Pub Date : 2018-06-11DOI: 10.3997/2214-4609.201800913
T. Birchall, K. Senger, S. Olaussen
Summary Underpressure, defined as any pore pressure below the hydrostatic, is relatively underrepresented in literature. In this contribution we document underpressure both onshore Svalbard and in the northern part of the Norwegian Barents Sea. Furthermore we discuss the potential geological processes contributing to the underpressure generation and the implications to petroleum exploration. Underpressure of up to 50 bar is observed onshore Svalbard and in five of the northernmost wells of the Barents Sea, with the former equating to some 50% of hydrostatic pressure at approximately 850 metres depth. Basins, including the study area, where naturally occurring underpressure has been documented share several common geological features; most notably all have undergone recent uplift. Whilst previously documented cases of underpressure have been observed in elevated onshore basins, underpressure on the Barents Shelf occurs below sea level. The combination of detailed onshore well and outcrop observations from Svalbard’s Longyearbyen CO2 lab and outcrops, and numerous offshore exploration wells in the northern Barents sea provide insight into the different potential underpressure forming mechanisms.
{"title":"Subnormal Pressure Regimes of the Northern Barents Shelf: Causes and Implications for Hydrocarbon Exploration","authors":"T. Birchall, K. Senger, S. Olaussen","doi":"10.3997/2214-4609.201800913","DOIUrl":"https://doi.org/10.3997/2214-4609.201800913","url":null,"abstract":"Summary Underpressure, defined as any pore pressure below the hydrostatic, is relatively underrepresented in literature. In this contribution we document underpressure both onshore Svalbard and in the northern part of the Norwegian Barents Sea. Furthermore we discuss the potential geological processes contributing to the underpressure generation and the implications to petroleum exploration. Underpressure of up to 50 bar is observed onshore Svalbard and in five of the northernmost wells of the Barents Sea, with the former equating to some 50% of hydrostatic pressure at approximately 850 metres depth. Basins, including the study area, where naturally occurring underpressure has been documented share several common geological features; most notably all have undergone recent uplift. Whilst previously documented cases of underpressure have been observed in elevated onshore basins, underpressure on the Barents Shelf occurs below sea level. The combination of detailed onshore well and outcrop observations from Svalbard’s Longyearbyen CO2 lab and outcrops, and numerous offshore exploration wells in the northern Barents sea provide insight into the different potential underpressure forming mechanisms.","PeriodicalId":325587,"journal":{"name":"80th EAGE Conference and Exhibition 2018","volume":"13 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116373103","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-06-11DOI: 10.3997/2214-4609.201801686
D. Anomneze, A. U. Okoro
{"title":"Dynamics and Evolution of Growth Faults - Implications on Stratigraphic Geometries and Facies Distribution","authors":"D. Anomneze, A. U. Okoro","doi":"10.3997/2214-4609.201801686","DOIUrl":"https://doi.org/10.3997/2214-4609.201801686","url":null,"abstract":"","PeriodicalId":325587,"journal":{"name":"80th EAGE Conference and Exhibition 2018","volume":"111 2","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114016097","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-06-11DOI: 10.3997/2214-4609.201801071
J. Brackenhoff, J. Thorbecke, K. Wapenaar
Retrieval of the homogeneous Green's function is often done using a single-sided boundary, even though the theory states that an enclosing boundary is required. In recent years the theory has been modified to create a single-sided representation. This is done by using the Marchenko method, to redatum the wavefield from the boundary to a virtual receiver location inside the medium. The results on synthetic data have been encouraging, but on field data this method is largely unproven, due to the fact that the Marchenko method assumes that the medium is lossless, which in practice it is not. We have shown how to apply the classical representation and that it does not deliver the desired result on the field data. We have also demonstrated how to apply the new representation on the field data and that the result has improved over the classical representation. We visualize the result as snapshots over a region of interest to show the propagation of the wavefield through the medium.
{"title":"Homogeneous Green's Function Retrieval on Field Data Using the Marchenko Method","authors":"J. Brackenhoff, J. Thorbecke, K. Wapenaar","doi":"10.3997/2214-4609.201801071","DOIUrl":"https://doi.org/10.3997/2214-4609.201801071","url":null,"abstract":"Retrieval of the homogeneous Green's function is often done using a single-sided boundary, even though the theory states that an enclosing boundary is required. In recent years the theory has been modified to create a single-sided representation. This is done by using the Marchenko method, to redatum the wavefield from the boundary to a virtual receiver location inside the medium. The results on synthetic data have been encouraging, but on field data this method is largely unproven, due to the fact that the Marchenko method assumes that the medium is lossless, which in practice it is not. We have shown how to apply the classical representation and that it does not deliver the desired result on the field data. We have also demonstrated how to apply the new representation on the field data and that the result has improved over the classical representation. We visualize the result as snapshots over a region of interest to show the propagation of the wavefield through the medium.","PeriodicalId":325587,"journal":{"name":"80th EAGE Conference and Exhibition 2018","volume":"63 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114766725","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-06-11DOI: 10.3997/2214-4609.201801283
C. Feng, C. Niu, Q. Wang, X. Du, M. Zhao, Z. Han, G. Xiao
{"title":"Characteristics and Genesis of the Inherited-Fracture Conglomerate Reservoir: Taking the Lvda 29-A Structure as an Examp","authors":"C. Feng, C. Niu, Q. Wang, X. Du, M. Zhao, Z. Han, G. Xiao","doi":"10.3997/2214-4609.201801283","DOIUrl":"https://doi.org/10.3997/2214-4609.201801283","url":null,"abstract":"","PeriodicalId":325587,"journal":{"name":"80th EAGE Conference and Exhibition 2018","volume":"58 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124505110","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-06-11DOI: 10.3997/2214-4609.201800837
S. Ursegov, A. Zakharian, E. Taraskin
A new adaptive approach is proposed to create full field geological and hydrodynamic models of the unconventional carbonate reservoirs with heavy oil. In the adaptive geological model, the number of layers of its grid does not exceed the number of layers identified by the results of detailed correlation, while all model parameters are constructed depending on seismic data. The grid of the adaptive hydrodynamic model completely coincides with the geological grid without upscaling. In the adaptive hydrodynamic model, the system of differential equations describing the filtration process is solved according to the rules of the theory of percolation and cellular automata. The adaptive hydrodynamic models are always history matched. Calculation of the adaptive hydrodynamic model allows generating the distribution of remaining oil reserves and reservoir pressure. Using the adaptive hydrodynamic model, it is also possible to evaluate the development strategies of the reservoirs, using the iterative fuzzy-logical method to determine the oil decline rates first, and then to solve the system of equations for the interference of the wells. The proposed adaptive models are not simplified, they are complex and requires practically the same run time as their deterministic analogues. However, the adaptive models are easier and cheaper for users.
{"title":"Full Field Unconventional Carbonate Reservoir Modelling Using Adaptive Simulation Technique","authors":"S. Ursegov, A. Zakharian, E. Taraskin","doi":"10.3997/2214-4609.201800837","DOIUrl":"https://doi.org/10.3997/2214-4609.201800837","url":null,"abstract":"A new adaptive approach is proposed to create full field geological and hydrodynamic models of the unconventional carbonate reservoirs with heavy oil. In the adaptive geological model, the number of layers of its grid does not exceed the number of layers identified by the results of detailed correlation, while all model parameters are constructed depending on seismic data. The grid of the adaptive hydrodynamic model completely coincides with the geological grid without upscaling. In the adaptive hydrodynamic model, the system of differential equations describing the filtration process is solved according to the rules of the theory of percolation and cellular automata. The adaptive hydrodynamic models are always history matched. Calculation of the adaptive hydrodynamic model allows generating the distribution of remaining oil reserves and reservoir pressure. Using the adaptive hydrodynamic model, it is also possible to evaluate the development strategies of the reservoirs, using the iterative fuzzy-logical method to determine the oil decline rates first, and then to solve the system of equations for the interference of the wells. The proposed adaptive models are not simplified, they are complex and requires practically the same run time as their deterministic analogues. However, the adaptive models are easier and cheaper for users.","PeriodicalId":325587,"journal":{"name":"80th EAGE Conference and Exhibition 2018","volume":"113 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124159702","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-06-11DOI: 10.3997/2214-4609.201801267
A. Khitrenko, K. Binkov, K. Garina
Summary In this paper we present a case study from onshore in the north Western Siberia deepwater sediments, where quantitative interpretation of seismic inversion attributes was based on a rock physics and statistical framework. A lot of companies try to implement Poisson Impedance for encasing contrast between sandstone reservoir and shale for determining situation where difference is small. Poisson Impedance is a difference between the P-impedance and scaled S-impedance (PI=Ip-c*Is). Reservoir and tight sandstones in Achimov formation has approximately the same values of Poisson Impedance compared to the appropriate separation between shale and sandstone. Therefore, deterministic simultaneous inversion along with a Bayesian classification are followed in order to identify distribution of lithofacies using Poisson Impedance and P-impedance.
{"title":"Poisson Impedance for Achimov Formation Sandstone Reservoirs Characterization","authors":"A. Khitrenko, K. Binkov, K. Garina","doi":"10.3997/2214-4609.201801267","DOIUrl":"https://doi.org/10.3997/2214-4609.201801267","url":null,"abstract":"Summary In this paper we present a case study from onshore in the north Western Siberia deepwater sediments, where quantitative interpretation of seismic inversion attributes was based on a rock physics and statistical framework. A lot of companies try to implement Poisson Impedance for encasing contrast between sandstone reservoir and shale for determining situation where difference is small. Poisson Impedance is a difference between the P-impedance and scaled S-impedance (PI=Ip-c*Is). Reservoir and tight sandstones in Achimov formation has approximately the same values of Poisson Impedance compared to the appropriate separation between shale and sandstone. Therefore, deterministic simultaneous inversion along with a Bayesian classification are followed in order to identify distribution of lithofacies using Poisson Impedance and P-impedance.","PeriodicalId":325587,"journal":{"name":"80th EAGE Conference and Exhibition 2018","volume":"26 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127599649","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-06-11DOI: 10.3997/2214-4609.201800860
Y. Lee, H. Park, S. Kim, Y. Song, J. Kim, W. Sung
This study experimentally investigates the effect of pH and SO42- on oil production in carbonate reservoir applying low-salinity water based polymerflooding (LSWPF), which has additional synergetic effect by altering the wettability and improving the mobility ratio. Particularly, SO42- ions contained in injection water not only decrease electrical potential of rock surface, but also retain stability of polymer chain. Therefore, it is essential to analyse the potential of sulfate on oil production in LSWPF. From the results of viscosity analysis and zeta potential measurement of polymer solution, it was confirmed that Ca2 yielded precipitation with polymer molecule, leading to viscosity reduction, while SO42- stretched the polymer chains. In the results of coreflooding experiments for LSWPF, injecting polymer solution containing higher concentration of sulfate with neutral pH revealed less degradation and affected wettability alteration, resulting in enhancing oil recovery. In overall, we demonstrated the interaction between low-salinity waterflooding and polymerflooding, especially the impact of sulfate ions on polymer degradation and consequently enhanced oil recovery. In field application of low-salinity polymerflooding method to carbonate reservoir, pH and PDI of injection water should be designed in advance to maximize the oil recovery.
{"title":"Assessment of Oil Production for Low-Salinity Water Based Polymer Injection Method in Carbonate Oil Reservoir","authors":"Y. Lee, H. Park, S. Kim, Y. Song, J. Kim, W. Sung","doi":"10.3997/2214-4609.201800860","DOIUrl":"https://doi.org/10.3997/2214-4609.201800860","url":null,"abstract":"This study experimentally investigates the effect of pH and SO42- on oil production in carbonate reservoir applying low-salinity water based polymerflooding (LSWPF), which has additional synergetic effect by altering the wettability and improving the mobility ratio. Particularly, SO42- ions contained in injection water not only decrease electrical potential of rock surface, but also retain stability of polymer chain. Therefore, it is essential to analyse the potential of sulfate on oil production in LSWPF. From the results of viscosity analysis and zeta potential measurement of polymer solution, it was confirmed that Ca2 yielded precipitation with polymer molecule, leading to viscosity reduction, while SO42- stretched the polymer chains. In the results of coreflooding experiments for LSWPF, injecting polymer solution containing higher concentration of sulfate with neutral pH revealed less degradation and affected wettability alteration, resulting in enhancing oil recovery. In overall, we demonstrated the interaction between low-salinity waterflooding and polymerflooding, especially the impact of sulfate ions on polymer degradation and consequently enhanced oil recovery. In field application of low-salinity polymerflooding method to carbonate reservoir, pH and PDI of injection water should be designed in advance to maximize the oil recovery.","PeriodicalId":325587,"journal":{"name":"80th EAGE Conference and Exhibition 2018","volume":"46 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128028686","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-06-11DOI: 10.3997/2214-4609.201801432
B. Haworth, Stephen J. Rippington
{"title":"Structure of the Wyville-Thomson Ridge: Reducing Uncertainty by Integrated Potential Fields and Seismic Interpretation","authors":"B. Haworth, Stephen J. Rippington","doi":"10.3997/2214-4609.201801432","DOIUrl":"https://doi.org/10.3997/2214-4609.201801432","url":null,"abstract":"","PeriodicalId":325587,"journal":{"name":"80th EAGE Conference and Exhibition 2018","volume":"74 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125461734","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-06-11DOI: 10.3997/2214-4609.201800805
O. Bradulina, V. Shelkov, K. Bogachev, D. Eydinov, H. Tran, A. Diaz
{"title":"Solving the Reservoir Simulation Bottle Neck with a Hybrid Approach Based on Modern CPU and GPU Computational Platforms","authors":"O. Bradulina, V. Shelkov, K. Bogachev, D. Eydinov, H. Tran, A. Diaz","doi":"10.3997/2214-4609.201800805","DOIUrl":"https://doi.org/10.3997/2214-4609.201800805","url":null,"abstract":"","PeriodicalId":325587,"journal":{"name":"80th EAGE Conference and Exhibition 2018","volume":"40 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125617904","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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