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GEOPHYSICAL CHARACTERIZATION OF THE UPEMBA GRABEN: SEDIMENTARY THICKNESS ESTIMATION VIA SOURCE PARAMETER IMAGING (SPI) OF REPROCESSED MAGNETIC DATA
Kenny Lose Manzembele; Bavon Diemu Tshiband; Dominique Westhondo Osomba; Patrick Vualu Ibula Mambenga; Michel Seya Kabongo2/28/202610.51865/JPGT.2026.01.02engineering; technologyThe Upemba Rift, located in the southeastern Democratic Republic of Congo, constitutes a sedimentary sub‑basin that remains largely underexplored despite its presumed petroleum potential. Covering an area of approximately 46,519 km², it recently attracted attention during the licensing rounds launched in 2022 by the Ministry of Hydrocarbons of the Democratic Republic of Congo. However, the absence of modern seismic data as well as detailed geological and geochemical surveys significantly constrains the assessment of its hydrocarbon prospectivity. The only available information derives from the magnetic survey conducted by CGG in 1986, which has already been interpreted in various studies. Within this context, the present study – Geophysical characterization of structures in the Upemba Graben and estimation of sedimentary thickness using the Source Parameter Imaging (SPI) method: Reprocessing and integrated analysis of magnetic data – aims to propose a preliminary sedimentary model and to shed light on the morpho‑tectonic evolution of the basin, thereby further highlighting its petroleum potential as well as the maximum sedimentary thicknesses of this intra‑cratonic basin. The results obtained are based on an integrated methodological framework combining a multimodel numerical approach, critical and comparative analysis, and an in‑depth morpho‑tectonic interpretation, together with sediment thicknesses derived from the SPI method, emphasizing their quantitative contribution. Taken together, these elements provide a robust preliminary argument that contributes to a better understanding of the morpho‑tectonic history and sedimentary dynamics of the Upemba Graben and its petroleum system, thereby paving the way for increased interest from potential partners and renewed momentum in future exploration campaigns. -
GROSS DEPOSITIONAL ENVIRONMENT ASPECTS OF THE UPPER HOLOCENE SANDS FROM PETROLEUM-GAS UNIVERSITY OF PLOIESTI AREA USING GRANULOMETRIC ANALYSIS
Dan-Romulus Jacotă; Daniela-Doina Neagu2/18/202610.51865/JPGT.2026.01.01engineering; technologyGranulometric analysis conducted on four samples from the same Holocene depth (covering 1363.73 sqm) reveals strong evidence for a braided fluvial environment, consistent with channel bar, levee, and floodplain deposition. Upon analysis, statistics reveal significant spatial heterogeneity: mean grain sizes range from 0.124 to 0.226 mm, while standard deviations (0.161–0.212 mm) reflect variable sorting. Kurtosis spans from 0.717 to 2.99, with higher values indicating well-sorted, peaked distributions from low-energy suspended settling (levee/floodplain) and lower values marking broader, mixed sorting in active channel bars. Positive folk skewness and diverse uniformity coefficients further point to episodic fluctuations in hydraulic flow and rapid sediment pulses. The coexistence of fine and coarse fractions and contrasting sorting regimes – supported by the absence of marine influence in the Holocene – confirms alternating energy and sediment supply typical of a braided river. These textural signatures underpin a gross depositional environment map, highlighting dynamic channel migration and nuanced fluvial architecture. -
NUMERICAL MODELING OF CONVECTIVE AND MOLECULAR TRANSPORT MECHANISMS OF HYDROGEN IN DEPLETED GAS RESERVOIRS
Rami Doukeh; Timur-Vasile Chiș; Laura-Ștefania Păun; Alexandra Mohanu; Mihai Adrian Albulescu; Doru Bogdan Stoica12/7/202510.51865/JPGT.2025.02.15engineering; technologyThis study presents a numerical investigation of hydrogen injection and migration in a depleted natural gas reservoir, integrating convective and molecular transport mechanisms. A 2D simulation model based on real geological data was developed using a discretized mesh and realistic operational parameters, including 15 active injection wells each delivering 250,000 Sm³/day. Four main operational scenarios were analyzed: continuous injection over 120 days and three subsequent cycles incorporating post-injection relaxation intervals of 5, 10, and 15 days. Results show that continuous injection leads to stable reservoir behavior, with progressive pressure buildup and efficient gas accommodation. However, the introduction of relaxation periods reveals improved gas redistribution and saturation homogeneity, especially in the 15-day case, where hydrogen diffusion becomes significantly more uniform across the reservoir volume. Despite minimal differences in global pressure between relaxation scenarios, only the extended relaxation phase ensures optimal pore space utilization and mitigates localized overpressure risks. These findings emphasize the critical role of tailored injection-relaxation cycles in maximizing hydrogen storage efficiency and maintaining reservoir integrity, contributing to the optimization of underground hydrogen storage strategies in depleted gas formations. -
EVALUATION OF THE CONTRIBUTION OF HYDRAULIC FRACTURING OF THE CENOMANIAN RESERVOIR TO THE PRODUCTIVITY OF WELLS IN THE MAKELEKESE FIELD, DEMOCRATIC REPUBLIC OF CONGO
Emmanuel Balu Phoba; Dona Kampata Mbwelele; Dieudonné Yenga Zidiaposo; André Yelembangu Ngwey; Jean Iyolo Lungembo12/5/202510.51865/JPGT.2025.02.14engineering; technologyThe Democratic Republic of Congo, with its Coastal Basin, represents a major source of liquid and gaseous hydrocarbons. This study explores the use of hydraulic fracturing as a method to enhance production in the Makelekese-08 (MS-08) and Makelekese-10 (MS-10) wells within the Makelekese field. As many oil fields in the region mature, it becomes essential to adopt advanced techniques to maximize the extraction of remaining reserves. The primary objective of this research is to assess the impact of hydraulic fracturing by analyzing fracture propagation and its influence on reservoir productivity. Specific objectives include characterizing the lithological and petrophysical properties of the Cenomanian reservoir, including porosity and permeability. Providing a detailed description of the fracturing treatment, including the fluids, additives, and injection parameters. Analyzing production variations before and after fracturing, demonstrating increases of up to three times the initial production. This study aims to fill a gap in quantitative assessments and local geological data regarding hydraulic fracturing in the Coastal Basin. By integrating geological, petrophysical, and operational analyses, it offers significant insights into reservoir stimulation and its effectiveness in enhancing hydrocarbon recovery. -
PIPE SORTING SYSTEM – FROM DESIGN TO IMPLEMENTATION
Bogdan Cojocaru; Cristina Popescu; Gabriela Bucur; Emil Gocan12/3/202510.51865/JPGT.2025.02.13engineering; technologyThis paper presents the design, development, and validation of an automated pipe sorting system built as a small-scale prototype integrating mechanical structures, infrared sensing, and Arduino-based control. The project follows the complete engineering workflow, beginning with concept generation and functional decomposition, continuing with iterative prototyping, subsystem testing, and final integration. The system performs pipe transportation, length measurement through timed sensor interruption, and robotic sorting using a 6-DOF arm. Emphasis is placed on experimental calibration, modular programming, and problem-solving strategies that address challenges such as sensor sensitivity, mechanical alignment, and communication constraints. Results show that the prototype achieves consistent classification for four pipe lengths, demonstrating that low-cost components and systematic testing can yield a reliable model of industrial automation. The project can also be expanded diversifying the types of pipes that can be sorted, increasing measurement accuracy, as well as using AI techniques in decision-making mechanism. The study highlights the educational value and scalability potential of modular, resource-efficient automation design. -
THE INFLUENCE OF DIGITALISED MAINTENANCE DATA ON OPTIMISING PREDICTIVE MAINTENANCE IN THE SOUTH AFRICAN PETROCHEMICAL INDUSTRY
This study investigates the impact of digitalising maintenance data on the optimisation of predictive maintenance practices within the South African petrochemical industry. A conceptual model framework was developed through a systematic literature review. The framework explored the relationship between current maintenance practices, centred around Computerised Maintenance Management Systems (CMMS), and the projected benefits of digitalised predictive maintenance. A questionnaire was administered to maintenance and operations personnel to determine the status of maintenance data usage, perceptions of digitalisation benefits and organisational readiness indicators within the South African petrochemical industry. Findings indicate that while maintenance data are already utilised for operational decisions, much of it is manually collected and input into CMMS platforms. There is a clear opportunity for digital transformation, even though the supporting infrastructure remains partially developed. The results affirm that digitalising maintenance data can significantly improve predictive maintenance capabilities and decision-making effectiveness. Recommendations highlight the need for further research into how maintenance personnel, especially those from older or less technologically exposed cohorts, can be supported in embracing digital tools. The study’s managerial implications underscore the necessity for leadership to address human-centric challenges when deploying data-driven maintenance strategies and to foster a culture that enables digital transformation in maintenance environments. -
COMPREHENSIVE CHARACTERIZATION OF RESERVOIR VARIABILITY WITH THE ROCK TYPING METHODOLOGY: A CASE STUDY OF FIELD F-A, BREDASDORP BASIN, OFFSHORE SOUTH AFRICA
Omar Derder; Mimonitu Opuwari11/19/202510.51865/JPGT.2025.02.11engineering; technologyThis research categorizes the sandstone reservoir rock type (PRT) and flow units (FU) by the inaugural effort to amalgamate Winland and MLP studies for the classification of flow units in the Bredasdorp Basin, Offshore South Africa. Within a system of structural and stratigraphic traps lies the upper shallow marine sandstone reservoir, which is the primary target. Shelf and fluvial sandstones are the secondary targets. Shallow marine and shelf sandstones compose quartz-rich, mature reservoirs featuring stable, laterally extensive flow units, whereas fluvial sandstones are classified as less mature lithic types with more heterogeneous flow units influenced by geometry and diagenesis. This study used cores and well logs data from five different wells provided by the Petroleum Company of South Africa (PetroSA). The quantitative identification and classification of rock types and flow units within the reservoir are accomplished by integrating standard and specialized core analysis with a comprehensive core description. The reservoir rocks mostly comprise shale, lithic, siltstone, and sandstone, varying from very fine to medium grain size. Windland R35 analysis. Modified Lorenz plotting, statistical clustering, lithofacies identification, flow capacity evaluation, and storage capacity evaluation was used to classify the rock types and five flow units in the Bredasdorp reservoir. Low quality reservoir is represented by the first group, which includes PRT5 and Nano-port types. Intermediate qualities reservoirs are represented by PRT4 and PRT3, Micro-Meso port types, which include shale, siltstone, and very fine to fine sandstones. High quality reservoirs, including PRT1 and PRT2, Meso-Mega port types, also composed of fine to medium sandstones. The litho-facies (SM4) demonstrate the largest porosity exceeding 17.5 %, permeability surpassing 200 mD, and superior flow unit characteristics with pore throat size more than 20 µm in comparison to the other petrofacies. The litho-facies (SM3) demonstrate relatively high porosity and permeability, while litho-facies (SM2) demonstrate moderate values when compared to litho-facies (SM3). Conversely, the lithofacies of shallow marine (SM1) and fluvial (F) environments demonstrate the lowest porosity, below 13%, permeability under 1.5 mD, and a minimal pore throat of 1 µm among the four litho-petrofacies found in the deposits. -
SEDIMENTARY BASINS AND HYDROCARBON RESOURCES ON A GLOBAL SCALE: INSIGHTS FROM ROMANIA
Daniela-Doina Neagu; Elena-Rodica Stoica-Negulescu11/19/202510.51865/JPGT.2025.02.10engineering; technologyGlobal economies and infrastructure still depend heavily on petroleum-based products. Despite significant initiatives aimed at transitioning to renewable energy, the oil and gas sector continues to play a key role in shaping both the global economy and political landscape. Organizations like the U.S. Energy Information Administration, the U.S. Geological Survey, and the BP Statistical Review of World Energy have gathered extensive data reflecting this ongoing reliance. Oil reserves are not uniformly distributed across the globe. The Middle East holds the majority of the world's confirmed reserves, followed by countries such as United States and the Canada, as well as regions in Latin America, Africa, and the former Soviet states. Hydrocarbon deposits of a basin, or even part of it, led to the concept of an oil province that is mainly based on the analysis of geological setting. The defining of a petroleum system or province considers several criteria: geographic criteria (especially the extent and volume of rocks of interest); geological criteria (type of basin and its classification, stratigraphy) and petroleum criteria (potential and volume of discoveries, type of reservoir). After classifying giant oil fields according to basin and tectonic setting, several conclusions were drawn and a hierarchy was established: passive continental margins facing large ocean basins host of about 31% of giant deposits; continental rifts and overlying sag basins contain about 30% of the world's largest oil fields; the final collision belts between two continents form major basin that contains for approximately 24% of global giant fields; and continental arcs at convergent plate boundary, strike-slip systems, and subduction margins together host 15% of the world's giant fields. Looking ahead, the direction of oil exploration will be influenced not only by the quantity and type of resources available in the mentioned areas, but also by geopolitical dynamics and technological advances. Improved seismic imaging and detailed reservoir analysis are expected to play a greater role, especially in the development of unconventional resources such as tight oil, tight gas and shale formations. Romania can be considered the second largest oil producer and the third largest gas producer in the EU. Most known oil and gas fields in Romania have reached maturity, but the exploration of deeper structures has led to several recent discoveries. Current research techniques based on high-resolution seismic images correlated with a complex geophysical well investigation are expected to reveal new hydrocarbon accumulations both onshore areas (in orogenic or foreland type basins) and offshore in the western Black Sea basin. In order to have a clear picture of the development directions for oil and gas fields, this study analyzed data and statistics provided by specialized institutions and literature, synthesizing them in a clear and suggestive way possible according to the diagram below. The paper represents a first step in guiding future exploration efforts. -
GEOPRESSURE PREDICTION AND INTENSITY CHARACTERIZATION BASED ON FUZZY INFERENCE SYSTEM IN BARBADOS FIELD OF THE NIGER DELTA, NIGERIA
Olabanji Adeolu Ojo; Oluwatoyin Abosede Oluwadare; Jeremiah Ademola Balogun; Kehinde Olubunmi Akinterinwa11/12/202510.51865/JPGT.2025.02.09engineering; technologyIn the paper we present a method of characterizing overpressure intensity in an oil field from wireline log with fuzzy inference system using well logs from Barbados field in the Niger Delta area of Nigeria. The method employs pressure coefficients obtained from the ratio of the pore pressure and the hydrostatic pressure as input into the fuzzy system. The lithostatic and hydrostatic pressures were derived from sonic and density log equations while the Hunt and Shi classifications were used to characterize the overpressure intensity, although with a slight modification. The plot of sonic log with depth in the wells followed a typical stepped-tiered configuration having a maximum of three episodes of abnormal pressure. The distribution of pressure coefficient (PC) increases from the left flank to the right flank of the field. Mild overpressure with PC values of 1.28, 1.35 and 1.53 were observed at shallowest depth and 1.33, 1.36 and 1.32 at intermediate depths. Strong overpressure with maximum PC values of 2.04, 2.46, 3.60 and 3.75 were observed in Barbados wells 1, 2, 3 and 4 respectively at greater depths. The result from this study has proven to be a dependable tool in the characterization of overpressure intensity as well as serve as a guide for predicting overpressure behavior in adjacent areas. Further work on pressure coefficient (PC) computation in the vicinity of well kicks, caving, loss of drilling mud, or possibly full blowout is welcomed from other workers. -
EVALUATION OF THE GEOCHEMICAL AND PETROGRAPHIC CHARACTERISTICS OF THE INKISI FORMATION IN THE SEDIMENTARY BASIN OF THE CENTRAL BASIN
Jean Iyolo Lungembo; Joël Etshekodi Lohadje; Serge Diemo; Dona Kampata Mbwelele; Adalbert Makutu Mangwayaya11/5/202510.51865/JPGT.2025.02.08engineering; technologyThe Congo Craton, located in the central depression, hosts an interior sedimentary basin covering over 800,000 km², subdivided into four intracontinental sub-basins: Busira, Lokoro, Lomami, and Bushimayi. The formation of this vast Neoproterozoic basin results from an initial stretching of the lithospheric crust followed by thermal subsidence, corresponding to the rebalancing of the lithosphere during the Pan-African orogenic cycle. This tectonic activity led to the formation of pull-apart basins, reflecting the generalized subsidence of the craton in the central depression. The general lithostratigraphic column of the basin comprises five sedimentary sequences, among which the Inkisi sandstone formation is central to our study as a potential reservoir rock. The analysis of the deposits and sedimentary evolution of this formation is essential for determining its porosity and permeability, key characteristics for a hydrocarbon reservoir. The choice of the southwestern part of the basin, specifically on the outskirts of the provincial city of Kinshasa, is motivated by the accessibility of this rock and the absence of in-depth studies in this area. This research aims to enhance the understanding of the geological characteristics of the Inkisi formation, particularly in a context that has never been studied in depth. Geochemical analysis and the assessment of the alteration state of the rocks will provide unprecedented information on their petrographic potential. By highlighting aspects such as porosity and permeability, this study offers new perspectives for oil exploration in the central depression. Despite the importance of the Inkisi formation, previous research has often overlooked a detailed analysis of its petrographic and sedimentary characteristics. Few studies have been conducted on the southwestern portion of the basin, particularly regarding geochemical properties and the alteration state. This study aims to fill these gaps by providing a comprehensive and integrated analysis that could serve as a basis for future research and the exploitation of natural resources in the region. -
AI-COORDINATED SELF-SUSTAINING FLOATING PLATFORM FOR COMPLETE ECOLOGICAL CONVERSION OF SUBMARINE PETROLEUM WASTE
This paper presents an integrated system comprising marine platform engineering, thermal processing technologies, and AI-based automation for ecological conversion of submarine petroleum waste into exportable electrical energy. The system combines a floating platform adapted from offshore wind technology, established thermal processing methods, and AI coordination to achieve autonomous operation. The platform engineering utilizes proven offshore wind stabilization principles for optimal performance in shallow water conditions (50-200m depth). The thermal processing integrates CO₂-protected pyrolysis with oxygen-enhanced gasification, while thermoelectric conversion systems capture energy across all temperature ranges. The AI coordination system manages real-time process optimization and autonomous operation. Building upon established research in petroleum waste treatment, this integrated approach addresses the complete technological chain from platform stability to energy export. Initial calculations indicate high thermal utilization efficiency with energy self-sufficiency plus surplus energy available for export. The platform maintains stable operation in marine conditions including waves up to 15m height and winds up to 30 m/s, demonstrating 95% operational uptime during severe weather events. -
THE VALUE OF FRP PIPE FLEXIBILITY
Alin Diniță; Marius-Gabriel Petrescu; Costin Nicolae Ilincă; Ștefan Alexandru Gavrilă10/21/202510.51865/JPGT.2025.02.06engineering; technologyThis article examines the use of fibre-reinforced polymer (FRP) composites in pipeline transport applications, highlighting the advantages of these materials in terms of mechanical performance and durability. The properties and classification of FRP materials, manufacturing processes, joint types, and above-ground and underground installation solutions are analysed. In addition, reference is made to the ISO 14692 regulatory framework used to assess pipe flexibility, including experimental investigations of mechanical behaviour through tensile and bending tests. The last part of the study presents analytical models and numerical simulations designed to determine maximum stress and displacements, with the results obtained demonstrating compliance with the requirements of relevant international standards. -
NUMERICAL MODELING OF THERMAL ENERGY TRANSFER BETWEEN ROCKS AND GROUNDWATER
Ioana Purghel; Maria Stoicescu; Dragos Cristea; Monica Tegledi9/30/202510.51865/JPGT.2025.02.05engineering; technologyGeothermal energy, derived from the Earth's internal heat, stands out as a powerful and consistent renewable resource. Unlike intermittent sources such as solar and wind, it provides a stable, 24/7 baseload power supply suitable for everything from large-scale electricity generation to direct-use heating and climate control. This study investigates the low-enthalpy geothermal potential near the Petroleum-Gas University of Ploiesti, Romania, where the ground maintains a constant temperature of 13-14°C at a 100-meter depth. We developed a numerical model to simulate the heat transfer between rock formations and groundwater to assess the viability of a thermal recovery project.The simulation results point to a stable heat transfer rate of 2-10 kW/m² from the surrounding rock to the groundwater. Our model shows that a four-well system could sustainably produce water at 13.5°C with a flow rate of 30 l/h over a 10-year period, causing a negligible temperature drop of less than 0.5°C in the reservoir. Ultimately, the model confirms that harnessing low-enthalpy geothermal energy in Ploiesti is a viable option. The constant and accessible underground temperature presents a significant opportunity for direct-use applications, such as a district heating system for the university campus. This research demonstrates that even modest thermal gradients can be effectively utilized to develop local and sustainable energy solutions. -
RELIABILITY ANALYSIS AND OPERATIONAL RISK MATRIX OF SAFETY VALVES
This research investigates the application of reliability theory to safety valves, emphasizing fundamental concepts such as the reliability function R(t), failure function F(t), failure rate λ(t), Mean Time To Failure (MTTF), and Mean Time Between Failures (MTBF). A practical case study, based on data collected from a petrochemical operator, illustrates how reliability analysis can identify critical failure modes such as blockage, leaks, early opening, and corrosion, highlighting their severe consequences in safety-related applications. This research applies reliability theory to safety valves, utilizing statistical models like Exponential and Weibull distributions to analyse failure modes such as blockage, leaks, early opening, and corrosion. A key finding is that valve reliability significantly declines after approximately 3,000 operational hours, emphasizing the need for predictive maintenance strategies based on historical and real-time operational data. The study advocates for integrating reliability and maintenance analysis throughout the safety valve lifecycle, shifting from reactive to proactive maintenance to reduce unexpected failures and optimize costs. The study develops an integrated mathematical methodology for failure probability estimation. A case study from a petrochemical operator uses risk assessment tools like risk matrices to prioritize maintenance actions. Data analysis reveals an MTBF of 4250 hours, a CoV of 0.577, and reliability dropping to 49.3% at 3000 hours and 30.8% at 5000 hours. Valve blockage and leaks are critical risks, while premature opening and corrosion are medium risks. Recommendations include using the exponential distribution for reliability analysis, implementing predictive maintenance after 3000 hours, periodic inspections and fluid filtration for valve blockages, and seal replacements and leak-tightness checks for leaks. -
AUTOMATIC SYSTEM WITH PLC FOR MONITORING THE PARAMETERS OF A GAS WELL
Alexandru Vasile; Gabriela Bucur9/29/202510.51865/JPGT.2025.02.03engineering; technologyMonitoring gas well parameters is essential to ensure the efficient, safe and compliant operation of natural gas extraction and transportation facilities. By monitoring critical values in real time, any anomalies can be quickly detected and corrective measures can be implemented to prevent incidents and optimize production. The monitored parameters typically include: pressure (at the wellhead and in the column), gas flow, temperature, water content or other impurities, sand or solid particle level (if applicable). Modern monitoring systems use digital sensors, data transmission through SCADA networks and analysis algorithms for rapid data interpretation. This provides complete visibility into the performance of each well and contributes to extending the life of the equipment and increasing operational efficiency. The paper presents aspects of the design and implementation of an automatic PLC monitoring system for gas well parameters. Based on the block diagram of the monitoring system, a new configuration of the placement of transducers on the well eruption head is proposed. The system’s electrical diagrams are provided, along with the PLC programming steps and the operating specifications. Additionally, details are included regarding the HMI interface, highlighting how users can easily navigate, set transducer measurement intervals, perform calibrations, or activate alarms. -
NUMERICAL MODELING OF THE RISKS OF OIL PLATFORMS
Daniel Iancu; Al-Gburi Hasan Ali Mosleh; Timur Chis; Monica Tegledi9/24/202510.51865/JPGT.2025.02.02engineering; technology(1) Background: The structural integrity of offshore platforms can be compromised by numerous environmental factors, including wind, waves, ocean currents, seismic activity, or biological accumulations (e.g., vegetation). These elements, acting in concert, generate complex dynamic stresses that must be considered both at the design stage of these structures and subsequently, when assessing their safe operating life. (2) Methods: Based on the research of the international study and the local research study, the authors simulated the effects of the wind and wave equations of the Romanian Offshore Gas Platform Ana. In the context of the above, this paper will focus on describing a method for predicting horizontal displacements for fixed jacket platforms. These displacements are induced by the combined action of the environmental factors mentioned above, and their prediction will be achieved through artificial neural networks. (3) Results: This study presents a new model of ANNs, enabling forecasts of the structural behaviour of a platform deck under various scenarios involving wind, waves, sea currents, and different water depths, and predictions that are particularly valuable in the engineering design process. We introduced in this paper a new Artificial Intelligent Models to prediction environments effects of the Romanian Gas Platform Ana. (4) Conclusions: The design of any element of a fixed structure's analysis function to external forces is determined, and we will analyse exclusively the impact generated by waves, considering that the influence of sea currents is negligible in the specific context of this demonstration, applying the Morison equation. -
CONTRIBUTION TO THE STRUCTURAL STUDY AND PETROLEUM INTEREST OF THE NORTHERN PART OF THE TANGANYIKA BASIN OF THE WESTERN BRANCH OF THE EAST AFRICAN RIFT OF D.R. CONGO
Yves Bolokole Mpehenzale; Chadrack Lulaila Mongoto; Albert Ongendangenda Tienge; Tychique Moke Impumpu; Aristide Mbongeli Kinda8/7/202510.51865/JPGT.2025.02.01engineering; technologyDiscoveries are succeeding each other as oil was perceived, a long time ago, as a rather rare resource in sub-Saharan Africa. Paradoxically, it is found everywhere, from Angola to Guinea-Bissau, then along the entire western coast, notably in Ghana, Ivory Coast, and other countries. In addition, for East Africa, interest is not only focused on offshore oil from the Indian Ocean (Mozambique, Tanzania), but also within the continent in the geological structures formed by the East African rifts. In our work, we consider the Tanganyika basin in the East African rifts. Indeed, in certain parts of the Tanganyika basin, oil seepages are visible, with a significant proportion on the side of the D.R.C. (Cap Kalamba), indicating the maturation of the source rock in this area. Thus, the Tanganyika basin has been the subject of hydrocarbon research by several companies, universities, and organizations. However, a problem arises; in 1987, former oil company AMOCO conducted a drilling campaign in the Ruzizi plain during which two wells were drilled, Buringa-1 and Ruzizi-1. Neither of these wells produced oil, and subsequently, AMOCO abandoned all its concessions in the rift region in 1989. This work consists of contributing to the reinterpretation of seismic data conducted by Duke University in 1983-1984 as part of the project PROBE (Proto-Rifts and Oceanic Basin Evolution) in the northern part of the Tanganyika basin, with a view to clarifying its structural model and its oil potential. Indeed, with the advancement of technology, the reinterpretation of these old data can prove important in that we may be able to highlight certain previously unnoticed information due to the limitations of interpretation tools. -
A REGRESSION MODELS OF THE GAS DRILLING WELL ERUPTION
Daniel Iancu; Al-Gburi Hassan Ali Mosleh; Timur-Vasile Chis6/27/202510.51865/JPGT.2025.01.25engineering; technologyDuring drilling operations carried out to explore or exploit oil and/or natural gas deposits, uncontrolled eruptions (technical accidents) have also occurred, which have led to damage to the well and, above all, have affected the capacity of the productive layers to continue producing under the initial conditions provided for in the exploitation projects. Also, the explosion of the Deepwater Horizon platform has brought the creation of numerical models (based on numerical regression or artificial intelligence) to avoid such accidents back into the discussion. We developed AI-based numerical regression models to prevent uncontrolled eruptions during Black Sea drilling. -
OPTIMIZATION OF AI-COORDINATED INTEGRATED THERMAL-ELECTRIC SYSTEMS FOR GEOTHERMAL WATER VALORIZATION: A CASE STUDY FROM CĂCIULATA REGION, ROMANIA
This study presents an innovative AI-coordinated approach for integrated thermal-electric systems applied to geothermal water valorization in the Căciulata region, Romania. The research combines advanced thermodynamic analysis with electrochemical extraction techniques and artificial intelligence for autonomous optimization. Based on comprehensive analysis of geothermal water characteristics following validated Romanian mineral water standards [1] and advanced AI modeling, results demonstrate significant optimization potential with estimated electricity generation of 1,262,665 kWh annually from 317,706 cubic meters of geothermal water processing. The AI system incorporates optimal mineral composition parameters with bicarbonate concentrations >20mEq% and Kurlow formula adaptations for maximum thermal conductivity. The AI-coordinated system shows enhanced economic viability with efficiency improvements of 15-25% and a payback period of 1.95 years. Environmental benefits include 838 tonnes annual CO₂ reduction and sustainable mineral recovery of 640,484 kg annually. The study contributes to advancing AI-integrated geothermal energy utilization and provides a scalable model for Industry 4.0 thermal facilities. -
END-TO-END SECURE WIRELESS SENSOR NETWORK USING PKI INFRASTRUCTURE AND RASPBERRY PI PICO W
Emil Gocan; Gabriela Bucur; Cristina Popescu6/16/202510.51865/JPGT.2025.01.23engineering; technologyIndustry 5.0 is the evolution of the industrial revolution that goes beyond automation and smart systems (Industry 4.0). It focuses on human-machine collaboration, sustainability, resilience, and security. The proposed security system also aligns with the vision of Industry 5.0, which emphasizes not only automation and efficiency but also cyber-resilience, sustainability, and human-centric design. By employing a Public Key Infrastructure (PKI) combined with JWT-based authentication and lightweight cryptographic techniques, the proposed system enhances the trustworthiness and adaptability of Wireless Sensor Networks (WSNs). These features are critical for Industry 5.0 environments, where secure collaboration between humans and intelligent devices is expected to be seamless, scalable, and resilient against emerging cybersecurity threats. This paper proposes a secure, lightweight, end-to-end architecture for WSNs using a Raspberry Pi Pico W microcontroller, digital certificates and a Public Key Infrastructure (PKI) server. The system uses AES and RSA cryptography, JWT-based authentication, and HTTPS communication to protect data from MITM, replay, spoofing, and injection attacks. Data collected from sensors is encrypted and sent via a REST API to a secure server with MySQL integration. The paper details the implementation, testing, and performance of this model and discusses its limitations and future improvements, including extended sensor coverage and blockchain-based trust models. -
A REVIEW OF HYDROGEN STORAGE IN GEOLOGICAL FORMATIONS
Rami Doukeh; Alexandra Mohanu; Daniel Nereamza; Iuliana Cristea; Mihai Adrian Albulescu; Timur-Vasile Chiș6/7/202510.51865/JPGT.2025.01.22engineering; technologyThis review presents a thorough analysis of the technical, geological, and economic aspects of Underground Hydrogen Storage (UHS), positioning it as a key enabler for large-scale deployment of clean hydrogen supply chains. As global hydrogen demand increases particularly in traditional sectors such as refining and ammonia production the development of safe, seasonal, and scalable storage systems becomes essential to support renewable-based energy infrastructures. Geological hydrogen storage is identified as the most viable solution due to its advantages in volumetric energy density, intrinsic safety, and the availability of suitable subsurface structures such as salt caverns, depleted hydrocarbon reservoirs, and deep aquifers. Techno-economic analyses show that UHS is considerably more cost-effective and technically feasible for large volumes compared to surface-based storage methods. The review synthesizes real-world experiences from the UK, USA, and Austria, where field-scale pilot projects demonstrated up to 82% recovery of injected hydrogen with no significant degradation in reservoir integrity. The paper also highlights challenges related to microbial activity, particularly in porous formations with residual hydrocarbons or brine, where biological methanation or hydrogen loss could occur. A comparative analysis of hydrogen’s physical properties versus methane is included, focusing on density, viscosity, interfacial tension, solubility, and diffusivity, and how these influence hydrogen behavior in porous geologic media. Additionally, the role of cushion gas (e.g., CO₂, N₂, CH₄) is evaluated for its contribution to maintaining reservoir pressure and enhancing extraction performance. The gas selection is shown to significantly impact chemical compatibility, environmental risk, and operational efficiency. In conclusion, this review underscores that the successful deployment of UHS requires a multi-scale understanding of hydrogen dynamics in subsurface formations, supported by robust experimental validation and numerical modeling, to ensure safe, efficient, and climate-resilient storage operations over the long term. -
CONTRIBUTION TO THE GRAVIMETRIC AND MAGNETOMETRIC STUDY FOR THE IDENTIFICATION OF ZONES WITH OIL POTENTIAL IN THE CENTRAL BASIN: CASE OF BLOCKS 1 AND 24 IN THE DRC
César Tambashie Okitafumba; Ravely Nsieto Lusakueno; Michel Ndete; Osée Mayinga Mayinga; Bob Mayemba Kisaka; Franklein Muamba Kanangila6/7/202510.51865/JPGT.2025.01.21engineering; technologyIn the search for hydrocarbons, geologists, geochemists and geophysicists work together on the scale of a sedimentary basin. They seek to identify a petroleum system in order to maximise the chances of finding an accumulation of hydrocarbons in a specific part of the subsoil. The exploration campaign in the Cuvette Centrale began in the 1950s with geological, geophysical, geochemical and drilling campaigns carried out by several foreign organisations, including the Belgian firm Remina. These campaigns provided key information about the petroleum systems. These include the presence of hydrocarbon showings and geological structures that may favour the formation, migration and trapping of hydrocarbons. The main aim of this work is to highlight the geological structures of major petroleum interest, while identifying the geological structures found in our study area, particularly in Blocks 1 and 24 in the central basin of the Democratic Republic of Congo, and their petroleum interest, based on the processing and interpretation of magnetic and gravity data. To better study our sedimentary basin, we used the method of regional-residual separation and variation of the Magnetic Field, we had to highlight the faults in different directions North-West towards the South-East, the collapse trenches localised in the North-East, the zones of uplift of Socle which today constitute the top of Inongo. As never done before, this study develops a structural reference model by integrating the analysis of Bouguer and magnetic anomalies. It aims to locate zones of source rock maturation, identify possible hydrocarbon migration paths and pinpoint geological structures conducive to hydrocarbon accumulation. The results, presented in map form, are a strategic tool for petroleum exploration and the analysis of regional tectonic dynamics. In particular, it provides an unprecedented and detailed geophysical record for Blocks 1 and 24 of the Cuvette Centrale, enabling a targeted and efficient assessment of petroleum potential. -
BASIC WELL LOG INTERPRETATION IN PYTHON PROGRAMMING LANGUAGE
Mihai Iorgandopol; Patricia Tita6/6/202510.51865/JPGT.2025.01.20engineering; technologyPython has rapidly become the programming language of petroleum geoscientists during the last decade. It is used widely in development, research and scientific activities and is included in many commercial software as an option for additional scripting purposes. Geophysical well log data interpretation is one of the most useful and important tools available to a petroleum geologist [12]. The results of log analysis and interpretation play an important role in the decision making in oil and gas activities throughout the exploration, development and production stages. The standard log interpretation workflow for petrophysical analysis of the wells includes: data loading, QC and editing (1); borehole environmental corrections (2); calculation of shale volume (3); porosity calculation (4); water saturation calculation (5); identification of lithology type (6); estimation of net and pay thickness (7). In this tutorial it is shown how to use Python programming code to carry out the standard well log interpretation steps. Third-party libraries have been used in the tutorial: Matplotlib was used in the graphical parts of the scripts; Pandas library was used as a data analysis and manipulation tool. In addition, the following specifically designed Python libraries were used for log data reading and calculations: Lasio, a Python package to read and write Log Ascii Standard (LAS) files and petrophysics, which is a library containing a petrophysical collection of formulas written as Python functions. -
ANALYSIS OF THE PERFORMANCE OF THE TSHIENDE OIL FIELD DURING WATER INJECTION
Joseph Lukola Empenga; Dominique Wetshondo Osomba; Daddy Balondo Iyela; Dona Kampata Mbwelele; Joel Kabesa Kilungu6/6/202510.51865/JPGT.2025.01.19engineering; technologyWe analysed the efficiency of the production technique used by Perenco in the Tshiende oil field in the Democratic Republic of Congo. Initially, this field produced oil by natural drainage, based on the mechanisms of fluid expansion and rock compressibility. However, in 1986, a drop in reservoir pressure led to a reduction in production, making it necessary to adopt water injection to compensate for this loss and optimize hydrocarbon recovery. This research responds to the imperative of satisfying growing energy demand while preventing the early abandonment of fields. We used a data storage unit, a computer system and specialized software to process and analyses the data collected. The results show that water injection has considerably improved field performance. Oil production increased and the average reservoir pressure remained above the bubble pressure (927). In addition, the volume of water produced (128907050 m3) gradually exceeded the volume of water injected (107348149 m3), demonstrating the effectiveness of the reservoir sweep. However, variations in the injection rate created imbalances between injection and withdrawal. In 2014, the Voidage Replacement Ratio (VRR) was equal to 1, indicating a temporary equilibrium. The relationship between oil production and VRR confirms that the production rate is directly dependent on the amount of water injected, signalling inactivity in the aquifer. Between 1986 and 1991, the production of oil and water was almost equivalent, but currently, the production of water exceeds that of oil, indicating that the water produced is greater than the water injected. Thanks to the injection of water, the recovery rate for the Tshiende field has increased significantly, from 2.6% to 39.8%, due to the improved efficiency with which the oil is displaced. A volume of water corresponding to that of the pores occupied by the hydrocarbons exceeds 0.90, showing that water saturation is greater than that of the oil. In conclusion, water injection has proved to be an effective solution for extending the productive life of the Tshiende field and improving its recovery rate. We recommend that the company continue to investigate the existence of an aquifer in the field and explore other development campaigns, particularly in the Pinda reservoir, where the results promise new production opportunities. -
DRILLING OPTIMIZATION IN ROMANIAN GAS FIELDS USING ADVANCED DIGITAL TOOLS
Viorel Dragomir; Bogdan Andrei Ionete; Dragos Răzvan Dicu; Mihail Tudose; Lazăr Avram; Liviu Dumitrache6/5/202510.51865/JPGT.2025.01.18engineering; technologyThe continuous evolution of the energy industry, driven by decarbonization goals and digital transformation imperatives, has led to significant advancements in drilling operations. This article explores the integration of advanced digital tools, real-time monitoring systems, predictive analytics, and automated drilling rigs as key enablers of operational excellence in upstream activities. A comprehensive overview is provided on how closed-loop digital workflows, adaptive control systems, and automation technologies have improved drilling efficiency, reduced non-productive time (NPT), enhanced safety, and supported environmental sustainability efforts. The paper presents an in-depth case study conducted in a Romanian gas field, where targeted drilling optimization initiatives were implemented across multiple well sections. In addition to digital enhancements, the use of Non-Aqueous Drilling Fluids (NADF) was a decisive factor in overcoming geological challenges associated with reactive shales and unstable formations. Compared to conventional Water-Based Muds (WBM), NADF systems delivered superior wellbore stability, reduced filtrate invasion, higher rate of penetration (ROP), and improved compatibility with directional drilling. Through real-time parameter adjustments, connection efficiency improvements, surveying strategy optimization, and dynamic management of critical-path activities, cumulative time savings exceeding five rig days per well were achieved. The study also highlights the benefits of predictive maintenance, adaptive drilling practices, and digital twin simulations as future avenues for further optimization. The findings demonstrate that a strategic approach combining advanced technology, high-performance drilling fluids, real-time operational intelligence, and continuous improvement frameworks can substantially enhance drilling performance, reduce costs, and support sustainable field development. The article concludes by identifying future focus areas such as adaptive drilling systems, machine learning-driven predictive analytics, expanded use of digital twins, and organizational standardization, offering a roadmap for achieving resilient and competitive drilling operations in the context of the global energy transition.
ISSN print: 2734–5319
ISSN online: 2972–0370
ROMANIAN JOURNAL OF PETROLEUM & GAS TECHNOLOGY
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