bluuebunny/crossref_metadata_2025 huggingface dataset:
Hands-Free Control Line Clamp System to Remove Red Zone Exposure
Authors: Gravouia Mark , Alleman Neil
Published: November 2024

The Remote Clamp Installation System (RCIS), Sheaveless Control Line Manipulator Arm (SCLMA) and Hands Free Hole Cover is an advanced, integrated system that remotely positions control line packages and installs the control line clamp with minimal operator interaction during smart completions. The system is designed to reduce hazards through automated sequencing that eliminates manual operations, hazardous setups, and the need for personnel to enter the red zone.

The Hands-Free Control Line Clamp System can install a control line clamp with no personnel entering the red zone. All functions are operated automatically with a one-touch system of controls and sensors, or it can be manually operated utilizing a remote console. Installed sensors ensure seamless operation of the system and guard against damage of equipment and control lines. Typical red zone manual functions are eliminated, replaced by the Integrated System with increased safety and efficiency through automation and delivers repeatability on every clamp installation.

The control lines run through the SCLMA as opposed to an overhead sheave and are presented correctly to the tubing to ensure the control line clamp can be installed without damaging the control lines. The retainer lids that secure the control lines are installed in the RCIS out of the red zone. Once the SCLMA has positioned the control lines correctly on the tubing, the RCIS is safe to function, the manipulator slews the clamp head in line with the tubing and translates the clamp head to well center. Once in proper position, the clamp head translates the retainer lid to its position and after acknowledgment from sensors, the clamp head will complete the installation by clamping the male and female collars to retain the retention lid and ensure the control lines are secure.

This solution not only enhances the industry's experience with improved safety and reliability, but it is also a paradigm shift that revolutionizes the control line installation process providing a fully autonomous, hands-free solution. This paper will deliver comprehensive details on the novelty of this technology and the solution offered to the industry.
Quantitative Assessment Method and Application of Natural Fracture Risk in Shallow Shale Gas Based on Geomechanics-A Case Study of Zhaotong Shale Gas Area in Southern China
Authors: Zhang Muyang , Xian Chenggang , Huang Xiaoqing , Liu Yunyi , Liu Yang , Liu Mingyang , Wang Jianjun , Liu Cheng , He Yong
Published: November 2024

The presence of natural fractures in the study area, combined with complex stress conditions, poses challenges for accurately quantifying fracture stability, directly impacting block development. This study employed a three-dimensional geomechanical model and a natural fracture model to calculate the critical stress states of natural fractures across the region. It provided a quantitative characterization of fracture shear slip stability through normalized analysis and classified the risk of natural fracture slip. The stress state of the block was quantitatively described using the Q index, and the stability of fractures under different stress conditions was analyzed. Additionally, the study examined the relationship between fracture stability and interference from horizontal well fracturing, casing deformation in horizontal wells, and well productivity. These findings are crucial for optimizing the exploration and development of shallow shale gas resources in southern China.
Offshore Acid Stimulation, Reaching New Limits
Authors: Rivas J. , Prossaird S. , Bakir H. , Faour F. , Elsayed H. , Elhassanat A.
Published: November 2024

With long horizontal sections on carbonate reservoirs being more common on the Middle East, the industry needs to contagiously evolve to match the market needs. Not more than 10 years ago reservoirs were stimulated with acid dosage of 100 to 150 gallons per foot (gpf); nowadays is common to find 10,000 ft. horizontal sections requiring around 24,000 bbl. of acid to meet the 100 gpf request bringing new levels of complexity to offshore operations.

Since the inclusion of the high volume/high pumping rate vessel to our customer's offshore oil fields the average volume is around 5,000 bbl. of acid systems and, thanks to the 200,000 gal. below-deck raw acid storage capability, it was possible to perform an acid stimulation connected to an offshore platform by a high-pressure flexible hose to pump 10,500 bbl. of 15% hydrochloric acid (HCl) system at an average pumping rate of 20 bbl./min. and wellhead injection pressure (WHIP) of ∼2,200 psi. This operation set a milestone for offshore (barges and rigs) operation in the region.

Due to its versatility this stimulation vessel has the capability to also pump at low pumping rates (down to 0.3 bbl./min.) for coiled tubing operations and it has been assigned to execute stimulations in offshore environment and island wells which is a hybrid set-up where, having the vessel docked at the island's jetty, it is required to rig-up up to 5,200 ft. of 3in. treating lines being able to pump acid treatments at 35 bbl./min. in an inland well. All these while transmitting in real-time the operation parameters with our customer in town.

The bigger the better, stability issues have been reduced due to the vessel's length and weight allowing it to stay offshore longer time in a safer and comfortable way for the crew on board. Also, it was possible to reduce the number of vessels trips for re-loading purposes on operations above 3,000 bbl. for 15% HCL systems and 2,000 bbl. for 28% HCL systems, leading to reduce the diesel consumption and CO2 emissions of the rig and barges and the vessel itself (marine and stimulation engines). This time optimization is also considerably reducing the cost of the operation by doing a 10,500 bbl. job in 2 days’ rig-time instead of 6 to 7 days as it was being done before.
Navigating Energy Transition: a Marine Logistics Perspective
Authors: Saxena S.
Published: November 2024

This paper aims to provide an overview of the current state of energy consumption and carbon emissions in marine logistics, and to explore the potential and challenges of energy transition and net zero practices in this sector. Marine logistics accounted for about 2.8% of all global greenhouse gases (GHG) emissions as per a 2020 IMO study, mainly due to the fact that more than 80% of the world merchandise trade by volume is transported by sea.

The paper reviews the literature and data sources on the topic, and analyses the trends, drivers, barriers, and opportunities for energy transition and net zero practices in marine logistics. The paper also presents some case studies of actual implementation of such practices in different regions and contexts.

The paper finds that marine logistics is a significant contributor to global greenhouse gas emissions, and that there is a need and a potential for energy transition and net zero practices in this sector. However, the paper also identifies some technical, economic, regulatory, and social challenges that need to be addressed to enable and accelerate such practices. The paper suggests some possible solutions and recommendations for future research and action.

The paper provides a comprehensive and updated overview of the topic and synthesizes the findings and insights from various sources and perspectives. The paper also highlights some gaps and limitations in the existing literature and data and proposes some directions for further exploration and innovation.
WeLead - Shaping Leaders of the Future Through Mentoring
Authors: Poole A. , Sonika S. , Bhobhiya K. , West S.
Published: November 2024

With the accelerating digital transformation, close cross-communication and knowledge sharing are imperative to deliver the best possible results to our customers and help our employees prepare for their roles in the future.

Mentoring is the process of assisting and encouraging people to take charge of their own education in order to maximize their potential, enhance their talents, optimize their performance, and become the person they aspire to be.

Mentoring is also long used by Fortune 500 companies to improve talent attraction and talent retention, as well as to accelerate employee development. This entry highlights an innovative approach to mentoring that maximizes participant energy and company culture engagement, aligning with the standard mentoring benefits recognized by 84% of FORTUNE 500 companies (Gross 2023).

An inclusive, diverse workforce needs mentoring to promote individual growth, job satisfaction and talent retention. Mentoring program described in this manuscript channels early adopters’ energy to mentor and purposefully reinforce company culture accelerating the alignment of greater organization with company purpose, strategy and culture through "leadership stories" & experience sharing.
High Molecular Weight Polymer Injection in Polymer Flood EOR Project South Oman: Achieving More Oil with Less Polymer
Authors: Riyami Omaira , Riyami Samiya , Abri Hasanaa , Nadeem Muhammad , Farsi Samya , Handali Mahmood , Jabri Reham , Hinai Suliman , Hajri Abdulaziz Hashimi. Mohammed , Busaidi Hamood
Published: November 2024

Since commencement, full field polymer flood application in Marmul field located in southern of Oman has been a worldwide successful polymer enhanced oil recovery project. This project was effective in realizing incremental oil volume on top of water flood, with recent realization of the highest polymer oil gain since the beginning of polymer flood project life cycle. Oil daily rate improved to double comparing to previous years with the same well stock. This achievement was a result of many initiatives like data automation, improvements on troubleshooting, increase in polymer viscosity, high sustainable polymer pump uptime and better equipment maintenance to minimize mechanical issues. Integrated team effort and collaboration between petroleum engineers, production chemists and operation team helped to significantly improve polymer flood performance. Partially hydrolyzed polyacrylamide (HPAM) of a molecular weight of around 20 million Daltons has been used in the project since its start date with target viscosity of around 15 cP at relatively low brine salinity (~5000 ppm) and reservoir temperature (46 °C). In the polymer plant, stabilizing package (isopropanol, thiourea and water, (ITW) has been added to the polymer solution to enhance long-term viscosity stability of the polymer at reservoir conditions. Entire polymer mixing facilities are nitrogen blanketed and maintained in an anaerobic condition. Given that polymer projects are OPEX driven (mainly by chemical consumption), the team has successfully piloted an initiative to increase the polymer molecular weight from around 20 to 25 million Daltons, hence, reducing polymer dosage by 20-25% to achieve target viscosity of 15 cP. This led to the implementation of full field injection of the high molecular weight polymer. The new self-stabilized polymer has been selected based on its excellent injectivity performance validated by labs and field pilot trial. This project is expected to yield savings in the opex & improving the overall project UOC attributed to the use of self-stabilized high molecular weight polymer by eliminating ITW package and achieving viscosity with low concentration.
Enhancing Asset Integrity by Gamma Online Scanning
Authors: Hussain Sikkandar , AlBahrani Mohamed , AlBreiki Mohammad , Razack Abdul Fathah
Published: November 2024

Performance of industrial static equipment depends upon its mechanical design and chemical process optimization. Any degradation of the static equipment due to corrosion issues and process abnormalities, can cause material degradation and huge production loss which eventually result in high revenue losses.

To avoid such scenarios and in line with ADNOC unwavering commitment towards 100% HSE and asset integrity, ADNOC GAS, Habshan-5 plant recently deployed Gamma scanning known as Accu-Scanning that works on the principle low curie radiography for scanning the entire static equipment surface. The purpose of this paper is to present the successful deployment and highlight the key benefits and value created from having such technology.

Using the conventional, such as Ultrasonic and Radiography methods for inspecting static equipment found to be challenging one and has its own limitations. To inspect such assets, the usual requirement of having complete isolation, manual entry and examine the condition of internals using conventional Ultrasonic and Radiography technique found to be time consuming activity and by which complete 100% inspection also not found to be feasible, due to large are coverage requirement and inaccessibility of the locations. Hence, it gives some uncertainty in evaluating the Asset Integrity of such static equipment. But, with this Gamma Scan technology that operates based on simple Radiography based technique, the complete thickness profile of the shell surface along with equipment internal insight being captured.

This Diagnostic scan in-addition to identification of thickness reduction along the periphery, it provides the condition of the internals, mechanical damages and hydra-dynamic abnormalities such as flooding that normally occur in the static equipment such as towers and columns. Moreover, this technology can be deployed during on-line condition, without the need of equipment shutdown and isolation requirements and the output produces massive digital and accurate measurements that can be later fully utilized to perform fitness for service and remanent life assessment in line with API.

Post-deployment and to validate the technology, the data obtained from the Gamma Scan has been validated with conventional Ultrasonic and Radiography, the results revealed more confidence on the technique that confirms the accuracy and reliability.

Looking ahead, having this massive digital accurate and reliable inspection date will be utilized in Machine Learning platform for future prediction to further optimize inspection intervals of Static equipment.
An Insight into Fracture Pattern and Characterization in Salt Dome Area
Authors: Zhang Sihai , Fu Xin , Cao Peng , Xu Ning , Liu Huifeng
Published: November 2024

Salt halokinesis and salt domes are prominent geological phenomena in the southwest of the Arabian Gulf and influence the formation and evolution of the overlying fractures (Richard et al., 2017). These small-scale faults and fractures subjecting to multi-phase stress regimes show diverse and characteristic fracture patterns. The fractures play a crucial role in the production performance of the tight carbonate reservoir in the 4-way dip closure above the salt dome (Fig. 1). However, mapping the extremely complex and diverse fracture system in this region under multi-phase stress regimes presents a significant challenge. The objective of this study is to investigate fracture development under multi-phase deformation and characterize the complex fracture system of the Upper Jurassic in this salt dome-dominated area.

Understanding the fracture system is critical for optimizing drilling strategies and improving the accuracy of reservoir simulations from these tight carbonate reservoirs. Detailed geological and geophysical analyses are conducted to understand the formation and evolution of fractures influenced by tectonic activities. Multiple seismic attribute analysis, along with core examinations and dynamic data analysis, will be employed to gain insights into the orientation and distribution of fractures. This study aims to (1) provide insights into the insights into the dynamics of fracture systems in salt dome environments and (2) enhance our ability to predict fracture behavior under varying stress conditions and inform better reservoir management practices.
Sustainable Practices for ERD Cementing: Success Story from Arabic Gulf
Authors: Herrera Juan Isaias Sarmiento , Nino Adriana Contreras , Sasso Alejandro De La Cruz , Zuleta Rodny Masoud
Published: November 2024

Wellbore integrity is particularly complex during extended reach drilling (ERD) operations, and the curve section is one of the most complicated intervals. In the Arabic Gulf, reliable cement barriers in long horizontal sections are frequently compromised by weak formations, pipe standoff limitations, inadequate equivalent circulating density (ECD) management, and mud displacement issues. The application of advanced engineering practices and state-of-the-art cementing techniques under these conditions are highlighted and supported by discussion of successful case studies.

Robust engineering best practices and superior field execution were essential to meet operator requirements. Custom fluid designs were meticulously tailored and monitored to ensure optimal slurry and spacer performance. This included cement fluid-loss management, compressive strength development, enabling the spacer-to-bridge thief zones, exceptional bonding between the cement and wellbore, ECD control, and precise slurry placement within designated depths. The selection of casing hardware was also vital; the combination of centralizers improved standoff values, optimized torque-and-drag forces, and helped ensure the planned casing point was achieved. A specialized shoe-track arrangement was introduced to mitigate undesired cement consistency during drill out.

A campaign of seven wells were executed and deemed successful by the operator. Comprehensive evaluation through positive and negative pressure tests and cement bond logs (CBLs) demonstrated excellent cement coverage and bonding. Preapplication verification testing of all slurries with mixing fluid samples and location blends confirmed their readiness for flawless execution, with slurry behavior consistent with initial tests. Early development of set cement compressive strength and low slurry fluid loss were fundamental to minimize shoe-track contamination and achieve the necessary top of cement (TOC). Spacer and slurry designs and volume met fluid dynamics and mud removal requirements, which allowed ECD control and effective cement placement. Pressure values during pumping closely aligned with simulation results, which facilitated well-controlled execution and predictable job success. The appropriate selection of casing hardware enabled the crew to reach the casing point in each well and ensure sufficient standoff for optimal cement coverage. The operator's confidence in the design led to its use even when the previous casing was set beforehand, which allowed successful cementing of challenging zones traditionally left as pay zones.

The tailored solutions implemented in these ERD wells can help enhance best practices to achieve outstanding cement bonding and shoe integrity while cementing long horizontal pipe in weak formations with narrow ECDs.
Leveraging Machine Learning and Open Source Tools for Rock Image Characterization at the Pore-Scale
Authors: Al Ibrahim M. A.
Published: November 2024

Executive Summary

A software for pore-scale rock image analysis and interpretation has been developed based on open source tools and libraries. The software focuses on specialized workflows and processes for rock characterization rather than image processing workflows and tools. Example workflows implemented include grain morphology estimation, rock component identification, carbonate rock classification, and palynomorph darkness index calculation. Overall, the developed workflows provide quantitative results, improves the accuracy and lowers the bias in the interpretation.
Navigating the Future of Maritime Operations: The AI Compass for Ship Management
Authors: Joshva J. , Diaz S. , Kumar S. , Suboyin A. , AlHammadi N. , Baobaid O. , Villasuso F. , Konig M. , Binamro A. , Saputelli L.
Published: November 2024

The maritime industry stands on the brink of a technological revolution, with artificial intelligence (AI) at the helm. This paper explores AI's transformative potential in ship management, where it is poised to redefine roles and responsibilities within the maritime workforce. With the potential to automate up to 300 million full-time jobs globally, AI's impact on route optimization, predictive maintenance, and decision support systems is significant. The research underscores AI's role in enhancing fuel efficiency and operational effectiveness, setting the stage for a new era in maritime operations.

Through a comprehensive methodological approach that includes a literature review, benchmark, case studies, and discussions with key stakeholders—ship-owners, classification societies, and technology providers—the paper analyzes the technical and financial impact of AI-powered initiatives. It proposes a novel AI-based decision support system tailored to the unique challenges of ship management. The paper outlines a detailed governance structure for AI adoption, reflecting the industry's shift towards smart, eco-friendly ships. This shift is projected to increase the number of technical employees in the industry from 35,549 in 2018 to 49,000 by 2028, highlighting the growing demand for skilled professionals in this evolving landscape.

The findings reveal that AI significantly enhances operational efficiency and decision-making capabilities through predictive analytics and real-time optimization. The integration of AI initiatives, such as digital twins, is identified as a key future enhancement, potentially offering substantial efficiency gains and risk mitigation. The study also notes that 6.5% of ships in operation and 51% on order are capable of operating on alternative fuels, reflecting a growing uptake of methanol, LPG, and the first hydrogen-fuelled newbuilds. This trend underscores the industry's commitment to sustainable shipping practices and the pivotal role of AI in achieving these goals.

The study introduces a pioneering AI framework for ship management, emphasizing the need for a custom AI evaluation framework to assess and prioritize AI technology applications across the maritime industry. It suggests that sustainable value creation can be realized through AI adoption models, enhancing collaboration and regulatory compliance. The research highlights AI's potential to revolutionize the efficiency, safety, and sustainability of maritime operations, presenting transformative insights for the industry's advancement.
Real Time Efficiency Based Energy Optimization
Authors: Sengupta Subhendu , Goveas Vincent , Al Seyabi Mathla
Published: November 2024

This paper is based on successful implementation of dynamic efficiency-based optimisation in Habshan-5 Utility Boilers

Objective was to Minimize Loss Opportunities in optimal Fuel Gas Consumption in Boilers while maintaining steam balance across Habshan-5 Utility Steam network.

Thus, scope was

To Implement efficiency-based optimizer that allocate load among boilers based on their dynamic efficiency instead of equal allocation

To Minimize letdown between STS and STL to minimum allowable while ensuring stability of both STS & STL headers

Maintaining header balance across steam system accounting all consumers and producers

Original Method

Original Operation was Equal allocation based on STS header pressure. Hi Selector based PID controls the letdown.

Drawback

Package Boilers though identical, differ in efficiency due to various reasons.

Similarly, WHRB also differ in steam generation efficiency from duct firing.

There is a significant efficiency difference between WHRB and Package boilers & respective fuel consumptions. Also, variation existed in let-down opening with scope for optimisation.

Advanced Energy Solution (AES)

To meet the improvement needs, M/s Honeywell Advanced Energy Solution coupled with Honeywell APC was used.

Economic Load Allocation of boilers based on cost curve generated from reconciled efficiency (calculated dynamically using ASME method) curve.

Non-linear economic load allocation of boilers considering all constraints & efficiency curves are reconciled at every execution.

Multivariable Predictive Controller APC minimise Letdown opening.

Project Outcome

First of its kind in ADNOC, this real time dynamic efficiency-based optimisation resulted in significant reduction in Fuel Gas consumption & equivalent amount of GHG 24.7K Tons. Apart from this, the implementation completed in record low time (6 months) with payback period less than 4 months
A Novel Approach to Reduce Energy in Crude Transfer Operations
Authors: Nachiappan M. , Baudry M. , Saleh Ahmed. , Al Ali H. Abdulazi , Venkatesan K. , Brahmbhatt H. H. , Alebri F. , Chandran J. , Al Qassab I , Eisa Z. M. , Kadyrov I. , Finkbeiner N. , Zecha L.
Published: November 2024

As part of its 2030 Sustainability strategy, ADNOC set an ambitious target of reducing operational Green House Gas (GHG) emission by 25%. Inspired by this strategy, ADNOC Onshore Task force teams partnered with Contractors to pursue new technologies and best practices.

Main Oil Pumping from field to terminals in ADNOC is one of the significant energy consumers. The quest for energy efficiency prompted ADNOC Onshore to identify energy losses in the main oil pumping facilities and explore means to reduce it as much as possible.

As an innovative approach, it was decided to conduct a trial for reducing frictional pressure losses in the pipeline by injecting a Drag Reducing Agent (DRA) and optimizing the number of running oil pumps.

By injecting DRA, it was observed during the trial that the frictional pressure loss in the pipeline can be reduced significantly. Depending on the concentration injected (tested concentrations ranged from 7 PPMv to 20 PPMv), these frictional pressure losses were reduced by 50% to 66%. This reduction in observed pipeline frictional pressure losses meant the station discharge pressure could be reduced while still maintaining the same pipeline crude flow rate. By reducing the required station discharge pressure, one of the running main oil pumps would no longer be needed and could be stopped. This resulted in power savings of around 33% in one system (2 pump utilization against normal 3 pump operation) fields and around 50% in another system (1 pump utilization against normal 2 pump operation).

This paper analyzes the outcome of the trial study carried out using LSPI's LP 111 Flow Improver (‘LP 111’).
Stake-Less Nodal Seismic Deployment Using Internal GNSS Receiver
Authors: Garden M.
Published: November 2024

Pre-surveying receiver point locations is extremely time consuming and unreasonably lengthen seismic acquisition projects if the planned receiver grid is very dense. An alternative is to approximately deploy receivers and then use receivers internal Global Navigation Satellite Systems (GNSS) device for their final position. After some cleaning, these positions have an acceptable accuracy to be used in the processing of the seismic data.

Receiver deployment does not need accuracy. In practice it was carried out using a hand-held GNSS device, but it could have been done using simpler techniques like line of sight or steps counting. On the contrary, final positions need accuracy so that processing tools work optimally. While one GNSS measurement is not precise enough, repeated measurements at the same position are refined and combined into a much more accurate final position. Accuracy obtained following this procedure is below three meters in most cases, thus acceptable for all seismic processing algorithms.

Tests performed on real seismic datasets show that perturbations of less than six meters for receiver positions does not adversely impact the seismic image quality. Based on these findings, it was decided to make use of GNSS-derived horizontal coordinates. The accuracy of these coordinates, taken individually, is low but by combining several days of GNSS readings, the accuracy can reach acceptable levels, to below three meters. Since geophone nodes are usually deployed to the same location for several days or even weeks, large numbers of GNSS readings are available to be processed into a single accurate position. Raw GNSS vertical coordinates are even less accurate than horizontal ones and cannot been improved adequately. Instead, a Light Detection and Ranging (LiDAR) survey over the entire seismic survey area, provided centimeter accuracy for nodal geophones' elevations. Such LiDAR survey does not need to be concomitant to the seismic survey and thus does not hamper the seismic survey schedule.

Modern land seismic nodal systems onboard GNSS receivers. While GNSS receivers are primarily used in nodes to define times for recorded seismic traces, they can also provide horizontal coordinates of an acceptable precision simplifying greatly node layout and removing the need for lengthy and costly surveying operations.
Wireless Control and Monitoring; The Next Generation Downhole Completions
Authors: Abbott J. , Forrest K.
Published: November 2024

Dynamic downhole well production management has been historically limited to cabled intelligent completion systems. This paper introduces a new technology that provides wireless communication, control, monitoring and autonomy while being retrofittable for existing downhole well completions. The technology has been field deployed in three variants to address different challenges: remediate failed safety valves, restore downhole monitoring and provide flow control at a given interval. The field application of this technology has proven the feasibility and long-term performance of this wireless command, control and monitoring system under downhole conditions. It has also demonstrated the cost and CO2 savings of retrofitting versus recompletion.

The tool is designed to be deployed or retrofitted in an existing completion and record downhole data, responding to wireless commands from surface or operating autonomously in response to a change in a well's flowing conditions. Most variants were deployed via slickline intervention with the option to retrieve later in the well life. The intelligent safety valve is a fully autonomous system, API14A qualified, device that enables the safe production of wells with failed downhole safety valves. This valve was installed in both oil and gas wells to restore production under a variety of challenging production conditions. The intelligent control valve was installed to provide commanded flow control of a long lateral with a late life risk of water. The wireless gauge was trialled for retrofit to replace a failed downhole gauge and allow continuous downhole measurements in wells without existing gauges. We will review the field applications of this wireless technology and discuss the challenges overcome through application.

The production of five wells was restored by retrofitting the wireless intelligent safety valve. The valve successfully operated under a variety of challenging conditions including cyclic loading, gas lift, velocity string and slug production. The intelligent control valve successfully actuated to provide zonal isolation on a subsea well without intervention. The wireless gauge provided pressure, temperature and gauge diagnostics on a daily basis while recording shut-in data at high rates to capture valuable transients during well shut in. This data was compared with existing downhole gauges as part of a trial to validate the technology. The retrofit ability of this technology significantly reduced environmental impact and overall project costs.

This is the first publication that describes widespread application of this technology to address industry challenges. This is one of the only wireless control and command technology that does not rely on repeaters. The two-way communication method utilizes pressure perturbations in the production fluids to transmit downhole data or tool commands. The communications protocol allows for communication with multiple devices in the well and independent of depth.
Innovative Approaches and Lessons Learned from Longest Slim Hole Smart Completion Wells with Hybrid Cable: Twin Fraternal Well Monobore Case Study
Authors: Antoro Robertus , Al Zaabi Alyazia , Baranek Bartlomiej , Jinqiang Xue , Qasem Khalifa , Malalla Mohamed , Mwansa Peter , Bahroom Abdulraman , Al Soliman Abdulkareem , Waka Turky , Tleulin Artur
Published: November 2024

This case study aims to break down the engineering and operational strategies, along with the challenges faced in deploying the longest slim hole smart completion wells, with hybrid cable in a monobore configuration. The slim hole monobore smart completion design with twin fraternal were required as part of the Reservoir Monitoring Plan (RMP) in the Simultaneous Injection of Miscible Gas and Polymer (SIMGAP) project. It is a pilot concept to perform Enhanced Oil Recovery (EOR) with the purpose of increasing recovery factor (RF).

The twin fraternal wells, equipped with water injector and oil producer, have been presented with challenges due to material availability for 7" liner, 3.5" tubular, and completion accessories. These requires for a slim open hole size of 6" for a monobore, a completion made of carbon steel (L-80) and chrome resistance alloy (CRA P-110), additional line and completion accessories for the oil producer, and a targeted total depth (TD) of 13,000 feet measure depth (MD) in water-based mud.

Slim hole monobore deployment and smart completion in one trip are challenging due to the risk of longer stationary time in the open hole that can lead to differential sticking. Additionally, the risk of buckling with the small size of the tubing, and well tortuosity itself. It opted for a hybrid cable to improve the completion process and reduce the number of installed lines. Critical steps included open-hole preparation, operational strategy, and detailed execution, all defined by a comprehensive approach.

The first well completion installation as a successful case for the water injector, using carbon steel (L-80) material without a centralizer in the open hole, Limited Entry Liner (LEL) configuration in the lower part, successfully reached over 12,000 feet. The second installation was unsuccessful for the oil producer, which used CRA (Alloy SM2535) with a feed-through centralizer, additional lines for chemical injection, gas lift mandrels, and a tubing hanger groove. Despite the unsuccessful landing and completion to the planned TD, the second well reached over 12,700 feet MD.

This application represents the longest monobore slim hole smart completion as a journey in the UAE onshore field, The fraternal wells reveal successes and lessons learned from the other case, emphasizing adaptability and continual learning for similar applications in the future and successful deployment.
Integrating PVT Data of Complex Fluid Systems with the Regional Geology of the Northern Oman Fahud and Ghaba Salt Basins: Examples from the Haima Supergroup of Oman
Authors: Al Amri S. S. , Van Jaarsveld J. , Bell A. , El-Azhary A.
Published: November 2024

An integrated analysis of fluid property data of deep tight gas-condensate stacked reservoirs was coupled with regional petroleum system analysis across North-Central Oman to investigate variations observed in PVT data. The study, focused on the lower Haima reservoirs of the Haima Supergroup, aims to identify the broad links between the petroleum system and the PVT properties in order to delineate areas of varying properties within the basin and develop a common Equation of State (EoS) fluid model for modelling purposes.

The approach is based on investigating fluid property variation observed from PVT lab reports across multiple fields and reservoirs. Data trends were plotted against a range of key subsurface parameters for multiple fluid samples. A comparison of the fluid property data from PVT with the maturity and temperature history of the basin was carried out to understand property variation and link it with the regional geology. The process links PVT trends to Geochemistry by investigating HC maturity and mixing of Hydrocarbon sources. It also dives into the reservoirs’ temperature and maturity history within the basin.

The study focused on ensuring that the developed approach can help in understanding fluid property variation within the subsurface by integrating PVT Lab data with the charge history. While it was anticipated that reservoir stratigraphy and depth would have a direct relationship with fluid density and composition, the findings revealed that the complexity of charge history, hydrocarbon mixing, and temperature history significantly influence the observed variability. However, coming to this understanding can aid in identifying areas with potential for development, such as delineating uncertainty range of the fluid properties & CGR across the basins. Despite these insights, the common EoS model was found to be reasonably effective across the area of interest.

This workflow has provided good insights into the fluid history of the basin by linking PVT data trends and variation with observations from charge history understanding. It has also assisted in understanding the limitations of PVT modelling across complex reservoir fluid systems.
The Use of Bio-Distillate Marine Fuel To Decarbonize Marine Operations - Sea-Trial Experiment on A Small-Scale Vessel
Authors: Heyberger B. , Callu C.
Published: November 2024

Biodiesel blend is one of the multiple solutions that will contribute reaching the Carbon Footprint Reduction ambitions of the marine activities.

However, field experience has shown issues with the use of FAME due to its hydroscopic behavior, resulting in filter blocking, increase of maintenance, injectors fouling… These issues are mainly linked to microbiological contamination.

The objective of this test is to mitigate the risk of using biodiesel blends in small-scale vessels, representative of fishing and Exploration & Production activities, i.e. with engines from 150kW to 7 MW.

To demonstrate the possibility of using biodiesel blends on small-scale vessels, a sea-trial was performed on a rescue ship equipped with two twin engines, Iveco Cursor (346 kW). The fuel tanks were isolated to dedicate one tank to one engine. Tanks and piping were cleaned, and filters replaced before the sea trial. One tank contained DMA the other one DFA with 30% FAME. The engines were instrumented with lubricant and fuel sensors as well as emissions sensors. In parallel, DMA and DFA were submitted to an ageing in specific lab conditions to follow a microbiological growth if any.

The rescue ship is running on DMA (marine distillate) and DFA (marine distillate containing FAME) since July 2023 without any issue. The NOx emissions sensors don't emphasize any significant difference when the engine is running on DMA or DFA whereas the particulates matter emissions are reduced up to 50% at full load on the engine fueled with the DFA containing 30% of FAME. The crew didn't observe any dysfunction nor maintenance increase. The FAME content was increased to 50% without any issue so far.

The ageing study to follow the microbiological growth is performed on the first production of DMA and DFA. DMA and DFA were spiked with 1% of contaminated water and the DFA sample is considered without and with an additive package containing a bacteriostatic molecule. ASTM D7687 is performed on a monthly basis and ATP (Adenosine TriPhosphate) was not detected in any of the samples.

The demonstration of the smooth use of biodiesel blends on a small-scale vessel, with no adverse effect on-board the ship or in terms of pollutants emissions, is the essential step before developing a reliable and cost-efficient supply chain of biodiesel blends for offshore activities to reduce its carbon footprint. This solution can be implemented without any modification except a careful pre-cleaning of the tanks, fuel piping and filters onboard.
Decarbonising a Gas Processing Facility: Optimisation through Innovative Solar Thermal Technology in Northern Africa
Authors: Abdalla H. , Abdeljawed F. , Kriechbaum L. , Von Moy C. G. , Trofaier N. , Hunyadi-Gall M.
Published: November 2024

Integrating power from renewable energy sources (RES) into existing gas processing facilities to reduce their electricity and fuel consumption plays a crucial role in decarbonising the industry. However, the volatile nature and seasonal intensity fluctuations of RES introduce significant uncertainties when designing or optimising process facilities for technological and cost effectiveness to achieve the highest possible fuel and CO2 emission reduction. Detailed models and simulations based on historical weather and operational data supported by traditional engineering approaches and tools are required for this multidisciplinary iterative optimisation.

With the initial project goal to create a technology blueprint for decarbonisation initiatives in the gas processing industry, a comprehensive case study focusing on the integration of an innovative solar thermal technology into the gas processing facility of the Nawara gas field in Tunisia was conducted. The study's novel core technology is an inflatable concentrating solar thermal collector of proprietary design that is made of recyclable plastics suitable for sunbelt conditions. The primary objective was to demonstrate the engineering approach required for its optimal integration into the facility's existing process heat supply system, consisting of a single gas-fired heater and multiple consumers at various temperature levels, to reduce overall fuel consumption and increase economic viability. Thermodynamic models of the solar thermal farm and its integration into the process heat cycle were developed for performing time series calculations based on hourly resolved historical heat demand and solar radiation data to investigate optimal system tie-in, sizing, and operation. Additionally, design-relevant parameters like media temperatures and volume flows were determined to assist a projected basic engineering phase.

As the study showed, the substitution of heat from the natural gas-powered heater with energy from a solar thermal source is highly dependent on the design of the collector farm, its tie-in point, and the operational flexibility of the existing process heat supply system. During the evaluation of the various scenarios with different equipment sizes and integration approaches, fuel savings between 13 and 29% were attainable even without the implementation of a thermal energy storage unit for operation during nighttime. A follow-up risk assessment based on the study's results provided crucial insights into the operational aspects of the integration of the considered solar thermal technology, enabling significant risk reduction potential for the future development of respective assets. The case study is the first to examine the integration of solar thermal energy into a gas processing facility and is also the first commercial demonstration of the inflatable solar thermal collector technology at megawatt-scale.
Analyzing Limited Steam Chest Collapse in Thermal Oil Recovery: Insights from Field Data
Authors: Riyami Hamed , Chelladurai Samuel , Siyabi Majid
Published: November 2024

Steam injection has played a pivotal role in the evolution of Enhanced Oil Recovery (EOR) techniques, significantly enhancing hydrocarbon extraction from reservoirs. Applied mainly in heavy oil reservoirs where other forms of EOR are less effective, steam injection has proven to be a mainstay EOR method since the 1960s. However, developments are still being taken to understand the intricacies of the steam injection process in the field.

The findings presented are derived from extensive field data analysis on a steam injection field in Oman with more than 40 years of history, where steam is continuously injected in an inverted nine spot pattern steam drive project. The analytical evaluation of producers-injector communication reveals novel insights into the performance, efficiency, and optimization of steam injection for optimal extraction of hydrocarbons.

It was found that the behavior of water cut in producers can be adversely affected by shutting in nearby communicating injectors, especially, when an injector is shut in for a short duration and then started again. This does not allow enough time for the condensed water in the channels between the injector and producer to be withdrawn. This results in a waterfront development from this unflushed water which gets pushed from the injector to the producer, significantly increasing the water cut.

Field behavior has shown, the stopping of a steam injector can, in some cases, increase the water cut of nearby communicating producers. Steam injectors form pathways to producers, these pathways get heated and retain that heat as long as steam is injected. Both steam and oil flow in these channels. Intermittent shut ins of steam injectors interrupt the steam propagation within these pathways and introduces an imbalance in the system. Cooling the fluids in the reservoir will condense the steam and without the pressure drive from the injector, the water remains in the reservoir until the injection starts again. Once injection is started again, the pressure drive pushes the condensed water into the producer. The unfavorable mobility ratio of oil resulting from reservoir cooling, yield more water production compared to when the injector was running continuously.

The study investigates the physics behind the intermitting steam interruption and its implications on well and reservoir management, especially, steam injection strategy and how to minimize oil loss from intermittent steam injector shut in.
Cybersecurity in Oil & Gas 4.0: A Systematic Literature Review of Challenges, Threats, and Mitigating Measures
Authors: Alsalama Ahmed M. , Alzahrani Mona S.
Published: November 2024

Oil & Gas 4.0 refers to the journey of the oil and gas industry toward digital transformation as part of the Fourth Industrial Revolution. Enterprises around the globe are adopting technologies such as Artificial Intelligence (AI), Machine Learning (ML), Cloud Computing, Virtual and Augmented reality to boost overall business productivity. The oil and gas industry is an essential part of the energy sector that plays a vital role in the global economy. Like most international enterprises, this sector is susceptible to cyber-attacks due to its reliance on technology and digital systems. Cyberattacks on oil and gas facilities can cause significant damage to critical infrastructure such as pipelines, refineries, and drilling rigs. These attacks can disrupt the supply of energy resources and lead to environmental disasters. The oil and gas industry deals with sensitive data including information about reserves, production volumes, planned expansions, financial information, and intellectual property related to innovation and research. Cyberattacks can compromise this data leading to financial losses and reputational damage. For all oil and gas companies that are committed to the Oil & Gas 4.0 journey, cybersecurity presents complex challenges and major threats to the business. This systematic literature review aims to identify and analyze the cybersecurity challenges, threats, and mitigations in the oil and gas industry. This review includes comprehensive research of relevant literature published between 2014 and 2023. The findings reveal that the oil and gas industry is facing various cybersecurity challenges, including a significant increase of cyberattacks, a lack of awareness among employees, and inadequate cybersecurity measures. The review also highlights the different types of cyber threats faced by the industry, such as malware attacks, phishing scams, and ransomware attacks. These cyber threats present substantial challenges to the progress of oil and gas companies in implementing digital transformation strategies. This paper provides valuable insights into the current state of cybersecurity in the oil and gas industry and offers recommendations for improving cybersecurity practices to ensure a smooth digital transformation.