bluuebunny/crossref_metadata_2025 huggingface dataset:
A Success Story of Implementing Autonomous Inflow Control Devices (AICD) for Gas Control in a Brownfield Asset - What Can We Learn?
Authors: Martinez Santiago Maryvi , Priyadarshini B. , Ortiz J.
Published: October 2023

An onshore oil field in Abu Dhabi with high gas saturation has been implementing flow control devices since 2019 to control the undesired fluids production. Over the course of production ‘Reservoir 1’ is experiencing a gradual GOR increase as a results gas injection in underlying units. The key objective of this assessment was showed the optimal reservoir management Lower Completion (LC) strategy adopted during the last 4 years to mitigate the gas production and extend the well production life.

Steady-state numerical solutions were set up to explore separate scenarios where Flow control devices (FCD) and Intelligent Completion (IC) were incrementally implemented. Overdesigned ICDs was avoided since they not just increase the cost of well completion, but also will impact the well Productivity Index negatively. The output is compared in terms of well cumulative oil and water/gas production thru the scenarios and their value quantified.

Conveying in the use of integrated LC (i.e. ICV, ICD/AICD, DHPG, PPL), Seven (7) new wells were drilled and completed with FCD in 2019-2023. Following the AICD Well performance evaluation: 1. Regular Surface Well Testing and Multi Rate Test MRT, 2. Production Logging Tool (PLT) and 3. Reservoir Well Modelling were conducted. Furthermore, an integrated review regarding utilization of ICD technologies for GOR control and lesson learnt has been performed.

The utilization of ICD technologies as a means for GOR control, is feasible and more efficient practice for well and reservoir management. All the wells with segmented completion with Autonomous Inflow control Device AICD shown enhanced production performance compared with barefoot completion.

Recent PLT’s tests at various choke sizes in all the wells revealed no evidence or minimum free gas production down the horizontal wellbore adhering to reservoir management guidelines and ensuring production sustainability. In capturing GOR evolution trends, the use of multiphase flowmeters has proved crucial. The simulation model calibration with actual AICD well performance proved a significant oil recovery in long term.

The delivered results supported the adoption of the technology on a larger scale; The provided solution effectiveness is continuously monitored to improve Lower completion design and increase production uptime.
Efficient Water Flood Management Along with Novel Approach to Infill Drilling Resulting in Increased Oil Production at Lower Cost and Reduced GHG Intensity
Authors: Kumar G. , Khadhuri S. , Shehab S. , Hajri Y. , Yazidi R.
Published: October 2023

Water flood is dominant development mechanism to produce oil from lower Shuaiba carbonate reservoirs in North Oman. Efficient water flood management along with a novel approach to drill infill wells has resulted in increased oil production at lower GHG intensity while reducing cost and improving value. This paper describes steps that were taken to improve water utilization factor and sweep, in addition to measures adopted to reduce cost which resulted in significant value addition.

Cluster wide effort to improve production from water flood fields in Cluster X focused on throughput and sweep improvement along with measures to reduce cost of drilling. Throughput improvement was mainly achieved through WRFM activities like stimulation and opening of closed in wells. Sweep improvement was achieved by increasing water injection in patterns with high injection efficiency. Digitalization workflows were used for better integration of production data with water flood management. Additionally, significant cost reduction and value improvement was realized through novel approach to infill drilling. Key to success was closing of high water cut wells before drilling new wells and side-tracking wherever possible.

Throughput improvement achieved by enhanced WRFM practices resulted in the fields in cluster achieving highest throughput levels in the organization. This, along with sweep improvement resulted in stabilization of NFA decline, and higher start rates for new wells, which resulted in oil production gain of 2-5% which translates into more than a thousand barrels a day increase in oil production.

Implementation of infill drilling approach mentioned earlier resulted in improved project economics due to the following:Several of new infill producers will be side-tracks instead of new wells. This can save between 20-40% of the well cost.The infill producers can re-use surface equipment and flow lines of closed in (high water cut) wells, resulting in substantial cost saving.The number of new injectors to be drilled can be significantly reduced, resulting in considerable cost saving. While not drilling these new injectors changes the sweep pattern, numerical simulation modelling has demonstrated that such impacts are small, and these additional injectors don’t pay for their cost.

The approach described in this paper has been demonstrated in the cluster and has resulted in significant production gain and cost saving. Improvement in throughput and sweep not only results in higher production, but also reduces disposal water which is good for environment. Additionally, the approach to infill drilling, which is novel in the organization, results in reduction in GHG intensity and total emissions, apart from decrease in cost and improves value.
Repurposing Wells Instead of Abandoning Them to Generate Electricity Using Geopressure
Authors: Salehabadi M. , Buang A. , Tupman B. , Bakar A. Abu , Omar A. , Tarif S. Md , Yakup M. A. Md , Mukherjee S. , Jaafar I.
Published: October 2023

There is a continues effort to search for different forms of green energy to facilitate energy transition from fossil fuels to green energy. Solar PV is currently an attractive renewable energy option to generate electricity for the considered location. However, the considered location is placed in the tropical environment with limited access to ground space. These factors limit large deployment of solar PV in the considered location justifying a need to search for alternative green way of generating electricity. Repurposing of existing oil and gas facilities instead of decommissioning them to generate electricity as an additional stream of revenue is an attractive option. It will potentially unlock a significant source of green energy to generate another stream of value by keeping the same workforces who are skillful in fossil fuel industry, using oil and gas facilities and facilitate smooth transition into net zero. The Northern part of Borneo is mainly controlled by a complex interaction between the tectonics of Southeast Asia and the deltaic systems resulted in the presence of basin wide over pressured brine formations. Drilling into such formations have been always disappointing from the hydrocarbon exploration point of view as they imply compromised traps. However, if we change our view and not necessary look for hydrocarbon as the only source of energy, then these formations can potentially provide a new source of green energy by extracting the kinetic energy from over pressured formation water. This paper presents efforts and details of a pilot trial which was planned and executed to demonstrate the concept of repurposing existing wells into electricity generators instead of abandoning them. The paper shares a workflow which can be added to an existing abandonment workflow for repurposing wells and generating electricity. The presented concept can potentially be utilized in the industry enabling concurrent electricity generation while producing hydrocarbon from existing or newly completed wells.
Novel Real-Time Artificial Intelligence Algorithm Detects Mud Motor Stalls for Automated Stall Recovery
Authors: Groh A. , Kaya M. E. , Christopher C.
Published: October 2023

Operating under harsh conditions, mud motors frequently stall, causing the rotor to seize and a buildup of torque and standpipe pressure throughout the drill string. When not recovered from correctly, this event can cause abrupt changes in drill string torque, potentially damaging the motor and other BHA components. Current recovery methods usually rely upon field crews to detect and react correctly to this event, with results depending on varying levels of training, awareness, and other factors. This paper seeks to outline a method to automatically detect mud motor stalls in real-time using machine learning. The method itself involves unique methods of representing time series data that have yet to be applied to drilling data in the literature and provides a flexible technique for pattern recognition in general.

With the assistance of subject matter experts, 200ms time series data for 100+ stalls were acquired and labeled to indicate the exact moments of a stall condition. The data itself consisted of surface values for torque, differential pressure, and other traces over which a model was developed that could successfully flag a particular instant as being in a stall. Significant effort was put towards feature engineering, and a novel application of spline regression was used to create robust features that were passed to a gradient-boosted random forest classification model to determine the probability of a stall occurring. During initial training, the model was validated against unseen stall data and achieved high (greater than 90%) precision and recall and had a reaction time superior to human operators, implying that it was a suitable candidate for integration into the control system. The model was then deployed to all rigs of this drilling contractor’s onshore rig fleet, providing a robust method for detecting even further motor stalls for additional training. The final model held acceptable performance and will be integrated into control systems to trigger automated stall recovery routines.
Enhancing Digital Twin Accuracy for Energy Efficiency and Decarbonization
Authors: White R. J. , Alhamoud A. A. , Fallatah H. A. , Elbaradie M. M. , Mulfi M. S.
Published: October 2023

The development of Production Optimization Models, exemplified by Mixed Integer Non-Linear Programming Models, aims to optimize process parameters within a network of Gas-Oil Separation Plants, ultimately resulting in minimal energy consumption while achieving production targets. The efficacy of these models hinges upon the accuracy of digital twins for compressors and pumps. This paper presents the methodology employed to ensure that the model reflects actual equipment performance. Additionally, the paper outlines a plan for introducing Artificial Intelligence (AI) into the process model to further validate and optimize production.

A process model was established for each major energy user of significance by employing the design performance curves. The model's outcomes, which included pressures, temperatures, and power consumption, were subsequently compared to actual process data retrieved from the data historian and adjusted accordingly. This was particularly crucial for equipment that exhibited considerable deviation from the original design. In some facilities, flow, pressure, or temperature data were inconsistent, prompting the calibration of the model to align it with the process data of the highest level of confidence. Additionally, process data was utilized to estimate the facility's backpressure in the absence of a hydraulic model. Changes made to the system were validated by examining the accuracy of the system curves, which were accomplished by matching predicted outcomes with actual results.

The implementation of precisely calibrated digital twins within the process model significantly improved the Production Optimization Models’ ability to forecast the ideal distribution of production. The model's output corresponded closely with the actual energy consumption of the facility, resulting in considerable savings in energy consumption and costs, as well as a reduction in CO2 emissions. As equipment performance is known to evolve over time due to factors such as shutdowns, maintenance, and frequency of changeover, an Artificial Intelligence-based system is being developed to validate the process model and optimize it over time. Various process and equipment parameters are known to affect performance, and these will be taken into account during system development.

The process of calibrating process models through the utilization of simulation software to generate a digital twin is a critical stage in guaranteeing the accuracy of the production optimization model. This paper presents a novel approach that incorporates any observed deviations in the digital twin's performance. Furthermore, the paper introduces the concept of using Artificial Intelligence to validate the performance of rotating equipment.
Energy Sector: An Operator's Perspective on New Regulatory Frameworks for Methane Emissions Reduction
Authors: Kotsiopoulou G.
Published: October 2023

The balance between growing energy demands and global climate targets is a delicate one to maintain. The need for limiting its environmental impact has become evident to the Energy Sector, dictating higher transparency and granularity of the emissions data from operated and non-operated assets. Specifically, in the European Union, an upcoming regulation targets the reporting of methane emissions and their reduction, bringing operators to a critical crossroad, and calling for drastic reforms and actions.

For satisfying the ultimate global request for reduction of methane emissions, as a first step, a proper development of emissions data baselines is required. The new regulation offers a great opportunity and motivation for operators to deepen their understanding of their emission sources, as well as being the starting point for the collection of methane data. In this regard, as Oil & Gas operators, we need to follow an agile approach while preparing for the new era. This paper will present the integrated approach undertaken to promote, adopt and execute key incentives that positively contribute to the Company's ethical and legal compliance.

For the required methane reporting levels, source-level and site-level quantification, a full detailed inventory of assets, facilities, and wells are prerequisites, especially for quantifying fugitive emissions. This entails a challenge by itself: asset documentation, listings of equipment and components up to flange level, numerous options for storage of the inventory and many more elements need to be defined, embraced and deployed. Furthermore, measurement at each potential core methane source is essential in order to assess any emission reduction initiatives, considering that all contributions are important so that the methane intensity target of below 0.1% is achieved by 2030, as per Company's targets issued in the released annual sustainability report [Ref.2]. As anticipated, the rising demand for methane measurements has led to a plethora of available, new, and improved, technologies and methodologies. Therefore, via a large number of performed pilot tests it was imperative to evaluate the different solutions at diverse facilities in terms of their automation level, age, type and location in order to finally determine the most favorable solution for different scenarios, and ultimately build the overall strategy for the Energy division's portfolio.

This paper portrays the steps involved in adopting a new strategy for methane measurement, monitoring, reporting and emissions reduction. Furthermore, it contains the lessons learnt from the pilot tests, covering experience with different technologies, big data management and the potential "automated" workflows to support the future data acquisition, integration, contextualization, and visualization.
First Application of Hybrid Bit Technology to Drill Abrasive and Massive Cherts in Long Interval Section, Reaching Successfully the Target in One Run in Unconventional Gas Field, ADNOC Onshore UAE
Authors: Ruiz F. , Elzeky M. , Al-Rahma R. , Anumba C. , Eldeiry A. , Abdelhamid M. , Nunez Y. , Kumar R. , Kamble R. , Ibrahim M. , Sas M. , Baruno A. , Anwar M. , Hamdy I. , AL Shamisi E. , Sumaida A. Bin , Shamlan A. Bin , Kirby C. , Coscia M. , El Yossef B.
Published: October 2023

This paper outlines the creation, implementation, execution, and assessment of the first 16" usage of a hybrid bit on a rotary steerable system for drilling lengthy interbedded formations with up to 50% of abrasive cherts in Unconventional Gas reservoirs.

The main hurdle overcome by the solution was drilling through the tough layers of chert while steering clear of trips caused by damage to the PDC bit or time constraints of Tricone Bit Inserts. Furthermore, it improved the overall drilling speed (ROP) and met the necessary directionality. This solution proved superior in ROP compared to rollercone bits, in addition to enhancing PDC cutter durability and decreasing reactive torque, leading to improved steering and stability, which will be further explored in this paper.

A key element to the success was the use of a new hybrid bit technology that combines the cutting methods of both Polycrystalline Diamond Compact (PDC) and rollercone bits. This allowed for more efficient drilling by employing the robust crushing action of rollercone to penetrate tough interbedded rock layers and the effective shearing action of PDC cutters to boost ROP without compromising the toughness of the cutting structure's edge.

Combined with the continuous proportional rotary steering system, the proposed solution successfully drilled a footage of 7,018 ft through a mixed formation with chert nodules, achieving an average ROP of 47 ft/hr. It reached the casing point in a single run, eliminating the need for additional trips using rollercone bits to drill through the sizable cherts and preventing damage to the PDC bit.

This resulted in a 30% cost reduction per foot. Furthermore, the hybrid bit outperformed expectations, accomplishing 1.49 million revolutions, with an efficient bearing and well-preserved drilling cutting structure. The directional goals were also achieved with high-quality directional drilling that avoided colliding with neighboring wells. This success was made possible through careful analysis, creating drilling plans for specific formations, and optimizing drilling parameters for improved overall efficiency.

The incorporation of rollercone and PDC components in a hybrid bit, specifically designed for better efficiency and torque stability, greatly improved drilling performance by completing the section in one single run. This confirms that varied rock formations can be drilled end to end.
Integrity Challenges and Damage Mechanisms Affecting Storage Tanks Bottom Plates: Implementation of Cost-Effective Mitigation and Control
Authors: Ameri Saleh Salem Al , Nair Ajiv Mohan , Pattali Jayadevan
Published: October 2023

This submission studies severe corrosion observed underneath oil storage tanks (Above Ground Storage Tank -AST) bottom plates from the external soil side. Monitoring and measurement of corrosion mechanisms in this context remains challenging for Integrity professionals due to limitations in effective monitoring technologies and measuring such corrosion. The propagation of such corrosion remains unpredictable and can be catastrophic considering associated impacts such as Loss of primary containment, HSE, environmental Impacts, production losses and institution reputation.

Inadvertent failure on AST's used for millions of barrels of oil storage will turn out catastrophic resulting in production and operational impact as such equipment's are categorized as critical safety equipment. This case study focuses on the failure of AST bottom plate constructed as per API650 on the concrete ring wall foundation. The bottom is plate placed over soil and protected with a grid anode cathodic protection system with an expected design life of more than 30 years. However, the tanks were observed with severe soil side corrosion including through holes during the inspection within a mere 10 years from commissioning. This study delves into various factors contributing to the damage mechanism of tank bottom plates such as shortfalls in design, poor quality controls during construction, limitation of monitoring methodology etc. In addition, the study provides some recommendations on mitigation programs. This study report delineates the cases of three above-ground storage tank bottom plates with similar construction and operating envelopes that underwent off- stream inspection. This report aims to shed light on the causes and consequences of severe corrosion in AST bottom plates and offer practical recommendations for mitigating these risks.
A Novel and Innovative Flare Gas Recovery Solution - From Waste to Value
Authors: Muthalaly Mathen , Harthy Fatma , Mihajlov Rodoljub , Hadhrami Abdullah
Published: October 2023

South Oman Sour Cluster facilities have historically recorded high rates of non-routine flaring representing the largest volumes within the company. Non-routine flaring is mainly attributed to lower system availability and is inclusive of safety flaring. This paper describes a novel and innovative Flare Gas Recovery (FGR) solution using new flue gas treatment technology that is designed to convert waste flare gas to value and thereby reduce Green House Gas Emission (GHGE) footprint significantly within the company/Oman.

Non-routine Flaring in the cluster has been reduced recently via ongoing initiatives but there do remain substantial flaring volumes. As part of decarbonisation initiatives, the cluster in collaboration with technology vendors assessed wide range of potential FGR solutions. Flare to Power has been established as the most optimum solution to effectively handle non-routine flaring scenarios. Novel flue gas treatment technologies have been identified which is integrated and deployed along with this solution to ensure all harmful emissions are cleaned and valuable byproducts (CO2 and fertilizers) are generated which are being commercialized to make these projects technically and economically attractive.

The proposed FGR solution will reduce the cluster GHGE by ~510 k tons of CO2e per year by recovering the flare gas which would otherwise have been burned in flare stack and converting it into valuable commercial products. The flare gas is either converted to power to be fed into existing grid or is partially exported to existing gas pipelines based on available infrastructure at respective facilities. Acid Gas flare streams are burned in incinerators and the exhaust gas from these along with those from power generation are cleaned up in the new technology flue gas treatment units wherein harmful emissions like SOx is converted to fertilizers, CH4 is broken down into CO2 and water, NOx is removed and finally all CO2 is captured. The fertilizers and bottled CO2 are sold in the market to generate revenue for the project. These FGR projects hence have attractive UTC with positive NPV.

Novel flue gas treatment technologies are being deployed where harmful emissions are cleaned, and valuable byproducts (CO2 and fertilizers) are generated which are being commercialized. The flue gas treatment technology will have much wider applications to reduce GHGE footprint from power plants, gas fired equipment’s and other industrial applications thereby significantly helping in accelerating the clean energy transition in a cost effective manner.
Hydrogen as a Futuristic Solution to Energy Poverty in Eastern Europe - Case Study of Greece
Authors: Aluko A. O. , Odularu G. O. , Suleymanli L
Published: October 2023

Using Greece as a case study, this article explores the use of hydrogen as a futuristic panacea for energy poverty in Eastern Europe. The evidence from peer-review literature and the preliminary research questionnaire survey of 197 respondents from different Eastern European countries; shows that there is a futuristic prospect for hydrogen in becoming one of the innovative solutions to energy poverty. This research further explores the possible hindrances of practical affordability, reliability, and sustainability of hydrogen energy sources in ending energy poverty. The SPSS preliminary result presents 57.4% of the total 197 respondents who depict that the household income for many citizens of Eastern European countries is within the total budget of 20000-30000 Euros per annum regardless of the population within the household. The results further justify that 60.4% of the questionnaire respondents within Eastern European and Greece probably do not have a well-paying profession or careers that can enhance the affordability and accessibility of clean energy such as hydrogen. The accessibility, cost-efficiency and dependability of hydrogen as an energy solution has the potential to combat energy poverty, a situation with dire and far-reaching consequences for quality of life, health, social and economic development. The social exclusions and limitations to economic development and opportunities energy poverty causes guides the need for this study's focus on leveraging hydrogen in efforts at achieving SDG 7.
Selection of Acid Types to Achieve Uniform Stimulation in Long Laterals of Horizontal Wells
Authors: Huifeng Liu , Ning Xu , Qi Liu , Hongzhao Tian , Yue Ming , Zhangxin Chen
Published: October 2023

Horizontal wells with long laterals are being used to develop low-permeability carbonate reservoirs in the world. After completion of a well, acidizing is usually conducted to remove the potential damage caused by drilling and completion. However, in bullheading acid injection, it is usually difficult for the acid to distribute evenly along a lateral due to quick consumption of acid along the wellbore, especially in MRC (Maximum Reservoir Contact) wells or wells with long laterals (>1000m). In many cases the toe area is even left un-stimulated at all.

Different types of retarded acids are being developed in industry to reduce acid consumption rate in order to let them penetrate further, but the effective travelling distances of these acids are never systemically studied and compared, leaving field engineers a difficulty in selecting an acid for a specific well. In our work, the properties of different types of acids in industry are reviewed. A flow and reaction model with consideration of acid flow friction and acid-rock reaction kinetics is established and a method is found to solve it. Five typical cases are run based on the model and the results of an effective acid flowing distance, effective acid reacting distance and effective acid travelling distance are obtained and compared.

Based on our study, two principles of selecting acid types for horizontal wells with long laterals are proposed: "flow to the toe" and "react to the toe", which mean the friction of an acid as well as the leak off rate of the acid should be small enough to let the fluid reach the toe under a given injection rate; the diffusion rate of H+ and the acid-rock reaction rate must be small enough to ensure that the acid is still active when it reaches the toe. Four key considerations are proposed regarding acid type selection: acid flow friction, acid leak off rate, mass transfer of H+, and acid-rock reaction rate. A general guideline for the key parameter control and acid type selection to achieve a good acid distribution in the wellbore under different conditions is also shown. Field engineers can use our guideline to select acid candidates initially, and then use our model and program to quantitatively evaluate if the acid can effectively cover the whole lateral length.
Corrosion Under Insulation: Detection and Rectification
Authors: Priyadarshan Amit , Kumar Ashutoh
Published: October 2023

Corrosion Under Insulation (CUI) is a critical issue in the oil and gas sector, specifically in industrial piping systems. The conventional assessment methods used to evaluate insulation materials often focus solely on individual laboratory tests, neglecting the assessment of the entire applied system. Additionally, the physical values obtained from these tests may not accurately represent the potential influence of insulation materials or systems on the risk of CUI [1].

This paper proposes a more advanced approach that takes into account not only the applied insulation system but also the behavior of CUI failures and the processes of water or water vapor ingress and retention. By integrating these factors, individual risk assessments of applied insulation systems can be conducted under different water ingress scenarios. Furthermore, factors such as insulation configuration, types of materials, aluminum barrier foils, outside claddings, and construction or installation methods also influence the risk assessment.

Understanding the underlying conditions that promote CUI and identifying vulnerable areas within the infrastructure are crucial for establishing an effective CUI management program. This paper aims to enhance readers’ understanding of insulation materials and their impact on CUI risk. By utilizing the proposed approach, readers will be able to identify susceptible areas in their facilities and develop appropriate CUI management strategies [2].

Advanced inspection techniques tailored for CUI detection, such as guided wave ultrasonics and thermography, can significantly enhance the effectiveness of CUI programs. These techniques enable targeted inspections and monitoring of critical areas, facilitating early detection of CUI-related issues and allowing for timely interventions.

This research contributes to the field of CUI risk assessment in the oil and gas sector by presenting a comprehensive methodology that surpasses traditional approaches. It emphasizes the importance of considering the entire applied insulation system and the specific factors influencing CUI risk. By recognizing the challenges posed by CUI, understanding its causes, and implementing comprehensive CUI programs, the oil and gas industry can effectively mitigate the risks associated with CUI-induced failures. This paper serves as a call to action for industry professionals to prioritize CUI management as an integral part of asset integrity and environmental stewardship. By shedding light on the importance of insulation materials and systems in mitigating CUI, this paper seeks to enhance industry knowledge and promote informed decision-making. It emphasizes the need for comprehensive insulation strategies that effectively protect against corrosion, improve asset lifespan, and safeguard operational efficiency and safety in the oil and gas sector.
Enhancing Red Zone Management and Operational Excellence in HWU Rig Operations Through Digitalization Using Real-Time CCTV Monitoring with Artificial Intelligence
Authors: Abdul Hamid A. , Ahmad T. , Majid Bin Allapitchai M. , Sellapan S. , Arumugam S. , Redzuan S. B. , Mohd Effendi S. , Abdul Razak M.
Published: October 2023

Real-time monitoring through CCTV is a crucial aspect of offshore operations in all types of rigs. While this system is widely utilized in conventional drilling rigs, it is not as commonly used in hydraulic workover unit (HWU) rig and this create a huge gap in Red Zone Management and Operation Excellence in term of efficiency. The primary purpose of this system is to enhance red zone management, increase operational efficiency, and allow for remote operation or supervision.

Recently, this system was implemented for workover operations in Malaysia that utilized an HWU rig. Six ATEX-rated cameras were installed in critical areas of the HWU rig and the accommodation work barge (AWB). ATEX rated are required to comply Zone 2 requirement. A detailed site survey and engineering were conducted to install these cameras, which had never been installed before on an HWU rig. The system is wired, requiring a long cable connection from the HWU rig on the platform to the AWB and supervisor office. Additionally, it is connected to the project team's mobile devices, allowing for real-time monitoring, and enabling the team to observe operations from onshore.

This system provides supervisors with improved supervision of offshore operations, equipment movement, and HSE supervision. Prior to its implementation, supervisors only had voice communication via walkie-talkie and no visual access to the operation from the supervisor's office. Furthermore, engineers in the office and service providers can observe the operation, especially during critical jobs. The system also aids in HSE case investigation by providing footage for the investigation team to review using its playback feature.

This pilot system closes a significant gap in the HWU rig, improving red zone management, increasing operational efficiency, and allowing for remote operation or supervision. This paper outlines the system's functionalities, installation and engineering procedures, detailed implementation, and the future scope of artificial intelligence in closing gaps in terms of HSE and operation.
Managing New Development Uncertainty with Scenarios and Multiscale Modelling: An Integrated Study of the Fogelberg Discovery
Authors: Mullins James R. , Mendez Maria , Bajan Luka , Rocher Dimitri , Spitzmüller Adam , Marsh Tom , Berntsen Bjørn A.
Published: October 2023

Recent hydrocarbon developments are generally characterised by high complexity and uncertainty with lower margins for error in an unpredictable financial market. This is further compounded by new oil and gas discoveries being typically smaller today, than in the past; highlighting the need for robust and fit-for-purpose reservoir models that accurately capture key uncertainties to inform management decisions and to help avoid substantial financial losses.

To make an informed decision on either field development or relinquishment of the Fogelberg production license on the Norwegian Continental Shelf (NCS), an alternative full field reservoir model was commissioned by one of the License partners of a complex stacked tidal bar system in the Norwegian Sea. The model includes an accurate representation of the underlying heterogeneities observed in a drill stem test (DST) performed in 2018, incorporating the spatial evolution of the tidal bar system including the placement of low permeability inter-bars to stylolitisation at core-plug scale. Furthermore, the model is robust enough to permit future forecasting and well planning required to enable a management decision.

A scenario-based modelling approach (after Bentley and Smith, 2008) based on three discrete concepts was undertaken, accounting for uncertainty in the spatial geometry of the tidal bar complexes. This approach was combined with a hierarchical modelling strategy to honour the depositional concept model and to provide modelling flexibility. Sub-cell resolution heterogeneity in the form of stylolites that were prevalent in cored intervals were incorporated using a multi-scale approach in the form of a representative elementary volume (REV). A full uncertainty ensemble was generated for each of the three modelling scenarios.

The model produced a robust match to the bottom hole pressure (BHP) reported during the DST and was used to generate production potential and optimize lower completion strategy, including a side-by-side comparison of recovery of horizontal wells with fishbone stimulation, hydraulic fracturing stimulation and unstimulated slotted liner completions. Based on new static and dynamic understanding of the reservoir, the license will be re-applied for with a view to future development.

This paper highlights the importance of managing uncertainty through the use of scenarios, their flexibility with ensembles and the use of a multi-scale approach to accurately represent the respective lengths at which heterogeneities occur to build a better knowledge of the subsurface. The work undertaken for this petroleum system is both highly relevant and transferable for the future transition of safe and permanent storage of carbon, hydrogen and nuclear storage.
Application of 4D Geomechanical Modelling for Fault Critical Re-Active Stress Evaluation in CO2 Storage
Authors: He Xinxing , Zhou Wei , Tang Yongliang , Chen Dong , Huang Zhaotin , Xu Hanbing , Lian Liming , Cheng Ronghong , Chen Xiaobo , Fu Ying , Wu Yongping , Wu Mimi , Qiao Xia , Wang Yandong , Feng Guang , Xu Zhenzhen
Published: October 2023

In order to provide effective guidance for optimizing and adjusting the maximum operation pressure and dynamic monitoring well pattern of underground gas storages and ensure the operation safety of gas storages. With the continuous enhancement demand for resources is also growing. At the same time, with the rapid development of industry, the industrial waste gas led by CO2 has also caused great harm to the environment. Therefore, to solve the above two problems, it is crucial to accelerate the construction of underground gas storage, safe and efficient extraction of oil and gas reservoirs, and geological storage of CO2. As a critical technology for the construction of underground gas storage, oil and gas field exploitation, and geological storage of CO2, many scholars have carried out research on fault stability in terms of complex stratigraphic stress environment, lithologic contrasts on both sides of the fault, mudstone smear content, fracture mechanics and so on, and have made many vital understandings and progresses. However, with the development of oil and gas fields and geological sequestration of CO2, the problem of fault destabilization caused by fluid injection, leading to fault activation and, thus, oil and gas leakage, has become increasingly prominent. Fault destabilization activation will not only form a possible path for oil and gas leakage and cause fault seal failure but also may cause a series of safety problems. There have been many major oil and gas leaks caused by fault slipping at home and abroad, resulting in many casualties and property damage. Therefore, studying the fault activation and seal failure caused by fluid injection is urgent.
Minimizing Geological Core Destructive Analysis Using Machine Learning
Authors: Mezghani M. , Tao L.
Published: October 2023

The core analysis program we developed is based on artificial intelligence (AI) and aims to complement conventional core analysis methods for the measurement of rock properties. This program offers several advantages over traditional destructive analyses.

Firstly, the program allows for non-destructive analysis of rock samples. This means that the rock samples are not completely destroyed during the analysis process, allowing for their potential use in further studies or for future reference.

Secondly, the AI-based program is capable of conducting a large number of analyses, overcoming the restriction on the number of measurements that can be conducted using conventional core analysis. This enables a more comprehensive understanding of the rock properties, improves the accuracy of the results, and therefore reduces the subsurface modeling uncertainties.
Uncertainty and Sensitivity of Permeability Models
Authors: Farmer Russell
Published: October 2023

Quantifying and managing uncertainty leads to improved project and business performance, robust decision making, increased chance of success, fewer surprises and optimised reservoir characterisation outcomes. Informed decisions will be robust to risk and increase the likelihood of an outcome that delivers promised production from a well or development.

Petrophysicists have a crucial role in delivering an appropriate product for estimating productivity and its' uncertainty can have a significant impact on exploration, appraisal, and development project economics. This is particularly the case when estimating permeability and permeability thickness (kh) which are fundamental to predict robust productivity rates for wells.

When using core to build log-based permeability models, many issues need to be addressed, some of which may be significant. This paper supports an assessment of other factors that may contribute to variability between core, model estimates and well performance, but is primarily focused on a rapid screening of irreducible uncertainty and sensitivity as opposed to rebuilding a new model.

Quantifying the sensitivity and uncertainty of model estimates of permeability provides a framework to optimise reservoir management challenges and a workflow to screen for differences that contribute to sensitivity and ranges of permeability in individual cored wells and as a predictor in uncored wells.

for setting expectations (irreducible uncertainty), estimating ranges for undrilled reservoir and infill targets identifying other factors that may be significant in well and reservoir performance supporting optimised reservoir management indicating the potential benefits and value of additional data acquisition.
Transforming Decision Making in Carbonate Matrix Acidization Domain
Authors: Chandola Gaurav , Panga Mohan K. R. , Ugursal Assiya , Kumar Amit , Garima Garima , Chen Yang
Published: October 2023

Acid stimulation treatments are typically designed using a combination of experience, available field/lab testing data and a stimulation design software that ties it all together. The final design, given the large degrees of uncertainty, requires multiple iterations to arrive at the (near) optimum stimulation design. To account for the large number of variables and their uncertainty, a framework and associated tools have been developed for automating and optimizing the design process that allow to significantly reduce the optimization time. The adopted approach leverages modern web applications for overcoming the limitations associated with the legacy stimulation design tools. Python Dash is used for creating an interactive web application, allowing users to load a file containing all necessary inputs for the calculation and specify the ranges for different design parameters. The web app then generates a parameter space and spawns multiple parallel runs of the calculation engine. An optimization module utilizing existing python optimization libraries is developed within the web app framework, which guides the selection of the next sample point in the parameter space after each iteration until the optimum point is reached. After implementing this framework across multiple workflows, considerable improvements have been realized with time savings ranging from hours to days. A detailed case study is presented to demonstrate the application of the framework for designing a Limited Entry Liner (LELs) completion, where the nozzle distribution in different reservoir sections (compartments) is varied to achieve a desired acid placement into the formation and improve stimulation efficiency.
New Technologies and Practices to Enable Remote Operations, Increasing Complex Long Multilateral Horizontal Wells and Enriching Project Sustainability and Efficiency: A Real Case from Northern Europe
Authors: Dixit A. , Bang M. , Gonzalez R. , Inge Andresen O. , Stangeland T.
Published: October 2023

While many global energy transitions have happened throughout history, today we need to satisfy the world's growing demand for energy while contributing to deliver energy in a cleaner, safer and continuously more efficient way. This paper looks into how the latest multilateral wells delivered, achieved the well targets by choosing optimized solutions to deliver on efficiency and accuracy from planning to execution. Using the latest digitalization and automation technology, along with recent developments on advanced rotary steerable systems (RSS), low friction water-based mud and extended life drill bits, has played a major role in relocating most of the service company personnel from rig site to remote operations centers. Relocating personnel has reduced exposure at rigsite and thereby reduced health, safety and environment risks and carbon footprint, while continuously improving operational performance. This is achieved through close collaboration between different subject matter experts in the same geographical location, enabling collaboration during follow up of multiple operations and improving the overall project executionWe will detail how successfully drilled 6624m horizontally in one run within the well target in the reservoir and without any HS&E incident. The services were run from a remote operations center with minimum personnel at the rig site. The rotations per minute (RPM) were optimized to reduce high frequency torsional oscillation (HFTO) vibration. No severe whirl was observed which is common in long tangent sections. The run ended in the top 5 fastest average ROP for the field and achieved the longest bit run in the same field. Moreover, due to running the operation remotely, it saved in transport to and from rig site, enabling an estimated of 697,261kg in savings of equivalent CO2.

This outstanding result was achieved by incorporating technology across multiple product lines, enhancing performance, reducing cost and risk associated with several bit-runs and improving effective wellbore placement. The aim of this paper is to present how new ways of working to manage projects by continuous improvement in technology, automation, digitalization enables energy deliveries in a safer, more efficient and sustainable way.
Diagnosis of GOR Evolution in Carbonate Reservoir, Offshore Abu Dhabi, Undergoing a Major Miscible Gas Injection Operation
Authors: Khan M. N. , Mogensen K. , Sainz A.
Published: October 2023

One of the largest miscible gas injection operations worldwide is currently being conducted in an offshore carbonate field located in Abu Dhabi, which has a near-critical fluid system. Throughout the production process, there is an observed gradual increase in the gas-oil ratio (GOR) in ‘Reservoir A’. The evolution of the gas-oil ratio (GOR) may be attributed to various physical mechanisms, including production below the bubble point, gas coning, or the breakthrough of miscible gas. In the latter scenario, there exists ambiguity regarding the extent to which reservoir dispersion has caused the diffusion of the miscible displacement front, potentially leading to a loss of miscibility. The primary aim of this study was to assess the GOR response through the utilization of numerical simulation and other analytical techniques.

A producer-injector pair was utilized in a numerical simulation to investigate various scenarios, including: (1) production below the bubble point; (2) gas coning originating from the gas cap; (3) a perfect miscible displacement; (4) a perfect immiscible displacement; (5) a miscible displacement that transitions to immiscible due to dispersion; (6) a combination of the aforementioned scenarios. The primary output parameters monitored encompassed the gas-oil ratio (GOR) and the flowing bottom pressure at the producer. Subsequently, various runs were compared to each other and in relation to the observed gas-oil ratio (GOR) response.

A surveillance strategy that was suitable for the intended purpose was implemented in order to evaluate the efficacy of the overall development strategy. The results of recent production logging tool (PLT) tests conducted at different choke sizes revealed no evidences of free gas production downhole. The utilization of inline multiphase flowmeters has been deemed essential in capturing the evolutionary trends of gas-oil ratio (GOR). The primary factor contributing to the evolution of gas-oil ratio (GOR) was determined to be the oil swelling resulting from miscibility, as observed through the comparison of simulation-based type curves with the GOR trend.

In addition, it has been suggested that regular monitoring of compositional ratios (C1/C2+C3) should be conducted alongside the ongoing inter-well tracer campaign. This will provide an enhanced ability to anticipate and track the movement of the gas front within the reservoir. Optimizing the gas injection pattern and oil production offtake is crucial in order to enhance sweep efficiency.