , Saleh Nada 
Published: October 2024

Abstract
A giant onshore KOC oil asset has a complex surface network with hundreds of jump-overs, several manifolds, trunk lines & thousands of flow lines. The goal of the asset is to identify bottlenecks that is impeding production, determine hydraulic health of pipelines and identify optimization opportunities. Only way to reach the mandate set by the asset is to have a calibrated surface network model on a daily basis which then can be used to confidently identify issues in the network.
Wellhead Chokes for individual wells are calibrated using a dedicated workflow called as Automatic Choke Calibration (ACC) workflow. ACC workflow selects only wells which have valid IPR/VLP files. Eight simulation runs are performed by varying wellhead choke discharge co-efficient (CD). Iterations are performed to calculate exact CD which will match pressure delta observed in the test across the choke. If deviation is within +/-5% then choke is flagged as calibrated. Automatic Network Model Calibration (ANMC) workflow is used for calibrating entire surface network starting after the wellhead choke till GC slot. Workflow identifies wells which have valid IPR/VLP, chokes are calibrated, have valid connection length, real time wellhead pressure (WHP), Flowline pressure (FLP) & artificial parameters. Averaged (24 hours, 5:00 AM to 5:00 AM) real time pressure data are updated for pipelines which will be undergoing calibration. Pipeline connections are calibrated by adjusting friction factor multiplier using simulating annealing algorithm to match the observed real time pressure data. For pipelines which are successfully calibrated, their friction factor multiplier values are stored in the database. Finally, model is updated by incorporating friction factor multiplier value identified in the calibration process. With a calibrated model, engineers have greater trust on the virtual rates reported by the simulation tool for individual wells & pipelines. Friction factor multiplier reported by the workflow has given valuable insights into the hydraulic health of the pipelines enabling engineers to take preventive actions effectively. Calibrated model is used by another workflow to identify changes which have to be performed in terms of choke and artificial lift parameter to maximize oil production.
This paper describes a pioneering new way of developing an integrated & automated workflow for calibrating choke and surface network on a daily basis instead of traditional way where calibration is performed less often which has major implications on the recommendations provided for the day-to-day operations of the asset.
Consequence Analysis of High-Pressure Natural Gas Pipelines to Determine the Safe Zones Around the Pipelines by Using PHAST
Authors: EL-Kanishy A. 
Published: October 2024

Abstract
Natural gas pipelines are essential for energy, but their failures can result in severe consequences. Egypt has established measures that include location classification for pipeline safety design and operation. Additionally, safe separation distances from communities are defined based on risk assessment principles. Nonetheless, a standardized method for determining these distances is lacking.
This research introduces a methodology employing PHAST consequence modelling to ascertain safe separation distances, replacing the Fixed Distance/Rule-Based approach. Event Tree Analysis evaluates potential hazards from pipeline ruptures, such as dispersion and explosions. PHAST simulates these hazards, delineating zones for gas dispersion, thermal radiation, and overpressure. It models full-bore ruptures of varying pipeline sizes and pressures under different soil conditions. The modelling identifies safe distances for specific gas concentration, thermal radiation, and overpressure metrics. Results are illustrated through tables and graphs correlating safe distances with pipeline specifications.
The PHAST modelling indicates that safe separation distances are directly proportional to pipeline size and pressure. Flammable gas dispersion is notably longer in sandy soil than in mixed soil. Stable weather conditions (2/F) produce larger dispersion areas but reduced thermal radiation and overpressure distances compared to neutral conditions (5/D). When compared to UKOPA and IGEM standards, PHAST modelling often predicts equal or greater safe distances. Methodological validation occurred by aligning the PHAST simulation of the 2021 Raven pipeline incident with observed flammable gas zones.
Recommendations emphasize integrating safe distance findings into Egyptian legislation, exploring other hazardous materials, and mitigating ignition sources near pipelines due to flammable zone risks. The PHAST model serves as an effective tool for determining safe separation distances for natural gas pipelines, accounting for various operational factors.
Comparative Study of Hydrogen Production from Organic Waste Fermentation and by Electrolysis to Achieve Sustainability and Decarbonization
Authors: Boshnak Eman. Bedair. Abdelbaset. 
Published: October 2024

Hydrogen has a vital role in attaining a sustainable and carbon-free future. Especially, when hydrogen is generated from renewable energy resources, hydrogen acts as an environmentally friendly source. this study compares the generation of hydrogen from the fermentation of organic wastes and water electrolysis. This study aims to collect data to help decision-makers make their decision according to effectiveness, cost-effectiveness, and sustainability.
Hydrogen power has many advantages, such as sustainability and clean energy, and can be used in industry, power generation, and transportation. Reducing the carbon footprint of hydrogen production requires generating hydrogen from renewable energy resources.
Fermentation of organic wastes produces hydrogen and other products during anaerobic digestion, which requires a breakdown of organic material by microorganisms in anaerobic conditions. This technique not only produces hydrogen but also aids in the management of organic wastes. On the other hand, water electrolysis is an electrochemical process that consumes electricity to split water into hydrogen and oxygen. If the source of the electricity is renewable the generated hydrogen is called green hydrogen, which is completely carbon-free.
Enhanced Integration to Characterize Heavy Oil in Complex Environment
Authors: Mattar Tariq , Ahmad Hamza , Sultan Gamal , Ramadan Moad , Maguri Ahd , Badr Ashraf , Masoud Ayman , Salih Abdelmalek 
Published: October 2024

Abstract
Heavy Oil Exploration is one of the great challenges faced in upper Ordovician in Murzuq basin due to the geological & petrophysical complexity. Few wells were explored earlier & resulted in water production. Leaving high uncertainty behind.
Hydrocarbon exploration in the Upper Ordovician, Mamuniyat Formation in Murzuq Basin is known to be challenging, being a product of fluvioglacial and glaciomarine processes, it is characterized by episodes of erosion and deposition. This resulted in stratigraphic units with limited lateral extent and varying reservoir quality, mostly tight due to quartz overgrowth cementation except when fractures are observed.
Furthermore, from petrophysical aspect the tight quartzite sandstone with the presence of fresh water, causes the resistivity to be high, beyond conventional tool limit. This leads to a difficulty to compute saturation profiling & distinguishing between oil & water.
Full evaluation techniques were utilized to characterize & identify potential zones to enable flow of black & heavy oil in such poor quality, complex reservoirs. The advancement in the interpretation of image logs, petrophysical logs lead to guide the reservoir Formation Testing Tools to enable flowing of black & heavy oil in such tight, complex reservoirs & conducting a Mini-Drill Stem Testing for reservoir potential assessment.
These wells when produced earlier had no signatures of heavy oil.
This paper describes the advancement in integrated approaches in Wireline logging to fully characterize such complex environments which resulted in the discovery of black & heavy oil in unprecedented area.
Integrated Automation and Intervention Solutions for Extended ESP Run Life in Complex Reservoir Environments
Authors: Hammad Mustafa , Musbah Ahmed. M. , Abdulatif W. , Shanbour H. , Masoud Mohamed H. , Elhajjaji R. R. , Awedan H. , Elhamali B. , Anabtawi E. , Budeeb M. , Bosnina S. , Bunkheila K. 
Published: October 2024

Abstract
A remote field that was discovered in 1970 relies on natural flow, supplemented by electric submersible pumps (ESPs) in some wells, to produce oil from a thin-limestone reservoir. With extensive faulting and low permeability, the primary recovery mechanism is solution gas drive. ESP systems previously struggled to achieve optimal run life, prompting the development of integrated solutions to extend the run life in challenging conditions.
Detailed failure analysis proved that the primary cause of ESP failures was motor overheating, exacerbated by inadequate reservoir influx. Therefore, a comprehensive integrated intervention workflow was developed to optimize ESP operation within this complex environment. First, a dual approach to stimulate the reservoir formation encompassed acid treatment and fracturing with rod-shaped proppant to mitigate the risk of proppant flowback and premature ESP failure. Addressing challenges such as deep reservoir pressure decline and a high gas-oil ratio, a wide range of a mixed-stage pump types and multiphase gas handlers were installed. Additionally, motor derating, tailored ESP shrouds, and variable speed drive technology were employed to optimize ESP operation. This included continuous 24/7 monitoring and remote control for enhanced performance.
The successful implementation of the workflow has delivered historical ESP run life exceeding 1 year in the field, coupled with sustained oil production. The first deployed ESP system yielded an average daily oil rate of 520 BOPD, prompting the extension of the approach to an additional four wells, resulting in a total rate of 3,750 BOPD. Continuous monitoring of well performance, facilitated by an automated workflow, has enabled the maintenance of optimal operating conditions. This includes fine-tuning the ESP running frequency to each well's performance, accounting for variations in well flowing pressure and reservoir fluid properties, such as different bubble points leading to varying gas-lock settings. Continuous monitoring and remote operation have minimized downtime to a remarkable 4.5%, which was mainly due to scheduled maintenance of the power system. This result verifies the effectiveness of the implemented solutions in optimizing field performance and maximizing hydrocarbon recovery.
The success of this approach has sparked interest in its application to similar reservoir environments, potentially unlocking additional oil potential in nearby fields. This promising prospect underscores the potential impact of our findings on the broader oil production landscape, paving the way for enhanced reservoir management and increased hydrocarbon recovery in comparable geological environments.
A Data-Driven Agile Approach for Faster Response to Lost Circulation
Authors: Sharma Sunil , Converset Julien , Le Blay Florian 
Published: October 2024

Abstract
In this paper we introduce a data-driven agile method specifically designed, implemented, and validated to yield actionable insights for more efficient and accurate responses to lost circulation events. Lost circulation is a significant challenge in drilling operations, leading to non-productive time and financial losses. It is also frequently observed that despite similar field conditions, the success rates of various solutions vary widely due to a lack of insights about the loss zone during planning and execution. Traditionally, response plans and decision trees are not dynamic and rely on categorizing loss rates as seepage, partial, or total losses. However, these plans often overlook critical factors such as the types of losses (e.g., natural fractures, induced fractures, vugs) and dynamic changes over time in loss rates, wellbore stresses, and pressures. Thus, developing a solution that processes these changes in near real-time to provide automated insights to the person monitoring the event can improve the success rates of our loss event response.
Additionally, there exists a disconnect between the multiple tools available for addressing lost circulation. These tools, when used together, can help in driving actionable insights and accurate detection of losses; i.e., active pit tracking by mud logging and mud logger's real-time comments, annular pressure while drilling (APWD) bottomhole pressure anomaly detection, geomechanics pressure wellbore limits, etc. Finding a way to bring all these tools and technologies to one platform so they can collaborate and complement each other can be a game changer in the precise detection of loss events and rates.
While developing the solution, numerous complexities were observed in pursuing a fully automatic method to put these multiple data sources together and drive a comprehensive outcome with the required precision, thus the concept of keeping a human in the loop was adopted.
In this paper, we delve into the details and uniqueness of the lost circulation monitoring workflows. We discuss the methodology used during workflow development and the establishment of a well-defined system for workflow validation using a labeled database. An overview of the uniqueness of the workflow computation, workflow verification process, and tiering of a workflow based on the quality of inputs and outputs will also be provided, along with the results of the real-time job applications and their successes.
Building a Sustainable Workforce: Cross-Posting and Secondment Strategies in Indonesia's Oil and Gas Operations
Authors: Endrawati Yohana , Putra Iswahyudi Sondi , Ningsih Retno 
Published: October 2024

In today's disruptive era, marked by rapid technological advancements and evolving global conditions, human resources have become more critical than ever. Organizations must adapt quickly to remain competitive and sustainable. Effective human resource management is essential for attracting, developing, and retaining talent to navigate the complexities of the modern business landscape. Building a sustainable workforce—one that is resilient, adaptable, and continuously evolving—is crucial for long-term success.
Indonesia's oil and gas industry, a key contributor to the country's economy, faces unique challenges in this disruptive era. As a leading producer in Southeast Asia, the sector must continuously innovate and optimize operations to meet rapid technological changes, shifting market demands, and stringent environmental regulations. This demands a workforce that is not only highly skilled but also capable of adapting to new technologies and sustainability practices.
To address these challenges, the oil and gas industry must focus on preparing its human resources for the disruptive era while building a sustainable workforce. This includes equipping employees with the necessary technical skills and fostering continuous learning, adaptability, and sustainability. Aligning talent management strategies with the industry's evolving needs is essential for maintaining a competitive edge and supporting Indonesia's economic prosperity in a rapidly changing world.
Comprehensive Investigation for Gas Flaring Recovery as a Potential Pathway for Oil and Gas Decarbonization
Authors: ElMasry H. 
Published: October 2024

Abstract
The worldwide movement to cut greenhouse gas (GHG) emissions and drive decarbonization as a strategy to reach net-zero objectives is swiftly accelerating. It is broadly recognized as a key force influencing contemporary energy policies. While many nations have made significant environmental promises, the essential next phase involves converting these promises into concrete decarbonization initiatives with allocated financing.
Methane emissions within the oil and gas industry typically originate from three main sources: leaks (which occur unintentionally due to a defective seal or a leaking valve), venting (which happens when gas is deliberately released for safety or operational reasons), and flaring (which involves burning gas that cannot be utilized or recovered). The oil and gas sector faces significant pressure to lower greenhouse gas (GHG) emissions from non-emergency gas flaring and venting.
The urgency arises because these activities emit large quantities of methane into the atmosphere, which significantly exacerbates climate change and presents a major environmental challenge to reaching net-zero targets. Methane is regarded as the second-largest contributor to global warming after CO2. Despite having a shorter atmospheric lifespan than CO2, methane has a much stronger greenhouse effect. It is estimated to account for around 30% of the global temperature rise.
Exploring Hydrocarbon Reserves in Mature Oil Fields by Interpreting the Subsurface and Using Dynamic Modeling
Authors: Salim M. M. , Hamada G. , Dahab A. A. 
Published: October 2024

Abstract
An effectiveness study of building strategy nondrained oil reservoir blocks to increase hydrocarbon production from mature oil fields—dynamic modeling techniques with subsurface interpretations and sharply adjacent well data—offers new development well placements for oil recovery and field life extension.
The study combines production data, pressure surveys, and detailed subsurface studies— including well log interpretations—to develop proper understanding of the behavior of the reservoir for its performance estimation. Dynamic modeling techniques are applied in the estimation of optimal well placement. This multi-disciplinary approach is normally aimed at accurate reservoir characterization and making strategic decisions on the development of new wells in non-drained blocks. Its effective implementation may require studies by the geologist, engineer, and data scientist concerning comprehensive data analysis in formulating solutions.
Important results were that new development wells increased oil production by up to ∼15% in total field production. The approach has been of high value with limited risks/costs; characterized by a short payout period and good opportunities for reinvestment of the savings. It, therefore, identifies the potential for residual capacity unlocking from low-productivity or shut-in wells in the pursuit of maximizing an asset's value. This paper substantiates the effectiveness of strategic drilling through real field empirical evidence by featuring a convincingly logical workflow applicable to similar mature oil fields, hence lending practicality with respect to production enhancement and field life extension. Its effective implementation must be based on multi-discipline teamwork in order to complete an adequate analysis of the data available and formulate solutions.
This paper contributes new insights into the efficiency of production optimization strategy execution in mature oil fields. The combination of dynamic modeling with detailed subsurface interpretation enables the provision of valuable empirical evidence to a research study and mapping out the constructs of a systematic workflow that improves hydrocarbon recovery, extends the productive life of mature fields, and advances current knowledge in the petroleum industry.
Enhanced Well Delivery with the Application of at Bit Steerable System in Tough Reservoir Targets. A Case Study
Authors: Khurshid Muhammad Imran , Roomi Shamlan Al. , Varela Rodrigo , Almeer Ali , Ruzhnikov Alexey 
Published: October 2024

Abstract
The objective of this paper is to systematically device a detailed mechanism for engineering application of advanced at bit steerable system with motor and explicate development of directional plans, risk analysis along with mitigation and prevention plan for each possible option. The scope of this paper is to establish selection criteria and execution, performance objectives with applicable tools and post run analysis to help industry for future applications.
Drilling in a very challenging environment where the directional profile achievement always remained critical, it is important to deliver well within given timelines. Due to geological constraints and specific required reservoir contact, reservoir target objectives were set in really challenging steering options. Most of time such tough targets are not hit and resulting risk of well delivery delays and frequent risk of geological sidetracks. In an onshore field, during the planning phase given surface location and target reservoir coordinates were assessed, resulting real challenge in drilling long curved and horizontal sections.
In the given circumstance of reservoir Target entry and limited kick off point a systematic procedure was adopted to layout directional profile. A really difficult directional profile was built to geosteer from slanted pilot hole resulted into a highly challenging 3D directional profile. The directional profile needs to curve into the formations that always remain famous in posing risk to achieve required dog leg severity. The risk indexation was tabulated, and a process was devised to achieved required well profile. Moreover, challenges faced during the execution and key points, to make such application more successful, are also discussed in this paper.
The results of this case study lay out technical approach adopted to enhance performance as well as productivities that can be further optimized. This case study explains, detailed strategy and its implementation with the application of at-bit rotary steerable system (RSS) with motor to achieve required 3D target entry. This strategy explained how such tight targets can be achieved resulting into early well delivery with the application of at bi steerable system with motor. Application of at-bit steerable system along with motor resulted into smooth landing as per reservoir requirement and better steering into reservoir with enhanced contact area.
This paper cover methods that how this new technology at-bit steerable system with motor application supported in comparison to the other possible options to achieve highest performance with better control on directional profile