Deciphering Well Performance of Hydraulically Fractured Tight Gas Wells Through Work-Flow Based Study

2017 ◽  
Author(s):  
Arshad Waheed ◽  
Sonny Irvana ◽  
Ali Habbar ◽  
Abdoerrias M. Noer
Keyword(s):  
Work Flow ◽  
Tight Gas ◽  
Well Performance ◽  
Gas Wells

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.

Beyond Volumetrics: Unconventional Petrophysics for Efficient Resource Appraisal (Example from the Khazzan Field, Sultanate of Oman)

2015 ◽  
Author(s):  
David R. Spain ◽  
German D. Merletti ◽  
William Dawson
Keyword(s):  
Gas Permeability ◽  
Stress Profile ◽  
Tight Gas ◽  
Well Performance ◽  
Flow Properties ◽  
Dynamic Flow ◽  
Stress Regime ◽  
Flow Units ◽  
Fluid Saturation ◽  
Rock Typing

Abstract The Middle East region holds substantial resources of unconventional tight gas and shale gas. The efficient extraction of these resources requires significant technology and expertise across numerous disciplines, including reservoir description and geomechanical characterization, hydraulic fracture modelling and design, advanced numerical simulation capabilities, sensor and surveillance technologies, and tightly integrated workflows. The effective application of these integrated subsurface and completion workflows leads to improved capital efficiency and well performance through increased well potential, increased ultimate recovery, and reduced costs. Key elements include dynamic rock typing to highlight potential flow units that will maximize gas deliverability, geomechanical modelling to provide a calibrated stress profile, and an integrated model that demonstrates the importance of understanding both dynamic flow properties and geomechanical response in complex tectonic environments. Dynamic rock typing focuses on using both depositional and petrophysical properties including rock type, porosity, and effective gas permeability at reservoir conditions to divide the reservoir into flow units in the context of their saturation history. The geomechanical profiling generates a tectonics-corrected minimum horizontal stress (SHmin) and the net confining stress (NCS). The rock-log-test calibration requires the evaluation and integration of subsurface fracture tests, including After-Closure Analysis (ACA), Data Fracs and Micro Fracs. All three involve different injection volumes and sampled reservoir volumes. Tight gas petrophysical studies must go “beyond volumetrics”, and should consider not only the static (storage) and dynamic (flow) properties within the context of the petroleum system and evolution of the current day pore geometry and fluid saturation distribution, but also the geomechanical stress regime and its implications for efficient completion optimization. Alternative interpretations test the range of uncertainty and are useful in designing field trials and surveillance strategies to reduce the subsurface uncertainty and to mitigate development risks.

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
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