Integrated Workflow Towards Characterizing Hydraulic Fractures in Tight Gas Reservoirs-Modeling, Uncertainty Analysis, History Matching & Production Forecasting.

2013 ◽  
Author(s):  
Tony Thomas ◽  
Natela Belova ◽  
Andrey Goloborodko
Keyword(s):  
Uncertainty Analysis ◽  
History Matching ◽  
Hydraulic Fractures ◽  
Tight Gas ◽  
Gas Reservoirs ◽  
Tight Gas Reservoirs ◽  
Modeling Uncertainty ◽  
Production Forecasting

The effect of hydraulic-fracture parameters on the welltest response of multi-fractured tight-gas reservoirs

2013 ◽  
Vol 53 (1) ◽  
pp. 375
Author(s):  
Chaolang Qiu ◽  
Mofazzal Hossain ◽  
Hassan Bahrami ◽  
Yangfan Lu
Keyword(s):  
Hydraulic Fracture ◽  
Transient Flow ◽  
Hydraulic Fractures ◽  
Tight Gas ◽  
Gas Reservoirs ◽  
Pressure Derivative ◽  
Unconventional Gas ◽  
Tight Gas Reservoirs ◽  
Fracture Parameters ◽  
Unconventional Gas Reservoirs

With the reduction of conventional reserves, the demand and exploration of unconventional sources becomes increasingly important in the energy supply system. Low permeability, low porosity, and the complexities of rock formation in unconventional gas reservoirs make it difficult to extract commercially viable gas resources. Hydraulic fracture is the most common technique used for commercial production of hydrocarbon resources from unconventional tight-gas reservoirs. Due to the existence of an extremely long transient-flow period in tight-gas reservoirs, the interpretation of welltest data based on conventional welltest analysis is quite challenging, and could potentially lead to misleading results. This peer-reviewed paper presents a new approach based on a log-log reciprocal rate derivative plot. Emphases are given on the identification of factors affecting the welltest response in multiple hydraulic-fractured wells in unconventional gas reservoirs based on numerical simulation. The objective is to investigate the sensitivity of various reservoir and hydraulic-fracture parameters, such as multiple hydraulic-fracture size, fracture number and fracture orientation on welltest response, and the effect of the pressure derivative curve on the slopes of welltest diagnostic plots, as well as on well productivity performance. The results can be used to understand the welltest response for different hydraulic-fracturing scenarios for the efficiency and characteristics of hydraulic fractures.

Effect of sand lens size and hydraulic fractures orientation on tight gas reservoirs ultimate recovery

2012 ◽  
Author(s):  
Narisara Kantanong ◽  
Hassan Bahrami ◽  
Reza Rezaee ◽  
Md Mofazzal Hossain ◽  
Amir Nasiri
Keyword(s):  
Hydraulic Fractures ◽  
Tight Gas ◽  
Gas Reservoirs ◽  
Tight Gas Reservoirs

Thermally Controlled Fluid to Reduce Formation Breakdown Pressures in Tight Gas Reservoirs

2021 ◽  
Author(s):  
Misfer J Almarri ◽  
Murtadha J AlTammar ◽  
Khalid M Alruwaili ◽  
Shuang Zheng
Keyword(s):  
Cost Effective ◽  
Hydraulic Fractures ◽  
Tight Gas ◽  
Effective Solution ◽  
Gas Reservoirs ◽  
Breakdown Pressure ◽  
Tight Gas Reservoirs ◽  
Tight Gas Reservoir ◽  
Oil Flow ◽  
Reservoir Simulator

Abstract High breakdown pressure is one of the major challenges in deep tight gas reservoirs. In certain wells, achieving breakdown pressures within the completion tubular yield limit is not possible, and those zones may have to be abandoned without fracturing. Using thermally controlled fluid can lower the formation temperature and ultimately reduce the stresses of the tight gas reservoir formation near the wellbore. The objective of this study is to prove numerically that having a cooled near-wellbore region is a feasible and effective solution to reduce the breakdown pressure. An integrated hydraulic fracturing and reservoir simulator that has been developed at the University of Texas at Austin is utilized for this study. The simulator is a non-isothermal, multi-phase black-oil flow in reservoir, fracture, and wellbore domains. It was found that using thermally controlled fluid is effective in reducing breakdown pressure. Bottomhole Pressure (BHP) decreased by up to around 60% when the temperature of the near-wellbore region is reduced by 60 °F under the simulated conditions in this study. Injecting thermally controlled fluid did not only reduce the high breakdown pressure but also improve the hydraulic fractures efficiency and complexity. This technique is novel and has not been studied in depth in the literature. Utilizing thermally controlled fluid can be a cost effective solution to reduce high breakdown pressure in tight gas reservoirs.

scholarly journals Analysis on the effect of different fracture geometries on the productivity of tight gas reservoirs

2020 ◽  
Vol 16 (2) ◽  
pp. 201-211
Author(s):  
Temoor Muther ◽  
Adnan Aftab Nizamani ◽  
Abdul Razak Ismail
Keyword(s):  
Hydraulic Fracture ◽  
Constant Width ◽  
Hydraulic Fractures ◽  
Tight Gas ◽  
Gas Reservoirs ◽  
Fracture Geometry ◽  
Tight Gas Reservoirs ◽  
Constant Height ◽  
Tight Gas Reservoir ◽  
Half Length

Tight gas reservoirs are unconventional reservoir assets which have been the focus of major research in the petroleum industry owing to the global decline in conventional reservoirs. They are widely unlocked by creating hydraulic fractures in the formation to increase the flow capacity and productivity. The objective of this paper is to analyze different fracture geometries and their effect on tight gas production. The reservoir simulation model of the tight gas reservoir has been built with single porosity approach. A single vertical well with a single stage fracture has been used in the model to predict the behavior of fracture geometry. The major parameters of fracture geometry studied are fracture half-length, fracture width, and fracture height. Four sensitivities are run over different fracture geometry that is constant height and constant width, constant height and changing width, changing height and constant width, and changing height and changing width, while increasing the fracture half-length from 100 ft to 500 ft in each case. Sensitivity analysis exhibited that keeping the hydraulic fracture at constant height and constant width while increasing the fracture half-length resulted in enhanced tight gas productivity i.e. 11.63%, 14.14%, 16.06%, 17.48%, and 18.89% at hydraulic fracture half-lengths of 100 ft, 200 ft, 300 ft, 400 ft, and 500 ft, respectively, compared to other types of fracture geometry.

Data Acquistion and Formation Evaluation Strategies in Anistrospic, Tight Gas Reservoirs

2008 ◽  
Author(s):  
Hans de Koningh ◽  
Bernd Heinrich Herold ◽  
Koksal Cig ◽  
Fahd Ali ◽  
Sultan Mahruqy ◽  
...  
Keyword(s):  
Tight Gas ◽  
Gas Reservoirs ◽  
Tight Gas Reservoirs ◽  
Formation Evaluation ◽  
Evaluation Strategies ◽  
Data Acquistion
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