Modeling from Reservoir to Export: A Compositional Approach for Integrated Asset Model of Different Gas Fields in North Kuwait Jurassic Carbonate Reservoirs

Torrens, Richard; Daoud, Ahmed; Amari, Mustafa; Sharifzadeh, Ahmad; Prakash, R.; Al-Enzi, Bashayer; Dashti, Qasem

doi:10.2118/ms

Cited by 8 publications

(2 citation statements)

References 36 publications

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“…which is based on variable flow head model and showed that it has advantages over the previous studies. Christou and Kokou Dadzie [17] have recently used this model in their study of direct simulation Monte Carlo methods in porous media with varying Knudsen number. The equation for the mean free path is given by,…”

Section: Classifications Of Flow Regimes Based On Knudsen Numbermentioning

confidence: 99%

A Realistic Transport Model with Pressure-Dependent Parameters for Gas Flow in Tight Porous Media with Application to Determining Shale Rock Properties

Ali

Malik

2018

Transp Porous Med

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Shale gas recovery has seen a major boom in recent years due to the increasing global energy demands; but the extraction technologies are very expensive. It is therefore important to develop realistic transport modelling and simulation methods, for porous rocks and porous media, that can compliment the field work. Here, a new nonlinear transport model for single phase gas flow in tight porous media is derived, incorporating many important physical processes that occur in such porous systems: continuous flow, transition flow, slip flow, Knudsen diffusion, adsorption and desorption in to and out of the rock material, and a correction for high flow rates (turbulence). This produces a nonlinear advection-diffusion type of partial differential equation (PDE) with pressure dependent model parameters and associated compressibility coefficients, and highly nonlinear apparent convective flux (velocity) and apparent diffusivity.An important application is to the determination of shale rock properties, such as porosity and permeability, by history matching of the the simulation results to data from pressure-pulse decay tests in a shale rock core sample [Pong K., Ho C., Liu J., Tai Y. Non-linear pressure distribution in uniform microchannels. ]. The estimates of the rock porosity and the permeability from our model simulations are realistic of shale rocks, more realistic than obtained from previous models, and illustrates the potential of the modelling strategy presented here in producing accurate simulations of shale gas flow in tight reservoirs.

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Section: Classifications Of Flow Regimes Based On Knudsen Numbermentioning

confidence: 99%

A Realistic Transport Model with Pressure-Dependent Parameters for Gas Flow in Tight Porous Media with Application to Determining Shale Rock Properties

Ali

Malik

2018

Transp Porous Med

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“…Torrens et al (2015) also discussed an onshore fractured carbonate gas condensate and volatile oil asset in Northern Kuwait. The integrated model is implemented to design new well drilling and surface facilities.…”

Section: Introductionmentioning

confidence: 99%

The Benefit of Integrated Asset Modeling and Optimization in Evaluating Production Strategies under various Oil and Gas Price Scenarios

Rahmawati¹,

Hoda²

2015

Day 2 Tue, November 10, 2015

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The decrease in oil and gas prices results in a huge impact in the oil and gas company. This paper discusses the importance of integrated asset modeling and optimization of oil and gas fields under various oil and gas price scenarios. The integrated model is defined as simulation runs from the reservoir up to the surface process and continues with an economic evaluation.Various field models under different production strategies are presented in the paper and evaluated based on the integrated asset model. The reservoir models are a gas condensate reservoir under gas cycling and an oil reservoir under water alternating gas (WAG) injection production strategies taken from SPE 3 and SPE 5 comparative projects. Derivative free optimization methods are used to find the best operating conditions for the field. The optimization objective is to maximize economic key performance indicators, such as net present value, and to minimize cost, such as gas injection cost. The decision variables are gas injection fraction, gas injection time, water injection rate and WAG time.Using integrated system modeling, the operating parameters can be determined accurately considering reservoir and surface process capabilities. The optimization results showed that optimum gas injection time is longer during high oil prices compared to low oil prices for the gas condensate reservoir under gas injection. The oil and gas prices are fluctuating in a certain cycle over time, and the dynamic fluctuations are accommodated in the economic model. Many reasons are behind the dynamic fluctuations of oil and gas prices. The fluctuations will have an impact on company production strategies. The economic model will be simulated under very high, high, intermediate, low and very low price scenarios. For each scenario, the model will be run in the integrated modeling and reservoir only modeling. A scenario of varying the ratio of oil to gas price is also included in the analysis. Different oil and gas prices will lead to different management decisions during the field lifetime. A conservative production strategy, meaning when the field is simulated separately part-by-part, could mislead field production decisions. Based on the reservoir simulation, the liquid production might flow easily from the reservoir to the surface. However, based on the surface simulation, the well might be shut᎑down due to flow restriction on the surface. This paper presents the important concept of the integrated model and optimization under dynamic oil and gas prices. The oil and gas prices have an influence in determining production parameters. The integrated model that is used in the paper is flexible and can be replaced with another reservoir model, surface process model, or economic models.

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Coexistence of Gas-Condensate and Volatile Oil at Pressure Higher than Saturation Pressure. Physical Explanation and Modeling Approaches. Case Study: Sabriyah Field in North Kuwait Jurassic Asset

et al. 2015

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Sabriyah and Raudhatain are the main fields producing from the Middle Marrat Jurassic formation in North Kuwait with approximately 5 km distance between the two fields. Raudhatain fluid is considered as Volatile Oil, while Sabriyah is described as Gas-condensate. 16 PVT samples from Raudhatain were analyzed and described as Volatile oil. 12 PVT samples taken from Sabriyah field where 7 samples show gas condensate behavior and rest shows volatile oil. A key challenge in understanding the Sabriyah fluid characterization is the fact that 5 well samples that showed Volatile oil behavior are not separated from the Gas condensate wells by any apparent barrier. In addition, the initial reservoir pressure is much higher than the saturation pressure, preventing the equilibrium of those fluids. The objectives for this study are to analyze the physical explanation of coexistent of oil and gas-Condensate in one communicated reservoir with reservoir pressure higher than saturation pressure, apply different modeling approaches to accurately describe the fluid behavior in Sabriyah field and finally capture the influence of uncertainty in the type of fluid on the production forecast. The physical explanation for this phenomenon was investigated from different points of view: the variation of temperature, compositional variation with depth, existence of geological barriers, and facies changes. It was found that the compositional variation with depth and the change of fluids with changes of facies can provide reasonable explanation for this phenomenon. The first explanation related to compositional variations with depth is supported by the observed data that shows a strong relationship between depth and fluid type, while the temperature did not influence significantly the gas-oil phase change. The second explanation related to the concept of gas and oil charge depending on facies is supported by mercury injection capillary pressure data taken from different depth in the reservoirs, this concept improves the understanding of fluid distribution which could not be explained in previous approaches. This paper shows the way of modeling this phenomena based on these two explanations, which honor both static and dynamic data with special reference to the effect of these different modeling approaches on the production forecast of Sabriyah field. The near critical fluids which are the type of fluids in Sabriyah field are usually problematic to handle with Equation of State; therefore solving this particular case is expected to add technical value to reservoirs of the same type of fluids. The facies dependence of gas and oil distribution and the way of modeling this phenomenon is an innovative view that can contribute to the description of similar fields.

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Modeling from Reservoir to Export: A Compositional Approach for Integrated Asset Model of Different Gas Fields in North Kuwait Jurassic Carbonate Reservoirs

Cited by 8 publications

References 36 publications

A Realistic Transport Model with Pressure-Dependent Parameters for Gas Flow in Tight Porous Media with Application to Determining Shale Rock Properties

A Realistic Transport Model with Pressure-Dependent Parameters for Gas Flow in Tight Porous Media with Application to Determining Shale Rock Properties

The Benefit of Integrated Asset Modeling and Optimization in Evaluating Production Strategies under various Oil and Gas Price Scenarios

Coexistence of Gas-Condensate and Volatile Oil at Pressure Higher than Saturation Pressure. Physical Explanation and Modeling Approaches. Case Study: Sabriyah Field in North Kuwait Jurassic Asset

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