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Reservoir Simulation and Prediction of Gas, Oil and Coal Mine
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Reservoir Simulation and Prediction of Gas, Oil and Coal Mine

A special issue of Energies (ISSN 1996-1073). This special issue belongs to the section "H: Geo-Energy".

Deadline for manuscript submissions: closed (31 July 2019) | Viewed by 29633

Special Issue Editor

Prof. Dr. Rafiq Islam

E-Mail Website
Guest Editor
1. Petroleum Engineering, Dalhousie University, Halifax, NS, Canada
2. Emertec Research and Development Ltd., Halifax, Nova Scotia, Canada
Interests: reservoir engineering; petroleum exploration; gas enhanced oil recovery; drillingwell; drilling technology; petroleum economics; CO2 sequestration; crude oil

Special Issue Information

Dear Colleagues,

Reservoir simulation is the most powerful tool for estimating reserve as well as predicting reservoir performance.  However, serious limitations exist in the fundamentals of reservoir simulation when it comes to unconventional or complex reservoirs. Difficulties exist, from data acquisition to the applicability of governing equations and solution techniques. In reservoir simulation, the principle of GIGO (garbage in and garbage out) is well known.  This principle implies that the input data have to be accurate for the simulation results to be acceptable.  The petroleum industry has established itself as the pioneer of subsurface data collection. Historically, no other discipline has taken so much care in making sure input data are as accurate as the latest technology would allow. The recent superflux of technologies dealing with subsurface mapping, real-time monitoring, and high-speed data transfer supports the fact that input data in reservoir simulation are not the weak link of reservoir modeling. However, the areas that need to be developed are data filtering, data processing, appropriate governing equations (since Darcy’s law does not apply to most complex reservoirs), solutions techniques, handling heterogeneity, modeling unconventional reservoirs (including basement formations), and others. This Special Issue is dedicated to advancing the state of knowledge in the following topics:

  1. New solution techniques and improved accuracy
  2. The modeling of unconventional reservoirs
  3. Fracture modeling and reservoir characterization
  4. Advanced data filtering
  5. Basement reservoir modeling
  6. Non-Darcian flow modeling
  7. Fluid characterization
  8. Parallel processing and cloud modeling

Prof. Rafiq Islam
Guest Editor

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Keywords

  • Reservoir characterization
  • Unconventional oil and gas
  • Basement reservoir
  • Cloud modeling
  • Non-linear filters
  • Non-Darcian flow
  • Parallel computing
  • Tar sand
  • Fracture modeling
  • EOR modeling

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Published Papers (5 papers)

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Research

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16 pages, 8428 KiB  
Article
A Workflow for Optimization of Flow Control Devices in SAGD
by Anas Sidahmed, Siavash Nejadi and Alireza Nouri
Energies 2019, 12(17), 3237; https://doi.org/10.3390/en12173237 - 22 Aug 2019
Cited by 4 | Viewed by 3580
Abstract
In McMurray Formation, steam assisted gravity drainage is used as the primary in-situ recovery technique to recover oil sands. Different geological reservoir settings and long horizontal wells impose limitations and operational challenges on the implementation of steam-assisted gravity drainage (SAGD). The dual-string tubing [...] Read more.
In McMurray Formation, steam assisted gravity drainage is used as the primary in-situ recovery technique to recover oil sands. Different geological reservoir settings and long horizontal wells impose limitations and operational challenges on the implementation of steam-assisted gravity drainage (SAGD). The dual-string tubing system is the conventional completion scheme in SAGD. In complex reservoirs where dual-string completion cannot improve the operation performance, operators have adopted flow control devices (FCDs) to improve project economics. FCDs secure more injection/production points along the horizontal sections of the SAGD well pairs, hence, they maximize ultimate bitumen recovery and minimize cumulative steam-oil ratio (cSOR). This paper will focus on the optimization of outflow control devices (OCDs) in SAGD reservoirs with horizontal wellbore undulations. We present the detailed optimization workflow and show the optimization results for various scenarios with well pair trajectory undulation. Comparing the results of the optimized OCDs case with a dual-string case of the same SAGD model shows improvements in steam distribution, steam chamber growth, bitumen production, and net present value (NPV). Full article
(This article belongs to the Special Issue Reservoir Simulation and Prediction of Gas, Oil and Coal Mine)
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22 pages, 5671 KiB  
Article
Methane Emission during Gas and Rock Outburst on the Basis of the Unipore Model
by Skoczylas Norbert, Anna Pajdak, Katarzyna Kozieł and Leticia Teixeira Palla Braga
Energies 2019, 12(10), 1999; https://doi.org/10.3390/en12101999 - 24 May 2019
Cited by 13 | Viewed by 2716
Abstract
The goal of this paper is to analyze the phenomenon of gas emission during a methane and coal outburst based on the unipore Crank diffusion model for spherical grains and plane sheets. Two occurrences in the Upper Silesian Coal Basin were analyzed: an [...] Read more.
The goal of this paper is to analyze the phenomenon of gas emission during a methane and coal outburst based on the unipore Crank diffusion model for spherical grains and plane sheets. Two occurrences in the Upper Silesian Coal Basin were analyzed: an outburst in a Zofiówka coal mine in 2005 and an outburst in a Budryk coal mine in 2012. Those two outbursts differed considerably. The first one was connected with an unidentified tectonic disturbance in the form of a triple, interlocking fault, and the other one is an example of an outburst in an area free from tectonic disturbances. The model analysis required laboratory tests in order to determine the sorption properties of coals from post-outburst masses. Sorption isotherms and the values of the effective diffusion coefficient were specified. The post-outburst masses were subjected to sieve analysis and the grain composition curves were plotted. The researchers also used the measurement data provided by proper mine services, such as the methane content, the volume of post-outburst masses, and the time courses of CH4 concentration changes in excavations. They were recorded by methane measurement systems in the mines. Full article
(This article belongs to the Special Issue Reservoir Simulation and Prediction of Gas, Oil and Coal Mine)
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18 pages, 5514 KiB  
Article
Facies and the Architecture of Estuarine Tidal Bar in the Lower Cretaceous Mcmurray Formation, Central Athabasca Oil Sands, Alberta, Canada
by Mingming Tang, Kexin Zhang, Jixin Huang and Shuangfang Lu
Energies 2019, 12(9), 1769; https://doi.org/10.3390/en12091769 - 10 May 2019
Cited by 18 | Viewed by 5365
Abstract
In this study, data obtained from the Lower Cretaceous McMurray Formation in the central Athabasca Oil Sands, northeastern Alberta, Canada, are examined and used to establish the architecture of stacked fluvial and estuarine tidal bar deposits. A total of 13 distinguishable facies (F1–F7, [...] Read more.
In this study, data obtained from the Lower Cretaceous McMurray Formation in the central Athabasca Oil Sands, northeastern Alberta, Canada, are examined and used to establish the architecture of stacked fluvial and estuarine tidal bar deposits. A total of 13 distinguishable facies (F1–F7, F8a–F8b, and F9–F13) corresponding to stacked fluvial and estuarine deposits are recognized. These facies are then reassembled into four facies associations: fluvial deposits, tidal flat, tidal bar complex, and tidal bar cap. Of these, the lower fluvial deposits show a highly eroded channel lag and tidal influences in the cross-stratified sand and wavy interbeds. The fluvial deposits pass upwards into upper tidal-dominated tidal flats and a massive homogeneous tidal sand bar complex. Very thick tidal-influenced facies (F8a–F8b, up to 22 m) caused by semi-diurnal and semi-lunar cycles are also observed in tidal flats. Based on studies of the facies and facies associations, a three-dimensional (3-D) architecture model is finally established and used to analyze the internal distribution of the stacked fluvial and estuarine deposits. This is the first time that a 3-D model of the paleo-estuary tidal bar has been constructed. The results of this study will assist future research analyzing the architecture of stacked fluvial and estuarine deposits. Full article
(This article belongs to the Special Issue Reservoir Simulation and Prediction of Gas, Oil and Coal Mine)
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27 pages, 13267 KiB  
Article
3D-Basin Modeling of the Changling Depression, NE China: Exploring Petroleum Evolution in Deep Tight Sandstone Reservoirs
by Jinliang Zhang, Jiaqi Guo, Yang Li and Zhongqiang Sun
Energies 2019, 12(6), 1043; https://doi.org/10.3390/en12061043 - 18 Mar 2019
Cited by 6 | Viewed by 4212
Abstract
The Changling Depression is the largest and most resource-abundant reservoir in the South Songliao Basin, NE China. The petroleum evolution rules in the Lower Cretaceous deep tight sandstone reservoir are unclear. In this study, 3D basin modeling is performed to analyze the large-scale [...] Read more.
The Changling Depression is the largest and most resource-abundant reservoir in the South Songliao Basin, NE China. The petroleum evolution rules in the Lower Cretaceous deep tight sandstone reservoir are unclear. In this study, 3D basin modeling is performed to analyze the large-scale petroleum stereoscopic migration and accumulation history. The Changling Depression has a complex fault system and multiple tectonic movements. The model is calibrated by the present formation temperatures and observed maturity (vitrinite reflectance). We consider (1) three main erosion episodes during the burial history, one during the Early Cretaceous and two during the Late Cretaceous; (2) the regional heat flow distribution throughout geological history, which was calibrated by abundant measurement data; and (3) a tight sandstone porosity model, which is calibrated by experimental petrophysical parameters. The maturity levels of the Lower Cretaceous source rocks are reconstructed and showed good gas-generation potential. The highest maturity regions are in the southwestern sag and northern sag. The peak hydrocarbon generation period contributed little to the reservoir because of a lack of seal rocks. Homogenization temperature analysis of inclusions indicated two sets of critical moments of gas accumulation. The hydrocarbon filling in the Haerjin and Shuangtuozi structures occurred between 80 Ma and 66 Ma, while the Dalaoyefu and Fulongquan structures experienced long-term hydrocarbon accumulation from 100 Ma to 67 Ma. The homogenization temperatures of the fluid inclusions may indicate a certain stage of reservoir formation and, in combination with the hydrocarbon-accumulation simulation, can distinguish leakage and recharging events. Full article
(This article belongs to the Special Issue Reservoir Simulation and Prediction of Gas, Oil and Coal Mine)
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Review

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22 pages, 9488 KiB  
Review
Artificial Intelligence Applications in Reservoir Engineering: A Status Check
by Turgay Ertekin and Qian Sun
Energies 2019, 12(15), 2897; https://doi.org/10.3390/en12152897 - 27 Jul 2019
Cited by 72 | Viewed by 12420
Abstract
This article provides a comprehensive review of the state-of-art in the area of artificial intelligence applications to solve reservoir engineering problems. Research works including proxy model development, artificial-intelligence-assisted history-matching, project design, and optimization, etc. are presented to demonstrate the robustness of the intelligence [...] Read more.
This article provides a comprehensive review of the state-of-art in the area of artificial intelligence applications to solve reservoir engineering problems. Research works including proxy model development, artificial-intelligence-assisted history-matching, project design, and optimization, etc. are presented to demonstrate the robustness of the intelligence systems. The successes of the developments prove the advantages of the AI approaches in terms of high computational efficacy and strong learning capabilities. Thus, the implementation of intelligence models enables reservoir engineers to accomplish many challenging and time-intensive works more effectively. However, it is not yet astute to completely replace the conventional reservoir engineering models with intelligent systems, since the defects of the technology cannot be ignored. The trend of research and industrial practices of reservoir engineering area would be establishing a hand-shaking protocol between the conventional modeling and the intelligent systems. Taking advantages of both methods, more robust solutions could be obtained with significantly less computational overheads. Full article
(This article belongs to the Special Issue Reservoir Simulation and Prediction of Gas, Oil and Coal Mine)
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