Optimal Development Strategies to Different Scenarios of Reservoir Properties - Application to a Real Field

Seismic petrophysics focused case study for AVA modelling and pre-stack seismic inversion

The APPEA Journal ◽

10.1071/aj15025 ◽

2016 ◽

Vol 56 (1) ◽

pp. 341

Author(s):

Jahan Zeb ◽

Sanjeev Rajput ◽

Jimmy Ting

Keyword(s):

Model Building ◽

Rock Physics ◽

Seismic Inversion ◽

Oil Field ◽

Well Logs ◽

Real Field ◽

Seismic Responses ◽

Reservoir Properties ◽

Rock Types ◽

Amplitude Versus

Hydrocarbon reservoirs are characterised by integrating seismic, well-log and petrophysical information, which are dissimilar in spatial distribution, scale and relationship to reservoir properties. Well logs are essential for amplitude versus offset (AVO) modelling and seismic inversion. The usability of well logs can be determined during wavelet estimation, seismic-to-well ties, background model building, property distribution for inversion, deriving probability density functions and variograms, offset-to-angle conversion of seismic data, and many other processes. For the implementation of seismic inversion workflows, accurate and geologically corrected compressional-sonic, shear-sonic and density logs are necessary. Preparing the logs for quantitative interpretation becomes challenging in a real-field environment because of bad borehole conditions including washouts, uncalibrated and variability of logging tools, invasion effects, missing shear logs and change of borehole size. Conventional petrophysical analysis is usually restricted to the reservoir interval, the calculation of reservoir versus non-reservoir (including sands or shales), and log corrections for smaller intervals; in contrast, seismic petrophysics encompasses the entire geological interval, calculates the volume of multi-minerals, incorporates boundaries between non-reservoir and reservoir, and often includes the prediction of missing compressional and shear-sonic for AVO analysis. A detailed seismic petrophysics analysis was performed for amplitude versus angle (AVA) modelling and attributes analysis. To perform the AVA modelling, a series of forward models in association with rock physics modelled fluid-substituted logs were developed, and associated seismic responses for various pore fluids and rock types studied. The results reveal that synthetic seismic responses together with the AVA analysis show changes for various lithologies. AVA attributes analysis show trends in generated synthetic seismic responses for various fluid-substituted and porosity logs. Reservoir modelling and fluid substitution increases understanding of the observed seismic response. This paper describes detailed data analysis using various techniques to confirm the rock model for petrophysical evaluation, rock physics modelling, AVA analysis, pre-stack seismic inversion, and the scenario modelling applied to the study of an oil field in Australia.

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A New Approach for Determining the Control Volumes of Production Wells considering Irregular Well Distribution and Heterogeneous Reservoir Properties

Geofluids ◽

10.1155/2021/6666831 ◽

2021 ◽

Vol 2021 ◽

pp. 1-13

Author(s):

Cheng Lu ◽

Ling Chen ◽

Xiaodong Wang ◽

Wanjing Luo ◽

Yue Peng ◽

...

Keyword(s):

Control Volume ◽

Computational Cost ◽

Real Field ◽

Well Performance ◽

Production Well ◽

Reservoir Model ◽

Reservoir Properties ◽

New Approach ◽

Production Wells ◽

Control Volumes

The oil and gas fields are commonly developed with a group of production wells. Therefore, it can be essential for the industries to predict the performance of the production wells in order to optimize the development strategies. In practice, it frequently happens that we only hope to study the performance of a single production well. In such cases, it can be time consuming to run the reservoir simulation with the entire reservoir model to study the well performance. Hence, it can be preferred to determine the control volume (or drainage volume) of the target well from the entire reservoir and run the simulation with the small control volume to reduce the simulation cost. However, an irregular layout of the production wells and the heterogeneity of reservoir properties, which can be commonly observed in real field cases, can induce a stringent barrier for one to determine the control volumes. At present, we are still lacking a method to determine the control volumes of the production wells considering well distribution and reservoir heterogeneities. In order to overcome such a barrier, the authors proposed a new approach to divide the entire reservoir into small control volumes on the basis of the fast marching method (FMM). This approach is validated by comparing the simulation outputs of the target well calculated only with the determined control volume to those calculated with the entire reservoir model. The calculated results show that using the control volume that is determined with the proposed method to calculate the well performance can yield results that agree well with the results that are calculated with the entire reservoir model. This indicates that this proposed method is reliable to determine the control volume of the production wells. In addition, the calculated results in this work show that changing fracture length exerts a slight influence on the control volumes if the length of all fractures is increased, whereas, if only one of the fracture lengths is increased, the control volume of the corresponding well will be significantly increased. The number of the production wells and the distribution of the production well can noticeably influence the control volumes of the production wells. The findings of this study can help for optimizing the well spacing, estimating the ultimate recovery, and reducing the computational cost.

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Geostatistically-Consistent History Matching Of Lithofacies And Reservoir Properties Applied To Synthetic and Real-Field Cases

ECMOR XVI - 16th European Conference on the Mathematics of Oil Recovery ◽

10.3997/2214-4609.201802142 ◽

2018 ◽

Author(s):

E.S. Zakirov ◽

I.M. Shiryaev ◽

I.M. Indrupskiy ◽

O.V. Lyubimova ◽

E.Yu Arkhipova ◽

...

Keyword(s):

History Matching ◽

Real Field ◽

Reservoir Properties

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History Matching Using the Ensemble Kalman Filter With Multiscale Parameterization: A Field Case Study

SPE Journal ◽

10.2118/118879-pa ◽

2010 ◽

Vol 16 (02) ◽

pp. 307-317 ◽

Cited By ~ 22

Author(s):

Yanfen Zhang ◽

Dean S. Oliver

Keyword(s):

Kalman Filter ◽

Ensemble Kalman Filter ◽

History Matching ◽

Multiple Scales ◽

Gaussian Random Fields ◽

Rock Properties ◽

Real Field ◽

Production Data ◽

Reservoir Properties ◽

Water Cut

Summary The increased use of optimization in reservoir management has placed greater demands on the application of history matching to produce models that not only reproduce the historical production behavior but also preserve geological realism and quantify forecast uncertainty. Geological complexity and limited access to the subsurface typically result in a large uncertainty in reservoir properties and forecasts. However, there is a systematic tendency to underestimate such uncertainty, especially when rock properties are modeled using Gaussian random fields. In this paper, we address one important source of uncertainty: the uncertainty in regional trends by introducing stochastic trend coefficients. The multiscale parameters including trend coefficients and heterogeneities can be estimated using the ensemble Kalman filter (EnKF) for history matching. Multiscale heterogeneities are often important, especially in deepwater reservoirs, but are generally poorly represented in history matching. In this paper, we describe a method for representing and updating multiple scales of heterogeneity in the EnKF. We tested our method for updating these variables using production data from a deepwater field whose reservoir model has more than 200,000 unknown parameters. The match of reservoir simulator forecasts to real field data using a standard application of EnKF had not been entirely satisfactory because it was difficult to match the water cut of a main producer in the reservoir. None of the realizations of the reservoir exhibited water breakthrough using the standard parameterization method. By adding uncertainty in large-scale trends of reservoir properties, the ability to match the water cut and other production data was improved substantially. The results indicate that an improvement in the generation of the initial ensemble and in the variables describing the property fields gives an improved history match with plausible geology. The multiscale parameterization of property fields reduces the tendency to underestimate uncertainty while still providing reservoir models that match data.

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Factors Determining Commercially Optimal Development Strategies for CO2 Storage With and Without CO2-EOR

10.2172/1836589 ◽

2021 ◽

Author(s):

Mike Godec ◽

George Koperna ◽

Dave Riestenberg ◽

Gerald Hill ◽

Ben Wernette

Keyword(s):

Co2 Storage ◽

Development Strategies ◽

Optimal Development ◽

Co2 Eor

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Optimal Development Strategies in a Labor-Surplus Economy with Increasing Returns: Is Industrialization Desirable at All?

Environment and Planning A Economy and Space ◽

10.1068/a151151 ◽

1983 ◽

Vol 15 (9) ◽

pp. 1151-1159

Author(s):

T Miyao ◽

K Nishimura

Keyword(s):

Production Function ◽

Capital Stock ◽

Critical Value ◽

Development Strategies ◽

Increasing Returns ◽

Rigorous Proof ◽

Initial Capital ◽

Optimal Development ◽

Labor Surplus

The authors analyze the problem of optimal development strategies in a labor-surplus economy, where manufacturing production is subject to a convex-concave production function. Our contribution is to provide a rigorous proof of the existence of a critical value of capital such that industrialization is optimal if the initial stock of capital is above the critical value, whereas nonindustrialization is optimal if the initial capital stock is below the critical value.

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