bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Robust New Method for Optimizing Intelligent Reservoir Production
Authors: Chen Cunliang , Han Xiaodong , Wu Qiongyuan , Chen Xiaoming , Liu Bin , Wang Zhiqiang , Sun Shibo 
Published: February 2024

Abstract
With the rapid development of big data and intelligent algorithms, intelligent oil reservoirs production has emerged. It brings new ways to generate profits for oil fields. The key of this technology is related to the rapid processing of oilfield data, which enables to obtain production decisions faster.
This article proposed a new method for intelligent production optimization of oil reservoirs based on big data. Firstly, according to the injection and production development data of the oilfield, a connection model between injection and production wells was established using the principle of material balance. This model not only helps to understand the corresponding relationship between injection and production data in the oilfield, but also enables to predict liquid production. Secondly, a new model was established through reservoir engineering methods which can predict the relationship between oil production and the injection multiples of pore volume, achieving the prediction of oil production in oil fields. Finally, in order to obtain the maximizing net present value, an optimization objective model was established successfully using intelligent algorithms. Compared with the numerical simulation method, this method saved a lot of times and costs.
This method has been using on various types of numerical simulation conceptual models, and the calculation results are perfect consistent with the model results, with an error of only 5%. However, compared to the numerical simulation, it not only saves time and costs, but also improves oil production efficiency.
This method was applied to a certain oilfield in Bohai and achieved excellent results. The results of research have strong promotion significance, which can be spread in more oil fields in Bohai.
Improving Drilling Safety and Efficiency with 100% Reservoir Exposure in a Challenging Low Resistivity Mature Reservoir Associated with Structural and Geological Uncertainties by Integrating Extra Deep Azimuthal Resistivity Technology in a Source-Less Solution - A Case Study From UAE Offshore
Authors: Wahbah Salima , Bellah Samir , Hattori Tadataka , Tsuda Ryuchi , Mumtaz Asim , Sanathoi Potshangbam , Hameed Mahmoud , Rawy Mohammed 
Published: February 2024

Abstract
Improvement in drilling efficiency and maximum reservoir exposure are two key considerations in determining the success of a well. Detailed planning covering these aspects is critical, especially when the reservoir is associated with a complex geological setting. In this case study, oil producers in a complex low resistivity environment associated with high heterogeneity, karstification, caves, collapsed holes, fractured and faulting as common geological features were drilled on the flank of a mature field. Drilling challenges would be profound if the well bore passed through the sub-seismic karst features and the overlaying shale formation. Drilling into such features risk drilling complications that could potentially result in unwanted sidetracks and/or reduce reservoir exposure. The main challenge was to maximize reservoir exposure in the target interval, characterized by thin pay thickness, while maintaining a safety buffer of 15 to 20 ft between the overlying shale and the well trajectory. Maintaining a standoff from an uncertain oil-water contact (OWC) was also critical due to prolonged production in the field.
Historically, a combination of a high-resolution resistivity-imaging service with nuclear magnetic resonance technologies was utilized for drilling the lateral sections in this area, primarily for fluid typing, permeability, porosity distribution, and detailed geological evaluation. However, this solution was insufficient for proactive geosteering to place the wellbore optimally in the reservoir and map the sub-seismic structural changes and the uncertain OWC. To overcome these challenges, Extra Deep Azimuthal Resistivity (EDAR), along with reservoir navigation services was integrated into the existing solution after completing feasibility studies based on the offset data.
The feasibility study demonstrated that EDAR could map the structural and fluid changes from the wellbore satisfying drilling and well placement requirements.
EDAR inversion mapped the structural changes on top of the reservoir, reducing the geological uncertainty related to sub-seismic faults, karsts, and the OWC.
This enabled informed geosteering decisions to achieve 100% reservoir exposure in the optimum target zone and helped to maintain a smooth well profile facilitating a trouble-free completion operation. Placing the well in the best porous zone of the reservoir resulted in a 28% increase in ROP. The completion design was optimized based on fluid distribution analysis and structural information from EDAR inversion. The acquired data improved the knowledge of the geological setting of this area.
Experiment and FEM Modelling of Stress Shadow Effect in Multi-Stage Hydraulic Fracturing to Optimize the Stimulation
Authors: Li Zheng , Wang Jingyi , Gates Ian , Chen Tiange , Zheng Zigang , Lyu Wenfeng , Gao Jian , Yu Hongwei 
Published: February 2024

Abstract
The stress shadow effect is well observed in the field operations of multi-stage hydraulic fracturing and it can greatly influence the fracturing effect. In the research documented here, lab experiments were made with the artificial gelatin blocks to visually examine the stress shadow effect during multi-stage hydraulic fracturing process. A related finite element modelling was conducted to understand the changes of the stress distribution after a first-stage hydraulic fracture evolved. The results of the visual fracturing experiments and finite element modelling (FEM) were consistent, which illustrated that a later-stage hydraulic fracture that follows an previous-stage hydraulic fracture may have its orientation and fracturing pressure altered from that of the previous one due to the altered stress distribution in the formation nearby. The experiment observations clearly showed the process of a first-stage hydraulic fracture generated obliquely at the very beginning due to near-wellbore effect and then turned to extend more and more perpendicularly to the direction of the minimum principal stress. After this first-stage fracturing done, a second-stage fracturing started but the fracture evolved towards a different direction that is nearly orthogonal to the first-stage fracture. According to the related FEM modelling, the main stress shadow affected region was within a range that depends on the injection pressure and the principal stresses difference in the formation nearby. If the later-stage hydraulic fracturing is done beyond this range, the fracture will have a similar orientation and fracturing pressure to the previous one. A suitable spacing between each stage as well as the injection pressure should be well designed to optimize the stimulation.
Carbon Life Cycle Assessment of Non-Metallic Downhole Tubulars
Authors: Sarmah P. , AlAdawy A. , Powell T. 
Published: February 2024

Abstract
Non-metallic oil and gas pipes are replacing their metal alternatives due to their various advantages such as mitigating corrosion issues, lowering total cost of ownership and reducing carbon footprint. Reduction of carbon footprint is an important aspect to consider due to environmental concerns and global initiatives while developing new products. As an effort to assess the impact of utilizing non-metallic tubulars in a downhole environment, this paper explores the carbon life cycle and footprint of metal and non-metallic tubulars.
This paper presents a step-by-step process of the carbon life cycle assessment (LCA) which includes the fabrication of the selected base materials, the loadings, environment conditions, manufacturing techniques used for non-metallic pipe development, logistics and transportation from the manufacturing facility to the destination, deployment and completion in field, as well as end of product life accounting for product disposal and/or recycling. The methodology of evaluating the carbon footprint at each stage is described throughout the composite tubular life cycle. A comparison with metal tubular carbon life cycle is also performed.
An assessment is conducted on the carbon life cycle of non-metallic tubulars starting from base material fabrication, end product development and manufacturing, transportation and logistics, final implementation of the product in the well to the end of lifespan. The study shows a comparison between metal and non-metallic pipes from a carbon life cycle perspective. Various inputs to the methodology (e.g., types of base materials, transportation distance, manufacturing energy input and percentage of recyclable material) are considered, including their impacts on the carbon footprint outcomes.
In this publication, an effort is made to explore the carbon life cycle and footprint of non-metallic pipes focusing on downhole applications. The study shows that non-metallic pipes may provide the potential to reduce carbon emissions with respect to their metal alternatives.
Deep-Learning Based LSTM for Production Data Analysis of Hydraulically Fractured Wells
Authors: Zhang Fengyuan , Xu Minghao , Deng Chao , Zhang Wei , Liu Chuncheng , Rui Zhenhua , Emami-Meybodi Hamid 
Published: February 2024

Abstract
During the production and operations of hydraulically fractured wells, large amounts of data are collected through numerous sensors or flowmeters, which can provide valuable understanding on the formation and hydraulic fractures. Although much studies try to use physical-justification based approaches to analyze these well history data, the analysis accuracy is significantly limited due to many assumptions made in physical models. This paper developed a deep-learning based Long Short-term Memory (LSTM) approach for production data analysis in shale reservoir and proposed a workflow to quantitatively evaluate fracture parameters. The proxy model is based on deep-learning algorithm of LSTM and is combined with a semi-analytical (base) model for multiphase water and hydrocarbon (oil or gas) flow in the hydraulically fractured reservoirs. To rigorously consider the multiphase flow mechanism in the semi-analytical model, LSTM and attention mechanism are introduced to forecast the key relationship of average saturation and pressure for semi-analytical model by training and predicting the time-dependent pressure and saturation series. We generated thousands of numerical simulation cases of wells in hydraulically fractured rservoirs, which provide production data and static reservoir data to train the deep-learning based proxy model. Model verification and comparison show that the proxy model can effectively predict pressure-dependent average saturation relationship with high accuracy. The numerical validation confirms the superiority of the proposed deep-learning based model than the semi-analytical model in accuracy with the error of estimated reservoir and fracture parameters less than 10% and in calculation efficiency with the speed two orders of magnitude faster.
Legacy Wells Screening Method for Potential CO2 Storage Sites
Authors: Enriquez H. Costeno , Dick H. , Holloway C. , Salter R. 
Published: February 2024

Abstract
The authors developed a legacy-wells screening method for potential CO2 storage sites. The screening method enables project teams to evaluate qualitatively, in a consistent manner, the legacy wells risks at potential Carbon Capture and Sequestration (CCS) candidate sites. It does so by identifying the legacy wells current status, preliminary corrective action requirements and associated risks based on a specific data set that can be extracted from public well records.
For CO2 storage sites, legacy wells are existing wells that are located within the predicted CO2 plume and/or pressure front area. When assessing the feasibility of potential storage site candidates, legacy wells risk is an important variable for ranking the feasibility of potential locations against each other. Legacy wells risk is a result of not only the number of wells but also their leakage potential and the complexity of the corrective actions required. Often, only legacy well density (number of wells per squared kilometer) is evaluated, disregarding elements of risk such as well status, well age, well architecture, well mechanical status, etc.; if or when a risk level is assigned to the wells, it is done so in a subjective manner. A systematic method will be illustrated in this paper that evaluates existing well conditions and intervention requirements to evaluate legacy wells risk for potential storage sites.
To evaluate the legacy wells risk beyond only well density and to eliminate the subjectivity of screening, the authors used a method based on a ranking system that considers a few, critical, well characteristics to assign a risk score that can then be compared equally between potential locations. The ranking system assigns risk scores to legacy wells based on the availability and quality of well data, and in parallel the complexity and risks of each potential remediation or corrective action.
The paper will present a case study of a CCS site feasibility study where the workflow was applied to provide a consistent approach to legacy well assessment and qualitative risk evaluation for potential storage sites. Future CCS operators will benefit from this approach to improve decision making before selecting and moving forward with a storage site.
Sustainable Drilling Fluid Design; Utilizing Waste Biomass as Drilling Fluid Additive
Authors: Khan Azam , Shahid Arshad Shehzad Ahmad , Zahoor Muhammad Khurram 
Published: February 2024

Abstract
The use of drilling mud is an essential part of the drilling process in the petroleum sector. It is responsible for managing formation pore pressure as well as cleaning boreholes, among other responsibilities. The necessary qualities can be obtained from the components that are contained in drilling mud. These features can be obtained using specific chemical additions in drilling fluids; however, these compounds can be harmful to the environment and make storage and disposal more difficult. These problems can be alleviated to some extent by using sustainable alternatives to traditional materials. In this study, various solid waste materials were evaluated for their potential use as alternative drilling fluid additives. These materials were assessed for their densities, plastic viscosities, yield points, and gel strengths. There was the possibility of using sustainable additions such as banana peel powder, eggshell powder, date seed powder, and aloe vera gel. The findings demonstrated encouraging outcomes, with noticeable enhancements in comparison to the traditional approaches. Natural solid waste products provide an incremental improvement to already existing drilling muds and have the potential to promote environmental sustainability. By employing waste biomass, our approach improved the quality of drilling fluids while also making them more environmentally friendly. In general, it had a considerable effect in reducing the impact on the environment while maintaining performance.
Automated Workflow to Couple Hydraulic Fracture Modeling Results into Dynamic Simulation Process for Unconventional Reservoir
Authors: Belaifa Elhadi , Abdelrahman Moemen A , Almubarak Abdullah A , Adebamiro Adedayo D 
Published: February 2024

Abstract
The objective of this study is to integrate two main workflows seamlessly; i.e. hydraulic fracture modeling and dynamic reservoir simulation process. A smooth coupling is developed and implemented for unconventional reservoir.
The work is designed as an automated multidisciplinary and integrated workflow consisting of hydraulic fracturing, geologic, and reservoir modeling. The hydraulic fracturing configuration was built at a detailed resolution using a commercial software, which is used to calibrate a 3D subsurface refined geological model using Local Grid Refinement (LGR), and it honors long-term flowback history of unconventional well Pad.
The study was conducted in four main phases Phase-1 is to execute hydraulic fracture modeling where Hydraulic Fracture (HF) job data was analyzed and matched using 3D Mechanical Earth Model (MEM) to predict the HF propagation possible scenarios.
Phase-2 is to transform frac geometry into the dynamic model using LGR methodology. For this phase, it includes a comprehensive software development to automate this transformation process between two different applications. Phase-3 is designed to match the long-term flowback data, where the fracture geometry, such as fracture height, fracture half-length and fracture conductivity used as main history matching parameters.
Finally, for Phase-4, the calibrated model is used to predict the well EUR perform sensitivity analysis.
The implemented integrated workflow helps in optimizing key field development plan parameters, including well spacing, cluster spacing, well stacking, lateral length optimization, testing well interference and its impact on wells’ EUR.
Prospective Saline Aquifer CO2 Storage Resource Estimates in Data Lean Regions
Authors: Gravestock Christopher , Jennings Joseph , Simmons Mike 
Published: February 2024

CO2 storage in geological formations is widely agreed to be a key carbon abatement technology. Whilst CO2 can be stored in depleted fields for which there will be abundant subsurface data to calculate storage resource, these calculations will be more difficult for saline aquifers which will often lack data since they may lie outside traditional petroleum systems considerations. Therefore, there is a two-fold challenge: Firstly, to screen for potential saline aquifer storage units rapidly and cost-effectively in any given basin close to point sources of CO2 production.Secondly, for those rock units so identified, to calculate the potential prospective storage resource (PSR) estimate (Mt CO2/km2), both at the gross fairway level and to high-grade areas within the fairway where storage resource is likely to be greatest, or where it meets given thresholds. Such calculations allow potential saline aquifers to be ranked within a region/basin, providing a focus for further data gathering and study.
We have approached this problem by developing workflows for spatial screening that use simple regional geological parameters to identify suitable rock units, and then maximize limited subsurface data to provide an estimate of storage resource. To illustrate this approach, we have used the Cretaceous Shuaiba Formation of the Middle East as an example. The Shuaiba Formation is an established carbonate reservoir in super-giant fields such as Bu Hasa, Shaybah, and Safah (van Buchem et al., 2010; Droste, 2010). It includes bioherm, lagoonal, and more distal facies. Whilst within the industry there is abundant data concerning the Shuaiba Formation, we have limited ourselves to only the data available in the public domain – thus providing a proxy for genuinely data lean rock units. Furthermore, the results, whilst data limited, provide insight into the storage potential of the Shuaiba Formation which is likely to form a key CO2 storage unit in the Middle East.
Addressing Reservoir Management, Operational Challenges and Strategic Planning Utilizing the Dynamic Model of the Worlds’ Largest Clastic Reservoir - The Wara-Burgan
Authors: Al-Samhan Amina , Al-Shamali Adnan , Al-Nemran Shahad , Al-Fadhli Wuroud , Yaser Muhammad , Jilani Syed Zeeshan , Maldonado Jorge E , Yunusov Manuchehr , Ibrahim Muhammad 
Published: February 2024

Abstract
To sustain oil production, the Wara-Burgan reservoirs have undergone massive drilling and water-injection over the past decade, leading to 1000s of new wells. These introduced several reservoir management and operational challenges, including localized pressure depletion, formation of secondary gas-cap, non-uniform water encroachment, by-passed oil formation, and fluid property changes. This paper focuses on identifying, analyzing, and evaluating the impact of these factors on reservoir management decisions using calibrated dynamic model across the Greater Burgan field.
To analyze and assess the reservoir management challenges with eight stacked reservoirs having 2400+ wells coupled under 14 gathering-centers, an integrated and up-to-date dynamic model was deemed indispensable, to provide a holistic picture of the reservoir performance. The dynamic model history matching was performed successfully by including all the available drilling, workover, production, injection, pressure, and surveillance data for newly drilled and existing wells. The update of history match exercise was conducted on the existing dynamic model for Wara and Burgan reservoirs to achieve field, gathering center and reservoir level matches.
The history matched dynamic model was subsequently used in simulating field development strategies, asset-action plans, and conducting high-resolution sector modeling of the Greater Burgan reservoirs. A comprehensive list of multiple forecasting and development options was mutually agreed with the Kuwait Oil Company (KOC) asset team. These were simulated whilst honoring all available data and information pertaining to wells and facilities, including their respective constraints.
Further variations to the simulation cases, including focused work on the Ahmadi ridge and Northern Burgan area were all simultaneously performed. Simulation cases related to testing the system capacity limit for the entire field as well as implementation of horizontal wells to target the sweet spots in the Middle and Lower sands were completed in addition.
This work was in part, used for proof-of-concept modelling pertaining to simultaneous injection and production, within the Wara-Burgan reservoir. This invariably led to a decision for facility re-assignment with respect to availing injection slots, for utilization in the field for water injection.
This work further formulates the asset strategy to develop all operational reservoirs of the Greater Burgan field with given and foreseeable constraints in view of the strategic objectives of KOC.
Optimized PDC Point-Loading Cutter Placement Drives Higher Performance in Anhydrite
Authors: Alsaif H. F. , Almarhoon Q. , Alraheb M. 
Published: February 2024

Abstract
Shaped cutters have been popular in the PDC cutter development realm. However, the optimum placement of those shaped cutters in a drill bit remains wide field to be explored. This paper illustrates how placement of the point-loading cutters drove higher performance in Anhydrites minimizing the need for multiple bits to complete the 8.5" section in the Unconventional Gas unit in The Middle East.
Formations rich in anhydrites and carbonates present a challenge to successfully drill given the hardness of the anhydrite and interbedding with carbonates. To assure consistent success with this application, a detailed application study was carried out to determine cutter failure modes. After that, multiple bit designs have been evaluated using Tetrahedron, a drilling simulator software, having variable position of the shaped cutter. Once the shaped cutter position has been optimized, the bit was tested in a lab environment. It was then deployed in the field after successful lab results.
Lab testing showed promising results for field deployment. Once the bit is run in the field, ROP improvement of 33% was achieved. Then, more field deployment followed with higher performance compared to other PDC bits. This bit consistently drills the entire section in one run replacing 2 bits. The field deployments resulted in significant cost savings for the operator as well as reductions in well delivery time. This repeatable performance proved that optimizing the position of point-loading shaped cutters leads to a higher performance drilling anhydrite. This higher performance results in enormous savings to the operator in terms of time and economics.