bluuebunny/crossref_metadata_2025 huggingface dataset:
Integrating Seismic Inversion with Machine Learning for Porosity Cube Estimation: A Synergistic Approach
Authors: Rauf R. , Zubair B. , Vega E. G.
Published: November 2024

This study investigates porosity prediction by integrating seismic inversion with machine learning, employing chi angle-based and Acoustic Impedance (AI) cube-based techniques to estimate porosity values. A systematic approach involving data collection, preprocessing, and seismic inversion is utilized to extract rock property information crucial for accurate subsurface characterization. Advanced machine learning models are developed and rigorously trained on diverse, relevant datasets, with porosity estimated using both methodologies. The efficacy of these methods is thoroughly evaluated through cross-validation and comparison with well-log data, ensuring robust validation. Results indicate that the chi angle-based method excels in capturing subtle, intricate patterns for precise porosity predictions, particularly in complex geological environments, while the AI cube-based method provides robust and reliable predictions across diverse geological settings. A detailed comparative analysis highlights the complementary nature of these two techniques, showing how their integration enhances porosity characterization, providing deeper insights than traditional methods alone. This innovative approach offers valuable insights for subsurface exploration and reservoir management, emphasizing the significant benefits of combining seismic inversion with machine learning for improved porosity prediction, enhanced accuracy in reservoir assessment, and more informed decision-making in exploration and production strategies.
Fiscal Allocation of Partially Stabilized Crude Oil for Marginal Fields
Authors: Saadawi H. , Al Mheiri F.
Published: November 2024

Al Dhafra Petroleum operates marginal fields in remote desert locations southeast of Abu Dhabi. Produced fluids are exported via a multiphase flow pipeline to a nearby sister company for further processing. Multiphase Flowmeters (MPFMs) are used for fiscal allocation. The MPFMs have their limitations and inherent accuracy in flow measurement. A 10 % deduction on oil production was applied for fiscal allocation between the companies.

To enhance fiscal measurement accuracy, new facilities for measurement of single-phase partially stabilized crude oil were recently implemented. The facilities were commissioned in January 2023 and are currently operational and used for custody transfer between the two companies.

This paper addresses the experience gained from this unique application. The approach and methodology adopted in measuring the partially stabilized crude oil are described. Testing, calibration, and proof of the new metering facilities are also discussed. Based on the experience discussed here, measurement of partially stabilized crude outlet from a 3-phase separator offers a reliable alternative to MPFMs by largely reducing the uncertainty, or inaccuracies, associated with measuring multiphase flow.
Challenges Overcome and Lessons Learned: Knowledge Acumens from Drilling Geothermal Wells in Turkey
Authors: Birinci S. B. , Merey M. G. , Buyukekinci O. , Bukhamseen R.
Published: November 2024

This paper provides an overview of the extensive geothermal drilling activities in Turkey. Based on the large-scale data obtained in Turkey, the study identifies and classifies the challenges and risks that have been faced during drilling according to the risk severity and repetition frequency. The main challenges that have been encountered can be grouped into several categories: formation/lithology, equipment requirements, excessive vibration levels, and high temperature. Due to the fractured nature of the metamorphic formations, partial or full losses have been faced frequently, which increases the possibility of stuck pipe issues. Directional control and the hole geometry are frequently affected by the strong formation dips, requiring extensive directional planning and detailed offset well analysis. Moreover, since the stratigraphy is interbedded with heterogeneous and hard formations that act like a "stinger", the bit choice and drilling parameter evaluation possess extra caution and necessitate point-by-point analysis. In addition, these formations are severely abrasive and require a high level of tool quality, especially coating-wise. Downhole drilling temperatures up to 180 degrees Celsius require service companies to utilize more durable seals, sensors, and materials. Extreme levels of vibrations and shocks above 100G may be faced during drilling, causing a lower rate of penetration. Results show that extensive off-set well analysis, utilization of vibration mitigation tools, cooling procedures, proper bit and directional equipment selection, and certain stuck pipe practices may minimize the risks involved while drilling geothermal wells, especially in metamorphic rocks.
Smart Alarm Management Framework for Gas Condensate Field Surveillance and Production Optimization
Authors: Alsaeedi Ayesha , Alhammadi Maryam , Alhammadi Rashed , Albadi Mohamed , Alzeyoudi Mohamed , Alharethi Fahed , Konkati Sarath , Jani Mansi , Siddiqui Sameer
Published: November 2024

With the industry’s drive to move toward smart field implementation, data-driven surveillance and monitoring have become the need of the hour. Especially, for large matured and depleting reservoirs with well deliverability sensitive and deteriorates rapidly. This paper elaborates on the smart alarm management system to make surveillance and monitoring more efficient to overcome suboptimal production and well downtime reduction.

To support the critical and tedious daily task of surveillance and monitoring wells for large, depleted fields, a smart alarm management system was created within the Integrated Asset Operation Model (IAOM) solution. The alarm management was implemented in three different categories, such as

Category-1 (Real-time alarm): These alarms are based on the real-time parameters from the field sensors (via real-time data source). Category-2 (Setpoint alarm): These alarms are based on the well’s operating point parameters. Category-3 (Custom intelligent alarm): These are user-defined alarms that are created in the conjugation of measured and physics-based tuned models.

The smart alarm management system facilitated efficiently and proactively the identification of the wells with suboptimal well performance either due to external factors (facility bottlenecks) or due to well deliverability deterioration. The alarm management system was able to highlight the wells for different categories.

Category-1 (Real-time alarm): Identified wells with small delta pressure across the choke suffering from high backpressure. Category-2 (Setpoint alarm): Identified wells with a large deviation between estimated volumes and the measured daily production volume. Thus, identifying the instrumentation issue in the field. Category-3 (Custom intelligent alarm): Identification of the wells with suboptimal well deliverability as the well was suffering from liquid loading

The alarm management system on a daily basis sends an email notification to all the stakeholders with a summary of the alarm wells along with the brief details of the alarm. Advanced dashboards report provided systematic information, and guide users' engineering judgment to take preventive decisions.

Advanced action tracking (operation management system) was utilized to plan and execute the remedial action. Well’s downtime time was reduced, and significant production improvements were observed for these wells, thereby leading to a tangible reduction in cost and time.

Using the smart alarm management system under the IAOM provides tools to identify wells that are currently demonstrating sub-optimal well performance and might even cause cease to flow conditions. Thus, utilizing the integrated framework in taking a proactive remedial reduces loss in production and also acts as a guideline while optimizing the gas production.
Surgical Mapping of Subtle Carbonate Trap Plays at a Jurassic Intrashelf Basin Margin Using Seismic Chronostratigraphy and Semi-Automatic Techniques
Authors: Wharton S. R.
Published: November 2024

The search for elusive and subtle carbonate stratigraphic traps on the Arabian carbonate platform in the Middle East continues apace to bolster oil and gas exploration in the supply of energy to the world. To support this search for exploration plays within basin-wide intrashelf basins that transcend international boundaries, significant strides are made applying innovative technologies during exploration phases. A surgical mapping procedure is presented to investigate subtle, grainstone-dominated, stratigraphic traps and associated geobodies across prograding systems of a section of a wider Arabian Platform intrashelf basin. The aim is to apply innovative, integrated, seismic and well log analytical techniques, utilizing Machine Learning algorithms and sequence stratigraphy principles, to locate subtle, grainstone-dominated reservoir sequences that trend across a platform margin, to deeper water settings. A reprocessed, post-stack, 3D seismic volume is integrated with core and biostratigraphy data targeting stacked, composite sequences. Key regional unconformities, well cores, biostratigraphy and electrofacies log data from seven wells, are tied to seismic data to deconstruct the architecture of key depositional sequences. A seismic chronostratigraphy cube is generated from dense sets of horizons throughout the seismic. Selected horizons in Relative Geological Time (RGT) are targeted within the seismic chronostratigraphy cube for detailed assessment using Unsupervised Seismic facies, Spectral Decomposition and Curvature seismic attribute analyses tied to electrofacies well log data.
First Multilateral Well Drilled in Under Balanced Manner within ADNOC Group with Successful Trials Of UBCTD
Authors: Zain Fawad , Deshmukh Rohit V. , Almteiri Nama , Baslaib Mohamed Ahmed , Osama Mohamed , Mantilla Alfonso , Solaiman Tarek , Alzeyoudi Mona , Jayeoula Abiodun , Elshehat Ayman , Abdulsalam Fouad , Mengal Salman , Alshehhi Hajar
Published: November 2024

Objectives/Scope

Exploring the frontiers of exploration, ADNOC Onshore's ASR Team has pioneered the use of Underbalanced Coiled Tubing Drilling (UBCTD) within the entirety of the ADNOC Group, further extending its application to a multilateral well. This technique reduces reservoir impairment resulting from overbalanced drilling conditions and employs coiled tubing instead of a traditional drill rig. The operation realized a remarkable total drilled footage of 11,422 ft, overcoming the technical and safety challenges associated with drilling in an environment containing sour gas with a concentration of 6% H2S.

Methods, Procedures, Process

The initiative involved exploiting the UBCTD approach for tapping into sour gas deposits, a first for any ADNOC entity. A multitude of stages such as selecting appropriate sites, intricate engineering planning, optimizing well designs, comprehensive risk assessments, the tendering process, recruitment of services, standard drilling operations, connections, and finally, CT drilling took place. The adoption of UBCTD facilitated a safer and more efficient drilling method, allowing for continuous production testing and directional steering while drilling. By creating triple lateral wells, the project not only enhanced reservoir exposure but also cemented UBCTD's efficacy compared to other examined technologies on these specific gas reservoirs.

Results, Observations, Conclusions

ADNOC, a dominant force in energy resources, adopted the UBCTD method to access reservoir sections without most conventional logging tools. This innovative drilling technique offers several benefits including reducing formation damage, enhancing well productivity and recovery rates, achieving ideal drainage lengths, decreasing completion times, and elevating net present value. Despite initial apprehensions owing to inexperience and perceived risks, the inaugural implementation of UBCTD within the ADNOC conglomerate signifies a leap forward, particularly for re-entry and new sour gas wells where traditional underbalanced drilling is constrained. Notably, UBCTD is gaining global acceptance for its efficiency in both new wells and revisiting existing ones with the goal of maximum resource extraction.

Novel/Additive Information

The document will delineate a comprehensive procedure used in orchestrating the unique Multilateral CTUBD venture for ADNOC Group, highlighting operational and HSE factors that contributed substantially to the accomplishment of this groundbreaking project.
Habshan Seismic Stratigraphy Framework to Reveal Stratigraphic Play Potential in Southeast Abu Dhabi, UAE
Authors: Kim Dongoh , Yoo Seunghak , Di Simone Salvatore
Published: November 2024

The Lower Cretaceous (Berriasian to Valanginian) of Southeast Abu Dhabi, U.A.E. consists of a large carbonate platform system and the Habshan Formation is a major carbonate reservoir in the region, hosting significant hydrocarbon potential with more than 1,000 feet in reservoir thickness. The progressive nature and clinoform structures have been highlighted through many vintages of seismic imaging and previous stratigraphic studies. This underlines the necessity of understanding sequence stratigraphy to appreciate the variations and distribution of facies by the integration of all available geological and geophysical data in the study area.

Seismic data interpretation based on a high-resolution 3D survey covering more than 4,400 sq-km was conducted to identify geological features and variations in the Habshan Formation. Data-driven interpretation utilizing different types of 3D seismic attribute volumes, including acoustic impedance volume, was used to identify main cycles and their internal stratigraphic architectures. Well correlation was also conducted to build well-scale stratigraphic framework. Core, logs, and well test data were integrated to understand reservoir properties and distribution. Updated Gross Deposition Environment (GDE) maps and depositional sketches were produced through the integration of seismic data analysis, the revised stratigraphic understanding and well correlation.

A seismic-based revision of the existing sequence stratigraphic interpretation allowed for the identification of better-defined sequences and their systems tracts. The Habshan Formation is interpreted to comprise four main cycles (I, II, III and IV), while the Zakum Member represents one cycle (V). The seismic-based interpretation of the cycles is supported by core and log data and is in line with published data from various locations in Oman. The enhanced sequence stratigraphic understanding resulted in a better definition and prediction of reservoir development and distribution across the study area, by filling the gaps between the sparse available drilled wells. The study results allowed the identification of potential hydrocarbon plays in different stratigraphic settings, by highlighting the geometry and reservoir quality variations of each cycle.

This work demonstrates the role of in-depth, refined data interpretation and integration in identifying possibly overlooked subtle traps through the understanding of sequence stratigraphic signatures in seismic and well data. The results of this work can be used as a basis for the understanding and exploration of the Habshan Fm. and other similarly stratigraphically complex formations in the study area and beyond.
Assessment of CO2 Storage Capacities and Identification of Operational Risks Using Large Basin-Scale Multi-Physics Simulation on Unstructured Mesh
Authors: Chehade Philippe , Ramsay Travis , Raguenel Margaux , Gacem Mohamed , Ronot Cyril , Kloucha Chakib , Jellema Raymond , Hamon Francois , Gross Herve , Bourgeois Frederic , Kachuma Dick
Published: November 2024

The assessment of safe and permanent CO2 storage is of outmost importance to both International and National Energy Companies. Large-scale and robust geological carbon storage projects align with Net-Zero strategy of government and private companies, solidify the response to climate change, and establish entities as major global player in the advance for decarbonization. These aspirations are in line with the Paris Climate Change Agreement, and they offer major economic opportunities to elevate the national and private entities to the forefront of a nascent global decarbonization economy.

A major hurdle for geological carbon storage is ensuring that detailed numerical simulations of the CO2 plume evolutions and the induced geomechanical rock deformations demonstrate safe and permanent storage for several centuries after the injection has stopped. A multiphysics approach combining flow and geomechanics is necessary for a detailed assessment of storage capacity. Combining flow in porous media with rock mechanics over large areas (greater than 60,000 km2) and long periods of time (1,000 years) calls for advanced numerical methods and tools designed for high-performance computing. Safe storage of the injected CO2 requires detailed modelling of all physical phenomena involved in injection and trapping, and a complete risk assessment using uncertainty quantification methods calls for fast simulations. CO2 geological storage simulations must therefore quantify: The migration of the CO2 plume (saturation) and the associated pressure changes,Well performance and injectivity near injection points,Global and local changes in stress (leading to possible fault activation, cap rock fracturing),CO2 dissolution in the brine, and its mineralization,Surface expressions due to the injection, and induced seismicity risks.
Full-Scale Drilling Test Facility: Fast Field Validation of Drilling Automation Solutions
Authors: Wessling S. , Koeneke J. , Arevalo P. , Klemme V. , Schuberth F. , Biedorf R.
Published: November 2024

The worldwide land and offshore drilling fleet is implementing automated rig and bottom hole assembly (BHA) control functionality using surface and downhole data. End-user validation of automation functionality, conducted during early development, is imperative for qualification. Late-user adoption and inappropriate test environments cause lengthy and costly system adjustments and detrimentally affect end-user trust in the operational system. This paper presents the experiences and benefits of using a full-scale test rig for acceptance testing of automation functionality.

The test rig has been instrumental in shortening the time required to qualify BHAs and validate the functionality of automated features covering automated directional drilling (ADD), optimization of drilling parameters, and a variety of well protection features, such as the definition of safe operating envelopes (SOE) for surface parameters. By including a full-scale test rig in the process of technology development, the risk of downhole tools or software malfunctioning is greatly reduced. This translates into more stable deployments and avoidance of non-production time (NPT).

In the context of drilling automation applications, the test rig has enabled a faster validation of automated directional drilling (ADD) features in full control mode. This has been achieved by drilling over 2000m of pre-defined well paths covering a variety of drilling and steering scenarios. Such test deployments have enabled a faster evaluation of performance, robustness and accuracy of the overall application. For the case of advisory applications, such as rate-of-penetration (ROP) optimization and well protection, the test rig facilitates and end-to-end validation of the whole data chain including visualization. The visualization concept used by the drilling automation applications varies depending on the final user: directional driller (DD), drilling optimization engineers (DOE), and the driller. For the case of the driller, a driller’s advisory display is installed in the driller’s cabin to show target set points of surface parameters and steering commands, as well as set point limits for surface parameters and the rig equipment. Having a dedicated UI in front of the driller at the test rig provides a faster feedback loop to appraise user acceptance.
Definitive Dynamics Survey: Redefining Efficiency in Wellbore Surveys, A Novel Approach in Andaman Sea Deepwater
Authors: Firnanto Andrean , Siregar Ronny Costamte , Bonafid Kalim , Halim Hulyadi , Salim Victor , Wijayanto Timora
Published: November 2024

Since the 1960s, the oil and gas industry has utilized six-axis stationary surveys with measurement-while-drilling (MWD) technology, requiring torque and pressure release for stationary downhole surveys, leading to time wastage and increased stuck pipe risks. The innovative definitive dynamics survey (DDS) technology improves MWD efficiency by allowing definitive surveys during bottom drilling without the need for a stationary mode. This paper highlights DDS's benefits over conventional MWD, that was introduced first time in deepwater frontier exploration in the Andaman Sea – Indonesia, which is essential for cost management.

The deployment method involves comparing actual survey amounts using DDS against scenario survey amounts with ±120-ft intervals (based on rig tubular handling capability). The study focuses on evaluating the technology's benefits, as follow: eliminating static survey time; reducing the ellipsoids of uncertainty; and enhancing accuracy in determining actual trajectory (wellbore positioning and tortuosity index). Furthermore, the evaluation is performed on benefit of potential reducing the differential stuck pipe risk for future development projects with deviated well trajectories.

The result of this pioneering technology represents a significant advancement in the oil and gas sector, providing operators with key benefits such as reducing EOUs, improving rig time efficiency, and offering enhanced insights into wellbore position and tortuosity. By surpassing the limitations conventional MWD technology that required static time for surveying and provided less accurate trajectory data, this innovation emerges as a compelling replacement.

Finally, this paper validates the directional drilling survey selection method used and emphasizes the pivotal role accurate surveying technology plays in enhancing operational efficiency. In addition, DDS technology provide potential benefits for the highly deviated well development by having accurate surveying enables precise reservoir mapping, optimal well placement in geo-steering applications, reducing stuck pipe risk and enhances reservoir drainage.
Holy Grail of Offshore Decommissioning – Regulatory Approvals for Minimally Invasive, Cost Optimized Abandonment
Authors: Shaik Mohiddin , Jovan Stojkovski , Taha Nagi
Published: November 2024

Offshore decommissioning is a critical aspect of the energy industry, with significant financial implications. The forecast for offshore decommissioning expenditure from 2023 to 2032 is approximately $118 billion, with annual spending expected to exceed $14 billion by 2032. This represents about 3% of the total offshore exploration and production budget. This paper focuses on plugging and abandonment (P&A) of offshore wells, as well as the removal of platforms and subsea equipment. We explore the regulatory framework, items to be decommissioned, removal technologies, demand trends, and cost considerations.

Regarding offshore wells, new decommissioning technologies offer significant cost-saving potential, particularly within the P&A of wells, which accounts for approximately 60% of total offshore decommissioning expenditure. Key technological advancements include rigless WL, CT and HWU well P&A, highly efficient casing milling or perf wash & cement casing penetration techniques for plug placement. As for platform and subsea equipment, technological advancements also aim to remove or repurpose infrastructure, where Innovations in cutting techniques and lifting technology further contribute to cost reductions.

In terms of results and observations, delaying decommissioning spending is generally ill-advised, especially for the permanent P&A of wells. Costs can increase significantly if decommissioning is postponed by several years compared to P&A within three years after well production ends. Similarly, removal costs for platforms and subsea structures may escalate over time. Interestingly, even in regions with stringent regulations (e.g., the North Sea), obtaining approvals for technologically innovative solutions is feasible. Approaches like "rigs-to-reefs" and repurposing existing structures for renewables, CCS can lead to substantial cost reductions while ensuring environmentally sustainable outcomes.
Maximizing Efficiency: Centralized Project Material Management For Owner Operators in Oil and Gas
Authors: Kalleparambil S. A. , Mekala S. , Ibrahim A. , Granata M. M.
Published: November 2024

The demand for oil and gas remains high despite the increasing prominence of renewable energy sources, highlighting the industry's vital role in the global economy. Oil and gas projects, requiring significant capital and facing high complexity and risk, necessitate effective project management to optimize performance through agility, accurate forecasting, risk mitigation, and stakeholder collaboration (Redda, Turner, and Milano 2018; Yananto, Putro, and Sunitiyoso 2022). Leveraging data-driven approaches enhance operational efficiency, reduce costs, and support informed decision-making, which is crucial given the lengthy timelines and substantial financial commitments in this sector (Darusulistyo et al. 2022; Urton and Murray 2021).

Oil and gas projects span upstream exploration, midstream transportation, and downstream refining and distribution. Each phase presents unique challenges due to technical complexity, stringent regulatory demands, environmental considerations, and market volatility. Projects are generally managed through portfolios to enable dynamic prioritization based on scope, financial goals, risks, resource availability, and alignment with the organization's strategy and governance (Sirisomboonsuk et al. 2018). Portfolio management helps prioritize projects based on scope, financial goals, risks, and strategic alignment, improving financial performance and transparency (Sirisomboonsuk et al. 2018; Wood 2016). Major projects typically follow a stage-gate process, breaking the project into phases—Concept, Feasibility, Definition, Execution, and Operation—each marked by a gate ensuring the project is on track (Newman, Begg, and Welsh 2020; Akhtar 2020).

This paper focuses on the critical aspect of material management that spans across all project phases and relevant contribution to improve capital-project performance. Globally, 64% of projects face budget overruns, and 73% experience schedule delays with material and equipment issues as one of the primary contributors (EY 2020). Material cost is a significant component of overall construction costs, constituting 25–40% of the total cost of typical projects (Mir et al. 2021). Effective material management is integral throughout the entire project lifecycle, from initial concept and feasibility studies to the final operation and maintenance phases. By emphasizing a comprehensive and integrated approach to material management, this study aims to demonstrate how coordinated efforts across all project phases can lead to enhanced project performance, reduced costs, and improved alignment with long-term operational goals.
Specialized High Tensile Strength and Quick Disconnect Tool Used to Achieve 6,500-ft Plug Length Saves 9 Days of Rig Time
Authors: Benberber Mohammed Rebbou , De Barros Adelson Jose Calleia , De Melo Alexandre Bezerra , Iskander Mirette , Aghayarova Nargiz , Manga Patrick , Bertheux Willem Brontheis , Ledevin Pierre
Published: November 2024

Ensuring long-term integrity of the pilot hole through permanent plug and abandonment (P&A) presents challenges related to the maximum length of the plug, type of formation to be isolated, and the type of cement slurry used. The technology used to abandon an appraisal well with 6,463 ft of tubing in one operation is discussed. It highlights the use of specialized, high-tensile-strength, quick-disconnect tool in highly deviated and deep well conditions. The operation was successfully completed and saved the operator nine days of rig time.

The main challenge of the given appraisal well was to isolate a 6-in. pilot hole with 20,000 ft TD and 88° inclination. A specialized, high-tensile-strength, quick-disconnect tool with sacrificial 3.5-in. tubing was run in hole (RIH) and, after placement of cement across and inside the tubing, was successfully disconnected to leave 6,463 ft of the tubing in the hole. Because the job principle was close to the primary casing operation, centralizers were used with consideration to standoff calculations to determine eccentricity of the tubing with such inclination. To help ensure long-term isolation and minimize channeling, slurry with enhanced mechanical properties was used for cementation.

The primary purpose for the specialized, high-tensile strength quick-disconnect tool was to place a competent cement plug for P&A. Placement of the release mechanism near the top of cement (TOC) minimized contamination by avoiding swabbing of the cement plug while the work string was pulled out of the hole (POOH). The tailpipe remained in the cement plug to prevent cement contamination as the work string was POOH. The disconnect mechanism of the tool is simple and all risks were evaluated and considered during operational planning. Conventional abandonment methods consume significant rig time, including placement time, POOH time, WOC, and RIH to verify the plug to place the next one. Typical industry recommended plug length is usually no more than 1,000 ft, as considerable risk of stuck drillpipe and contamination were potential outcomes of this operation.

The successful application of the tool technology combined with the appropriate slurry design are discussed. Use of the proposed technology can help reduce well abandonment time and costs to operators as well as reduce the overall authorization for expenditure (AFE).
Deployment of Automated Hole Cleaning Advisor Increases Adoption of Drilling Automation Applications at a Global Scale
Authors: Arévalo P.
Published: November 2024

Modeling of cuttings transport has been profoundly enhanced to become the backbone of drilling automation applications dealing with well control. This paper presents the evolution and adoption of a world-leading physics-based drift flux cuttings transport model, its deployment as part of a drilling automation application validated across the globe in different environments, and the tangible benefits delivered to drilling operations.

The drift flux cuttings transport model is part of a digital twin of the wellbore and equipment deployed in real-time to continuously assess the well condition. The model has evolved over the years to become a world-leading cuttings transport model. This paper presents the continuous development of technology following agile processes to promptly create tangible deliverables for drilling operations.

The digital twin is part of a drilling automation application deploying a more holistic and automated hole cleaning advisor. The transient model is executed on demand to produce updated cuttings transport results and the associated context for it. Such results are converted into relevant information for drilling optimization engineers, hence simplifying the decision-making process. The adoption of the service is assessed globally and discussing the different regions.

The automation application containing the physics-based cuttings transport model was deployed in several locations across the globe. Some of the most sensitive deliverables of this model are the concentration of cuttings, its behavior as they are transported to surface, and the estimation of time and flow rate to transport the cuttings to surface. This kind of context information has enabled users to make informed decisions to maintain the health of the operation and avoid stuck-pipe events. Users can better decide where and for how long to circulate the wellbore after drilling a section to reduce cleaning time without endangering the formation and avoiding stuck-pipe events.

Furthermore, the hole cleaning application provides a central and concise visualization to highlight regions with high cuttings concentration and increasing risk of stuck-pipe events. The field deployments in Latin America, Asia Pacific, North Sea, Middle East, and North America Land are presented as example. Such deployments span across high-pressure, high-temperature environments, managed pressure drilling (MPD), long lateral sections, among others.

The automated hole cleaning advisor assess the wellbore condition in real-time and enhances the ability of drilling operations to react to potential drilling risks related to poor hole cleaning, thus avoiding costly corrective actions. The integration of transient modeling with drilling automation enables a safer optimization of procedures.
Optimizing Route of Produced Water Disposal
Authors: Al Siyabi Manal
Published: November 2024

This article presents a detailed concept selection study aimed at economically optimizing the disposal of produced water from high water cut and maturing oil reservoirs. The study is carried out on an existing oil production facility that has a built and operating network specifically for water disposal through water disposal wells (WDW). Given that forecasts indicate additional produced water will exceed the current network's capacity, this study was initiated to determine whether the existing base route of disposing of the water through disposal wells should be maintained or if alternative routes might be more economically attractive. To achieve this objective, a comprehensive analysis of key surface and subsurface factors was undertaken to assess the optimal operating conditions for disposal via water disposal wells. Additionally, hybrid and alternative disposal routes were thoroughly investigated to enhance both efficiency and cost-effectiveness in the process of water disposal.

The concept development process began with a thorough evaluation of subsurface factors that affect water disposal through wells. This involved assessing the injectivity index, which quantifies the rate of water injection in relation to pressure, and evaluating the frequency of acid stimulation required to sustain well performance. Additionally, surface factors such as water quality and disposal pressure were scrutinized to understand their impact on the efficiency of water injection rates.

The study explored two principal disposal routes: (1) complete disposal through water disposal wells and (2) a hybrid approach that integrates wells with various surface disposal methods. Surface disposal routes, including evaporation ponds and wetlands, were examined in detail to evaluate their feasibility and cost-effectiveness.

By integrating both subsurface and surface considerations, the study provides a thorough analysis of how these factors interact to influence water disposal strategies. The findings offer valuable insights into optimizing water disposal practices within the oil and gas industry, underscoring the potential for enhanced economic outcomes and improved operational efficiency. This comprehensive overview delivers a holistic approach to produced water disposal, aiming to balance both surface and subsurface technical considerations to achieve economically optimal results.
Assessment of the Environmental Risks and Policies Associated with Carbon Capture and Storage in the United Kingdom – A Case Study of the HyNet North West Project
Authors: Badejo Adeshina O. , Aminu Nuruddeen I. , Kumar Sekar Lokesh , Rita Okoroafor Esuru
Published: November 2024

In the United Kingdom, the North West of England and North of Wales are significantly industrialized regions generating approximately six million tonnes of CO2 industrial emissions per year. Undoubtedly, there is a need to decarbonize these regions as part of progress towards NetZero. The HyNet North West project, a £72 million project, is one of the two Track 1 projects selected by the United Kingdom government to help decarbonize these regions starting from 2025. With a focus on environmental risks, this comprehensive desk study conducts a feasibility assessment of the environmental risks and policies/regulations associated with CO2 sequestration in the United Kingdom, using the HyNet North West Project as a case study.

Using the Green Leaves III Government’s Guidelines for Environmental Risk Assessment and Management, the project’s inherent risks and hazards including groundwater contamination, surface water pollution, and potential impacts on protected species that could be affected by this development have been identified. In terms of policies, the current legal, political, and social context for this project were extensively studied. This approach aims to strike a balance between competitiveness, sustainability, and security in the execution of the project.

Based on the identified risks, an environmental risk monitoring and management plan, including pre-injection, injection, and post-injection phases, as well as risk mitigation measures, were formulated. Suggestions on how regulation and legislation can be used to achieve common energy policy objectives were provided. Recommendations were also made to outline a forward plan for the maturation of the UK’s First-Of-A-Kind Carbon Capture and Storage project, which cannot afford to fail. Overall, it was concluded that additional policies need to be implemented to support the execution of clean energy projects to meet the UK’s energy and climate goals. Additionally, the associated risks must be mitigated and contained.

Novel to this work is the identification of specific stakeholders who should be heavily involved in discussions around CCS deployment, particularly relating to this project, given its proximity to residential areas. This study identifies political and public support, especially at the local level, as essential for the project's success.
Game Changer in Chemical Reagents Design for Upstream Applications: From Long-Term Laboratory Studies to Digital Factory Based On AI
Authors: Saifullin E. R. , Gimadiev T. R. , Khakimova A. A. , Varfolomeev M. A.
Published: November 2024

The modern oil production industry necessitates an ever-expanding use of various chemical agents to optimize extraction processes, enhance recovery efficiency, and address operational challenges such as corrosion, scaling, and emulsion stability.Development of hard-to-recover oil reservoirs and extraction of residual oil from mature oilfields are the main reasons for the widespread application of chemical enhanced oil recovery (EOR) and improved oil recovery (IOR) techniques. Each oilfield and reservoir have unique conditions and fluid properties. To successfully implement chemical EOR (Enhanced Oil Recovery) and IOR (Improved Oil Recovery) technologies, it is essential to select or develop specific chemicals or chemical formulations tailored to the particular conditions of the reservoir. However, development of such reagents takes a lot of time and resources, it is limited by available initial reagents and precursors in the market. This work presents a new approach for developing chemicals using chemoinformatics models and artificial intelligence. The proposed approach consisted of three stages: generation of synthetically available molecules using the "Virtual Factory" algorithm, prediction of properties using a graph neural network with selection of the best candidates, and laboratory synthesis and validation of the predicted properties. The Virtual Factory algorithm used 159 of the most widely produced precursors on the local market and 10 templates of most common in practice reaction. The result of the algorithm was 5731 digital structures of surfactants of five various chemotypes. Graph neural network was designed to predict to predict interfacial tension (IFT) which is the most crucial property for surfactant flooding technology. A training set consists of 55,477 data points of molecule structural properties along with 218 IFT measurements for different reservoir conditions and oil properties for the training set. From 5731 generated digital surfactants structures, 4 surfactants with the lowest IFT among various chemotypes for oilfield X conditions were selected based on graph neural network predictions. The surfactants were synthesized in the laboratory and IFT was measured for oilfield X conditions to validate the neural network prediction.
Carbon Dioxide Conversion To Advanced Carbon Nanotubes
Authors: Wattana P. , Thivasasith A. , Nunthakitgoson W. , Rodaum C. , Wattanakit C.
Published: November 2024

The conversion of CO2 into valuable substances is a topic of great interest for decarbonization. Among them, the CO2 conversion to advanced materials such as carbon nanotubes (CNTs) has emerged as promising CO2 utilization. In this work, we have successfully developed catalysts and process to convert CO2 to CNTs. We developed catalysts by loading active transition metals on to hierarchical zeolite for CNT synthesis using CO2 as raw material. The synthesis of CNTs from CO2 over the developed catalysts was carried out via a chemical vapor deposition (CVD) process. The quantity and quality of the resulting carbon nanotubes were determined using thermogravimetric analysis (TGA), scanning electron microscope (SEM), transmission electron microscopy (TEM), and Raman spectroscopy. The synthesized CNTs were also evaluated for their current response using cyclic voltammetry (V vs. Ag/AgCl) method. By optimizing metal type, metal loading, zeolite topologies and pore structures (hierarchically porous or conventionally microporous), we successfully converted CO2 to CNTs over the metal-loaded hierarchical zeolite catalysts. The CNTs produced using the 25wt.% Fe on hierarchical FAU zeolite provided the most promising result with a high CNTs yield of 15.4%, an average CNTs diameter size of 23.1 nm, and ID/IG ratio of 0.56 indicating high quality CNTs. The synthesized CNTs were tested and exhibited higher current response compared to commercial CNTs. This enhanced performance highlights the significant contribution of the small diameter and superior quality of our synthesized pure CNT. Transition metals play a crucial role as catalysts in the decomposition of CO2 during the CNTs synthesis. Moreover, well-distribution of metal nanoparticles on the hierarchical zeolite contributes to enhanced catalytic activity, consequently resulting in more favorable CNTs synthesis outcomes. This work demonstrates conversion of CO2 towards highly conductive CNTs-based materials, which have many potential applications including energy storages, sensors, electronic circuits, etc.
Overcoming Realtime LWD Limitations of Longest Horizontal Drilling: A Unique Experience from Abu Dhabi
Authors: Abbas Nashat. , Noukhatha J. Al , Radwan K. , Aljaberi S. , Alqaydi N. , Arenas Milena. , Shrivastava Chandramani
Published: November 2024

Drilling long horizontal sections has been modus operation for some offshore operations by ADNOC for efficient exploitation through extended reach wells. Getting Realtime data for operational decisions becomes hugely challenging as the footage drilled goes higher, due to limitations posed by mud pulse telemetry and associated noise. This study presents a unique experience where logging-while-drilling (LWD) data could be streamed with high quality in Realtime in a record length extended-reach drilling (ERD) well through complex carbonate reservoirs with deployment of an advanced new solution.

Record drilling footage of more than fifty-two thousand feet was achieved in a long horizontal well drilled through a complex carbonate formation offshore Abu Dhabi. Operations suffered with the loss in real-time communication and degradation of real-time data quality after forty-one thousand feet of drilling. A novel technology of advanced telemetry was deployed to drill next section of planned additional eleven thousand feet that provides increased bandwidth for high fidelity Realtime data transmission with better data quality even at higher rates of drilling (ROP) in extreme conditions for measurements while drilling (MWD) and logging while drilling (LWD) in record measured total depth.

This new mud pulse telemetry platform enabled transmission of high quality Realtime MWD and LWD data to surface while drilling the deepest and longest section of the well towards the total depth at fast penetration rates. Good quality density images could be sent up hole with more than 100-ft/ hr. drilling rates in addition to the petrophysical triple combo data from the depths of >52,000 ft (about 15.85 km). Advanced data algorithms and embedded intelligent modulation methods pushed the boundaries towards achieving this unique experience.

This paper illustrates good geosteering practices in a challenging long horizontal well with carefully selected LWD program to achieve the target and reduce risks. The success of high quality Realtime data from such ERD wells opens new opportunities for drilling such wells through complex settings while still being able to acquire high-quality data without worrying about legacy limitations of mud pulse telemetry.
CO2 Transport Specification, Purification and Dehydration Solutions
Authors: Cao H. , Greene M. , Kuppler J. , Ali M.
Published: November 2024

CCUS is one of the key solutions to reduce emissions like carbon dioxide (CO2) in the atmosphere and minimize the effect on global warming. CO2 is separated from other gases at large industrial facilities like refineries, natural gas power plants, steel mills, and cement plants, or from the atmosphere. The two most common technologies for CO2 capture are membranes using physical separation and amines using chemical absorption. The bulk CO2 that is separated must go through additional purification steps to be ready for transportation. Once the CO2 meets pipeline specification, the CO2 is further compressed using high pressure to change the CO2 from a gas to a supercritical liquid. Pipelines are the most common mode of transport. After being transported to the well-characterized and permitted geological storage site, the CO2 is injected underground into deep rock formations where it is safely and permanently stored. Geologic formations have safely contained a variety of liquids and pressured gases such as oil, natural gas and naturally occurring CO2.

It is expected that several CCUS projects are coming live, and it is also expected that they are connected through a CO2 transportation network. Such a network will be a combination of ship, trailer, train, and pipelines. Carbon steel is a natural choice as construction material for the CO2 transportation system since it has excellent strength, is relatively cheap and is readily available in large quantities. Carbon steel corrodes when exposed to CO2 and water and/or glycol, therefore it is crucial that the transportation systems are operated in a manner that prevents formation of aqueous phases (Müller et al., 2023). Although treatment specifications vary by project, some specifications are commonly accepted. First, water in the treated CO2 typically needs to be less than 50 ppmv. The water content of <50 ppmv is well below that suggested to avoid the risk of corrosion for transport in pipelines and is set to avoid the risk of formation of ice in the liquefaction process equipment, rather than for any issues with transport containers. Second, for liquefaction, water specification in the treated gas can be as high as 50 ppmv. This is due to the higher liquefaction temperature of CO2 compared to other gases, like natural gas or nitrogen. Finally, glycol needs to be completely removed. This last point often disqualifies triethylene glycol (TEG) units for CO2 dehydration service.