Fluid Delumping Applied to the Goliat field: A Black-oil Model Coupled with a Process Design

Vignati, Emanuele; Bonotto, William; Cominelli, Alberto; Stano, Elena; Maitre, Claire Le

doi:10.2118/130783-ms

Cited by 4 publications

References 11 publications

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Dynamic Delumping of Reservoir Simulation

Kuntadi¹,

Whitson²,

Hoda³

2012

All Days

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Integrated modeling is becoming a necessary tool in the petroleum industry to manage the value chain of different models. Reservoir models commonly utilize a simple fluid model to reduce computational time. However, the downstream models often require a more detailed EOS fluid model to perform surface-process facility modeling. This paper presents a dynamic delumping method to generate detailed compositional streams from either black-oil or compositional (lumped-EOS) reservoir simulations, performed as a simple post-processing step. A set of phase-specific, pressure-dependent split factors are used to perform dynamic delumping. The split factors are generated from simulated depletion PVT experiments using a detailed-EOS model. Delumping is performed phase-wise at the well-connection level, for each time step of the reservoir simulator. For gas injection processes, the amount of injection gas is estimated from stream information and, accordingly, removed from the stream before applying the phase-specific pressure- dependent split factors. Different split factor sets are used when the reservoir model has multiple PVT regions. We have run many reservoir simulation cases using different production mechanisms and reservoir fluids. Compared with detailed-EOS simulations, the proposed method gives near-exact results for depletion, and excellent agreement in gas injection cases. Dynamic delumping also works with complex fluid systems exhibiting large in-situ compositional (GOR) variations. For injection gas cases, improved accuracy is obtained using a tracer option in the reservoir simulator, to better estimate injection-gas quantity. This approach requires negligible cpu compared with detailed-EOS reservoir simulation. Dynamic delumping is applied as an automated post-processing for any reservoir simulator. The results of our work provide a key technology for integrating subsurface and surface petroleum models, ensuring greater consistency in the complete value chain and enabling engineers to optimize assets, both locally and globally.

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Dynamic Delumping of Reservoir Simulation

Kuntadi¹,

Whitson²,

Hoda³

2012

All Days

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Fully Coupled Simulation of Multiple Compositional Reservoirs with a Shared Surface Facility Network

Fleming

Wong

2013

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When multiple reservoirs are produced through a common facility network, the capability of integrating the modeling of surface and subsurface can be critical to field development and optimization. The shared facility network imposes constraints that the combined production cannot exceed, determines the pressure decrease in the flow lines, and determines the composition and volume of the sales and reinjection streams. Pressure decrease in flow lines is particularly important in deepwater field development, where flow lines are long and production from multiple reservoirs can flow through the same riser. The most robust method of optimizing the combined surface-subsurface system is to fully couple and simultaneously solve the reservoir and facility equations. However, if the reservoirs fluids are represented with compositional equation of state models, and different pseudo-components are used in some or all of the reservoirs, then the reservoir fluid must be delumped into a common set of pseudo-components in the network. In this paper, we describe a method to consistently and efficiently model such a system with a fully coupled surface-subsurface simulator. At every point in the network where fluid from only a single reservoir is present, the phase behavior calculations can use the fluid characterization for that reservoir, and exactly reproduce the result that would have been obtained if the fluid had not been delumped into the network pseudo-components. However, at any point in the network, the characterization of the common network fluid can be used. In addition, if more compositional accuracy is required, the network fluid can be further delumped into more pseudo-components; if accuracy is not critical, the fluid can be lumped into fewer pseudo-components for more computational efficiency. The paper provides examples that demonstrate the flexibility, efficiency, and consistency of the method.

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Perdido Development: Unified Fluid Model for Integrated-Production-System Modeling

Galvan

McVinnie

Dindoruk

2015

SPE Reservoir Evaluation &Amp; Engineering

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Summary The Perdido development is one of the most-complex deepwater projects in the world. It is operated by Shell in partnership with Chevron and BP. It currently produces hydrocarbons from 12 subsea wells penetrating four separate reservoirs. The properties of produced fluid vary per reservoir as well as spatially. The producing wells display a relatively wide range of fluid gravities, between 17 and 41 °API, and producing gas/oil ratios (GORs), between 480 and 3,000 scf/bbl. The fluids produced from the subsea wells are blended in the subsea system and lifted to the topside facilities by means of five seabed caisson electrical submersible pumps. In the topside facility, gas and oil are separated, treated, and exported by means of dedicated subsea pipelines. The fluid compositions and properties across the various elements of the production system are used as input data to the respective simulation models, and the corresponding outcomes (e.g., fluid properties, compositions) vary upon the well/caisson lineup and daily operating conditions. Given the wide spectrum of fluids produced through the Perdido spar, a special equation-of-state (EOS) characterization of the fluids had to be developed. Because a common EOS model was used to characterize the fluids, we will call this the unified fluid model (UFM) throughout this study. This approach enables accurate and efficient prediction of the properties of blended fluids and is suitable for use in an integrated-production system model (IPSM) that connects reservoirs, wells, subsea-flowline networks, and topside-facilities models. Such a modeling scheme enables effective integration among relevant engineering disciplines and can represent production and fluid data from field history with high confidence. The IPSM uses a black-oil fluid description for the well and subsea-flowline network models. By use of the initial composition and producing GOR of each well, the fluid composition is estimated by means of a simple delumping scheme. The resulting composition is tracked through the subsea network to the topside-facilities model, where compositional flash calculations are performed. The IPSM can forecast production rates together with fluid properties and actual oil- and gas-volumetric rates across the whole production system. The model can be used to optimize production under constrained conditions, such as limited gas-compression capacity or plateau oil production.

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Fluid Delumping Applied to the Goliat field: A Black-oil Model Coupled with a Process Design

Cited by 4 publications

References 11 publications

Dynamic Delumping of Reservoir Simulation

Dynamic Delumping of Reservoir Simulation

Fully Coupled Simulation of Multiple Compositional Reservoirs with a Shared Surface Facility Network

Perdido Development: Unified Fluid Model for Integrated-Production-System Modeling

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