Corrigendum to "Shale gas production decline trend over time in the Barnett Shale" [J. Petrol. Sci. Eng. 165 (2018) 691–710]

AbstractPoland has been estimated to possess large volumes of technically recoverable shale gas resources, which has raised national hopes for increasing energy security and building export capacity. In this paper, we aim to examine political claims and hopes that Poland could achieve natural gas self-sufficiency and even become a gas exporter by harnessing domestic shale potential. We do so by relying on well-by-well production experience from the Barnett Shale in the USA to explore what scope of shale gas extraction, in terms of the number of wells, would likely be required to achieve such national expectations. With average well productivity equal to the Barnett Shale, at least 420 wells per year would be necessary to meet the domestic demand of 20 Bcm in 2030. Adding Poland’s potential export capacity of five Bcm of gas per year would necessitate at least 540 wells per year. Such a significant amount of drilling and hydraulic fracturing would require reconsideration and verification of national energy security plans and expectations surrounding shale gas production. A more informed public debate on technical aspects of extraction would be required, as extensive fracking operations could potentially have implications in terms of environmental risks and local land-use conflicts.

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Barnett Shale gas production, Fort Worth Basin: Issues and discussion

AAPG Bulletin ◽

10.1306/06190606018 ◽

2007 ◽

Vol 91 (4) ◽

pp. 523-533 ◽

Cited By ~ 344

Author(s):

Kent A. Bowker

Keyword(s):

Shale Gas ◽

Gas Production ◽

Barnett Shale ◽

Fort Worth ◽

Fort Worth Basin

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Well Screen and Optimal Time of Refracturing: A Barnett Shale Well

Journal of Petroleum Engineering ◽

10.1155/2013/817293 ◽

2013 ◽

Vol 2013 ◽

pp. 1-10 ◽

Cited By ~ 12

Author(s):

Shayan Tavassoli ◽

Wei Yu ◽

Farzam Javadpour ◽

Kamy Sepehrnoori

Keyword(s):

Numerical Simulation ◽

Shale Gas ◽

Fracture Network ◽

Gas Production ◽

Sensitivity Analyses ◽

Optimal Time ◽

Barnett Shale ◽

Vast Number ◽

Access To Data ◽

The Right

Gas-production decline in hydraulically fractured wells in shale formations necessitates refracturing. However, the vast number of wells in a field makes selection of the right well challenging. Additionally, the success of a refracturing job depends on the time to refracture a shale-gas well during its production life. In this paper we present a numerical simulation approach to development of a methodology for screening a well and to determine the optimal time of refracturing. We implemented our methodology for a well in the Barnett Shale, where we had access to data. The success of a refracturing job depends on reservoir characteristics and the initial induced fracture network. Systematic sensitivity analyses were performed so that the characteristics of a shale-gas horizontal well could be specified as to the possibility of its candidacy for a successful refracturing job. Different refracturing scenarios must be studied in detail so that the optimal design might be determined. Given the studied trends and implications for a production indicator, the optimal time for refracturing can then be suggested for the studied well. Numerical-simulation results indicate significant improvement (on the order of 30%) in estimated ultimate recovery (EUR) after refracturing, given presented screen criteria and optimal-time selection.

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Development of Shale Gas Prediction Models for Long-Term Production and Economics Based on Early Production Data in Barnett Reservoir

Energies ◽

10.3390/en13020424 ◽

2020 ◽

Vol 13 (2) ◽

pp. 424 ◽

Cited By ~ 2

Author(s):

Viet Nguyen-Le ◽

Hyundon Shin ◽

Edward Little

Keyword(s):

Shale Gas ◽

Net Present Value ◽

Prediction Models ◽

Input Parameter ◽

Gas Production ◽

Barnett Shale ◽

Production Data ◽

Production History ◽

Early Production

This study examined the relationship between the early production data and the long-term performance of shale gas wells, including the estimated ultimate recovery (EUR) and economics. The investigated early production data are peak gas production rate, 3-, 6-, 12-, 18-, and 24-month cumulative gas production (CGP). Based on production data analysis of 485 reservoir simulation datasets, CGP at 12 months (CGP_12m) was selected as a key input parameter to predict a long-term shale gas well’s performance in terms of the EUR and net present value (NPV) for a given well. The developed prediction models were then validated using the field production data from 164 wells which have more than 10 years of production history in Barnett Shale, USA. The validation results showed strong correlations between the predicted data and field data. This suggests that the proposed models can predict the shale gas production and economics reliably in Barnett shale area. Only a short history of production (one year) can be used to estimate the EUR and NPV of various production periods for a gas well. Moreover, the proposed prediction models are consistently applied for young wells with short production histories and lack of reservoir and hydraulic fracturing data.

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