Oilfield reservoir souring during waterflooding: A case study with low sulphate concentration in formation and injection waters
A case study is presented which addressed the origin of Hydrogen Sulphide (H2S) in produced gas associated with the oil in Las Heras - Cerro Grande oilfield in Gulf of San Jorge Basin, Argentina. The reservoir was initially sweet. However, after waterflooding an increase in H2S concentration was det...
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2005
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| Acceso en línea: | https://bibliotecadigital.exactas.uba.ar/collection/paper/document/paper_10461779_v_n_p131_Cavallaro http://hdl.handle.net/20.500.12110/paper_10461779_v_n_p131_Cavallaro |
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paper:paper_10461779_v_n_p131_Cavallaro2023-06-08T16:01:11Z Oilfield reservoir souring during waterflooding: A case study with low sulphate concentration in formation and injection waters Corrosion rate Injection waters Nutrients Sulfate concentration Bacteria Biofilters Corrosion Environmental impact Geology Hydrocarbons Isotopes Petroleum reservoirs Project management Sulfur compounds Water injection Well flooding Oil fields A case study is presented which addressed the origin of Hydrogen Sulphide (H2S) in produced gas associated with the oil in Las Heras - Cerro Grande oilfield in Gulf of San Jorge Basin, Argentina. The reservoir was initially sweet. However, after waterflooding an increase in H2S concentration was detected in several wells. The H2S amount varies across the field with the highest values found in wells where water injection was initiated and the wells produce with a high water cut. Knowledge of H 2S origin contributes to effective control and therefore, to reduce environmental risk, minimize emissions, improve quality of produced hydrocarbons and reduce corrosion rate. The main stages followed include, H2S measurements, H2S source identification and mitigation treatments. The possible mechanisms of reservoir souring have been analyzed by sulphur isotope ratio analysis. These results have been integrated with geological factors and other parameters related to waterflooding. This case is unusual because of water composition. The formation and injection waters have low salinity and are not rich in sulphate ion concentration, very different from sea water composition. Nutrients such as fatty acids are present in both formation and injection waters. The increase in H2S production is attributed to sulphate reducing bacteria (SRB) living in the reservoir. The proposed model to explain H2S origin suggests a closed system with reactive-limited reaction where H2S production is controlled by low sulphate concentration present in waters. A strong correlation was demonstrated between produced H2S, injection water parameters and subsequent souring. A decrease in sulphate concentration present in water production appears to correspond with an increase in H2S concentration. At present, the produced gas is being treated with scavengers. A nitrate injection project is being analyzed to control reservoir souring. The development of a biofilter to oxidize H2S in plant treatment is in laboratory phase. Copyright 2005, Society of Petroleum Engineers Inc. 2005 https://bibliotecadigital.exactas.uba.ar/collection/paper/document/paper_10461779_v_n_p131_Cavallaro http://hdl.handle.net/20.500.12110/paper_10461779_v_n_p131_Cavallaro |
| institution |
Universidad de Buenos Aires |
| institution_str |
I-28 |
| repository_str |
R-134 |
| collection |
Biblioteca Digital - Facultad de Ciencias Exactas y Naturales (UBA) |
| topic |
Corrosion rate Injection waters Nutrients Sulfate concentration Bacteria Biofilters Corrosion Environmental impact Geology Hydrocarbons Isotopes Petroleum reservoirs Project management Sulfur compounds Water injection Well flooding Oil fields |
| spellingShingle |
Corrosion rate Injection waters Nutrients Sulfate concentration Bacteria Biofilters Corrosion Environmental impact Geology Hydrocarbons Isotopes Petroleum reservoirs Project management Sulfur compounds Water injection Well flooding Oil fields Oilfield reservoir souring during waterflooding: A case study with low sulphate concentration in formation and injection waters |
| topic_facet |
Corrosion rate Injection waters Nutrients Sulfate concentration Bacteria Biofilters Corrosion Environmental impact Geology Hydrocarbons Isotopes Petroleum reservoirs Project management Sulfur compounds Water injection Well flooding Oil fields |
| description |
A case study is presented which addressed the origin of Hydrogen Sulphide (H2S) in produced gas associated with the oil in Las Heras - Cerro Grande oilfield in Gulf of San Jorge Basin, Argentina. The reservoir was initially sweet. However, after waterflooding an increase in H2S concentration was detected in several wells. The H2S amount varies across the field with the highest values found in wells where water injection was initiated and the wells produce with a high water cut. Knowledge of H 2S origin contributes to effective control and therefore, to reduce environmental risk, minimize emissions, improve quality of produced hydrocarbons and reduce corrosion rate. The main stages followed include, H2S measurements, H2S source identification and mitigation treatments. The possible mechanisms of reservoir souring have been analyzed by sulphur isotope ratio analysis. These results have been integrated with geological factors and other parameters related to waterflooding. This case is unusual because of water composition. The formation and injection waters have low salinity and are not rich in sulphate ion concentration, very different from sea water composition. Nutrients such as fatty acids are present in both formation and injection waters. The increase in H2S production is attributed to sulphate reducing bacteria (SRB) living in the reservoir. The proposed model to explain H2S origin suggests a closed system with reactive-limited reaction where H2S production is controlled by low sulphate concentration present in waters. A strong correlation was demonstrated between produced H2S, injection water parameters and subsequent souring. A decrease in sulphate concentration present in water production appears to correspond with an increase in H2S concentration. At present, the produced gas is being treated with scavengers. A nitrate injection project is being analyzed to control reservoir souring. The development of a biofilter to oxidize H2S in plant treatment is in laboratory phase. Copyright 2005, Society of Petroleum Engineers Inc. |
| title |
Oilfield reservoir souring during waterflooding: A case study with low sulphate concentration in formation and injection waters |
| title_short |
Oilfield reservoir souring during waterflooding: A case study with low sulphate concentration in formation and injection waters |
| title_full |
Oilfield reservoir souring during waterflooding: A case study with low sulphate concentration in formation and injection waters |
| title_fullStr |
Oilfield reservoir souring during waterflooding: A case study with low sulphate concentration in formation and injection waters |
| title_full_unstemmed |
Oilfield reservoir souring during waterflooding: A case study with low sulphate concentration in formation and injection waters |
| title_sort |
oilfield reservoir souring during waterflooding: a case study with low sulphate concentration in formation and injection waters |
| publishDate |
2005 |
| url |
https://bibliotecadigital.exactas.uba.ar/collection/paper/document/paper_10461779_v_n_p131_Cavallaro http://hdl.handle.net/20.500.12110/paper_10461779_v_n_p131_Cavallaro |
| _version_ |
1768544513651900416 |