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Gulf of Suez (Oilfield Places)
Abstract This work aims to elucidate the potential applications of 2D basin and petroleum system modeling (BPSM) software in the assessment of hydrocarbon accumulations. To demonstrate how much information can be inferred regarding the existence of hydrocarbons and their mechanisms of accumulation in the subsurface, 2D BPSM was applied to two seismic sections that were utilized as case studies. The faults and horizons were digitally represented throughout the modeling phase to create the 2D BPSM for both seismic sections. The 2D BPSM construction used the age and lithology of each layer of the model as inputs. The hybrid technique was used to simulate hydrocarbon migration paths. The simulation findings showed that when the depth decreases, the degree of maturity declines, as some parts are characterized by transformation ratios of up to 100%. For the Upper Cretaceous source rock in model ABZ88-18, the levels of vitrinite reflectance (Ro%) are in the maturity phase and provide oil with Ro% values ranging from 0.6% to 1.3%. Whereas, in model 370, the Ro% values range from 0.55% to 1.3%. Based on the results of the modeling, new prospective hydrocarbon accumulations were found. Model ABZ88-18's estimated total mass is 292.9 million bbl oil and 11.49 million m gas, compared to model 370's estimated total mass of 178.52 million bbl oil.
- Africa > Middle East > Egypt > Gulf of Suez (1.00)
- Africa > Middle East > Egypt > Suez Governorate > Suez (0.41)
- Phanerozoic > Mesozoic > Cretaceous (0.74)
- Phanerozoic > Cenozoic > Paleogene > Eocene (0.32)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (1.00)
- Geology > Rock Type > Sedimentary Rock > Organic-Rich Rock > Coal (0.54)
- Geology > Structural Geology > Fault > Dip-Slip Fault > Normal Fault (0.47)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (0.68)
- Geophysics > Seismic Surveying > Seismic Processing (0.55)
- Europe > Norway > Barents Sea > Hammerfest Basin (0.99)
- Africa > Middle East > Egypt > South Central Desert > Kombombo Basin > West Kom Ombo Concession > Duwi Formation (0.99)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Ras Budran Field (0.99)
- (8 more...)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Samir Abdelmoaty received his B.Sc. degree in physics and geology from Cairo University in 1971, followed by a Diploma and M.Sc. in geophysics. Recently, Samir attended The Management Program at Rice University and the International Management Program at Texas A&M. In 1972, Samir began his career with the Academy of Scientific Research before joining GUPCO in 1976. He was seconded to BG Egypt as the chief geophysicist in 1989. Returning to GUPCO, he progressed through several positions ending as the geophysics general manager.
- Asia > Middle East > Saudi Arabia (1.00)
- Asia > Middle East > Yemen (0.95)
- Africa > Middle East > Djibouti (0.95)
- Africa > Middle East > Egypt > Cairo Governorate > Cairo (0.26)
- Information Technology > Knowledge Management (0.76)
- Information Technology > Communications > Collaboration (0.76)
- Information Technology > Data Science (0.47)
A new nuclear magnetic resonance-based permeability model based on two pore structure characterization methods for complex pore structure rocks: Permeability assessment in Nanpu Sag, China
Xie, Weibiao (China University of Petroleum (Beijing) at Karamay, China University of Petroleum (Beijing)) | Yin, Qiuli (China University of Petroleum (Beijing) at Karamay) | Wu, Lifeng (China Petroleum logging Co., Ltd) | Yang, Fan (China Petroleum logging Co., Ltd) | Zhao, Jianbin (China Petroleum logging Co., Ltd) | Wang, Guiwen (China University of Petroleum (Beijing))
ABSTRACT The nuclear magnetic resonance (NMR) estimate of permeability is a fundamental method that has numerous applications in reservoir engineering and petrophysics. To improve the accuracy of the NMR-based permeability model, many variables are introduced into NMR-based permeability prediction models due to geometric complexity and pore structure heterogeneity. In this paper, two pore structure characterization methods are investigated based on the Kozeny-Carman model and equivalent component model. Furthermore, an NMR-based permeability model accounting for the effect of pore structure is developed based on the analysis of the relationship between two pore structure parameters, and it is applied to practically predict permeability. Results indicate that the new model-calculated permeability has good agreement with experimental data; moreover, the adaptability of the new NMR-based permeability prediction model is highly improved through reducing undetermined variables, and key parameters can be measured directly using NMR. The new model provides a valuable scientific resource and assists in the evaluation of hydrocarbon-bearing reservoirs with complex pore structure, such as tight sandstone, shale, and carbonate rock.
- Asia > China (1.00)
- Africa > Middle East > Egypt (0.46)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.70)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.35)
- Asia > China > Xinjiang Uyghur Autonomous Region > Junggar Basin > Lucaogou Formation (0.99)
- Asia > China > Shandong > Gaoqing Field (0.99)
- Asia > China > Bohai Basin (0.99)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Kareem Formation > Shagar Member (0.99)
Samir Abdelmoaty received his B.Sc. degree in physics and geology from Cairo University in 1971, followed by a Diploma and M.Sc. in geophysics. Recently, Samir attended The Management Program at Rice University and the International Management Program at Texas A&M. In 1972, Samir began his career with the Academy of Scientific Research before joining GUPCO in 1976. He was seconded to BG Egypt as the chief geophysicist in 1989. Returning to GUPCO, he progressed through several positions ending as the geophysics general manager.
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
A new nuclear magnetic resonance-based permeability model based on two pore structure characterization methods for complex pore structure rocks: Permeability assessment in Nanpu Sag, China
Xie, Weibiao (China University of Petroleum (Beijing) at Karamay, China University of Petroleum (Beijing)) | Yin, Qiuli (China University of Petroleum (Beijing) at Karamay) | Wu, Lifeng (China Petroleum logging Co., Ltd) | Yang, Fan (China Petroleum logging Co., Ltd) | Zhao, Jianbin (China Petroleum logging Co., Ltd) | Wang, Guiwen (China University of Petroleum (Beijing))
ABSTRACT The nuclear magnetic resonance (NMR) estimate of permeability is a fundamental method that has numerous applications in reservoir engineering and petrophysics. To improve the accuracy of the NMR-based permeability model, many variables are introduced into NMR-based permeability prediction models due to geometric complexity and pore structure heterogeneity. In this paper, two pore structure characterization methods are investigated based on the Kozeny-Carman model and equivalent component model. Furthermore, an NMR-based permeability model accounting for the effect of pore structure is developed based on the analysis of the relationship between two pore structure parameters, and it is applied to practically predict permeability. Results indicate that the new model-calculated permeability has good agreement with experimental data; moreover, the adaptability of the new NMR-based permeability prediction model is highly improved through reducing undetermined variables, and key parameters can be measured directly using NMR. The new model provides a valuable scientific resource and assists in the evaluation of hydrocarbon-bearing reservoirs with complex pore structure, such as tight sandstone, shale, and carbonate rock.
- Asia > China (1.00)
- Africa > Middle East > Egypt (0.46)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.70)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.35)
- Asia > China > Xinjiang Uyghur Autonomous Region > Junggar Basin > Lucaogou Formation (0.99)
- Asia > China > Shandong > Gaoqing Field (0.99)
- Asia > China > Bohai Basin (0.99)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Kareem Formation > Shagar Member (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 Objectives/Scope Kuwait energy company has started to develop oil reserves since 2008 in AREA-A Concession, started with production of 2,000 BOPD increased to 7,000 BOPD in 2021, most of the wells are being pumped with SRP, AREA-A wells conductivity are sufficiently high to produce wells with reservoir pressure of 150 PSI up to 1800 BBL/Day; which result in harsh condition of severe depletion, severe sand production, and increased gas production. This harsh condition of severe depletion required to produce the area wells while placing the pumps below the perforations to maximize the draw down; which resulted in increased pumps sticking with sand and increased pumps gas locking tendency; thus, with the need to maximize the wells productivity to achieve a positive and economic concession profits. A solutions has been studied such as placing of gravel pack to help preventing coarse and medium grains sand particles from entering the pumps but found that gravel pack will induce additional production drop of 200 to 300 PSI; while area reservoir pressure is 150 PSI, thus will reduce wells flow rates, another solution was to place a standalone sand screen; but selection was very critical due to sand sorting wasn't uniform to choose any of the market screens, which result in either of screen plugging or sand passing from screens. Methods, Procedures, Process To achieve the challenging high wells fluid flow rates, in a harsh condition of depletion, sand, and gas production; an innovative solutions has been implemented; which are; Producing the wells with non-conventional 3.25โโ Oversized SRP; the pump is able to produce the wells with flow rates up to 1800 BFPD at depths of 700 Mt. instead of Costly ESP which is expected to not produce such gassy depleted wells, also OTP pump has better durability than the conventional SRP to produce in such harsh conditions due to increased balls sizes that can overcome sand and gas production troubles, also OTP could be run in 3.5โโ TBG sizes instead of 4.5โโ TBG size that designed to be run inside, thus due to usage of innovative idea "On-Off tool associated with the plunger thus helps running the whole pump altogether and connecting with rods" the second solution applied is to produce the wells with high clearance plunger of -0.011 instead of current -0.003 SRP; which resulted in increasing the mean time between failures (MTBF) of pump sticking to 12 months instead of 3 months SRP lifetime, the third applied solution is placing more than pump size in one completion string (i.e. placing pump seating nipple of 2.25โโ rod pump with 2.75โโ TBG pump; which give the opportunity switching the failed pump to the other pump with using of simple pulling unit), the last applied solution is placing poor boy gas anchor below perforations which working as gas separations and sand trap in the same time Results, Observations, Conclusions However, the very harsh production condition; KEE was able to produce the wells with the maximum possible production rates with controlled failure rates and able to achieve an exceptional production targets for the fourth year in a row. Novel/Additive Information Whenever the operations are challenged with cost optimizations; which require lower expenditure and higher potential to be produced, searching for such a kind innovative solution is highly effective to achieve the corporation's goals.
- North America > United States > Texas > Terry County (0.41)
- North America > United States > Texas > Gaines County (0.41)
- Europe > United Kingdom > North Sea > Southern North Sea (0.41)
- Africa > Middle East > Egypt > Gulf of Suez (0.34)
One Fracture at a Time - Saving Expenses on Lost Circulation Through 3D Far Field Sonic in the Gulf of Suez
Hegazy, Amr (General Petroleum Company) | Hakim, Emad Abdel (General Petroleum Company) | Saleh, Khaled (SLB) | Patro, Radhika (SLB) | Hussain, Syed Aaquib (SLB) | Sinha, Mrinal (SLB) | Abdulla, Mariam (SLB) | Ghanim, Mohamed (SLB) | Gomes, Renata (SLB) | Galal, Mahmoud (SLB) | Al-Mansour, Mansour (SLB)
Abstract Lost circulation is one of the significant challenges encountered while drilling in a depleted reservoir. Downhole mud loss problems get accentuated while drilling through highly permeable or fractured reservoirs or drilling with inadequate mud weight. Worldwide, the expenses due to mud loss can be significant in the drilling of a well. The presence of fractures can act as conduits for mud losses into the formation in a depleted reservoir. Hence, a comprehensive petrophysical and geomechanical evaluation was needed to identify and characterize these fracture networks. Though high-resolution image logs are the industry standard for identifying the presence of fractures, their shallow depth of investigation limits their information near the wellbore, and the extent of fractures in the far field couldn't be determined. Here, seismic, acoustics, and petrophysical data can shed information on the fractures at different levels. Understanding the stability of the detected fractures with the current-day stresses is vital in ascertaining its potential to support the flow of reservoir fluids. Thus, a collaborative workflow linking the high-resolution logs and deeper depth of investigation logs was devised for exhaustive characterization of the fractured reservoir. Drilling through the depleted formations of multiple reservoirs was challenging because of the lost circulation problems, with mud losses going as high as 140 bbls/hr. Detailed analyses of different acquired data were conducted to understand and evaluate this naturally fractured reservoir. Image interpretation showed the presence of fractures, vugs, and dissolution features in different densities across various encountered formations. Acquired acoustic monopole, dipole, and Stoneley data were studied in diverse domains to understand other properties: Stoneley reflection and transmission analysis provided information on the openness of the fractures in the near wellbore. Since an extensive fracture network creates intrinsic anisotropy in a formation, anisotropy analysis and sonic waveform dispersion analysis were carried out to identify and characterize the acoustically anisotropic zones. A forward modeling approach incorporating image interpretation and acoustic data were used to model and interpret acoustic anisotropy associated with geological features such as beddings and fractures. It provided a consistent solution, differentiating open fractures from closed ones. Acoustic reflection survey analysis delivered insight into laterally extensive fractures penetrating as deep as 20 m. Detailed geomechanical analysis hinted at current-day pore pressure and stresses acting on different formations and was used further for fracture stability analysis. This paper aims to describe how an integrated evaluation using geological, petrophysical, acoustic, and geomechanical analysis help delivers invaluable information on the laterally extensive, critically stressed fractures acting as primary culprits for severe mud losses, thus helping in optimizing the drilling of future wells to avoid mud losses in depleted fields.
- Asia > Middle East > Yemen (1.00)
- Asia > Middle East > Saudi Arabia (1.00)
- Africa > Middle East > Djibouti (1.00)
- (3 more...)
- Phanerozoic > Cenozoic > Neogene > Miocene (0.51)
- Phanerozoic > Mesozoic > Cretaceous (0.46)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.69)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Africa > Middle East > Egypt > South Sinai Governorate > Lagia Field > Thebes Formation (0.99)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Ras Gharib Field (0.99)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Matulla Formation (0.99)
- (4 more...)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
The NMR estimate of permeability is one of the fundamental methods and have numerous applications in reservoir engineering and petrophysics. To improve the accuracy of NMR-based permeability model, many variables are introduced into NMR-based permeability prediction models due to geometrical complexity and pore structure heterogeneity. In the paper, two pore structure characterization methods are investigated based on Kozeny-Carman model and equivalent component model. Furthermore, a NMR-based permeability model accounting for the effect of pore structure is proposed based on the analysis of the relationship between two pore structure parameters, and it is applied to practically predict permeability. Results show that the new model calculated permeability has good agreement with experimental data, moreover, the adaptability of the new NMR-based permeability prediction model is highly improved through reducing undetermined variables, and key parameters can be measured directly using NMR. The new model provides a valuable scientific resource and assists in the evaluation of hydrocarbon-bearing reservoirs with complex pore structure, such as tight sandstone, shale and carbonate rock.
- Asia > China (1.00)
- Africa > Middle East > Egypt (0.28)
- Overview > Innovation (0.55)
- Research Report > New Finding (0.34)
- Research Report > Experimental Study (0.34)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.68)
- Asia > China > Xinjiang Uyghur Autonomous Region > Junggar Basin > Lucaogou Formation (0.99)
- Asia > China > Bohai Basin (0.99)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Kareem Formation > Shagar Member (0.99)
Identification of an oil-bearing layer by formation water resistivity: A case study of the Jurassic reservoir, Southwest Ordos Basin
Guo, Jingzhe (Northwest University, Northwest University) | Li, Ya (PetroChina Changqing Oil Field Company Ltd.) | Wang, Yuxia (Northwest University, Northwest University) | Lyu, Qiqi (Yangtze University) | Zhou, Lifa (Northwest University, Northwest University)
ABSTRACT In the southwestern Ordos Basin, the formation water salinity and resistivity of Jurassic sandstone reservoirs are characterized by rapid changes and great variations, which lead to difficulties in the identification of reservoir fluid types and the development and exploration of the hydrocarbons in this area. To explore appropriate methods for reservoir fluid identification provided with complex formation water salinity and resistivity, we have conducted three research steps. First, using formation water testing and well-logging data, the formation water salinity, spontaneous potential, and reservoir resistivity are used to calculate the formation water resistivity. Second, the calculation results were used to separate the reservoir fluid types. Third, the calculated formation water resistivities are classified and the relationship between the formation water resistivity and the oil-producing interval is established. The results indicate that, for oil-producing intervals, the formation water resistivity calculated using the reservoir resistivity is the highest, whereas that using the formation water salinity is the lowest. Based on this understanding, two identification methods of reservoir fluid types are developed, including the qualitative curve overlap method and the quantitative ternary graph method. The curve overlap method can be applied to visually distinguish reservoir fluid types through the differentiation of formation water resistivity. Compared with some earlier quantitative methods, the ternary graph method can achieve an efficiency of 87.7% in identifying the type of reservoir fluid. Finally, the reliability of both methods is verified by case studies.
- Asia > China > Shaanxi Province (0.85)
- Asia > China > Shanxi Province (0.71)
- Asia > China > Gansu Province (0.71)
- Geology > Geological Subdiscipline (0.93)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.72)
- North America > United States > Wyoming > Sand Wash Basin (0.99)
- North America > United States > Utah > Sand Wash Basin (0.99)
- North America > United States > Colorado > Sand Wash Basin (0.99)
- (11 more...)