scholarly journals Modeling Gas Migration, Sustained Casing Pressure, and Surface Casing Vent Flow in Onshore Oil and Gas Wells

2019 ◽  
Vol 55 (1) ◽  
pp. 298-323 ◽  
Author(s):  
G. Lackey ◽  
H. Rajaram
Keyword(s):  
Oil And Gas ◽  
Gas Migration ◽  
Gas Wells ◽  
Oil And Gas Wells ◽  
Sustained Casing Pressure ◽  
Casing Pressure

Predicting gas migration through existing oil and gas wells

2018 ◽  
Vol 25 (4) ◽  
pp. 121-132 ◽  
Author(s):  
James A. Montague ◽  
George F. Pinder ◽  
Theresa L. Watson
Keyword(s):  
Oil And Gas ◽  
Gas Migration ◽  
Gas Wells ◽  
Oil And Gas Wells

scholarly journals A Prediction Model for Sustained Casing Pressure under the Effect of Gas Migration Variety

2019 ◽  
Vol 2019 ◽  
pp. 1-9
Author(s):  
Fuping Feng ◽  
Ziyuan Cong ◽  
Wuyi Shan ◽  
Chaoyang Hu ◽  
Maosen Yan ◽  
...  
Keyword(s):  
Reynolds Number ◽  
Prediction Model ◽  
Recovery Time ◽  
Oil And Gas ◽  
Pressure Recovery ◽  
Flow State ◽  
Gas Migration ◽  
Gas Leakage ◽  
Sustained Casing Pressure ◽  
Casing Pressure

Sustained casing pressure (SCP) is a challenge in the well integrity management in oil and gas fields around the world. The flow state of leaked gas will change when migrated up annulus protective fluid. To show the influence of gas migration on casing pressure recovery, a prediction model of SCP based on Reynolds number of bubbles was established. The casing pressure prediction of typical wells and the sensitivity analysis of casing pressure are performed. The results show that the casing pressure recovery time decreases with the increase of cement permeability. However, larger cement permeability has little effect on the casing pressure after stabilization. Increasing the height of annulus protective fluid reduces the stable casing pressure value and shortens the casing pressure recovery time. Compared with the existing models, the results show that the time of casing pressure recovery will be shortened by the change of gas migration, and the effect of bubbles Re < 1 on SCP will be greater. The new model can be used to detect and treat the SCP problem caused by small Reynolds number gas leakage.

scholarly journals Groundwater methane in relation to oil and gas development and shallow coal seams in the Denver-Julesburg Basin of Colorado

2016 ◽  
Vol 113 (30) ◽  
pp. 8391-8396 ◽  
Author(s):  
Owen A. Sherwood ◽  
Jessica D. Rogers ◽  
Greg Lackey ◽  
Troy L. Burke ◽  
Stephen G. Osborn ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Oil And Gas ◽  
High Volume ◽  
Geochemical Data ◽  
Gas Migration ◽  
Gas Wells ◽  
Coal Seams ◽  
Oil And Gas Development ◽  
Water Wells ◽  
Oil And Gas Wells

Unconventional oil and gas development has generated intense public concerns about potential impacts to groundwater quality. Specific pathways of contamination have been identified; however, overall rates of contamination remain ambiguous. We used an archive of geochemical data collected from 1988 to 2014 to determine the sources and occurrence of groundwater methane in the Denver-Julesburg Basin of northeastern Colorado. This 60,000-km2 region has a 60-y-long history of hydraulic fracturing, with horizontal drilling and high-volume hydraulic fracturing beginning in 2010. Of 924 sampled water wells in the basin, dissolved methane was detected in 593 wells at depths of 20–190 m. Based on carbon and hydrogen stable isotopes and gas molecular ratios, most of this methane was microbially generated, likely within shallow coal seams. A total of 42 water wells contained thermogenic stray gas originating from underlying oil and gas producing formations. Inadequate surface casing and leaks in production casing and wellhead seals in older, vertical oil and gas wells were identified as stray gas migration pathways. The rate of oil and gas wellbore failure was estimated as 0.06% of the 54,000 oil and gas wells in the basin (lower estimate) to 0.15% of the 20,700 wells in the area where stray gas contamination occurred (upper estimate) and has remained steady at about two cases per year since 2001. These results show that wellbore barrier failure, not high-volume hydraulic fracturing in horizontal wells, is the main cause of thermogenic stray gas migration in this oil- and gas-producing basin.

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