bluuebunny/crossref_metadata_2025_split huggingface dataset:
Unlocking Geothermal Potential: Advancing Exploration with Artificial Intelligence for Sustainable Energy Solutions
Authors: AlGaiar Mahmoud. M. 
Published: November 2024

Abstract
The objective of this study is to investigate the potential benefits and challenges of integrating Artificial Intelligence (AI) into geothermal exploration for resource identification and drilling location optimization. The scope includes investigating the application of AI algorithms in the analysis of subsurface datasets to improve prediction accuracy and reduce uncertainty in geothermal resource evaluation.
A critical review of published articles on AI applications in the geothermal industry was conducted to gain insight into the effectiveness of AI models in resource exploration. Various AI algorithms such as Logistic Regression, Artificial Neural Networks and Decision Tree were analyzed for their contributions to geophysical and geochemical data analysis in geothermal exploration. The review focused on the identification of hidden patterns in large datasets using AI algorithms to improve the understanding of subsurface properties and to locate hidden/blind geothermal systems. The analysis involved evaluating the performance of different AI techniques in predicting reservoir properties, lithology and fluid content based on geochemical and geophysical data. The results of the study demonstrate the significant potential of AI in improving the accuracy of predicting geothermal reservoir properties and optimizing drilling locations. AI models outperformed traditional expert-based and statistical methods, demonstrating their effectiveness in uncovering hidden geothermal resources and reducing exploration risks. Observations from the review highlight the importance of collaboration and partnerships within the geothermal industry to leverage multiple datasets and insights for improved efficiency and productivity in energy development. While there are challenges such as model transferability between locations, the continued growth of AI in geothermal exploration provides opportunities for further research and development of deep learning techniques. The increasing use of AI in geothermal exploration indicates a shift towards data-driven decision making and advanced predictive modelling techniques.
Optimal Matching of Multi-stage Fracturing Parameters with Geological Characteristics in Shale Gas Well Based on Deep Learning Algorithm
Authors: Luo Yang , Kang Bo , Qu Jianhua , Wang Hehua , Mi Zhongrong , Cheng Yi , Xiao Yong , Zhao Xing , Feng Yan , Guo Jianchun , Lu Cong 
Published: November 2024

Abstract
Multi-stage hydraulic fracturing in horizontal well is a pivotal technology for the efficient development of shale gas reservoirs. Given the pronounced heterogeneity along the horizontal section, precise matching of fracturing parameters with geological characteristics in each fracturing stage is imperative for enhancing well productivity.
In this paper, a data-driven productivity prediction model at the stage level was established based on field data and the Gate Recurrent Unit (GRU) algorithm. Fracturing and geological features in each stage was integrated as the model input matrix, and an additional mask layer was employed to accommodate varying stage numbers among different wells. To achieve optimal matching between fracturing parameters and geological characteristics, a novel variable-dimension optimization algorithm was proposed. Aiming at maximizing well productivity, this algorithm can determine the optimal number and positions of fracturing stages according to the geological profile and generate corresponding fracturing parameters.
Trained with real data from over 120 wells in Sichuan basin, China, the productivity prediction model achieved a robust performance with a mean relative error (MRE) of 10.1%. This MRE represents a 34.3%~67.7% improvement over traditional multilayer perceptron and random forest models, demonstrating the significance of extracting features in each stage. Optimization results for a representative well case indicate that to maximize productivity, the optimal stage number is 28, with stage length ranging from 51m to 91m, and fracturing parameters tailored to the geological characteristics in each stage. Furthermore, post-fracturing optimization, micorseimic monitoring reveals a 32.3%~44.5% increase in stimulated reservoir volume compared to adjacent wells, resulting in a productivity boost of 21.2%~35.7%.
Unlike manual stage division and separate fracturing parameters optimization in each stage, the approach proposed in this paper can identify the optimal stage number, stage positions and fracturing parameters in each stage perfectly matching the geological characteristics. This study provides a novel framework for the fracturing parameters optimization in shale gas wells.
Legal Insights on Energy Projects Management: Challenges of the Implementation of Liquidated Damages Provisions Under Engineering, Procurement, Construction and Commissioning Contracts
Authors: Elshazly Mostafa 
Published: November 2024

Abstract
Energy projects are frequently a subject of very detailed specifications and strict deadlines, poor performance or delays can throw the project and its schedules into disarray, inflate budgets, and strain relationships between the Contractor and the project company/owner. Poor performance and delayed performance of works related to the energy project often translates into increased costs due to overtime wages, penalties for missed deadlines, or additional expenses incurred by the project company/owner to rectify off-specs works and to expedite progress of the project. This may result in triggering the implementation of the liquidated damage provisions that are usually stated under the relevant signed EPCC contract/s to put the party who has not breached the EPCC contract into the position he would has been in if the contract had been properly performed. From practical standpoint, the implementation of liquidated damages provisions is a subject of argument and sometimes leads to potential dispute between the relevant parties in the concerned energy project due to lack of clear understanding of the mechanism, functions and the legal nature of these liquidated damage provisions. For instance, the parties of an EPCC contract may apply the liquidated damage clause as a penalty during the contract execution, while the intention at the earliest phases of the project during negotiating the terms and conditions of the contract was to insert the liquidated damage clause to set a pre-estimation for the losses/damages that is likely to be suffered by the affected party due to the breach of the counter party in the contract. Though, it is important to shed the light on the functions and the legal nature of liquidated damages provisions in energy contracts and to set a road map for the efficient use and enforcement thereof.
Successful Low Salinity Single-Well Pilot and SWCTT Operations in a High Temperature/High Salinity Carbonate Reservoir of the UAE. SWCTT Operations, Numerical Interpretation, and Integration with Well Logging
Authors: Balobaid L. , Berrahmoun H. , Tverinev A. , Shankar V. , Romero C. , Alhammadi M. , Masalmeh S. , Saxena P. , Huseby O. , Hartvig S. , Yvonnou P. , Pedersen R. , Garnier O. 
Published: November 2024

AbstractThis paper provides results and interpretation of an onshore Middle-East field first low salinity EOR pilot, carried out to verify the previous lab results of an extensive project to evaluate the EOR potential of low salinity water injection. It presents the design, execution and results of the extensive SWCTT project preparation of two Single Well Chemical Tracer Tests (SWCTT) and a detailed saturation logging campaign designed to evaluate the EOR potential of low salinity water injection.Following an extensive laboratory program of fluid-fluid tests and core flood experiments. Single Well Chemical Tracer Tests (SWCTT) were designed based on the results of this experimental program. The SWCTT pilot was accompanied by a detailed saturation logging campaign to evaluate changes in remaining oil saturations (ROS) in a fractured carbonate reservoir in south-east Abu Dhabi.The SWCTT pilot, together with PLT, noise-temperature logs and Pulsed Neutron Capture (PNC) logs provided insight into ROS distribution across the reservoir intervals.Contributions from the different reservoir intervals contacted by the tracer were included, aligned with log results, and uncertainties in ROS determination were calculated. This paper will focus on the specially designed multi-realization numerical simulations considered by field operator as the most robust method for pilot results.Detailed radial single-well models were built with fine geological layering, and partitioning and hydrolysis reactions were added to match historical tracer back-production profiles. From the history match of tracer profiles non-ideal flows were detected impacting the tracer's profile response and contribute to SWCTT uncertainties.The results confirm a positive low salinity EOR effect, matching the results from the laboratory experiments, with δROS above 4% and the EOR potential of low salinity water on this reservoir.This paper presents the field operator's first successful Low Salinity EOR pilot at HT/HS conditions. It highlights the ability of pilot result interpretation using multi-realization simulation models and demonstrates the importance of a thorough logging campaign to support and validate SWCTT modelling work.
How Drillpipe Deployed Well Integrity Measurements is Changing the Way We Log
Authors: Hawthorn A. , Steinsiek R. , Hered W. , Leslie Iain , Kamgang S. 
Published: November 2024

Abstract
The oil and gas industry is in a state of continually challenging the way to improve the efficiency and safety of well construction activities. An interesting path has been followed in the last 30 years in the development and use of logging while drilling tools. The measurement quality and reliability of these tools for open hole formation evaluation and geosteering has propelled an entire sequence of highly complex and highly deviated wells with enormous improvements in productivity from existing fields. You would be hard pressed to find any wells, particularly in the offshore domain, that do not utilize logging while drilling measurements that were once the province of wireline tools only. This development of technologies and tools has, as stated above, largely focused on open hole and while drilling applications only. The same cannot be said for cased hole evaluation tools in general, and for well integrity tools that measure the condition and properties of the casing and cement.
This paper will demonstrate the development of a new drillpipe conveyed tool that can both measure the casing condition and what is in the annular space behind the casing. We will show two examples that demonstrate the range of applications that the tools can be run in. The ability to run anytime drillpipe is deployed in the well therefore increases the amount of opportunity to get these critical measurements and also to be run in parallel with existing operations throughout the well construction period. As can be imagined this can lead to considerable efficiency gains as the logging does not require a dedicated run. The basic premise of the tool is that a drill collar is fitted with three circumferential pulse echo ultrasonic transducers. This allows for a full azimuthal image of the casing and annular space behind the casing if the tool is rotated, either from a downhole device such as a mud motor, or by surface rotation through the rig rotary table or top drive. The tool can be run in real-time and also in memory mode, in either case data is both processed downhole and the raw waveforms can be recovered from the tool when back on surface. Analysis of the acquired data allows for interpretation of internal caliper, the thickness of the casing, the location of casing collars and an evaluation of the material in the annular space behind the first casing string. The need to provide oriented images means the tool has magnetometers, accelerometers and a basic gyro measurement device that can be used for orientation of downhole devices such as whipstocks or oriented perforations.
Enhanced CO2 Capture from Flue Gas Using Monoethanolamine and Silica Nanoparticles
Authors: Boral Pranab , Borgohain Gogoi Subrata 
Published: November 2024

Abstract
Carbon neutrality is crucial in the fight against climate change, as it refers to a state in which CO2 emissions balance with measures of removal and offsetting, effectively meaning no net increase of CO2 in the atmosphere. This mandates that technologies for the capture of CO2 from flue gases a technology of the utmost importance in reducing greenhouse gas emissions from industrial sources. MEA is a very established solvent for CO2 capture, but it could be improved if nanoparticles are added to make the performance better. The primary objective of the study is to evaluate the CO2 absorption efficiency of MEA in combination with RH-derived silica nanoparticles and compare the absorption–desorption rates of the nanoparticle-enhanced MEA solution to that of pure MEA.
Adding RHSNp to the MEA solution greatly improved the CO2 capture efficiency and absorption rates. The experiment showed an 83.33% efficiency of CO2 capture using a 22 wt% MEA solution with 0.5 wt% silica nanoparticles (RHSNp), whereas 66.67% CO2 capture efficiency was observed without adding RHSNp. The rate of absorption of CO2 was calculated to be 4.5 litres per hour. During desorption, a CO2 stripping efficiency of up to 95% was realized. These results demonstrate improved solvent regeneration and CO2 capture with the nanoparticle-enhanced MEA solution.
This research work has demonstrated the potential of silica nanoparticles to enhance MEA performance for CO2 capture from flue gases. It is concluded that nanoparticle-enhanced MEA solution can be more effective and absorb at an increased rate compared to the usual MEA solution. These results suggest that this could be a promising approach to incorporate nanoparticles into amine-based solvents for process intensification in industrial CO2 capture, with benefits that are particularly prominent in scalability and application.
Analytical Approach to Predict Water Breakthrough Time Using Time-Lapse Pressure Transient Analysis: Application to Single Gas Well Reservoirs
Authors: Bhat S. , Choudhary A. , Kumar A. , Fife D. 
Published: November 2024

Abstract
Water breakthrough time (WBT) prediction is crucial for effective reservoir management with significant impact on field life and recovery. Time-Lapse Pressure Transient Analysis (PTA) can be used as one of the tools to predict WBT based on aquifer boundary movement over time. This paper aims to propose a simple yet effective approach for predicting WBT and cumulative gas production at WBT for gas reservoirs with single producer based on boundary movements observed in consecutive pressure build-ups (BUs).
BUs conducted over the span of three years were analyzed using appropriate analytical boundary models for each well. For consecutive BUs, upward shift in derivative during late time region indicated aquifer boundary movement towards the well. For each BU, equivalent radius corresponding to aquifer boundary was calculated based on PTA boundary distances. Correlation between equivalent radii and cumulative gas production was then established. WBT equivalent radius was calculated from the intersection of reservoir top and horizontal plane through the well bottom. Corresponding to WBT equivalent radius, cumulative gas production at WBT was found from the correlation. WBT can then be back calculated from cumulative gas based on gas production targets.
WBT was predicted for multiple wells for multi-reservoir gas field with single producers. Actual WBT closely matches with the predicted WBT validating the proposed methodology for future applications. This methodology provides vital inputs for optimizing production strategy and surveillance plan to extend the field life and improve recovery. This methodology is found particularly useful in dealing with the field with multiple reservoirs with single producer where managing life of each well is critical. Since this methodology is based on analytical approach, it does not account for reservoir heterogeneities, interference with other wells, coning, fingering etc. Regardless of the limitations, this method can effectively predict water-breakthrough time in single well reservoirs.
This novel water-breakthrough prediction method uses analytical model instead of numerical models proposed earlier. Hence, this approach requires limited inputs and simplified workflow. Considering reasonably accurate prediction of WBT, it can be used as primary input for optimizing production strategy. Further integration with the reservoir simulation model will be advantageous.
Emulsion System with Nanoparticles for Selective Control of Water Flows in Mature Sandstone Formations Offshore
Authors: Sergeev V. , Abe M. 
Published: November 2024

Abstract
This paper presents results of laboratory research conducted in the framework of a nano-emulsion technology piloting project for reduction of water production in mature sandstone oilfields offshore. Efforts of a technology developer, an oil and gas exploration and production (E&P) company and a petroleum research institute were put together to develop a fit-for-purpose piloting program. The offshore oilfields selected for the pilot are in the South of Vietnam. A laboratory part of program included list of experiments for testing physical and technological properties of the new product, a nano-emulsion called ESN which stands for Emulsion System with Nanoparticles. This new system is an inverse emulsion, whose nanoparticle augmented physical properties can be easily adapted for control of fluids flow in a wide range of reservoir conditions. A synergy from natural and artificial surfactants chemically intertwined with supercharged silicon dioxide nanoparticles brings to life a whole new scientific concept of the flow-control technologies for petroleum and geosystems industry. The ESN is an environmentally friendly technology used for advanced control of fluids flow subsurface. In this study, an application of ESN is aimed to selectively shut-off water zones within a profile of oil-gas well. The ESN consists of three liquid components: process or sea water, crude oil or diesel and nanoparticle-based surfactant. Implementation of the laboratory part of the piloting program resulted in a ready-for-pilot solution at reasonable cost and time. One of the main tasks of this research was to quantitatively demonstrate effectiveness of the unique features of ESN for selectively blocking water-bearing zones of sandstone reservoirs in Lower Miocene (2950 psi and 91°C) and Late Oligocene (3900 psi and 107°C) hydrocarbon formations. As a basic requirement from the E&P company, ESN had to be stable at said reservoir conditions and compatible with reservoir and process fluids. Besides that, the operator wanted to confirm that ESN is an easy-to-handle flow-control agent in the offshore environment, meaning that it can be prepared with ordinary equipment available at the vessel, all components must be liquids that can be easily mixed at ambient conditions, and properties of the ready-to-use composition do not change during operation. Thus, the laboratory program was executed in three successive stages: 1) ambient condition; 2) high pressure and temperature conditions; and 3) the reservoir conditions. As a result, a stable and reservoir-compatible ESN formulation that met all requirements set by the E&P company was quickly selected. In the series of core floods, it was confirmed that ESN selectively blocks predominantly water-saturated cores, while oil-saturated cores permeability drops slightly with clear tendency to full recovery under crude oil flow.
Diagnosing Well Integrity in Oilfield with Corrosive Aquifer with Pulse Electromagnetic and Chorus Acoustic Technologies
Authors: Evdokimov S. , Kadura M. , Ben Boudiaf M. , Sikander S. , Ezwai J. , Zitouni M. , Ezarrug N. , Abosart A. , Elyaseer M. , Hander M. 
Published: November 2024

Abstract
This paper discusses the approach of through-barrier diagnostics to direct Plug and Abandonment (PnA) and sidetracking operations in one of the fields in Libya. PnA before sidetracking is a critical procedure in the lifecycle of a well, involving the secure sealing of mother wellbore to prevent hydrocarbon leaks and ensure environmental and safety compliance. Proper PnA confirms the integrity of the new sidetrack wellbore.
The initial plan to revive the well involved abandoning the main borehole by isolating the perforated interval below and then drilling a sidetrack. Traditional evaluation methods revealed moderate corrosion in the 9 5/8″ production casing. To gain a comprehensive understanding of the well's condition, Pulse electromagnetic and Chorus acoustics technologies were employed, uncovering more extensive issues: approximately 200 feet of severe external metal loss in the 9 5/8″ casing and around 1200 feet in the 13 3/8″ casing, primarily due to a shallow aquifer and H2S / CO2 presence.
Understanding and mitigating the effects of corrosive aquifers are essential for maintaining the integrity, safety, and productivity of wells. Therefore, Pulse electromagnetic survey was performed on a nearby well to evaluate the impact of the aquifer. This assessment revealed similar metal loss in the external casing, attributed to the active aquifer. However, the extent of the metal loss was less severe due to the younger age of the well.
To address and manage these risks effectively, a time-lapse monitoring approach was proposed. This approach involves continuous or periodic monitoring over time to track the progression of corrosion and implement timely interventions. Such proactive measures are crucial for ensuring the long-term sustainability and operational efficiency of the wells, as well as for preventing potential environmental and safety hazards associated with corrosive aquifer interactions.