bluuebunny/crossref_metadata_2025_split huggingface dataset:
Automating Reservoir Pressure Measurement Insights from Deep Water Carbonate Formations in Brazil
Authors: Bertolini A. , Dantas M. , Haik E. 
Published: October 2024

Abstract
The primary objective is to achieve consistent pressure measurement acquisition while optimizing the time required for high-quality data collection. Specifically, for carbonate formations in deep water Brazil, where reservoir intervals often exceed 200 meters, the aim is to streamline wireline formation tester programs, which can typically take less than a day up to a few days depending on formation thickness and type.
To achieve desired efficiency in pretesting acquisition, we implemented an automated workflow and AI classification of pretests. Automation reduces human intervention in tasks at the pretest station. The AI, a supervised algorithm trained on a generalist dataset of pressure build-ups, predicts valid or invalid pretests within the first 60 seconds. This enables rapid decision-making to either wait for pressure stabilization or abort and retry with different parameters. We measure total station time and time between events/pretests, comparing these metrics with other wells in the same reservoir to evaluate efficiency.
The proposed solution was successfully implemented in three carbonate formation fields in Brazil. The results, compared with previous manual pressure measurement sequences, demonstrated significant improvements. The total time required to complete the pressure campaigns was reduced, and the measurement sequence was optimized at all stations. A standardized protocol for pressure measurement was established, with consistent pressure stabilization criteria applied across the entire reservoir intervals.
Automation in WFT pressure measurements yielded positive outcomes. The WFT probe set and retract times were optimized at all pressure stations, and the build-up pressure behavior was evaluated within a 60-second window, enabling quick decision-making within minutes. These advancements highlight the efficiency and effectiveness of automated pressure measurement in deep water carbonate formations.
For over 50 years, WFT pressure measurements have been integral to formation evaluation programs, typically relying on experienced professionals for high-quality data acquisition. This paper introduces a novel automated solution that complements traditional methods, enhancing data quality and significantly reducing rig time, thereby advancing the current state of knowledge in the petroleum industry.
Technical Competence Management - ELNG TCM Program
Authors: Qabel A. 
Published: October 2024

Abstract

Objectives/Scope
In the context of building organizational capability, Technical Competence Management is an essential role in the dimension of "People" and an effective method to achieve operational excellence guaranteeing the achievement of company strategic and business objectives. Egyptian LNG adopted Technical Competency Management (TCM) framework for guaranteeing world class competency management system supporting in producing LNG safely, reliably, and efficiently and creating competency-based organization.

Methods, Procedures, Process
TCM framework was established to manage entire technical competences of technical workforce through:

Results, Observations, Conclusions
TCM swapped from ordinary talent development approach into management approach that focuses dynamically as a companywide upskilling program for serving company strategic and business objectives through:
TCM diverges between employees’ safety critical competence to be assured for the purpose of preventing major hazard accidents, and other required technical competences for performing positions functions. These aids company to declare feasibilities and define priorities of future talent development schemes.
TCM maintain all competence candidates’ records aligned with their positions’ Competence Profiles. This serves company to identify talented people for future succession/promotion plans, and to define properly the individual development of Not-Yet-competent people to rectify pre-identified technical gaps.
Geothermal Energy to Reduce CO2 Emissions from Oil and Gas Fields
Authors: Ahmed A. A. , Assadi M. , Batee M. 
Published: October 2024

Abstract
The need to make oil and gas extraction cleaner and greener is more important than ever. The industry is facing a big challenge: how to cut down on its carbon emissions. In places like the North Sea, where oil and gas are taken from under the sea, machines powered by gas are a big source of pollution, causing about three-quarters of the emissions. This paper explores the potential of using heat from the Earth (geothermal energy) from old, unused wells to make oil and gas extraction less harmful to the environment. This study also investigates a special way to use carbon dioxide (CO2) in its supercritical form – a state where it acts like both a liquid and a gas – to help with this process. The work is divided into two main parts. First, we use computer models to simulate how well we can get heat from these old wells and convert the thermal energy to electric power. Second, integration between geothermal and other heat sources to maximize the energy output. Results reveal that the achieved outlet temperature at surface from a closed-loop borehole heat exchanger (CBHE) is found to be 90°C to 130°C to when circulating scCO2 at flow rates between 1.25 kg/s to 5 kg/s, resulting in electric power of 105.7 kW from one well. However, integration of the CBHE with other heat sources (i.e. waste heat) would result in increased power output e.g. 323 kW when circulating 10 kg/s of scCO2 due to increased turbine inlet temperature to 200°C. But circulating scCO2 at high flow rate reduces thermosiphon effect and increases friction losses through CBHE, which requires significant pumping energy. Pumping power increases up to 70% of the produced energy in the case with 10 kg/s of scCO2. The optimum scCO2 flow rate through the CBHE was shown to be 7.5 kg/s. In simple terms, our study shows how tapping into Earth's natural heat can make oil and gas extraction more environmentally friendly. This research is a step towards cleaner energy practices and shows that even traditional industries like oil and gas can find new, greener ways to operate.
New Insights in Bapetco New Wells Delivery Process
Authors: El-Bagoury Mohamed 
Published: October 2024

Abstract
Badr El-Din Petroleum Company (Bapetco) is one of the major operators in Egypt. Bapetco is one of the pioneer companies to apply the well delivery process. We have had a lot of advances to the well delivery process from best practices and the culture of process management in the last 40 years.
The well delivery process (WDP) was deployed in Bapetco to improve integration and communication between the different disciplines and to keep an effective time frame for new wells and subsurface projects. This process is compatible with the high-level business guidelines (assess, select, define, execute, and operate). These five elements facilitate the new wells workstream. Since 2015 a lot of revisions and continuous improvements have taken place to modernize the well-delivery workstream and replace the existing practice with agile reforms.
Installing the new wells process mainly depends on six factors; wells-to-facility integration, digital control and transformation, dual leading responsibility, document standardization, proactive tracking, and management of change (MoC). These tools and techniques were adjusted to accommodate the requirements of the national operating environment in a fit-for-purpose style. The deployed process describes the best practices in timely managed well proposals to ensure full alignment between internal and external stockholders and provide the required support to wells planning in creating robust execution plans.
This paper will demonstrate a description of the new wells delivery workstream and its key pillars in addition to the applied improvements that led to effective lean management, enhanced quality of work deliverables, and minimized time to first production including lessons learned during the pandemic COVID-19 world crisis.
Analysis and Modeling of an Extensive Data Material for the Compositional Variation with Depth in a North Sea Reservoir
Authors: Pedersen K. S. , Hjermstad H. P. 
Published: October 2024

Abstract
Detailed compositional data is presented for 43 fluid samples taken at different depths in a 359 m North Sea reservoir fluid column with a gas cap on top and an underlying oil zone. The data enables the depth of the gas-oil contact to be determined quite accurately. A common equation of state model has been developed for the fluids and depth gradient simulations carried out. In the gas zone, gravitational forces can explain most of the observed compositional variation. In the oil zone, the compositional variation is larger than can be explained by the gravitational effect. There is a need to also account for the heavy hydrocarbons orienting themselves towards the warmer bottom zone and lighter hydrocarbons towards the colder top zone. The Haase model, which is based on the theory of irreversible thermodynamics, is used to describe how the vertical temperature gradient affects the compositional gradient. It requires knowledge of the absolute partial molar enthalpies of the individual components, of which it thanks to the extensive data material has been possible to give a good estimate. With the presented model concept, it is possible to represent the compositional gradient over the entire fluid column including the depth of the gas-oil-contact and the variations in gas/oil ratio and saturation point with depth. The determined model parameters are also expected to be applicable to other petroleum reservoirs.
The Strength of Surface Seismic Attributes as a Quick Tool for the Dolomitization Detection in Alamein Carbonate Reservoir, Khepri Field, Shushan Basin, North Western Desert, Egypt
Authors: Raslan Y. , Deghaidy N. , Abdo K. , Morsi M. , Metwally R. 
Published: October 2024

Abstract
Khepri deep Field was discovered in 2020 by drilling the exploratory well KPR-D-1 which encountered 59 feet net pay in the Alamein dolomite reservoir and tested 4000 BOPD. The Alamein formation is recognized as a very good carbonate reservoir in this field with up to 4 million barrels of oil were produced there. Core analyses revealed that the reservoir attains up 15% vuggy porosity with about 20% residual oil saturation. Initial volumetric calculations were 7 MMSTB of original oil in place that increased to 10 MMSTB, where the Alamein structure elevated by about 50 feet. In order to understand any lateral changes related to subsurface geology, surface attributes have numerous applications in both structural and stratigraphic aspects. These applications depend on the extraction of data or information regarding amplitude, frequency, and phase from seismic data across a selected surface that represented the reservoir or between two surfaces. The main risk in this case is the dolomitization process; when dolomite is found in our wells at an appropriate structural level, oil is found as well. The density of limestone is higher than that of dolomite. Due to the fact that the secondary porosity produced by the dolomitization process lowers density, which in turn lowers seismic wave velocity. The important thing to remember is that dolomite, unlike limestone, is supposed to have a lower amplitude value and acoustic impedance. Our reservoir's seismic interpretation has been completed, and additional top and base surfaces have been made so that it can apply a variety of seismic properties through this zone in order to capture any events. Anomalies can be seen in some places and surrounding the main fault according to the minimum amplitude, average strength, sweetness, and RMS qualities. Thankfully, our data for lithological interpretation of dolomite from wells matches these abnormalities.
Simulating Lost Circulation in a Primary Cement Job Design
Authors: Bogaerts M. , Flamant N. , Abdulaal A. , Zalata R. 
Published: October 2024

Abstract
Losses can occur during many stages of well construction and with various severities, ranging from seepage losses to total losses. In an ideal situation, losses should be addressed and cured prior to the primary cementing operations, as losses can affect the cement job results in various ways. Losses during cement placement will affect top of cement (TOC), downhole equivalent circulating densities (ECDs) and potentially well control, circulating temperature, annular velocity, and mud removal.
In the Middle East, losses are common during drilling operations and often are present at the start of the cementing operations. If it is expected that a primary cement job will be executed with losses, it brings benefits to be able to simulate the results. This enables us to set realistic expectations toward the outcome of the cement job and enables educated decision making.
However, there are also cement jobs where losses are not expected but occur during the actual cement job. Having the ability to run simulations using actual execution data will enable the drilling team to make more educated decisions on the next steps of operations.
A proprietary cement job simulation software has been upgraded with a losses model. Using the losses model will enable the design engineer to define one or multiple loss zones in the wellbore. For each identified loss zone, a percentage of losses can be provided. The simulator uses the losses input data and other well and fluid data for a detailed dynamic simulation. The simulator will provide output for temperature, u-tubing, ECD, and expected TOC. Sensitivity simulations can be run toward the selected loss zone intervals and expected losses.
In case losses occurred when not expected or were more significant than anticipated, simulations can be run post-execution to visualize the outcome of the cement job. Using actual execution data and loss rate, the simulation results can be used to make a decision on the next operations. It will provide an additional input to decide to continue operations or if wireline evaluation logs need to be run ahead of possible remedial cementing operations.
In this manuscript, case studies will be provided where the loss circulation model was used during the design phase as well as during the job evaluation phase. The case studies will show how the model can accurately provide TOC and ECDs.
Using the novel loss zone simulations during cement job simulations enable the design team to discuss the potential outcomes of the cementing operations while experiencing losses. It will enable the team to prepare proper mitigation plans ahead of the cement job or to facilitate quick post-cementing decisions for upcoming operations.
Challenging Plug & Abandon Cementing Operation under Influx and Losses Scenario
Authors: Mesaud R. , Shafqat A. , Al-Jadhar A. , Kharchi S. , Bermudez F. , Pohl J. 
Published: October 2024

Abstract
The cement plugs are usually required when the well requires a sidetrack due to various circumstances such as a change in its trajectory, abandonment, or to cure loss circulation. These can occur in the initial drilling phase, just after drilling, or during the production phase. Requirements to perform these operations vary and may include different scenarios such as an increase of contact area with producing formation, producing formation depletion, production of unwanted fluids, non-economical hydrocarbons production, temporary isolation, regulatory, or operational issues including fish in the hole, casing repairs, formation squeeze, or to cure loss circulation.
Cementing plug operations are one of the most critical operations to be designed and executed, due to the required slurry and set cement properties, a relatively small volume of cement slurry that can be subject to contamination, critical design considerations, and meticulously required field execution. This manuscript presents the challenges and the engineered solution while designing, executing, and evaluating the success of a critical plug and abandon (P&A) cementing operation under an influx and losses scenario. This study will cover a challenging well that was not possible to be hydrostatic balanced without inducing fluid losses to the formation and the decision that was made to plug and abandon the well by pumping cement plugs.
Reconstructing Missing and Non-Recorded Well Log Data Using Machine Learning Techniques.
Authors: Amadi K. W. , Elgaddafi R. M , AlAli M. A , Dashti A. M 
Published: October 2024

Abstract
Petrophysical estimation of rocks are carried out for lithologic characterization and to quantify the reservoir hydrocarbon prospects. During drilling operation, the continuous recording of well log data is performed using Logging Whilst Drilling (LWD) tools and sometimes the LWD tool failure results in loss of data especially when decision was made to drill ahead due to project economics resulting in gaps or unrecorded data. This study is aimed at using Machine Learning (ML) techniques in predicting missing and unrecorded data using offsets well data. During the study detailed literature review addressing current industry trends in the handling gaps in petrophysical log were reviewed, then four ML models were trained and used in predicting lost data entries using offsets well log data. The models utilized comprised CatBoost (CB), Gradient boost (GB), Random Forest (RF) and Support Vector Machine (SVR). The ML algorithms were first trained with 21595 data points using a 70:30 percentage ratio for training and testing respectively. After that, 8650 data points from a different well were used to validate the developed model. The real-time drilling parameters required as input data includes Gamma ray(GR), neutron (NPHI), bulk density (RHOB), photoelectric absorption factor (PEF), the borehole diameter, (CALI). The modeling result showed a good match between the actual and predicted (logs) with coefficients of determination for training and testing dataset of 0.99 and 0.97 for CatBoost and RF respectively which are the two best predictors. The main added value of this approach is that the input drilling parameters are readily available in real-time and can timely aid in well placement decisions which improves the productivity of the well.
Developing of Lower Cretaceous Clastic Reservior for Menes-Nu Fields as Stratigraphic Play Using Integration of Multiple Data, North Western Desert, Egypt
Authors: Adly O. , Tarasov S. , Hassan M. , Sharaawy H. 
Published: October 2024

Abstract
Menes and Nu fields are discovered by Khalda petroleum company in 2016, the two fields located North west from Shushan basin. They are on a ridge high west from Umbarka field and North from fault bonding Shushan basin, also North from Barakat deep field, Distance between Menes -1x and UMB-1X almost 15 km to east, Nu are up dip from Menes and west from Menes closure.
The phanerozoic history of the Western Desert was shaped by opening of first Paleotethys and then Neotethys which morphed into the modern Mediterranean Sea when the seaway between Arabia and Eurasia closed about 15 Ma. Extensional structures related to Paleotethys are present in the subsurface of the Western Desert but are presently not well known. Neotethyan rifting, however, left a complex legacy of multi- phase basins along the northern margin of Gondwana (Bosworth and Tari, 2021).
Shushan basin lies to the south of Matrouh basin and shows the effect of ENE-WSW and WNW-ESE oriented faults on the basin architecture. Shushan basin witnessed Jurassic and early Cretaceous extension followed by late Cretaceous - Early Tertiary inversion (El Awdan et al., 2002). NE-SW and NNE-SSW oriented inversion anticlines as well as tilted fault blocks bounded WNW-ESE and NW-SE oriented normal faults from the main structural traps in the basins (Mostafta, 2008)
Menes and Nu are Cretaceous play where are the main reservoirs mainly in AEB and Alamein with rare pay calculated in Baharyia
The tectonic effect the area of deposition though to be there are uplift for the Paleozoic and Jurassic section before Cretaceous age where there are no Jurassic deposited and Paleozoic or eroded represented by Shia formation deposited directly on basement, unconformity represent the non-deposition age from Paleozoic to early Cretaceous
Advancing Rotating Machinery Condition Monitoring: Wireless Vibration Sensors in ADNOC's AIP5 Autonomous Operation Plan
Authors: Youssef K. , Alkaabi A. 
Published: October 2024

Abstract
Condition monitoring of rotating machinery is a critical aspect of maintaining operational efficiency, reliability, and sustainability in industrial sectors, particularly within the oil and gas industry. In an era where digital transformation is reshaping industries, ADNOC has embarked on a strategic initiative under its AIP5 autonomous operation plan to leverage advanced technologies such as wireless vibration sensors. This initiative aims to integrate cutting-edge wireless vibration sensors to enhance machinery monitoring processes, especially in remote and offshore environments.
The use of wireless vibration sensors in ADNOC's operations represents a significant step forward in digital transformation, aligning with the company's broader goals of innovation, sustainability, and operational excellence. This manuscript discusses a pilot project conducted within ADNOC Offshore to evaluate various sensor manufacturers, highlighting the benefits of wireless vibration sensors in reducing dependency on contractor mobilization, predicting machinery failures early, and improving overall operational efficiency.
In addition, this study details a workshop arranged with multiple Original Equipment Manufacturers (OEMs) to explore available products before initiating a pilot installation at one of ADNOC's offshore fields. A thorough comparison of seven OEM products was conducted based on their technical specifications, hazardous area classification, and customer references. This paper also examines the challenges faced during the COVID-19 pandemic, which underscored the necessity for wireless solutions to ensure continuous data acquisition and analysis without on-site mobilization.
Development and Optimization of Epoxy-Resin Based Cement Reinforced with Low-Cost Fly Ash for High Durability Environmentally Friendly Cement
Authors: Salib Ann Maria , Fakher Sherif 
Published: October 2024

Abstract
This research investigates the development of a novel, high-performance cement composite to address the limitations of traditional cement, including its environmental impact and durability issues. The study focuses on the incorporation of epoxy resin and fly ash to enhance the mechanical properties, durability, and sustainability of cement-based materials. A comprehensive experimental program was conducted to evaluate the effects of varying epoxy resin and fly ash dosages on the composite's properties. Results indicate that the incorporation of epoxy resin and fly ash significantly improves the composite's performance, including enhanced mechanical strength, increased resistance to acid and alkaline environments, and improved durability. The findings demonstrate the potential of this novel cement composite to offer a sustainable and high-performance alternative to traditional cement for construction applications