The Research on Rational Proration to Low Yield and Pressure Gas Well in Tight Gas Reservoir

2012 ◽  
Vol 524-527 ◽  
pp. 1647-1650
Author(s):  
Deng Sheng Lei ◽  
Zhi Lin Qi
Keyword(s):  
Low Pressure ◽  
Gas Production ◽  
Low Permeability ◽  
Tight Gas ◽  
Gas Wells ◽  
Liquid Loading ◽  
Gas Reservoir ◽  
Gas Well ◽  
Factors Influencing ◽  
Tight Gas Reservoir

The rational proration is the prerequisite condition of realizing the high gas production and steady production of gas reservoir. Especially to the tight gas reservoir, due to the very low permeability, there are many low yield and low pressure gas wells. Because low yield and low pressure, the gas well is easily effected by the liquid loading and the change of working system, which cause the degree of reserve recovery decrease, more seriously make the gas stop producing directly. Based on the seepage rule in tight gas reservoir and analyzing the every factors influencing the production of low yield and pressure gas well, the low yield and pressure gas well have been classified to several types. And the gas well yields of different type have been optimized.

Liquid loading in wellbores and its effect on cleanup period and well productivity in tight gas sand reservoirs

2010 ◽  
Vol 50 (1) ◽  
pp. 559
Author(s):  
Hassan Bahrami ◽  
M Reza Rezaee ◽  
Vamegh Rasouli ◽  
Armin Hosseinian
Keyword(s):  
Numerical Simulation ◽  
Gas Production ◽  
Production Performance ◽  
Tight Gas ◽  
Gas Reservoirs ◽  
Liquid Loading ◽  
Performance Modelling ◽  
Well Productivity ◽  
Tight Gas Reservoirs ◽  
Tight Gas Reservoir

Tight gas reservoirs normally have production problems due to very low matrix permeability and significant damage during well drilling, completion, stimulation and production. Therefore they might not flow gas to surface at optimum rates without advanced production improvement techniques. After well stimulation and fracturing operations, invaded liquids such as filtrate will flow from the reservoir into the wellbore, as gas is produced during well cleanup. In addition, there might be production of condensate with gas. The produced liquids when loaded and re-circulated downhole in wellbores, can significantly reduce the gas production rate and well productivity in tight gas formations. This paper presents assessments of tight gas reservoir productivity issues related to liquid loading in wellbores using numerical simulation of multiphase flow in deviated and horizontal wells. A field example of production logging in a horizontal well is used to verify reliability of the numerical simulation model outputs. Well production performance modelling is also performed to quantitatively evaluate water loading in a typical tight gas well, and test the water unloading techniques that can improve the well productivity. The results indicate the effect of downhole liquid loading on well productivity in tight gas reservoirs. It also shows how well cleanup is sped up with the improved well productivity when downhole circulating liquids are lifted using the proposed methods.

Novel apparatus to measure the low-permeability and porosity in tight gas reservoir

2016 ◽  
Vol 142 ◽  
pp. 1-12 ◽  
Author(s):  
Hochang Jang ◽  
Wonsuk Lee ◽  
Junggyun Kim ◽  
Jeonghwan Lee
Keyword(s):  
Low Permeability ◽  
Tight Gas ◽  
Gas Reservoir ◽  
Tight Gas Reservoir

scholarly journals Multiphase Multicomponent Numerical Modeling for Hydraulic Fracturing with N-Heptane for Efficient Stimulation in a Tight Gas Reservoir of Germany

Energies ◽  
2021 ◽  
Vol 14 (11) ◽  
pp. 3111
Author(s):  
Faisal Mehmood ◽  
Michael Z. Hou ◽  
Jianxing Liao ◽  
Muhammad Haris ◽  
Cheng Cao ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Gas Production ◽  
Real Field ◽  
Fluid Viscosity ◽  
Tight Gas ◽  
Gas Reservoir ◽  
Hydraulic Stimulation ◽  
Fracture Closure ◽  
Tight Gas Reservoir ◽  
Water Based

Conventionally, high-pressure water-based fluids have been injected for hydraulic stimulation of unconventional petroleum resources such as tight gas reservoirs. Apart from improving productivity, water-based frac-fluids have caused environmental and technical issues. As a result, much of the interest has shifted towards alternative frac-fluids. In this regard, n-heptane, as an alternative frac-fluid, is proposed. It necessitates the development of a multi-phase and multi-component (MM) numerical simulator for hydraulic fracturing. Therefore fracture, MM fluid flow, and proppant transport models are implemented in a thermo-hydro-mechanical (THM) coupled FLAC3D-TMVOCMP framework. After verification, the model is applied to a real field case study for optimization of wellbore x in a tight gas reservoir using n-heptane as the frac-fluid. Sensitivity analysis is carried out to investigate the effect of important parameters, such as fluid viscosity, injection rate, reservoir permeability etc., on fracture geometry with the proposed fluid. The quicker fracture closure and flowback of n-heptane compared to water-based fluid is advantageous for better proppant placement, especially in the upper half of the fracture and the early start of natural gas production in tight reservoirs. Finally, fracture designs with a minimum dimensionless conductivity of 30 are proposed.

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