Re-development of the Frøy Field

Selection of the injection water

T. Østvold, E. J. Mackay, R. A. McCartney, I. Davis, E. Aune

    Research output: Chapter in Book/Report/Conference proceedingConference contribution

    Abstract

    The Frøy Field, Norwegian North Sea, was closed down in March 2001 but there are plans to re-develop it. Previously, seawater (SW) injection caused persistent BaSO4 scaling problems in the production wells, so this study was undertaken to determine whether there would be any benefit in using Utsira formation water (UW; low SO4) as opposed to seawater as the injection water. Thermodynamic calculations indicated that whether SW or UW is injected, the principle scaling risks are from BaSO4 and CaCO 3 deposition. Being more difficult to treat, the study focused on the BaSO4 risk. ECLIPSE modelling was used to estimate FW:SW:UW ratios over time for each new well assuming (a) SW injection and (b) UW injection. The results indicated that in each case, initial peaks in BaSO4 Saturation Ratio (SRBaso4) would occur after ~1.5-2.5 years before declining. The peaks reflect co-production of seawater already present in the reservoir and formation water. The subsequent decline in SRBaso4 reflects (a) decrease in the FW:SW ratio (SW injection case) and (b) dilution of produced Ba and SO4 as the produced UW fraction increases (UW injection case). An evaluation of produced water analyses from Frøy and from analogue fields indicated that reservoir reactions will occur at Fray whether SW or UW are injected but significant BaSO4 would only occur in the presence of seawater. Two methods were used to quantify SR Baso4 in the new production wells over time after accounting for BaSO4 precipitation in the reservoir. In the first, the amount of BaSO4 deposition in the reservoir was predicted from past produced water analyses and applied to the ECLIPSE results. The second involved the use of STARS to model the effect of reservoir reactions on the scaling potential. There were some differences in the results related to the amount of mixing predicted to be occurring in the reservoir, but contrary to initial expectations, both methods indicated that UW injection would not be beneficial. Based on these results, seawater has been selected as the injection water resulting in significant OPEX and CAPEX cost savings. © 2010, Society of Petroleum Engineers.

    Original languageEnglish
    Title of host publicationSociety of Petroleum Engineers - 10th SPE International Conference on Oilfield Scale 2010
    Pages176-198
    Number of pages23
    Publication statusPublished - 2010
    Event10th SPE International Conference on Oilfield Scale - Aberdeen, United Kingdom
    Duration: 26 May 201027 May 2010

    Conference

    Conference10th SPE International Conference on Oilfield Scale
    CountryUnited Kingdom
    CityAberdeen
    Period26/05/1027/05/10

    Fingerprint

    redevelopment
    seawater
    water
    formation water
    well
    savings
    dilution
    thermodynamics
    petroleum
    saturation

    Cite this

    Østvold, T., Mackay, E. J., McCartney, R. A., Davis, I., & Aune, E. (2010). Re-development of the Frøy Field: Selection of the injection water. In Society of Petroleum Engineers - 10th SPE International Conference on Oilfield Scale 2010 (pp. 176-198)
    Østvold, T. ; Mackay, E. J. ; McCartney, R. A. ; Davis, I. ; Aune, E. / Re-development of the Frøy Field : Selection of the injection water. Society of Petroleum Engineers - 10th SPE International Conference on Oilfield Scale 2010. 2010. pp. 176-198
    @inproceedings{e1bd3b041b2148e78c5bf5c28547bd67,
    title = "Re-development of the Fr{\o}y Field: Selection of the injection water",
    abstract = "The Fr{\o}y Field, Norwegian North Sea, was closed down in March 2001 but there are plans to re-develop it. Previously, seawater (SW) injection caused persistent BaSO4 scaling problems in the production wells, so this study was undertaken to determine whether there would be any benefit in using Utsira formation water (UW; low SO4) as opposed to seawater as the injection water. Thermodynamic calculations indicated that whether SW or UW is injected, the principle scaling risks are from BaSO4 and CaCO 3 deposition. Being more difficult to treat, the study focused on the BaSO4 risk. ECLIPSE modelling was used to estimate FW:SW:UW ratios over time for each new well assuming (a) SW injection and (b) UW injection. The results indicated that in each case, initial peaks in BaSO4 Saturation Ratio (SRBaso4) would occur after ~1.5-2.5 years before declining. The peaks reflect co-production of seawater already present in the reservoir and formation water. The subsequent decline in SRBaso4 reflects (a) decrease in the FW:SW ratio (SW injection case) and (b) dilution of produced Ba and SO4 as the produced UW fraction increases (UW injection case). An evaluation of produced water analyses from Fr{\o}y and from analogue fields indicated that reservoir reactions will occur at Fray whether SW or UW are injected but significant BaSO4 would only occur in the presence of seawater. Two methods were used to quantify SR Baso4 in the new production wells over time after accounting for BaSO4 precipitation in the reservoir. In the first, the amount of BaSO4 deposition in the reservoir was predicted from past produced water analyses and applied to the ECLIPSE results. The second involved the use of STARS to model the effect of reservoir reactions on the scaling potential. There were some differences in the results related to the amount of mixing predicted to be occurring in the reservoir, but contrary to initial expectations, both methods indicated that UW injection would not be beneficial. Based on these results, seawater has been selected as the injection water resulting in significant OPEX and CAPEX cost savings. {\circledC} 2010, Society of Petroleum Engineers.",
    author = "T. {\O}stvold and Mackay, {E. J.} and McCartney, {R. A.} and I. Davis and E. Aune",
    year = "2010",
    language = "English",
    isbn = "9781617386619",
    pages = "176--198",
    booktitle = "Society of Petroleum Engineers - 10th SPE International Conference on Oilfield Scale 2010",

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    Østvold, T, Mackay, EJ, McCartney, RA, Davis, I & Aune, E 2010, Re-development of the Frøy Field: Selection of the injection water. in Society of Petroleum Engineers - 10th SPE International Conference on Oilfield Scale 2010. pp. 176-198, 10th SPE International Conference on Oilfield Scale, Aberdeen, United Kingdom, 26/05/10.

    Re-development of the Frøy Field : Selection of the injection water. / Østvold, T.; Mackay, E. J.; McCartney, R. A.; Davis, I.; Aune, E.

    Society of Petroleum Engineers - 10th SPE International Conference on Oilfield Scale 2010. 2010. p. 176-198.

    Research output: Chapter in Book/Report/Conference proceedingConference contribution

    TY - GEN

    T1 - Re-development of the Frøy Field

    T2 - Selection of the injection water

    AU - Østvold, T.

    AU - Mackay, E. J.

    AU - McCartney, R. A.

    AU - Davis, I.

    AU - Aune, E.

    PY - 2010

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    N2 - The Frøy Field, Norwegian North Sea, was closed down in March 2001 but there are plans to re-develop it. Previously, seawater (SW) injection caused persistent BaSO4 scaling problems in the production wells, so this study was undertaken to determine whether there would be any benefit in using Utsira formation water (UW; low SO4) as opposed to seawater as the injection water. Thermodynamic calculations indicated that whether SW or UW is injected, the principle scaling risks are from BaSO4 and CaCO 3 deposition. Being more difficult to treat, the study focused on the BaSO4 risk. ECLIPSE modelling was used to estimate FW:SW:UW ratios over time for each new well assuming (a) SW injection and (b) UW injection. The results indicated that in each case, initial peaks in BaSO4 Saturation Ratio (SRBaso4) would occur after ~1.5-2.5 years before declining. The peaks reflect co-production of seawater already present in the reservoir and formation water. The subsequent decline in SRBaso4 reflects (a) decrease in the FW:SW ratio (SW injection case) and (b) dilution of produced Ba and SO4 as the produced UW fraction increases (UW injection case). An evaluation of produced water analyses from Frøy and from analogue fields indicated that reservoir reactions will occur at Fray whether SW or UW are injected but significant BaSO4 would only occur in the presence of seawater. Two methods were used to quantify SR Baso4 in the new production wells over time after accounting for BaSO4 precipitation in the reservoir. In the first, the amount of BaSO4 deposition in the reservoir was predicted from past produced water analyses and applied to the ECLIPSE results. The second involved the use of STARS to model the effect of reservoir reactions on the scaling potential. There were some differences in the results related to the amount of mixing predicted to be occurring in the reservoir, but contrary to initial expectations, both methods indicated that UW injection would not be beneficial. Based on these results, seawater has been selected as the injection water resulting in significant OPEX and CAPEX cost savings. © 2010, Society of Petroleum Engineers.

    AB - The Frøy Field, Norwegian North Sea, was closed down in March 2001 but there are plans to re-develop it. Previously, seawater (SW) injection caused persistent BaSO4 scaling problems in the production wells, so this study was undertaken to determine whether there would be any benefit in using Utsira formation water (UW; low SO4) as opposed to seawater as the injection water. Thermodynamic calculations indicated that whether SW or UW is injected, the principle scaling risks are from BaSO4 and CaCO 3 deposition. Being more difficult to treat, the study focused on the BaSO4 risk. ECLIPSE modelling was used to estimate FW:SW:UW ratios over time for each new well assuming (a) SW injection and (b) UW injection. The results indicated that in each case, initial peaks in BaSO4 Saturation Ratio (SRBaso4) would occur after ~1.5-2.5 years before declining. The peaks reflect co-production of seawater already present in the reservoir and formation water. The subsequent decline in SRBaso4 reflects (a) decrease in the FW:SW ratio (SW injection case) and (b) dilution of produced Ba and SO4 as the produced UW fraction increases (UW injection case). An evaluation of produced water analyses from Frøy and from analogue fields indicated that reservoir reactions will occur at Fray whether SW or UW are injected but significant BaSO4 would only occur in the presence of seawater. Two methods were used to quantify SR Baso4 in the new production wells over time after accounting for BaSO4 precipitation in the reservoir. In the first, the amount of BaSO4 deposition in the reservoir was predicted from past produced water analyses and applied to the ECLIPSE results. The second involved the use of STARS to model the effect of reservoir reactions on the scaling potential. There were some differences in the results related to the amount of mixing predicted to be occurring in the reservoir, but contrary to initial expectations, both methods indicated that UW injection would not be beneficial. Based on these results, seawater has been selected as the injection water resulting in significant OPEX and CAPEX cost savings. © 2010, Society of Petroleum Engineers.

    M3 - Conference contribution

    SN - 9781617386619

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    EP - 198

    BT - Society of Petroleum Engineers - 10th SPE International Conference on Oilfield Scale 2010

    ER -

    Østvold T, Mackay EJ, McCartney RA, Davis I, Aune E. Re-development of the Frøy Field: Selection of the injection water. In Society of Petroleum Engineers - 10th SPE International Conference on Oilfield Scale 2010. 2010. p. 176-198