scholarly journals Implementation of Hydraulic Fracturing Operation for a Reservoir in KRG

2019 ◽  
Vol 3 (2) ◽  
pp. 10-21
Author(s):  
Akram Humoodi ◽  
Maha Hamoudi ◽  
Rasan Sarbast
Keyword(s):  
Hydraulic Fracturing ◽  
Design Procedure ◽  
Oil Field ◽  
Fracture Conductivity ◽  
Fracture Width ◽  
Fracturing Process ◽  
Before And After ◽  
Fracture Height ◽  
Well Data ◽  
Field Formation

This study focuses on procedures to enhance permeability and flow rate for a low permeability formation by creating a conductive path using the hydraulic fracturing model. Well data are collected from the Qamchuqa KRG oil field formation. A Fracpro simulator is used for modelling the hydraulic fracturing process in an effective way. The study focuses on an effective hydraulic fracturing design procedure and the parameters affecting the fracture design. Optimum design of fracturing is achieved by selecting the proper fracturing fluid with a suitable proppant carried in a slurry, determining the formation fracturing pressure, selection of a fracture propagation fluid, and also a good proppant injection schedule, using a high pump rate and good viscosity. Permeability and conductivity are calculated before and after applying the hydraulic fracturing. Fracture height, length, and width are calculated from the Fracpro software, among other parameters, and the production rate changes. From the results, it is observed that by using hydraulic fracturing technology, production will increase and permeability will be much higher. The original formation permeability is 2.55 md, and after treatment, the average fracture conductivity has significantly increased to 1742.3 md-ft. The results showed that average fracture width is 0.187 inch. The proppant used in this treatment has a permeability of 122581 md. The suitable fluid choice is hyper with an apparent viscosity of 227.95 cp, and the proper proppant type is Brady sand with a conductivity of 2173.41 md-ft. Fracture orientation from the Khurmala oil field in Kurdistan is vertical fractures produced at a depth of 1868 m. Fracture half-length, total fracture height, and average fracture width are 220 ft, 42 ft, and 0.47 inch, respectively. After fracturing, the maximum and average area of fracture are 33.748 and 17.248 ft2, respectively. The recommended pump hydraulic horse power is 3200 HHP, and the total required fluid is 1076.3 bbl. In this study, hydraulic fracture is designed, and then, it has been analyzed after that production is optimized.

scholarly journals OPTIMISATION OF HYDRAULIC FRACTURING DESIGN IN LOWER OLIGOCENE RESERVOIR, KINH NGU TRANG OILFIELD

2018 ◽  
Vol 18 (3) ◽  
pp. 323-337
Author(s):  
Nguyen Huu Truong
Keyword(s):  
Hydraulic Fracturing ◽  
Complex Structure ◽  
Power Requirement ◽  
Fracture Conductivity ◽  
Fracture Width ◽  
The North ◽  
Fracture Closure ◽  
Average Water ◽  
White Tiger ◽  
Fracture Height

Kinh Ngu Trang oilfield is of the block 09-2/09 offshore Vietnam, which is located in the Cuu Long basin, the distance from that field to Port of Vung Tau is around 140 km and it is about 14 km from the north of Rang Dong oilfield of the block 15.2, and around 50 km from the east of White Tiger in the block 09.1. That block accounts for total area of 992 km2 with the average water depth of around 50 m to 70 m. The characteristic of Oligocene E reservoir is tight oil in sandstone, very complicated with complex structure. Therefore, the big challenges in this reservoir are the low permeability and the low porosity of around 0.2 md to less than 1 md and 1% to less than 13%, respectively, leading to very low fracture conductivity among the fractures. Through the Minifrac test for reservoir with reservoir depth from 3,501 mMD to 3,525 mMD, the total leak-off coefficient and fracture closure pressure were determined as 0.005 ft/min0.5 and 9,100 psi, respectively. To create new fracture dimensions, hydraulic fracturing stimulation has been used to stimulate this reservoir, including proppant selection and fluid selection, pump power requirement. In this article, the authors present optimisation of hydraulic fracturing design using unified fracture design, the results show that optimum fracture dimensions include fracture half-length, fracture width and fracture height of 216 m, 0.34 inches and 31 m, respectively when using proppant mass of 150,000 lbs of 20/40 ISP Carbolite Ceramic proppant.

scholarly journals Effect of Shale Anisotropy on Hydration and Its Implications for Water Uptake

Energies ◽  
2019 ◽  
Vol 12 (22) ◽  
pp. 4225
Author(s):  
Yunhu Lu ◽  
Lingping Zeng ◽  
Yan Jin ◽  
Guanglei Chen ◽  
Junfan Ren ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Water Uptake ◽  
Rock Interaction ◽  
Longmaxi Formation ◽  
Fracture Width ◽  
Flowback Water ◽  
Bedding Planes ◽  
Before And After ◽  
Shale Anisotropy

Water uptake induced by fluid–rock interaction plays a significant role in the recovery of flowback water during hydraulic fracturing. However, the existing accounts fail to fully acknowledge the significance of shale anisotropy on water uptake typically under in situ reservoir temperature. Thus we investigated the shale-hydration anisotropy using two sets of shale samples from the Longmaxi Formation in Sichuan Basin, China, which are designated to imbibe water parallel and perpendicular to shale bedding planes. All the samples were immersed in distilled water for one to five days at 80 °C or 120 °C. Furthermore, samples’ topographical and elemental variations before and after hydration were quantified using energy-dispersive spectroscopy–field-emission scanning electron microscopy. Our results show that shale anisotropy and imbibition time strongly affect the width of pre-existing micro-fracture in hydrated samples. For imbibition parallel to lamination, the width of pre-existing micro-fracture initially decreases and leads to crack-healing. Subsequently, the crack surfaces slightly collapse and the micro-fracture width is enlarged. In contrast, imbibition perpendicular to lamination does not generate new micro-fracture. Our results imply that during the flowback process of hydraulic fracturing fluid, the shale permeability parallel to bedding planes likely decreases first then increases, thereby promoting the water uptake.

The Study on Fractal Damage of Rock under Hydraulic Fracturing Basing on Conversation of Energy

2010 ◽  
Vol 29-32 ◽  
pp. 1363-1368 ◽  
Author(s):  
Wan Chun Zhao ◽  
Ting Ting Wang ◽  
Guo Shuai Ju ◽  
Da Chun Zheng
Keyword(s):  
Hydraulic Fracturing ◽  
Oil Field ◽  
Damage Variable ◽  
Rock Damage ◽  
Porosity Evolution ◽  
Variable Porosity ◽  
Fracturing Process ◽  
Fractal Characteristics ◽  
Damage Theory ◽  
Energy Conservation Principle

The fractal characteristics is Considered in rock porosity structure, and rock damage variable is defined by reduced amount pore number whose radius is greater than R during arbitrary fracturing stage. Assuming that the micro-fracturing process of evolution cracks meets Logistic bifurcation standard model, according to energy conservation principle, the model of hydraulic fracturing of rock damage and infiltration of evolution is established based on the porosity fractal damage theory. And then the hydraulic fracturing rock evolution model is built. Taking one well of any oil field as the example, rock damage variable, porosity evolution during fracturing process are calculated, which shows that the results are reasonable and accurate.

Integrated Hydraulic Fracture Geometry Evaluation Based on Pre-Cambrian Tight Silicylate Reservoir in South Oman Salt Basin

2022 ◽  
Author(s):  
Dmitrii Smirnov ◽  
Omar AL Isaee ◽  
Alexey Moiseenkov ◽  
Abdullah Al Hadhrami ◽  
Hilal Shabibi ◽  
...  
Keyword(s):  
Best Practices ◽  
Hydraulic Fracturing ◽  
Hydraulic Fracture ◽  
Hydraulic Fractures ◽  
Bond Quality ◽  
Fracture Geometry ◽  
Acoustic Anisotropy ◽  
Sonic Log ◽  
Before And After ◽  
Fracture Height

Abstract Pre-Cambrian South Oman tight silicilyte reservoirs are very challenging for the development due to poor permeability less than 0.1 mD and laminated texture. Successful hydraulic fracturing is a key for the long commercial production. One of the main parameter for frac planning and optimization is fracture geometry. The objective of this study was summarizing results comparison from different logging methods and recommended best practices for logging program targeting fracture geometry evaluation. The novel method in the region for hydraulic fracture height and orientation evaluation is cross-dipole cased hole acoustic logging. The method allows to evaluate fracture geometry based on the acoustic anisotropy changes after frac operations in the near wellbore area. The memory sonic log combined with the Gyro was acquired before and after frac operations in the cased hole. The acoustic data was compared with Spectral Noise log, Chemical and Radioactive tracers, Production Logging and pre-frac model. Extensive logging program allow to complete integrated evaluation, define methods limitations and advantages, summarize best practices and optimum logging program for the future wells. The challenges in combining memory cross-dipole sonic log and gyro in cased hole were effectively resolved. The acoustic anisotropy analysis successfully confirms stresses and predominant hydraulic fractures orientation. Fracture height was confirmed based on results from different logging methods. Tracers are well known method for the fracture height evaluation after hydraulic frac operations. The Spectral Noise log is perfect tool to evaluate hydraulically active fracture height in the near wellbore area. The combination of cased hole acoustic and noise logging methods is a powerful complex for hydraulic fracture geometry evaluation. The main limitations and challenges for sonic log are cement bond quality and hole conditions after frac operations. Noise log has limited depth of investigation. However, in combination with production and temperature logging provides reliable fit for purpose capabilities. The abilities of sonic anisotropy analysis for fracture height and hydraulic fracture orientation were confirmed. The optimum logging program for fracture geometry evaluation was defined and recommended for replication in projects were fracture geometry evaluation is required for hydraulic fracturing optimization.

Socio-Inspired Multi-Cohort Intelligence and Teaching-Learning-Based Optimization for Hydraulic Fracturing Parameters Design in Tight Formations

2021 ◽  
pp. 1-18
Author(s):  
Temoor Muther ◽  
Fahad Iqbal Syed ◽  
Amirmasoud Kalantari Dahaghi ◽  
Shahin Negahban
Keyword(s):  
Hydraulic Fracturing ◽  
High Performance ◽  
Local Maximum ◽  
Gas Production ◽  
Production Performance ◽  
Design Parameters ◽  
Fracture Conductivity ◽  
Fracture Width ◽  
Teaching Learning Based Optimization ◽  
Teaching Learning

Abstract Hydraulic fracturing is one of the revolutionary technologies widely applied to develop tight hydrocarbon reservoirs. Moreover, hydraulic fracture design optimization is an essential step to optimize production from tight reservoirs. This study presents the implementation of three new socio-inspired algorithms on hydraulic fracturing optimization. The work integrates reservoir simulation, artificial neural networks, and preceding optimization algorithms to attain the optimized fractures. For this study, a tight gas production dataset is initially generated numerically for a defined set of the fracture half-length, fracture height, fracture width, fracture conductivity, and the number of fractures' values. Secondly, the generated dataset is trained through a neural network to predict the effects of preceding parameters on gas production. Lastly, three new socio-inspired algorithms including Cohort Intelligence (CI), Multi-cohort Intelligence (Multi-CI), and Teaching Learning-based optimization (TLBO) are applied to the regressor output to obtain optimized gas production performance with the combination of optimum fracture design parameters. The results are then compared with the traditionally used optimizers including Particle Swarm Optimization (PSO) and Genetic Algorithm (GA). The results demonstrated that the Multi-CI and TLBO converge at the global best position more often with a success rate of atleast 95% as compared to CI, PSO, and GA. Moreover, the CI, PSO, and GA are found to stuck many times at the local maximum. This concludes that the Multi-CI and TLBO are good alternatives to PSO and GA considering their high performance in determining the optimum fracture design parameters, in comparison.

Controlling Fracture Height in Fracturing Effect Prediction of Oil Well Based on Uncertain Multi-Attribute Decision Making

2012 ◽  
Vol 457-458 ◽  
pp. 989-993 ◽  
Author(s):  
Jun Qi Wang ◽  
Ni Li
Keyword(s):  
Decision Making ◽  
Oil Field ◽  
Fluid Loss ◽  
Oil Well ◽  
Fluid Viscosity ◽  
Sudden Increase ◽  
Fracturing Process ◽  
Multi Attribute Decision Making ◽  
Fracture Height ◽  
Attribute Value

Hydraulic fracture to oil well, creating fracture in the bottom stratum, making the crude oil flow to the bottom along the fracture are common stimulation treatment used in oil field. Controlling fracture height fracturing is controlling the extension of fracture within oil layer area, which is the key to success or failure of hydraulic fracturing. Especially, controlling fracture height to avoid pressing to wear the near water layer, which causes a sudden increase of oil water production, is particularly important to oil production. Fracture extension theory and field practice indicate that in controlling fracture height fracturing process, the fracture height extension is related with reservoir stress difference of oil layer and adjacent barrier on a certain scale of construction also it is related with the 8 parameters such as the rock Young's modulus, fracture toughness, Poisson's ratio, permeability, reservoir thickness, fracturing fluid viscosity and fluid loss coefficient and so on. This study introduces uncertain multi-attribute decision making method to the well needing controlling fracture height fracturing, takes expected minimum fracture height as the target, concentrates the 8 attribute values of oil well with OWA operator, obtains comprehensive attribute value, and sorts the expected oil well fracturing effect according to the size of comprehensive attribute value, then selects construction well according to the sort results. In this way, it not only solves the difficulty to accurately resolve fracture height of analytical method and problem of large calculation of numerical method, also provides a simple and practical method for live well selection. According to fracturing selection of Changqing oil field 5 wells and on-site application comparison of 2 wells, it is consistent with the prediction result.

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