Pub Date : 2018-09-18DOI: 10.3997/2214-4609.201802760
J. Hernández, R. Prinsloo, R. Marriott
{"title":"Downhole Decomposition of Biocide Dazomet and Implications in the Delayed Onset of Hydrogen Sulfide in Hot Shale Gas Production","authors":"J. Hernández, R. Prinsloo, R. Marriott","doi":"10.3997/2214-4609.201802760","DOIUrl":"https://doi.org/10.3997/2214-4609.201802760","url":null,"abstract":"","PeriodicalId":438697,"journal":{"name":"First EAGE/IFPEN Conference on Sulfur Risk Management in Exploration and Production","volume":"96 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121564254","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 : 2018-09-18DOI: 10.3997/2214-4609.201802766
M. Mosesyan, H. Alexander, K. Edin, L. Surguchev, A. Rabey
There are a number of geological and hydrogeochemical modelling techniques that can be used in order to ascertain formation and generation of the hydrogen sulphide (H2S) in the formation fluid within a geological setting in several blocks of the Norwegian Barents Sea. Careful consideration of the H2S generation can then be used in the drilling context especially when presence of H2S is coupled Permian and Carboniferous carbonate plays prone to causing severe drilling fluid losses and increasing exposure time of the downhole equipment to the H2S. Using appropriate analogues and adequate well offset analysis tend to demonstrate that most or all of the risk factors can be well mitigated.
{"title":"The Barents Sea of the Norwegian Continental Shelf: Drilling through Carbonates if Hydrogen Sulphide is Present: Modelling. Risk Management. Well Planning","authors":"M. Mosesyan, H. Alexander, K. Edin, L. Surguchev, A. Rabey","doi":"10.3997/2214-4609.201802766","DOIUrl":"https://doi.org/10.3997/2214-4609.201802766","url":null,"abstract":"There are a number of geological and hydrogeochemical modelling techniques that can be used in order to ascertain formation and generation of the hydrogen sulphide (H2S) in the formation fluid within a geological setting in several blocks of the Norwegian Barents Sea. Careful consideration of the H2S generation can then be used in the drilling context especially when presence of H2S is coupled Permian and Carboniferous carbonate plays prone to causing severe drilling fluid losses and increasing exposure time of the downhole equipment to the H2S. Using appropriate analogues and adequate well offset analysis tend to demonstrate that most or all of the risk factors can be well mitigated.","PeriodicalId":438697,"journal":{"name":"First EAGE/IFPEN Conference on Sulfur Risk Management in Exploration and Production","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121596477","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 : 2018-09-18DOI: 10.3997/2214-4609.201802763
L. T. Bryndzia, C. Macaulay
{"title":"H2S in Unconventional Resource Plays: Occurrence, Origin and Mechanisms of Formation","authors":"L. T. Bryndzia, C. Macaulay","doi":"10.3997/2214-4609.201802763","DOIUrl":"https://doi.org/10.3997/2214-4609.201802763","url":null,"abstract":"","PeriodicalId":438697,"journal":{"name":"First EAGE/IFPEN Conference on Sulfur Risk Management in Exploration and Production","volume":"24 3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116697985","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 : 2018-09-18DOI: 10.3997/2214-4609.201802771
V. Lamoureux-Var, Z. O. Ameur, P. Michel, I. Lévêque, A. Ravin, D. Pillot, S. Ayache, Christophe Preux
H2S emissions from thermal recovery operations of bitumen and heavy oil are becoming an increasing concern. Many Steam Assisted Gravity Drainage (SAGD) programs are finding H2S level rising as wells are aging. Steam injection causes aquathermolysis reactions between bitumen, reservoir rock and high temperature steam, converting some organosulfur compounds into H2S. To precise its origin, a pre-SAGD oil sand sample from Foster Creek-Athabasca was submitted to aquathermolysis laboratory tests at 250°C, 45 bar and various durations up to one year. After each run, H2S yield was quantified, the extracted SARA fractions and the mineral fraction were weighed. Their total and labile sulfur contents were measured using Rock-Eval Sulfur pyrolysis, enabling the calculation of total sulfur and labile sulfur distributions over the fractions. The results show that aquathermolysis reactions led to sulfur depletion of the asphaltene fraction and to sulfur enrichment of the resin and aromatic fractions, simultaneously to H2S generation. This suggests that labile sulfur containing asphaltenic compounds generate H2S, resins and aromatics upon aquathermolysis conditions. These data can be used to entirely calibrate an integrated aquathermolysis kinetic model in reservoir simulator, for simulating H2S production in a SAGD project at Foster Creek existing producing asset.
{"title":"Characterizing Sulfur in Foster Creek Bitumen Using Rock-Eval Sulfur, for Assessing H2S Production Risk in SAGD Operations","authors":"V. Lamoureux-Var, Z. O. Ameur, P. Michel, I. Lévêque, A. Ravin, D. Pillot, S. Ayache, Christophe Preux","doi":"10.3997/2214-4609.201802771","DOIUrl":"https://doi.org/10.3997/2214-4609.201802771","url":null,"abstract":"H2S emissions from thermal recovery operations of bitumen and heavy oil are becoming an increasing concern. Many Steam Assisted Gravity Drainage (SAGD) programs are finding H2S level rising as wells are aging. Steam injection causes aquathermolysis reactions between bitumen, reservoir rock and high temperature steam, converting some organosulfur compounds into H2S. To precise its origin, a pre-SAGD oil sand sample from Foster Creek-Athabasca was submitted to aquathermolysis laboratory tests at 250°C, 45 bar and various durations up to one year. After each run, H2S yield was quantified, the extracted SARA fractions and the mineral fraction were weighed. Their total and labile sulfur contents were measured using Rock-Eval Sulfur pyrolysis, enabling the calculation of total sulfur and labile sulfur distributions over the fractions. The results show that aquathermolysis reactions led to sulfur depletion of the asphaltene fraction and to sulfur enrichment of the resin and aromatic fractions, simultaneously to H2S generation. This suggests that labile sulfur containing asphaltenic compounds generate H2S, resins and aromatics upon aquathermolysis conditions. These data can be used to entirely calibrate an integrated aquathermolysis kinetic model in reservoir simulator, for simulating H2S production in a SAGD project at Foster Creek existing producing asset.","PeriodicalId":438697,"journal":{"name":"First EAGE/IFPEN Conference on Sulfur Risk Management in Exploration and Production","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133977159","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 : 2018-09-18DOI: 10.3997/2214-4609.201802756
A. Wattripont, N. Bouton, J. Espitalie, R. Antonas, G. Constantinou
The presence or absence of H2S in oils and oil reservoirs plays an important role in many oil-related sectors. The Rock-Eval 7 Sulfur and Geoworks software make possible, among other things, to analyze the organic and mineral sulfur of the studied levels and thus to better answer problems around sulfur presence. First the machine itself puts forward a more efficient oxidation cycle that can reach the temperature of 1200°C allowing decomposition of sulfates. The device is also equipped with Geoworks software which is used to acquire and process the signals and then calculate parameters related to different methods proposed according to the type of sample studied. Finally, this software offers a kinetic part (Quik Kinetic) making possible calculation of kinetic distributions on hydrocarbons and sulfur produced during the pyrolysis for each analyzed sample with a single heating ramp. An additional module will allow a more complete kinetic analysis as well as a simplified basin modeling. These technical breakthroughs make it possible to highlight the significant interest of this new device and software in the following sectors: gas shale exploration, in reservoir studies, in the refining sector as well as in the study of soils.
{"title":"Rock-Eval Sulfur & GEOWORKS software","authors":"A. Wattripont, N. Bouton, J. Espitalie, R. Antonas, G. Constantinou","doi":"10.3997/2214-4609.201802756","DOIUrl":"https://doi.org/10.3997/2214-4609.201802756","url":null,"abstract":"The presence or absence of H2S in oils and oil reservoirs plays an important role in many oil-related sectors. The Rock-Eval 7 Sulfur and Geoworks software make possible, among other things, to analyze the organic and mineral sulfur of the studied levels and thus to better answer problems around sulfur presence. First the machine itself puts forward a more efficient oxidation cycle that can reach the temperature of 1200°C allowing decomposition of sulfates. The device is also equipped with Geoworks software which is used to acquire and process the signals and then calculate parameters related to different methods proposed according to the type of sample studied. Finally, this software offers a kinetic part (Quik Kinetic) making possible calculation of kinetic distributions on hydrocarbons and sulfur produced during the pyrolysis for each analyzed sample with a single heating ramp. An additional module will allow a more complete kinetic analysis as well as a simplified basin modeling. These technical breakthroughs make it possible to highlight the significant interest of this new device and software in the following sectors: gas shale exploration, in reservoir studies, in the refining sector as well as in the study of soils.","PeriodicalId":438697,"journal":{"name":"First EAGE/IFPEN Conference on Sulfur Risk Management in Exploration and Production","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121057787","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 : 2018-09-18DOI: 10.3997/2214-4609.201802755
A. Amrani, Ward Said–Ahmad, Nathalie Luu, T. Jaksier, Courtney Turich, A. Stankiewicz
{"title":"Sulfur Isotope Analysis of Organic Sulfur Compounds in Natural Gas Samples and Pyrolysis Experiments","authors":"A. Amrani, Ward Said–Ahmad, Nathalie Luu, T. Jaksier, Courtney Turich, A. Stankiewicz","doi":"10.3997/2214-4609.201802755","DOIUrl":"https://doi.org/10.3997/2214-4609.201802755","url":null,"abstract":"","PeriodicalId":438697,"journal":{"name":"First EAGE/IFPEN Conference on Sulfur Risk Management in Exploration and Production","volume":"112 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123066517","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 : 2018-09-18DOI: 10.3997/2214-4609.201802762
D. Standnes, I. Skjevrak, A. Kjølhamar, K. Håland, P. Munkerud
Many mature oil fields in the North Sea are experiencing challenges with respect to increasing H2S production representing big economical challenges. The current manuscript is describing an attempt to extract information about these issues using a “macroscale” reservoir simulation approach for a large mature offshore field in the North Sea. The strategy chosen is to assume that the underlying processes of microbial, chemical and physical origin are capturing generation and transport of H2S in the reservoir with sufficient accuracy by applying only two major variables in a reservoir souring simulation tool (SourSimRL (SSRL)). Such a strategy is driven both from a practical (constrained on time) as well as a scientific point of view (Occam’s razor - be able to make useful conclusions). The overall goal of the research reported is to identify a total simulation workflow capable of reducing the uncertainty in future predicted H2S vs. time for each individual well and the total field production.
{"title":"Simulation Approach for Investigation of H2S Generation Mechanisms","authors":"D. Standnes, I. Skjevrak, A. Kjølhamar, K. Håland, P. Munkerud","doi":"10.3997/2214-4609.201802762","DOIUrl":"https://doi.org/10.3997/2214-4609.201802762","url":null,"abstract":"Many mature oil fields in the North Sea are experiencing challenges with respect to increasing H2S production representing big economical challenges. The current manuscript is describing an attempt to extract information about these issues using a “macroscale” reservoir simulation approach for a large mature offshore field in the North Sea. The strategy chosen is to assume that the underlying processes of microbial, chemical and physical origin are capturing generation and transport of H2S in the reservoir with sufficient accuracy by applying only two major variables in a reservoir souring simulation tool (SourSimRL (SSRL)). Such a strategy is driven both from a practical (constrained on time) as well as a scientific point of view (Occam’s razor - be able to make useful conclusions). The overall goal of the research reported is to identify a total simulation workflow capable of reducing the uncertainty in future predicted H2S vs. time for each individual well and the total field production.","PeriodicalId":438697,"journal":{"name":"First EAGE/IFPEN Conference on Sulfur Risk Management in Exploration and Production","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128789645","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 : 2018-09-18DOI: 10.3997/2214-4609.201802775
M. Al-Hajeri, H. Akbar, A. Bishop, L. Gao, Y. Tang
Significant concentrations of hydrogen sulphide (H2S) are observed in the Marrat reservoir in the Raudhatain and Sabriya fields (northern Kuwait). In this study, we have attempted to determine the origin of H2S and what factors may control its relative concentration. Our data show that it is most likely a product of thermochemical sulphate reduction (TSR). However, this process has not gone to completion, as the levels of H2S in the samples studied are still below 5%. Additionally, the hydrocarbon constituents of the gas phase do not appear to have been severely affected by TSR. So far, this process has primarily impacted the oil phase: increasing oil gravity and decreasing oil sulphur content. Some of the Marrat fluids from the Sabriyah field have lower H2S concentrations, though with equivalent H2S sulphur isotopic compositions to the other Marrat fluids from Raudhatain. We hypothesize that these differences are related to original compositional grading and/or reservoir charge histories, which influence the degree of TSR alteration by virtue of differences in original fluid polar and associated labile sulphur contents. This study demonstrates that pre-TSR reservoir charge histories and fluid phase distributions should be taken in to account for effective evaluation of H2S occurrences.
{"title":"Controls on the Magnitude of TSR Derived Hydrogen Sulphide in the Marrat Reservoir, Northern Kuwait","authors":"M. Al-Hajeri, H. Akbar, A. Bishop, L. Gao, Y. Tang","doi":"10.3997/2214-4609.201802775","DOIUrl":"https://doi.org/10.3997/2214-4609.201802775","url":null,"abstract":"Significant concentrations of hydrogen sulphide (H2S) are observed in the Marrat reservoir in the Raudhatain and Sabriya fields (northern Kuwait). In this study, we have attempted to determine the origin of H2S and what factors may control its relative concentration. Our data show that it is most likely a product of thermochemical sulphate reduction (TSR). However, this process has not gone to completion, as the levels of H2S in the samples studied are still below 5%. Additionally, the hydrocarbon constituents of the gas phase do not appear to have been severely affected by TSR. So far, this process has primarily impacted the oil phase: increasing oil gravity and decreasing oil sulphur content. Some of the Marrat fluids from the Sabriyah field have lower H2S concentrations, though with equivalent H2S sulphur isotopic compositions to the other Marrat fluids from Raudhatain. We hypothesize that these differences are related to original compositional grading and/or reservoir charge histories, which influence the degree of TSR alteration by virtue of differences in original fluid polar and associated labile sulphur contents. This study demonstrates that pre-TSR reservoir charge histories and fluid phase distributions should be taken in to account for effective evaluation of H2S occurrences.","PeriodicalId":438697,"journal":{"name":"First EAGE/IFPEN Conference on Sulfur Risk Management in Exploration and Production","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131071442","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 : 2018-09-18DOI: 10.3997/2214-4609.201802754
J. Kok, W. Strien, R. Malekzadeh, A. Hofmann, B. Challenger
{"title":"Why H2S Can Be Overlooked in Early Stage of Field Development","authors":"J. Kok, W. Strien, R. Malekzadeh, A. Hofmann, B. Challenger","doi":"10.3997/2214-4609.201802754","DOIUrl":"https://doi.org/10.3997/2214-4609.201802754","url":null,"abstract":"","PeriodicalId":438697,"journal":{"name":"First EAGE/IFPEN Conference on Sulfur Risk Management in Exploration and Production","volume":"52 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132276485","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 : 2018-09-18DOI: 10.3997/2214-4609.201802765
I. Kowalewski, X. Guichet, R. Traby, Y. Hamon, E. Dickens, S. Wolf, T. Euzen, N. Maurand
Improved exploration strategies for the oil and gas fields involve high temperatures and pressures. This may induce Thermochemical Sulfate Reduction (TSR) risks. TSR is a complex succession of redox reactions that occur in deeply buried anhydrite-rich carbonate reservoirs under high temperatures. Such reactions lead to the formation of a high amount of H2S (toxic and corrosive gas) and a decrease in the quality of the hydrocarbons due to their oxidation. A new basin-scale approach was developed to compute a TSR risk index and, to assess the spatial distribution of H2S. The produced H2S can then be either dissolved in the formation water or released as a free gas phase. These two possibilities have been integrated into the TemisFlow™ software and were successfully applied to the Western Canadian Sedimentary Basin (WCSB). The Devonian carbonate reservoirs of WSCB are known to have experienced TSR reactions, some of them containing up to 30% of H2S. The obtained numerical results show high TSRI values for the Devonian petroleum system. These values increase with the burial associated to the Laramide orogeny. Our results are in agreement with the petrography analyses. Given our simulation criteria, the order of magnitude of average simulated H2S masses is the same as the one reported by Machel (2005).
{"title":"Assessment of H2S Generated by TSR Reaction in the Devonian Petroleum System of Alberta (Canada) Using Basin Modeling","authors":"I. Kowalewski, X. Guichet, R. Traby, Y. Hamon, E. Dickens, S. Wolf, T. Euzen, N. Maurand","doi":"10.3997/2214-4609.201802765","DOIUrl":"https://doi.org/10.3997/2214-4609.201802765","url":null,"abstract":"Improved exploration strategies for the oil and gas fields involve high temperatures and pressures. This may induce Thermochemical Sulfate Reduction (TSR) risks. TSR is a complex succession of redox reactions that occur in deeply buried anhydrite-rich carbonate reservoirs under high temperatures. Such reactions lead to the formation of a high amount of H2S (toxic and corrosive gas) and a decrease in the quality of the hydrocarbons due to their oxidation. A new basin-scale approach was developed to compute a TSR risk index and, to assess the spatial distribution of H2S. The produced H2S can then be either dissolved in the formation water or released as a free gas phase. These two possibilities have been integrated into the TemisFlow™ software and were successfully applied to the Western Canadian Sedimentary Basin (WCSB). The Devonian carbonate reservoirs of WSCB are known to have experienced TSR reactions, some of them containing up to 30% of H2S. The obtained numerical results show high TSRI values for the Devonian petroleum system. These values increase with the burial associated to the Laramide orogeny. Our results are in agreement with the petrography analyses. Given our simulation criteria, the order of magnitude of average simulated H2S masses is the same as the one reported by Machel (2005).","PeriodicalId":438697,"journal":{"name":"First EAGE/IFPEN Conference on Sulfur Risk Management in Exploration and Production","volume":"40 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127157498","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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