Factors Affecting Hydraulically Fractured Well Performances in the Marcellus Shale Gas Reservoirs

2011 ◽  
Author(s):  
Tunde Adebowale Osholake ◽  
John Yilin Wang ◽  
Turgay Ertekin
Keyword(s):  
Shale Gas ◽  
Marcellus Shale ◽  
Gas Reservoirs ◽  
Factors Affecting ◽  
Shale Gas Reservoirs ◽  
Fractured Well

Factors Affecting Hydraulically Fractured Well Performance in the Marcellus Shale Gas Reservoirs

2012 ◽  
Vol 135 (1) ◽  
Author(s):  
Tunde Osholake ◽  
John Yilin Wang ◽  
Turgay Ertekin
Keyword(s):  
Hydraulic Fracturing ◽  
Shale Gas ◽  
Marcellus Shale ◽  
Operating Conditions ◽  
Gas Reservoirs ◽  
Factors Affecting ◽  
Reservoir Compaction ◽  
Multistage Hydraulic Fracturing ◽  
Shale Gas Reservoirs ◽  
Fracturing Process

Development of shale gas reservoirs has become an integral part of the North American gas supply. The Marcellus shale reservoir contains large untapped natural gas resources and its proximity to high demand markets along the East Coast of the United State makes it an attractive target for energy development. The economic viability of such unconventional gas development hinges on the effective stimulation of extremely low permeability reservoir rocks. Horizontal wells with multistage hydraulic fracturing technique are the stimulation method of choice and have been successful in shale gas reservoirs. However, the fundamental science and engineering of the process are yet to be fully understood and hence the protocol that needs to be followed in the stimulation process needs to be optimized. There are several factors affecting the hydraulic fracture treatment and the postfracture gas production in shale gas reservoirs. In this paper, we used numerical reservoir simulation techniques and quantified the effect of the following pertinent factors: multiphase flow, proppant crushing, proppant diagenesis, reservoir compaction, and operating conditions on the performance of the designed multistage hydraulic fracturing process. The knowledge generated in this study is expected to enable engineers to better design fracture treatments and operators to better manage the wells in the Marcellus shale gas reservoir.

Modeling Gas Adsorption in Marcellus Shale With Langmuir and BET Isotherms

SPE Journal ◽  
2016 ◽  
Vol 21 (02) ◽  
pp. 589-600 ◽  
Author(s):  
Wei Yu ◽  
Kamy Sepehrnoori ◽  
Tadeusz W. Patzek
Keyword(s):  
Shale Gas ◽  
Langmuir Isotherm ◽  
History Matching ◽  
Gas Adsorption ◽  
Marcellus Shale ◽  
Methane Adsorption ◽  
Gas Reservoirs ◽  
Gas Desorption ◽  
Shale Gas Reservoirs ◽  
Bet Isotherm

Summary Production from shale-gas reservoirs plays an important role in natural-gas supply in the United States. Horizontal drilling and multistage hydraulic fracturing are the two key enabling technologies for the economic development of these shale-gas reservoirs. It is believed that gas in shale reservoirs is mainly composed of free gas within fractures and pores and adsorbed gas in organic matter (kerogen). It is generally assumed in the literature that the monolayer Langmuir isotherm describes gas-adsorption behavior in shale-gas reservoirs. However, in this work, we analyzed four experimental measurements of methane adsorption from the Marcellus Shale core samples that deviate from the Langmuir isotherm, but obey the Brunauer-Emmett-Teller (BET) isotherm. To the best of our knowledge, it is the first time to find that methane adsorption in a shale-gas reservoir behaves similar to multilayer adsorption. Consequently, investigation of this specific gas-desorption effect is important for accurate evaluation of well performance and completion effectiveness in shale-gas reservoirs on the basis of the BET isotherm. The difference in calculating original gas in place (OGIP) on the basis of both isotherms is discussed. We also performed history matching with one production well from the Marcellus Shale and evaluated the contribution of gas desorption to the well's performance. History matching shows that gas adsorption obeying the BET isotherm contributes more to overall gas recovery than gas adsorption obeying the Langmuir isotherm, especially at early time in production. This work provides better understanding of gas desorption in shale-gas reservoirs and updates our current analytical and numerical models for simulation of shale-gas production.

scholarly journals Shale Gas Reservoirs Characterization: Marcellus Shale and Brazilian Potential

2015 ◽  
Vol 17 (2) ◽  
Author(s):  
Pamela Cardoso Vilela ◽  
Alexandre de Castro Leiras Gomes
Keyword(s):  
Shale Gas ◽  
Marcellus Shale ◽  
Gas Reservoirs ◽  
Shale Gas Reservoirs

Interpretation of fractures and joint inversion using multicomponent seismic data — Marcellus Shale example

2014 ◽  
Vol 2 (2) ◽  
pp. SE55-SE62 ◽  
Author(s):  
Shukun Yuan ◽  
Michael V. DeAngelo ◽  
Bob A. Hardage
Keyword(s):  
Shale Gas ◽  
Oil And Gas ◽  
Reservoir Characterization ◽  
Joint Inversion ◽  
Marcellus Shale ◽  
Natural Fracture ◽  
Gas Reservoirs ◽  
Horizontal Drilling ◽  
Multicomponent Seismic ◽  
Shale Gas Reservoirs

Evaluating and exploiting unconventional complex oil and gas reservoirs such as the Marcellus Shale gas reservoirs within the Appalachian Basin in Pennsylvania, USA, have gained considerable interest in recent years. Technologies such as conventional 3D seismic, horizontal drilling, and hydraulic fracturing have been at the forefront of the effort to exploit these resources. Recently, multicomponent seismic technologies have been integrated into some resource evaluation and reservoir characterization activities of low-permeability rock systems. We evaluated how multicomponent seismic technology provides value to reservoir characterization in shale gas exploration. We improved fault interpretations and natural fracture identifications by means of [Formula: see text] and [Formula: see text] integrated interpretation. In addition, using P-P-/P-SV-joint inversion, we extracted key parameters, such as [Formula: see text] ratio and density, that improve stratigraphic interpretation and rock-property descriptions of shale gas reservoirs.

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