Prediction and Evaluation of Sanding and Casing Deformation in a GOM-Shelf Well

Ispas, Ion; Bray, A.R.; Palmer, Ian; Higgs, N. G.

doi:10.2118/87842-jpt

Cited by 5 publications

(3 citation statements)

References 2 publications

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“…The risk of casing deformation was felt to be low due to the low volume of sand predicted to be produced. It has been noted by others however, that casing deformation may occur whenever sand is produced 6,7 .…”

Section: Evaluation Of Cavity-like Completion Techniquementioning

confidence: 99%

A Recent Gulf of Mexico Cavity Completion

Palmer¹,

Vorpahl

Glenn

et al. 2004

All Days

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractProduction was dramatically improved by cavitating (intentionally producing sand) an offshore gas well on the Gulf of Mexico Shelf. The cavity completion was conducted over a period of 10 days and involved producing the well through temporary equipment in order to safely produce, collect, and dispose of the produced sand. No hydrocarbon emissions resulted since production could be routed back through the permanent facilities. Following the operations, the well was returned to flow through the permanent facilities at a much higher producing rate, with much lower sand production.Prior to the cavity completion operations, the well had been choked back to a low gas rate, <1 MMscfd, due to sand production. The low gas rate was insufficient to continuously lift liquids, causing the well to become liquid loaded and/ or slug. The well was evaluated for a sand control completion, but this type of repair was felt to entail too much economic risk due to significant reservoir unknowns. Further evaluation suggested that the well had the attributes for a successful cavity completion. This paper will discuss the cavity completion evaluation process employed and operational results and learnings. A similar process may be applicable to other wells.

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Section: Evaluation Of Cavity-like Completion Techniquementioning

confidence: 99%

A Recent Gulf of Mexico Cavity Completion

Palmer¹,

Vorpahl

Glenn

et al. 2004

All Days

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“…2). This plot is useful for sanding evaluation 3,4 . In this plot the flowing well pressure (BHFP) is plotted versus reservoir pressure and regions of no flow, sand production and acceptable sand production are defined.…”

Section: An Empirical Sand Production Criterionmentioning

confidence: 99%

The Relative Importance of Drawdown and Depletion in Sanding Wells: Predictive Models Compared With Data From the Statfjord Field

Hettema

Andrews

Papamichos

et al. 2006

Proceedings of International Symposium and Exhibition on Formation Damage Control

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractExperience of sand production from the Statfjord field has been systemized to be able to predict the effect of drawdown and depletion on sand production. The aim of the study is to determine how reservoir pressure depletion will influence the sand production and to determine how sand production will influence the maximum liquid production rates. Most wells produce according to a maximum acceptable sand production criterion. Field data based on more than 300 maximum acceptable sand rate tests have been systemized by fitting those to an empirical criterion. For a better determination of the parameters, sand production histories of four wells have been analyzed in detail.To understand more about the mechanisms underlying the sand production, the field results are compared with four different models. This work concludes that the behaviour of sanding wells at Statfjord can be described by a concept of two sand production regimes, one controlled by shear failure and the other controlled by rate.Finally the empirical model is used to extrapolate the field experience to low reservoir pressures related to the planned deep depressurization. The results show that sand production will limit well production rates unacceptably for most formations and that downhole sand control is needed to secure high production rates during the late-life development of the field. IntroductionThe Statfjord field is a large oil field located in the Northern part of the Viking Graben and straddles the border between the Norwegian and UK sectors. The field has been in production since 1979 and has utilized both water flooding and gas injection for secondary recovery. To date over 65% of the STOOIP has been recovered. The producing reservoirs (Brent and Statfjord) consist of weak to intermediate strength

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“…A third aspect is to be able to evaluate whether a cased/perforated completion can be used initially, and to defer a sand control option until later, with cost and flow rate and environmental advantages. 1 In summary, there is often a substantial cost benefit -both for capital and operating expenditure -if sand management can be deployed successfully.…”

Section: Introductionmentioning

confidence: 99%

Predicting and Managing Sand Production: A New Strategy

Palmer¹,

Willson²,

Moschovidis

et al. 2003

All Days

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractSand prediction at BP has been developed by dividing it into three parts: (1) onset, (2) transient sanding, (3) steady-state sanding. For example, as drawdown is increased in a well in a sand-prone formation, significant sanding begins at some point (the onset), and this is followed by a transient sand burst, which may last hours or days or months. The sanding eventually declines to a background level (steady-state), in the range 1-100 pptb. We have made recent step-changes in (2) and (3), and we now have a tool that can predict sanding onset, and volumes during any stage of a well's production history, or even injection history.The onset of sanding is predicted using a stress-based model. This model is conservative, based on a benchmarking study of field applications. One application predicts sanding in water injectors during shut-in, and recommends not using sand control. Another application explains delayed sanding in an HPHT gas reservoir, in terms of restraining forces due to capillary cohesion (i.e., the damp sand effect at the beach). The transient sanding model is a fully-coupled finite element (FE) model. The model has successfully predicted sand volumes in laboratory and field tests. With this model, we can judge whether we can manage the produced sand, from both production and injection wells. Finally, we have applied this to predict whether a well will kill itself after a blowout, due to sand in the wellbore increasing the hydrostatic pressure.The steady-state model is an empirical model that is based upon extensive tests of sanding from cores in the laboratory. The model has been applied to predict sanding in an offshore field, and this has led to the conclusion that sand rates can be managed at surface, without sand control: a huge economic advantage. Finally, we present a case history where we use all three models to make an integrated prediction of onset, * now at Higgs Technologies, Houston transient, and steady-state sanding, and find quite good agreement with field observations. In summary, the new threefold strategy of sand prediction at BP has significantly increased our capability to predict sanding in production or injection wells. This quantum leap is invaluable to help decide if we can manage the sand at surface (or if downhole sand control is required); to decide if we can defer sand control until a later date (possibly increasing production as well as saving completion costs); to decide how much sand will be produced if we increase the drawdown in a sand-prone well; and even decide if we need sand control in water injectors.

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Prediction and Evaluation of Sanding and Casing Deformation in a GOM-Shelf Well

Cited by 5 publications

References 2 publications

A Recent Gulf of Mexico Cavity Completion

A Recent Gulf of Mexico Cavity Completion

The Relative Importance of Drawdown and Depletion in Sanding Wells: Predictive Models Compared With Data From the Statfjord Field

Predicting and Managing Sand Production: A New Strategy

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