Design and assessment of a penile fracture simulation model

2021 ◽  
Author(s):  
A.A. Kozan ◽  
M. Logan ◽  
A. Parnham ◽  
M. Liew ◽  
B. Barrass ◽  
...  
Keyword(s):  
Simulation Model ◽  
Penile Fracture ◽  
Fracture Simulation

Fracture simulation model for API X80 Charpy test in Ductile-Brittle transition temperatures

2020 ◽  
Vol 182 ◽  
pp. 105771 ◽  
Author(s):  
Ji-Su Kim ◽  
Yun-Jae Kim ◽  
Myeong-Woo Lee ◽  
Ki-Seok Kim ◽  
Kazuki Shibanuma
Keyword(s):  
Simulation Model ◽  
Transition Temperatures ◽  
Charpy Test ◽  
Brittle Transition ◽  
Fracture Simulation

Developing a Tool for 3D Reservoir Simulation of Hydraulically Fractured Wells

2007 ◽  
Vol 10 (01) ◽  
pp. 50-59 ◽  
Author(s):  
Josef R. Shaoul ◽  
Aron Behr ◽  
George Mtchedlishvili
Keyword(s):  
Simulation Model ◽  
Reservoir Simulation ◽  
Hydraulic Fracture ◽  
Fracture Plane ◽  
Tight Gas ◽  
Fracture Conductivity ◽  
Fracture Width ◽  
Fracture Simulation ◽  
Reservoir Simulator ◽  
Actual Fracture

Summary This paper describes the development and capabilities of a novel and unique tool that interfaces a hydraulic fracture model and a reservoir simulator. This new tool is another step in improving both the efficiency and consistency of connecting hydraulic fracture engineering and reservoir engineering. The typical way to model hydraulically fractured wells in 3D reservoir simulators is to approximate the fracture behavior with a modified skin or productivity index (PI). Neither method captures all the important physics of flow into and through the fracture. This becomes even more critical in cases of multiphase flow and multilayered reservoirs. Modeling the cleanup phase following hydraulic fracture treatments can be very important in tight gas reservoirs, and this also requires a more detailed simulation of the fracture. Realistic modeling of horizontal wells with multiple hydraulic fractures is another capability that is needed in the industry. This capability requires more than an approximate description of the fracture(s) in the reservoir-simulation model. To achieve all the capabilities mentioned above, a new tool was developed within a commercial lumped 3D fracture-simulation model. This new tool enables significantly more accurate prediction of post-fracture performance with a commercial reservoir simulator. The automatically generated reservoir simulator input files represent the geometry and hydraulic properties of the reservoir, the fracture, the damaged zone around the fracture, and the initial pressure and filtrate fluid distribution in the reservoir. Consistency with the fracture-simulation inputs and outputs is assured because the software automatically transfers the information. High-permeability gridblocks that capture the 2D variation of the fracture conductivity within the reservoir simulator input files represent the fracture. If the fracture width used in the reservoir model is larger than the actual fracture width, the permeability and porosity of the fracture blocks are reduced to maintain the transmissibility and porous volume of the actual fracture. Both proppant and acid fracturing are handled with this approach. To capture the changes in fracture conductivity over time as the bottomhole flowing pressure (BHFP) changes, the pressure-dependent behavior of the fracture is passed to the reservoir simulator. Local grid refinement (LGR) is used in the region of the wellbore and the fracture tip, as well as in the blocks adjacent to the fracture plane. Using small gridblocks adjacent to the fracture plane is needed for an adequate representation of the filtrate-invaded zone using the leakoff depth distribution provided by the fracture simulator. The reservoir simulator input can be created for multiphase fluid systems with multiple layers and different permeabilities. In addition, different capillary pressure and relative permeability saturation functions for each layer are allowed. Introduction Historically, there have been three basic approaches commonly used for predicting the production from hydraulically fractured wells. First, analytic solutions were most commonly used, based on an infinite-conductivity or, later, a finite-conductivity fracture with a given half-length. This approach also was extended to cover horizontal multiple fractured wells (Basquet et al. 1999). With the development of reservoir simulators, two other approaches were developed. For complicated multiwell, multilayer, multiphase simulations (i.e., full-field models), the fracture stimulation was usually approximated as a negative skin. This is the same as increasing the effective wellbore radius in the simulation model. An alternate approach, developed initially for tight gas applications, was to develop a special-purpose numeric reservoir simulator that could explicitly model the flow in the fracture and take into account the special properties of the proppant, such as the stress-dependent permeability or the possibility of non-Darcy flow. Such models typically were limited to a single-layer, single-phase (oil or gas) situation.

Optimizing Production/Injection and Accelerating Recovery of Mature Field through Fracture Simulation Model

2005 ◽  
Author(s):  
Saad A. Al-Garni ◽  
Bevan Bun Wo Yuen ◽  
Nazih Farid Najjar ◽  
Stig Lyngra ◽  
Methgal Al-Shammari
Keyword(s):  
Simulation Model ◽  
Fracture Simulation ◽  
Mature Field

Effect of Multiple Fracture Initiation on the Accuracy of Hydraulic Fracturing Simulation

2020 ◽  
Author(s):  
Ziad Bennour ◽  
Walid Mohamed Mahmud ◽  
Mansur Ermila
Keyword(s):  
Hydraulic Fracturing ◽  
Simulation Model ◽  
Fracture Model ◽  
Single Fracture ◽  
Multiple Fractures ◽  
Actual Treatment ◽  
Fracture Simulation ◽  
Fracturing Process ◽  
Simulation Results ◽  
Actual Fracture

Abstract Hydraulic fracturing is a stimulation technique in which the formation is fractured using high pressure exerted by a fluid. The induced fracture increases the permeability of the formation by providing conductive channels to the formation which results in improved fluids productivity. Hydraulic fracturing is a common practice in oil and gas, particularly in the development of unconventional low porosity and low permeability reservoirs. However, as the hydraulic fracturing technique is costly, considerable preparations efforts must be made before executing the fracturing operation including simulating the intended fracture model. A simulation model of a hydraulic fracturing assists in forecasting and controlling the intended fractures that are to be induced. Although the simulation model can be helpful, it may not exactly mimic or predict the actual initiated fractures due to the complex nature of the actual fracturing process. Thus, the simulated model and the actual fracture might differ in many ways which results in an uncertainty in the simulated fracture model. Therefore, in order to reduce uncertainty, initial data input and assumptions made before and during the fracturing simulation need to be precise in order to obtain accurate simulation results. The growth of a single fracture is often assumed during the simulation of hydraulic fracturing which maybe incorrect as multiple fractures may initiate at the start or middle of the actual fracturing treatment and can have significant effect on the simulated fracturing results. This paper proposes a method to minimize the difference between fracturing simulation and actual fracture treatment results by utilizing sensitivity tests to the main fracturing parameters. Thus, the initial actual fracturing results were used to detect the occurrence of multiple fractures where the latter was considered to enhance the upcoming simulation accuracy of the proposed treatments. The analysis of high net pressure data during the actual treatment indicates the possible presence of multiple fractures where history matching between actual treatment and simulation results data can give an estimate on when and how many multiple fractures were initiated during the fracturing treatment. As a result, the data analysis showed that multiple fractures initiation had a significant effect on the fracture simulation results and the assumption of a single fracture during hydraulic fracturing should be discarded unless it is confirmed to be the case. Geological settings of the reservoir and the presence of natural fractures were also found to cause multiple fractures initiation during the treatments, and therefore, the reservoir data and description need to be determined properly before attempting the simulation of a fracturing treatment.

Optimizing Production/Injection and Accelerating Recovery of Mature Field through Fracture Simulation Model

2005 ◽  
Author(s):  
Saad A. Al-Garni ◽  
Bevan Bun Wo Yuen ◽  
Nazih Farid Najjar ◽  
Stig Lyngra ◽  
Methgal Al-Shammari
Keyword(s):  
Simulation Model ◽  
Fracture Simulation ◽  
Mature Field

946: Management of Penile Fracture in Men with Peyronie's Disease

2005 ◽  
Vol 173 (4S) ◽  
pp. 256-256
Author(s):  
Thomas X. Minor ◽  
Nadeem U. Rahman ◽  
Tom F. Lue
Keyword(s):  
Peyronie’S Disease ◽  
Penile Fracture ◽  
Peyronie's Disease
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