bluuebunny/crossref_metadata_2025 huggingface dataset:
Characterization of 3D Pore Structure in a Carbonate Reservoir Through Rock Typing: a Case Study of Khasib Limestone, Ah Field, Iraq
Authors: Chen Mingjiang , Zhang Qing , Li Hongxi , Han Chong , Yang Bei , Li Xiansheng
Published: November 2024

The Khasib limestone reservoir in the Ah oil field of Iraq is characterized by a variety of pore types and pore interconnectivity resulting in strong heterogeneity in fluid flow capability. To elucidate the underlying factors contributing to the elevated water cut and swift penetration of injected water in horizontal wellbores, this study proposes a novel methodology for characterizing pore structure variation within the three-dimensional reservoir space of the Khasib limestone, utilizing a rock typing approach.

Core slabs, thin sections, scanning electron microscopy (SEM) and mercury injection capillary pressure (MICP) curves obtained from cored wells are subjected to quantitative analysis. A multi-hyperbolic-tangent function is created to quantify the MICP curves and pore-throat size distribution is obtained. By integrating lithofacies and petrophysical properties, 24 rock types are identified in cored wells and spatial distribution of these rock types is elucidated through well-log clustering; Pore structure parameters, including pore types and pore-throat radii, are upscaled for each rock type by introducing a volumetric weight factor. Consequently, a 3D visualization of pore structure variation within the Khasib reservoir is achieved.

The Khasib reservoir is stratified into seven distinct horizons, with its effective pore-throat radius varying from 0.09 μm to 9.2 μm, showing an increasing trend upwards and a decreasing trend westward along the major axis of the structural anticline. Among these horizons, the Kh2-1-2L horizon, characterized by an average thickness of 0.8 m, predominantly comprises two rock types typified by interparticle porosity. These two rock types exhibit an average effective pore-throat radius of 8.53 μm and a permeability of 278 mD, surpassing neighboring rock types by several orders of magnitude. It is designated as the high-permeability "thief zone," serving as a preferential conduit for fluid flow and representing the principal factor influencing the rapid breakthrough of injected water.

The findings are corroborated through production logging and discernible variations in resistivity observed in vertical wells. These results hold significant implications for optimizing protocols to stabilize oil production and effectively manage water influxes. The method presented in this paper also provides a reference for production optimization in other types of reservoirs.
Developing Leaders Through a Transparent Succession Management Approach
Authors: Thomas Rincy Mariam , Al Ali Dhabia Majed
Published: November 2024

This paper addresses the concept of enhancing transparency in the succession process to drive ownership of successor development and create a sustainable talent pipeline.

The scope includes Line Driven Succession, which leverages technology to enable the identification and nomination of successors, forming a core component of this transparent approach. This aligns with strategic business goals aimed at developing future leaders.

The Line Driven Succession Process is a people-centric, data-driven approach that leverages technology to enable line managers to access and review talent data and provide nominations based on their authorized organizational level. Upon approval of the nominations, successors are informed of their inclusion in the ADNOC talent pool to facilitate targeted development.

This transparent approach empowers line managers and engages successors to actively pursue development in preparation for future opportunities. Key enablers include enhancing organizational maturity, fostering a growth mindset, providing career opportunities, engaging employees, and ensuring effective communication.

Transparency is implemented through a phased approach to cultivate organizational maturity and improve employee engagement and retention.

Leveraging technology and transparency in Succession Management represents a transformative approach for ADNOC, addressing the limitations of traditional succession planning and resulting in more efficient and effective talent management processes. Transparent Succession Planning aims to foster a culture of openness, ensuring business continuity and talent retention.

Following the implementation of Line Driven Succession, a survey revealed that 93% of participants were satisfied with the improved succession process. Initial observations from key stakeholders indicated that the transparent approach would motivate talent to drive their development. Conclusions underscore a shift towards fairer and more objective decision-making based on comprehensive talent insights.

This paper aims to provide new insights into the application of technology and the promotion of transparency in Succession Management processes. The Line Driven Succession project is novel in emphasizing the role of line managers in identifying and developing potential employees. Transparency ensures that stakeholders are well-informed about decisions and changes, fostering an environment of trust and collaboration.
Digitisation of Marine Break Away Couplings with a View to Improve Marine Hose Operations
Authors: Zandiyeh A R Kambiez
Published: November 2024

For offshore import and export of crude oil and other products systems such as SPM (Single Point Mooring), Floating Production Storage and Offloading (FPSO), Multi Buoy Mooring (MBM), etc. may be used. The main equipment that make up these systems can be summarized as the structure e.g. Calm Buoy, floating and submarine hoses. A typical SPM system is illustrated in Fig. 1 and the equipment used in these may be classed as critical enabling continuous and reliable operation of the system. However, these are at risk of damage and failure due to a range of factors such as tanker breakout, surge pressures, extreme environmental conditions, etc. Failure of any of these critical equipment can have catastrophic consequences such as environmental damage, system downtime, etc. To protect the entire system from damage Marine Break Away Couplings (MBC) are used and typically installed among the floating and submarine marine hoses. The location where an MBC is installed in a SPM system is highlighted in Fig. 1. An MBC is designed to activate at a pre-defined axial and pressure load protecting the system. Further, the MBC automatically energizes internal valves preventing the product from being released into the environment.

In the main, the design of an MBC has remained unchanged for over 30 years. In this period, although the industry has benefited from the safety protection offered by an MBC, on occasions the industry has experienced short falls in the operation of an MBC. For example, in case of an activation at night, it has not been possible to detect the activation, conduct an effective root cause analysis to determine the exact reasons for an activation, a partial separation of the two halves of the MBC has gone unnoticed, etc.
Reservoir Architecture and Channel Belt Mapping of Fluvial Systems: A Case Study from the Middle and Upper Members of the G Formation in the B Field, Central Oman
Authors: Al Mughairy Muthanna , El Ghali Mohamed
Published: November 2024

The G Formation is one of the most prolific hydrocarbon reservoirs in the Sultanate of Oman and is the target for extensive exploration and production campaigns. The study seeks to understand the reservoir architecture, depositional environments, and reservoir quality of the upper and middle members of the G Formation. In particular, Middle G 2 (MG2), Middle G 1 (MG1), Upper G 4 (UG4), and Upper G 3 (UG3) in the B field. Well correlation was conducted on 53 wells in the B field using the Petrel (2020) software for all G units. Paleogeographic (channel fairway) maps of G subunits were created with the aid of log signature analysis, petrophysical facies logs (reservoir rock typing), and paleocurrent analysis. Integrated reservoir descriptions "plumbing diagrams" scenarios were created and linked to the paleogeographic maps. A conceptual depositional model of Middle and Upper G was created based on this analysis. The reservoir quality of Middle G was assessed using log data and limited core data and linked with the previous findings of the study. Well correlation results indicate that MG3 was deposited in a shoreface environment. In contrast, MG2 and MG1 were deposited in a fluvial environment dominated by ephemeral channels and sheetflood deposits in an arid to semi-arid climate. UG4 was deposited above an erosional surface, resulting in compensational stacking in a meandering fluvial environment, while UG3 was deposited in a classical high-sinuosity meandering fluvial system (humid/tropical climate). MG2 and MG1 paleogeographic maps indicate two channel belt orientations trending NW-SE and NE-SW, with relatively wide channel belts. UG4 and UG3 show an overall channel belt orientation of NE-SW, matching the regional channel belt orientations. MG1 in the B field is Arkose to subarkose in composition, while MG2 is dominantly litharenitic to sublitharenitic. The reservoir quality of MG1 is highly impacted by clay mineral infiltration directly below an erosional surface. Conversely, the reservoir quality of MG2 is controlled by the rock fabric and compaction. The distribution of the reservoir properties in the B field was found to closely resemble the paleogeographic maps of this unit. This work presents a novel approach to mapping the distribution and deposition of complex and heterogenous fluvial reservoir systems. The use of a combination of log signature analysis (qualitative), reservoir rock typing (quantitative), and paleocurrent analysis is seldom seen in these types of reservoir systems. This study also outlines methods of predicting the reservoir quality of fluvial reservoirs when core data is unavailable or limited.
The Feasibility of Autonomous Flow Control Devices for Matrix Acid Stimulation Operations in Carbonate Reservoirs
Authors: Ganjoo Virochan , Moradi Mojtaba
Published: November 2024

The matrix acidization operation has been extensively associated with unconformity. The challenge remains to distribute the acid treatment fairly along the wellbore. It has been observed that acid prefers the less resistance spots along the wellbore which are characterized by high permeability streaks / fractures. During the operation, the injection to these areas is highest which further increases its permeability whereas low permeability zones never receive the similar treatment and are left out with lower permeability.

To counter this challenge, an approach of utilizing an advance completion consisting of Autonomous Outflow Control Device's (AOCD) was implemented.

Although there are multiple case histories of successful installation of AOCD in water injection wells for conformance, the high rate of stimulation operation poses a major challenge. This study involves developing a methodology to ascertain that a similar performance of acid stimulation can be achieved with much lower rates through optimization. This will be possible by conforming stimulation fluids through the wellbore, allowing operation to be executed at lower rates than Open hole or standard completion. The solution will also provide cost effectiveness as a much less volume of fluids will be required to produce better performance as compared to non-optimized completion. The study also involved upgrading a stimulation software to convert it into a fit for purpose platform which will incorporate the operational envelope of AOCD.

The AOCD is a rate-controlled device. At the heart of the device is a spring-based mechanism that reacts to the pressure drop/flow rate across the nozzle. Once a predefined upper flow-rate limit is reached at a zone, the valve autonomously closes. This eliminates the impact of the thief zone on acid injection conformance and maintains a prescribed acid distribution.

The technology is proven in water or polymer injection wells; this study highlights the value addition that AOCD can bring to matrix stimulation operations; further presenting AOCD as a fit for purpose solution for injection wells irrespective of the injection type or application. A novel approach is developed through modelling to display that Autonomous Flow Control Devices can provide substantial value in stimulation operations. This will enable the operators to minimize the impacts of heterogeneity on the acid conformance and the completion system will autonomously respond to a dynamic change in reservoir properties, specifically the growth of wormholes.
Understanding High-Frequency Torsional Oscillations HFTO in Rotary Steerable Applications: Observations, Learnings, and Tales of Caution
Authors: Wilson J. K. , Robles E.
Published: November 2024

High-Frequency Torsional Oscillations (HFTO) continue to be a challenge for Rotary Steerable System (RSS) Performance. While ruggedization of downhole tools has improved significantly over the years and has enabled tools to survive these violent events, excessive vibrations can still lead to drilling inefficiencies, shortened lifespans of components (increased replacement rates during tool servicing), or occasionally errors in sensor readings. This study shares some key observations during HFTO events including relationships between other vibration modes, behavior with other commercially available vibration mitigation tools, mitigation strategies, and practical limitations.

Case histories are presented highlighting HFTO behavior and what this vibration mode looks like within drilling data. Real-time, log, and high-frequency data are all examined to illustrate the differences and variability of each. Mitigation strategies are addressed in detail, looking at parameter adjustments, changes to the Bottom-Hole Assembly (BHA), and different types of dedicated vibration mitigation tools. Benefits and shortcomings are shown for each.

Results show the benefit of planning for this type of vibration event and illustrate how the specific drilling application can impact the dynamic response of the BHA. Some unique dynamic characteristics have been observed and are discussed. One such behavior that has been noted is the presence of a torsional beating phenomenon when utilizing a torsional spring-like type of vibration mitigation tool. The physics of this behavior is further examined through detailed modeling and simulation, accurately replicating the observed field measurements. General HFTO observations over the years have also led to the development and implementation of a new at-bit viscous damper type of HFTO mitigation device. Due to the success of this at-bit mitigation device, it has been integrated directly into the Rotary-Steerable System (RSS), removing the need for additional tools or connections in the BHA, and is now a standard technology on all RSS deployments.

The data presented in this study is the first documented case of a torsional beating phenomenon during an HFTO event. In addition to this, general HFTO observations are shown in a concise format to share the knowledge gained thus far with this type of vibration. The success resulting from the implementation of the only at-bit HFTO mitigation device is also highlighted.
Non-Metallic Low Carbon Footprint Solutions – Qualification of Structural Materials and Case Study of Modular & Adjustable Pipeline Crossing Supports
Authors: Brattekås Jon Inge , Berg Mathias V.
Published: November 2024

CSUB has developed a modular and adjustable Pipeline Crossing/Freespan Support designed to support pipelines subjected to freespan due to uneven seabeds or scouring. This support can also be used for crossing supports of rigid pipelines. CSUB has qualified the use of Glass Fiber Reinforced Polyester (GRP) material in accordance with DNV standards, leveraging over three decades of extensive use. The main findings indicate that high-quality GRP is environmentally benign, exhibits very low degradation in seawater, and is well-suited for offshore applications. These conclusions are corroborated by independent third-party evaluations from organizations such as DNV. The Adjustable Pipeline Crossing/Freespan Support is patent pending.

CSUB wish to acknowledge Mr. Qasim Saleem at Offshore Pipeline Department of Aramco for valuable insight and contribution during the development and testing of the Adjustable Pipeline Crossing/Freespan Support.

The Adjustable Freespan Support was tested at CSUB's factory in Arendal in 2023. The tests involved pulling the foundation under the pipe on a concrete floor, installing wedges, and securing them using a threaded mechanism. The objective was to demonstrate the functionality of the support and measure the operational loads.

Tests were conducted using 8" (1250 kg) and 28" (4840 kg) pipes with two sets of wedges, 15 degrees and 30 degrees. The recorded loads for maneuvering the freespan support equipment are as follows: Table 1Recorded loads for maneuvering of freespan support equipmentTaskMaximum forceCorresponding friction factorPulling foundation under pipeline1160 kg0.62Moving wedge into position, manually55 kg0.34Table 2Measured torque/load taken from 28" pipeline with weight of 4840 kg and maximum lifting height of pipeWedgeTorque appliedResulting lifting forceMax. lifting height15° Wedge100 Nm4840 kg220mm30° Wedge100 Nm2220 kg645mm150 Nm3640 kg200 Nm4840 kg

The tests proved that the Pipeline Freespan Support operates as intended for:

Movement of assembly under pipeline Wedge operation, including connection to the threaded rod and lift mechanism, effectively transferring the pipeline load to the support.
Research and Experiment on Electrification Technology for Deep Heavy Oil Reservoir
Authors: Yang L. L. , Yuan A. W. , Long H. , Zhang F. X. , Wu X. M. , Yang X. , Yang X. Z. , Liu F. S , Li C. X.
Published: November 2024

Focus on the problems such as high energy consumption, high carbon emission and low steam dryness in deep heavy oil, research and field test on electrification technology and supporting technology series had been carried out. And three types of electrification technology series had been developed. According to the characteristics of different oil Wells, the corresponding technology of downhole high power electric heating assisted steam injection to increase dryness had been formed. Through numerical simulation analysis, the principle of increasing dryness by electric heating assisted steam injection and the application limits of reservoir were defined. The regulation method of electric heating power was established in combination with the construction of ground wind power and solar power. Field tests showed that the electrification technology series could effectively meet the oilfield production needs and provide technical support for green and low-carbon development of deep heavy oil.
Integrating Solar Farm for Sustainable Oilfield Operations
Authors: Tagong K.
Published: November 2024

Objective

PTT Exploration and Production Public Company Limited (PTTEP) is currently the operator of S1 oilfield located in Kampheangphet province, Thailand. Previously, the electricity used in operating the S1 oilfield was primarily generated by in-plant Gas Turbine Generators (GTG) fueled by natural gas. Recognizing the importance of sustainable energy development, PTTEP initiated "Lan Sang Arun project", a 9.98 MW solar farm designed to provide green energy to support the operations of the S1 oilfield and reduce carbon emission.

Method and Procedure

The project involves building a 9.98 MW solar farm and the related infrastructure to supply green energy to support S1 oilfield operations. Integrating the solar farm into the S1power management system presents unique challenges. Unlike most conventional solar farms that connect to either the grid or the user, Lan Sang Arun plant is a special case because it connects to both the in-plant gas turbine generators and the public grid. The power management system required modifications to enable smooth power control between the solar farm, the GTGs, and the grid.

Results, Observations, Conclusions

The solar power plant was successfully constructed and started operation in July 2023. The renewable energy generated from an Sang Arun solar plant are now used to support the operation of S1 oilfield, reducing the natural gas consumption by approximately 0.5 million cubic feet per day, which lead to carbon reduction of 13,000 tCO2e per year.

Novel/Additive Information

Lan Sang Arun solar farm is the first project in Thailand to supply electricity from a renewable source to support petroleum operations. It contributes to both PTTEP's and Thailand's net zero greenhouse gas emission targets and serves as a showcase for oilfield electrification in Thailand.
Successful Application of Integrated Fiber-Optics with Coiled Tubing Operations Enhances Acid Stimulation Treatment
Authors: Ahmed Usman , Noguera Jose , Alfonzo Ruben Ortega , Chishti Sadaf
Published: November 2024

Matrix-stimulation methods are often applied in Carbonate reservoirs to ensure uniform distribution of treating fluids / acid and successful stimulation in the hydrocarbon-producing wellbore. The treating fluids typically take the path of least resistance (or high permeability zones), thereby requiring the use of diverters for effective stimulation of low permeability and/or damaged zones. However, under downhole conditions, it is challenging to directly determine, measure, or simulate the effect of a specific acid / diverter operation. As a possible solution, distributed temperature sensing methods can be used to understand the complex downhole dynamics, effects of treating fluids on the formation (through transient temperature response) and most importantly, qualify and quantify the success of a stimulation operation.

Of interest to this study is a horizontal, open-hole producer well in the prolific Carbonate formation in one of the major fields. As part of the objectives to effectively optimize acid and diverter placement, an integrated fiber-optics enabled coiled tubing intervention operation was planned for this study. The technology involved deploying a 2.375-in. coiled tubing string with a 0.125-in. tube wire housing a triple fiber-optic cable. Distributed temperature sensing (DTS) measurements were taken at several stages of pre-and-post stimulation that involved visualization and interpretation of temperature traces to identify fluid distribution and optimize acid-diverter strategy.

In a systematic process, DTS surveys at depth for two scenarios: well base-line conditions followed by pre-stimulation solvent treatment were first conducted. The DTS analysis included heat maps and transient temperature curves along the entire wellbore. Comparisons between the baseline and pre-stimulation flush conditions provided qualitative insight into areas of the well that took a greater proportion of the pre-treatment fluid. This information was then used to revisit the original acid-treatment plan and update the stimulation plan to optimize the acid-diverter placement in target zones. As part of the optimized strategy, 45% of the open hole was treated with a proprietary acid-diverter system and the remaining 55% with 20% HCl acid.

This unique approach of fiber-optics enabled coiled tubing operation and analysis resulted in an optimized acid program reducing the total acid volume by over 30%, thereby saving the operator around 20% from the allocated budget on this well. In summary, the data presented here demonstrates that the distributed nature of fiber-optics monitoring in conjunction with intelligent coiled tubing and pumping strategies can be effectively used to improve and optimize future acid-stimulation jobs.
Introduction of Stimulation with Single-Phase Retarded Acid Help to Achieve Superior Results in Highly Depleted Reservoir Newly Drilled Wells Offshore Republic of Congo
Authors: Mutschler V. , Gallut J. , Lamiable A. , Bremner S. , Artola P. , Reyes J. S. , Boussaidi L. , Tardy P. M. J.
Published: November 2024

Redevelopment of the Tchibeli main field in offshore Republic of Congo began with the drilling of five new wells targeting the Upper Albian formation. Being carbonate in nature, these reservoirs benefit from initial hydrochloric (HCl) acid stimulation to enable and promote economic production. A project was devised with a stimulation vessel pumping single-phase retarded acid and a particulate/fiber-based diverter.

The wells were drilled and completed with a 9 ⅝-in. cemented casing. This casing was perforated using 7-in. tubing-conveyed perforation (TCP) guns with a shot density of one to six shots per meter. A single well was completed using a ball-actuated fracture port completion with the target of completing three acid fracturing stages in a single well. For this well, acid fracturing modeling software was used to predict fracture coverage and ideal placement of fracturing ports. Optimization of stimulation fluids was carried out using core flow testing with formation cores. Analysis of the cores showed a variation in permeability to gas (10 md to 2,000 md) and carbonate content across the pay zone. By investigating different fluids and injection rates, engineers were able to optimize treatment design and react during operations without compromising on quality. Degradation tests of the particulate diverter were conducted and evaluated to ensure the correct product used.

Well stimulation operations were carried out using a stimulated vessel to enable efficient use of time and achieve large stimulation design volumes in one bullheading pumping operation. During the process, three stages were completed in a single load out for the acid fracturing candidate at rates up to 40 bbl/min. This was followed by the completion of three matrix wells in a single load out, with the final well being completed at a later date. All these stimulations were performed offline with the rig performing the flexible drilling and completion sequence. Post-stimulation production results were analyzed and matched with the stimulation software production model to further improve the accuracy of the simulation.

This campaign used a combination of single-phase retarded acid for matrix and acid fracturing operations, plus degradable particulates and fiber diverters to achieve complete zonal coverage of matrix treatment. Core testing showed pore volume to breakthrough (PVBT) results in high-permeability cores above 345 md. Plus, cores were used with high calcite content instead of the traditional dolomite/limestone lithology that is often presented in PVBT results. The combination of core data and production prediction was able to further develop stimulation fluid placement in modeling software.
Improved Method of Estimating Cable Pull-In Resistance by Factoring Variable Seabed Friction as a Function of Cable Displacement
Authors: Onesto S. , Cheryian K. , Aldo M. , Ashton G. , Brunning P.
Published: November 2024

The aim of this technical paper is to present an enhanced methodology for improving the estimation of subsea cable resistance (pulling loads) during cable pull-in. The methodology has been proposed based on a validated case study demonstrating the cable second end pull-in by considering the seabed friction in terms of the changes in cable displacement. The product under installation in this case study was a power cable being pulled into a J-tube. Accurate estimation of friction coefficients are essential for the reliable estimation of pull- in loads. Hence, a detailed geotechnical study has been performed and presented.

During the pull-in, the power cable must overcome the seabed friction, which includes lateral and axial components, both of which depend on the soil embedment and resistance. Unlike the conventional industry approach, in this methodology, the pull-in tension and loads are estimated by factoring the impact of breakout friction and residual friction explicitly (discrete friction values for every cable displacement value). Variable soil friction coefficients based on cable displacement have been defined during the study. Improved reliability in predicting the pull-in load is of benefit for accurately designing the product under installation, the pull-in head, selection of the platform winch, winch wire and other accessories. The design parameters for the pull-in analysis include maximum allowable pull-in load of the cable, seabed topography and cable surface roughness.

The results of the case study which are operationally significant are the maximum pull-in load at the platform winch and maximum load on the cable pull-in head. In general, the pull-in loads at platform winch and cable pull-in head are observed to be maximum and equivalent when the cable pull-in head reaches the platform topside. However, for specific cases when the breakout friction is significant due to the cable embedment in the seabed soil, the peak pull-in loads are observed at the commencement of pull-in. This peak load developed on the cable pull-in head is amplified at the platform winch due to the capstan effect arising from the J-tube curvature and friction between the cable and J-tube. It is evident from this case study that the definition of breakout friction and residual friction as a function of cable displacement is relevant, when the effects of soil embedment (breakout friction) dominate the resistance.
Enhancing Engineering Document Analysis Through Structured Data Mapping
Authors: Rascanu G. , Dzhusupova R. , Guo Z.
Published: November 2024

This paper presents an innovative approach for mapping engineering documents, particularly unstructured PDF files, to knowledge graphs, offering significant benefits for both engineering processes (i.e. such as ‘review-check-approve’ process) and AI-powered development.

The method aims at improving efficiency, enhancing decision-making capabilities, reducing document turn-around duration, and thus decreasing costs while increasing productivity.

Specific advantages include: Quick overview for reviewers to prioritize tasks - more weight can be given to identified main topics with less time on the side topics.Improved quality: interrupted relationships and isolated entities may indicate inconsistency that is usually overlooked in the traditional review process.A faster review process achieved through common understanding between reviewers, resulting in a subjective time reduction (average 10% improvement) while enhancing quality.

Our method leverages advanced natural language processing (NLP) techniques, sentence transformers and large language models (LLMs) to transform complex document content into structured knowledge visual representations. This approach addresses the challenge of efficiently extracting information from unstructured engineering documents by first identifying relevant keywords, that align with the main topics of the document, through a robust initial process. The extracted keywords define the framework upon which the entire knowledge graph is built, ensuring its relevance and utility.

Central to our methodology are novel techniques in LLM-based prompt engineering that enhance entity and relationship extraction in complex engineering contexts. These techniques incorporate chain-of-thought reasoning for improved accuracy. Furthermore, we introduce a robust process of relevant keyword extraction as an initial step, which sets the foundation for all subsequent stages from entity extraction to final graph presentation.

The resulting knowledge graphs serve as a method of enhanced visual understanding of documents that are often complex and difficult to comprehend through human analysis alone. By extracting patterns and connections that would otherwise be challenging to identify or understand, these graphs facilitate simplified document comprehension and improved data integration.

Our proof-of-concept results demonstrate the effectiveness of this method in supporting decision-making processes in the energy sector. Using this methodology as the ground base we outline directions for future AI development applications such as generating contextually relevant responses of the interrogated documents, summary creation and integration with other AI technologies.
Large Scale Electric Heater
Authors: Ahmed-Seddik Bouhadjar , Kolhe Pushkar , Kumar Navlok
Published: November 2024

Decarbonizing industrial heat is paramount for achieving climate targets and facilitating a successful energy transition. High-temperature industrial processes, often exceeding 500°C, present significant decarbonization challenges due to their heavy reliance on fossil fuel combustion. This is particularly critical for energy-intensive sectors such as oil and gas, iron and steel, cement and minerals, chemicals, and pulp and paper.

Electrification emerges as a promising solution for these industries; however, current technologies capable of achieving the requisite high temperatures and scalability are limited. This paper introduces a groundbreaking technology: the electric heater utilizing inductive technology. This system generates heat through induced current in the secondary coil, which is subsequently transferred to the gas or fluid used in the process.

Powered by low-carbon electricity, the electric heater is poised to become the preferred choice for numerous energy-intensive applications. This innovative inductive heater technology offers a sustainable and scalable solution for process heat. Successful proof-of-concept testing at a 0.5 MW scale has demonstrated the inductive operating principle and its performance.

Leveraging materials and design practices proven in generators and power transformers, the inductive heater is projected to achieve temperatures exceeding 1000°C at a power scale of 1000 MW. This technology provides a viable decarbonization pathway for various industrial processes and offers potential operational value through end-user co-creation. The inductive heater not only addresses the high-temperature requirements but also aligns with the global push towards sustainable energy solutions, making it a critical component in the future of industrial heat management.
Alternative Remediation Technique for Safely and Reliably Performing Single-Trip Perforation and Squeeze Operations
Authors: Arabie Blake , Koppenhaver Carey
Published: November 2024

Complex wells lead to complex abandonment strategies, which lead to creative solutions for early-life to end-of-life well operations. When balancing unknown well conditions with personnel safety, operator standards, and government requirements, effective solutions that satisfy all are difficult to develop. Multiple well entries are often required, exposing the operator to costly, time-consuming, and high-risk operations. Successful well intervention is critical for well integrity, maximizing oil and gas production, and ensuring operational safety.

In the case of a Hess-operated deepwater well in the Gulf of Mexico, drilled in 2006 and temporarily abandoned in 2007, the complexity of well entry was high due to the development of multiple flaws in the wellbore. A risk assessment of a traditional multi-trip system resulted in high-risk well integrity issues, subjecting the team to potentially severe safety breaches, leaving the team to devise an innovative alternative. Through collaboration between Oilfield Services Professionals (OSP) and Hess Corporation, a single-trip system solution reduced risk and provided a safe plan forward.

This paper introduces the alternative single-trip remediation technique designed for safely and reliably performing perforation and squeeze operations. The proposed method integrates hydro-mechanical perforation technologies with an improved squeezing mechanism, enabling the execution of both processes in a single trip. This integration reduces operational time and minimizes the Health, Safety, & Environmental (HSE) impact and risks associated with standard practices.

Through a series of pre-job qualifications and field studies, this technique successfully demonstrated significant improvements in operational efficiency and safety. The application of the developed solution provides a comprehensive evaluation of the single-trip system's performance, including comparisons with traditional methods and discussion on its versatility for various wellbore designs. The results indicate a notable reduction in non-productive time (NPT) and enhanced control over the perforation placement and quality of cement squeezes. Adopting this single-trip approach enhanced well-remediation operations, offering substantial cost savings and improved safety outcomes for the oil and gas industry.
Maximizing Efficiency: Coiled Tubing Success in Cutting Needles for Fishbones Completion
Authors: Sissembayev N. , Al-Braiki A. M. , Bakri H. , Turniyazov N. , Soliman I. , Malak M. , Rashid S.
Published: November 2024

This paper delves into a groundbreaking approach aimed at enhancing Weil stimulation in tight reservoirs through the utilization of Fishbones technology. The specific objectives of this study include the deployment of Fishbones completion, activation of needles using high-volume acid, and the cutting of needles without the need for a rig, achieved through the innovative use of Coiled Tubing.

The methodology employed in this study involved the installation of Fishbones completion following the drilling process. Subsequently, the needles were activated using high-volume acid pumping, and the cutting process was executed using Coiled Tubing without relying on a rig. This entire process was meticulously planned and executed with a keen focus on ensuring safety, operational efficiency, and minimizing environmental impact.

The results obtained from this project serve as a testament to the feasibility and effectiveness of utilizing Coiled Tubing for the purpose of cutting Fishbones needles. The findings from this study underscore the potential of Coiled Tubing as a viable alternative for needle cutting in Fishbones completion, offering substantial advantages over conventional rig-based methods. There are certain risks when cutting the needles with Coiled Tubing related to Coiled Tubing lockup. However, this could be greatly optimized using higher size Coiled Tubing and aviso taking precautionary steps when deciding to cut more than two subs per run. Cutting all needles was not implemented completely, however it didn't stop this approach resulting in the achievement of the main objective of avoiding the post stimulation brine loss.

Furthermore, this paper presents a novel contribution to the petroleum industry by presenting a successful case study that demonstrates the efficacy of cutting Fishbones needles without the need for a rig, using Coiled Tubing. This innovative approach not only enriches the existing body of literature but also offers a cost-effective and efficient solution for enhancing well stimulation practices. By disseminating these findings, this paper aims to contribute significantly to the industry's collective knowledge and inform best practices in well stimulation operations.
New Hybrid Completion Technology for Tight Carbonate Reservoir Productivity and Injectivity Enhancement
Authors: Rachapudi R. , Alshehhi S. , Mogensen K. , Chaudhry M. , Barragan E. , Utama I. , Abdussalam F. , Karbi H. Al , C Wissam , Fishbones Malak. M , J Sami , L Javier Antonio , B Noureddine , S Alexander , R El Sayed , S Saleh Ali , S Shamma. Al
Published: November 2024

Tight carbonate reservoir productivity & injectivity enhancement along with sustainability has been a challenge in the oil and gas industry for an extended period. Limited entry Liner and Fishbone technique are two technologies that can stimulate the entire horizontal section. In this work, we devise a hybrid method to combine both techniques together to deliver deep worm holing.

New liner completion technology, consisting of partly liner subs to introduce special needles that can penetrate deeper into the formation up to 40 ft i.e., and remaining liner subs with special holes that can jet the acid is under piloting. This innovative technology has the capability to connect sublayers & natural fractures that improves the poor vertical communication (low Kv/Kh) within the target zone and simultaneously can stimulate the horizontal section to bypass the near well bore damage. In addition, this technology provides a flexible option for deep stimulation of the reservoir during installation, followed by near well bore stimulation using liner holes as a second step after a certain production duration. This flexibility provides a backup option for regaining sustainability after a production period. The liner holes offer the possibility to improve the overall stimulation efficiency by generating worm holing in-between adjacent needles.

This innovative technology pilot is under implementation at field A. The reservoir is a tight carbonate reservoir with a permeability range of 1-2 md. The present strategy is to install Limited entry liner completions as part of the field development. However, with this successful Implementation of new pilot with special liner completion increased the production rate up to two times will provide a chance to revise field development plan with special liner technology in the upcoming new well drilling campaign. This paper will provide the details of the technology, well selection, completion design, implementation steps, pilot results along with lesson learned for inclusion as part of next Implementations. Further discuss about well monitoring plan, data collection and performance evaluation of the pilot. In summary this technology will provide a backup option to conduct stimulation in case sustainability of well productivity needs to be reestablished and overcome the current limitation of advanced completion stimulation techniques

This technology is an invention that combines deep acid stimulation technique and near well bore jetting with an option to execute them either together or separately.
Development of Fast Predictive Models for CO2 Enhanced Oil Recovery and Storage in Mature Oil Fields
Authors: Peralta Yessica , Ganesh Ajay , Zambrano Gonzalo , Chalaturnyk Rick , Shokri Alireza Rangriz
Published: November 2024

Reservoir modelling tools have played a significant role in designing the subsurface fluid injection, such as CO2 enhanced oil recovery (EOR). However, these models are computationally expensive; they require extensive geological and engineering data that often are not available in the early phase of carbon utilization and storage projects. This work presents the development of fast predictive models and optimization methodologies to quickly evaluate the CO2 EOR and storage operations in mature oil fields.

Considerable experience with CO2 EOR and storage has been gained by the petroleum industry. In particular, the Weyburn-Midale project (Canada) is a comprehensive case to show how an oil reservoir could securely store CO2. Employing the Weyburn-Midale project, we developed, trained and tested several types of proxy models in multiple scenarios to assess the performance of the miscible CO2 flood in recovering residual oil, increasing the ultimate oil recovery factor while maximizing the permanent CO2 storage.

The history matching of the Weyburn-Midale CO2 EOR model involved 216 well histories (producers and injectors) from 1964 to 2006 using a compositional reservoir simulator. The predominant exploitation scheme was based on an inverted nine-spot pattern waterflooding, water alternating CO2, and consequently CO2 injection. Two simulation data sets were employed at different periods of 1956 through 2006, and 2007 through 2025. Among several proxy models, an artificial neural network (ANN) model proved to accurately estimate features of interest, namely fluid production (oil, water, gas), fluid injection (water, CO2) and the amount of CO2 stored in the reservoir. Additionally, an autoregressive exogenous input (ARX) model was implemented to predict the future outputs in response to a future input. Inspection of the relative estimation error and the model fitness score showed that the proxy model was capable of rapidly reproducing the trend in the validation set satisfactorily. Lastly, we evaluated the transfer of learning from a proxy model, trained to the Weyburn-Midale field (Canada), to assess the performance of CO2 EOR in another mature oil reservoir in Europe (Romania).

The application of proxy models under geological and operation uncertainties offers huge reduction in computational time and engineering data requirements. The results from the Weyburn-Midale case study deliver critical insights into the analysis of many process factors and modeling techniques intended to assess the economic limits and long-term performance of CO2 EOR and storage in mature oil fields.
Case Study: Edge Computing Solutions for Well Performance Monitoring and Asphaltene Detection in Deep Carbonate Reservoir, Greater Burgan Oilfield
Authors: Al-Shammari A. , Al-Azmi N. , Sinha S. , Agarwal S. , Al-Mutairi H. , Shamsaldeen M. , Al-Shamali A. , Harami K. , Abdulrahim K. , Robert H. , Parker A. , Biya A. , Hernandez M.
Published: November 2024

A huge amount of sensors data is daily being generated from a single well site, posing challenges for data transmission, storage and analysis. Marrat reservoir is adeep carbonate reservoirs in Greater Burgan Oilfield and is prone to asphaltene deposition. The present study leverages Edge computing technology which may revolutionize data processing, analysis, and algorithm-based decision making to enhance well performance in a cost-effective manner.

This case study illustrates a pilot project of an on-prem edge computing infrastructure. The project particularly focuses on monitoring well performance and tackling asphaltene problems. The utilization of edge computing in this context introduces two outstanding solutions: the virtual flow meter (VFM) and asphaltene problem detection module. The VFM solution is based on a combination of data-driven and physics workflows. While the Asphaltene module quantifies the asphaltene risk by utilizing fluid data and asphaltene precipitation envelope for well operating conditions. Numerous physical well tests and fluid sampling have been carried out to validate both the solutions.

The data-driven Virtual flow meter (VFM) has demonstrated a very high model accuracy over the test period, which signifies the reliability and potential of edge computing in the field. This solution seeks to estimate flow rates without the need for conventional flow meters, resulting in optimizing the frequency of wells production measurements and operating expenses. Through the estimation of real-time flow rates and asphaltene risk, a proactive wellbore clean-out job could be run to prevent any production losses due to asphaltene blockages. This study shows an opportunity of field scale implementation, which potentially will help in managing and optimizing reservoir performance.

The edge computing technology provides an innovative approach which enables real-time access to all the pertinent well information. The developed modules can be reliably used to identify potential well issues for early resolution and avoid significant production deferral. Asphaltene detection module will not only reduce the downtime but also deliver insights for production assurance, reservoir management and field development planning.