Approaches to monitoring the state of the high-temperature oxidation front

UDK: 622.276.65
DOI: 10.24887/0028-2448-2020-12-115-117
Key words: high-temperature oxidation, combustion monitoring
Authors: E.O. Mikitin (LUKOIL-Engineering LLC, RF, Moscow), T.A. Matyukhina (LUKOIL-Engineering LLC, RF, Moscow), D.A. Mett (LUKOIL-Engineering LLC, RF, Moscow)

Oil industry are faced with the challenge of developing fundamentally new oil fields associated with deposits in unconventional hydrophobic reservoirs. The old approaches, unfortunately, are inapplicable in the development of such deposits, which are widespread in the Upper Jurassic deposits of the West Siberian oil and gas basin. As shown by the conducted field studies, using the example of the Sredne-Nazymskoye field, classical water injection is impossible for such fields, due to the rapid breakthrough of water to the bottom of production wells. The use of horizontal wells with multi-stage hydraulic fracturing allows entering these fields into development; however, they provide low values of the oil recovery factor of 7-9%. Methods of maintaining reservoir pressure can radically change the situation. As one of these methods, the method of thermal gas exposure or high-flow rate air injection was studied. At the Sredne-Nazymskoye field, for the first time in the post-Soviet space, technological approaches to the organization of injection were successfully developed. Despite the undoubted advantages over the classical water injection, there are still questions of improving the process of high-flow rate air injection. In addition to the tasks of maintaining reservoir pressure, the task is to convert organic matter, namely kerogen into mobile hydrocarbons. Due to the specifics of the process, the fastest markers are the outgoing gases. The article discusses an approach to monitoring high temperature oxidation processes based on changes in the composition of the outgoing gases. The proposed approach was substantiated on the basis of a set of laboratory studies. Also, based on the proposed approaches, it is possible to control the combustion process in the field. In the course of research, were established markers of kerogen transformation, it was shown that the presence of CO does not always mark low-temperature oxidation.

References

1. Bartlesville energy technology center U.S. department of energy, URL: https://www.energy.gov/fe/downloads/bartlesville-energy-research-center

2. Ren Y., Freitag N.P., Mahinpey N., A simple kinetic model for coke combustion during an in-situ combustion (ISC) process, Petroleum Society of Canada, 2007, April 1, doi:10.2118/07-04-05

3. Agca C., Yortsos Y.C., Steady-state analysis of in-situ combustion,

SPE-13624-MS, 1985, doi:10.2118/13624-MS

4. Bagci A.S., Kok M.V., Okandan E., Combustion reaction kinetics in limestones containing heavy oils, SPE-15737-MS, 1987, doi:10.2118/15737-MS.

5. Guindon L., Kinetic modelling of the in-situ combustion process for Athabasca oil sands, Journal of Canadian Petroleum Technology, 2015, V. 51, no. 1, doi:10.2118/0115-012-JCPT.

6. Gutierrez D., Moore R.G., Ursenbach M.G., Mehta S.A., The ABCs of in-situ combustion simulations: From laboratory experiments to the field scale, SPE-148754-MS, 2011, doi:10.2118/148754-MS.

7. Coats K.H., In-situ combustion model, SPE-8394-PA, 1980, doi: 10.2118/8394-PA.

8. Nemova V.D., Panchenko I.V., The productivity factors of Bazhenov formation in Frolov megadepression (Western Siberia) (In Russ.), Neftegazovaya geologiya. Teoriya i praktika, 2017, V. 12, no. 4, URL: http://www.ngtp.ru/rub/4/46_2017.pdf

Oil industry are faced with the challenge of developing fundamentally new oil fields associated with deposits in unconventional hydrophobic reservoirs. The old approaches, unfortunately, are inapplicable in the development of such deposits, which are widespread in the Upper Jurassic deposits of the West Siberian oil and gas basin. As shown by the conducted field studies, using the example of the Sredne-Nazymskoye field, classical water injection is impossible for such fields, due to the rapid breakthrough of water to the bottom of production wells. The use of horizontal wells with multi-stage hydraulic fracturing allows entering these fields into development; however, they provide low values of the oil recovery factor of 7-9%. Methods of maintaining reservoir pressure can radically change the situation. As one of these methods, the method of thermal gas exposure or high-flow rate air injection was studied. At the Sredne-Nazymskoye field, for the first time in the post-Soviet space, technological approaches to the organization of injection were successfully developed. Despite the undoubted advantages over the classical water injection, there are still questions of improving the process of high-flow rate air injection. In addition to the tasks of maintaining reservoir pressure, the task is to convert organic matter, namely kerogen into mobile hydrocarbons. Due to the specifics of the process, the fastest markers are the outgoing gases. The article discusses an approach to monitoring high temperature oxidation processes based on changes in the composition of the outgoing gases. The proposed approach was substantiated on the basis of a set of laboratory studies. Also, based on the proposed approaches, it is possible to control the combustion process in the field. In the course of research, were established markers of kerogen transformation, it was shown that the presence of CO does not always mark low-temperature oxidation.

References

1. Bartlesville energy technology center U.S. department of energy, URL: https://www.energy.gov/fe/downloads/bartlesville-energy-research-center

2. Ren Y., Freitag N.P., Mahinpey N., A simple kinetic model for coke combustion during an in-situ combustion (ISC) process, Petroleum Society of Canada, 2007, April 1, doi:10.2118/07-04-05

3. Agca C., Yortsos Y.C., Steady-state analysis of in-situ combustion,

SPE-13624-MS, 1985, doi:10.2118/13624-MS

4. Bagci A.S., Kok M.V., Okandan E., Combustion reaction kinetics in limestones containing heavy oils, SPE-15737-MS, 1987, doi:10.2118/15737-MS.

5. Guindon L., Kinetic modelling of the in-situ combustion process for Athabasca oil sands, Journal of Canadian Petroleum Technology, 2015, V. 51, no. 1, doi:10.2118/0115-012-JCPT.

6. Gutierrez D., Moore R.G., Ursenbach M.G., Mehta S.A., The ABCs of in-situ combustion simulations: From laboratory experiments to the field scale, SPE-148754-MS, 2011, doi:10.2118/148754-MS.

7. Coats K.H., In-situ combustion model, SPE-8394-PA, 1980, doi: 10.2118/8394-PA.

8. Nemova V.D., Panchenko I.V., The productivity factors of Bazhenov formation in Frolov megadepression (Western Siberia) (In Russ.), Neftegazovaya geologiya. Teoriya i praktika, 2017, V. 12, no. 4, URL: http://www.ngtp.ru/rub/4/46_2017.pdf



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