Intensity of Induced Earthquakes in Northeast British Columbia, Canada

2021 ◽  
Author(s):  
Alireza Babaie Mahani ◽  
Stuart Venables ◽  
Honn Kao ◽  
Ryan Visser ◽  
Michelle Gaucher ◽  
...  
Keyword(s):  
British Columbia ◽  
Oil And Gas ◽  
Intensity Data ◽  
Induced Earthquakes ◽  
Damage Potential ◽  
Western Canada Sedimentary Basin ◽  
Isoseismal Map ◽  
It Systems ◽  
Shallow Earthquakes ◽  
Meizoseismal Area

Abstract The damage potential of induced earthquakes associated with fluid injection is a major concern in hydrocarbon resource development. An important source of data for the assessment of damage is macroseismic intensity perceived by people and structures. In the Western Canada Sedimentary Basin (WCSB) where the occurrence of seismicity is mostly related to oil and gas activities, the collection of intensity data is incomplete. In this study, we present a comprehensive dataset gathered by the BC Oil and Gas Commission in the period 2016–2020. We assign intensities to individual felt reports according to the modified Mercalli intensity (MMI) scale and associate each MMI value to an earthquake. The isoseismal map of the largest earthquake in the Septimus region of northeast British Columbia is also provided using the compiled intensity dataset complemented with data from the U.S. Geological Survey and Natural Resources Canada “Did You Feel It?” systems along with the intensities converted from ground-motion amplitudes. We consider an approximate 10 km radius around the mainshock of 30 November 2018 earthquake with moment magnitude of 4.6 to be the meizoseismal area based on maximum intensities of 4–5. We also investigate the distance decay of intensity for shallow induced earthquakes in comparison with deeper natural events with the same magnitudes. Although intensities from shallow earthquakes (depth≤5  km) can be higher than deep events (depth≥10  km) at close distances (10–15 km), they tend to decrease abruptly at greater distances to become lower than deep events. The localization of large intensities from induced earthquakes within the meizoseismal area warrants special attention in future resource developments and call for systematic intensity data collection in the WCSB.

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 Deep Geothermal Heating Potential for the Communities of the Western Canadian Sedimentary Basin

Energies ◽  
2021 ◽  
Vol 14 (3) ◽  
pp. 706
Author(s):  
Jacek Majorowicz ◽  
Stephen E. Grasby
Keyword(s):  
British Columbia ◽  
Northwest Territories ◽  
Geothermal Energy ◽  
Sedimentary Basin ◽  
Electrical Power ◽  
Foreland Basin ◽  
Geothermal Gradient ◽  
Energy Potential ◽  
Western Canada Sedimentary Basin ◽  
Geothermal Heating

We summarize the feasibility of using geothermal energy from the Western Canada Sedimentary Basin (WCSB) to support communities with populations >3000 people, including those in northeastern British Columbia, southwestern part of Northwest Territories (NWT), southern Saskatchewan, and southeastern Manitoba, along with previously studied communities in Alberta. The geothermal energy potential of the WCSB is largely determined by the basin’s geometry; the sediments start at 0 m thickness adjacent to the Canadian shield in the east and thicken to >6 km to the west, and over 3 km in the Williston sub-basin to the south. Direct heat use is most promising in the western and southern parts of the WCSB where sediment thickness exceeds 2–3 km. Geothermal potential is also dependent on the local geothermal gradient. Aquifers suitable for heating systems occur in western-northwestern Alberta, northeastern British Columbia, and southwestern Saskatchewan. Electrical power production is limited to the deepest parts of the WCSB, where aquifers >120 °C and fluid production rates >80 kg/s occur (southwestern Northwest Territories, northwestern Alberta, northeastern British Columbia, and southeastern Saskatchewan. For the western regions with the thickest sediments, the foreland basin east of the Rocky Mountains, estimates indicate that geothermal power up to 2 MWel. (electrical), and up to 10 times higher for heating in MWth. (thermal), are possible.

Blockchain and 6G-Based Supply Chain Management Framework for Oil and Gas Shipment

2021 ◽  
Author(s):  
Md Abdur Rahman ◽  
Syed M. Belal
Keyword(s):  
Supply Chain ◽  
Supply Chain Management ◽  
Oil And Gas ◽  
Current System ◽  
Oil And Gas Industry ◽  
Chain Process ◽  
Chain Management ◽  
It Systems ◽  
Supply Chain Management System ◽  
Gas Supply

Abstract Keeping track of the oil and gas supply chain is challenging task as the route and transportation requires sophisticated security environment - both physical systems’ and IT systems’ security. Thanks to the recent advancement in IoT, specialized sensors can keep track of the required supply chain environment. With the help of blockchain, the supply chain data can be immutably saved for further sharing with stakeholders. Due to the introduction of AI as an embedded element within 6G networks, the end-to-end supply chain process can now be automated for safety, security, and efficiency purposes. By leveraging 6G, AI, blockchain, and IoT, the supply chain data during the transportation or at rest can be monitored for any changed environment during the movement of the ship through national or international routes. In this paper, we study the requirements of such intelligent and secure supply chain management system conducive to the oil and gas industry. We also show our proof-of-concept implementation and initial test results. Our obtained results show promising prospect of the current system to be deployed to safeguard the oil and gas supply chain.

Detrital zircon geochronology of Neoproterozoic to Permian miogeoclinal strata in British Columbia and Alberta

1998 ◽  
Vol 35 (12) ◽  
pp. 1380-1401 ◽  
Author(s):  
George E Gehrels ◽  
Gerald M Ross
Keyword(s):  
British Columbia ◽  
Detrital Zircon ◽  
Isotopic Signature ◽  
Detrital Zircons ◽  
Detrital Zircon Geochronology ◽  
Salmon River ◽  
Western Canada Sedimentary Basin ◽  
Cordilleran Margin ◽  
Peace River Arch ◽  
Detrital Zircon Ages

U-Pb ages have been determined on 250 detrital zircon grains from Neoproterozoic through Permian miogeoclinal strata in British Columbia and Alberta. Most of the grains in these strata are >1.75 Ga and are interpreted to have been derived from nearby basement provinces (although most grains were probably cycled though one or more sedimentary units prior to final deposition). Important exceptions are Ordovician sandstones that contain grains derived from the Peace River arch, and upper Paleozoic strata with detrital zircons derived from the Franklinian orogen, Salmon River arch (northwestern U.S.A.), and (or) Grenville orogen. These provenance changes resulted in average detrital zircon ages that become progressively younger with time, and may also be reflected by previously reported shifts in the Nd isotopic signature of miogeoclinal strata. In addition to the grains that have identifiable sources, grains of ~1030, ~1053, 1750-1774, and 2344-2464 Ma are common in our samples, but igneous rocks of these ages have not been recognized in the western Canadian Shield. We speculate that unrecognized plutons of these ages may be present beneath strata of the western Canada sedimentary basin. Collectively, our data provide a record of the ages of detrital zircons that accumulated along the Canadian Cordilleran margin during much of Paleozoic time. Comparisons between this reference and the ages of detrital zircons in strata of potentially displaced outboard terranes may help reconstruct the paleogeography and accretionary history of the Cordilleran orogen.

scholarly journals The Changing Regulatory Scheme in Northeast British Columbia

2011 ◽  
Vol 49 (2) ◽  
pp. 369 ◽  
Author(s):  
Wally Braul
Keyword(s):  
British Columbia ◽  
Land Tenure ◽  
Oil And Gas ◽  
Contaminated Sites ◽  
Public Concern ◽  
Consultation Process ◽  
New Era ◽  
The Third ◽  
Regulatory Changes ◽  
Exploration And Production

The Northeast British Columbia (NEBC) oil patch is undergoing a boom in land tenure sales, exploration, and production. This comes at a time of increasing public concern over the use of hydraulic fracturing (or “fracking”), an unconventional technology that ushered in a new era of production in NEBC, along with several new contentious issues. Recently, four significant regulatory changes have been enacted or planned for the immediate future. The first, likely in response to public concern over fracking, occurred in October 2010 with an overhaul of the decades-old Petroleum and Natural Gas Act and the coming into force of the bulk of the provisions in the Oil and Gas Activities Act. The changes primarily affect production and environmental management, and several new provisions have a direct impact on fracking. The second change under development is the creation of a long-awaited groundwater licencing regime, marking a stronger environmental presence in the NEBC, and possibly abrogating pre-existing extraction rights. The third change arises from the expiry of Crown-First Nation Consultation Process Agreements (CPAs). Recent jurisprudence continues to point to the need for improved consultation and accommodation, but current negotiations may or may not succeed in arriving at a more comprehensive successor to the expired CPAs. Finally, under British Columbia’s contaminated sites regime, new measures expand the liability exposure of oil patch operators for contaminated sites in both civil actions and government enforcement proceedings.

Complex Shear-Wave Anisotropy from Induced Earthquakes in West Texas

2020 ◽  
Vol 110 (5) ◽  
pp. 2242-2251 ◽  
Author(s):  
Regan Robinson ◽  
Aibing Li ◽  
Alexandros Savvaidis ◽  
Hongru Hu
Keyword(s):  
Shear Wave ◽  
Induced Seismicity ◽  
High Rate ◽  
Normal Faults ◽  
Permian Basin ◽  
Induced Earthquakes ◽  
Large Delay ◽  
Delaware Basin ◽  
West Texas ◽  
Shallow Earthquakes

ABSTRACT We have analyzed shear-wave splitting (SWS) data from local earthquakes in the Permian basin in west Texas to understand crustal stress change and induced seismicity. Two SWS parameters, the fast polarization direction and the delay time, are computed using a semiautomatic algorithm. Most measurements are determined in the Delaware basin and the Snyder area. In both regions, SWS fast directions are mostly consistent with local SHmax at stations that are relatively far from the earthquake clusters. Varying fast directions at one station are related to different ray paths and are probably caused by heterogeneity. In the Snyder area, most northeast–southwest fast directions are from the events in the northern part of the cluster, whereas the northwest–southeast fast directions are mostly from the southern part. The northeast–southwest and northwest–southeast fast directions could be attributed to the northeast-trending normal faults and the northwest-trending strike-slip faults, respectively. SWS results in the Delaware basin have two unique features. First, most shallow earthquakes less than 4 km deep produce relatively large delay times. This observation implies that the upper crust of the Delaware basin is highly fractured, as indicated by the increasing number of induced earthquakes. Second, diverse fast directions are observed at the stations in the high-seismicity region, likely caused by the presence of multiple sets of cracks with different orientations. This situation is possible in the crust with high pore pressure, which is expected in the Delaware basin due to extensive wastewater injection and hydraulic fracturing. We propose that the diversity of SWS fast directions could be a typical phenomenon in regions with a high rate of induced seismicity.

Achieving Efficiency in Environmental Assessment Through Focused Selection of Valued Components

2014 ◽  
Author(s):  
Ward Prystay ◽  
Andrea Pomeroy ◽  
Sandra Webster
Keyword(s):  
British Columbia ◽  
First Nations ◽  
Environmental Assessment ◽  
Local Governments ◽  
Oil And Gas ◽  
Assessment Process ◽  
Environmental Assessments ◽  
Baseline Information ◽  
The Government ◽  
Selection Of

Some of the largest oil and gas projects in Canada are currently being proposed in British Columbia. Establishing a fulsome and scientifically and socially defensible scope for environmental assessments in the oil and gas sector is a serious challenge for government and proponents. The approach taken by the federal National Energy Board to scope effects assessments on pipelines is quite different than the approach taken by the British Columbia Environmental Assessment Office on other types of oil and gas projects. The NEB has published guidelines for scoping and conducting environmental and socio-economic assessments within its Filing Manual (National Energy Board [NEB] 2014). This manual sets out the expectations for scoping, baseline information, and effects assessments to be submitted as part of approval applications. Proponents are expected to provide all information necessary to meet the guidelines. In British Columbia, the environmental assessment process is dictated by the British Columbia Environmental Assessment Act and includes a negotiated terms of reference for the assessment, called the Application Information Requirements (AIR). The approach to selection of valued components is guided by provincial guidelines (EAO, 2013). The first draft of the AIR is prepared by the proponent and is then amended to address matters raised by federal and provincial agencies, local governments, and representatives of potentially affected First Nations. Through two to three revisions, the scope of assessment is jointly established and then formally issued by the government. While there are valid reasons for the differing federal and provincial approaches to scoping environmental assessments, each of these processes create risks for proponents in terms of project timelines and costs for preparing the environmental assessment. More specifically, the use of generic and negotiated guidelines can result in a number of issues including: • A scope of assessment that is broader than necessary to understand the potential for significant adverse effects • Inclusion of issues that are “near and dear” to a specific regulator or community but has no direct relationship to the effects of the project itself • Selection of valued components that do not allow for defensible quantification of effects or use of directly relevant significance thresholds • Selection of valued components that are only of indirect concern as opposed to focusing the assessment on the true concern. • Double counting of environmental effects • Risks in assessing cumulative effects This paper discusses where and how these risks occur, and provides examples from recent and current environmental assessments for pipelines and facilities in British Columbia. Opportunities to manage the scope of assessment while providing a fulsome, efficient, effective and scientifically/socially defensible assessment are discussed.

Environmental pathways of potential impacts to human health from oil and gas development in northeast British Columbia, Canada

2012 ◽  
Vol 20 (2) ◽  
pp. 122-134 ◽  
Author(s):  
Judi Krzyzanowski
Keyword(s):  
Heavy Metals ◽  
British Columbia ◽  
Human Health ◽  
Health Risks ◽  
Fossil Fuels ◽  
Oil And Gas ◽  
Oil And Gas Development ◽  
Volatile Organic ◽  
Actual Health ◽  
Water Borne

Concerns have arisen recently as to whether the upstream oil and gas (UOG) sector — responsible for exploration, production, and some processing of raw fossil fuels — is negatively impacting human (and environmental) health in northeast British Columbia (NEBC). The region has experienced increased rates of cancers and other illnesses that have been linked to the contaminants and stressors associated with UOG. Contaminants reach human receptors through environmental pathways, namely air, soil, water, and food. Each contaminant or stressor has specific sources, transport, exposure mechanisms, and biochemistry; and each can impact health both directly and indirectly. Of particular concern are airborne sulphur and nitrogen oxides, hazardous volatile organic compounds, hydrogen sulphide, ozone, noise, and radiation; as well as soil- or water-borne hydrocarbons, heavy metals, and radiation — some of which can also impact human health through food pathways. It has been determined that UOG is negatively impacting human health in NEBC; however, further information, such as environmental monitoring, is required before the actual health risks and impacts posed by UOG can be quantified.

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