Predicting Brine Mixing Deep Within the Reservoir, and the Impact on Scale Control in Marginal and Deepwater Developments

Predicting Brine Mixing Deep Within the Reservoir, and the Impact on Scale Control in Marginal and Deepwater Developments E.J. Mackay; E.J. Mackay Heriot-Watt University Search for other works by this author on: This Site Google Scholar M.M. Jordan; M.M. Jordan ONDEO Nalco Energy Services Search for other works by this author on: This Site Google Scholar F. Torabi F. Torabi Heriot-Watt University Search for other works by this author on: This Site Google Scholar Paper presented at the International Symposium and Exhibition on Formation Damage Control, Lafayette, Louisiana, February 2002. Paper Number: SPE-73779-MS https://doi.org/10.2118/73779-MS Published: February 20 2002 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Mackay, E.J., Jordan, M.M., and F. Torabi. "Predicting Brine Mixing Deep Within the Reservoir, and the Impact on Scale Control in Marginal and Deepwater Developments." Paper presented at the International Symposium and Exhibition on Formation Damage Control, Lafayette, Louisiana, February 2002. doi: https://doi.org/10.2118/73779-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search nav search search input Search input auto suggest search filter All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE International Conference and Exhibition on Formation Damage Control Search Advanced Search AbstractSulphate scale deposition is a common problem in hydrocarbon reservoirs where injection seawater, rich in sulphate, mixes with formation brines, rich in barium, strontium and calcium. The deposition of these scales can cause significant production impairment if it occurs within zones near the production wellbores. To control scale deposition within the near wellbore region of a reservoir, scale squeeze treatments are commonly deployed. In cases where the scale severity is very high, removal of sulphate ions from the injection water is an alternative scale control strategy. Both these methods of mitigation have associated CAPEX (e.g. desulphation plant) and OPEX (e.g. scale squeeze treatments) costs.Typically, to assess the severity of the problem in new fields, thermodynamic calculations are performed to calculate the mass of scale that will form. Until present there has been little work carried out to identify the location of scale formation within the reservoir. In this paper, field data and flow simulations from three North Sea fields are presented to show that the formation of scale can in fact occur deep within the reservoir, and have negligible negative impact on oil production within the near wellbore region.Evidence is presented from these North Sea fields that shows the evolution of the brine chemistry as seawater breakthrough occurs and squeeze treatments were applied. The evidence from the produced brine chemistry is linked to flow calculations for these fields to show that in some systems scale is depositing deep within the reservoir, reducing the potential for damage in the near production wellbore region. The extent and impact of the deposition varies throughout the reservoir and can be quantified. The ability to model brine mixing and stripping of the scaling ions before the fluids reach the production wellbore has a very significant impact on the economic assessment of marginal fields and deepwater developments. In such fields, the technical challenge and cost (CAPEX/OPEX) of scale control might make development un-economic. This paper outlines the data requirements and methodology used to allow such an assessment to be made.IntroductionFlow assurance is an essential aspect of the economic production of hydrocarbons. It can be considered as the ability to produce petroleum fluids economically from the reservoir to a production facility over the lifetime of a field. Scale control is one of the key aspects of flow assurance. The increasing number of subsea wells and deepwater developments raises particular issues and evolving challenges for flow assurance, beyond those seen for simple vertical wells. The complexity of new well completions, in terms of horizontal and multi-lateral wells, subsea tiebacks, and commingled flow, presents particular challenges. Where scale inhibitor treatments are required for such complex wells, they are often associated with very high intervention costs.Scale control issues need to be addressed as part of asset life cycle management, whereby the issues are tackled prior to field development/production (CAPEX phase), rather than being confronted in a reactive manner once water breakthrough occurs (OPEX phase). Such an approach allows for selection of appropriate economic technology. Indeed, the anticipated problems may influence the plans to develop a field, for example, in terms of water injection strategies or implementing appropriate technology upon well completion. Keywords: hydrate inhibition, hydrate remediation, paraffin remediation, symposium, mackay, upstream oil & gas, scale control, injection, remediation of hydrates, ppm Subjects: Production Chemistry, Metallurgy and Biology, Improved and Enhanced Recovery, Inhibition and remediation of hydrates, scale, paraffin / wax and asphaltene This content is only available via PDF. 2002. Society of Petroleum Engineers You can access this article if you purchase or spend a download.

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