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GTA LGR/AMR Truck Campaign July 24 - August 4, 2017
Borealis
Wunch, Debra; Arrowsmith, Colin; Heerah, Sajjan; Mostafavipak, Seyedehnasrin; Tevlin, Alex; Gichuki, Susan; Risk, David — 2017-08-31 These are preliminary, uncalibrated, synchronized data from the University of Toronto LGR multigas analyser and Airmar weather station while aboard the Risk Lab survey truck. These measurements were taken throughout the GTA on 9 surveys between July 24, 2017 and August 4, 2017
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Methane emissions measurements from Canadian oil and gas sites
Borealis
MacKay, Katlyn; Risk, David; Lavoie, Martin — 2022-02-17 An aggregated dataset of methane emission measurements from Canadian oil and gas sites. Measurements were collected between 2007 and 2020, using a variety of techniques and sensors. The dataset consists of both published and unpublished measurements, and includes details such as site and/or component type(s), site location (approximate), measurement date, measurement technique, and quantified rate.
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Methane emissions from contrasting production regions within Alberta, Canada: Implications under new federal methane regulations
Dryad
O'Connell, Elizabeth; Risk, David; Atherton, Emmaline; Bourlon, Evelise; Fougère, Chelsea; Baillie, Jennifer; Lowry, David — 2018-11-01 <p class="TAMainText" style="text-align:justify;margin:0cm 0cm;">Aggressive reductions of oil and gas sector methane, a potent greenhouse gas, have been proposed in Canada. Few large-scale measurement studies have been conducted to confirm a baseline. This study used a vehicle-based gas monitoring system to measure fugitive and vented gas emissions across Lloydminster (heavy oil), Peace River (heavy oil/bitumen), and Medicine Hat (conventional gas) developments in Alberta, Canada. Four gases (CO<sub>2</sub>, CH<sub>4</sub>, H<sub>2</sub>S, C<sub>2</sub>H<sub>6</sub>), and isotopic δ<sup>13</sup>C<sub>CH<span><span>4</span></span> </sub>were recorded in real-time at 1 Hz over a six-week field campaign. A point-source gaussian plume dispersion model was used to quantify emissions rates. We sampled 1,299 well pads, containing 2,670 unique wells and facilities, in triplicate. Geochemical emission signatures of fossil fuel-sourced plumes were identified and attributed to nearby, upwind oil and gas well pads. Emission occurrences and rates were highest in Lloydminster, where 40.8% of sampled well pads were estimated to be emitting methane-rich gas above our minimum detection limits (µ = 9.73 m<sup>3</sup>d<sup>-1</sup>). Of the well pads we found to be emitting in Lloydminster, an estimated 40.2% emitted above the threshold in which emissions mitigation under federal regulations would be required, suggesting government estimates of infrastructure affected by incoming regulations may be low. Comparing emission intensities with available Canadian-based research suggests good general agreement between studies, regardless of the measurement methodology used for detection and quantification. This study also demonstrates the effectiveness in applying a gaussian dispersion model to continuous mobile-sourced emissions data as a first-order leak detection and repair screening methodology for meeting regulatory compliance.  </p>
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Methane flux estimates from continuous atmospheric measurements and surface-water observations in the northern Labrador Sea and Baffin Bay
Borealis
Vogt, Judith; Risk, David; Bourlon, Evelise; Azetsu-Scott, Kumiko; Edinger, Evan N.; Sherwood, Owen A. — 2022-06-22 Datasets were obtained from ship-based measurements in the northern Labrador Sea and Baffin Bay in Canada onboard the CCGS Amundsen. The datasets are divided into: 1. Atmospheric measurements 2. Results from water sampling 3. Calculated sea-air fluxes Please refer to the README file for explanation.
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Methane emission rate estimate using airborne measurement at offshore oil platforms in Newfoundland and Labrador, Canada
Borealis
Khaleghi, Afshan; MacKay, Katlyn; Darlington, Andrea; James, Lesley A.; Risk, David — 2023-04-19 Methane (CH4) measurements are needed to better understand emissions from oil and gas sources. While many CH4 measurement studies have been done in Canada, they have not yet targeted offshore production from which low emission intensities are reported by industry. For this study, a Twin Otter aircraft was equipped with a Picarro 2210-i gas analyzer and an Aventech wind measurement system (AIMMs_30) to measure CH4 emissions from three oil production facilities in offshore Newfoundland and Labrador. Each facility was visited three times to account for daily variability. Measured concentrations were used to estimate emission rates and production-weighted intensities using two different methods, Top-down Emission Rate Retrieval Algorithm (TERRA), a mass conservation technique developed by Environment and Climate Change Canada, and a Gaussian Dispersion method (GD). Overall, TERRA mass balance-derived emission rates from our measurements were 2,890±3,027 m3 CH4 day-1(GD=7,721 m3 CH4 day-1), 3,738 ±7,199 m3 CH4 day-1 (GD=13,131 m3 CH4 day-1) and 7,975±4,453 m3 CH4 day-1 (GD=7,242 m3 CH4 day-1), respectively for SeaRose, Hibernia and Hebron. Based on results from both TERRA and Gaussian dispersion the weighted average was (considering number of samples in each method) 5,000 m3 CH4 day-1 (3.35 tonnes CH4 day-1), which is comparable to the federally reported estimate of 8,037 m3 CH4 day-1 of federal estimates, reported in 2019. Production-weighted methane intensities calculated using measured emission rates and reported oil production show that Canadian offshore production ranges from 0.4-2.2 MJ emitted/MJ produced, making it among the least methane-intensive oil produced in Canada.

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(Author: Risk, David)

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