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Energy Powering Opportunity
June 11-13, 2024
BMO Centre at Stampede Park - Calgary, Canada

Technical delegates will be able to access and enjoy two forms of technical educational content at the event, along with the main technical program, technical posters will be displayed and presented on the exhibition floor. The technical posters will cover a wide range of technical topics in the energy industry and be presented by the authors during specific scheduled times throughout all three days of the Global Energy Show Canada.

Access to the poster session on the exhibition floor is included with a visitor, strategic or technical conference pass.

 

Categories covered include:

  • Clean Technology and Environmental Management
  • Cleaner Hydrocarbon Production and Enhanced Oil Recovery - EOR
  • Field Development and Infrastructure
  • Hydrogen
  • Methane Emissions Reduction
  • Pipeline and Processing Facilities
  • Sustainable Electricity Generation and Grid Modernization

Schedule

Tuesday, June 11, 2024

12:00 PM - 1:30 PM

2:30 PM - 3:00 PM

 

Wednesday, June 12, 2024

12:00 PM - 1:30 PM

2:30 PM - 3:00 PM

 

Thursday, June 13, 2024

12:00 PM - 1:30 PM

 

2023 Poster Sessions Include:

 

Beyond the Perimeter: A Case Study on Operational Efficiency

Category: Sustainable Electricity Generation and Grid Modernization

It is undeniable that the world is in a climate change crisis, and the need for action is more than pressing ? it’s vital. Nations around the world are increasing their use of renewable sources to meet their targets for CO2 emissions. One country seeking to invest in more renewable resources is Brazil, specifically with one of its largest energy companies, Elera Renováveis, which works to generate electricity from renewable resources. With over 44 hydroelectric plants, 19 wind farms, and eight miles of perimeter to cover, it’s easy to understand the security challenges of such a large-scale facility. At peak capacity, the solar farm’s acreage is equivalent to more than 800 football fields, generating nearly 360 megawatts of power ?" serving the electricity needs of nearly a quarter million homes. However, the more sustainable our critical infrastructure has become, the more vital it is to ensure it’s protected and able to provide essential services to area businesses and residents. A sprawling solar farm presents its own unique challenges, and ensuring the security of solar farms, power grids, water plants, etc. is vital to business’ functions, resident wellbeing, and the livelihoods of many. In this presentation, Joe Morgan, Segment Development Manager ?" Critical Infrastructure at Axis Communications will review the challenges Elera Renováveis faced, and how they overcame skepticism with innovation. The audience will gain an understanding of what it takes to secure large critical infrastructure facilities, such as solar farms, and how to take it a step further. Not only by protecting the perimeter, but by maximizing their investments to streamline processes."

Presented By:

Joe Morgan

Segment Development Manager - Critical Infrastructure

Axis Communications

Combination of Methods to Assess Cement Sheath Success: Case Study

Category: Drilling and Completion

Scope: Cementing operations, especially in modern day challenging wells, presents challenges related to slurry design, job design and execution, and measurement or validation upon completion of the job. Multiple methods and tools are used to both predict and evaluate how well a cement sheath has been placed. This paper is a case study, combining proven industry equations, an established cementing software model, and cement logs to evaluate a cement sheath placed around a liner using rotation. Methods, Procedures, Process: This paper presents pre-job calculations, fluid design, and the job design in conjunction with the results of pre-job predictive software modeling. The well data is also presented, including top drive torque, fluid volumes and rates, pump pressures, fluid densities, and sets of actual vs. synthetic logs. These are then compared to assess and validate the success of the cement sheath after the slurry had been pumped. Unfortunately, a software model is limited by necessary assumptions with input data, methods used to generate synthetic logs are naturally limited, and field data collected for comparison is often challenging to interpret. Experienced field personnel using engineering best practices can make use of current tools in combination to overcome the limitations commonly inhibiting accurate design during the planning stages. Combining these available tools with field data allows operators and service companies to alter their approach for the next well in that field, increasing the likelihood of success. Results, Observations, Conclusions: Data measured in the field, and lab data combined with field measurements, were evaluated to gain confidence on the inputs used for the software models. Synthetic and actual logs were used to validate and gain confidence in conclusions. The software models were then compared to rig data. As these all matched to a reasonable degree, confidence was gained on the conclusions drawn from all data sources. The quality of the cement job was compared to two offset wells, and accurate recommendations were reached for application in the next well. Novel/Additive Information: It is the goal of the authors to disseminate technical information on the methodology and practice of combining available resources and modeling wells post-job to both validate the accuracy of post-job evaluations and equip engineers in the industry to better recommend changes for future offset wells.

Presented By:

John McCormick

Engineer

PVI Software

Enabling the Hydrogen Economy with Leading Technical Performance

Category: Hydrogen

Optimising new hydrogen plants for the lowest possible carbon intensity Objective: Hydrogen is expected to play a critical role in the energy transition required to achieve net zero targets. According to BNEF, up to 24% of global energy consumption in 2050 could be supplied by hydrogen. As hydrogen is well-suited for the remediation of hard-to-decarbonise areas such as heavy industry and transport, the provision of low carbon hydrogen at scale is essential for mass decarbonisation efforts. Clean hydrogen projects are eligible for Canadian tax credits of up to 40% depending on their level of carbon intensity, so minimising CO2 production is of the utmost importance to help project developers achieve the highest possible incentives for their hydrogen plant. Process: Johnson Matthey (JM) has developed a CCS enabled ‘blue’ hydrogen process which delivers the lowest possible process carbon intensity with high CO2 capture rates and best-in-class economics. This process combines JM’s novel gas heated reformer (GHR) and autothermal reformer (ATR). This approach produces a higher hydrogen yield and is more energy efficient than existing steam methane reforming (SMR) technologies (currently the most deployed technology for H2 production). Crucially, this process makes decarbonisation via CCS easier and cheaper than using a steam methane reformer. The process can deliver a high CO2 capture rate (>99%), making it a high efficiency, low-cost solution which provides significant benefits compared with SMR and alternative ATR technologies. The solution is based on established chemical process engineering and over 40 years of operating experience, and is designed to operate at scale, enabling carbon reduction for hard-to-abate sectors including industry and dispatchable power. Results: Compared with conventional SMR, the combined GHR- ATR flowsheet demonstrates:

• 10% lower natural gas consumption

• 10% less CO2 produced

• 75% lower capital cost for the CO2 capture system

Additional Information: Use of the combined GHR-ATR flowsheet will futureproof and de-risk projects by minimising the impact of increasing feedstock costs, increasing costs of CO2 transmission and storage, and any potential governmental scheme for carbon taxation. Working with partners and collaborators will further accelerate the deployment of large scale hydrogen plants. This process will enable energy companies to produce ultra-low carbon intensity hydrogen to decarbonise their operations, or to export to other markets, enabling the reduction of Scope I, II or III emissions and improving the sustainability and viability of hydrogen production in the future.

Presented By:

Bedar Islam

Global Business Manager

Johnson Matthey

ENHANCED SOLVENT EXTRACTION INCORPORATING ELECTROMAGNETIC HEATING

Category: Cleaner Hydrocarbon Production and Enhanced Oil Recovery - EOR

The goal of the ESEIEH, Effective Solvent Extraction Incorporating Electromagnetic Heating, technology is to replace steam for in situ bitumen extraction with electromagnetic heating in combination with solvent dilution. The ESEIEH process eliminates the need for steam, while providing an improved framework for significant reduction in carbon emissions. By some estimates, on a full cycle basis, GHG emissions may be reduced by greater than 80% from steam- assisted gravity drainage with the potential, through the use of renewable energy sources, to approach zero GHG production. Phase 1: The mine face test represents the first demonstration of the use of Electromagnetic Heating in an oil recovery process. The mine face test focused on a proof of concept that RF energy can be effectively used to heat oil sands and that coupled numerical models could adequately predict the results in-situ. The major test objectives were: -Demonstrate effective equipment installation and system performance. -Establish antenna performance metrics in oil sands -Obtain a comprehensive dataset to identify relevant physics of RF heating. -Provide technology validation for RF reservoir pre-conditioning to a coupled solvent process. These objectives were demonstrated through the design, deployment, and operation of an RF heating system at a built-for-purpose pit at the North Steepbank Mine. The CEMRS numerical method was validated and the test proved that the hardware could deliver the required lineal power density required for a commercial scale ESEIEH process. Phase 2: Furthering the system technology to TRL 7 with a single component remaining at TRL4/5 (Center Isolator). The updated component solution was proven in lab-scale testing just prior to the coronavirus shut down. Both the Mine Face Test (MFT) and Phase 2 validated electromagnetic energy penetration into native, heterogeneous oil sands. The project also completed the first field validation of a simulation tool (CEMRS) capable of predicting temperature profiles, penetration and heating rates by electromagnetic energy in a hydrocarbon resource. The Effective Solvent Extraction Incorporating Electromagnetic Heating (ESEIEH) or “easy” process is envisioned as a long-term replacement to the SAGD process. It combines significant GHG reductions with cost efficiencies having the potential to dramatically improve on the performance of current practices to produce the province's vast bitumen resources. The ESEIEH project is a collaboration that was initiated by four industry petroleum and technology leaders now the Pathways Consortium.

Presented By:

Mark Blue

CTO

TerraVent

Flexible Steel Pipe Helps Solve Five Challenges of CO2 Transportation

Category: Pipeline and Processing Facilities

Pipelines are a crucial part of the global effort to decarbonize the energy industry. While CO2 is a common component in the hydrocarbon mixtures produced in the oil and gas industry, it has significantly different properties when pumped as a standalone fluid in the supercritical state. Many materials used in the existing and newly constructed pipelines experience challenges when used for the supercritical CO2 service. Flexible steel pipe is the pipe technology that solves these challenges in pipeline construction, operation, maintenance, and risk management. This presentation will describe the distinct advantages of flexible steel pipe that enable fast, reliable, long-term, and safe construction of new pipelines and rehabilitation of the existing pipelines. The ability to repurpose the existing pipelines and convert them from a liability into a valuable and economically feasible network of CO2 pipelines is the primary advantage of flexible steel pipe. The excellent tensile capability of the product allows for pulling up to 2-3 km at a time which requires minimal excavation of the existing pipeline sections. The high-pressure capability and corrosion-resistant properties of the HDPE-based flexible steel pipe provide a brand-new pipeline with a pressure rating higher than the host pipe and a 20+ year design life. The ability to install flexible steel pipe with minimum resources reduces the Right-Of-Way requirements and simplifies the installation of the new pipelines to the CO2 emitters historically not connected to the energy pipeline network. The longer spoolable flexible steel pipe sections require less equipment and personnel for pipe deployment which makes the construction safer. The composite structure of the flexible steel pipe addresses the risk of rapid crack propagation pertinent to carbon steel pipelines and minimizes the risk of catastrophic pipeline failure in case of a leak. The simplified integrity management for the technology significantly reduces the operating expenditure for the project and reduces the chance of human error during pipeline inspection and maintenance. The presence of the designated annulus space in the flexible steel pipe presents the opportunity to verify the integrity of the pipeline on demand or run real-time annulus pressure monitoring for leak detection. The simplified integrity management requirements and the inherent leak-detection capability further de-risk the CCUS operations for the owner, the communities, and the environment. During the presentation, we will review several case studies that demonstrate the advantages of flexible steel pipe technology and the benefits realized by the operators.

Presented By:
Kirill Kovalenko

Technical Services Engineer

FlexSteel Pipeline Technologies, Ltd

Hydrogen & Ammonia Combustion Capabilities in Boilers and Gas Turbines

Category: Hydrogen

Scope: Hatch’s presentation will focus on industrial applications of fuel switching in boilers and gas turbines, highlighting current and projected near-future capabilities to burn hydrogen and ammonia. Hatch will concentrate on equipment capabilities and plans, required modifications to conventional systems, and safety aspects concerning combustion systems required for burning hydrogen vs. ammonia. Methodology: The Hatch Thermal team will utilize experience with recent projects, relationships with major boiler and gas turbine OEMs, and open literature to provide an overview of current industry trends and capabilities, and future capabilities based on initiatives in the industry. This includes new facilities and retrofitting existing facilities. Safety concerns and required safety features will be reviewed. Differences in fuel properties of natural gas, hydrogen, and ammonia, and their impact on combustion systems will be discussed. This will identify key areas that require modifications, discuss existing capabilities, and the latest technologies to overcome issues with hydrogen and ammonia combustion. Results & Conclusions:

• Hydrogen: Most boiler and gas turbine OEMs offer products that can burn substantial amounts of hydrogen. Today, gas turbines can burn up to 35% hydrogen, with some models burning up to 85%. In the future, gas turbine OEMs plan to have up to 90% hydrogen capable turbines by 2028 and reaching 100% in 2030 and beyond. Similar numbers have been reported by boiler OEMs for hydrogen. • Ammonia: Ammonia capability is very limited in gas turbines due to many factors including the high air-to-fuel ratio, low calorific value, and safety factors associated with ammonia. Boiler manufacturers can burn ammonia, with pilot tests and R&D examples demonstrating capability, but there are no full-scale applications with ammonia burning capability.

• Hydrogen, ammonia, and NG have highly different volumetric energy densities and flame speeds, which impact the overall combustion system. Combustion control and safety modifications will be required including fuel nozzles, valves and pipes, flame detection, fuel blend control, and re-rating of solenoids and motors.

• NOx generation with hydrogen and ammonia is a known challenge. Mitigation methods include low-NOx burners, air staging, and selective catalytic reduction. These technologies, both new and retrofitted, increase the overall cost of equipment.

• Generally, most boilers and gas turbines can burn substantial amounts of hydrogen, and it is the hydrogen generation, storage, and transportation which presents the highest level of technical and economic challenges. Novel Aspects: In the rapidly developing area of hydrogen and ammonia as alternative fuels, OEMs are advancing quickly to ensure they have the product offerings available to meet the new needs of industrial partners. This presentation provides an up-to-date analysis, using the most recent data from Hatch’s projects, vendors, and literature research, and defines current end-use capabilities, retrofit requirements and safety risks, and the trend towards 2030 vis-à-vis technologies’ availability.

Presented By:
Saleha Habib

Power EIT

Hatch Ltd.

Improved Bitumen Recovery to Emissions Free Hydrogen Economy

Category: Cleaner Hydrocarbon Production and Enhanced Oil Recovery - EOR

Over the last three decades our Group have developed a plurality of breakthrough energy technologies based on the application of Dimethyl Ether (DME) and solvent vapor drainage (SVD) for in-situ bitumen extraction. The follow-up process involves the conversion of DME to hydrogen incorporating innovative transportation and storage methodologies. Compared to SAGD, DME-SVD eliminates emissions and water usage, reduces energy consumption by approximately 90% and the capital and breakeven costs of bitumen recovery by approximately 5 times. DME-SVD accelerates bitumen production rates by up to 4 times compared to other solvents tested. To achieve maximal benefits from application of DME-SVD an integrated, low-cost, emissions free DME synthesis facility has been devised which can also form the basis for production of hydrogen by hydrolysis/reforming of DME/water blends. The generated hydrogen gas contains up to 30% CO2 which is recycled for DME synthesis. The hydrolysis/reforming reaction generates twice the volume of hydrogen compared to natural gas reforming. It is expected that generation of hydrogen from DME/water blends will prove superior to water electrolysis for hydrogen production. While DME can be readily liquefied, hydrogen must be pipelined in gaseous form and shipped as liquid. World-wide infrastructure for hydrogen handling does not exist and its development would cost trillions of dollars. Existing infrastructure for carbon based gaseous and liquid fuels is perfectly suitable for DME handling, transportation, and conversion to hydrogen at final delivery location. It is expected that conversion of DME/water blends in micro reactors mounted directly in on-land vehicles will eliminate the need for extra heavy batteries in EV’s, the demand for rare metals and the expensive carbon-fiber tanks for highly compressed hydrogen. DME-SVD provides an immediate environmental and economic improvement for bitumen recovery while offering a low-cost solution to hydrogen production and accelerated transition from carbon to hydrogen economy.

Presented By:
Gerald Chalifoux

President

Petrospec Engineering Inc

Leveraging Big (and Small) Data in the Energy Sector

Category: Field Development and Infrastructure

It is sometimes said Data is the new oil", and whilst data will never match the raw material value of oil as a resource, it does provide a game-changing asset that can positively improve every industry sector. Bringing the insights data has to offer into the Energy sector can affect every phase of the industry, from discovery, through extraction, transport and delivery, and every step of the process in between. However, the IT segment is famous for its unapproachable complexity, Clouds, Artificial Intelligence, Deep Learning, Block Chains, Observability, IoT, and many more technology buzz-words confuse and mystify what is otherwise an invaluable tool set. The most important thing to know is, from the smallest sensor on a device inside a plant, through to the excessive data flowing from your IT and OT management systems, or from physical security devices, wireless localization and tracking systems, all of the data your organization captures is like a gold-mine. It is just a matter of knowing how to find it. This session will outline some real world examples of how the Data within every Energy provider can be utilized to unlock otherwise unseen information from within your operational environment. By capturing, normalizing and pooling all of your data, while potentially augmenting it with new sensors, monitoring and data sources, you can create a Data Lake from which these new insights can be extracted. Using both customized sophisticated data mining tools, as well as a rapidly growing pool of off-the-shelf "low/no code" data analytics systems, we will demonstrate some of the amazing discoveries that can be made from otherwise uninteresting information. This session will leave you with a practical path to leveraging all of the data, both big and small, within your organization to provide insights and visibility that will cost-effectively improve many aspects of your business operations."

Presented By:
Ronnie Scott

CTO

Charter Telecom

 

Maximizing NGL Recovery Economics with Thermally Driven Deep Cut

Category: Pipeline and Processing Facilities

Deep cut plants are field gas processing plants with specialized refrigeration processes to extract greater quantities of (natural gas) liquids from field gas than conventional “shallow cut” plants. Conventional deep cut refrigeration processes utilize turbo-expanders, which rapidly decompress and chill natural gas so that liquids drop out of the gas stream. Extracting natural gas liquids allows gas producers to maximize the value of their hydrocarbons rather than selling rich gas into a transmission system at a benchmark gas price. This increased value provides producers incentive to develop greenfield deep cut facilities or convert existing shallow cut plants. However, conventional deep cut facilities are capital intensive due to the high cost of installing turbo expansion equipment. Furthermore, turbo-expanders are only efficient within a narrow range of operations meaning a significant loss of efficiency during periods of off-design operations. Cool Ventures Inc. (“CVI”) has developed a patented thermally driven refrigeration system capable of providing deep cut processing capacity without the need for turbo-expansion equipment. CVI uses a modified aqua ammonia absorption refrigeration technology (“MA3TM”) that can achieve process temperatures as cold as -70°C and can achieve colder temperatures with additional cooling provided using a Joule-Thomson valve. The aqua-ammonia system can be configured with staged chillers which provide operating flexibility and maximize natural gas liquid recoveries. CVI’s deep cut solution is ideal for greenfield applications of raw gas processing or brownfield upgrading of shallow cut facilities where residual natural gas liquids are available for recovery. The aqua-ammonia system has a capacity range of 5 - 100MMscfd (in a single train), a highly efficient turndown ratio of 10:1, and can utilize waste heat from compressor drivers or power generation equipment to provide the thermal energy necessary to drive the refrigeration process. By providing a cost-effective, flexible, and highly efficient deep cut solution, CVI’s aqua-ammonia refrigeration will allow gas producers to maximize the value of their hydrocarbons while minimizing capital spending.

Presented by:

Patrick Mills

Business Analyst

Cool Ventures Inc.

Methane Reduction During Upstream Flowback Operations

Category: Methane Emissions Reduction

Eliminating flaring and venting during completion operations is possible. Tara commercially introduced pressurised storage for produced well fluids to the Canadian Oil and Gas Industry in 2013. With the industry focus turning to pad development and concurrent flowback operations there was significant gas being vented from atmospheric tanks. (400bbl/ open top tanks). This innovation eliminated venting of methane from atmospheric tanks. Utilizing pressurised storage tanks allowed Tara to flare the waste gas reducing the carbon footprint of well flowback operations. Tara has now deployed a new “Net Zero” process that leverages the utilization of pressurised storage for produced well fluids and takes it to the next level of conservation by compressing the captured waste gas and flowing it inline as sales gas. This eliminates the CO2 created by flaring the waste gas, increases revenue by increasing total sales gas volume, and reduces carbon tax exposure.

Presented By:

Braydon Garagan

Facilities Engineer, E.I.T.

Tara Energy Services LLC

and 

Justin Nguyen

Multi Phase Metering Engineer

Tara Energy Services LLC

Modelling of Production and Transportation Constraints on Future Hydrogen Pathways

Category: Hydrogen

There is a growing global consensus around the need to reduce greenhouse gas emissions to net zero by 2050 to address climate change. Many countries, including Canada, are making investments in building out low carbon hydrogen infrastructure as a pathway to decarbonize power, heat, and transportation domestically and for export. Two likely methods for low carbon hydrogen production are via natural gas with carbon capture and storage and electrolysis of water with electricity generated from renewable energy, commonly referred to as blue and green, respectively. Currently, blue hydrogen is cheaper, but decreasing costs are expected to make green hydrogen competitive in the future. In Alberta, the possibility of creating blue hydrogen for export is an enticing opportunity because of the available carbon storage space and low natural gas costs. Despite this opportunity, there are gaps in the research for direct comparison between this hydrogen export pathway to other likely options. While several existing studies evaluate specific pathways, comparability across results requires harmonization of assumptions. This research addresses this gap through a technoeconomic analysis of two scenarios: blue hydrogen production in Alberta compared to green hydrogen production in Australia, with a final export target in Japan. Australia is currently considered one of the best options in providing hydrogen for export, making it a good example for comparison to see if Alberta blue hydrogen is viable. Japan is the export target because of its high local hydrogen production cost and declared intent to import hydrogen. This technoeconomic model was created in Python. The data required for both pathways were mainly found from Canadian and Australian government sources, as well as academic literature. The cost of each pathway is analyzed in the present as well as up to 2050 with sensitivity analyses to determine how external factors address competitiveness. For both pathways, this technoeconomic analysis includes the production of hydrogen and subsequent conversion to ammonia for transport. The ammonia is then transported by train to a port and then shipped to Japan for use. The full costs are included, and the biggest cost differences come from hydrogen production, train transportation distance, and policy differences between Canada and Australia. Overall, the costs of blue hydrogen export from Canada were found to be lower currently compared to green hydrogen export from Australia. However, this changes in the future, with the Australia pathway reaching lower costs by 2050. This suggests that blue hydrogen export from Alberta may not be able to economically compete in the long term with other options and may only be a short-term solution to immediate energy needs. This conclusion will depend on the policy choices of respective governments, as certain policies may be created to reduce costs in one of the pathways.

Presented By:
Julian Palandri

Graduate Student

University of Calgary

Multi-Track InSAR Monitoring of Surface Heave from CSS Operations

Category: Reservoir Engineering

Interferometric synthetic aperture radar (InSAR) has been used to monitor ground heave in the Alberta oil sands for many years. The technology has been evaluated for use in general for monitoring heave and use in caprock integrity studies. Oil extraction by cyclic steam stimulation (CSS) induces reservoir thermal expansion and contraction from steaming operations. This subsurface movement produces a surface expression that is related to the timing of injection and production activities. Accurate monitoring of the ground deformation that occurs at a CSS field can be used to calibrate predictive models, show the effectiveness of steam injection and demonstrate the impact of the recovery operation on the surface elevation. Accurate monitoring, however, requires the ability to consistently measure large, non-linear changes in surface height over relatively small areas. CSS sites can experience 20+ cm of surface heave in one month. InSAR compares radar returns within a sequence of Synthetic Aperture Radar (SAR) images to precisely measure topographic changes on the observed surface. Arid regions are ideal for radar observations as they provide coherent phase values used to measure surface movement. The ground conditions in the regions of the Alberta oil sands are not ideal for InSAR monitoring. The amount of ground water, variation in vegetation cover due to seasonal change, and the sparsity of effective radar reflectors has led to the development of InSAR methods that employ installed targets and advanced filtering techniques to improve the accuracy of InSAR-measured surface heave. In the case of CSS operations, like that of Imperial Oil’s Cold Lake operations in Alberta, the use of advanced filtering techniques has worked particularly well, especially when combined with multiple SAR satellite beam modes. The combined methodology, termed multi-track analysis, extracts the surface deformation signal in high-noise conditions from multiple satellite tracks collected at a high temporal frequency from the same SAR satellite to ensure, in most cases, a seamless heave profile and therefore increasing the effectiveness of InSAR observations. The heave profiles derived from the InSAR measurements are compared against Imperial Oil’s steam strategies and used to validate the affected reservoir volume during the steam cycle. The InSAR-derived ground movement patterns provide an indication of steam distribution along horizontal wells by modelling the heave induced by steaming and comparing that to the measured heave from InSAR. The InSAR measurements have shown good agreement with steam strategies. This paper will present the benefits of using advanced InSAR analysis from multi-track SAR satellite for surface movement measurements to support CSS operations by exploiting the spatial and temporal characteristics of the radar images to produce a more robust estimate of the ground movement than has been possible previously.

Presented By:
Gillian Robert

Project Manager

MDA Geointelligence

Simulating Cement Plug Temperature During Pull-Out-Of-Hole

Category: Drilling and Completion

Predicting wellbore and cement slurry temperatures is a basic demand for plug cementing job design. The calculations required are advanced. To meet the P&A industrial need, a numerical model suitable for well temperature prediction during mud displacement and pull out of the hole has been developed to meet the P&A industrial need. The model considers transient heat transfer between wellbore fluids, the work string, and the formation for all well depths during and after the job. This model is an upgrade from existing 2D models for wellbore temperature simulation with a stationary pipe string, often fixed at the well's total depth (TD).

Presented By:
John McCormick

Sales Manager

Pegasus Vertex, Inc

Spatiotemporal Evaluation of SCVF Methane Emissions in Alberta

Category: Methane Emissions Reduction

Surface Casing Vent Flows (SCVFs) are estimated to be contributing approximately 20% of fugitive emissions in Alberta. However, it has repeatedly been reported that methane emissions from SCVFs are underestimated. This is problematic for both the Government of Canada’s commitment to a 75% or greater reduction of oil and gas industry methane emissions from 2012 levels as well as producers striving to meet the reduction targets they have signalled to the markets and their stakeholders. Given their contribution to corporate, provincial and federal methane inventories, it is crucial that emissions from SCVFs are efficiently and effectively detected, quantified and mitigated. The ongoing research discussed in this paper is another contribution to the body of knowledge needed to effect meaningful and lasting methane emissions reductions. In addition to our research, this body of knowledge is growing from a number of federal and provincially funded initiatives. For example, the Government of Alberta has drawn on the Technology, Innovation, and Emissions Reduction Fund (TIER) to finance several grant programs including the Alberta Methane Emission Program (AMEP). Its objective is to enable methane emissions reductions in Alberta’s oil and gas industry, while supporting government regulatory revisions, cutting industry costs, and assuring best practices regarding methane detection and management. The ongoing research discussed in this paper broadly aligns with these objectives and highlights the importance of SCVFs in the pursuit of reducing methane emissions. Our research aims to characterize the spatial and temporal variations in occurrence and potential causes and sources of methane emissions by SCVFs in Alberta. Emission rates, frequencies of leakage, and wellbore characteristics are analyzed by applying descriptive and inferential statistical methods. This work is different from previously published studies by using the most recent Alberta Energy Regulator (AER) SCVF data set, analyzing and identifying more in-depth characteristics of SCVFs leaks based on their geographical locations. It is estimated that more than 460,000 wells have been licensed in Alberta, of these wells, over 15000 are reported to AER with SCVF leaks since 1970’s. From these reported SCVF leaks, 58% of the leaks are not quantified. The majority of the quantified leaks are suspended wells; however, this can vary regionally. For example, active or abandoned wells outweigh suspended wells in some regions in Alberta. In addition, it has been found that the emission rates are significantly different based on wellbore trajectories e.g., horizontal or vertical. In certain regions, such as Red Deer, the likelihood of a SCVF leak is doubled for horizontal wells compared to vertical wells. Our research demonstrates that spatiotemporal analysis of SCVF emissions is an important contributor to the understanding of the current state of methane emissions that will lead to development of better emissions mitigation strategies and reduction pathways.

Presented By:

Negar Nazari

Emissions Analyst

Carbon Management Canada

Techno-Economic Assessment of Producing Carbon Fiber from Asphaltenes in Alberta.

Category: Methane Emissions Reduction

Alberta Oil Sands Asphaltene (AOA) is a low economic value by-product of oil sands upgrading process. Due to its high carbon content, AOA has the potential to replace polyacrylonitrile (PAN) as a low-cost precursor in carbon fiber manufacturing. On average, PAN precursor contributes 50% of the total manufacturing cost of conventional carbon fiber. Currently, the production of AOA carbon fibers has only been demonstrated at the laboratory scale. Based on laboratory experiments, this study will determine the economic feasibility of commercial-scale AOA carbon fiber production. The main steps of PAN carbon fiber manufacturing are polymerization of PAN, wet spinning, oxidation, carbonization, surface treatment, and sizing. Except for polymerization and wet spinning, the production of AOA carbon fiber is comparable to PAN carbon fiber production. AOA is not polymerized; instead, it is extracted from oil sands after being pre-treated with pentane and toluene. At the moment, laboratory experiments are being conducted to determine whether substituting wet spinning with melt spinning will lower the production cost. A four-step approach was implemented to scale-up the laboratory AOA carbon fiber process to an industrial scale. In the first step, mass and energy balances were utilized to define the laboratory procedure. Next, each lab process was independently scaled-up to comparable commercial processes. Then, energy and material recovery served as the basis for synchronizing all independently scaled-up processes. Finally, the techno-economic assessment (TEA) was conducted on the synchronized commercial scale production. TEA results of this study will be based on a class 4 cost estimate. The accuracy of a class 4 cost estimate is L: -15% to -30% and H: 20% to 50%. A class 4 cost estimate helps to determine the preliminary cost of producing commercial AOA carbon fiber, thereby helping technology developers decide on potential future improvements and scaling techniques. The TEA of this project primarily focuses on the fixed capital investment (FCI) and annual operational costs of an AOA carbon fiber facility, as well as the price of 1 kg of AOA carbon fiber. A commercial AOA carbon fiber manufacturing facility with an annual capacity of 3200 tons would have an estimated FCI and annual operational cost of USD 58 million and USD 34 million, respectively. The cost of 1 kg of AOA carbon fiber is around USD 13. The calculated TEA results are reasonably similar to those reported in PAN carbon fiber studies. Oxidation and carbonization are energy-intensive heat treatment processes in AOA carbon fiber manufacturing. Currently, laboratory experiments are underway to investigate the feasibility of substituting energy-intensive furnaces used in carbonization with low-energy microwave ovens. Laboratory experiments are also being conducted to improve the mechanical properties of AOA carbon fibers to achieve parity with PAN carbon fibers..

Presented By:

Chanuka Perera

Graduate Student

University of Calgary

 

Thermal Well Control//Physics Combined with Experience

Category: Drilling and Completion

A comprehensive safety presentation covering the following topics; • Thermal expansion • Reflux / re-boil • Vapor / condensation assisted gas flow • Low pressure / high temperature issues • Upper wellbore temperature characteristics • Well kill procedures • Trickle well control • Blow out preventer limitations • Importance of compliance to procedures • Built in safety factors • Safe fluid temperatures

Presented By:

Darcy Pashak

Director of Operations

NES Fircroft

The Use of Sealing Materials in Hydrogen Service

Category: Hydrogen

Flexitallic have been providing sealing solutions to industry for over 100 years. As the inventor of the spiral wound gasket in 1912 has been involved in providing innovative ideas across the globe. With the current movement towards a Hydrogen solution Flexitallic will detail the solutions and products used in this industry sector. Discussions on the development of semi metallic sealing gaskets including the High Performance Gaskets ( HPG ) along with new novel sealing materials Corriculite offering levels of sealing previously difficult to achieve with conventional materials. Discussion on comparison sealing leakage testing between Helium and Hydrogen, corrosion testing, fire safety and case studies

Presented By:
Anthony Currie

Director Engineering and Technology

Flexitallic Canada

Use of Artificial Intelligence for Environmental Management of Industrial Processes

Category: Clean Technology & Environmental Management

The quest for global optimization of Industrial processes to tackle environmental management recently took a new path thanks to the advent of big data analysis techniques, the IIoT, the machine learning techniques and the use of artificial intelligence science. During the last three decades, the industry in general has accumulated vast amounts of data but only a very small amount, e.g., less than five percent, was generally explored. mainly to solve problems or to confirm assumptions. This paper will show how nowadays it is possible to explore hundred percent of data accumulated over years as well as linking the data of individual processes together along the chain of the processes to end the era of siloed process optimization and to enter the age of global optimization. The authors explain through tangible examples how supply chain and trade flows as well as available environment open-source databases (e.g. meteorology, air quality, water quality, geology) can be pooled in the same data lake along with process data and explored with powerful big data analytics tools to twin not only the industrial process chain but also to twin its footprint and impact on the environment (e.g. water, air, ground, underground) in the short haul and on the long haul. The authors conclude with a new emerging paradigm called “The Green AI”, that resulted from the ever-increasing use of new techniques such as big data analytics, artificial intelligence, hypercube mathematics, serving the sustainability cause. This new paradigm, according to the authors will be used more and more extensively in the next decade to the benefit of Environmental Management. The obvious payback of this paradigm will be accompanied by major cultural change spanning from the improvement of the equipment lifetime, resource recycling, water efficiency, material efficiency, energy savings and reduction of greenhouse emissions. Keywords: AI (Artificial Intelligence), Data Lake, Big data analytics, Global Optimization, Energy efficiency, Energy savings, Cleaner Emissions, IIoT (Industrial Internet of Things), Machine learning, hypercube mathematics, Sustainability, Energy efficiency, Material efficiency, Water efficiency, Greenhouse gas emissions, Green AI, Lifetime, Recycling, Pattern Oil and Gaz Industry, Petrochemistry Industry, Metal Industry, Mining Industry, HVAC Industry, Chemical Industry.

Presented By:
Roelf Janse Van Rensburg

Africa CMO

ALTech Group - AST Technology



Using High-density, Autonomous Sensors to Track Subsurface Hydrocarbon Contamination

Category: Clean Technology and Environmental Management

Objective/Scope. Environmental site managers are increasingly turning to high-density data streams and AI-assisted technology to overcome the limitations and data gaps that occur with traditional data collection at contaminated sites. High-density real-time data allows site managers to track changes in plume extent and remedial success in real-time across varying seasonal conditions so that changes in site conditions are detected earlier and estimated accurately. Using continuous data streams is a game changer for site owners whose goal is to improve their accuracy and efficiency in analyzing, managing, and prioritizing their portfolio towards the ultimate goal of closing sites. Methods, Procedures, Process. Our new technology, Soil Sense, produces the continuous data streams necessary to track plume stability, extent, and natural source zone depletion (NSZD) rates across a light non-aqueous phase liquid (LNAPL) plume in real-time. At a site, a Soil Sense network can be installed providing high-resolution spatial and temporal quantification of LNAPL plume dynamics, NSZD metrics, and remediation system effectiveness. Soil Sense networks have already been deployed at fourteen sites ranging from decommissioned oil and gas sites to former gas bars to active sites such as refineries and storage terminals. The high-density real-time data generates robust continuous estimates of plume areal extent, plume volume, plume mass, NSZD rates, remedial system success, and time to closure. Results, Observations, Conclusions. At EMS we have constructed Soil Sense networks within and surrounding LNAPL plumes at fourteen sites. These networks allow high-resolution spatial and temporal quantification of LNAPL plume dynamics and biological processes associated with NSZD. The data were collected at 30-minute intervals and include gas flux (CO2, O2, CH4), pressure, air and soil temperatures, relative humidity, and petroleum hydrocarbon vapour concentrations. NSZD rates varied as a function of site and LNAPL plume characteristics. Moreover, while NSZD rates slowed during soil freeze-up, they were non-zero, which affords users a more nuanced and robust picture of NSZD at their site over seasons to years. Novel/Additive Information. NSZD has emerged as a practical alternative for restoration LNAPL sites that are in the later stages of their remediation lifecycle. Concerned about climate change and environmental sustainability (in other words, the “E” in “ESG” (Environmental, Social, Governance metrics)), site owners and managers are increasingly adopting this as a greener (i.e., less greenhouse gas (GHG) emissions than ex situ methods) and more viable approach towards site closure. This has driven demand for high-density data to better characterise patterns and processes underlying soil gas emissions (e.g., NSZD) at daily to seasonal timescales. Soil Senses may also be used to monitor GHG emissions at other, non-contaminated properties to facilitate sustainable investing by quantifying ESG metrics.

Presented By:

Amy Jimmo

Director of Remediation

Environmental Material Science Inc.

 

ZIF-8/MWCNTs-Nanocomposite for Selective Detection of Methane in Parts-Per-Billion

Category: Methane Emissions Reduction

New carbon policies and regulations based on the recent Global Methane Assessment launched by the Climate and Clean Air Coalition and the United Nations Environment Program require cutting human caused CH4 by 45% within this decade. This alone would prevent nearly 0.3°C global temperature increases by the 2040s and would keep global warming below the threshold agreed by world leaders. Therefore, detecting CH4 at leak relevant levels at normal atmospheric conditions is crucial for environmental and industrial safety considerations in gas production, transportation, and consumption/utilization. However, with the current state-of-the-art detection techniques, low-cost and high-performance detection of CH4 at very low concentration with a miniaturized integrated gas sensor is still a formidable challenge. In recent years, the advances in micro/nano-fabrication technology and the use of newly designed nanomaterials facilitate the development of cost-effective miniaturized integrated gas sensors that have enhanced sensitivity and selectivity towards target analytes. However, the generally weak interaction of CH4 with these nanomaterials makes its detection at low concentrations a considerable challenge in normal atmospheric conditions. Moreover, the presence of moisture in the order of few parts per thousand at normal atmospheric conditions often leads to false positives, jeopardizing gas selectivity. In this work, we introduce a new-class of nanocomposite based on zeolitic imidazolate framework–8 (ZIF-8) with bare multiwall carbon nanotubes (MWCNTs) and demonstrate its first ever usage as a sensing layer of a chemiresistive sensor for selective detection of CH4 at very low concentration of 10 parts per billion (ppb) with unprecedented repeatability and appreciable reversibility in normal atmospheric conditions. The limit of detection of this sensor is determined to be ~0.22 ppb. This outstanding performance could be attributed to the p-type semiconducting behavior of ZIF-8/MWCNT with a narrower band gap which could significantly enhance gas-sensing performance due to the easier sharing of electrons to make van der Waals interaction with CH4.

Presented By:

Setareh Homayoonnia

Student

University of Calgary

and

Seonghwan (Sam)

Associate Professor

University of Calgary

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