Effectiveness of five soil reclamation and reforestation techniques on oil and gas well sites in northeastern British Columbia

2012 ◽  
Vol 92 (1) ◽  
pp. 165-177 ◽  
Author(s):  
Trevor McConkey ◽  
Chuck Bulmer ◽  
Paul Sanborn
Keyword(s):  
British Columbia ◽  
Bulk Density ◽  
Physical Condition ◽  
Oil And Gas ◽  
Wood Chip ◽  
Soil Reclamation ◽  
Mechanical Resistance ◽  
Gas Well ◽  
Large Variability ◽  
Least Limiting Water Range

McConkey, T., Bulmer, C. and Sanborn, P. 2012. Effectiveness of five soil reclamation and reforestation techniques on oil and gas well sites in northeastern British Columbia. Can. J. Soil Sci. 92: 165–177. Techniques developed for forestry landing reclamation were applied to five oil and gas well sites in northeastern British Columbia to ameliorate soil and facilitate reforestation. Treatments implemented in fall 2003 and spring 2004 were tillage, wood chip mulch, tillage+wood chip mulch, tillage+incorporated wood chips, brush mats and a control. Lodgepole pine (Pinus contorta var. latifolia) and white spruce (Picea glauca) seedlings were planted. Soil and vegetation were assessed (bulk density, soil mechanical resistance, water content, air filled porosity, water retention, least limiting water range, nutrient availability, seedling survival and growth) throughout 2004 and 2005 growing seasons. Tillage improved soil physical condition, reducing soil mechanical resistance and bulk density; treatments did not affect soil chemical properties. Treatments did not significantly affect species survival; after 6 yr, spruce height and root collar diameter improved with tillage but treatments did not affect pine. Brush mats led to increased spruce growth. Regression relationships between tree performance and soil condition were significant, but generally did not explain large variability. More elaborate soil physical condition measures were no better than bulk density for predicting seedling performance, but relative bulk density and least limiting water range may be useful for evaluating soil productivity.

Long-term grazing effects on grassland soil properties in southern British Columbia

2012 ◽  
Vol 92 (4) ◽  
pp. 685-693 ◽  
Author(s):  
C. R. W. Evans ◽  
M. Krzic ◽  
K. Broersma ◽  
D. J. Thompson
Keyword(s):  
British Columbia ◽  
Soil Properties ◽  
Bulk Density ◽  
Aggregate Stability ◽  
Soil Bulk Density ◽  
Mechanical Resistance ◽  
Stocking Rate ◽  
Grassland Soil ◽  
Grazing Effects

Evans, C. R. W., Krzic, M., Broersma, K. and Thompson, D. J. 2012. Long-term grazing effects on grassland soil properties in southern British Columbia. Can. J. Soil Sci. 92: 685–693. Although grazing effects on soil properties have been evaluated on various temperate grasslands, no study has dealt with these effects in the southern interior of British Columbia. The objective of this study was to determine the effects of spring versus fall season grazing as well as grazing [at a moderate rate of 0.6 animal unit months (AUM) ha−1] versus non-grazing by beef cattle on selected soil properties. Effects were determined 20 and 30 yr after the establishment of the field experiment. Soil properties were determined for the 0- to 7.5-cm, 7.5- to 15-cm, and 15- to 30-cm depths. In comparison with fall grazing, spring grazing had greater soil bulk density, greater mechanical resistance within the top 15 cm of the soil profile, higher pH, and lower polysaccharides. This was true for both 20 and 30 yr of treatment. Grazing effects on aggregate stability were observed only after 30 yr with spring grazing leading to a more stable structure with a mean weight diameter (MWD) of 1.5 mm and 32% and 10% of aggregates in the 2- to 6-mm and 1- to 2-mm size fractions, respectively, compared with a MWD of 1.0 mm and 20% and 6% under fall grazing. Greater soil bulk density, mechanical resistance, and pH were observed under the grazed treatment relative to the control without grazing, but as we used a moderate stocking rate the impacts were not as great as in previous studies, which used heavy stocking rates. Our findings show that long-term grazing at a moderate stocking rate of 0.6 AUM ha−1did not have critical detrimental effects on soil properties as some land managers and ranchers have suggested.

scholarly journals A portrait of wellbore leakage in northeastern British Columbia, Canada

2019 ◽  
Vol 117 (2) ◽  
pp. 913-922 ◽  
Author(s):  
Joshua Wisen ◽  
Romain Chesnaux ◽  
John Werring ◽  
Gilles Wendling ◽  
Paul Baudron ◽  
...  
Keyword(s):  
British Columbia ◽  
Oil And Gas ◽  
Ghg Emissions ◽  
Aquifer Contamination ◽  
Gas Well ◽  
Test Population ◽  
Abandoned Wells ◽  
Well Leakage ◽  
Incident Rates

Oil and gas well leakage is of public concern primarily due to the perceived risks of aquifer contamination and greenhouse gas (GHG) emissions. This study examined well leakage data from the British Columbia Oil and Gas Commission (BC OGC) to identify leakage pathways and initially quantify incident rates of leakage and GHG emissions from leaking wells. Three types of leakage are distinguished: “surface casing vent flow” (SCVF), “outside the surface casing leakage” (OSCL), and “cap leakage” (CL). In British Columbia (BC), the majority of reported incidents involve SCVF of gases, which does not pose a risk of aquifer contamination but does contribute to GHG emissions. Reported liquid leakage of brines and hydrocarbons is rarer. OSCL and CL of gas are more serious problems due to the risk of long-term leakage from abandoned wells; some were reported to be leaking gas several decades after they were permanently abandoned. According to the requirements of provincial regulation, 21,525 have been tested for leakage. In total, 2,329 wells in BC have had reported leakage during the lifetime of the well. This represents 10.8% of all wells in the assumed test population. However, it seems likely that wells drilled and/or abandoned before 2010 have unreported leakage. In BC, the total GHG emission from gas SCVF is estimated to reach about 75,000 t/y based on the existing inventory calculation; however, this number is likely higher due to underreporting.

Mapping Quaternary paleovalleys and drift thickness using petrophysical logs, northeast British Columbia, Fontas map sheet, NTS 94IThis article is one of a selection of papers published in this Special Issue on the theme Geology of northeastern British Columbia and northwestern Alberta: diamonds, shallow gas, gravel, and glaciers.

2008 ◽  
Vol 45 (5) ◽  
pp. 577-591 ◽  
Author(s):  
Adrian S. Hickin ◽  
Ben Kerr ◽  
Derek G. Turner ◽  
Tom E. Barchyn
Keyword(s):  
British Columbia ◽  
Oil And Gas ◽  
Special Issue ◽  
Quaternary Sediments ◽  
Shallow Gas ◽  
Gas Well ◽  
Well Drilling ◽  
Bedrock Topography ◽  
Petrophysical Logs ◽  
Selection Of

The relatively subdued topography of British Columbia’s northern interior plains does not reflect the irregular, buried bedrock surface. Many areas have been deeply incised by preglacial rivers that have subsequently filled with a succession of Quaternary sediments. In this study, oil and gas petrophysical logs, drill chip samples, water well logs, and surficial and bedrock outcrop maps were used to model the bedrock topography of the Fontas map sheet (NTS 94I). The modelled data produced several depressions that are interpreted to be paleovalleys incised into the soft Cretaceous shale of the Fort St. John Group. Understanding the geometry, thickness, and stratigraphy of the drift has considerable safety and resource management implications as artesian aquifers and natural gas were encountered in the drift during oil and gas well drilling. Four major paleovalleys are suggested. The most dominant paleovalley (Kotcho–Hoffard Paleovalley) is located south of the Etsho Plateau and trends west-southwest across the map area. A second depression occurs within the loop of the Hay River and may be a tributary of the Kotcho–Hoffard Paleovalley that links with the Rainbow Paleovalley in Alberta. A third paleovalley is mapped south of the Sahtaneh River (Kyklo Creek Paleovalley) and is either a tributary to, or crosscuts the Kotcho–Hoffard Paleovalley. The Niteal Creek Paleovalley is located between the Fontas and Sikanni Chief rivers. Its geometry is speculative as there are sparse data, but it may be a tributary of the Kotcho–Hoffard Paleovalley.

Potential of recovering elements from produced water at oil and gas fields, British Columbia, Canada

CIM Journal ◽  
2018 ◽  
Vol 9 (4) ◽  
pp. 195-214
Author(s):  
G. J. Simandl ◽  
C. Akam ◽  
M. Yakimoski ◽  
D. Richardson ◽  
A. Teucher ◽  
...  
Keyword(s):  
British Columbia ◽  
Oil And Gas ◽  
Produced Water ◽  
Oil And Gas Fields ◽  
Gas Fields

scholarly journals Oil and gas well drilling technology based on the system approaches and the results of application

2021 ◽  
Vol 1064 (1) ◽  
pp. 012059
Author(s):  
R R Gazizov ◽  
A P Chizhov ◽  
V E Andreev ◽  
A V Chibisov ◽  
V V Mukhametshin ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Gas Well ◽  
Well Drilling ◽  
Drilling Technology ◽  
System Approaches

Analysis and Comparison of Seal Ability of Premium Tubing Connections under Axial Alternating Load

2013 ◽  
Vol 423-426 ◽  
pp. 2035-2039
Author(s):  
Long Cang Huang ◽  
Yin Ping Cao ◽  
Yang Yu ◽  
Yi Hua Dou
Keyword(s):  
Contact Pressure ◽  
Oil And Gas ◽  
Element Analysis ◽  
Gas Well ◽  
Cycle Number ◽  
Compression Load ◽  
Well Production ◽  
Maximum Contact ◽  
Contact Pressures ◽  
Better Than

In the process of oil and gas well production, tubing connection stand the axial alternating load during open well, shut well and fluid flow. In order to know premium connection seal ability under the loading, two types of P110 88.9mmx6.45mm premium tubing connections which called A connection and B connection are performed with finite element analysis, in which contact pressures and their the regularities distribution on sealing surface are analyzed. The results show that with the increasing of cycle number, the maximum contact pressures on sealing surface of both A connection and B connection are decreased. The decreasing of the maximum contact pressures on B connection is greater than those on A connection. With the increasing of cycle number of axial alternating compression load, the maximum contact pressure on sealing surface of A connection is decreased, and the maximum contact pressure on sealing surface of B connection remains constant. Compared the result, it shows that the seal ability of A connection is better than B connection under axial alternating tension load, while the seal ability of B connection is better than type A connection under axial alternating compression load.

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