bluuebunny/crossref_metadata_2025 huggingface dataset:
Advancing Sustainability: Rig-Less, Environmentally Friendly Wireline Stimulation Technology for Enhanced Oil and Gas Production
Authors: Tiar Saloua , Leguizamon Javier , Shehhi Maha Al , Alblooshi Ayesha , Sereidi Ali Al , Eissaee Ahmed Al , Hendi Ahmed Al , Sinha Manish , Perkash Wanod , Hadziavdic Ina. , Forsyth John.
Published: November 2024

This paper introduces an innovative wireline acidizing technique using a special sealed metal carrier with a dry chemical inside. The carrier is sent down the well using Wireline or digital slickline methods. When it reaches the target zone, an electric trigger causes a reaction that produces hot acid vapor, reducing the need for heavy equipment.

The main goal was to stimulate a section of the Lower Cretaceous Reservoir Zone to clean the near-wellbore area, reduce skin, and improve productivity. This method, deploying the tool inside 3 1/2″ tubing, significantly cut costs and CO2 emissions compared to traditional coil tubing stimulation methods and increased injectivity by 1.8 times after stimulation.

The process involved close cooperation between the operator and the service company. Damage mechanisms, well completion design, mineralogy, well deviation, formation characteristics, and compatibility were carefully assessed. A single 2.5″ HCl Thru-Tubing tool to treat a 9-foot perforated interval was used, which effectively removed scale and stimulated the near-wellbore matrix, improving fluid flow into the reservoir.

Before treatment, an injection test showed a flow rate of 1.5 bpm at 1900 psig. After treatment, the injection rate increased to 2.7 bpm at the same pressure. The rig-less procedure only needed a wireline and pump unit, finishing in less than a day and allowing the well to return to production quickly. This method saved 25% in costs compared to coil tubing applications.

Importantly, this new technique greatly reduces the carbon footprint of acid stimulation. It cut CO2 emissions by 69% compared to coil tubing applications, showing significant environmental benefits.
Introduction of a New Friction and Wear Testing Method to Set New Standards for Low Friction Centralizers
Authors: Raszczyk Christoph , Levie David
Published: November 2024

Low friction testing is a crucial aspect in various industries where reducing friction between interacting surfaces is essential for improving performance, efficiency, and durability of mechanical systems. Low friction centralizers play a critical role in the efficient deployment and operation of casing and liner strings in oil and gas wells. The design of low friction centralizers typically incorporates features such as streamlined profiles, low-friction materials, and specialized coatings to minimize contact resistance between the casing, the centralizer, and the wellbore wall. These centralizers are often deployed in challenging wellbore environments, including highly deviated or horizontal wells, where frictional forces can be particularly pronounced. Overall, low friction centralizers play a crucial role in well construction by enhancing casing placement efficiency, improving cementing quality, and reducing operational risks. Their adoption contributes to safer and more cost-effective wellbore operations in the oil and gas industry. So far, there is no reliable method worldwide to allow comparability tests between the different centralizers if it comes to friction reduction as well as wear resistance.

The focus of this SPE paper is on experimental testing methods, which typically involve laboratory-scale setups to simulate downhole conditions. Various parameters, such as centralizer geometry, material properties, and wellbore fluid characteristics are considered in the testing process. Key testing techniques include axial and radial load tests, casing rotation tests, and torque and drag measurements. The paper discusses the significance of low friction centralizers in optimizing well construction and integrity, reducing operational risks, and enhancing overall well performance. Furthermore, challenges and opportunities for further research in the field of low friction centralizers testing are highlighted, with the aim of advancing technology and improving industry standards. This paper will also present an overview of testing methodologies and techniques used to evaluate the performance of low friction centralizers in wellbore applications developed by Maxwell Oil Tools. Maxwell has tested over 200 different materials used for centralizers and protectors. This SPE paper introduces the test procedure and presents the test results on friction and wear.
Can CCS Make it Cheaper for a Sustainable Hydrogen Supply? A Technoeconomic Assessment
Authors: Alyousef Abdullah A. , Alshammari Yousef M.
Published: November 2024

Worldwide demand for hydrogen has been rising steadily as an alternative to fossil fuel energy. This work presents a study of techno economic assessment of hydrogen production via natural gas reforming and photo-electrolysis by estimating the levelized cost of hydrogen (LCOH) of various hydrogen production processes. Carbon sequestration is employed to realize low carbon dioxide emissions and prevents the affluence of carbon dioxide into the atmosphere, as such, mitigating climate change. Our work establishes that carbon capture and storage (CCS) technology increases capital expenditure, which surges the LCOH. Comparison between the PEC system and PV systems is explored. Our work uses the H2A model with different methodologies to find the various results regarding LCOH. Furthermore, the work reviews recent research in solar hydrogen generation. Based on the current literature, contemporary technologies can achieve $2/kg of carbon-free hydrogen production with CCS. From our findings, a 2000 kg/day of hydrogen production plant can achieve an estimated LCOH of $2.20/kg. However, considering the surge in the cost of raw materials over time, this figure is bound to slightly increase to $2.70/kg by 2040.
Optimum Supply Chain Management and its Positive Impact on Hydraulic Fracturing Project Start-Up – A Case Study Review
Authors: Badurayq S. , Bajusair A. , Aljorephani S. , Yudin A. , Nurlybayev N. , Farouk M. , Al-Jalal Z. , Al Hadyani F.
Published: November 2024

One of the pillars of hydraulic fracturing services is the tailored supply chain workflows. Localization strengthens supply chain elements by procuring parts and services locally which plays a massive role in terms of pricing, lead time, and storage. This study addresses a case history located in KSA for a hydraulic fracturing operations start-up and evaluates how effective supply chain management can result in a significant synergy and improved service delivery of hydraulic fracturing operations.

The method starts by describing the fracturing operations start-up from zero to 200 plus employees and to building two complete heavy-weight frac packages with capabilities to deliver high-end fracturing services at extreme pressure and temperature. A robust supply-chain organization, which includes the industry standards and business processes, enabled the supply-chain workflow to be more effective both internally within the company and externally. Key metrics that were considered in this study included cost reduction, lead time requirement and materials/product quality. The study will show how the solid and well-followed procurement standards led to cost and lead time optimization.

Supply chain and logistics management for hydraulic fracturing encompasses the strategic procurement and efficient delivery of essential materials, optimized to minimize costs. A strategic plan was initiated to request proposals from local and international suppliers for a specific scope for the high-spend products. 24 vendors, out of 49 invited, submitted their proposals including technical data, prices, and incoterms. The result of the project led to a saving percentage exceeding 56% by selecting domestic chemical manufacturers and committing to a certain purchase over a planned operational period. Overall, materials cost from direct and indirect suppliers was reduced by more than 20% within 12 months period. Localization percentage has increased from 70% to 78% during first year of fracturing project start-up. A significant reduction of lead time was achieved through several initiatives including the reduction of in-kingdom stock. For instance, personal protective equipment supply process was reduced by more than 70%.

This paper evaluates how effective supply chain, and procurement processes can positively reflect on fracturing operations start-ups. It also highlights the importance of localization in terms of materials supply and spare part and maintenance readiness.
Fostering Innovation Through Leveraging Disruptive Technologies
Authors: Hannabi Abdoulelah N. , Owaid Yazeed A.
Published: November 2024

Innovation and technology programs are among the top priority for the success of any industry around the globe. Combining these programs addresses the key gaps that are found on the current practices where a culture of innovation, eco-system and sustainability is captivated by leveraging disruptive technologies including but not limited to generative AI, digital twin, VR …. Etc. The imp act of utilizing a top to bottom approach in running a business has created a barrier in the workforce to adopt new technologies or brainstorm innovative ideas. Even with the engagement form management, leadership, allocating resources, rewards and metrics, yet, it is challenging to experience the change of culture, achieve what innovation program are designed for to gain a competitive edge. Thus, a comprehensive program was established where technology and innovation are presented in one platform. This platform is designed to showcase innovative ideas, technology projects and on-going virtual campaigns across the organization.

To improve and streamline innovative ideas, guiding principles, procedures and the recommended best practices in a concise description were provided and delivered with the help of generative AI that is impeded within the innovation and technology platform. The generative AI is a one example of combining innovation and technology to gain insight based on the organization accumulated experience which were formulated into best practices and procedures along with other suggestions received by the users directly. The ultimate goal of this program is an autonomous and structured approach to refine innovative idea management processes and make it more efficient and valuable. Key metrices were developed as a starting point and are adopted to achieve a set of goals in a value adding system to constantly improve the innovation culture with the focus on quality, scalability and impact on the organization.

Part of the key metrics are the participation rate, idea review rate, approval rate, implementation rate and innovation realized value. These metrics were the starting point to measure the effectiveness of the innovation program. However, when combined with technology deployment, more metrics are added including: technology realized value, approved technology utilization, development of technology roadmap and others. As a result, this unique innovative and technology program has paved the way toward creating the culture of innovation. In addition, it proved its credibility through a comprehensive platform equipped with the necessary tools to effectively evaluate and process innovative ideas and technologies. Moreover, it provided a dynamic guideline for improving the idea evaluation process and enhancing the implementations of innovative ideas and technology deployment companywide.
Charting a Path to Low-Carbon Leadership in the GCC: Unlocking up to 90% Emissions Reductions in Greenfield LNG
Authors: Carydias Peter , Flowers Simon
Published: November 2024

The LNG industry stands at the cusp of a transformation driven by the climate imperative. Focusing on an innovative low emission industrial hub in Northern Australia, this paper shows how CO2 emissions can be reduced in a world-class LNG asset by strategic master planning, colocation of industrial facilities and taking a marginal cost approach to assessment, screening, and implementation of existing and new decarbonisation technologies.

We propose:

A new breed of electrified LNG processing facilities that could deliver a ~90% reduction in Scope 1 and 2 CO2 equivalent intensity with sufficient renewable firmed imported power – given that gas Driven emissions constitute ~78%-93% of Scope 1 and 2 CO2 equivalent emissions on a sample of current practice LNG facilities. Leveraging partnerships in upstream renewable power, hydrogen supply and enabled downstream carbon capture and storage (CCS) technologies, we outline how we can de-risk assets from economic and regulatory uncertainty by providing alternative pathways to sustaining emissions reduction. A strategic methodology to screen and implement ‘avoid and mitigate’ options first, focusing on those opportunities the offer the most cost-effective emissions reduction opportunities. Phase 1 – Establish a Baseline Emissions Profile: At a conceptual level, estimate all emissions sources from energy usage to fugitive to flaring emissions in line with the relevant carbon accounting standards. Understand the largest emissions sources and their drivers.Phase 2: Identify & Prioritise Emission Reduction Opportunities: Apply existing and innovative technologies to uncover opportunities for GHG emission reductions. Identify the GHG reduction potential and the lifecycle costs of implementation of such opportunities.Phase 3: Select Initiatives and Develop Emissions Reduction Roadmap: Plot all emissions reduction opportunities on a Marginal Abatement Cost Curve (MACC) that clearly shows the lowest to highest marginal abatement costs for each opportunity. Understand non-cost risks of each opportunity which may be technology readiness or third-party risks and then select the opportunities for more detailed assessment that align to your businesses strategic GHG reductions roadmap and risk appetite. A deeper analysis into an industrial Precinct Case study in Northern Australia (Middle Arm) and how key attributes are comparable with Gulf countries.
Transformed Towards the Digitalization of 30 Years Mature Field by De-Manning to Reduce Operating Cost (OPEX)
Authors: A Shatiry M Sahir , M Ros M Ikranizam , Ramli M Fariq Effendi , Embong Azrol , Bahrin Rosmiah Samsul , Asmadi M Noraznan
Published: November 2024

Field XY is a conventional shallow water field, and it is under a mega brownfield and rejuvenation project under PETRONAS Carigali Sdn Bhd—the project's objective is to transform the existing field into a remote operation. Hence, the project's scope included modifying the existing manual operation to a digitalization operation. The field has operated since 1978, and it is located 250 kilometers offshore of Peninsular Malaysia. In summary, the field has been produced for more than 30 years. Therefore, upgrading the existing facilities to minimize the operating cost is essential to continue the production of gas and oil from Field XY. This project objective covers 3 main goals:

To transform the current operation to digitalization by upgrading the control system and expanding the internet network. To reduce the operating cost by de-manning the existing B-A Platform and centralizing the operation at the T-A Platform. To reduce the GHG produced during operation by improving the overall process system & installation of the Vapour Recovery Unit (VRU).
Identifying Natural Fractures in Unconventional Carbonate Source Rocks in Abu Dhabi by Comparing Borehole Image Logs and Drilling Parameters to 3D Seismic Fracture Analysis Techniques
Authors: Mykhaylenko S. , Burgess C. , Al Marzooqi H. , Baig M. Z. , Alharthi A.
Published: November 2024

The identification of high-prospectivity areas in unconventional fields is a critical aspect of optimizing hydrocarbon recovery and ensuring economic viability. These are areas within the reservoir that exhibit higher porosity and permeability, making them prime targets for drilling and production. The integration of seismic inversion results, which provide insights into the porosity of the rock, with the identification of fractured areas that enhance permeability, offers a comprehensive approach to delineate these favorable zones.

Seismic inversion is a powerful tool that transforms seismic reflection data into a quantitative rock-property description of the reservoir. It enables the prediction of porosity variations within the subsurface, which is a key attribute in evaluating the quality of unconventional reservoirs. By integrating seismic inversion results with the identification of natural fractures or artificially induced fractures, geoscientists can better understand the reservoir's heterogeneity and fluid flow characteristics.

Fractures play a significant role in unconventional reservoirs as they can significantly enhance permeability, a critical factor in formations where matrix permeability is inherently low. The presence of fractures can transform an otherwise tight rock into a productive reservoir. Therefore, the accurate mapping of fractured zones, in conjunction with porosity data from seismic inversion, is essential for the effective exploitation of unconventional resources.
Industrial Deployment of Power Reserve Optimization
Authors: de Meyer F. , Guzman J. , Labastie E. , Germain-Vu C.
Published: November 2024

In remote oil and gas production facilities, power is often produced on site with gas turbine generators or internal combustion engines. The difference between the maximum available power and the current load of the group of running machines is known as the power reserve. The rationale for optimizing the power reserve is to increase the efficiency of power generation and reduce the greenhouse gas emissions. A four-steps approach to optimize the power reserve has been developed and is being deployed on all operated assets. First, all data related to power generation and consumption is collected and reviewed. Second, an optimized configuration is identified and modelled. Third, the feasibility is studied, and the business case is evaluated. Fourth, the optimal configuration is tested and implemented. The following enablers for power reserve optimization are considered in the second and third step: reduction of electricity consumption, load shedding strategy update, detailed power generation reliability study and improvement, site interconnection, hybridization and the use of a battery energy storage system. The optimization of the power reserve is under deployment on all our operated sites. The total potential greenhouse gas reduction potential identified is around 350 ktCO2eq per year. Eight gas turbine generators have already been switched off resulting in a reduction of around 130 ktCO2eq per year, as well as lower fuel gas consumption and lower maintenance costs. The main enablers are improved reliability of the power generation, site interconnection and hybridization. As part of the deployment strategy a real-time monitoring tool has been implemented (PowerBI). A key performance indicator related to power reserve optimization has also been defined for follow-up by senior management. Return of experience has been collected and shared with other sites. The paper presents a novel, structured and systematic approach to optimize the power reserve that can directly be applied to all assets. The approach often results in a reduction of greenhouse gas emissions at a low net technical cost and should thus be one of the first steps to reduce the carbon footprint of remote production sites.
Relief Well as a Derisking Tool - A Case History
Authors: Amer Mohamed , Barnett David
Published: November 2024

Offshore well operations are inherently complex and demand a high level of technical prowess, strategic collaboration, and adaptability. Wild Well Control exemplifies these qualities through its intricate and challenging projects. This paper provides a comprehensive look at the multifaceted challenges faced during a specific gas well operation, the strategic decisions made to address these challenges, and the invaluable lessons learned along the way. By delving into the detailed processes involved in well control and relief well operations, we aim to offer insights into the critical importance of meticulous planning, effective teamwork, and the methods required to ensure success in the field.
Drilling and Completion of the World's Longest Slim Hole Erd' with Limited Entry Liner Completions Using Water-Based Mud Saves 130 MM$ in Onshore Abu Dhabi
Authors: Varma Esha Narendra , Ditzler Theodore Jay , Sumaida Ali Ben , Mwansa Peter Levison , Husien Mohammad , Bahrom Abdul Raman Bin , Saragi Raymond
Published: November 2024

Extended reach drilling (ERD) can facilitate the development of untapped resources, reduce greenhouse gas emissions, surface congestion, and drilling costs. This ERD project with lower completion was started with an aim to lower well cost indicators including $/ft and $/bbl. Therefore, the challenge was to drill Slimhole ERD (6-1/8″ lateral) wells with water-based mud (WBM). WBM is more cost-effective, environmentally friendly, and less damaging to the reservoir than OBM (oil-based mud). The use of WBM instead of OBM can save $2MM per well. The major challenges in drilling Slimhole (6-1/8″ size) ERD well with lateral leg include higher torque and failure to deploy lower completion due to high friction factors.

The first pilot well was planned with a liner-less design considering the low friction factors required to drill 15,000′ of 6-1/8″ lateral hole and run the lower completion. The second pilot well was targeting a deeper and tighter reservoir zone with higher downhole temperatures. This involved drilling 12-1/4″ intermediate hole to the landing point with larger 5-1/2″ drill pipe. It enabled a push-pipe technique for drilling the lateral hole with improved weight transfer through the curved profile. The 6-1/8″ lateral hole was drilled with 4″ high-torque drill pipe, tandem high-flow circulating subs, and specially formulated drilling fluid lubricant. A conventional OBM system provides sufficient lubricity to reduce friction factors as low as 0.10. In this application, a low cost WBM system was made feasible by introducing stable high-temperature lubricant and unique hole cleaning practices.

Following this successful achievement, the 5-year business plan has been revised to include 63 similar wells with a projected total savings of ~ $250MM.

The Slimhole ERD project has demonstrated substantial value with a 35% reduction in CAPEX. The delivery of these two Slimhole ERD wells overturned conventional drilling and completion practices.

The implemented project resulted in saving up to 35% of the well cost and saved 20 days per well compared to a conventional ERD well with 8-1/2″ hole and OBM. These two Slimhole ERD (15,000′ lateral) wells were drilled with a challenging Directional Difficulty Index (DDI) of 7.2. The wells were both completed successfully by running the 4-1/2″ lower completion to reach the total depth.
Integrating Neural Operators and Transfer Learning for Efficient Carbon Storage Forecasting
Authors: Falola Yusuf , Misra Siddharth , Nunez Andres
Published: November 2024

Efficient forecasting involves generating accurate and reliable predictions while minimizing the use of resources, such as time, training data, and computational power. This study investigates the potential of Fourier Neural Operators (FNOs) combined with transfer learning (FNO+TL) for forecasting the spatiotemporal evolution of pressure and CO2 saturation in a large, heterogeneous geological carbon-storage aquifer. The enhanced FNO models, trained on the SACROC geological model, achieved high accuracy, with mean absolute errors (MAEs) of 0.046 MPa for pressure and 0.011 for saturation in large aquifer models. Transfer learning (TL) further enabled the adaptation of a trained FNO model to diverse operational conditions with minimal new training data. The adapted models achieved pressure prediction MAEs of 0.27 MPa, 0.51 MPa, and 0.59 MPa, and saturation prediction MAEs of 0.05, 0.056, and 0.14, under varying injection rates, schedules, and injector locations, respectively. Additionally, the FNO models generalized successfully to a geologically distinct site at the Illinois Basin - Decatur Project (IBDP), which had significantly different carbon storage operations. The models achieved prediction MAEs of 4.5 psia for pressure and 0.11 for saturation, with reductions of 87% and 80% in training data requirements, respectively. Furthermore, the FNO+TL models significantly reduced computational costs. The study concludes that integrating transfer learning with Fourier Neural Operators provides an efficient and scalable approach for CO2 storage forecasting.
First Successful Shaped Memory Polymer (SMP) Open Hole Sand Control Application in an Extended Reach Well
Authors: Antoniucci Cesare , Di Altobrando Cinzia , Gioia Valeriano , Ferrara Giovanni , Sportelli Marco , Mingozzi Michele , Derni Davide , Di Giampaolo Paolo , Fusilli Alessio
Published: November 2024

Shaped Memory Polymer (SMP) technology represents nowadays one of the more innovative sand control techniques available on the market for layered reservoir with water zones associated or characterized by different pressure regimes.

Even though the well configuration has not been identified as a constraint for the technology utilization, a limited number of applications has been carried out.

This paper presents the first Southern Europe deployment of the system in an extended-reach well, successfully performed.

The SMP is deployed into the wellbore like a sand screen, allowing the installation of the lower completion as a single trip assembly with a liner hanger system.

Upon downhole installation, an activation agent is pumped, causing the SMP media to expand. It conforms against the borehole, thus maintaining positive stress against the formation and stabilizing the near-wellbore region.

In order to succeed in deploying the completion in such highly deviated environment, detailed torque and drag studies have also been conducted considering the displacement and well drag friction factors (OH and CH).

This paper presents the successful deployment of the SMP in an extended-reach well, presenting a slant profile of 80° inclination while dropping to 65° over the last open hole phase (215m length), showing a final displacement at well total depth of 2900 meters.

The assembly has been customized considering four production zones separated by open hole packers with an inner string incorporating a sliding sleeve device (SSD) for each zone to ensure production selectivity. Once the SMP has been positioned at the desired open hole depth, the liner hanger is set and the activation fluid pumped. Based on detailed studies carried out considering specific well conditions such as hydrostatic pressure and bottom hole temperature, the contact time has been selected to 40 h to guarantee the full polymer expansion.

Subsequently, the liner packer element has been energized, followed by the installation of the upper completion system.

Then the clean-up operations started.

Shaped Memory Polymer technology stands out as one of the most cutting-edge sand control techniques available.

The successful deployment of the system in Southern Europe represents the first application of the technology in an extended-reach well over the few installations carried out worldwide. It validates its capability to effectively operate in highly deviated wells and confirms its viability and cost-effectiveness as an alternative to conventional standalone screens or other sand control techniques.
Impact of Industry 4.0 Technologies in Enhancing Sustainability of Maritime Logistics
Authors: Kumar U. , Dixit V. , Jha K.
Published: November 2024

Sustainability has become a pivotal point in the maritime industry, encompassing environmental, economic, and social dimensions. This study investigates the impact of Industry 4.0 technologies on improving maritime logistics sustainability. An extensive literature review will identify key technologies and sustainability goals across these dimensions. Using advanced decision-making frameworks like AI and ML-enabled decision intelligence or Neutrosophic-TOPSIS methods, the impact of these technologies will be quantified and ranked. The results will yield a prioritization of technologies and a strategic roadmap for their implementation, aimed at optimizing resource allocation and enhancing sustainability. This research provides an integrated approach to sustainability and technological adoption, offering a novel, industry-specific roadmap.
Selection and Maturation of a CO2 Store for Oman's First Blue Hydrogen Project
Authors: Borner N. D. , Aljiroudi F. , Al Baloshi S. , Al-Abri A. S. , Di Matteo A. , Gavnholt J. , Dhahli A. , Farajzadeh R. , Singhal M. , Al Mjeni R. , Al Bulushi N.
Published: November 2024

In May 2022, a Memorandum of Understanding was signed between Petroleum Development Oman (PDO) and Shell to pursue the development of Oman's first Blue Hydrogen project with Carbon Capture Utilisation and Storage (CCUS), based at the Port of Duqm. To create a certified blue product, the CO2 associated with hydrogen production from natural gas must be permanently sequestered underground. This required selection and maturation of a suitable CO2 storage site in the onshore area of Oman with sufficient capacity for the project, sustained reservoir injectivity, robust containment and adequate monitorability using available technologies.

The subsurface of Oman contains a vast succession of geological reservoirs and seals, from Pre-Cambrian through to the Tertiary, many of which are proven petroleum systems. It was quickly determined that saline aquifers, rather than depleted gas fields, presented the best opportunity for CO2 storage, due to their size and separation from Oman's dense network of hydrocarbon-producing fields and infrastructure. PDO's Block 6 concession contains the most likely candidates from a geological perspective, as it covers the main sedimentary basins within the country, plus benefits from a rich subsurface dataset for evaluation of the CO2 store.

This paper describes the process of selection and subsurface characterisation of a suitable saline aquifer CO2 store in Central Oman, to meet the pore space requirements of CO2 sequestration for the lifetime of the proposed Blue Hydrogen project.
Machine Learning Accelerates and Facilitates the Prediction of Stuck Pipe Events
Authors: Katzmann L. , Mayer H. , Arévalo P. , Forshaw M.
Published: November 2024

In the present social and economic climate, Exploration and Production (E&P) companies are under pressure to embrace low-cost digital technology that offers a dual benefit of lowering well construction capital expenditures, as presented in Fig. 1, by reducing Non-Productive Time (NPT) and Invisible Lost Time (ILT), while also aiding in meeting Environmental, Social and Governance (ESG) objectives.

One of the main sources of NPT in well construction is stuck pipe, as such incidents represent one of the most challenging and costly problems in drilling operations. In these cases, the drillstring becomes immovable in the borehole caused by different mechanisms such as differential or mechanical sticking and packing off. Such incidents can lead to not only NPT but also potential loss of equipment, hence necessitating expensive technical detours that prioritize projects over authorization for expenditure (AFE). Furthermore, stuck pipe events can significantly affect the safety and wellbore integrity. While approaches to identify stuck pipe scenarios retrospectively are well documented, this paper describes a data-driven approach to identify and predict such events at the edge in real time using machine learning.

Nowadays, the constant development of digital technologies, such as digital twins modeling behavior of the wellbore and equipment in real-time (Arévalo et al. 2021), drilling automation applications aiding in the monitoring of wellbore condition (Ait Ali et al. 2023, Arévalo et al. 2023, Arévalo et al. 2022), among others, have prepared the ground for a more accurate detection of downhole hazards, such as conditions leading to stuck pipe. This paper presents the utilization of machine learning (ML) to analyze surface data, detect stuck pipe events and classify such events into categories. The approach consists of a fuzzy logic algorithm to categorize acquired surface data and a real-time classifier to be trained. The score calculated by the fuzzy algorithm is mapped into five categories, which serve as labels for training validation and test data. A Long Short-Term Memory (LSTM) and a decision tree are trained by a sequence-to-label prediction approach to predict whether the drillstring will operate unimpeded or whether higher drag or even a stuck pipe event is expected.
Real-Time Forecasting of Subsurface Porosity During Drilling Using Advanced Time Series Models
Authors: Mohamed Badr A. , Aliyev Subhan , Ibrahim Ahmed Farid , Al-Shafloot Talal
Published: November 2024

Oil and gas exploration and production are critically dependent on well logging to gather essential subsurface data for effective reservoir characterization. Traditional well logging, while invaluable, incurs substantial costs and is typically confined to specific depths, thereby restricting a thorough understanding of reservoir properties across the entire wellbore. Addressing this challenge, this study harnesses the potential of various time series models, including ARIMA, LSTM, bi-directional LSTM, GRU, and simple RNN, to predict porosity in areas of the wellbore not yet reached by logging tools.

This research introduces a novel approach that involves predicting real-time reservoir porosity during drilling, using time series models to extend our knowledge into unlogged intervals. This method leverages existing log data to forecast porosity ahead of current drilling, allowing for real-time data-driven decision-making that can influence drilling directions and strategies. The methodology consists of preprocessing the data, segmenting it into training and testing sets, and training distinct models on porosity with depth serving as the time component. The efficacy of each model is rigorously evaluated using metrics such as mean squared error (MSE) and mean absolute error (MAE), with the most accurate model selected for real-time forecasting.

Results from the study highlight that while all tested models demonstrate capability in predicting subsurface properties, LSTM and bi-directional LSTM, in particular, show superior performance in modeling the complex patterns inherent in geological data. The introduction of a prediction strategy during drilling not only refines the model's accuracy but also revolutionizes how geological data is integrated into operational practices.

In conclusion, this study transcends traditional logging limitations by applying advanced time series forecasting models to predict porosity in the unlogged sections of the wellbore. The innovative approach of real-time forecasting of subsurface porosity during drilling could significantly alter operational dynamics in the oil and gas industry, facilitating more precise reservoir characterization and informed decision-making in field development and management.
Navigating the Depths: How High-Force Tractors Enable Access to Deep Reservoirs
Authors: Varghese Mathew , Woods John , Sheiretov Todor , Correia Gladwin , Altamimi Sarah , Tirado Eduardo , Ibrahim Ahmed
Published: November 2024

High-force wireline tractors address the conveyance challenges of ultradeep reservoirs with complex trajectories, enabling access to deep reservoirs. Accessing ultradeep wells for surveillance and intervention is highly challenging with conventional methods. Conveying long downhole tools through complex trajectories in ultradeep wells demands extreme conveyance forces, compounded by power delivery limitations associated with long cables. In this paper we provide an overview of these challenges faced by an operator in the United Arab Emirates (UAE) and a novel wireline tractor solution that overcomes these challenges to access ultradeep reservoirs with increased efficiency and reliability. The approach consists of analyzing conveyance challenges and deploying an innovative technological solution using high-force tractors to enable reliable data acquisition in deep reservoirs. The following methods are used: Model and analyze well tortuosity to estimate tractor forces and navigation challenges.Select a high-force tractor system with a bespoke motor design for the job.Choose an efficient telemetry system for reliable communication with downhole tools.Design a purpose-fit tool configuration and operation strategy to navigate complex completions.Conduct surface integration tests to assess tool capability and reliability.Provide feedback to enhance tool design and performance at the product manufacturing center.

The new high-force tractor design delivers a remarkable 70% increase in conveyance force compared to legacy tractors, as demonstrated in a surface integration test (SIT). Additionally, it achieves twice the tractoring speed under higher loads, enhancing operational efficiency and reducing intervention time. The implementation of an advanced high-speed telemetry system enables reliable surface acquisition of downhole sensor data across extended cable lengths while tractoring, maintaining a high signal-to-noise ratio. This new tractor system was successfully deployed in seven wells to access deep reservoirs for an operator in UAE. This system was first deployed to convey production logging tools in the main bore of a trilateral well with 18-ft long sidetrack windows. By combining increased force and efficiency, the tractors successfully navigated through these challenging sidetrack windows. Key achievements include secure access to reservoirs via multiple passes across sidetrack windows; a cumulative tractoring distance of more than 27,000 ft in the first well; reliable acquisition of downhole tool data over a 43,500-ft-long wireline cable using the new telemetry system; simultaneous acquisition of production log data during tractoring, which ensures high-quality data and improved operational efficiency; and accurate quantification of horizontal lateral zonal contributions from all three laterals. This successful deployment of high-force tractors opens opportunities for accessing ultradeep reservoirs.
Laboratory Evaluation of Single-Phase Retarded Acid System Performance in Limestone and Dolomite Rock - Part 1: Pore Volume to Breakthrough Experiments in Limestone
Authors: Morrow Timothy I. , Kelkar Shrihari , Mogensen Kristian , Leguizamon Javier , Mohammed Abdul Muqtadir , Ahmed Kamran , Nizamuddin Syed , Awan Ehsan Ul Haq , Veetilakath Yehiya
Published: November 2024

The objective of this work is to conduct systematic core acidization testing on commercial limestone and dolomite core plugs to compare different commercial acid systems and identify the most cost-effective recipe(s), including optimum dosage and pumping rate. The work involves state-of-the-art equipment for the acidizing experiment at reservoir conditions and makes use of advanced high-resolution imaging to visualize the results of the pore-volume-to-breakthrough acidization experiments.

Over the past few years, service companies have brought new acid stimulation products to market. These so-called retarded or delayed acid systems aim to slow down the kinetics of the acid-rock reaction to allow acid to penetrate deeper into the rock matrix and thereby increase reservoir contact. Prior to any deployment at scale, these new chemical products must be qualified by an independent lab facility rather than relying solely on performance data supplied by vendors. In addition to acid compatibility with the reservoir fluid, the ability to create deep penetration with the lowest possible acid volume needs to be quantified. A key experiment is called the pore-volume-to-breakthrough (PVBT) test conducted on cylinder-shaped reservoir rock samples called core plugs. Within a certain range of acid velocities, the chemical rock dissolution reaction yields an optimum penetration depth with a minimum acid volume. The lower the volume, the more cost-efficient the acid recipe.

Nine single-phase retarded acid (SPRA) systems were evaluated, and all showed better performance than standard 15% HCl (in limestone) or 28% HCl (in dolomite) cores. Some SPRAs were marginally better than the standard HCl systems while others showed significantly improved performance. This paper will report a ranking of each of the SPRA systems evaluated from best-to-worst. Of particular note is that SPRA systems containing lower retarder dosages showed similar performance to SPRA systems that contain significantly higher retarder dosages. The lowest PVBT, which would represent a single, thin, straight cylindrical wormhole in a linear coreflood may not be optimum in a 3D radial flow pattern. We present a discussion on the need for some degree of branching of the dominant wormhole to enhance the flow into an actual wellbore, depending on the completion type.

This work represents the first systematic comparison of multiple single-phase retarded acid systems at the same test conditions by an independent laboratory.
Planning Developing and Designing Unconventional Lifts for Brownfield Projects
Authors: Korat Hiren , Cherian Litty , Kamal Faris Ragheb
Published: November 2024

In the context of enhancing production facilities within a brownfield, whether to increase output or transition to safer technologies, modifying existing facilities by addition of new equipment and deck extensions becomes imperative. The design, modification and installation of these deck extensions undergoes a rigorous EPC cycle which is undertaken by EPC contractors in co-operation with various contractors. This EPC cycle address all the requirements of the brown field project, start from engineering operational requirements to construction and installation within budgeted cost.

Invariably these modifications need to be carried out in planned manner. Maximizing construction of modules onshore to reduce construction time, achieve good quality and reduce offshore construction time. These modules once constructed at an onshore facility, are loaded on to transportation barges and sent to offshore facility for installation. To receive the module on to the fixed platforms necessary arrangements are made. The arrangements are engineered based on the type of modification.

Often the modifications need to be carried out in area which are not in direct reach of cranes and hence requires engineering additional arrangements such as skidding, use of static rigging etc. to receive deck extensions/modules etc. Often it requires shutdown of the facility and temporary removal of existing facility components. These inaccessible areas can be often accessed easily using unconventional lifts. The unconventional lifting methods employs additional tools depending type of unconventional lift adopted.

Adopting unconventional lifting methodology has its own benefits which are not limited to:-

Reduction in hiring of costly resources and dependence on their availability. Reduction in temporary modifications in existing facility to receive modules. Simple and fast module installation. Reduction in project cost.

This paper will describe in detail concept of unconventional lifting. And will specifically cover unconventional lifting using spreader bar and counterweight mechanism.
Addressing Karst-Related Challenges in Seismic Imaging - A Case Study from Onshore Abu Dhabi
Authors: Hassan Shady , McCarthy David , Brajas Carlos , Seliem Abdulla , Blymyer Dustin , Bernal Maria Cristina
Published: November 2024

The karsted UER and Simsima formations in Abu Dhabi represent a major challenge for seismic imaging as well as for drilling. The heterogeneity of the eroded limestone results in strong lateral velocity variations that distort the deeper seismic image. The conventional approach using pre-stack time migration (PSTM) and pre-stack depth migration (PSDM) results in a strong reflection at the top of the UER, with poor imaging quality in the section below. This paper outlines the challenges of this onshore dataset and proposes a new workflow using multi-wave inversion (MWI), TLFWI, wave equation deconvolution, Q-tomography and QPSDM, which helps to better detect the karsts bodies and improve the image quality below UER.

The dataset was acquired and initially processed in 2021. The data were of high quality for most of the survey but deteriorated in the north-east, due to thickening of Miocene evaporites in the near surface and the presence of karsting, which poses challenges for seismic imaging both onshore and offshore Abu Dhabi. A re-processing project was launched in 2023 with the aim to enhance the image quality in the area affected by the thick evaporites and karsting. An advanced velocity model building flow was used.

The combination of multi-wave inversion for the near surface velocity model and 10Hz TLFWI produced a high-resolution velocity model that accurately imaged the complex overburden and the fast velocities associated with the karsts. The application of wave equation deconvolution, alongside standard deconvolution techniques, reduced the presence of high frequency ringing from the shallow evaporite sequence. Q-tomography was able to identify Q anomalies, with interval Q values as low as 20 within the karsts. The final QPSDM image shows improved amplitude fidelity, frequency content, and imaging below the karsts when compared with the legacy data.

By the end, we demonstrate that this combination of high-end approaches, i.e. TLFWI and wave equation deconvolution, solves the encountered challenges, which helps to improve geological understanding and drilling plans as well as to open more opportunities for discoveries in the sections hiding below the karsts.
Exploring the Role of Digital Substations in Driving the Fourth Industrial Revolution
Authors: Elfayoumy M.
Published: November 2024

The next generation of power substations, known as digital substations, are influencing contemporary digital technologies to change how energy is delivered and transported. The objective of the paper is to clearly define how the Industrial Internet of Things (IIoT) can improve the performance and value of assets without requiring replacement of the fleet, reshaping the future of electrical power substations.

The paper introduces a case study that analyses smart digital substations, connecting wind farms to the grid, where both primary and secondary assets and wind turbines data are made available to a SCADA system. Following a methodological approach and considering the off-line (historical data, operators’ inspections, off-line reports) and on-line (interconnected sensors, protection & control IEDs and SCADA parameters) data being captured from assets and are ingested into the platform, breaking the information silos, contributing to assess the risk level for each asset, in a user friendly and easily accessible cloud SaaS (Software as a Service) environment.

The methodological approach deployed in this paper helped to define how to use data to its fullest potential and enable renewable energy sources to provide more dependable power supplies while utilizing the same grid infrastructure. The approach defines a clear path starting by applying predictive maintenance fundamentals through condition monitoring, moving to turning data into information, evolving to turning information into decisions as outcomes from the Asset Performance Management system (APM), and finally Video Analytics technology. As a result of applying this approach on a step-up power transformer and protection relays, APM application is proved to be able to produce more insights, of higher quality and level of detail, that helps in having effective decision-making process.