An Integrated Approach for Planning of Multistage Hydraulic Fracturing in Low-Permeability Gas-Saturated Reservoirs with Natural Fractures

2019 ◽  
Author(s):  
Nikolay Pavlyukov ◽  
Ruslan Melikov ◽  
Valeriy Pavlov ◽  
Aleksandr Ptashniy ◽  
Anatoliy Stepanov ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Integrated Approach ◽  
Low Permeability ◽  
Natural Fractures ◽  
Multistage Hydraulic Fracturing

Experience in Optimizing the Location and Parameters of Multistage Hydraulic Fractures for a Multilateral Well Based on Reservoir Simulation

2021 ◽  
Author(s):  
Vil Syrtlanov ◽  
Yury Golovatskiy ◽  
Konstantin Chistikov ◽  
Dmitriy Bormashov
Keyword(s):  
Hydraulic Fracturing ◽  
Reservoir Simulation ◽  
Optimal Placement ◽  
Hydraulic Fractures ◽  
Low Permeability ◽  
Advantages And Disadvantages ◽  
Modeling Methods ◽  
Multistage Hydraulic Fracturing ◽  
Determination Of Parameters

Abstract This work presents the approaches used for the optimal placement and determination of parameters of hydraulic fractures in horizontal and multilateral wells in a low-permeability reservoir using various methods, including 3D modeling. The results of the production rate of a multilateral dualwellbore well are analyzed after the actual hydraulic fracturing performed on the basis of calculations. The advantages and disadvantages of modeling methods are evaluated, recommendations are given to improve the reliability of calculations for models with hydraulic fracturing (HF)/ multistage hydraulic fracturing (MHF).

scholarly journals The efficiency of gas injection into low-permeability multilayer hydrocarbon reservoirs

2021 ◽  
Vol 3 (10) ◽  
pp. 100-108
Author(s):  
Sudad H AL-Obaidi ◽  
Miel Hofmann ◽  
Falah H. Khalaf ◽  
Hiba H. Alwan
Keyword(s):  
Hydraulic Fracturing ◽  
Oil Recovery ◽  
Gas Injection ◽  
Oil Production ◽  
Recovery Factor ◽  
Low Permeability ◽  
Compositional Model ◽  
Multistage Hydraulic Fracturing ◽  
Low Permeability Reservoirs ◽  
Working Agent

The efficiency of gas injection for developing terrigenous deposits within a multilayer producing object is investigated in this article. According to the results of measurements of the 3D hydrodynamic compositional model, an assessment of the oil recovery factor was made. In the studied conditions, re-injection of the associated gas was found to be the most technologically efficient working agent. The factors contributing to the inefficacy of traditional methods of stimulating oil production such as multistage hydraulic fracturing when used to develop low-permeability reservoirs have been analyzed. The factors contributing to the inefficiency of traditional oil-production stimulation methods, such as multistage hydraulic fracturing, have been analysed when they are applied to low-permeability reservoirs. The use of a gas of various compositions is found to be more effective as a working agent for reservoirs with permeability less than 0.005 µm2. Ultimately, the selection of an agent for injection into the reservoir should be driven by the criteria that allow assessing the applicability of the method under specific geological and physical conditions. In multilayer production objects, gas injection efficiency is influenced by a number of factors, in addition to displacement, including the ratio of gas volumes, the degree to which pressure is maintained in each reservoir, as well as how the well is operated. With the increase in production rate from 60 to 90 m3 / day during the re-injection of produced hydrocarbon gas, this study found that the oil recovery factor increased from 0.190 to 0.229. The further increase in flow rate to 150 m3 / day, however, led to a faster gas breakthrough, a decrease in the amount of oil produced, and a decrease in the oil recovery factor to 0.19 Based on the results of the research, methods for stimulating the formation of low-permeability reservoirs were ranked based on their efficacy.

Integration of outcrop, subsurface, and microseismic interpretation for rock-mass characterization: An example from the Duvernay Formation, Western Canada

2018 ◽  
Vol 6 (4) ◽  
pp. T919-T936 ◽  
Author(s):  
Mason K. MacKay ◽  
David W. Eaton ◽  
Per K. Pedersen ◽  
Christopher R. Clarkson
Keyword(s):  
Rock Mass ◽  
Hydraulic Fracturing ◽  
Distinct Element ◽  
Integrated Approach ◽  
Natural Fracture ◽  
Western Canada ◽  
Natural Fractures ◽  
Data Set ◽  
Fracture Geometry ◽  
Rock Mass Characterization

Identifying and characterizing geomechanical domains is important for understanding how a reservoir will respond to hydraulic fracturing, including interaction with natural fractures to create new permeable pathways. We have used a rock-mass characterization approach, which describes the mechanical reservoir package by combining parameters of the intact rock, such as brittleness, with inferred geometry and density of natural fractures. Insights from outcrop observations are important to complement the interpretation of fracture geometry and density derived from subsurface data, to give a more complete understanding of natural fracture networks. This integrated approach is applied to a data set from the Duvernay play in Western Canada. A synthetic model of the subsurface reservoir is constructed using data from well logs, cores, and outcrop analogs. Numerical simulation of the response of the artificial rock mass to hydraulic fracturing is performed using a distinct element code. Independent validation of the model is obtained by achieving an agreement between the simulated microseismic response and the observed distribution of microseismicity during hydraulic fracturing.

A Case Study of High-Rate Multistage Hydraulic Fracturing in Petrikov Horizon of the Pripyat Trough

2021 ◽  
Author(s):  
Kirill Victorovich Mironenko ◽  
Oleg Leonidovich Voytekhin ◽  
Vladimir Vladimirovich Marchenko
Keyword(s):  
Hydraulic Fracturing ◽  
Sedimentary Cover ◽  
Effective Porosity ◽  
High Rate ◽  
Low Permeability ◽  
Resource Base ◽  
Oil Companies ◽  
Multistage Hydraulic Fracturing ◽  
Stage Of Development ◽  
The Republic

Abstract Currently, the vast majority of the oil fields of the Republic of Belarus are at the final stage of development. In this connection, in order to expand the resource base, Belarusian oil companies are assigned with the task of searching, exploring and developing hard-to-recover reserves. In recent years, a number of geological works have been carried out to search and study the sedimentary cover rocks of the Belarusian part of the Pripyat Trough, the results of these works were the discovery of promising deposits of the Petrikov Horizon of the Upper Devonian. These deposits are represented by dense fractured carbonate rocks with ultra-low permeability (less than 0.01 mD) and low effective porosity (up to 10%). The most promising technology for the development of such reservoirs is the drilling of horizontal wells and the subsequent implementation of Multistage hydraulic fracturing. This article presents the experience of developing ultra-low-permeability reservoirs in the Republic of Belarus in the period 2014-2021, briefly describes the main technologies used, the evolution of technological solutions for effective involvement in the active development of hard-to-recover reserves.

Challenges in modelling of hydraulic fracturing in low-permeability coal seams with complex cleat networks and stress regimes

2019 ◽  
Vol 59 (1) ◽  
pp. 166
Author(s):  
Mohammad Ali Aghighi ◽  
Raymond Johnson Jr. ◽  
Chris Leonardi
Keyword(s):  
Numerical Methods ◽  
Hydraulic Fracturing ◽  
Hydraulic Fracture ◽  
Fractured Reservoirs ◽  
Computational Cost ◽  
Naturally Fractured Reservoirs ◽  
Natural Fracture ◽  
Low Permeability ◽  
Natural Fractures ◽  
Fracture Development

Improved hydraulic fracturing models can better inform operational decisions regarding production from low-permeability coals and ultimately convert currently classified contingent resources to reserves. Improving current modelling approaches requires identification and investigation of the challenges involved in modelling hydraulic fracture stimulation in complex eastern Australian cases where permeability systems and stress regimes can vary significantly. This study investigated differences among existing and emerging advanced hydraulic fracture models and codes including numerical methods used to model fluid and rock behaviours during treatments; the ability to contextualise structure, behaviour and interaction of natural fractures with the propagating hydraulic fracture (e.g. cleat or natural fracture fabric, discrete fracture networks and pressure-dependent leak-off); and their capabilities in handling simultaneously growing or complex fracture development. One finding is that the new generation of models or codes that fully or partially use particle-based numerical methods are more capable in handling complexities associated with hydraulic stimulation of naturally fractured reservoirs. However, the computational cost and time for these models may cause concerns, particularly when modelling large reservoirs and treatments. Based on these limitations, many of the advanced, industry preferred, commercial hydraulic fracture simulators still choose to incorporate limited complexities with regard to natural fractures or represent them mathematically or implicitly. This investigation also indicates that most emerging models provide better representation of natural fractures, visualisation and integration into workflows for completion or stimulation design.

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