Middle East
Fractures Characterization and Their Impact on the Development of a Tight Oil Field
Conde, Oliver Rojas (Texas A&M University, College Station) | Silva, Henry Galvis (Texas A&M University, College Station) | Doghmane, Mohamed Zinelabidine (University of Sciences and Technology, Bab Ezzouar, Algiers)
Abstract Revived interest in the Hassi Toumiet area has been sparked by oil discoveries in the Ordovician Formation near Hassi Messaoud field. However, the Hamra Quartzite reservoir in Hassi Toumiet has thinned and has poor quality compared to the Hassi Guettar field. Several studies have been conducted further research in Hassi Toumiet, located north of the Amguid-El-Biod axis, through 3D seismic and wells, resulting in new discoveries. Understanding the natural fractures in the area is crucial for its development, so a study was done using core samples, borehole imagery, and 3D seismic data. The study found three fault networks, with the dominant orientation being ENE-WSW and secondary orientation being NW-SE. Analysis of well cores showed low density of mostly cemented fractures, confirmed by borehole imagery. The fractures were found to be sparse, poorly connected, and strongly cemented, but this should be taken into consideration with respect to the well's verticality.
- North America > United States (1.00)
- Europe (0.94)
- Africa > Middle East > Algeria > Ouargla Province > Hassi Messaoud (0.57)
- Geology > Rock Type (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Structural Geology (0.96)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Faults and fracture characterization (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Geomechanical Characterization of the Broom Creek Reservoir for Geologic Carbon Storage in the Williston Basin, North Dakota, U.S.
Bakelli, Omar (University of Utah, Salt Lake City) | Xiao, Ting (University of Utah, Salt Lake City) | McPherson, Brian (University of Utah, Salt Lake City) | Doghmane, Mohamed Zinelabidine (University of Sciences and Technology, Bab Ezzouar, Algiers)
Abstract The research examines geological carbon dioxide (CO2) sequestration in North Dakota's Broom Creek Formation, situated within the Williston Basin, as a method to reduce greenhouse gas emissions mainly from fossil fuel-based electricity production. Part of the Permian Minnelusa Group's upper unit, the Broom Creek Formation consists of sandstone interspersed with layers of dolostone and anhydrite. The study provides a thorough analysis that encompasses lithology, petrophysical properties, mineralogy, and geomechanics, assessing both storage potential and seal integrity. Particular attention is given to geomechanical characteristics such as permeability, porosity, resilience, and in-situ stress conditions to evaluate the formation's suitability for geological carbon dioxide storage. Using well-log data and geomechanical modeling, the investigation reveals the reservoir's heterogeneous nature. The findings affirm the structural integrity of the formation, indicating that it can securely store CO2 while presenting minimal seismic risk. This study significantly bolsters ongoing efforts in geological carbon storage strategies and recommends future research to explore the reservoir's long-term response to CO2 injection using advanced modeling techniques and additional field data.
- North America > United States > North Dakota (1.00)
- North America > Canada (1.00)
- Asia > Middle East > Saudi Arabia > Eastern Province (0.28)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.47)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock > Dolomite (0.36)
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.99)
- North America > United States > North Dakota > Williston Basin > Bakken Shale Formation > Middle Bakken Shale Formation (0.99)
- North America > United States > Montana > Williston Basin > Bakken Shale Formation (0.99)
- (23 more...)
Advanced Seismic Interpretation, Multivariate Attribute Analysis, and Petrophysical Evaluation Techniques for Holistic Structural and Reservoir Characterization of the Joya Mair Oilfield, NW-Himalayas, Pakistan
Fayyaz, Najwa (Institute of Geology, University of the Punjab, Quaid-e-Azam Campus) | Ahsan, Naveed (Institute of Geology, University of the Punjab, Quaid-e-Azam Campus) | Ali, Abid (Institute of Geology, University of the Punjab, Quaid-e-Azam Campus)
Abstract Seismic and Petrophysical techniques were applied to illustrate subsurface structural analysis and reservoir characterization. Seismic assessment is essential for characterizing the underground anatomy and analyzing the petroleum prospects of the designated geographical region. Density, Resistivity, Caliper, Neutron porosity, photoelectric absorption (PEFZ), Gamma-ray, and spontaneous potential logs were used to carry out petrophysical analysis. A standard logging mechanism for fracture demarcation has been addressed in the present research. The investigated site is situated in Pakistanโs Upper Indus Basin which is split apart by the Potwar and Kohat regions. Minwal X-1 well located in Joya Mair oilfield has been chosen for this study. The area possesses a triangular domain resulting from compressional tectonic movements. The Minwal-Joyamair field has a distinctive history of hydrocarbon production with complicated stratigraphy and structure. Fracture porosity drives the emergence of Eocene limestone strata. The existence of fractured zones in the Chorgali formation and Sakesar limestone is demonstrated by using well-log responses along with the Secondary Porosity Index (SPI). Researchers can benefit through the method of figuring out hydrocarbon regions with the assistance of traditional well logging. The evidence of fracturing in Eocene limestone is confirmed through all the conventional log responses and cross-plots.
- Geology > Geological Subdiscipline > Stratigraphy (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock > Limestone (0.68)
- Geology > Structural Geology > Tectonics > Compressional Tectonics (0.34)
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Seismic Interpretation (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Asia > Pakistan > Upper Indus Basin > Potwar Basin (0.99)
- Asia > Pakistan > Punjab > Upper Indus Basin > Potwar Basin > Joya Mair Field (0.99)
- Africa > Middle East > Egypt > Western Desert > Kombombo Basin > West Kom Ombo Concession (0.99)
- (11 more...)
Characterization of Maximum Horizontal Stress from Wellbore Failures โ A Case Study from the Tight Paleozoic Hamra Quartzite Oil Reservoir of Oued Mya Basin, Algeria
Baouche, Rafik (University MโHamed Bougara Boumerdes) | Sen, Souvik (Baker Hughes) | Benmamar, Salim (Baker Hughes) | Perumalla, Satya (Baker Hughes)
Abstract The Cambro-Ordovician Hamra Quartzite Formation is one of the important reservoirs from Algerian Sahara. The objectives of this study were to characterize the wellbore breakouts and constrain the maximum horizontal stress (Shmax) based on the inferred compressive failures within the Paleozoic reservoir. A-Quality breakouts were deciphered within the reservoir interval from a cumulative of 138m of acoustic image log indicating a mean SHmax orientation of N118หEยฑ8ห. Interpreted breakout widths exhibit a range between 32.6ห and 90.81ห, which indicated a SHmax range of 24.4-34.7 MPa/km. The average breakout width of 62.58ห translates to a SHmax gradient range of 27.2 and 31.2 MPa/km. The relative magnitudes of the principal stresses indicate a strong strike-slip tectonic stress state with a SHmax/Shmin ratio of 1.41-1.81 within the Ordovician interval. Following the frictional faulting-based stress polygon approach, measurement of minimum horizontal stress (Shmin) from minifrac tests and observations of compressive failures from acoustic image log provided strong constraints on the SHmax magnitude in the studied Ordovician tight reservoir interval in the absence of core-measured rock strength.
- Africa > Middle East > Algeria > Eastern Algeria (0.53)
- Africa > Middle East > Algeria > Ouargla Province > Hassi Messaoud (0.29)
- Phanerozoic > Paleozoic > Ordovician (1.00)
- Phanerozoic > Paleozoic > Cambrian (0.67)
- Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous (0.47)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Metamorphic Rock > Quartzite (0.65)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.51)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Zubair Formation (0.99)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Mishrif Formation (0.99)
- Africa > Middle East > Tunisia > Kebili Governorate > Chotts Basin > Hamra Quartzite Formation (0.99)
- (11 more...)
Probabilistic Failure Occurrence Estimation Based on Survival Analysis Modeling: First Approach
Vianna, I. G. P. (Landmark-Halliburton, Rio de Janeiro, Rio de Janeiro, Brazil) | Valladares, I. F. (Petrobras, Rio de Janeiro, Rio de Janeiro, Brazil) | Pacheco, C. E. P. (Landmark-Halliburton, Rio de Janeiro, Rio de Janeiro, Brazil) | Netto, E. V. (Landmark-Halliburton, Rio de Janeiro, Rio de Janeiro, Brazil) | Brito, A. C. de A. (Landmark-Halliburton, Rio de Janeiro, Rio de Janeiro, Brazil) | Costa, F. R. (Landmark-Halliburton, Rio de Janeiro, Rio de Janeiro, Brazil) | de Carvalho, E. P. (Petrobras, Rio de Janeiro, Rio de Janeiro, Brazil) | Mendes, D. H. (Petrobras, Rio de Janeiro, Rio de Janeiro, Brazil) | da Silva, R. N. C. (Federal University of Cearรก/G4F, Fortaleza, Cearรก, Brazil)
Abstract Workover is a critical operation performed by drilling rigs, given the operational impact of resources involved in this activity. The yearly estimation of workover occurrences for drilling campaigns or mature fields is challenging for resource allocation, given the need to maintain the production of oil and gas fields. Based on these aspects, we established a group of business rules to identify failure historical with experts from a large Brazilian energy company. We presented an adapted survival analysis methodology to estimate failure occurrences. We scheduled several meetings with workover experts from a large Brazilian company to establish the business rules required to identify failure historical occurrences. To estimate future failure occurrences, it was necessary to adapt a traditional survival analysis into a well's failure survival analysis methodology that considers all premises from the business rules. The failure survival analysis methodology generates a survival curve; however, it still needs to be fulfilled, considering the rarity of failure occurrences. The next step was fitting a continuous distribution into the survival curve to complete the information. The continuous distribution represents the shape of the survival curve; thus, we performed linear regression to adjust the continuous fitted distribution in real data. We apply our methodologies to real well's data from two Brazilian fields. The failure identification methodology could identify most failures based on the business rules. We tested the failure estimation methodology and compared the total real failures with the total estimated failures. The failure methodology can be applied for failure estimation in new campaigns (using a similar field) or following years in mature fields (using the field's history itself). The results allow a future multivariate approach, introducing new features to multivariate survival analysis or a machine learning model. A multivariate failure model can generate more robust results, providing better estimation. The first novelty is the group of business rules established by workover experts to identify failure historical. The documentation and standardization of these rules compose the base for future works focused on probabilistic estimations of failures and workovers, building the premises required by any survival analysis or machine learning model. The second novelty is the methodology developed to adapt a traditional survival analysis into a failure survive analysis.
- Asia > Middle East > Israel > Mediterranean Sea (0.24)
- South America > Brazil > Rio de Janeiro (0.17)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 186 > Field A Field > Silurian Tanezzuft Formation (0.99)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 115 > Field B Field > Silurian Tanezzuft Formation (0.99)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 115 > Field A Field > Silurian Tanezzuft Formation (0.99)
Pore Size Structure Characterization and Poro-Fluid Facies Identification Using NMR Factor Analysis Improve Oil Producibility from Complex Carbonate Reservoir: Case Study from Gulf of Suez, Egypt
Hakim, Emad Abdel (General Petroleum Company, Cairo, Egypt) | Salim, Sadek (General Petroleum Company, Cairo, Egypt) | Hegazy, Amr (General Petroleum Company, Cairo, Egypt) | Sayed, Mayada (General Petroleum Company, Cairo, Egypt) | Gomes, Renata (SLB, Cairo, Egypt) | Saleh, Khaled (SLB, Cairo, Egypt) | Ghanim, Mohamed (SLB, Cairo, Egypt) | Ghadiry, Sherif (SLB, Cairo, Egypt) | Galal, Mahmoud (SLB, Cairo, Egypt)
Abstract The primary challenge posed by carbonates in petrophysics lies in the complexity of their pore systems, which exhibit a wide range of pore sizes within a small section of a single carbonate. In some cases, even the grains possess microporosity, distinct from the porosity between them, resulting in two different pore systems. Understanding the contribution of these pore systems to reservoir productivity is crucial for accurately assessing current and future water saturation levels. Conventional saturation equations like Archie's are not recommended for complex carbonate formations due to uncertainties related to wettability and cementation factors (m and n), which can vary significantly due to diagenesis and fractures. Additionally, the presence of vugs (whether connected or isolated) can substantially impact production and permeability over the reservoir's lifespan. To address these challenges, this paper introduces an integrated solution that employs nuclear magnetic resonance factor analysis (NMR-FA) in a carbonate reservoir in the Gulf of Suez, Egypt. This approach provides a precise understanding of reservoir quality, enables quantification of hydrocarbon in place, and optimizes oil production. The demonstrated methodology combines NMR-FA with NMR and spectroscopy data, focusing on the characterization of carbonates. By computing poro-fluid facies and integrating them with core data, it becomes possible to accurately determine the volumes of bound and free fluids, thus providing insights into the porosity and quantifying producible hydrocarbonsโan influential factor in production. The new bound/free fluid volumes are utilized to calculate continuous NMR permeability, which is then calibrated using core data. The classification of fluid facies based on pore-fluid porosities enables the evaluation of reservoir quality and identification of the sweet spotโthe zones characterized by high producible hydrocarbon porosity and permeability, indicating the best reservoir quality for production. Considering the complexity of carbonate reservoirs and the presence of secondary porosity is crucial when performing direct volumetric calculations for each constituent poro-facies within the T2 distribution. The results of this workflow successfully characterize the reservoir quality and producibility of the complex carbonate reservoir in the Gulf of Suez, Egypt, pinpointing its sweet spot. Furthermore, this workflow can be applied as a cost-effective solution in various scenarios and formation types.
- Phanerozoic > Mesozoic > Cretaceous (0.46)
- Phanerozoic > Cenozoic > Neogene > Miocene (0.36)
- Geology > Geological Subdiscipline > Stratigraphy (0.72)
- Geology > Sedimentary Geology (0.66)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.46)
- Africa > Middle East > Egypt > South Sinai Governorate > Lagia Field > Thebes Formation (0.99)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Matulla Formation (0.99)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Belayim Formation (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Egypt Field (0.93)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
Abstract Thermally Induced Fracturing (TIF) relates to the fracture generation due to the horizontal stress reduction because of cold fluid injection. An evaluation of this complex phenomenon, which involves geomechanics, fluid dynamics in porous media, and thermodynamics, is essential in any CCUS project. The scope of this paper is to show and compare the workflow followed with two commercial software, a multi-physics multipurpose one (COMSOL Multiphysicsยฎ) and a compositional reservoir simulator (CMG GEMยฎ), to perform Thermo-Hydro-Mechanical (THM) simulations to assess possible TIF occurrence. A preliminary validation is performed against a literature analytical model, followed by a real case study application. The real case evaluation starts with a 2D planar model built in COMSOL Multiphysicsยฎ to investigate TIF occurrence in reservoir and the possible temperature interference between wells. Subsequently a 2D near wellbore radial model is built with both software to evaluate TIF in reservoir and at reservoir-caprock interface. Results show that both models have good agreement with the literature analytical model confirming that the two software can evaluate TIF occurrence, demonstrating good match for what regards the real case study in terms of effective hoop stress reduction. COMSOL Multiphysicsยฎ is suitable for well scale/small scale models with simplified geometry and fluid compositions, and fast in terms of computational time; CMG GEMยฎ is instead a compositional reservoir simulator with the capabilities to model geomechanics and thermal phenomena on a wider scale.
- Research Report > New Finding (0.34)
- Research Report > Experimental Study (0.34)
- Europe > United Kingdom > Irish Sea > East Irish Sea Basin (0.99)
- Africa > Middle East > Algeria (0.91)
Abstract The main objective of this study is to provide a reservoir model that can guide geologists and geophysicists working on tight gas reservoirs in Algeria towards achieving selective drilling, ensuring both reservoir productivity and cost-effectiveness. The proposed approach aims to construct a more accurate non-conventional reservoir model for a fully controlled field, based on the extraction of tortuosity as a function of seismic and logging data. This enables the generation of a pore geometry model, initially near the wells and subsequently at the reservoir scale. Moreover, several deterministic seismic attributes have been derived from the seismic cube. The proposed equations linking the Petrophysical parameters have been mathematically demonstrated and tested. The results obtained are highly promising for unconventional shale gas reservoirs. The application of this novel technique in characterizing unconventional reservoirs facilitates the precise identification of potential net pay zones with great accuracy, optimizing exploration efforts and daily upstream production in mature reservoirs. It also aids in the strategic placement of new wells, determining their density and configurations. Furthermore, it offers a more precise and comprehensive reservoir characterization, improved reservoir geometry mapping, and a significant reduction in dry wells, thereby optimizing costs. Consequently, this developed model contributes to generating economic benefits by enhancing secondary recovery in mature fields, extending reservoir exploitation life by minimizing exploration uncertainties in gas reservoirs.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.30)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Interpretation (0.35)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (0.88)
Abstract DP3 and DP4 platforms of Bouri Oil Field are located in the Offshore Libyan Mediterranean Sea and are operated by Mellitah Oil & Gas B.V. Libyan Branch. In 2016, a project was established with the purpose to extend the life span of the production facilities which were approaching the end of their original design life. The study is intended to assess integrity of topside facilities and the impact of the corrosion to develop robust Risk Based Inspection program without impacting reliability and maintainability of existing facilities. A customized methodology has been developed and adopted to carry out the corrosion risk assessment of the topside pressure piping and equipment and the most relevant features of the adopted procedure are described in the paper. Given the great number of items involved in the assessment, the study developed an item categorization based on corrosion loops. Other hot topics addressed by the assessment were the definition of known corrosion issues, lesson learnt from field operations and the assessment of the effectiveness of the corrosion control measures in place. As the topside facilities are mostly made of corrosion resistant alloys (CRAs), simple but knowledgeable rules have been developed to assess the corrosion status of CRAs components after more than 30 years of operation. In addition, the available abundant inspection data have been collected and used to validate and amend both the applied rules and the corrosion predictive models applied for corrosion rate calculations. On the basis of the DNV RP G101 standard, the development of an effective and customized inspection plan was based on the output of the risk ranking process of the topside facilities pressure and piping components interrelated to the corrosion risk assessment as well as on a careful assessment of the past inspectionโs records of each item. Criteria for the inspections and most adequate non-destructive techniques (NDT) selected for each vessel and group of piping are discussed as well in the paper.
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Management (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
Unlocking Stranded Marginal Gas Fields in Malaysia with Low CAPEX Approach
How, L. L. (Vestigo Petroleum, Malaysia) | Farina, N. Norintan (Vestigo Petroleum, Malaysia) | Azmukiff, K. (Vestigo Petroleum, Malaysia) | Osman, Z. (Vestigo Petroleum, Malaysia) | Chang, Y. S. (Vestigo Petroleum, Malaysia) | Shahardin, S. (Vestigo Petroleum, Malaysia) | Azhar, S. Fairudul (PETRONAS, Malaysia)
Abstract Vestigo Petroleum Sdn. Bhd. (VPSB) has been awarded the right to develop and produce gas fields via a Petroleum Sharing Contract in offshore Peninsular Malaysia. The contract area consists of undeveloped Field T, Field I and Field B integrated late life asset. The undeveloped Field T and Field I marginal gas fields lie within 60km from existing Field B production hub. The production comes from gas dominant Field B, a producing field that is in decline and of which VPSB assumed operatorship in 2017. The immediate business driver is rapid monetization of the asset via tapping into nearby potential marginal gas fields. To enable this, low CAPEX and rapid development with fast investment return are required. Among the undeveloped gas fields, Field T was identified to anchor the development as it carries significant discovered gas volume. However, majority of the gas volume comes with H2S, and CO2 content which is beyond sales gas specification. Therefore, inter and intra fields blending were considered. Owing to the complexity of Field T that is dependent on other fields to provide blending medium, it is crucial to outline sequencing, timing of the other gas fields appraisal and development to optimize the development. To start with, Field T development from a wellhead platform tied back to existing VPSB processing facilities via a 60km long pipeline was the identified concept. A standardized wellhead platform, batch drilling and fit purpose well design in conjunction with application of Zap-Lok, mechanical connection technology in pipeline and sharing of operation cost with existing facilities led to cost effective development. This is the first application of Zap-Lok technology offshore Malaysia. The deployment of VPSB standard wellhead platform enabled rapid field development, with platform installed in less than eleven (11) months after project approval. All five (5) development wells were batch drilled to penetrate multiple stacked reservoirs and completed monobore to accommodate selective bottom-up perforation. These monobore wells either commingled minor reservoirs within similar pressure regime or selectively perforated at major reservoirs only for production to meet committed gas rate. This also ensures not to jeopardize major reservoirs gas reserves and reservoir management plan. Future developments are being planned to duplicate the success of Field T development to other identified marginal fields to drive cost reductions over time with higher efficiency.
- Asia > Malaysia (1.00)
- North America > United States > Texas (0.88)
- North America > United States > Gulf of Mexico > Central GOM > West Gulf Coast Tertiary Basin > Green Canyon > Block 807 > Anchor Field > Wilcox Trend Formation (0.99)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 115 > Field B Field > Silurian Tanezzuft Formation (0.99)