Quantification of Uncertainties for Drilling-Induced Formation Damage

Ding, Yu; Renard, G.; Herzhaft, Benjamin

doi:10.2118/100959-pa

Cited by 5 publications

(2 citation statements)

References 15 publications

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“…The authors [13] integrated a framework for field-scale modelling, HM, and robust optimisation of field scale low salinity waterflooding (LSW). An approach using the SRM for optimisation [14][15][16][17][18][19]. The authors [20] addressed the decision-making process over the determination of oil & gas production strategies.…”

Section: Background Studies Of Proxy Modelmentioning

confidence: 99%

Development of proxy models for petroleum reservoir simulation: a systematic literature review and state-of-the-art

Silva¹,

Avansi²,

Schiozer³

2020

IJAERS

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Proxy models are derived mathematical functions developed as substitutes for reservoir flow simulators. Several types of proxy models are reported in the literature, for instance, response surface models, surrogate models, or metamodels. These models are fast methods, recommended for their efficient response time to approximate model responses and, therefore, useful in the decision-making process related to reservoir management. These studies focus on modelling a limited set of factors, applications, and case studies of any technique. A systematic literature review (SLR) is performed to gather the aspects prompting the modelling of proxy models in the literature and state-of-the-art. For this, a set of search keywords with appropriate string were utilised to extract the most important studies that satisfied all the criteria defined and classified under journal and conference paper categories. The papers were condensed after removing redundancy, repetition and similarity through a sequential and iterative process. From the analysis carried out, several gaps were identified, especially during the proxy model construction. Proxy models have already been discussed in petroleum engineering as a representation of the real system of reservoir flow simulator software. However, the proxy model response is faster but has yet to establish the issues of uncertainty in the outputs. There is a need for the integration of fast methods and reservoir simulators which can improve and accelerate results within acceptance criteria and accuracy in decisionmaking processes related to reservoir management.

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Section: Background Studies Of Proxy Modelmentioning

confidence: 99%

Development of proxy models for petroleum reservoir simulation: a systematic literature review and state-of-the-art

Silva¹,

Avansi²,

Schiozer³

2020

IJAERS

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“…It also reduces or eliminates formation damage because there is no fluid lost to the formation in most cases, resulting in higher productivity wells, and possibly increases reserves. [6][7][8][9][10][11][12][13] More recent techniques in evaluating candidates for underbalanced drilling have removed much of the uncertainty whether a particular well will benefit from UBD 14 , and the development of new equipment and fluids has improved the safety, efficiency and productivity of wells drilled or completed underbalanced.…”

Section: Introductionmentioning

confidence: 99%

Fluid Customization and Equipment Optimization Enable Safe and Successful Underbalanced Drilling of High-H2S Horizontal Wells in Saudi Arabia

Hallman¹,

Muqeem²,

Cook³

et al. 2007

Proceedings of IADC/SPE Managed Pressure Drilling &Amp; Underbalanced Operations

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TX 75083-3836 U.S.A., fax 1.972.952.9435. AbstractSaudi Aramco planned to drill three horizontal wells underbalanced in the Uthmaniyah Field in Saudi Arabia but concern was raised because the large volume of fluid produced would also contain a high concentration of H 2 S. A detailed engineering study was conducted of the well parameters and it was recommended that a diesel-based fluid system be used initially for compatibility, cuttings carrying capacity and pressure control. Since the underbalanced operation was based on the flow drilling technique, the drilling fluid system was diluted and became a produced oil system as the underbalanced drilling operation progressed.An important part of the design and treatment program was the minimization of H 2 S exposure for personnel on the rig site. A preliminary review of the operation revealed the areas of greatest concern; and the equipment layout was designed to ensure efficient separation and permit fluid treatment at surface. Laboratory studies recommended a proprietary oilsoluble H 2 S scavenger to remove residual H 2 S in the circulating fluid, and treatment points were selected for optimal performance.All three wells were successfully drilled in an underbalanced condition. There were some minor H 2 S releases on the first well at several open points in the system, requiring a reassessment of the separation layout and design, particularly in the solids control equipment, and in the fluid treatment program.Once this was accomplished, the subsequent wells proceeded more smoothly. H 2 S levels in both the liquid and gas streams were monitored and showed very good removal efficiency despite the high production of both oil and gas from the wells. This paper describes the design of the fluid system and separation equipment for the three wells. It will also highlight results from all three wells, showing the learning experience and optimization of the drilling operation from a fluid engineering and treatment point of view, as well as recommendations for future wells.

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Equivalent Skin Factors for Nonuniformly Damaged Horizontal and Multilateral Wells

Yildiz

2008

All Days

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In the first part of this study, we scrutinize the equivalent skin concept used to emulate the influence of uneven formation damage on the performance of horizontal wells. Rigorous 3D multisegment well models are used to simulate the local changes due to nonuniform formation damage around wellbore accurately. We show that the simple models, presented in the literature, to compute equivalent skin factors are quite limited in their accuracy.Equivalent skin factor resulting from nonuniform formation damage around a horizontal well, in general, is influenced not only by the static damage distribution itself but also by many reservoir and wellbore variables. A convoluted interaction of well location, distance to reservoir boundaries, reservoir boundary type, formation thickness, well length, extent and nature of static formation damage itself, production time, and the contrast between the flux distributions around damaged and undamaged wells affects and controls the equivalent skin factor around horizontal wells.In the second part of the study, we investigate the uneven formation damage around multilateral wells. Our investigation concludes that, as far as the equivalent skin factor values are concerned, the multilateral cannot be represented as an extension of horizontal wells. The interaction between the laterals affects the flux distribution around the laterals which in turn influences equivalent skin factors. Commingled production from duallateral systems changes the nature and size of equivalent skin in comparison with equivalent skin factors resulting from individual and separate productions from each lateral. In a duallateral system, the contrast in the individual lateral lengths may have a strong impact on the equivalent skin factors for both laterals.

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Quantification of Uncertainties for Drilling-Induced Formation Damage

Cited by 5 publications

References 15 publications

Development of proxy models for petroleum reservoir simulation: a systematic literature review and state-of-the-art

Development of proxy models for petroleum reservoir simulation: a systematic literature review and state-of-the-art

Fluid Customization and Equipment Optimization Enable Safe and Successful Underbalanced Drilling of High-H2S Horizontal Wells in Saudi Arabia

Equivalent Skin Factors for Nonuniformly Damaged Horizontal and Multilateral Wells

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