Annular Velocity Enhancement With Gas Lift as a Deliquification Method for Tight Gas Wells With Long Completion Intervals

2010 ◽  
Author(s):  
Steven Anthony Pohler ◽  
William David Holmes ◽  
Stuart Cox
Keyword(s):  
Tight Gas ◽  
Gas Wells ◽  
Gas Lift ◽  
Velocity Enhancement

scholarly journals Energy Return on Energy Invested for Tight Gas Wells in the Appalachian Basin, United States of America

2011 ◽  
Vol 3 (10) ◽  
pp. 1986-2008 ◽  
Author(s):  
Bryan Sell ◽  
David Murphy ◽  
Charles A.S. Hall
Keyword(s):  
United States ◽  
United States Of America ◽  
Appalachian Basin ◽  
Tight Gas ◽  
Gas Wells

A New Approach for Reliable Estimation of Hydraulic Fracture Properties Using Elliptical Flow Data in Tight Gas Wells

2009 ◽  
Vol 12 (02) ◽  
pp. 254-262 ◽  
Author(s):  
Yueming Cheng ◽  
W. John Lee ◽  
Duane A. McVay
Keyword(s):  
Hydraulic Fracture ◽  
Finite Conductivity ◽  
Tight Gas ◽  
Well Test ◽  
Pressure Data ◽  
Gas Wells ◽  
New Approach ◽  
Fracture Properties ◽  
Elliptical Flow ◽  
Half Length

Summary Gas wells in low-permeability formations usually require hydraulic fracturing to be commercially viable. Pressure transient analysis in hydraulically fractured tight gas wells is commonly based on analysis of three flow regimes: bilinear, linear, and pseudoradial. Without the presence of pseudoradial flow, neither reservoir permeability nor fracture half-length can be independently estimated. In practice, as pseudoradial flow is often absent, the resulting estimation is uncertain and unreliable. On the other hand, elliptical flow, which exists between linear flow and pseudoradial flow, is of long duration (typically months to years). We can acquire much rate and pressure data during this flow regime, but no practical well test analysis technique is currently available to interpret these data. This paper presents a new approach to reliably estimate reservoir and hydraulic fracture properties from analysis of pressure data obtained during the elliptical flow period. The method is applicable to estimate fracture half-length, formation permeability, and skin factor independently for both infinite- and finite-conductivity fractures. It is iterative and features rapid convergence. The method can estimate formation permeability when pseudoradial flow does not exist. Coupled with stable deconvolution technology, which converts variable production-rate and pressure measurements into an equivalent constant-rate pressure drawdown test, this method can provide fracture-property estimates from readily available, noisy production data. We present synthetic and field examples to illustrate the procedures and demonstrate the validity and applicability of the proposed approach.

Gas Volumes in Place Estimation Method for Tight Gas Wells: Combining Formation Stress-sensitivity and Two-phase Flow

2015 ◽  
Author(s):  
Xiangji Dou ◽  
Xinwei Liao ◽  
Xiaofeng Li ◽  
Hongmei Liao ◽  
Xiangnan He ◽  
...  
Keyword(s):  
Two Phase Flow ◽  
Estimation Method ◽  
Stress Sensitivity ◽  
Phase Flow ◽  
Tight Gas ◽  
Gas Wells ◽  
Two Phase

Postbuildup Drawdown Analysis of Tight Gas Wells in the Rocky Mountains

1989 ◽  
Vol 4 (03) ◽  
pp. 288-296
Author(s):  
B.W. Hale ◽  
C.H. Firth ◽  
R.C. Hansen ◽  
M.J. Murphy ◽  
S.C. Woodcox
Keyword(s):  
Rocky Mountains ◽  
Tight Gas ◽  
Gas Wells

Well Completion for Effective Deliquification of Natural Gas Wells

2011 ◽  
Vol 134 (1) ◽  
Author(s):  
John Yilin Wang
Keyword(s):  
Natural Gas ◽  
Operating Cost ◽  
Gas Production ◽  
Gas Wells ◽  
Liquid Loading ◽  
Gas Recovery ◽  
Well Completion ◽  
Reservoir Permeability ◽  
Gas Fields ◽  
Gas Lift

Liquid loading has been a problem in natural gas wells for several decades. With gas fields becoming mature and gas production rates dropping below the critical rate, deliquification becomes more and more critical for continuous productivity and profitability of gas wells. Current methods for solving liquid loading in the wellbore include plunger lift, velocity string, surfactant, foam, well cycling, pumps, compression, swabbing, and gas lift. All these methods are to optimize the lifting of liquid up to surface, which increases the operating cost, onshore, and offshore. However, the near-wellbore liquid loading is critical but not well understood. Through numerical reservoir simulation studies, effect of liquid loading on gas productivity and recovery has been quantified in two aspects: backup pressure and near-wellbore liquid blocking by considering variable reservoir permeability, reservoir pressure, formation thickness, liquid production rate, and geology. Based on the new knowledge, we have developed well completion methods for effective deliquifications. These lead to better field operations and increased ultimate gas recovery.

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