Begell House Inc.
Journal of Porous Media
JPM
1091-028X
22
3
2019
APPLICATION OF IMAGE OVERLAPPING TECHNIQUE TO MULTI-PLANE VELOCITY MEASUREMENTS OF FLOWS IN A POROUS-LIKE CHANNEL
261-277
10.1615/JPorMedia.2019028840
Haoli
Wang
Institute of Flow Measurement and Simulation, China Jiliang University, Hangzhou, People's
Republic of China; School of Electrical Engineering, Jinling Institute of Technology, Nanjing, People's Republic of
China
Ming
Xu
School of Electrical Engineering, Jinling Institute of Technology, Nanjing, People's Republic of China
micro-PIV
image overlapping technique
porous-like channel
multi-plane 2D velocity
In large field-of-view measurements of micro-particle image velocimetry (micro-PIV), the depth of correlation (DOC)
will influence the accuracy of the velocity measurements. The image overlapping technique can effectively decrease the
DOC and improve the measurement accuracy of micro-PIV. In this study, the particle image overlapping technique
is applied to multi-plane 2D velocity measurements of flows in a porous-like channel with a micro-cylinder array.
The influences of additional displacement of the background particle images on the correlation peak displacement are
studied using synthetic particle images. The simulation results indicate that correlation peak displacement exists if the number of focal plane particles satisfies certain conditions. Reducing DOC by removing the background particle
images decreases the effect of the background particle images on the correlation peak displacement difference. Using the image overlapping technique, the velocity measurement accuracy was improved by background image removal, intensity threshold filtering, and image amplification to decrease the DOC. The 2D velocities on multi-fluid planes and the spatial averaged velocities estimated by the image overlapping technique are compared to those estimated by the correlation averaging technique. The results indicate that the velocity fields can reduce the measurement slip velocity and increase the peak velocity using the image overlapping technique.
DEVELOPMENT OF SCALING CRITERIA FOR WATERFLOODING AND IMMISCIBLE CO2 FLOODING IN TIGHT FORMATIONS
279-298
10.1615/JPorMedia.2019028940
Deyue
Zhou
Petroleum Systems Engineering, Faculty of Engineering and Applied Science, University of
Regina, Regina, Saskatchewan, Canada, S4S 0A2
Daoyong
Yang
Petroleum Systems Engineering, Faculty of Engineering and Applied Science, University of
Regina, Regina, Saskatchewan, Canada, S4S 0A2
Xiaoyan
Meng
Petroleum Systems Engineering, Faculty of Engineering and Applied Science, University of
Regina, Regina, Saskatchewan, Canada, S4S 0A2
scaling criteria
waterflooding
immiscible CO2 flooding
tight formation
displacement experiments
numerical simulation
Experimental studies on secondary and tertiary recovery processes in tight oil formations require a set of scaling criteria to scale them up to field dimension for either optimizing field production or designing displacement experiments. In this study, scaling criteria have been developed and validated to evaluate performance of waterflooding and immiscible CO2 flooding in tight formations by performing three-dimensional (3D) sandpacked displacements. Experimentally, waterflooding and immiscible CO2 flooding processes have been conducted with the 3D physical model, respectively. Continuous CO2 flooding results in a relatively low oil recovery with 33.8% of original-oil-in-place after 1.20 pore volume of CO2 injection. Theoretically, mathematical formulas have been developed for the corresponding processes on the basis of dimensional and inspectional analyses. Mass transfer from CO2 to oil by dissolution and diffusion has been considered in the inspectional analysis; for relaxation of the scaling criteria, gravitational force, viscous force, and dispersion and diffusion have been considered critical factors. The moderate water and CO2 injection rates (i.e., 2.0 cm3/min and 200.0 cm3/min for water and CO2, respectively) are ensured to result in a transverse diffusion-dominated flow, further simplifying the scaling group. The relaxed scaling group has been subsequently validated with the experimental measurements. Capillary force and geometric factors are found to be negligible when scaling up the 3D physical model to the prototype. There exists a reasonably good agreement between laboratory measurements and simulation results of a field production. By using the validated scaling criteria, displacement experiments in the 3D physical model can be properly designed to simulate waterflooding and immiscible CO2 injection in a targeted tight formation so as to design and optimize the field-scale exploitation processes.
PERFORMANCE ANALYSIS OF MULTI-FRACTURED HORIZONTAL WELLS WITH COMPLEX FRACTURE NETWORKS IN SHALE GAS RESERVOIRS
299-320
10.1615/JPorMedia.2019028826
Guanglong
Sheng
State Energy Center for Shale Oil Research and Development, Beijing, 100083, China; School of Petroleum Engineering, China University of Petroleum (East China), Shandong, 266580, China; Bureau of Economic Geology, Jackson School of Geosciences, University of Texas at Austin,
Austin, Texas, 78713, USA
Ting
Xu
State Energy Center for Shale Oil Research and Development, Beijing, 100083, China; Sinopec Petroleum Exploration and Production Research Institute, Beijing, 100083, China
Feifei
Gou
State Energy Center for Shale Oil Research and Development, Beijing, 100083, China; Sinopec Petroleum Exploration and Production Research Institute, Beijing, 100083, China
Yuliang
Su
School of Petroleum Engineering, China University of Petroleum (East China), No. 66 West Changjiang Road, Qingdao 266580,
China
Wendong
Wang
School of Petroleum Engineering, China University of Petroleum (East China), Shandong,
266580, China
Mingjing
Lu
School of Petroleum Engineering, China University of Petroleum (East China), Shandong,
266580, China
Shiyuan
Zhan
School of Petroleum Engineering, China University of Petroleum (East China), Shandong,
266580, China
shale gas reservoir
complex fracture networks
multiscale transport mechanisms
fractal diffusion equation
Shale gas reservoirs are composed of multiscale porous media and complex secondary fractures around hydraulic fractures,
and it is necessary to consider the effects of multiscale transport mechanisms and distribution of complex fracture
networks. In this paper, a fractal multiple porosity media (FMPM) model with a detailed description of complex fracture
networks was presented. In the proposed model, the fractal diffusion equation (FDE) was combined with a triple-media
model to describe complex fracture networks in the inner reservoir between two adjacent hydraulic fractures, and a
conventional dual-porosity model was used to describe the gas flow in the outer reservoir beyond the tips of hydraulic
fractures. Parameters of fracture networks were analyzed, and the results showed that the larger the fractal dimension
is, or the smaller the conductivity index of fracture networks is, the higher the production rate will be in the early-time flow period. The production rate difference between the inner reservoir and the outer reservoir slowly decreased as the development time was extended. The resulting curve calculated by the presented model was closer to the actual production than that of conventional models in the early period, which means that it could indicate the complexity of fracture networks around hydraulic fractures.
INCORPORATING GRAVITY DRAINAGE AND REIMBIBITION MECHANISMS IN TRADITIONAL MATERIAL BALANCE EQUATION FOR FRACTURED OIL RESERVOIRS: MATHEMATICAL MODELING AND SIMULATION ANALYSIS
321-342
10.1615/JPorMedia.2019019718
Negin
Rahmati
Petro Pars oil and gas company, Tehran, Iran
Mohammad-Reza
Rasaei
Institute of Petroleum Engineering, School of Chemical Engineering, College of Engineering,
University of Tehran, Iran
Farshid
Torabi
Petroleum Systems Engineering, Faculty of Engineering and Applied Science, University of
Regina, Regina, SK, S4S 0A2, Canada; Department of Petroleum Engineering, School of Chemical and Petroleum Engineering, Shiraz
University, Iran
Bahram
Dabir
Department of Chemical Engineering, Amir Kabir University of Technology, Tehran, Iran
fractured reservoirs
material balance equation
gas-oil contact level
gravity drainage
reimbibition
The contribution of gravity drainage as a main production mechanism in fractured reservoirs has not previously been
considered in the General Material Balance Equation (MBE). Although the traditional MBE for conventional oil and
gas reservoirs has been modified and applied to fractured reservoirs, none of them explicitly incorporated the Gravity
Drainage (GRD) mechanism. In this study, the MBE is reconstructed for fractured reservoirs to consider the effects of gravity drainage and reimbibition phenomena in the equation. This is realized using historical records of gas-oil contact level data in vertical fractures. The gravity drainage is numerically modeled in a series of synthetic cases (single matrix block and stacks of two and three matrix blocks), employing the finely gridded single porosity concept. A numerical computer program is developed to simulate the fluids' flow through the matrix and fracture system. Historical records of gas-oil contact in the vertical fractures, reservoir pressure, and production data are analyzed with the developed material balance equation to quantify the contribution of gravity drainage and all other active production mechanisms. Over 97% agreement is observed between the calculated oil production by gravity drainage based on our developed MBE and simulation results.
TRANSIENT PRODUCTION DECLINE BEHAVIOR ANALYSIS FOR A MULTI-FRACTURED HORIZONTAL WELL WITH DISCRETE FRACTURE NETWORKS IN SHALE GAS RESERVOIRS
343-361
10.1615/JPorMedia.2019028982
Mingqiang
Wei
State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum
University, Chengdu, 610500, Sichuan, China
Yonggang
Duan
State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum
University, Chengdu, 610500, Sichuan, China
Mingzhe
Dong
School of Petroleum Engineering, China University of Petroleum (East China), Qingdao
266580, People's Republic of China; Department of Chemical and Petroleum Engineering, Schulich School of Engineering, University of Calgary, 2500 University Drive NW, Calgary, Alberta T2N 1N4, Canada
Quantang
Fang
State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum
University, Chengdu, 610500, Sichuan, China
Morteza
Dejam
Department of Petroleum Engineering, College of Engineering and Applied Science, University
of Wyoming, 1000 E. University Avenue, Laramie, Wyoming 82071-2000, USA
shale gas
multi-fractured horizontal well
PEBI grid
discrete fracture network
type curves
Multi-fractured horizontal well (MFHW) is extensively applied to develop the shale gas reservoirs. After massive
fracturing, the complex fracture network will exist around the horizontal wellbore. To model the flow behavior more
rigorously, the fractures within the network should be represented explicitly rather than idealized as dual-porosity media around the wellbore. Thus, a conceptual model of discrete fracture network for MFHW is first constructed by using the unstructured perpendicular bisection (PEBI) grid. Then, a mathematical model considering the stress sensitivity of the reservoir permeability, Darcy flow, diffusion, and adsorption and desorption in shale gas reservoirs is developed and the numerical nonlinear production decline equations are derived and obtained. Subsequently, the model is verified by a simplified model and production decline curves for a MFHW with discrete fracture networks in shale gas reservoirs are plotted. Five flow regions including early formation linear flow, interference flow among discrete fracture networks,
compound pseudo-linear flow, pseudo radial flow, and pseudo-steady-state flow are identified. Finally, the sensitivity
studies for the eight related parameters are conducted on the production decline type curves, and the production decline type curves of the MFHW are verified by a field case study. This study can provide very meaningful references
for reservoir engineers to stimulate effectiveness and reservoir properties evaluation as well as production performance estimation of MFHW in shale gas reservoirs by matching the type curves with actual field data.
EVALUATING MODEL REDUCTION METHODS FOR HEAT AND MASS TRANSFER IN POROUS MATERIALS: PROPER ORTHOGONAL DECOMPOSITION AND PROPER GENERALIZED DECOMPOSITION
363-385
10.1615/JPorMedia.2019029049
Julien
Berger
Laboratoire des Sciences de l'Ingénieur pour l'Environnement (LaSIE), UMR 7356 CNRS, La
Rochelle Université, CNRS, 17000, La Rochelle, France
S.
Guernouti
Cerema, Dter Ouest, Nantes, France
M.
Woloszyn
Université Savoie Mont Blanc, CNRS, LOCIE, F-73000 Chambéry, France
model reduction method
proper generalized decomposition
proper orthogonal decomposition
heat and moisture transfer
This paper explores deeper the features of model reduction methods proper orthogonal decomposition (POD) and proper
generalized decomposition (PGD) applied to heat and moisture transfer in porous materials. The first method is an a
posteriori one and therefore requires a previous computation of the solution using the large original model to build
the reduced basis. The second one is a priori and does not need any previous computation. The reduced order model is
built straightforward. Both methods aim at approaching a high-dimensional model with a low-dimensional one. Their
efficiencies, in terms of accuracy, complexity reduction, and CPU time gains, are first discussed on a one-dimensional
case of nonlinear coupled heat and mass transfer. The reduced order models compute accurate solutions of the problem when compared to the large original model. They also offer interesting complexity reduction: around 97% for the POD and 88% for the PGD on the case study. In further sections, the robustness of the reduced order models are tested for different boundary conditions and materials. The POD method has lack of accuracy to compute the solution when these parameters differ from the ones used for the learning step. It is also shown that PGD resolution is particularly efficient to reduce the complexity of parametric problems.