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North America's Leading Energy Event
June 7-9, 2022
BMO Centre at Stampede Park - Calgary, Canada

Co-Host
  • 8 00 AM
Registration Opens
  • 10 15 AM
Opening Plenary Doors Open
  • 10 30 AM

Opening Ceremony & Blessing

Welcome to Global Energy Show 2021

Join the Global Energy Show Executive Committee, National Coalition of Chiefs and special guests to celebrate the official launch this year’s event.

Attend...

  • locationROOM DE
  • small-arm10:30 AM - 10:45 AM
tuesday September 21, 2021

Opening Ceremony & Blessing

  • pr-alarm10:30 AM - 10:45 AM
  • pr-locationROOM DE

Welcome to Global Energy Show 2021

Join the Global Energy Show Executive Committee, National Coalition of Chiefs and special guests to celebrate the official launch this year’s event.

Attendee Insights

Hear from our special guests as we kick off the opening of this year’s conference and exhibition.

  • 10 45 AM

Ministerial Address

Canada is a leader in energy production from low-carbon fossil fuels to hydro-power, wind and solar and emerging clean technologies. Hear how policy and technology will play a key role in meeting C...

  • locationROOM DE
  • small-arm10:45 AM - 11:00 AM
tuesday September 21, 2021

Ministerial Address

  • pr-alarm10:45 AM - 11:00 AM
  • pr-locationROOM DE

Canada is a leader in energy production from low-carbon fossil fuels to hydro-power, wind and solar and emerging clean technologies. Hear how policy and technology will play a key role in meeting Canada’s global climate commitments.

Attendee Insights

Hear about the vision for the future of clean energy leadership.

  • 11 00 AM

Balancing Existing Realities of Oil & Gas Dependency with Ambitions for a Low Carbon World

The world’s demand for oil and gas continues to grow and the industry remains a key economic driver. While renewables are expanding quickly, oil and gas is still estimated to supply over 50% of the...

  • locationROOM DE
  • small-arm11:00 AM - 11:45 AM
tuesday September 21, 2021

Balancing Existing Realities of Oil & Gas Dependency with Ambitions for a Low Carbon World

  • pr-alarm11:00 AM - 11:45 AM
  • pr-locationROOM DE

The world’s demand for oil and gas continues to grow and the industry remains a key economic driver. While renewables are expanding quickly, oil and gas is still estimated to supply over 50% of the world’s energy needs by 2045. What are the economic, social and technological challenges that need to be addressed to meet both global energy demand and climate goals?

Attendee Insights:

Hear from participants across the energy sector debate where the future of energy is headed and how to get there.

  • 12 00 PM
Networking Luncheon & Visit Exhibition
  • 1 25 PM
TECHNICAL CONFERENCE
  • 1 30 PM

Monitoring Oil And Gas Facilities for Methane Emissions Using a Satellite-Aircraft Hybrid Systems Based on the Same Imaging Spectrometer System

Water & Environmental Management

Monitoring methane emissions from oil and gas facilities requires the combination of several technologies to gain a full understanding of the challenge at a manageable cost. The integration of freq...

  • locationROOM A
  • small-arm1:30 PM - 2:00 PM
tuesday September 21, 2021
Water & Environmental Management

Monitoring Oil And Gas Facilities for Methane Emissions Using a Satellite-Aircraft Hybrid Systems Based on the Same Imaging Spectrometer System

  • pr-alarm1:30 PM - 2:00 PM
  • pr-locationROOM A

Monitoring methane emissions from oil and gas facilities requires the combination of several technologies to gain a full understanding of the challenge at a manageable cost. The integration of frequent and affordable high resolution satellite measurements to find the larger leaks with less frequent aircraft surveys, forms the basis of a tiered monitoring system showing great promise to optimize Leak Detection and Repair (LDAR) activities. In this paper, we will present examples of methane emissions measurements at oil and gas facilities acquired with both GHGSat’s second satellite, Iris (launched in September 2020) and the airborne variant with the imaging spectrometer design. While the combination of different technologies is not uncommon, this system is the first in the world utilizing the same sensor concept at two different altitudes. The performance parameters of each system will be highlighted and supported with recent examples. In addition, the advantages of the hybrid system will be discussed, including the opportunity for cross-validation of measurements. Finally, the potential of such a system to be used for regulatory reporting purposes will be discussed and contrasted to the standard of performing Optical Gas Imaging (OGI) camera campaigns three times a year used in jurisdictions, such as in Canada and the US.

David Wares 300x300
David Wares Sales Director, Western Canada GHGSat Inc.
  • 1 30 PM

AI-Enabled, Automated Digital Dull Bit Analysis - The Future of Bit Wear Forensics

Drilling & Completion

Objectives/Scope: IADC dull bit grading is the current industry standard to document the condition of a dull drill bit. However, since today’s methods rely on human interaction and judgement, the...

  • locationROOM B
  • small-arm1:30 PM - 2:00 PM
tuesday September 21, 2021
Drilling & Completion

AI-Enabled, Automated Digital Dull Bit Analysis - The Future of Bit Wear Forensics

  • pr-alarm1:30 PM - 2:00 PM
  • pr-locationROOM B

Objectives/Scope: IADC dull bit grading is the current industry standard to document the condition of a dull drill bit. However, since today’s methods rely on human interaction and judgement, the resulting data is limited in terms of its accuracy, its consistency, and its comparability. As a result, the usefulness of this data in improving how bits are designed and operated is also limited. This paper describes a system that overcomes these limitations by performing automated digital bit dull grade analysis, forensics, and analytics. Methods, Procedures, Process: The system described incorporates the automated generation of a digital three-dimensional model of a dull bit, which is then analyzed digitally to assess bit wear, as well as other bit dull grade characteristics, on an individual cutter basis, as well as on an overall bit basis. Since the process is automated and digital in nature, the uncertainties related to human interaction and judgement in the process typically used today are eliminated. This data can also be used to identify drilling dysfunctions, and modify drilling procedures accordingly, to optimize performance. Results, Observations, Conclusions: Examples of digital dull bit analyses will be shown, which demonstrate that the bit wear data obtained from the system is much more detailed, more accurate, more consistent, and more comparable than the methods employed today. The resulting data is also much more suited to analytics, as well as other types of analysis, with a view to modifying bit designs and/or operational parameters, as well as identifying drilling dysfunctions causing bit damage. Novel/Additive Information: Dull bit grading is one of the only area areas of modern drilling operations that has not yet been digitized. The system described in this paper remedies this by performing automated digital bit dull grade analysis, thereby eliminating the issues with human interaction and judgement in today's bit dull grading processes. It represents an important advance in how bit dull forensic information is gathered, analyzed and utilized.

Ron Schmitz 300x300
Ronald Schmitz Executive Advisor Trax Electronics Inc.
  • 1 30 PM

Small Modular Nuclear Reactors as a Source of Heat and Power for the Petroleum Industry

Sustainable Electricity Generation and Grid Modernization

Small Modular Nuclear Reactors (SMNRs) are an emerging class of Nuclear Reactor that are smaller and more flexible than conventional Nuclear Power Plants. Early analysis of SMNRs has shown that the...

Sponsored By : INNIO Group

  • locationROOM C
  • small-arm1:30 PM - 2:00 PM
tuesday September 21, 2021
Sustainable Electricity Generation and Grid Modernization

Small Modular Nuclear Reactors as a Source of Heat and Power for the Petroleum Industry

  • pr-alarm1:30 PM - 2:00 PM
  • pr-locationROOM C
Sponsored By
inno_300x300.png

Small Modular Nuclear Reactors (SMNRs) are an emerging class of Nuclear Reactor that are smaller and more flexible than conventional Nuclear Power Plants. Early analysis of SMNRs has shown that these reactors are well matched to the demand profile of oil and petroleum processing, presenting a potentially viable, carbon-free supply of process heat and electricity. Many SMNR designs make use of innovative technology that allows them to provide high-grade heat while remaining flexible enough to integrate into existing or new operations. This paper will provide an introduction of SMNR technology, with a focus on how the technology can support the heat and power needs of the oil and petroleum industry. This will include an overview of various SMNR designs and the current state of the industry as well as an examination of potential uses for SMNRs in oil and petroleum processes. Proposed use cases include steam and power production for resource extraction, processing, and refining. Consideration will also be given to an economic comparison of SMNRs to incumbent technologies. This effort will highlight the value proposition of SMNR deployment to the oil & petroleum industries.

Evan Konarek 300x300
Evan Konarek Engineering Manager Nuclear Technology Hatch Ltd.
  • 2 00 PM

Automating Offshore Platform Fluid Leak Detection with Continuous, Analytic Thermal Imaging

Water & Environmental Management

As the vast majority of offshore well-pads and platforms are unmanned and remote, direct detection and confirmation of oil leaks can take hours or days. Such leaks have immediate and direct impacts...

  • locationROOM A
  • small-arm2:00 PM - 2:30 PM
tuesday September 21, 2021
Water & Environmental Management

Automating Offshore Platform Fluid Leak Detection with Continuous, Analytic Thermal Imaging

  • pr-alarm2:00 PM - 2:30 PM
  • pr-locationROOM A

As the vast majority of offshore well-pads and platforms are unmanned and remote, direct detection and confirmation of oil leaks can take hours or days. Such leaks have immediate and direct impacts on the environment and can expand and travel long distances in a short time. Immediate action is critical in plugging the leak source and containing further spread to protect marine life and fishing industries key to the economy. Together with these ecological goals, regulatory compliance, higher HSE best practice standards, financial risk reduction (clean-up bills, penalties, inefficiencies) and safeguarding of reputational image are key factors driving the development of better leak detection technologies. The presentation will offer insight into the application of thermographics (uncooled microbolometer) and edge-based artificial intelligence to automate detection of small leaks at remote platforms and provide operators with tools to visually validate leak candidates quickly and cost-effectively. Analytic thermal imaging is a relatively new, non-traditional fluid leak detection method adopted in the middle of the last decade by major oil and gas operators in North America. The fixed-format technology is being used to continuously and autonomously monitor above-ground onshore facilities, including pump stations and pig launching/receiving assets, and has clocked in 350,000 of field hours. The system looks for a temperature change in the scene and analyzes leak characteristics in real time using patented and proprietary image processing software, and generates alerts (with photo and video) for validated events. An evaluation commissioned by a global operator in the Gulf of Thailand led to the installation of this fully automated computer vision solution in mid-2019 for 24/7 offshore well pad monitoring. The process of installing the thermographic leak detection system involved the following stages: risk analysis and identification of high priority well pads, site evaluation to determine coverage and camera requirements (potential placement locations, field of view, etc.), system set up with testing (leak simulation using water) and two to three weeks of calibration, and training of operators and administrators. Installations are currently running without downtime, resulting in a low/no maintenance solution to date. Leaks of 1L/s and lower can be detected and alarmed on in less than 30 seconds, and visually verified within a minute. Due to low false alarm rates, operators can easily manage this additional solution without requiring additional resources. There are other advantages of using the system. These include the incorporation of a fixed low-cost color camera for routine visual checks reducing boat trips and manpower, low bandwidth consumption from only transmitting alarms rather than continuous raw data, integrating security/intrusion analytics, and distributed assets monitoring. Thermal sensors coupled with background learning AI provides leak detection and asset condition monitoring across a wide visual area, which may not have sufficient monitoring means. This aligns with the industry best practice of deploying multiple technology solutions to achieve complete or overlapping coverage. The application note will educate operators on the specifics of this new and automated solution, the installation procedure, and the advantages and benefits that can be gained by augmenting their existing monitoring approaches with round-the-clock eyes on site.

Shane Rogers New 300x300
Shane Rogers Chief Technical Officer IntelliView Technologies Inc
  • 2 00 PM

Rapid, Rigless, Live-Well ESP or PCP Deployment System

Drilling & Completion

The objective is to introduce a rapid, rigless, live-well ESP or PCP deployment system. The paper shall describe new and novel deployment equipment, well completion design, and installation methodo...

  • locationROOM B
  • small-arm2:00 PM - 2:30 PM
tuesday September 21, 2021
Drilling & Completion

Rapid, Rigless, Live-Well ESP or PCP Deployment System

  • pr-alarm2:00 PM - 2:30 PM
  • pr-locationROOM B

The objective is to introduce a rapid, rigless, live-well ESP or PCP deployment system. The paper shall describe new and novel deployment equipment, well completion design, and installation methodology that together have resulted in a technically and commercially feasible system that delivers the objective. The system and the associated methodology have been developed to mimic the design and deployment of a rod insert pump on continuous rod and capture the speed and live well deployment benefits and apply them to an ESP or PCP installation. In this case, a coiled tubing umbilical replaces the continuous rod and a novel bottom hole assembly is added to the artificial lift components. In one embodiment, the ESP may be in the conventional configuration providing adaptability to all vendors' equipment. Alternatively, the deployment technology may be applied to an inverted ESP configuration which allows for through casing completion and the option of external positively pressure motor lubrication. The concept of a coiled tubing deployed artificial lift is an old one. Notwithstanding this, the idea failed to gain widespread commercial acceptance. The novelty of this approach is to deliver a highly reliable and economical coiled tubing umbilical and design features in the deployment equipment that greatly reduce the rig in and rig out times. Another feature is the concept of using a structurally reinforced lubricator that allows for the shipment of a fully assembled pump and motor, thereby negating time in the field for assembly and service while improving the reliability of the end product. Both conventional and legacy coiled tubing artificial lift deployment systems have been plagued with time consuming field tasks. The design philosophy of this system has resulted in the elimination of most of these tasks. The result is reliable system that is faster, safer, and able to install in live well conditions, all delivered at a lower cost. This novel well completion and artificial lift deployment technology provides the practicing engineer with a positive alternative in applications where there are issues with rig availability, cable damage, tubing wear, rod wear, high installation costs, and reservoir damage from using kill fluids during conventional artificial lift installs and pulls.

Gerry Chalifoux 300x300
Gerry Chalifoux President and CEO Petrospec Engineering
  • 2 00 PM

Clean Energy Future with INNIO Group

Sustainable Electricity Generation and Grid Modernization

As leading OEMs in the energy transition, Jenbacher and Waukesha develop ways to provide a clean energy future for our customers. Both engine lines offer extensive advantages for companies looking...

Sponsored By : INNIO Group

  • locationROOM C
  • small-arm2:00 PM - 2:30 PM
tuesday September 21, 2021
Sustainable Electricity Generation and Grid Modernization

Clean Energy Future with INNIO Group

  • pr-alarm2:00 PM - 2:30 PM
  • pr-locationROOM C
Sponsored By
inno_300x300.png

As leading OEMs in the energy transition, Jenbacher and Waukesha develop ways to provide a clean energy future for our customers. Both engine lines offer extensive advantages for companies looking to meet ESG demands from the presence of climate change, governmental agencies, and investors. This presentation will focus on these new technologies and highlight two case studies, one for each OEM. In these case studies, customers utilized Jenbacher or Waukesha engines to meet new energy and emissions needs reliably, efficiently, and innovatively.

Case Study INNIO Jenbacher

In November 2020, the world’s first hydrogen engine in 1-megawatt (MW) range started field testing at the combined heat and power plant of HanseWerk Natur in Hamburg Germany. The INNIO Jenbacher CHP plant, located in Jürgen-Töpfer-Strasse in central Hamburg, has an electrical output of 999 kilowatts in natural gas mode and runs on variable hydrogen/natural gas mixes, as well as 100% green hydrogen. In addition this is also the first natural gas engine which has been converted to hydrogen operation in the field. The facility, which has been optimized for use with natural gas, is remarkable for its excellent overall efficiency of 93%. When operating with pure hydrogen or hydrogen blends, the output will be adjusted accordingly. The heat generated is fed into HanseWerk Natur’s local heating network, while electrical energy is fed into the grid and made available for recharging electric vehicles at the site when required. This case study will highlight the development, testing rigor, and operations of this plant and future opportunities for hydrogen in the power generation space.

Case Study INNIO Waukesha

As one of many North American emissions reduction programs, the Alberta TIER grant program released $80M CAD for producers looking to fund greenhouse gas (GHG) reduction programs for their TIER-regulated facilities in late 2020. Many operators with existing Series Two Waukesha engines were eligible to apply to support up to 75% of total project costs through the TIER program funding. Measured GHG reductions through the upgrades were significant, ranging from 30-50%. Significant reliability and throughput benefits were also realized through these upgrades, also offsetting upfront costs. Along with specific examples, this case study will focus on the benefits of these programs: allowing operators to upgrade or swing their equipment keeps end customers’ costs down through reduced operational costs and higher productivity while substantially reducing emissions throughout the natural gas value chain.

Jon Rowland 300x300
Jon Rowland Senior Sales Manager, Canada INNIO Group
Sean Manz 300x300
Sean Manz Lead Sales Manager, Canada INNIO Group
  • 2 30 PM
Coffee Break & Visit Exhibition
  • 3 00 PM

Online Analyzers to Automate Water Quality Control at In-situ Oil Sands Facility

Water & Environmental Management

Total inorganic carbon (TIC) alkalinity, hardness, pH and Silica are important parameters to control hot lime softening performance for produced water treatment. At present, Imperial’s Cold Lake i...

  • locationROOM A
  • small-arm3:00 PM - 3:30 PM
tuesday September 21, 2021
Water & Environmental Management

Online Analyzers to Automate Water Quality Control at In-situ Oil Sands Facility

  • pr-alarm3:00 PM - 3:30 PM
  • pr-locationROOM A

Total inorganic carbon (TIC) alkalinity, hardness, pH and Silica are important parameters to control hot lime softening performance for produced water treatment. At present, Imperial’s Cold Lake in-situ oil sands is relying on grab samples data collected in every four hours interval to make decisions on lime, caustic, magnesium Oxide and soda ash dosages to control Hot Lime Softeners (HLS) effluent water quality within specific targets. Online pH analyzers are proven to provide reliable measurements for some time. Online measurement of hardness and alkalinity can help optimize lime, caustic and soda ash dosages. Online analyzers have not been commonly used in the heavy oil industry, partly due to the challenge caused by high total dissolved solids, and high organic material present in the water. In this presentation, we will share online alkalinity and hardness analyzer’s trial results and performance. We tested HACH Biotechtor TOC/TIC analyzer, and HACH EZ1000 series hardness analyzer at Imperial Oil Cold Lake facility with the objectives of automating chemical adjustments and reducing reliance on frequent operator measurements. The technologies were first validated based on preliminary acceptable correlation between manual lab and online analyzer. HACH hardness analyzer was also installed at boiler feed water location to maintain acceptable water quality for once through steam generator (OTSG). Both Online TIC alkalinity analyzer and hardness analyzer’s performance are encouraging. With new installation of afterfilter effluent hardness analyzer, these will help optimize chemical dosages for HLS and achieve consistently good quality water to minimize OTSG fouling. Online TIC analyzer is in service for more than 2 years; and hardness analyzer for more than 6 months. Quarterly maintenance frequency is found to be adequate for these instruments. Several learnings were gained through the trials to make use of online analyzer’s successfully in challenging environment. The learning from the trial of these technologies will help to advance online analyzer applications for produced water hardness and alkalinity determinations. The success of online analyzers will open the door for data driven decisions based on machine learning and advanced analytics in near future.

Mohammad Kabir 300x300
Mohammad Kabir Water Treatment SME Imperial
  • 3 00 PM

Case Study of a Multilateral Closed-Loop Geothermal System, Alberta

Drilling & Completion

Results from a full-scale demonstration project of a multilateral closed-loop geothermal system are presented. The project is located near Sylvan Lake, Alberta, Canada and consists of two 1.7 km lo...

  • locationROOM B
  • small-arm3:00 PM - 3:30 PM
tuesday September 21, 2021
Drilling & Completion

Case Study of a Multilateral Closed-Loop Geothermal System, Alberta

  • pr-alarm3:00 PM - 3:30 PM
  • pr-locationROOM B

Results from a full-scale demonstration project of a multilateral closed-loop geothermal system are presented. The project is located near Sylvan Lake, Alberta, Canada and consists of two 1.7 km long multilateral horizontal wellbores connecting two 2.4 km deep vertical wellbores to create a U-tube shaped closed-loop geothermal system. The horizontal wellbores are intersected using magnetic ranging technology, and sealed with a novel completion technique, resulting in a giant subsurface heat exchanger. It is an entirely closed system with no flow into or out of the formation. A water-based working fluid is then circulated through the system, entirely driven by the thermosiphon effect created by the density difference between the inlet and outlet wells. Design and execution of the project is described, along with important results. Key performance indicators are drilling execution, operational leak-off rate, solids production, and thermodynamic performance. Thermodynamic output of the system is modeled and forecasted prior to the start of circulating operations. Pilot results are scaled-up to a realistic commercial project to demonstrate that a closed-loop multilateral system is technically and economically feasible. This technology is unconstrained by formation permeability and enables projects in areas without hydrothermal flow capacity.

Matt Toews 300x300
Matt Toews Chief Technology Officer Eavor Technologies Inc.
  • 3 00 PM

Abandoned Well Sites – Liability or Opportunity?

Technical Panel Session

The abandonment services marketing is expected to grow by $920 million globally to 2023, with a staggering number maturing and uneconomic oil and gas fields sitting idle. Alberta alone has close to...

  • locationROOM C
  • small-arm3:00 PM - 4:30 PM
tuesday September 21, 2021
Technical Panel Session

Abandoned Well Sites – Liability or Opportunity?

  • pr-alarm3:00 PM - 4:30 PM
  • pr-locationROOM C

The abandonment services marketing is expected to grow by $920 million globally to 2023, with a staggering number maturing and uneconomic oil and gas fields sitting idle. Alberta alone has close to 100,000 inactive and 70,000 abandoned wells.

While these well sites are a huge challenge for governments and asset owners, some groups are also analyzing how brownfield sites could be repurposed for new opportunities in geothermal, micro-solar, hydrogen, recovery of lithium, or carbon capture and storage.

What technology is being developed for this market and how are costs managed? What is the environmental impact? How do decommissioning liabilities affect operator balance sheets? What is the potential to repurpose these sites and what are the technical and regulatory challenges in doing so?

Audience Insights:

Hear from policy makers, service providers and operators on how they are navigating the challenges, and opportunities, of end-of-life oil and gas wells.

Moderator
Marla Orenstein 300x300
Marla Orenstein Director, Natural Resources Centre Canada West Foundation
Ariane Bourassa 300x300
Ariane Bourassa Senior Advisor, Government Relations Pomerleau
Grant Strem New 300x300
Grant Strem Chairman and Chief Executive Officer Proton Technologies Canada, Inc.
Tony Ciarla 300x300
Tony Ciarla Executive Vice President Millennium EMS Solutions Ltd.
  • 3 30 PM

Oil-Field Water Recycling with Methanol Recovery Technology

Water & Environmental Management

Oil-field water consists of a mixed stream of gas, liquid hydrocarbons and water. After recovery of the oil and/or gas, the produced water is reinjected into a disposal well. In cold weather there...

  • locationROOM A
  • small-arm3:30 PM - 4:00 PM
tuesday September 21, 2021
Water & Environmental Management

Oil-Field Water Recycling with Methanol Recovery Technology

  • pr-alarm3:30 PM - 4:00 PM
  • pr-locationROOM A

Oil-field water consists of a mixed stream of gas, liquid hydrocarbons and water. After recovery of the oil and/or gas, the produced water is reinjected into a disposal well. In cold weather there is a risk of freezing due to the presence of water and so a 50:50 ratio of methanol to water is injected into the mixed stream of oil-field water. Industry’s use of methanol in produced water is a critical tool for inhibiting the formation of hydrates, which can block production flow. The use of greater than 90% methanol purity and recovery are essential to a project’s economic viability, because significant operational cost savings are anticipated. The MRT prototype developed in collaboration with SAIT is a self-contained and automated pre-treatment process which will be integrated with the MRT process for extracting high purity methanol (>90%) from produced water consists of 3 unit operations: 1. Methanol concentration probe 2. Water pre-treatment 3. Methanol recovery Objectives of the Methanol Recovery Technology (MRT) project include the assessment of the current process and establishment of a design basis for enhanced methanol recovery leading to a finalized design, procurement and construction of a MRT pilot in Phase-1 for field testing in Phase-2. The scope incorporates real-time sensing, monitoring and automation to address the high fluctuations in oil-field feedstock water characteristics, in order to deliver reduced TDS (total dissolved solids) and TSS (total suspended solids) concentrations of 1000 ppm or less. The overall approach includes an assessment of water quality, including design considerations to conduct water treatment of variable produced water chemistries, methanol recovery rates and purity with recirculation and removal of undesirable water inputs or waste outputs. Activities include: 1. Conducting a technical review of existing system, an engineering evaluation and develop a design basis 2. Consolidating existing physical hardware, software, literature and technology-based items from MRT work done to date. 3. Completing an Assessment / recommend “systems-thinking” based sound solutions; 4. Building an enhanced, automated pretreatment system (Phase-1) and Field test the MRT system (Phase-2) An automated water treatment system that would integrate into the methanol recovery pilot to intake oil-field produced waters of high concentrations of TDS and TSS. The MRT propriety process involves separating the gas and produced water while recovering the methanol for recycling. Upon regeneration, the methanol is expected to be greater than 90% pure. This methanol recovery technology and project has the potential to reduce operating and environmental costs during the recovery and reuse of methanol as a hydrate inhibitor. Additionally, the presence of methanol helps to dehydrate the gas, lowering the water dew point, which may have the potential to lower the amount of glycol dehydration necessary downstream depending on the separator’s pressures and temperatures.

Rogelio Lozan 300x300
Rogelio Lozano Chemical and Process Engineer ARIS
  • 3 30 PM

Autonomous Fracturing Operations

Drilling & Completion

Objective: Reduce human decisions and intervention in the well swap process on hydraulic fracturing plug and perf operations. Method/Procedures/Process: Connect all service providers on the comple...

  • locationROOM B
  • small-arm3:30 PM - 4:00 PM
tuesday September 21, 2021
Drilling & Completion

Autonomous Fracturing Operations

  • pr-alarm3:30 PM - 4:00 PM
  • pr-locationROOM B

Objective: Reduce human decisions and intervention in the well swap process on hydraulic fracturing plug and perf operations. Method/Procedures/Process: Connect all service providers on the completion site on to a single master control system (fracturing, wireline, wellhead, pump down, water storage & transfer and sand storage). An algorithm reviews various sensor data points from sand, water, pumps and wellheads in order to determine if the stage was completed to the operator's requirement. If yes, then the master control system signals the wellhead control system to actuate valves to close the wellhead, once complete, the master control system receives a signal back from the wellhead control system to alert all services on site to move to the next step. Results: The algorithm is operating at 99% accuracy relative to human expectations, and 100% accuracy relative to the operator's specifications and has been successfully implemented for a Marcellus based oeprator. Observations: Human intervention has been removed from this small area of the operation which removes the probability of human error on the completion site, and increases consistency in operations. As this logic is scaled across more of the well swap process, the operation will continue to become faster and safer due to humans being removed from the repeatable process. This results in increased operational governance. Conclusions: The autonomous end of stage sequence through connection of various on site services' control systems is just the start as the industry moves to autonomous fracturing operations in the near future. This presentation details how it was done, and what is happening next. Novel info: Autonomous fracturing operations are closer than most realize because of the completions master control system being used to connect all services on the completions site.

Matt Steen 300x300
Matt Steen Chief Operating Officer Cold Bore Technology
  • 4 00 PM

Reconciliation and Inclusion of Traditional Ecological Knowledge in Environmental Management

Water & Environmental Management

Objectives/Scope: For centuries, Indigenous peoples have been stewards of the land. Recently many Indigenous leaders have obtained training in Western and Indigenous formats. Sharing these teachi...

  • locationROOM A
  • small-arm4:00 PM - 4:30 PM
tuesday September 21, 2021
Water & Environmental Management

Reconciliation and Inclusion of Traditional Ecological Knowledge in Environmental Management

  • pr-alarm4:00 PM - 4:30 PM
  • pr-locationROOM A

Objectives/Scope: For centuries, Indigenous peoples have been stewards of the land. Recently many Indigenous leaders have obtained training in Western and Indigenous formats. Sharing these teachings of combined learning will be important to successfully deal with climate change in all facets of development. Water and Environmental Management initiatives can benefit from the inclusion of Indigenous peoples their perspectives and knowledge systems; Elders, and other knowledge holders who have more than 10,000 years of cultural wisdom of the ecosystem and cycles of the land have many teachings to share. In this session we will share principles of how to braid traditional ecological knowledge, ways of knowing and western science and systems to reduce impacts to the natural environment during development. • Know what steps to take in bridging (World views), people, land, knowledge, processes, and sciences • Understand the concepts of Indigenous-world views of Native science and ways of knowing • Explore innovations and opportunities with Indigenous Nations to look for indigenous innovation and new ways of water and environmental management Methods, Procedures, Process: Indigenous people have cared for the land for centuries and this continues in our teachings and outreach. Indigenous Visions continues this rich tradition of teaching and continuous learning. Indigenous Visions has trained over 400 Indigenous Environmental Monitors since 2006. This experience has led to participation in full lifecycle and beyond generational aspects of oil and gas projects from survey to reclamation and reconciliation, in the board room with regulatory bodies and Indigenous Leaders. This vision carries from boots on the ground with a team of Indigenous Environmental Monitors and continues with Elders involvement, teaching and vision including ceremony. This vision involves understanding Treaties and Indigenous Rights, changing legislation both nationally and internationally from implementing the articles in the United Nations Declaration of the Rights of Indigenous Peoples to the National calls to Action from the Truth and Reconciliation Commission. The results of inclusion of Indigenous peoples on resource projects has been reduced environmental impacts and environmental assessments with a long-term lens that identifies Indigenous indicators different from the western indicators but complimentary for all project goals. Indigenous indicators involve incorporating the concerns of Elders and respecting spiritual and cultural values and ceremonies. Examples of projects where potential environmental impacts and concerns are flagged and not included in the western science observations and assessment will be discussed. The challenge today is finding ways to incorporate, educating field staff and bringing these World views together through policy, education, and actionable ways that ensure we are taking the learnings from our experiences. In this session we will share some of those experiences in the field and what can be done going forward.

John Snow 300x300
John Snow Advisor, Instructor and Consultant Indigenous Visions Inc.
  • 4 00 PM

A New Frac Cluster System to Improve Operational Efficiency and Reduce Environmental Impact: Design and Field Data

Drilling & Completion

Objectives / Scope The scope of the paper is design and results of the field trials of a new frac cluster system. The system allows operators to improve project economics and minimize the environme...

  • locationROOM B
  • small-arm4:00 PM - 4:30 PM
tuesday September 21, 2021
Drilling & Completion

A New Frac Cluster System to Improve Operational Efficiency and Reduce Environmental Impact: Design and Field Data

  • pr-alarm4:00 PM - 4:30 PM
  • pr-locationROOM B

Objectives / Scope The scope of the paper is design and results of the field trials of a new frac cluster system. The system allows operators to improve project economics and minimize the environmental impact, in particular by lowering water use and the amount of green house gas emissions. Methods, Procedures, Process The new frac cluster system has been developed as an alternative to plug-and-perf which is currently the most commonly used frac technique in North America. The paper provides details of the design and performance of the system and its comparison to plug-and-perf. The system has a number of operational, economic and environmental benefits. Thus, it requires less water, fuel and personnel, eliminates the use of coil tubing and wellbore clean-up. Several field trials in North America are ongoing. Up-to-date data show that the new system helps to reduce complexities, risks and costs and avoid limitations of frac operations. Thus, the new system eliminates the use of wireline, guns/setting tool/plugs, coiled tubing milling and wellbore cleaning which are required in plug-and-perf operations. Results, Observations, Conclusions The system features a compact, intelligent, programmable dart made of magnesium alloy. The dart is programmed and launched at surface to land in a specific sleeve. Reliable, miniature electronic onboard sensors allow the dart to track its location within wellbore and “activate” the dart before landing on to the target sleeve. The dart dissolves after the fracturing treatment behind a large bore for production. Darts pumped downhole to date have functioned as expected and operated target sleeves correctly, with the darts beginning to dissolve shortly after pumping operations have been completed. Novel/Additive Information The oil industry is thriving towards becoming more sustainable and environmentally-friendly. Unconventional hydrocarbons have an increasingly important role in meeting the world’s energy needs. Advancements in horizontal drilling and hydraulic fracturing lead to commercial production of unconventional oil and gas and “the shale revolution” in North America where plug-and-perf is the most common frac technique. Compared to the plug-and-perf technique, the new frac cluster system has a small footprint, requires less water, fuel and personnel and is associated with lower safety concerns. That allows operators to improve operational efficiency and reduce environmental impact.

Tom Watkins 300x300
Tom Watkins Chief Technology Officer Advanced Upstream
  • 5 00 PM
Networking Reception
  • 5 00 PM

Networking Reception

Sponsored By : Cummins

  • locationROOM DE
  • small-arm5:00 PM - 6:30 PM
tuesday September 21, 2021

Networking Reception

  • pr-alarm5:00 PM - 6:30 PM
  • pr-locationROOM DE
Sponsored By
GES-cummins.png
  • 6 00 PM
Day One of Technical Conference Concludes for the Day
  • 7 30 AM
Registration Opens
  • 8 30 AM

Virtual Site Visits for Pipeline Maintenance Programs Using Advanced Geospatial Technologies - A Sustainable, Safer and More Cost-Effective Approach

Pipeline & Processing Facilities

Pipelines are integral and essential infrastructure for the safe and efficient transport of oil and gas. Maintenance solutions employed to extend the longevity and safety of the pipeline network ar...

  • locationROOM A
  • small-arm8:30 AM - 9:00 AM
wednesday September 22, 2021
Pipeline & Processing Facilities

Virtual Site Visits for Pipeline Maintenance Programs Using Advanced Geospatial Technologies - A Sustainable, Safer and More Cost-Effective Approach

  • pr-alarm8:30 AM - 9:00 AM
  • pr-locationROOM A

Pipelines are integral and essential infrastructure for the safe and efficient transport of oil and gas. Maintenance solutions employed to extend the longevity and safety of the pipeline network are vital in protecting the public and the environment. These solutions include programs such as dig sites, cathodic protection, class upgrades, hydrotesting, and above-ground features replacements (valves, launchers, receivers, etc.). Pre-planning for any of these programs requires individual site visits to each location and a thorough inspection to capture imagery and data about the site, access routes, crossings information, communications connectivity, proposed workspace, and terrain condition. Traditionally, each site visit involves deploying construction crews to access and assess the site, quickly becoming costly and time-consuming for operators. Since most of these sites are remotely located, this also requires driving long access routes by off-road vehicles, introducing additional safety hazards along the way. In this presentation, we present a new approach to limit the number of boots on the ground and add an enhanced interactive web-based visualization interface. The objective is to provide a safer and cost-saving alternative, as well as a sustainable solution that can be used in several other asset management applications. This approach includes integrating several sources of data based on the application and scope, such as Remotely Piloted Aircraft System (RPAS), terrestrial and sub-surface systems (laser scanning, mobile mapping, Ground Penetrating Radar and 360 cameras) and traditional surveying and line locating. This integrated data will be coupled with the site database and any relevant attributes and hosted on a GIS-based web-portal, providing up-to-date data that can be accessed and easily navigated from any location. Case studies, which include real-life examples and samples of virtual site visits, will be presented. This includes a recent site visit for one pipeline operator using UAV flights highlighting the access points to remote sites in different provinces, 360 panoramic images (aerial and ground) showing the terrain condition, and all pipeline and access crossings. The example virtual site visit reduced the number of field personal onsite from an average of eight to only two, significantly mitigating safety hazards through elimination. Cost-savings of around 60 per cent versus previous traditional site visits were observed. The developed web-portal provided an enhanced interactive visualization tool for planning, decision making and future maintenance and operational programs. In addition, the hosted data on the web-portal is considered the base for the client’s asset management programs.

Mohamed Attia 300x300
Mohamed Attia Director, Pipeline Integrity & Advanced Technology GeoVerra
  • 8 30 AM

Green Hydrogen from Upstream Oil & Gas Facilities

Future of Fuels

ALBERTA H2 has developed a system that generates gaseous hydrogen and oxygen products employing much of the equipment that is typical of existing oil and gas facilities. It was designed to enhance...

  • locationROOM B
  • small-arm8:30 AM - 9:00 AM
wednesday September 22, 2021
Future of Fuels

Green Hydrogen from Upstream Oil & Gas Facilities

  • pr-alarm8:30 AM - 9:00 AM
  • pr-locationROOM B

ALBERTA H2 has developed a system that generates gaseous hydrogen and oxygen products employing much of the equipment that is typical of existing oil and gas facilities. It was designed to enhance and supplement the assets currently employed in Western Canada for oil and gas extraction and will be of primary interest to producers interested in reducing their carbon emission intensity (CI). The key component of our modular system is the Dynamic Hofmann Electrolyzer, which employs standard oilfield equipment, except that the materials of construction are both more robust and of a superior metallurgy (typically Duplex, PTFE). It employs a simple electrode design that actively protects against electrode degradation and system performance reduction. Side reactions are inhibited by careful pH control. The effect of sour components and hard water components have both been included for. In particular, there are provisions for the effective and quick removal of gas bubbles from the electrode surface. The device employs on-board, on-line cleaning to maintain electrode viability / conductivity. Electrode change-out (as required) can be done on-line. Turndown is 10:1 or more, depending upon the number of modules installed. At high voltage, electrode power density varies up to 50 Amp/dm2 (500 mA/cm2). Hydrogen generation efficiency can be 75% of Direct Current input, depending upon water quality and electrode cleanliness.

Richard Enns 300x300
Richard Enns Process Lead Acero Engineering
  • 8 30 AM

3D Printing Reservoir Sandstone as Analogue for Experimental Testing of Transport and Geomechanical Properties

Reservoir Engineering

Natural rocks can be heterogeneous due to complex diagenetic processes that affect mineralogy and pore architecture. Correlation of geomechanical and transport properties of rocks in three dimensio...

  • locationROOM C
  • small-arm8:30 AM - 9:00 AM
wednesday September 22, 2021
Reservoir Engineering

3D Printing Reservoir Sandstone as Analogue for Experimental Testing of Transport and Geomechanical Properties

  • pr-alarm8:30 AM - 9:00 AM
  • pr-locationROOM C

Natural rocks can be heterogeneous due to complex diagenetic processes that affect mineralogy and pore architecture. Correlation of geomechanical and transport properties of rocks in three dimensions can lead to large variances in data when tested experimentally. 3D-printed rock analogs made from sand is a promising alternative for experimental testing that can be used to calibrate different variables during geotechnical testing [6-9]. While 3D-printed sand is a homogeneous material, the parameters for creating grain packing, porosity and pore infill can be tuned to mimic specific geomechanical and transport properties. Initially, the 3D-printed specimens suffer from decreased density, uniform distribution of grains and lack of compressive strength. Herein, we detail our efforts at increasing the density through incorporating a roller in the printing process to compact individual layers. We also present how the density of rock analogs can be increased through incorporation of a more heterogeneous sand mixture that encompasses a wide range of grain size distributions, close to natural sandstones. Lastly, a relationship between binder saturation (that infills the pore space) of the 3D-printed specimens and the axial strength, dimensional control and porosity is described within. 3D printing of rock analogs is critical in pursuing rigorous destructive tests required for geotechnical and geological engineering because it can provide repeatable, controlled data on rock properties. The use of sand to create test samples for verification of experimental modelling is an unprecedented achievement that integrates geoscience and engineering. 3D-printed rock provides stakeholders with a tangible, physical specimen with repeatable properties for use in experimental studies.

Sergey Ishutov 300x300
Sergey Ishutov Research Fellow University of Alberta
Rick Chalaturnyk 300x300
Rick Chalaturnyk Professor, Geotechnical Engineering University of Alberta
  • 9 00 AM

Retrofitting Existing Pipelines for Fiber Optic Monitoring

Pipeline & Processing Facilities

Distributed fiber optic sensing has become a reliable method of preventative leak detection, ensuring pipeline integrity and delivering value added services such as pig detection/tracking and flow...

  • locationROOM A
  • small-arm9:00 AM - 9:30 AM
wednesday September 22, 2021
Pipeline & Processing Facilities

Retrofitting Existing Pipelines for Fiber Optic Monitoring

  • pr-alarm9:00 AM - 9:30 AM
  • pr-locationROOM A

Distributed fiber optic sensing has become a reliable method of preventative leak detection, ensuring pipeline integrity and delivering value added services such as pig detection/tracking and flow monitoring. A number of practical challenges such as the high risk and cost prohibitive nature of daylighting buried pipelines have resulted in the deployment of this technology being primarily limited to new pipeline projects. In this paper, we present internal deployment, among other potential retrofitting approaches, as a viable method of retrofitting existing pipelines, especially in high consequence areas. Hifi’s high fidelity distributed sensing system (HDS) is capable of sensing acoustics, temperature, strain, and vibration. We present a case study for the deployment of this sensor system inside and outside a gas pipeline in Canada. We will discuss the practical design considerations for deploying this technology inside a pipeline, including the use of tow pigs for pulling the fiber optic cable inside the pipe, proper design of a pig launcher, selection of appropriate pressure levels during fiber injection, and choosing a reliable dislodgement mechanism to separate the fiber optic cable from the tow pig. The paper will provide a comparison of the sensitivity levels of the internally and externally deployed fiber optic cables. Results from field verification and validation tests for the two sets of fiber optic sensors will be provided to showcase the effectiveness of internal deployment as a reliable pipeline monitoring solution. The field tests included tap tests, water and nitrogen based external leak simulations, and right-of-way ground disturbance testing. Some challenges with internal deployment will be reviewed as well, including deployment length limitations and the potential need to retract the fiber optic cable prior to pipeline pigging or closing any block valves. Possible solutions such as piggable internal deployments and automatically retractable lines will be discussed.

Neil Gulewicz  300x300
Neil Gulewicz Director, Deployment and Project Engineering Hifi Engineering
  • 9 00 AM

Navigating the Slow, Medium and Rapid Paths to Decarbonization

Future of Fuels

Objective/scope Demand uncertainty, increasing renewable competitiveness and growing climate change regulatory and policy frameworks are leading oil and gas companies towards an uptick in decarboni...

  • locationROOM B
  • small-arm9:00 AM - 9:30 AM
wednesday September 22, 2021
Future of Fuels

Navigating the Slow, Medium and Rapid Paths to Decarbonization

  • pr-alarm9:00 AM - 9:30 AM
  • pr-locationROOM B

Objective/scope Demand uncertainty, increasing renewable competitiveness and growing climate change regulatory and policy frameworks are leading oil and gas companies towards an uptick in decarbonization ? and down the pathway to an energy transition. A necessary change, but a growing challenge to navigate as companies become increasingly strapped for cash. With capital markets putting a closer eye on ESG and non-financial performance ?" some even taking action to divest ?" oil and gas companies must act now to accelerate their ESG performance and demonstrate their long-term value to secure the capital needed to see this down cycle through and become fit for the future. Methods/process Black swan events faced by oil and gas companies this year have demonstrated that no strategy is immune to disruption. This presentation will explore the factors that will drive a slow, medium and rapid adoption of decarbonization, and the importance of scenario planning to account for even the most unthinkable events when establishing a energy transition strategy. Results/conclusion There are three conclusions that we hope the audience will take away: • The relevance of scenario planning to create long-term strategies that are validated and stress-tested for uncertain and complex environments based on slow, medium and rapid decarbonization adoption scenarios. • The role technology will play as a key enabler to both reduce emissions and support measurement for effective disclosures that will build trust and transparency in capital markets. • How to successfully position the company to attract sustainable finance initiatives to support investments in infrastructure and renewable energy sources. Actioning these items to implement and measure decarbonization will help companies secure greater capital and attract the next generation workforce that the industry will require to move forward. Additional info This presentation will pull from first-hand experience on developing the approaches, addressing the challenges and learning the best practices from some of the world’s leading oil and gas companies as they implement decarbonization. It will also look beyond the energy sector to explore successful methods from our work with clients across other industries that can be applied to oil and gas companies.

Lance-Mortlock-300x300
Lance Mortlock Senior Strategy Partner and National Oil and Gas Leader EY Canada
Meghan Harris-Ngae 300x300
Meghan Harris-Ngae Partner & Western Canadian Leader, Climate Change, EHS & Sustainability Services EY Canada
  • 9 00 AM

Improvement In the Characterization of A Dry Gas Reservoir by the Integration of Seismic, Petrophysics, Geology and Reservoir Engineering: A Case Study in Colombia

Reservoir Engineering

Canacol Energy has been investing in improving the reservoir characterization of its assets by the use of modelling and simulation techniques. Those techniques make use of regular surveillance data...

  • locationROOM C
  • small-arm9:00 AM - 9:30 AM
wednesday September 22, 2021
Reservoir Engineering

Improvement In the Characterization of A Dry Gas Reservoir by the Integration of Seismic, Petrophysics, Geology and Reservoir Engineering: A Case Study in Colombia

  • pr-alarm9:00 AM - 9:30 AM
  • pr-locationROOM C

Canacol Energy has been investing in improving the reservoir characterization of its assets by the use of modelling and simulation techniques. Those techniques make use of regular surveillance data in a matter that allows geoscientist to understand the reservoir connectivity better to create accurate conceptual models that can be verified and fine-tuned with seismic data. One of the main improvements of this workflow is the integration of seismic attributes and surveillance pressure RFT, PLT, noise logs and production data to understand channel size, direction and connectivity between wells. Thanks to the integration of these data Canacol has effectively predicted sand connectivity, possible issues behind casing, and changes in estimates of OGIP. The use of RFT and noise logs data has proven to be specially effective in detecting vertical connectivity between sands that happens over time, increasing the volume of gas connected to the wells. This paper highlights the workflow used to characterize reservoirs using each piece of data, but understanding its limitations and uncertainties.

Andrea Bernal 300x300
Andrea Bernal Coordinator Reservoir Modelling & Simulation Canacol Energy Ltd
  • 9 30 AM

Getting to AI - Key Steps and Best Practices for Preparing Your Pipeline Company for AI

Pipeline & Processing Facilities

As an industry, we are striving towards the ability to be more predictive and proactive about our pipeline infrastructure’s construction, operations, and maintenance. One of the main ways that thi...

  • locationROOM A
  • small-arm9:30 AM - 10:00 AM
wednesday September 22, 2021
Pipeline & Processing Facilities

Getting to AI - Key Steps and Best Practices for Preparing Your Pipeline Company for AI

  • pr-alarm9:30 AM - 10:00 AM
  • pr-locationROOM A

As an industry, we are striving towards the ability to be more predictive and proactive about our pipeline infrastructure’s construction, operations, and maintenance. One of the main ways that this will be possible is through artificial intelligence. However, lost in the push for ML/A.I. solutions is the substantial data preparation efforts required to build a foundation of trustworthy and accessible data suitable for use in A.I.-based solutions. Expert estimates indicate that over 80% of a digital transformation budget must be allocated to gathering, standardizing, and validating the data sources that will drive our A.I. solutions. It is imperative that owner/operators consider the key steps and data best practices that must occur, both on new projects and on their existing infrastructure, to achieve a trustworthy and accessible baseline of data that will feed predictive analytical solutions. Current state includes vast arrays of data trapped in unusable formats, such as PDFs, along with data that has not been validated for traceability, accuracy, and conformance to specifications. Organizations must investigate their existing data and records, evolve how they purchase new material, and consider their data sources stemming from construction, operations, and maintenance. This change management will be critical for the industry as we move towards more digital operations. Presentation supported by two case studies (historical and new construction) and a use case of two 3D models illustrating what was engineered versus what was fabricated and installed showcasing how ML and AI are susceptible to the garbage in, garbage out scenario.

Brendan Boyle 300x300
Brendan Boyle President & CEO Vintri Technologies Inc.
  • 9 30 AM

Blue Hydrogen Cogeneration from GTL Plant

Future of Fuels

Blue Hydrogen Co-production from GTL Plant Authors (*): Jan Wagner, P.Eng. Wagner Energy Consulting Inc. Steve Kresnyak, P.Eng. Expander Engineering Services Inc. (*) Co-presenters as well Ba...

  • locationROOM B
  • small-arm9:30 AM - 10:00 AM
wednesday September 22, 2021
Future of Fuels

Blue Hydrogen Cogeneration from GTL Plant

  • pr-alarm9:30 AM - 10:00 AM
  • pr-locationROOM B

Blue Hydrogen Co-production from GTL Plant Authors (*): Jan Wagner, P.Eng. Wagner Energy Consulting Inc. Steve Kresnyak, P.Eng. Expander Engineering Services Inc. (*) Co-presenters as well Background World will move eventually towards decarbonization of energy sources and zero carbon hydrogen will be increasingly in demand. The ultimate hydrogen society will be based on green hydrogen. As green hydrogen is currently the least economic option, blue hydrogen could be the interim solution. Blue hydrogen is derived from natural gas and must include carbon utilization or sequestration. The immediate solution can be to co-produce hydrogen with synthetic clean fuel production, such as gas-to-liquids (GTL) plants, whereby the process carbon from the natural gas is captured and utilized in the synthetic fuel. Study Basis The traditional way to produce hydrogen is Steam Methane Reformer (SMR) technology with about 90% of world hydrogen being produced this way using natural gas as feedstock. The SMR process economically produces raw syngas with H2/CO ratios of 3.0 to 5.0 and the carbon is subsequently converted to CO2 and released to the atmosphere. The issue here is the disposal or utilization of CO2 if hydrogen is the only final product. The only solution is to install carbon capture and sequestration to achieve Blue Hydrogen and avoid CO2 emissions. Beside hydrogen production, syngas can be utilized for several downstream processes such as methanol or GTL. SMR inherently produces syngas with above stoichiometric H2/CO ratios. Excess hydrogen is therefore available and can be removed as valuable co-product and the carbon in the syngas can be fully consumed in the downstream synthesis. Significant CO2 emissions can be avoided. To verify the feasibility of this concept an existing small capacity GTL plant was used for a case study. Case Study Results The study was based on hydrogen co-production from an existing GTL plant with capacity 500 bpd employing SMR for syngas generation. Membrane is used for excess hydrogen removal from syngas. The plant operates typically at steam/carbon (S/C) ratio of about 2.0 to 2.8. and any excess hydrogen in the syngas is removed and recycled back to the SMR as fuel. Increasing the S/C ratio, the plant will produce more hydrogen, but the following variables will be impacted: total feed and fuel gas, SMR duty and to lesser extent CO2 emissions. A parametric study with varying S/C ratio was conducted to identify the impact on the above values. The study for the 500 bpd GTL plant over varying the S/C ratios, indicates favorable economic results and further verified significant improvement in overall GTL plant carbon intensity due to the credit from downstream use of carbon free hydrogen fuel.

Jan Wagner 300x300.jpg
Jan Wagner Principal Wagner Energy Consulting Inc.
Steve Kresynk 300x300
Steve Kresnyak VP & Chief Technology Officer Rocky Mountain GTL Inc. (RMGTL)
  • 9 30 AM

A Machine Learning Model for Predicting Multi-Stage Horizontal Well Production

Reservoir Engineering

In this study, a hybrid convolutional-recurrent neural network (c-RNN) is evaluated for making predictions of the five-year cumulative production profiles in multistage hydraulically fractured well...

  • locationROOM C
  • small-arm9:30 AM - 10:00 AM
wednesday September 22, 2021
Reservoir Engineering

A Machine Learning Model for Predicting Multi-Stage Horizontal Well Production

  • pr-alarm9:30 AM - 10:00 AM
  • pr-locationROOM C

In this study, a hybrid convolutional-recurrent neural network (c-RNN) is evaluated for making predictions of the five-year cumulative production profiles in multistage hydraulically fractured wells. The model was trained by using a combinations of completion parameters, rock mechanical properties, and well spacing and completion order for each stage of 74 wells in the Montney Formation in British Columbia. The prediction accuracy of the various combinations was measured by using the mean average percent error (MAPE) generated through the leave-one-out method. The best combination of inputs was found to be the rock mechanical properties surrounding each perforation cluster, the proppant amount used for every stage, and the spacing and completion order of neighboring wells. The novelty of this study is that the input variables used are at the stage level rather than the average of the entire well. The accuracy of the model was found to increase exponentially as the production of multiple wells was aggregated. The approach yields insights for planning new well drills in fields with existing development since it provides the ability to run multiple field development scenarios without having to spend capital.

Ilia Chaikin
Ilia Chaikine Petroleum Engineer Sproule
  • 10 00 AM
Coffee Break & Visit Exhibition
  • 10 30 AM

A Practical Approach to Achieving Environmental Goals Through Your Electrical Equipment

Pipeline & Processing Facilities

Oil & Gas companies face mounting pressure from all sides to achieve net-zero greenhouse gas emissions. Standards put forth by the Greenhouse Gas Protocol (GHGP) divide the emissions into three sc...

  • locationROOM A
  • small-arm10:30 AM - 11:00 AM
wednesday September 22, 2021
Pipeline & Processing Facilities

A Practical Approach to Achieving Environmental Goals Through Your Electrical Equipment

  • pr-alarm10:30 AM - 11:00 AM
  • pr-locationROOM A

Oil & Gas companies face mounting pressure from all sides to achieve net-zero greenhouse gas emissions. Standards put forth by the Greenhouse Gas Protocol (GHGP) divide the emissions into three scopes: Scope 1, 2, and 3. Although this decarbonization is a serious challenge, it does not have to be as costly as you may think. In fact, there are practical steps that can be taken with the electrical system that will realize reduced Scope 1 and Scope 2 greenhouse gas emission reductions while at the same time offer sizeable returns on investment to the operator.
Electric motors are the workhorses in a pipeline and processing facility. These electric machines account for up to 70% of the electrical loads. Applying medium voltage (MV) adjustable speed drives (ASDs) for flow control and energy savings have been well understood and documented for decades. This savings in turn reduces the electric demand and therefor the carbon footprint associated with the generation of that demand. Another less understood method of reducing greenhouse gas emission is using ASDs for power factor improvement. By improving power factor the operating will see a corresponding electric bill savings and reduce even further the carbon footprint associated with power generation. While ASD has historically been used to impact the bill's energy component, it's only recently that ASDs gained capabilities to influence the power factor. This is a powerful capability that makes a case for applying drives very compelling.
In this presentation, we give an overview of the Greenhouse Gas Protocols and practical solutions that can bring progress towards these goals using available technology. The presenter will provide a deeper understanding of the monetized value by a novel approach to applying an ASD that reduces your Scope 1 GHG while saving you significant electrical consumption and costs.

Stephan Bondy 300x300
Stephan Bondy Business Development Manager, Energy & Infrastructure Solutions TMEIC Corporation Americas
  • 10 30 AM

Clean Energy from Medium and Heavy Oil Reservoirs

Future of Fuels

Alberta is endowed with an oil and bitumen resource of 1.6 trillion barrels in place. Current in-situ (subsurface) extraction limits the recovery factor to no more than 40%. In Alberta, roughly 15...

  • locationROOM B
  • small-arm10:30 AM - 11:00 AM
wednesday September 22, 2021
Future of Fuels

Clean Energy from Medium and Heavy Oil Reservoirs

  • pr-alarm10:30 AM - 11:00 AM
  • pr-locationROOM B

Alberta is endowed with an oil and bitumen resource of 1.6 trillion barrels in place. Current in-situ (subsurface) extraction limits the recovery factor to no more than 40%. In Alberta, roughly 15 billion STB of medium to heavy oil (excluding bitumen and tar sands) are found within 1000 m of surface. It is recognized that there are substantial releases of CO2 by utilizing this energy source. Trindade Reservoir Services has developed and patented a process that utilizes a reconfiguration of existing petroleum and geothermal technology to generate temperatures well over 1000 degrees F in the reservoir and exploit this thermal resource. This enormous amount of heat can be harvested by the careful layout of wells and well types and process controls. This offers significant advantages over different geothermal methods of heat recovery. These include minimal geologic exploration risk, very low drilling costs and higher efficiency of enthalpy extraction per barrel of water circulated through the reservoir. In addition, hydrogen and ethane generation (subsurface and surface) can also be generated, both subsurface and on surface using excess electricity capacity, which can be sold to market. The process is energy sufficient and all CO2 and other undesirable byproducts can be captured and stored in a deep geologic zone or sold for use in CO2 based EOR processes. The process reduces reliance upon oil pipeline export capacity and does not rely upon a significant source of water, and is scalable as the process matures and results of the reservoir response become clear. The process has flexibility to produce electricity, hydrogen or upgraded oil, allowing for the optimization of profitability as commodity prices change. The process has been validated by numerical simulation and economic evaluation.

Michael Aikman 300x300
Michael Aikman President Trindade Reservoir Services Inc.
  • 10 30 AM
wednesday September 22, 2021
Technical Panel Session

Hydrogen and Fuel Cells for Heavy-Duty Transportation

  • pr-alarm10:30 AM - 12:00 PM
  • pr-locationROOM C

Heavy-duty transportation is one of the best early applications for hydrogen and fuel cell technologies. To transition towards net-zero carbon neutrality by 2050, Canadian cities must adopt fuel cell electric buses and trucks in their urban fleets. For transit agencies and trucking operators, hydrogen powered buses and trucks are a proven zero-emission solution that offer excellent performance in terms of longer routes, colder weather, higher power requirements. In this session panelists will discuss the advantages of zero-emission hydrogen and fuel cell solutions for heavy-duty transportation, fueling infrastructure, and what is needed to overcome barriers to adoption.

Moderator
Mark Kirby 300x300
Mark Kirby President and CEO Canadian Hydrogen and Fuel Cell Association (CHFCA)
Terry Howe 300x300
Terry Howe Business Development Manager Ballard Power Systems
Milan Yang 300x300
Milan Yang Green Hydrogen Specialist Hatch
George Rubin 300x300
George Rubin Chief Commercial Officer Loop Energy
Doug Duimering 300x300
Doug Duimering VP Business Development Strategy Next Hydrogen Corporation
Laurent Amram 300x300
Laurent Amram Manager, Business Development, Advanced Gas Purification Systems Xebec
  • 11 00 AM

Integrated Planning and Construction Methodology for Energy Projects

Pipeline & Processing Facilities

Although there is an effort to implement the best project management practices worldwide, energy projects, regardless of size, complexity, or industry, still experience difficulties meeting the thr...

  • locationROOM A
  • small-arm11:00 AM - 11:30 AM
wednesday September 22, 2021
Pipeline & Processing Facilities

Integrated Planning and Construction Methodology for Energy Projects

  • pr-alarm11:00 AM - 11:30 AM
  • pr-locationROOM A

Although there is an effort to implement the best project management practices worldwide, energy projects, regardless of size, complexity, or industry, still experience difficulties meeting the three successful criteria. These criteria are: delivered on time, with a final actual cost on or below budget, and in full compliance with the technical and regulatory requirements. Energy projects are capital intensive, risky, and complicated endeavor. The larger the energy project, the greater the percentage of cost overrun and schedule slippage. It is imperative to reverse this trend to maintain a competitive edge in the energy sector. Two of the primary reasons why energy projects still experience difficulties to be successful are as follows. Firstly, the planning and construction phases are performed in a non-integrated way, where information is segregated into multiple systems, adding complexity to the challenging project environment. Secondly, the current practice to determine the project status during construction, using the activity percent complete technique, is an indirect and subjective method to determine progress. During the construction phase, project and construction managers are left tracking thousands of activities and tasks from multiple different contractors, and lose sight of the bigger picture. With an integrated approach, the planning phase's modeling starts with defining the scope of work ? with a results-based work breakdown structure, a work plan schedule, and a cost estimate based on project results defined as deliverables and work packages. During the construction phase, project performance is measured using earned value and earned schedule. Earned value is credited as deliverables and work packages are completed using the binary theory. This theory is a simplified approach to credit value only for the physical work completed, increasing objectivity to determine the project percent complete and forecast final cost and completion date when closing each measurement reporting period during construction. Combining this result-oriented concept with a simplified application of earned value and earned schedule facilitates the planning and construction phases. It also increases the probability of success because projects are handled more objectively and proactively, based on performance. Besides, the integration with the financial system (invoicing) allows for tracking profit margins by deliverables. This methodology also enables monitoring programs and portfolios more effectively due to the consistency in recording productivity and efficiency indices (CPI and SPI, respectively), project percent complete, and forecasts of final cost and completion date. This integrated planning and construction methodology was developed to encourage private companies and government organizations to introduce changes in the way construction projects are handled nowadays to track margins, improve performance, and increase profits. The main challenge is to overcome current common practices during the planning and construction phases of energy projects.

Williams Chirinos 300x300
Williams Chirinos President Inexertus, Inc.
  • 11 00 AM

Maximization of Biogenic Content in Finished Fuels by Co-processing Hydrofaction® Products with Petroleum Feedstocks

Future of Fuels

Refineries and long-haul transport fuel users seek to adopt low carbon solutions to cover fuel demand while complying with the GHG reduction targets for 2030. However, there is a gap between renewa...

  • locationROOM B
  • small-arm11:00 AM - 11:30 AM
wednesday September 22, 2021
Future of Fuels

Maximization of Biogenic Content in Finished Fuels by Co-processing Hydrofaction® Products with Petroleum Feedstocks

  • pr-alarm11:00 AM - 11:30 AM
  • pr-locationROOM B

Refineries and long-haul transport fuel users seek to adopt low carbon solutions to cover fuel demand while complying with the GHG reduction targets for 2030. However, there is a gap between renewable fuel producers, technology developers and refineries due to a lack of long-term reliable data to di-risk the incorporation of renewable molecules as feedstocks for upgrading at existing refineries. Furthermore, understanding storage and process requirements for co-processing and stand-alone upgrading of biocrude oils are crucial to facilitate the adoption of these feedstocks and define their market pathways. Steeper Energy is working towards bridging this gap by enabling existing refinery infrastructure to incorporate Hydrofaction® products as co-processing feedstocks. Advancements on biocrude stability, blending, and compatibility with petroleum feedstocks and identifying suitable pathways for co-processing have been carried out at Steeper’s Advanced Biofuels Centre in collaboration with catalysts manufactures and refineries. Hydrofaction® Oil is energy-dense, with a high heating value (HHV) of 38 MJ/kg, has low oxygen (~10 wt.%) and water content compared to other biocrudes and is rich in diesel boiling point range hydrocarbons. Although Hydrofaction® Oil resembles its fossil counterparts, its distinct properties need to be considered for upgrading, i.e., viscosity, total acid number (TAN) and oxygen content. Raw Hydrofaction® Oil may be used as a multi-purpose heavy fuel oil for large reciprocating engines such as those used in marine propulsion and power generation. Due to its oxygen content, Hydrofaction® Oil has physical and chemical properties that differ from petroleum which affect its blend-ability. Extent of blending is dependant on the polarity and heteroatom content of the blending feedstocks. Therefore, upgrading of the Hydrofaction® Oil is required to reduce the heteroatom content, viscosity, and density, as well as increase its HHV and H/C ratio, to enable complete compatibility with petroleum feedstocks. Partial upgrading results in improved blending, and in some cases full blend-ability with petroleum derived Vacuum Gas Oil (VGO). This upgrading stage decreases the biocrude’s oxygen content, TAN, viscosity, density, and micro-carbon residue, and improves its thermal stability while shifting its boiling point distribution towards lighter hydrocarbons. Optimal blends that were hydrotreated at industrially relevant conditions did not considerably affect the desulfurization yield compare to VGO baseline. The biogenic distribution for various process schemes was determined; results have shown the maximization of biogenic content in liquid fractions.

Julie Rodriguez 300x300
Julie Rodriguez Senior Renewable Oil Upgrading & Manager of Advanced Biofuels Centre Steeper Energy Canada Ltd.
  • 11 30 AM

Operating Wells By Exception Using Remote Video Analytics and Automation

Pipeline & Processing Facilities

Due to current economic and operational challenges, HSI’s clients approached us to design a remote monitoring system. There were a number of challenges present for site operation, including access,...

  • locationROOM A
  • small-arm11:30 AM - 12:00 PM
wednesday September 22, 2021
Pipeline & Processing Facilities

Operating Wells By Exception Using Remote Video Analytics and Automation

  • pr-alarm11:30 AM - 12:00 PM
  • pr-locationROOM A

Due to current economic and operational challenges, HSI’s clients approached us to design a remote monitoring system. There were a number of challenges present for site operation, including access, geographical limitations, staffing constraints, limited time on each location, environmental risks, and safety concerns. We devised a solution that could provide automated 24/7 site information via high speed wireless data utilizing integrated cameras and new AI features. We collaborated with technology manufacturers as well as Calgary-based energy producers. The goal was to incorporate their viewpoint as the on-site well operators. With their support and our design we created our new consumer-level industrial technologies product with no monthly operational costs or upkeep requirements. We have a selection of cameras offering a wide range of options for each application. This includes Pan-Tilt-Zoom for cameras that require movement, as well as fixed cameras for watching a specific location or device, thermal imaging for seeing potential HSE concerns or alerting operations changes, and explosion proof cameras for views within hazardous locations or even vessels. Our team was also mindful or the requirement for multiple voltages: 12vdv, 24vdv, 120vac, and solar/TEG offerings. We approached our first product from the viewpoint of our customers’ needs ? which meant tailoring the solution towards monitoring remote wellheads and locations. Then we built on that success by creating large wireless point to point networks to allow customers to add more devices. These networks started with simple connections (under 400 meters) and moved up to a couple kilometers. We then reached multi-points from multiple towers and connections tied into large scale multi-kilometer network assemblies. With our data back bones in place and our customers positively responding to the idea of owning their own equipment with no monthly costs, we put our sights on creating more innovations for our applications. In the end we created a design for sites that utilize a wireless backbone and a camera with installation for approximately $1,000 per location. With the support of our technology partner, Hikvision, we have implemented applications for ColorVu night vision. This technology allows for ultra high-definition views with full color in the darkest of conditions on remote wells without the requirement of additional lighting or infrastructure. We streamlined the IT operation with the integration of Hik-Central and the use of Microsoft active directory - allowing a simple way of connecting to the applications and maintaining user databases. Driven by the demands at the field level, our next offering was to allow monitoring of sound from site and to provide the ability to speak to people on locations. The sound-from-site was a request from a user with older wells who had a risk of pump jacks being off balanced and making noise or having a gas leak on the wellhead. Our next request was a bi-spectrum thermal imager on site with dual lens - thermal and HD video - for less than $1,500. Once again, with the support of Hikvision we attained this and now have them implemented on locations with for leak detection, packing failures, SAGD wellhead and flowline issues, pipeline and header monitoring. We are proud to offer a dedicated view on location solution with integrated AI to support your production, midstream, and refining processes

Brodie Tebay 300x300
Brodie Tebay Managing Partner - COO HSI Group
  • 11 30 AM

Feasibility of Hydrogen Production from Municipal Solid MSW by Gasification

Future of Fuels

Hydrogen is an alternative to fossil fuel with many benefits. It produces zero carbon emissions in use, is critical to decarbonizing industrial processes. However, while hydrogen is a potential pr...

  • locationROOM B
  • small-arm11:30 AM - 12:00 PM
wednesday September 22, 2021
Future of Fuels

Feasibility of Hydrogen Production from Municipal Solid MSW by Gasification

  • pr-alarm11:30 AM - 12:00 PM
  • pr-locationROOM B

Hydrogen is an alternative to fossil fuel with many benefits. It produces zero carbon emissions in use, is critical to decarbonizing industrial processes. However, while hydrogen is a potential product of the MSW gasification process, it is not currently a priority. This research explores the feasibility of adjusting the gasification of MSW to maximize hydrogen production through a technoeconomic analysis.

Canada’s estimated total municipal waste generation is about 25 million tonnes per year, 15% of which is from Alberta. This translates to a Canadian average of 720 kg of waste per person and an Alberta average of 1,000 kg of waste per person, the highest in the country. Gasification is one of the most promising thermochemical recycling techniques for extraction of the untapped energy that make up plastics and other biomass waste in MSW. Syngas consists of a mixture of Hydrogen (H2) and carbon monoxide (CO), which can be converted to electricity, renewable diesel, ethanol, hydrogen, fertilizer and other renewable chemicals. As MSW is considered a negative value waste stream, MSW gasification produced hydrogen, coupled with carbon sequestration, has the potential to economically produce hydrogen with zero or negative greenhouse gas (GHG) emissions.

Existing research has shown that the addition of some plastics at certain ratios to biomass waste can enhance the hydrogen production concentration in the syngas. Gasifying waste streams is also often constrained by contaminants in the feedstocks since they are known to bind with and disable the catalysts needed to drive the gasification process to the production of desirable end products like hydrogen. These results are used to evaluate the optimum composition of feedstock for gasification of MSW (plastic, wood and cardboard waste) in Alberta.

The economic feasibility of this process is also analyzed in light of the gradual increase of carbon tax to $170/ton of CO2 by 2030. In addition, the feasibility of the addition of a carbon capture, utilization and storage (CCUS) facility to such plants is analyzed from an environmental and economic standpoint. Through this research’s conclusions pathways to additional plastic and biomass waste gasification deployment for hydrogen production combined with CCUS in Alberta is highlighted and the conditions under which the process can be economically feasible will be discussed. This in turn will lead to further reductions in Canada’s GHG emissions, support the drive to carbon net zero and support the Canada Wide Strategy on Zero Plastic Waste.

Coauthors: Dr. Daya Nhuchhen, PhD, Peng, Energy Systems Analyst, Canadian Energy Systems Analysis Research (CESAR) Initiative, University of Calgary
Dr. David B. Layzell FRSC, Energy Systems Architect, The Transition Accelerator, Professor and Director, Canadian Energy Systems Analysis Research (CESAR) Initiative, University of Calgary; Dr. Josephine Hill, Professor, Department of Chemical and Petroleum Engineering, University of Calgary

Behna Afsahi LaFrenz 300x300
Behnaz Afsahi LaFrenz Sustainable Energy Development Graduate Student University of Calgary
  • 12 00 PM
Lunch & Visit Exhibition
  • 1 30 PM

OTSG: Steam Boiler Feed Water - Potential Solutions with the Use of Additives

Water & Environmental Management

Once Through Steam Generators (OTSGs) recycle steam-assisted gravity drainage (SAGD) produced waters for steam production to improve energy efficiency and lower the environmental footprint of the S...

  • locationROOM A
  • small-arm1:30 PM - 2:00 PM
wednesday September 22, 2021
Water & Environmental Management

OTSG: Steam Boiler Feed Water - Potential Solutions with the Use of Additives

  • pr-alarm1:30 PM - 2:00 PM
  • pr-locationROOM A

Once Through Steam Generators (OTSGs) recycle steam-assisted gravity drainage (SAGD) produced waters for steam production to improve energy efficiency and lower the environmental footprint of the SAGD operations. Additionally, the increased water recycle rates helps conservation of water. SAGD produced waters contain considerable amounts of dissolved constituents including calcium, magnesium, iron, sodium, silica, organics and suspended matter during bitumen recovery which are treated to meet boiler feed water (BFW) quality. Despite treatment some of these BFW constituents are prone to cause mineral (scale) and organic precipitates (fouling) upon heating during steam-generation, resulting in higher tube wall temperatures, which can cause premature OTSG failure. A state-of-the-art pilot OTSG pilot skid was built in collaboration with ConocoPhillips to investigate the chemical and process changes to reduce the inorganic and organic tube fouling occurrences in OTSGs, while improving the efficiency of steam generation. The objective of this study was to systematically investigate the efficacy of four chemical additives against tube scaling/fouling with synthetic and SAGD boiler feed water chemistries under high pressure and temperature operating conditions. The relative performance of four chemical additives was evaluated against synthetic and actual SAGD boiler feed water chemistries under operating conditions of ~314°C temperatures and ~11 MPa pressure. The additives include: ‘Additive A’: a boiler polymer; ‘Additive B’: a boiler polymer with silica inhibitor; ‘Additive C’: a silica inhibitor; and ‘Additive D’: an organic dispersant. Within the first phase of experiments, the baseline skin temperature profiles for the synthetic and SAGD boiler feed water chemistries were established. Each additive was then applied to identify any changes in the performance of the OTSG pilot skid. A combination of process conditions, chemistries, surface temperature profiles and ion balance analyses were used to evaluate the comparative efficiency of each additive and identify any changes in behavior and performance. ‘Additive A’, boiler polymer, showed a decrease in the skin temperature relative to the baseline indicating it’s effective in reducing the extent of scaling/fouling occurring within the skid. While being effective in reducing scaling/fouling extent, the ion balance studies showed the ‘Additive A’ resulted in significant precipitation of magnesium silicates within the pilot skid. ‘Additive B’, boiler polymer with silica inhibitor, showed similar results as ‘Additive A’, with reduced precipitation magnesium silicate salts. Upon comparison of skin temperature profiles, the ‘Additive D’, organic dispersant, showed the best performance amongst the additives, with a significant decrease in the skin temperature relative to the baseline. Overall, the results obtained from this study will be used to help industry enhance the understanding of potential problems and solutions associated with dissolved organics and inorganics in OTSG boiler equipment fouling and scaling with additives that may accelerate water recycle rates and reduce the environmental footprint.

Aprami Jaggi 300x300
Aprami Jaggi Research Scientist Southern Alberta Institute of Technology (SAIT)
  • 1 30 PM

Biomass Gasification and FT conversion into Renewable Synthetic Paraffinic Diesel and Jet

Future of Fuels

Expander Energy is a Calgary based Energy Technology firm that has developed a patented suite of transportation fuel production technologies based on the Fischer-Tropsch conversion method using Bio...

  • locationROOM B
  • small-arm1:30 PM - 2:00 PM
wednesday September 22, 2021
Future of Fuels

Biomass Gasification and FT conversion into Renewable Synthetic Paraffinic Diesel and Jet

  • pr-alarm1:30 PM - 2:00 PM
  • pr-locationROOM B

Expander Energy is a Calgary based Energy Technology firm that has developed a patented suite of transportation fuel production technologies based on the Fischer-Tropsch conversion method using Biomass, Natural Gas and Bitumen residue as feedstock for the process. Fischer Tropsch Gas to Liquids Expander (through its affiliate company Rocky Mountain GTL) will start-up its first Natural Gas to Liquids (EGTL™) facility in Carseland Alberta in Q2 2021. The Facility will produce 500 BPD (28 million liters/year) of Synthetic Paraffinic Diesel and Naphtha as well as 16 tonnes/day of surplus Hydrogen. Biomass / Gas to Liquids Expander in partnership with the Vanderwell Sawmill, are in the final stages of developing a Biomass to Diesel Facility in Slave Lake Alberta. The Slave Lake facility will be a commercial demonstration of Expanders Biomass / Gas to Liquids (BGTL™) technology. We expect that the plant will be operational in Q3 of 2022. The facility will utilize 22.4 t/day of forestry waste plus 1.5 mmscfd of natural gas to produce 120 BPD (6.1 million liters/year) of low carbon Synthetic Paraffinic Diesel (SPD) and / or FT Synthetic Paraffinic Kerosene jet fuel (FT-SPK) and Naphtha. Expanders BGTL facility when running at full production will produce 45 BPD of renewable paraffinic diesel (SPD) with Carbon Intensity of 3.7 gCO2/MJ and 70 BPD of natural gas derived Synthetic Paraffinic Diesel (SPD). with a blended carbon intensity of 56.8 gCO2e/MJ (43% less than the BC LCFS default of 98.96 CI) The facility will also produce 2.7 tonnes / day of surplus low carbon intensity “blue” hydrogen for transportation, industrial and residential use. Front End Engineering for the Slave Lake Biomass to Diesel facility is complete and we expect to have Governmental regulatory approvals in hand by Mid January 2021. Expander expects to have project financing finalized and make a final investment decision in late January 2021 In Slave Lake, the gasifier will utilize forestry residual hog material as feedstock. Expander plans to test the gasifier using osb cut-offs, agricultural by-products, landfill redirect, municipal sludge and railway ties. We expect that on completion of our commercial demonstration the Slave lake facility will be immediately expanded, and several other prospect locations will be developed. On successful commercial demonstration in Slave Lake, further development will proceed on Expanders next generation Biomass / Electrolysis to Liquids (BETL™) technology. Electrolysis of water is utilized in lieu of natural gas to balance the H:CO ratio for FT conversion. This technology will result in zero Carbon Intensity (CI) fuel production when using low CI / Hydro electricity in jurisdictions like BC, Manitoba, Quebec and Labrador. Expanders suite of technologies will utilize plentiful Canadian natural gas and non-food related biomass to create a sustainable domestic supply of low CI Synthetic Diesel / Jet fuel and reduce the Carbon Intensity of the Canadian transportation energy mix.

Gord Crawford 300x300
Gord Crawford VP Engineering Expander Energy Inc.
  • 1 30 PM

Biodiesel as Surfactant Additives to Improve Efficiency of Unconventional Oil Recovery Processes

Reservoir Engineering

In Alberta, Canada steam assisted recovery processes, such as SAGD and CSS processes are commercially used for bitumen and heavy oil production. Recently, oil industry invested in development of s...

  • locationROOM C
  • small-arm1:30 PM - 2:00 PM
wednesday September 22, 2021
Reservoir Engineering

Biodiesel as Surfactant Additives to Improve Efficiency of Unconventional Oil Recovery Processes

  • pr-alarm1:30 PM - 2:00 PM
  • pr-locationROOM C

In Alberta, Canada steam assisted recovery processes, such as SAGD and CSS processes are commercially used for bitumen and heavy oil production. Recently, oil industry invested in development of solvent co-injection with steam processes to improve bitumen recovery by reducing bitumen viscosity, which resulted limited commercial success. At our laboratory reduction of bitumen-water interfacial tension using surfactants was studied to improve bitumen recover efficiency by reducing bitumen-water interfacial tension. For this purpose, we studied in-situ sulfonation-sulfoxidation of bitumen asphaltenes to surfactant species by injecting a trace amount of gaseous SO2 with steam and co-injection of biodiesel (BD) as a surfactant additive with steam. BD is the commercial name of fatty acids methyl esters (CnHm-COO-CH3; m<2n+1), which behave as molecular surfactants by possessing hydrophobic (CnHm) and hydrophilic (COO-CH3) functional groups. BD are immiscible with water, boil at 325-400 oC temperatures at atmospheric pressure, possess sufficiently high vapor pressure, where saturated BD concentrations in steam are high enough to perform as surfactant additive under SAGD and CSS operating conditions. Laboratory scale bitumen recovery tests supported with interfacial tension measurements on BD-bitumen-pentane-water systems show that, BD is a suitable surfactant additive at about 2 g-BD/kg-bitumen dosages (corresponds to 0.670-kg/ton-steam if W/B ratio is 3:1) to improve bitumen recovery efficiency by about 40%. Interestingly, our tests simulating solvent co-injection with steam operating conditions resulted in lower bitumen recovery efficiency, which could indicate the importance of bitumen-water interfacial tension on bitumen mobility, therefore, recovery efficiency. We are expanding our research on use of BD as surfactant additives for UOR process. For this purpose, BD-water emulsions flooding, potentially with polymer addition also, are being studied for cold heavy oil, CHOPS, Post CHOPS and tertiary oil recovery applications. BD-solvent (light hydrocarbons)-water flooding will be studied for extra viscous heavy oil recover, and bitumen recovery from high permeability reservoirs. The present paper will present data generated on solvent versus surfactant co-injections with steam for bitumen recovery, and mathematical models on the effect of slip velocity at bitumen-water interface on oil recovery efficiency. Key Words: Biodiesel as surfactant additive for SAGD and CSS processes, oil-water interfacial tension and oil mobility, biodiesel-water and biodiesel-solvent-water emulsions flooding.

Baki Ozum 300x300
Baki Ozum Director Apex Engineering Inc.
  • 2 00 PM

How to Successfully use Low Temperature Thermal Desorption for Remediation of Hydrocarbon Contaminated Soil

Water & Environmental Management

Nelson Environmental Remediation (NER) has been offering Low Temperature Thermal Desorption soil remediation services for over 20yrs. The most commonly used method to treat hydrocarbon impacted so...

  • locationROOM A
  • small-arm2:00 PM - 2:30 PM
wednesday September 22, 2021
Water & Environmental Management

How to Successfully use Low Temperature Thermal Desorption for Remediation of Hydrocarbon Contaminated Soil

  • pr-alarm2:00 PM - 2:30 PM
  • pr-locationROOM A

Nelson Environmental Remediation (NER) has been offering Low Temperature Thermal Desorption soil remediation services for over 20yrs. The most commonly used method to treat hydrocarbon impacted soil is disposal at a landfill site. This method, however does not remediation the soil, it merely re-locates the problem while the property owner maintains the liability and is not sustainable in the long term. Low Temperature Thermal Desorption (LTTD) is an innovative process of remediating hydrocarbon contaminated soils, sediments and sludge in a sustainable manner which preserves the remediated soil for re-use that eliminates liability. LTTD is an Ex-Situ means of physically separating volatile and semi volatile organic contaminants from the soils through application of heat, incorporating sound environmental practices. Hydrocarbon impacted soils are placed in a chamber, and heated to volatilize the hydrocarbons. The contaminated gaseous vapors are then run through a bag house to remove particulates and the contaminants destroyed using a thermal oxidizer., converting them into carbon dioxide and water. The clean soil can be used to fill in the excavation at the site.

Darryl Nelson 300x300
Darryl Nelson President Nelson Environmental Remediation Ltd.
  • 2 00 PM

COVID-19 and the Oil Sands: Operational Responses and Future Growth Trajectories

Future of Fuels

There are few historical precedents for the disruption that the oil sands industry experienced in the second quarter of 2020, and the market turmoil caused by COVID-19 naturally raised questions ab...

  • locationROOM B
  • small-arm2:00 PM - 2:30 PM
wednesday September 22, 2021
Future of Fuels

COVID-19 and the Oil Sands: Operational Responses and Future Growth Trajectories

  • pr-alarm2:00 PM - 2:30 PM
  • pr-locationROOM B

There are few historical precedents for the disruption that the oil sands industry experienced in the second quarter of 2020, and the market turmoil caused by COVID-19 naturally raised questions about the possibility of extended shutdowns and asset integrity issues. This presentation aims to provide a comprehensive review of Western Canada’s heavy oil sector against the backdrop of COVID-19 and its aftermath. In terms of historical trends, the analysis will focus on how upstream players responded to COVID-related demand destruction from an operational perspective. Forward-looking analysis will assess prospects for future oil sands growth and the evolving development concepts that will allow heavy oil players to grow at a competitive cost of supply. The presentation will conclude with a review of recent midstream developments. The analysis will utilize well-level data from provincial regulators and proprietary oil and gas databases from Rystad Energy, which provide global supply forecasts through asset-level production and economic modeling. The analysis of operational responses will disaggregate monthly heavy oil production trends by oil sands projects to assess varying producer responses to the extreme low-price environment witnessed in the second quarter of 2020. Meanwhile, presentation will utilize a bottom-up, asset-by-asset modeling approach to highlight the most prominent near- and mid-term oil sands expansion opportunities. Early fears surrounding complete shutdowns and thermal asset integrity ultimately did not come to fruition. Although many thermal operators reduced production dramatically in 2Q20, almost none of these curtailments involved extended disruptions to producing wells or the minimal production levels that some operators had initially guided. In fact, operator responses varied widely amongst both mining and thermal schemes. In some cases, the impact to production was minimal; in other cases, operators used the market disruption to schedule extended maintenance and ramp up production in 4Q20. Looking forward, oil sands players continue to shift away from greenfield projects and large-scale expansion phases towards a growth model characterized by smaller incremental expansions with reduced facility requirements. As such, oil sands projects will maintain a competitive cost of supply and continue to grow throughout the 2020s, albeit at a more measured pace. The well- and asset-level granularity that underlies the analysis in this presentation will be a valuable addition to the state of knowledge in the energy industry. In addition to purely historical trends, the review of historical data will offer insights into how oil sands players could reasonably be expected to adjust upstream operations in the face of future market disruptions. Additionally, our analysis of project economics and development strategies will provide industry stakeholders with a concise, yet empirically robust overview of the sources of future supply growth in the oil sands and their expected go-forward breakeven prices.

Thomas Liles 300x300
Thomas Liles Analyst Rystad Energy
  • 2 00 PM

New Pore and Reservoir Scale Upscaling Solution for Large Models

Reservoir Engineering

Objectives/Scope We present an extended local solution for upscaling based on 3D electrical circuits representing variable size grid blocks. Homogeneous parts of models are represented by fewer lar...

  • locationROOM C
  • small-arm2:00 PM - 2:30 PM
wednesday September 22, 2021
Reservoir Engineering

New Pore and Reservoir Scale Upscaling Solution for Large Models

  • pr-alarm2:00 PM - 2:30 PM
  • pr-locationROOM C

Objectives/Scope We present an extended local solution for upscaling based on 3D electrical circuits representing variable size grid blocks. Homogeneous parts of models are represented by fewer larger grid blocks while heterogeneous parts are represented by many smaller homogeneous grid blocks. An adaptive octree data structure is implemented in building and simulating models that are equivalent to 109 blocks. Simulations run on a typical laptop in minutes not hours and compare results from nine different upscaling configurations. This solution works well at pore scale and reservoir scale without modeling flow dynamics that limits the model size. Methods, Procedures, Process The upscaling is based on connectivity between two opposite faces of the model and follows principles of capillary pressure tests. In virtual tests at pore scale, the wetting and non-wetting fluids interact under varying pressure in a 3D effective network. This process simulates trapping mechanisms when one of the fluids is surrounded by a different fluid type. The model's electrical properties are derived from grid blocks at the lowest tree level through recursive upscaling in a depth-first traversal. The resistivity estimates come from statistical averaging and three different configurations for electrical circuits representing grid blocks. Our first two non-statistical models correspond to the earliest methods of the porous media simulations and upscaling based on bundles of pipes representing grid blocks. In the third method, blocks are replaced by sets of six resistors organized as 3D crosses. Sets of eight blocks with the same parent are replaced by 48-element circuits used to estimate the resistance in horizontal and vertical directions. This process models 3D effective network connectivity, checks fluid types, and tests path length versus pressure values. This extends simulations with a regular cubic lattice yielding a network coordination number greater than six. Results, Observations, Conclusions Prior to 100% saturation of the pore space with the wetting phase, the total porosity, the effective porosity, and the path statistics (tortuosity) are estimated. During the drainage-imbibition tests the non-wetting and wetting phase percentages are recorded along pressure values. These are accompanied with nine resistivity estimates. The first three estimates represent arithmetic, geometric, and harmonic averages. The remaining six estimates represent the resistivity estimates from the chain, bundle, and mesh algorithms in horizontal and vertical directions Different model structures result in varying degrees of the hysteresis in fluid saturations and electric properties during these tests. The most advanced mesh interconnectivity works best for layered and/or correlated pore networks. Break-through events are detected in drainage and imbibition. Saturations and interconnected paths at each pressure are visualized in 2D and 3D space. Novel/Additive Information The above procedures and algorithms model and estimate properties directly in 3D space. They are fast and do not require intermediate representations relaying on networks or packs of simple objects (e.g. spheres). Differences between nine estimates indicate uncertainties in upscaled properties prior to reservoir simulations. Finally, permeability estimates can be made by substituting permeability for electrical conductivity or by using known relationships between permeability and conductivity for specific rock types.

Leon Fedenczuk 300x300.jpg
Leon Fedenczuk Analytical Consultant Gambit Consulting Ltd.
  • 2 30 PM
Coffee Break & Visit Exhibition
  • 3 00 PM

Optimizing Deployment of Methane Leak Detection Technologies Using an Open-Source Tool

Water & Environmental Management

There is a growing interest in the use of novel technologies for monitoring methane emissions. These technologies have come to include handheld instruments, continuous sensors, vehicles, drones, ai...

  • locationROOM A
  • small-arm3:00 PM - 3:30 PM
wednesday September 22, 2021
Water & Environmental Management

Optimizing Deployment of Methane Leak Detection Technologies Using an Open-Source Tool

  • pr-alarm3:00 PM - 3:30 PM
  • pr-locationROOM A

There is a growing interest in the use of novel technologies for monitoring methane emissions. These technologies have come to include handheld instruments, continuous sensors, vehicles, drones, aircraft, and even satellites. Dozens of new companies have emerged over the past decade offering a diversity of products and services. Available solutions differ significantly in performance, cost, data characteristics, interpretability, and capacity to recommend emission reduction activities. What technologies to use and where/when to deploy them will depend on a producer’s emission reduction goals, where their assets are located, historical emissions data, production characteristics, regulatory requirements, and so on. In other words, achieving methane reductions in the most cost-effective manner requires careful selection of the technologies best suited to a particular set of goals and constraints. A new, open-source software tool called the Leak Detection and Repair Simulator (LDAR-Sim) is able to evaluate different technologies and LDAR programs.1 LDAR-Sim is an agent-based numerical model and publicly available software tool designed for the oil and gas industry to optimize technology deployment and reduce methane emissions cost-effectively. To achieve the objective of empowering oil and gas companies to independently evaluate and confidently deploy novel methane monitoring technologies, we present a set of case studies on the use of LDAR-Sim. Our case studies explore a variety of scenarios to demonstrate the strengths and weaknesses of different technologies and show when and where their use makes sense. We perform thousands of simulations to explore where and when different technologies excel. Conditions explored include emissions profiles of different production types, regulations, environmental conditions, availability of infrastructure (e.g., roads, airports), facility densities, and best management practices for leak repairs and investigation of emissions sources. Our results demonstrate a broad range of emissions reduction potentials and highly variable LDAR program costs, showing that each of the aforementioned input variables are important to consider when determining which technologies to deploy. Based on our case studies, we conclude that technologies should be evaluated through simulation each time a new monitoring strategy is developed. Given the pace of change in innovation, emissions profiles, and emission reduction efforts in the oil and gas industry, iteratively revisiting reduction strategies and technologies used is important to remain competitive. 1 Fox, T., Gao, M., Barchyn, T., Jamin, Y. & Hugenholtz, C. An agent-based model for estimating emissions reduction equivalence among leak detection and repair programs. 2020. J. Clean. Prod. (In press).

Thomas Fox 300x300
Thomas Fox President & Director of Innovation Highwood Emissions Management
  • 3 00 PM

Innovative Standard Modular Small and Micro Scale Renewable LNG Plants Utilizing Zero Refrigerant Technology

Future of Fuels

Liquefied natural gas (LNG) has been around for decades and the usage is expanding globally. There are many large-scale LNG plants (> 1 mtpa) that are currently in design development phases through...

  • locationROOM B
  • small-arm3:00 PM - 3:30 PM
wednesday September 22, 2021
Future of Fuels

Innovative Standard Modular Small and Micro Scale Renewable LNG Plants Utilizing Zero Refrigerant Technology

  • pr-alarm3:00 PM - 3:30 PM
  • pr-locationROOM B

Liquefied natural gas (LNG) has been around for decades and the usage is expanding globally. There are many large-scale LNG plants (> 1 mtpa) that are currently in design development phases through to operating plants. These large-scale LNG plants are located by the water near a port. The LNG is typically transported to other countries by LNG tankers or ships, then regasified and the natural gas is then transported via pipeline or truck to inland users. A new concept that has been developing over the last ten years is the use of small-scale (< 500 ktpa) LNG plants. Small scale LNG plants are typically located inland where natural gas is available from biogas, “stranded” unconventional and conventional gas resources or a natural gas pipeline. The LNG has been trucked for use by power generators and more recently been used in the heavy transportation markets including trucking, mining haul trucks, marine and rail. These small and micro scale standardized modular plants can be built faster and more efficiently than large-scale LNG plants. The competitive advantage of these small plants when compared to the large-scale plants are the smaller local gas resources are monetized taking advantage of the reduced logistics cost of transport liquid LNG over large distances to these end users. There are different liquification technologies that have been used for small-scale LNG plants and include methane expansion, nitrogen (N2) refrigeration and single mixed refrigerant (SMR). PolaireTech has developed a standard modular small (60 ktpa) and micro (5 ktpa) scale LNG plants utilizing the zero refrigerant (methane expansion) ZR-LNGTM technology. Utilizing the ZR-LNGTM technology reduces the overall lifecycle costs when compared to traditional technologies by minimizing the quantity of equipment and the power consumption required. The plant consists of standard plug and play modules that can be interchanged depending on the FEED sources and these plants are scalable depending on the customers’ requirements. Small and micro scale plants are becoming more popular globally due to the initiatives to reduce greenhouse gases, as LNG burns more cleanly than other fossil fuels such as petroleum and coal (reducing CO2 emission between 30 ? 50%) . There needs to be innovative cost-effective methods to construct these environmentally friendly plants and ensure the customer has a profitable “total cost of ownership”. This presentation will review the overall ZR-LNGTM technology, PolaireTech plug and play module methodology and the benefits of utilizing a zero-refrigerant technology versus the traditional N2 and SMR technologies. It will also discuss combining this technology with using biogas as a renewable energy source. It will highlight how the overall lifecycle costs play an important role in ensuring the customers “total cost of ownership” is met.

Cathy Farina 300x300
Cathy Farina VP, Operations DyCat Solutions
  • 3 00 PM

Pivoting to Data: How Data-Driven Companies are Increasing Value

Technical Panel Session

In addition to the low-carbon energy transition, companies are also radically transitioning their business process to be increasingly data-driven.

On the oil and gas side, profitability is bein...

Sponsored By : IBS Software

  • locationROOM C
  • small-arm3:00 PM - 4:30 PM
wednesday September 22, 2021
Technical Panel Session

Pivoting to Data: How Data-Driven Companies are Increasing Value

  • pr-alarm3:00 PM - 4:30 PM
  • pr-locationROOM C
Sponsored By
ibssoftware_300x300.png

In addition to the low-carbon energy transition, companies are also radically transitioning their business process to be increasingly data-driven.

On the oil and gas side, profitability is being driven through efficiencies instead of additional exploration. While in renewables, big data, predictive analytics and machine learning may be the solution to improved forecasting.

What are the opportunities for implementing data solutions and how do they balance against, what can be, deep-seated data challenges?

Audience Insights:

This session provides examples from companies who have leveraged data to dramatically improve the way their business operates.

Moderator
Cara Wolf 300x300
Cara Wolf Founder and CEO Ammolite Analytx
Remasankar S 300x300
Remasankar S Vice President & Client Advisor IBS Software
Mark Speaker 300x300
Mark Speaker Industry Executive Microsoft
Sheldon Wall 300x300
Sheldon Wall Manager, Advanced Analytics Suncor Energy
  • 3 30 PM

Oil Sands Tailings: Accelerated Oil Separation and Dewatering

Water & Environmental Management

Technology: Chemical and mechanical processes uniquely combined to accelerate; and efficiently separate water, oil and tailings’ solids, aiding in the reclamation of oil sands tailings waste. Exi...

  • locationROOM A
  • small-arm3:30 PM - 4:00 PM
wednesday September 22, 2021
Water & Environmental Management

Oil Sands Tailings: Accelerated Oil Separation and Dewatering

  • pr-alarm3:30 PM - 4:00 PM
  • pr-locationROOM A

Technology: Chemical and mechanical processes uniquely combined to accelerate; and efficiently separate water, oil and tailings’ solids, aiding in the reclamation of oil sands tailings waste. Existing Problem: During the extraction of bitumen from oil sands, tailings are produced as a waste product. These tailings are a mixture of water, fines, ultra-fines, various toxic chemicals such as heavy metals, and a small number of leftover hydrocarbons, such as bitumen [3]. Current technology and economics are prohibitive for removal/separation/extraction of oil and water greater than 65% of from oil sands tailings; a byproduct of heavy oil production. Decade long timelines are required for current separation processes. Different methods may be used to extract the oil and water from the tailings. Each method follows guidelines as set by the Alberta Energy Regulators (AER) [2] and Canada’s Oil Sands Innovation Alliance (COSIA). The most common methods include thin-lift drying, the use of flocculants, or centrifugal forces. Tailings are small particles which take large amounts of time to settle out of emulsion byproducts. 65-70% solids w/w is required for reuse, but separation over 30% w/w is an industry challenge [1] Summary: BC-3 chemical is a protein-based water soluble, nontoxic, nonvolatile, nonflammable, and biodegradable chemical. BC chemicals have the ability to disrupt the hydrocarbon-hydrocarbon solubility interaction that forms crude oil. This proprietary uniqueness of chemical and bubbles yields the ability to reduce overall crude viscosity as it penetrates and adsorbs into the matrix of the formation, thus permitting rapid removal of heavy oil and water from tailings solids. The bubbles generated are Nanobubbles which break apart oil and solids more efficiently. More bubbles change the density of water and create gas saturation causing oil to rise and may be skimmed off. The solids to fall to bottom and may become reclaimed. The mixing process of BC chemicals and Nanobubbles encourages separation and extraction of solids, oil, water. Principal Uses: As tailings are abundant and labeled an environmental hazard, remediation pressure exists on mining industries and oil sand operations. Supervised reclamation happens slowly, resources run thin, and economically available technologies are common hurdles. Technical Features: Proven acceleration separating heavy oil, tailings’ solids, and entrained water, can be achieved with this proprietary innovation. Using BC Chemical, Nanobubbles, and a mechanical process rapid, economic, long-term separation/remediation may be realized.

Angela Vanden 300x300
Angela Vande Engineer Crosswind Resources
  • 3 30 PM

Accelerating Net-Zero: Reducing Emissions Intensity of Fossil Fuels through Waste Heat Recovery Projects and Technology

Future of Fuels

Canada’s Energy Future 2020 report stated that increasing energy efficiency and the share of low-carbon energy sources will be key in decarbonizing our energy systems. For the fossil fuel industry,...

  • locationROOM B
  • small-arm3:30 PM - 4:00 PM
wednesday September 22, 2021
Future of Fuels

Accelerating Net-Zero: Reducing Emissions Intensity of Fossil Fuels through Waste Heat Recovery Projects and Technology

  • pr-alarm3:30 PM - 4:00 PM
  • pr-locationROOM B

Canada’s Energy Future 2020 report stated that increasing energy efficiency and the share of low-carbon energy sources will be key in decarbonizing our energy systems. For the fossil fuel industry, this requires pathways that adopts clean technologies and environmental value additions without compromising economics in a lower price environment. A technology solution that reduces the emissions intensity of fossil fuel production and distribution in an economic way is waste heat recovery (WHR). Contrary to high-grade heat that is used in industrial processes, “waste heat” or heat lower than 500 °C is a by-product of operational inefficiencies that is often vented to atmosphere. This waste heat can be a powerful resource when captured using Organic Rankine Cycle (ORC) systems to produce emission-free, baseload electricity. Terrapin presents the variables and considerations of this technology integration. As an externally heated, closed cycle heat engine that uses an organic two-phase working fluid, the ORC is similar to the steam-based Rankine Cycle (SRC) but is optimized to work with lower temperature heat sources in the 120 °C-500 °C range. When integrating this technology into industrial facilities, waste heat resource owners should consider: • Waste heat stream characteristics • Project site characteristics and supporting infrastructure • Power and offset markets • Jurisdictional mandates and incentives This presentation walks through the complexities of developing waste heat to power projects and the optimal characteristics of an economic deployment of ORC technology. Terrapin presents two case studies of WHR to showcase the different outputs of projects that utilize lower temperature waste heat and higher temperature waste heat. Both case studies show inherent conversion opportunities, with the greatest value being derived from waste heat to power projects developed at existing natural gas turbine infrastructure. Today, ORC installations are primarily in Europe, recovering low-temperature heat from sources such as combustion turbine and reciprocating engine exhaust, industrial furnace exhaust, geothermal resources, and biomass combustion. Adoption of ORC technology in North America has been comparably slow, restrained by low-priced electricity and natural gas, despite the presence of a significant resource in the energy industry. Current shifts in North American emission policies and standards and the further development of the technology have begun to drive increased ORC adoption rates. The combustion turbine market alone is considerable. In Alberta and British Columbia combined, there is over 1,100 MW of installed pipeline compression. If 50% of this capacity utilized WHR with ORC, 175 MW could be recovered and used on site or supplied to the grid. For the waste heat resource owner, these projects can achieve a payback of 5 years under the right conditions. Incorporating ORC heat recovery into projects with 20-year lifespans can generate a considerable return for the owner, increase facility resilience, and lower carbon footprints.

Gray Alton 300x300
Gray Alton VP, Project Development Terrapin Geothermics
  • 4 00 PM

Massive Generation of Gas Nano-Bubbles in Water

Water & Environmental Management

Nanobubbles (NBs) are nanoscale gaseous domains than can exist in bulk liquids or at their solid surfaces. Their appearance in aqueous solutions has attracted significant recent attention due to th...

  • locationROOM A
  • small-arm4:00 PM - 4:30 PM
wednesday September 22, 2021
Water & Environmental Management

Massive Generation of Gas Nano-Bubbles in Water

  • pr-alarm4:00 PM - 4:30 PM
  • pr-locationROOM A

Nanobubbles (NBs) are nanoscale gaseous domains than can exist in bulk liquids or at their solid surfaces. Their appearance in aqueous solutions has attracted significant recent attention due to their apparent long-time stability (over timescales of months), and high potential for real-world applications by allowing for significantly enhance amounts of gas to be available in solution. However, the generation of NBs has proven to be somewhat difficult and energy intensive, for example involving intense agitation of solutions, ultrasonic treatment, or using microfluidic flows, with only modest concentrations of NBs achievable. Thus, to this point their potential applications have been effectively severely limited. Although surface NBs have been generated and observed using various experimental methods, bulk-liquid NBs have been much less investigated. Arguments based on Laplace pressure considerations would suggest that bulk NBs should be very transient features in solution, so the origins of their apparent stability has remained elusive. NBs are known to usually possess negative zeta potentials, resulting in mutual repulsions that are sufficiently large to prevent coalescence and slow any buoyancy rise. To explain this behaviour, it has been conjectured that NBs feature a build-up of anions (i.e. OH-) at the gas/liquid interface, yet observations of stable NBs in highly pure water suggest an alternative explanation is needed. In this presentation, we will demonstrate a novel and very recently reported method that utilizes electric fields to catalyze the massive and rapid generate of methane, oxygen, and carbon dioxide NBs in bulk aqueous solution with low energy input (1000x less than current conventional approaches). Using appropriate experimental probes, for example Dynamic Light Scattering, we characterize the NBs present and confirm their long-time stability. Using both molecular simulations and theoretical development, we also provide a consistent explanation for the apparent stability of aqueous NBs and their measured zeta potentials that does not require the presence of OH- ions. This explanation identifies unique features of the air-water interface as the origins for NB behaviour. The work has been published in Science Advances (2020; 6:eaaz0094). By achieving massive enhancement of bulk-NB formation in water, we are able to realize dramatically elevated levels of gas solubility in water many times the Henry’s-Law solubility. A groundbreaking aspect now possible will be the generation of nanoporous liquids, a new material with unique tunable properties, arising from solutions with high NB concentrations (>1% by volume). This discovery is expected to have enormous ramifications in, for example, wastewater-treatment and process industries, in addition to dramatically accelerating gas-(diffusion)-limited processes. The realization of nano-porous liquids (in the form of gas NBs in water) in a simple, facile and energy efficient manner will open up numerous opportunities across the spectrum of energy industries.

Peter Kusalik 300x300
Peter Kusalik Professor University of Calgary
  • 4 00 PM

The Role of Natural Gas in a Deeply Decarbonized Economy

Future of Fuels

As the economy decarbonizes, the role of natural gas changes. Initially it replaces higher-carbon fuels in baseload generation, but it evolves to providing reliability to the renewables fleet. As...

  • locationROOM B
  • small-arm4:00 PM - 4:30 PM
wednesday September 22, 2021
Future of Fuels

The Role of Natural Gas in a Deeply Decarbonized Economy

  • pr-alarm4:00 PM - 4:30 PM
  • pr-locationROOM B

As the economy decarbonizes, the role of natural gas changes. Initially it replaces higher-carbon fuels in baseload generation, but it evolves to providing reliability to the renewables fleet. As renewables increase their share of generation, some jurisdictions are considering what role, if any, natural gas plays in a deeply decarbonized economy. My presentation explores this issue by considering the challenges and costs of eliminating natural gas from our electrical system, and how this compares with other alternatives to decarbonize.
Much of my presentation will be based on research from the Roosevelt Project, an effort within the Center for Energy and Environmental Policy Research (CEEPR) at the Massachusetts Institute of Technology “to provide an analytical basis for charting a path to a low carbon economy in a way that promotes high quality job growth, minimizes worker and community dislocation, and harnesses the benefits of energy technologies for regional economic development.” To be clear, I am making my own argument on the role of natural gas and using the research materials to support my case.
The reliability that natural gas provides to our electric system is difficult and costly to replace. While technically possible, achieving net zero in a reasonable timeframe will probably be far more costly without natural gas. Natural gas, particularly abated natural gas, should be an important part of the drive to deeply decarbonize the economy.

Greg Zwick 300x300
Greg Zwick Principal Zwick Analytics
  • 4 30 PM
Day Two of Technical Conference Concludes for the Day
  • 7 30 AM
Registration Opens
  • 8 30 AM

Carbon Capture in Oilsands Production and Upgrading

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Carbon dioxide capture and sequestration (CCS) in oilsands production and upgrading is a viable and proven method to meet Canada’s climate change commitments while continuing to leverage one of the...

  • locationROOM A
  • small-arm8:30 AM - 9:00 AM
thursday September 23, 2021
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Carbon Capture in Oilsands Production and Upgrading

  • pr-alarm8:30 AM - 9:00 AM
  • pr-locationROOM A

Carbon dioxide capture and sequestration (CCS) in oilsands production and upgrading is a viable and proven method to meet Canada’s climate change commitments while continuing to leverage one of the country’s most valuable resources. The oilsands region is uniquely positioned to take advantage of CCS considering the existing infrastructure in place and proximity to geology favourable for Enhanced Oil Recovery (EOR) and sequestration. Carbon capture can be expanded in application to both oilsands production and in blue hydrogen generation, which can significantly reduce the carbon footprint of fossil fuels and hydrocarbon-based products. Commercial options for carbon capture technologies using amine-based solvents will be discussed, including specific examples developed for both pre- and post-combustion carbon capture solutions. Two specific opportunities for carbon capture will be explored in the oilsands value chain: one for steam generation in a typical SAGD facility, and another for blue hydrogen generation used in oilsands upgrading. The relative merits of these carbon capture options will be compared, including an examination of business drivers and impacts on net carbon intensity reductions to be applied to the Clean Fuels Standard in the generation of carbon credits.

Jon-Isley-300x300
Jon Isley Senior Director, Process Technology Fluor Canada Ltd.
  • 8 30 AM

Condition-Based Monitoring of an Actuated Surface Safety Valve through Edge Computing

Field Development & Infrastructure

Objectives/Scope: A surface safety valve (SSV) provides an immediate closure of the well in the event of an emergency. The actuated SSV is commonly controlled through a hydraulic circuit to open an...

  • locationROOM B
  • small-arm8:30 AM - 9:00 AM
thursday September 23, 2021
Field Development & Infrastructure

Condition-Based Monitoring of an Actuated Surface Safety Valve through Edge Computing

  • pr-alarm8:30 AM - 9:00 AM
  • pr-locationROOM B

Objectives/Scope: A surface safety valve (SSV) provides an immediate closure of the well in the event of an emergency. The actuated SSV is commonly controlled through a hydraulic circuit to open and close the valve. This circuit is composed of control elements that automatically trigger an Emergency Shutdown (ESD). Failure of one or more of these control elements can delay or prevent the SSV closure, thus routine inspection to ensure their proper functioning is critical to the overall SSV system reliability. Given the trend in recent years to optimize operational costs remote condition monitoring of wellhead components, including SSVs, is becoming an industry requirement. This paper discusses the recent development of a self-contained SSV with an autonomous remote condition monitoring system. Methods, Procedures, Process: The developed system integrates to an electro-hydraulic controlled actuator that opens and closes an SSV gate valve. The system is instrumented with pressure transmitters, position transmitter, temperature detector, and hydraulic reservoir level switch in a Class I Division 1 environment and is connected to a datalogger and process controller in a Class I Division 2 environment. The process controller includes an on-board logic software and connects to a wireless transmitter receiver. This system, fully developed and tested at Stream-Flo Group of Companies, is capable of logging data at high frequency during an Emergency Shutdown (ESD) event to provide an evaluation of the condition of the control elements using Edge Computing. This automated approach only sends critical data remotely after performing necessary computation, thus optimizing telemetry bandwidth and power usage. Results, Observations, Conclusions: The response time of the solenoid valve during an SSV closure event was evaluated under different conditions to be used as an indication of a healthy response. It was observed to vary depending on the signal pressure, but within a relatively fast response time of around 50 ms. Diagnostic algorithms were developed to detect leakage and over-pressure in the hydraulic system pressure reducing valve. Also, probable malfunctioning of the hydraulic pressure safety valve was determined based on over-pressure of the signal control circuit. Moreover, detection of a triggered local (electric or manual) or remote event was defined through data analytics of valve position and pressure gradients. A relationship between line pressure and total closure response time was evaluated to be used as a healthy event signature indicator. These results provide confidence in the ability to monitor and provide digitized feedback to well operators. Novel/Additive Information: Most published SSV condition monitoring efforts focus on the process valve health with less attention to the actuator signal control circuit, which is a critical element without which an SSV will fail to close or open upon demand. The work presented in this paper demonstrates the successful in-house integration of the reliable hydraulically actuated SSV with instrumentation and logic to develop an autonomous condition monitored SSV.

Hossam Gharib 300x300
Hossam Gharib Senior Product Engineer Stream-Flo Industries Ltd.
  • 8 30 AM

Going Autonomous: The Future of Human Free Operations

Technical Panel Session

Over the last decade many global energy players have been adopting Industry 4.0 technologies and making the switch to autonomous operations.

In Canada, oilsands producers have invested heavily...

Sponsored By : Cisco

  • locationROOM C
  • small-arm8:30 AM - 10:00 AM
thursday September 23, 2021
Technical Panel Session

Going Autonomous: The Future of Human Free Operations

  • pr-alarm8:30 AM - 10:00 AM
  • pr-locationROOM C
Sponsored By
Cisco_Logo_with_TM_Midnight_Blue-Pantone2767.png

Over the last decade many global energy players have been adopting Industry 4.0 technologies and making the switch to autonomous operations.

In Canada, oilsands producers have invested heavily in autonomous oilsands haulers to increase operational efficiency, lower costs and enhance safety performance on site. Drones have increasingly been adopted across oil and gas, renewable and power sectors for asset management and data collection.

What is the result of autonomous technology on operational efficiency and where do we go from here?

Audience Insights:

Join both users and suppliers to hear about how autonomous technology has been implemented in their business operations and the opportunity for advanced use in the future.

Moderator
Roland Plett 300x300
Roland Plett Business Development Manager, Energy and Mining Cisco Systems
Pete MacLeod 300x300
Pete MacLeod Principal Director Accenture
Indy Kar 300x300
Indy Kar Vice President of Strategic Growth FTP Solutions
  • 9 00 AM

Unlocking Economic Zero Bleed Pneumatic Instrument Air Retrofits: A Review of Learnings from Westgen’s Emission Reduction Alberta Demonstration Project

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Methane has a greenhouse gas intensity 25 times greater than CO2. According to the IEA, methane venting from pneumatic devices in the oil and gas industry is responsible for 532.5 million tonnes of...

  • locationROOM A
  • small-arm9:00 AM - 9:30 AM
thursday September 23, 2021
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Unlocking Economic Zero Bleed Pneumatic Instrument Air Retrofits: A Review of Learnings from Westgen’s Emission Reduction Alberta Demonstration Project

  • pr-alarm9:00 AM - 9:30 AM
  • pr-locationROOM A

Methane has a greenhouse gas intensity 25 times greater than CO2. According to the IEA, methane venting from pneumatic devices in the oil and gas industry is responsible for 532.5 million tonnes of CO2e per year, the equivalent of all emissions from 22% of the world’s coal fired power plants. Historically, a lack of cost-effective power generation solutions and the resulting high cost to deploy instrument air on remote sites has been one of the root causes of our industry’s legacy of venting gas to atmosphere through pneumatic devices. In July 2020, Westgen Technologies Inc. in conjunction with Emissions Reduction Alberta, Sustainable Technology Development Canada, and ten Canadian oil and gas companies undertook a project to develop and demonstrate a solution for eliminating methane venting from pneumatics on legacy wellsites in Alberta. The AirCUBE system, based on Westgen’s Global Energy Award winning EPOD power generation technology, presents an opportunity for emissions reductions projects with positive economics based on carbon credits and fuel gas expense savings. The project started with a desktop study of pneumatics inventory data from hundreds of wellsites. Crews were then deployed to the field to measure emissions rates and compare them against estimates. This data was used to inform design conditions to cover a large of variety of wellsite configurations. The next phase of the project involved deployment of 10 EPOD units equipped with an array of sensors and measurement devices. Real time data was collected from the EPODs on variables such as peak and average air compressor flow rates, compressor run times, and energy usage. Oil sampling and lab analysis was completed to understand performance of the engine while burning variable composition raw well gas. Westgen applied the learnings from each phase of the project to develop the AirCUBE in Q4 2020. In the final phase of the project, 10 AirCUBEs were deployed to remote wellsites for testing. The units will be closely monitored throughout 2021 to gather learnings and inform product improvements. An application for carbon credits will be pursued based on emission reductions achieved by the project. The Westgen team will compile data generated through the project to outline the technical and commercial case for instrument air retrofits. Learnings to be shared will include delineation of applicable sites, reliability metrics, cost estimates, and projected economic returns by site type. Westgen believes that this Alberta case study will have broad applicability and will inspire jurisdictions across the globe to follow Alberta’s lead in eliminating this significant environment impact of our industry.

Ben Klepacki 300x300
Ben Klepacki VP of Engineering Westgen Technologies Inc.
  • 9 00 AM

Optimizing Pipelines with Machine Learning Decision Support [Case Study]

Field Development & Infrastructure

The industrial nature of the Energy Sector means that even small improvements in measuring, monitoring, and controlling a system can significantly impact safety, reliability, and operating costs. M...

  • locationROOM B
  • small-arm9:00 AM - 9:30 AM
thursday September 23, 2021
Field Development & Infrastructure

Optimizing Pipelines with Machine Learning Decision Support [Case Study]

  • pr-alarm9:00 AM - 9:30 AM
  • pr-locationROOM B

The industrial nature of the Energy Sector means that even small improvements in measuring, monitoring, and controlling a system can significantly impact safety, reliability, and operating costs. Machine learning is an excellent vehicle for making these small improvements in daily operations, leading to tremendous outcomes. Willowglen Systems will highlight the value of machine learning with a 2020 Canadian case study. We will share how we reduced the cost of operating a pipeline by 28.5%! Machine learning (ML) enhanced decision support is becoming popular across a variety of industries. Given Willowglen's 50 year history in SCADA for oil and gas, applying ML to a pipeline was a logical next step combining our domain experience with this new form of automation. Also, the nature of pipelines lends itself particularly well to the use of ML decision support. Operators must consider a multitude of ever changing operational variables when managing flow rates. Even senior operators cannot be expected to control the infrastructure for optimal performance in all conditions. Decision support gives the operator the recommendations necessary for optimized flow management. We will step the audience through the process we took to successfully deploy ML models for pipelines in Canada and the US. It starts with identifying the goals, needs, or pain points of the operation. All organizations would like to lower their total cost of operations. However, for pipelines, other requirements can include decreasing the quantity of drag reducing agent (DRA) used, increasing safety, reducing electricity usage, maximizing throughput, and more holistic operator training. Next is the value assessment. Given the organization's goals, we receive 12 months of data, build an ML model, and test the model's ability to make predictions. It's important to share with the organization an estimate of the impact the ML model will have. For example, in our recent ML project's value assessment, we estimated cost savings of 20-40% for the pipeline. If the value assessment is appealing to a company, we move forward in deploying the model. Deploying ML models is dependent on the comfort level of the organization and anticipating that comfort levels will change over time. There are three key ways to deploy an ML model ranging from decision support to autonomous optimization. The first way is manual, running parallel in the system as a final check. Secondly, is semi-autonomous, where the model is integrated and changes pop up as a confirmation or notification for the operator. Thirdly, is autonomous, which allows the model to optimizes decisions and change settings accordingly. Artificial intelligence, ML, and automation integrated with SCADA is a significant trend we see across multiple industries. The whole Energy Sector, not just pipelines, could greatly benefit from ML models. Just think, if a single pipeline with six pumps can realize savings of over $1 million every year, what could you be saving?

Dean Anderson 300x300
Dean Anderson Energy Lead Willowglen Systems Inc.
  • 9 30 AM

The Benefits of Direct Contact Steam Generation for Enhance Oil Recovery

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Direct Contact Steam Generation (DCSG) that injects both steam and hot combustion flue or exhaust gases into the reservoir, has the potential to greatly improve the Steam-Oil-Ratio (SOR) for increas...

  • locationROOM A
  • small-arm9:30 AM - 10:00 AM
thursday September 23, 2021
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

The Benefits of Direct Contact Steam Generation for Enhance Oil Recovery

  • pr-alarm9:30 AM - 10:00 AM
  • pr-locationROOM A

Direct Contact Steam Generation (DCSG) that injects both steam and hot combustion flue or exhaust gases into the reservoir, has the potential to greatly improve the Steam-Oil-Ratio (SOR) for increased oil recovery as well as delivering environmental benefits related to reduced water and emissions. Reservoir production is increased by reducing oil viscosity through heat, repressuring the reservoir with the combustion gases and potentially improving miscibility with the CO2 that remains in the reservoir. GERI’s portable DCSG system was initially piloted in post-CHOPS wells in the Lloydminster area in partnership with oil operators. Each pilot test included at least one steam and production cycle. For two pilots, a reservoir model was first developed to assess the feasibility and approach for injection and production. A multi-well CHOPS model integrated with CMG STARS simulator was used to forecast reservoir performance by history matching the oil, water and sand production data for the selected test well and several surrounding wells. The initial test was a huff pull cycle followed by a second injection cycle. To date over 18,000 barrels of incremental oil production has been realized from the test and offset wells resulting in a combined SOR of less than 0.6 compared to a typical industry SOR of 3.0. Furthermore, the field trials were able to quantify the environmental benefits of DCSG as 50% less emissions with at least 70% of the CO2 sequestered. Based on the results of the pilots, a DCSG that injects both steam and hot combustion exhaust gases into the reservoir can be effective in other enhanced oil recovery applications. Steam Assisted Gravity Drainage (SAGD) applications include using the flue gas to re-pressurize late stage reservoir, potentially mitigating “thief zones or in combination with infill wells to connect separate heated pools. For tight oil or low permeability reservoirs, DCSG can provide energy and re-pressurize the reservoirs, but also introduce a sweep effect, thereby, increasing recovery. Although the heat impact introduced by steam may not be as great as it is on heavy oil reservoirs, it can reduce oil viscosity and increase oil mobility. A history matched multi-well reservoir model was developed on a tight and lighter reservoir, with an oil density of 20 API and average permeability of 40 md to assess the feasibility of DCSG. Simulation results showed that even with a short injection period (15 - 40 days) of steam plus flue gases, incremental oil recovery for the first year could be 3 to 4 times compared to the no-injection scenario. A portable DCSG solution allows for inexpensive, short term pilots to confirm the opportunity.

Brian Kay 300x300
Brian Kay Chief Technology Officer General Energy Recovery Inc. (GERI)
  • 9 30 AM

Reducing Methane Emissions and Operation Costs with Smart Electric Chemical Pump Solutions

Field Development & Infrastructure

In the coming years, heavy regulations are planned for pneumatic fuel gas driven equipment on oil and gas sites across Western Canada. Pneumatic pumps use pressurized natural gas as a power source...

  • locationROOM B
  • small-arm9:30 AM - 10:00 AM
thursday September 23, 2021
Field Development & Infrastructure

Reducing Methane Emissions and Operation Costs with Smart Electric Chemical Pump Solutions

  • pr-alarm9:30 AM - 10:00 AM
  • pr-locationROOM B

In the coming years, heavy regulations are planned for pneumatic fuel gas driven equipment on oil and gas sites across Western Canada. Pneumatic pumps use pressurized natural gas as a power source and then release the spend low pressure gas directly to the atmosphere. As Pneumatic pumps vent significant amount of methane they will not be allowed on a new site in British Columbia after 2022. In addition, the overall vent limit comes into effect in Alberta 2023 and existing sites that have multiple fuel gas driven pneumatic devices will likely breach the overall vent gas limit threshold. Sirius Controls designs and manufactures electric chemical injection packages that are engineered not only to eliminate green house gas emissions, but also to reduce two of the largest expenses for operating companies: manpower and chemical cost. These cost reductions and increased reliability are due in a large part to Autonomous local control, a topic that Sirius has recently published an article about in the World Oil magazine https://www.siriuscontrols.com/cmsAdmin/uploads/world-oil-advances-in-production.pdf Autonomous local control is local monitoring of multiple parameters combined with intelligent control adjustments, automatically made without manual interaction, human input. Upstream Oil and Gas production companies are adopting these new digital technologies to optimize production, reduce manpower, adopt predictive maintenance, and reduce chemical consumption. Putting smart controllers at the wellsite is a step forward in creating the Digital Oilfield as producers look to increase profitability When Sirius initially introduced the solar chemical injection system to the market, emissions reduction targets were not as prevalent as they are today, so the technology had to make a compelling economic case. Sirius designed its chemical injection systems to optimize the amount of chemical injected, reduce disposal costs, reduce maintenance costs, and reduce the risk of chemical spills. Solar has been infamous for not being well suited to cold climates. Sirius spent a long time building an exceptional reputation in the industry for the use of solar and is now one of the leading providers of chemical injection systems in Canada. Sirius has installed over 10,000 solar chemical injection systems, reducing upstream oil and gas emissions by almost 5.5 MT CO2e per year. Through constant customer driven improvement, lean thinking and a dynamic engineering team, Sirius focuses on helping the Canadian and International Oil and Gas industry reduce its environmental footprint in an economical and cost-effective manner.

Tyler Teece 300x300
Tyler Teece Business Development Manage Sirius Controls
  • 10 00 AM
Coffee Break & Visit Exhibition
  • 10 30 AM

Feasibility of In-Situ Combustion as a Post-Steam Drive Oil Recovery Process

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

In-situ combustion (ISC) was successfully applied after steam drive in some recent commercial heavy oil recovery projects in China. In this paper, we discuss two main aspects: initiation of ISC pro...

  • locationROOM A
  • small-arm10:30 AM - 11:00 AM
thursday September 23, 2021
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Feasibility of In-Situ Combustion as a Post-Steam Drive Oil Recovery Process

  • pr-alarm10:30 AM - 11:00 AM
  • pr-locationROOM A

In-situ combustion (ISC) was successfully applied after steam drive in some recent commercial heavy oil recovery projects in China. In this paper, we discuss two main aspects: initiation of ISC process (ignition), and performance of ISC in a tertiary mode. Following a steam flood, ignition can be initiated either by using a slug of steam prior to air injection, or by using artificial devices, such as electrical heaters. An in-depth analysis of data for six heavy oil field combustion projects was conducted, where combustion was initiated via pre-heating using steam. Long ignition delays were noted, leading to some operational challenges. Although steam-based ignition has been practiced for a long time, no rigorous analysis appears in the open literature. Our analysis yielded certain suggestions for improvement. Feasibility of ISC application in a tertiary mode (following steam flooding) was assessed by analysing the performance of two pilots, two semi-commercial operations and one commercial operation in four different oil fields. The first semi-commercial project involved application of ISC at a depth of 120 m for a pay zone of 6-8 m. Six inverted nine-spots were steam flooded for 4-6 years, and were subsequently harvested by line-drive ISC. The oil recovery increased from 35% to 52%. The second semi-commercial project involved application of ISC at a depth of 550 m for a 8 m pay zone. Initially 3 air injectors were used, but subsequently 4 more were added and formed a line drive beginning at the upper part of the reservoir. Steam injection (cyclic steam stimulation and steam drive) had been applied for 10 years prior to ISC. At initiation of ISC, the water cut was almost 100%. After 4 years of ISC, the water cut decreased to 60%, while air-oil ratio started around 5,000 sm3/m3, but continually decreased to as low as 2,200 sm3/m3. The project is now a successful commercial operation. Finally, based on mechanistic insights obtained from Toe-To-Heel Air Injection (THAI) field operations, some additional guidelines on the use of horizontal wells in tertiary post-steamdrive ISC projects are proposed and discussed.

Alexandru Turta 300x300
Alexandru Turta CEO and President A T EOR Consulting Inc.
  • 10 30 AM

Industrial Control System Device Management and Cybersecurity

Field Development & Infrastructure

Modern industrial control systems typically integrate a variety of different makes and models of devices, each designed to perform some task effectively or economically. The communication of real-t...

  • locationROOM B
  • small-arm10:30 AM - 11:00 AM
thursday September 23, 2021
Field Development & Infrastructure

Industrial Control System Device Management and Cybersecurity

  • pr-alarm10:30 AM - 11:00 AM
  • pr-locationROOM B

Modern industrial control systems typically integrate a variety of different makes and models of devices, each designed to perform some task effectively or economically. The communication of real-time or operational data between these devices has reached a state of maturity where most systems now use standardized protocols for this data and interoperability of real-time data between different devices is well-supported and readily achieved. ¬¬ In addition to the operational data, devices typically host other data such as asset management data, engineering management data, configuration data, fault records, etc. This data is often accessed in proprietary formats and this is especially true for engineering access and configuration data. Staff who have need to access this non-operational data are required to learn each device vendor’s tools, need access to passwords and device information such as device addresses and network access paths in order to access the data they require. This paper describes an integrated device management process that can provide each user with access to all data in all different kinds of devices through a single interface, while controlling what each user is permitted to access (role-based access control), hiding device details that the user does not need to manage and preventing inadvertent (or deliberate) device operation or data alteration by staff who do not have a need to perform those tasks. The single interface can provide additional cybersecurity functionality such as invisibly managing updates to device passwords, automation of periodic or automatic data collection processes (e.g. automatic retrieval of fault records or asset data from devices and delivery of that data to staff who need such access). The system can also automatically verify the status of software and configurations in use, ensuring that only approved code and configurations are operating. Any unauthorized change can be identified and automatically reverted to approved versions, if desired. All access and all actions (such as background version checking) and changes to the system are tracked in audit logs that assist verification of system integrity and cybersecurity. Centralized device management opens scope for integration of additional features such as version management of software, configurations and device documentation. It facilitates new operational workflows for the creation, approval, deployment and automatic verification of configurations. Centralized access management to all devices through a single interface lowers training requirements for most users. Centralized user access management and device password management simplifies the process of granting role-based access to users. The enabling of secure access to multiple sets of data enables new corporate applications for data analysis, system planning, allowing the system to be operated more efficiently and more reliably.

Ameen Hamdon New 300x300
Ameen Hamdon President SUBNET Solutions Inc.
  • 10 30 AM

Exploitation of Waste Energy within SAGD Facilities: How ORC Technology can Drive the Decarbonisation Path of the O&G Companies

Sustainable Electricity Generation and Grid Modernization

Following the trend of energy efficiency and carbon neutrality, the Oil&Gas sector is challenged to develop new solutions aimed to reduce CO2 emissions and improve its processes sustainability. The...

Sponsored By : INNIO Group

  • locationROOM C
  • small-arm10:30 AM - 11:00 AM
thursday September 23, 2021
Sustainable Electricity Generation and Grid Modernization

Exploitation of Waste Energy within SAGD Facilities: How ORC Technology can Drive the Decarbonisation Path of the O&G Companies

  • pr-alarm10:30 AM - 11:00 AM
  • pr-locationROOM C
Sponsored By
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Following the trend of energy efficiency and carbon neutrality, the Oil&Gas sector is challenged to develop new solutions aimed to reduce CO2 emissions and improve its processes sustainability. The conversion of residual, low-grade heat into useful power represents a prompt and effective way to address both issues. In this framework, Organic Rankine Cycle (ORC) technology represents a feasible option to exploit the several waste heat sources present in the O&G processes. This paper will focus on Steam-Assisted Gravity Drainage (SAGD) operations in Alberta facilities and the high potential of ORC technology in this specific application. On the one hand, SAGD is an enhanced oil recovery technology that utilizes large amount of high-pressure steam to produce heavy crude oil and bitumen. Albeit being an effective and consolidated technology, SAGD does not embody the ideal of efficiency and sustainability: indeed, this technique is known to require more water and primary energy compared to conventional oil drilling. On the other hand, ORC is a proven and viable technology that allows converting efficiently waste heat streams into electricity, showing major advantages over alternative technologies. Thanks to the use of organic fluids ORC systems result in simple power plants with no-water consumption, extremely low operation and maintenance costs, high availability and simplicity of operation. All these features make the ORC technology very appealing when coming to heat recovery applications from industrial processes and explain why these systems became more and more spread out in field such as steel and cement industries. Upon these experiences, O&G as well could greatly benefit from this technology. This paper analyzes an oil sand facility in Alberta that produces approx. 25,000 bopd, where an ORC unit can recover a considerable amount of thermal power, currently dissipated during the condensation of the Produced Gas (PG) stream, to generate electric power. Installed in parallel to the existing exchangers, the ORC heat recovery system, by using the thermal-energy content of the PG to vaporize its working fluid, acts as a cooler of the process. It returns the PG to a temperature range 25-80°C (depending on ambient conditions/process requirements), it completely condenses the water fraction and at the same time it produces up to 15 MWe. The results shows that for the 25,000 bpd facility considered, in one year frame, the ORC could produce 95+ GWh of green electricity and avoid 75,000+ Ton of CO2 emissions, in addition to the energy bill savings. By bringing to light these results and the latest developments of ORC heat recovery solutions for O&G processes and SAGD facilities, the paper shows how heat recovery by means of an ORC represents not only a way to enhance efficiency and meet sustainability targets, but also a remarkable and profitable business.

Andrea Savoca
Andrea Savoca Service Engineer North America Turboden
  • 11 00 AM

A Wind-down Ratio for Estimating SAGD/SA-SAGD Late Life Recovery

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Objectives/Scope (25-75 words): This paper proposes a concept of wind-down ratio to estimate the ultimate recovery that rises from the post-steam or post-solvent processes of SAGD or SA-SAGD. “Win...

  • locationROOM A
  • small-arm11:00 AM - 11:30 AM
thursday September 23, 2021
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

A Wind-down Ratio for Estimating SAGD/SA-SAGD Late Life Recovery

  • pr-alarm11:00 AM - 11:30 AM
  • pr-locationROOM A

Objectives/Scope (25-75 words): This paper proposes a concept of wind-down ratio to estimate the ultimate recovery that rises from the post-steam or post-solvent processes of SAGD or SA-SAGD. “Wind-down” is used herewith as a generic term for the late life SAGD/SA-SAGD operations, including gas injection, gas-steam co-injection, and blowdown (no injection). Methods, Procedures, Process (75-100 words): This approach analyzes the additional recovery from the sustaining production which uses the heat stored within the steam chamber. The additional bitumen to be recovered during the wind-down is assumed to be proportional to the previous heat added to the reservoir or the cumulative production of bitumen during the normal steam injection period. In another word, the wind-down ratio is defined as the ratio between the incremental recovery factor during wind-down and the reservoir recovery factor at the starting point of the wind-down process. Results, Observations, Conclusions (100-200 words): A numerical sensitivity study was conducted on 2D SAGD/SA-SAGD mechanism models. The wind-down ratio is plotted against the recovery factor at the starting point of wind-down. It was found that the wind-down ratio is almost a constant value (~ 10% for blowdown) over a wide recovery range (e.g., 35% ~ 80%), which is consistent with our concept model. A pseudo-continuous steam injection curve was also introduced to the analysis to provide an upper bound for the incremental ratios. With sufficient energy but limited availably of bitumen ahead in reservoir, this curve also explains why the wind-down ratio drops sharply if it starts at a certain higher recovery level. Novel/Additive Information (25-75 words): The concept of wind-down ratio was introduced to the thermal gravity drainage processes for analyzing their late life recovery. This proposed, physics-based ratio is able to give an estimate of wind-down performance over a wide range of recovery factor. Numerical sensitivity studies confirm the consistency of the concept.

Zhihong Liu 300x300.jpg
Zhihong Liu Research Engineer Imperial
  • 11 00 AM

ForeSite Flow? The Holy Grail of Flow Measurement

Field Development & Infrastructure

Multiphase flow measurement has been an achievement the oil and gas industry has longed for since its conception. A technology that could accurately measure oil, water, and gas rates without havin...

  • locationROOM B
  • small-arm11:00 AM - 11:30 AM
thursday September 23, 2021
Field Development & Infrastructure

ForeSite Flow? The Holy Grail of Flow Measurement

  • pr-alarm11:00 AM - 11:30 AM
  • pr-locationROOM B

Multiphase flow measurement has been an achievement the oil and gas industry has longed for since its conception. A technology that could accurately measure oil, water, and gas rates without having to separate them on multi-well pad installations would not only allow operators the ability to see real time well behavior, but it would also allow them to reduce capital spend on separation and facility costs, not to mention virtually eliminating emissions associated with test separators. Using a nuclear densitometer for density measurements through non-homogeneous, ever-changing, well flow has been a hinderance to the universal adoption of the multiphase flow metering technology because of HSE and performance related concerns… until now. Over the past few years, the Weatherford has been focused on developing a non-nuclear multiphase flowmeter that would provide our industry the accuracy and repeatability it demands for allocation measurement. Weatherford has coupled its infrared based water cut-meter, Red Eye, with proprietary venturi-sonar flow technology, to launch ForeSite Flow, a non-nuclear, full range multiphase flowmeter. Since early 2019, multiple ForeSite Flow field trial results have yielded a less than 5% deviation on oil, water, and gas rates, in comparison to the reference test separator. This paper provides the summary and results of a field trial in North Dakota, USA where a 3” Foresite Flow meter was installed, upstream of the operator’s test separator and several different wells were cycled through this setup. Once installed and commissioned, no changes could be made to the meter unless any changes to the well’s PVT profile were observed. Hourly flow rates and pressure data were collected from the meter and compared directly with the data gathered by the separator’s flow measurement, which consisted of an orifice meter for gas measurements, a Coriolis meter for oil measurements, and a Mag meter for water measurements. The initial trial lasted thirty days, and the cumulative measurements from both devices were compared on an hourly and daily total perspective and the deviations were calculated. The result of the comparisons showed that the gas rate measurements were less than 5% high for gas, 3.5% low for oil, and 3.4% high for water when compared to separator measurement results. In addition to the comparisons being within the acceptable deviation range per the KPIs established prior to the trial, no field visits or interventions were required throughout the duration of the trial, and no data loss was experienced due to meter or real time transmission disruption. The results led to the operator requesting approval from the North Dakota Industrial Commission and being granted a variance to use ForeSite Flow meters as allocation measurement on upcoming new well installations, reducing capital spend and gaining real time insight into well performance.

Adam Angelle 300x300
Adam Angelle North Americas Operations Manager - Flow Measurement Weatherford International
  • 11 00 AM

AI Enabled Autonomous Renewable Energy based Smart Microgrids

Sustainable Electricity Generation and Grid Modernization

As the world moves towards a more carbon-free future and there is wider adoption of EVs, the demand for power will increase by 30 %. Massive investment in power infrastructure will be required to m...

Sponsored By : INNIO Group

  • locationROOM C
  • small-arm11:00 AM - 11:30 AM
thursday September 23, 2021
Sustainable Electricity Generation and Grid Modernization

AI Enabled Autonomous Renewable Energy based Smart Microgrids

  • pr-alarm11:00 AM - 11:30 AM
  • pr-locationROOM C
Sponsored By
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As the world moves towards a more carbon-free future and there is wider adoption of EVs, the demand for power will increase by 30 %. Massive investment in power infrastructure will be required to meet this increase demand for power This investment in power infrastructure can be preempted by deploying smart microgrids utilising distributed energy resources like solar and wind. Smart-grid technologies make it possible to use the available renewable energy sources efficiently and sustainably to create added value to the energy service as well as reducing costs for energy consumers and prosumers while supporting a decentralized and open architecture and design for the energy system. However operating a microgrid is like operating a small utility. Complex decisions have to be made for monitoring operations, profiling and controlling power use and making optimal buy, use, store or sell decisions. This makes it difficult to deploy, operate and improve financial viability of microgrids. Hence preventing wide-scale roll-out of distributed renewable energy resources like roof-top solar in urban and rural areas of the developing world. We are developing voltOS, an AI/ML powered business operating system for electricity to make it easier to 1) Manage and optimize the operations of microgrids * Utilize forecast inputs generated for load, generation and pricing to create various optimization scenarios of operations. * Optimize energy routing using uncongested routing without dumping energy in system * Optimize mix of keeping reserve capacity availability * Manage functional parameters VAR compensation, frequency stability, voltage stability * Smooth to reduce peak load 2) Enable the operational decisions of the microgrid to be more financially prudent. * Renewable energy generation forecast based on localized weather predictions * Price Forecast utilizing historical patterns to predict expected pricing in near term * Optimal buy, generate, use, store, trade or sell strategy The developed solution will promote a greener planet by reducing dependence on fossil fuel based energy production systems and reducing losses during sourcing, transportation, storage, operational and distribution operations hence reducing carbon footprint. At city, district or society level the microgrid systems can further smartly analyse usage patterns, hence, reducing incidents of wastage and blackouts or unstable voltage supply occurrences hence, ensuring longer lives for consumer equipment hence, reducing carbon footprint at individual asset level.

Amardeep Sibia 300x300
Amardeep Sibia CEO Drishya AI Labs Inc.
  • 11 30 AM

Exothermic Chemical Treatment? Innovation Method for EOR

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Objectives/Scope: In today’s oil and gas world, there is an ongoing demand for Enhanced Oil Recovery (EOR) technologies, operators look for the best available solutions to optimise production from...

  • locationROOM A
  • small-arm11:30 AM - 12:00 PM
thursday September 23, 2021
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Exothermic Chemical Treatment? Innovation Method for EOR

  • pr-alarm11:30 AM - 12:00 PM
  • pr-locationROOM A

Objectives/Scope: In today’s oil and gas world, there is an ongoing demand for Enhanced Oil Recovery (EOR) technologies, operators look for the best available solutions to optimise production from the heavy crude fields which were not put to production due to the lack of technologies that are economically feasible, environmentally friendly and minimise the use of water. New Oil Generation is a Czech independent R&D and oil service company specialized in innovative EOR technologies. Our flagship is Exothermic Chemical Treatment (ECT®), technology based on the thermochemical stimulation of heavy oil reservoirs (crude oil ranging from approx. 10° to 22° API). Our presentation will cover the following points: • Application principles of the ECT® technology, • Presentation of ECT® technology components, • Operational configurations (Huff & Puff, Injection-Production), • Standardised application process, • Possible application scenarios, including Western Canada opportunities • Comparison with other conventional EOR technologies. Methods, Procedures, Process: • ECT® technology uses a designed Binary Mixture chemical reaction in combination with the state-of-the-art technology to heat and pressurize the reservoir pay zone. The liquid solution of chemical reagents is pumped through two separate channels to a specially developed Bottom Hole Assembly (BHA) equipped with sensors interconnected to the integrated logging system which commands the entire application from the surface control and monitoring unit. • Binary Mixture compounds trigger a chemical reaction once they meet in the well down under the packer in the compartment of the BHA called Injection Spearhead where the chemical reaction starts to produce a significant amount of energy which heats the pay zone. • Chemical reaction generates three key components: heat, nitrogen and pressure, which increases the reservoir pressure and lowers the viscosity of the heavy crude. Thus, ECT achieves a rapid increase in the oil production. Online system that controls and monitors temperature and pressure in the reaction zone, provides efficiency coefficient of Binary Mixtures reaction that are close to 1. Results, Observations, Conclusions: • ECT® leaves a long-lasting positive effect on the reservoir characteristics. • ECT® helps to achieve the highest possible recovery factor and increase the overall production, and potentially stabilise the reservoir hydrodynamic system. • Successful pilot tests of ECT® in Turkey and the USA and commercial deployment in Russia proved the technology as a cost-effective method capable to boost also the Canadian heavy oil production in a safe and economical way. Novel/Additive Information: • ECT® innovates the oil and gas industry with the unique combination of applied science and in-house developed technology. • ECT® brings a smart and effective solution of process optimisation, water and energy management and technology minimalization and high mobility leading to cost reduction and a low-profile environmental impact.

Ferdinand Lobkowicz 300x300
Ferdinand Lobkowicz Consulting Geologist (Retired) Lobkowicz Geological
  • 11 30 AM

How to Use Computer Vision for Asset Tracking and Enhanced Project Delivery

Field Development & Infrastructure

Objectives / Scope The objective of this presentation is to demonstrate how Computer Vision technology can be applied to engineering and technical applications. Two case applications will be pres...

  • locationROOM B
  • small-arm11:30 AM - 12:00 PM
thursday September 23, 2021
Field Development & Infrastructure

How to Use Computer Vision for Asset Tracking and Enhanced Project Delivery

  • pr-alarm11:30 AM - 12:00 PM
  • pr-locationROOM B

Objectives / Scope The objective of this presentation is to demonstrate how Computer Vision technology can be applied to engineering and technical applications. Two case applications will be presented: * Asset integrity and management. How object detection and classification can be used in asset tracking and management. The presentation will discuss object identification and classification of assets typically found in the energy sector such as: distribution lines, transmission lines, pumps, motors, solar panels and battery installations. The goal is to demonstrate how this technology can help in asset identification, integrity tracking, and asset management. * Digital capture and point cloud creation. How 3D stereo vision and the advances in SLAM (Simultaneous Location and Auto-Mapping) can be used to create a point cloud. This ability facilitates a digital capture at project initiation. Highlights of the technology will be provided as well as demonstrations on how to set up and utilize. They key take-away from this part of the presentation is that a digital capture is possible at project initiation, and having a digital capture available at the start of a project drivers down costs while increases project certainty. It also ensures all project team members are aligned with the project objectives. Demonstrations and instructions on how to utilize will be provided in this presentation. Methods, Procedures, Process The method by which the objectives of this presentation will be delivered is: 1. Providing an understanding of what Computer Vision is, and what is the difference between Computer Vision and Image Processing. 2. Providing a brief introduction and demonstration on how a computer “sees”. The goal is for people to understand that images are just a large array of numbers. 3. Giving people an understanding of what is AI and ML. 4. Show how object detection and image classification work, and showing the advantages of using AI for asset management and data capture, including how to train an object detection model yourself. 5. Discussing the advances in SLAM technology, and how to apply to digital capture. Two technologies will be explored: a. 3D Stereo cameras (Intel OAK-D, and a DIY 3D Stereo Camera) b. LiDar Results, Observations, Conclusions The results, observations, and conclusions we hope the audience takes away from this presentation is: * AI can be used to enhance digital capture and information management * The tools and technology to do so are affordable and accessible * These are tools that future engineering and technical people need to be capable of utilizing, and will help enhance engineering decision making. Novel / Additive Information Several companies are now offering AI and ML services, the point of this presentation is to get people excited about using this technology by showing them how to utilize in particle, everyday applications. Presentation notes, and source code will be made available to all participants.

Igor Cornejo 300x300
Igor Cornejo Senior Technical Consultant Enquete Smart Analytics
  • 11 30 AM

Advances in Solar Energy for Industry

Sustainable Electricity Generation and Grid Modernization

This presentation is an overview of latest developments and the improving economics of solar energy. Discussed is Concentrated Solar Power (CSP) for Enhanced Oil Recovery (EOR), and Solar Photovolt...

Sponsored By : INNIO Group

  • locationROOM C
  • small-arm11:30 AM - 12:00 PM
thursday September 23, 2021
Sustainable Electricity Generation and Grid Modernization

Advances in Solar Energy for Industry

  • pr-alarm11:30 AM - 12:00 PM
  • pr-locationROOM C
Sponsored By
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This presentation is an overview of latest developments and the improving economics of solar energy. Discussed is Concentrated Solar Power (CSP) for Enhanced Oil Recovery (EOR), and Solar Photovoltaic (PV) for industrial electricity applications. The solar sector has achieved grid-parity in many jurisdictions around the globe due to tiny but steady efficiency gains. Photovoltaic solar modules now generate energy from the front and back of the module; efficiency rates for Tier 1 modules are breaking the 20% barrier in most cases. Modules and inverters with 1500-volt capacities are reducing string costs, labour hours, and other balance of system costs. Self-consumption of solar electricity receives the highest value through net-metering programs being implemented in many North American jurisdictions. A solar generator avoids both the cost of grid electricity as well as part of their utility’s delivery charges (variable delivery costs). Over the past year Sol Power Projects Ltd. has tested concentrated solar thermal technologies and begun adapting them to a northern climate like Alberta where wind and temperature have made many of these technologies irrelevant. We’ve focussed on parabolic trough designs, enclosing them inside greenhouse-type transparent-membrane structures to shield the solar receivers from wind and cool temperatures. The enclosed-trough design has enabled the system to generate high-grade heat and steam for EOR. Using solar engineering models from European installation sites, we can now predict with accuracy the production potential of CSP at any project site, including Alberta’s oil sands. The new decade has also seen an increased focus on ESG values for corporate balance sheets, which is an adder to the economic case for solar energy in most applications. For example, the cost of GHG emissions compliance via the federal carbon tax will rise to $170 per tonne over the next 9 years which is 15% per year on a compounded basis. This is one reason for the increasing use of power purchase agreements (PPA’s) between utility-scale solar developers and corporations looking for ESG points. We see this mostly in productive solar locations like southern BC, Alberta and Saskatchewan. This paper will present the research data from our studies including internal rates of return (IRR) profiles for CSP and solar PV technologies as applied to energy production for industrial and utility-scale projects.

Tod Petersen 300x300
Tod Petersen CEO Sol Power Projects Ltd.
  • 12 00 PM
Lunch & Visit Exhibition
  • 1 30 PM

Acceleware to Provide Update and Initial Results from the Marwayne RF XL Pilot; Update on ‘Acceleware | Kisâstwêw’ Partnership

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Technological advancements are making possible the electrification of enhanced oil recovery (EOR) methods for heavy oil and oil sands. Economic electrification means that we can stop burning fossil...

  • locationROOM A
  • small-arm1:30 PM - 2:00 PM
thursday September 23, 2021
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Acceleware to Provide Update and Initial Results from the Marwayne RF XL Pilot; Update on ‘Acceleware | Kisâstwêw’ Partnership

  • pr-alarm1:30 PM - 2:00 PM
  • pr-locationROOM A

Technological advancements are making possible the electrification of enhanced oil recovery (EOR) methods for heavy oil and oil sands. Economic electrification means that we can stop burning fossil fuels to produce fossil fuels, instead enabling the use of green electricity - a critical step toward a clean energy transition and market growth. To that end, Acceleware has planned a commercial scale pilot at its partner Broadview Energy’s Marwayne, Alberta site to validate its patented and patent-pending RF XL (Radio Frequency XL) system; an all-electric, highly efficient heating system that can be applied to economically and cleanly produce heavy oil and oil sands, and that can be deployed and become operational quickly. The RF XL pilot project will start construction and heating in Q1 of 2021 to demonstrate how Acceleware’s RF XL technology functions at commercial scale in an operational environment, and is intended to prove out its heating capabilities as well as immediate and sustainable environmental, economic and social benefits, including: 1. Significant operating and capital cost reductions; 2. Half the energy required compared to SAGD, resulting in greenhouse gas (GHG) emissions reductions of approximately 50%; 3. Near-zero GHGs possible through direct or indirect use of renewable power; 4. No fresh water use and no solvents required; 5. Creation and maintenance of skilled, high-tech jobs; and 6. Transition of jobs in the oil sector to good paying jobs in the new energy economy. The objective of the project is to complete an in-reservoir test of RF-XL’s dynamic transmission line technology. The test will be completed at consortium partner, Broadview Energy Ltd.’s Marwayne property, and will validate performance and efficiency of the technology. In addition to potentially creating the means for a clean energy transition for fossil fuels, RF XL could be used as a heating engine for multiple other low carbon, clean-tech heating applications, providing a bridge to low-carbon prosperity for Alberta. In November 2020, Acceleware established Acceleware | Kisâstwêw, a partnership with Saa Dene Group. Acceleware | Kisâstwêw merges two great cultures to drive the commercialization and adoption of Acceleware technologies, including RF XL. Acceleware’s culture of innovation is a match with Saa Dene Group’s deep experience, contacts within the Canadian energy industry, and desire for responsible growth. In this presentation we will provide an overview the pilot project activities at Marwayne and results to date as well as provide an update on the activities and vision of the Acceleware | Kisâstwêw partnership.

Mike Tourigny 300x300.jpg
Mike Tourigny Chief Operating Officer Acceleware Limited
  • 1 30 PM

Decarbonizing Heavy Industry through Waste Heat to Power

Sustainable Electricity Generation and Grid Modernization

Kanin seeks to capture waste heat from industrial processes and convert it to clean baseload electricity. In doing so, Kanin contributes emission-free baseload electricity generation, thereby offse...

Sponsored By : INNIO Group

  • locationROOM B
  • small-arm1:30 PM - 2:00 PM
thursday September 23, 2021
Sustainable Electricity Generation and Grid Modernization

Decarbonizing Heavy Industry through Waste Heat to Power

  • pr-alarm1:30 PM - 2:00 PM
  • pr-locationROOM B
Sponsored By
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Kanin seeks to capture waste heat from industrial processes and convert it to clean baseload electricity. In doing so, Kanin contributes emission-free baseload electricity generation, thereby offsetting power produced from fossil fuels. Of all the energy produced and consumed to do ‘work’, up to 58% is lost in the form of waste heat during industrial processes. The ability to capture wasted energy and produce Waste Heat to Power (WHP) is viable in many different industries. The primary requirement is a source of at least 150⁰C. Kanin utilizes best-in-class Organic Rankine Cycle (ORC) systems that efficiently converts a waste product into a sustainable useable product through the development of WHP projects. These closed-loop systems generate electricity by heating an organic fluid that expands and gasifies to drive a turbine. The power generated by Kanin can be consumed by industrial facilities on-site or sold back to regional electricity grids. Kanin’s approach is founded on a third-party capital model that can unlock WHP projects across North America. In many instances these projects have previously been identified but were difficult to finance by host facilities because of internal hurdle rates. Kanin plans to own, operate, and maintain WHP systems without cost to industrial host facilities so that the potential of WHP can be realized. The industrial facilities Kanin targets are often scope-one emitters, so a Kanin system promotes sustainability in the most emission-intensive portion of supply chains. Electricity grid operators have mandates to decarbonize power production through adoption of intermittent renewable energy and retirement of fossil-fuel fired generation. WHP produces clean baseload electricity, which can provide a backstop to the intermittent power from wind and solar. To execute these projects, Kanin brings expertise in waste heat technology, project development, operations, energy financing, and energy & carbon markets. Heavy industry is the primary market for Kanin Energy with applications including natural gas compression stations, cement manufacturing, and steelmaking. For example, Kanin is developing an 8.6MW WHP project at an existing natural gas compressor station in Alberta. The WHP project can produce baseload, emission-free electricity that can be sold to the Alberta power market. A single project can produce enough energy to power ~9,000 homes per year. The project will also unlock a new revenue stream and reduce the facility's emissions profile. In North America alone, Kanin has identified a 9.6 GW potential from WHP generation with a capital deployment opportunity of $24 billion. North America has several hundred MWs installed but the market is undeveloped since projects require a 5-7-year payback period when industrials operators are seeking a 12-24-month payback. Through third-party capital, Kanin aligns the incentives of industrial operators who receive compensation for waste heat while capital providers gain a successful clean energy project.

Janice Tran 300x300
Janice Tran Chief Executive Officer Kanin Energy
  • 1 30 PM

Carbon Capture and Storage (CCS)

Technical Panel Session

Carbon Capture Storage (CCS) is an emissions reduction process designed to prevent large amounts of CO2 from being released into the atmosphere. Considered a necessary clean energy technology to re...

Sponsored By : RSM Canada

  • locationROOM C
  • small-arm1:30 PM - 3:00 PM
thursday September 23, 2021
Technical Panel Session

Carbon Capture and Storage (CCS)

  • pr-alarm1:30 PM - 3:00 PM
  • pr-locationROOM C
Sponsored By
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Carbon Capture Storage (CCS) is an emissions reduction process designed to prevent large amounts of CO2 from being released into the atmosphere. Considered a necessary clean energy technology to reduce industry-driven GHGs, CCS is a three-step process consisting of CO2 capture, transportation, and utilization and/or storage.

The panel will cover the following:

• Overview of CCS globally and in North America
• What are changing regulators landscape look like?
• The economics of Carbon Capture storage
• Some success stories
• What does the future of CCS look like?

Moderator
Michael Morrison 300x300
Michael Morrison Partner, Tax RSM Canada
Alex Kotsopoulos 300x300
Alex Kotsopoulos Partner, Projects and Economics RSM Canada
Beth Valiaho 300x300
Beth (Hardy) Valiaho Vice-President, Strategy & Stakeholder Relations The International CCS Knowledge Centre
  • 2 00 PM

Catalyzing Better Environmental Outcomes through Collaboration

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Oil and gas companies are the largest spenders on clean technology in Canada. Of the approximately $1.4 billion that Canadian companies invest in this space each year, 75 per cent comes from the...

  • locationROOM A
  • small-arm2:00 PM - 2:30 PM
thursday September 23, 2021
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Catalyzing Better Environmental Outcomes through Collaboration

  • pr-alarm2:00 PM - 2:30 PM
  • pr-locationROOM A

Oil and gas companies are the largest spenders on clean technology in Canada. Of the approximately $1.4 billion that Canadian companies invest in this space each year, 75 per cent comes from the oil and gas industry. At the forefront of that is Canada’s Oil Sands Innovation Alliance (COSIA), an alliance of oil sands producers focused on accelerating the pace of environmental performance improvement in Canada’s oil sands through collaborative action and innovation. COSIA’s members represent over 90% of total oil sands production. COSIA brings together leading thinkers from industry, government, academia and the wider public to improve measurement, accountability and environmental performance in the oil sands in the areas of greenhouse gases, land, water and tailings. Since COSIA was launched in 2012, its members have invested $1.6 billion to develop 1,076 technologies to improve tailings management and reduce industrial impacts on air, land and water. $621 million is currently dedicated to a total of 225 active projects. The results are evident. For example, through COSIA, oil sands operators have reduced freshwater use intensity at in situ operations by 44 per cent and reduced their water use intensity from the Athabasca river at mining operations by 22 per cent ?" all since 2012. Innovations have also resulted in a 20 per cent reduction in GHG emissions intensity from members between 2009 and 2018 (IHS Markit). COSIA’s globally unique model enables oil sands producers to share and leverage technologies, research, scientific data and intellectual property ?" resulting in substantial environmental performance improvement. COSIA’s unique “made-in-Canada” model provides opportunities for solution providers with capabilities to address key oil sands environmental innovation opportunities. At the same time, many of the innovations developed through COSIA have potential for applicability in other energy sectors and industries around the world. Collectively, these efforts in research and clean technology demonstrate the potential for reducing climate-impacts while also meeting growing global energy demand.

Wes Jickling 300x300
Wes Jickling Chief Executive Canada's Oil Sands Innovation Alliance
  • 2 00 PM

Low Carbon Generation

Sustainable Electricity Generation and Grid Modernization

The objective of this presentation is to examine Low Carbon Power Generation using Turbine technology. We will examine several common applications and a few nascent novel applications of Turbines....

Sponsored By : INNIO Group

  • locationROOM B
  • small-arm2:00 PM - 2:30 PM
thursday September 23, 2021
Sustainable Electricity Generation and Grid Modernization

Low Carbon Generation

  • pr-alarm2:00 PM - 2:30 PM
  • pr-locationROOM B
Sponsored By
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The objective of this presentation is to examine Low Carbon Power Generation using Turbine technology. We will examine several common applications and a few nascent novel applications of Turbines. The carbon intensity or offset of each of the cases is based on the Grid intensity of the location, and how the energy is utilized. There are many low carbon power generation technologies, this paper only examines cases using Turbines and associated equipment. As Coal fired thermal plants are retired, the intensity number will decrease. Looking out to 2050 systems fueled by natural gas will continue to reduce carbon emissions but the spread will close. Even cleaner fuels and combinations of technologies will be parts of the energy mix. Case 1 Theoretical SAGD operation importing 17 MW of Grid Power. Replace Grid Power with Cogeneration to make power and thermal energy at source. Examine impact of Nat Gas Fired versus blended H2 Nat Gas and 100% H2 fueled. Case 2 Widespread application of CHP and CCHP for buildings combined with District Heating and Cooling systems offering increased efficiency, lower cost and GHG versus Grid Power and Boiler systems. Greater energy security against weather events and other blackout situations. Case 3 Storage and Turbine combinations Hydro Turbine Pumped Storage ? Large Scale Hydro Turbine ?" micro gen for backcountry lodges and smaller demand sites with flowing water Gas Turbine and Battery Storage System Micro Grid Case 4 Solar Concentrator making sufficiently hot air to drive a microturbine, up to 20 hours a day, producing zero carbon emissions. Case 5 Efficient combustion of gases associated with Oil & Gas production. Flare reduction and Methane mitigation are an ongoing process in Oil & Gas production. Efficient combustion harvesting heat and power. Case 6 Efficient combustion of syngas from Pyrolysis operations. Waste to energy is a fast evolving industry. The product streams from these operations include Char, bio Diesel, and syngas. The syngas is not suitable for direct combustion in a turbine. Other fuel sources with low carbon rating: Landfill Gas (primarily Methane), is classified as a renewable source of energy Digester Gas from the anaerobic decomposition of waste from humans, animals, and some manufacturing processes is also a renewable. Microgrids, any combination of MTs, BESS, PVs, and Wind can generate electricity for dispatch to the load. SMR may be able to displace some grid power in the future, could have a material impact on Non-Conventional Oil production. Conclusion The solutions of the future are many and varied. Technology around low carbon generation is advancing rapidly. In addition, lifestyle changes and new technology not yet available or made public will also play a part.

Gordon Olson 300x300
Gordon Olson Director Business Development Capstone Green Energy
  • 2 30 PM

A Targeted Catalytic Approach Towards Reducing Diluent in Oil Sands Processes

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Recent growth of bitumen production in the Oil Sands has outpaced the construction of new takeaway capacity, causing a widening of the heavy-to-light differential and a deterioration in the profita...

  • locationROOM A
  • small-arm9:30 AM - 3:00 PM
thursday September 23, 2021
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

A Targeted Catalytic Approach Towards Reducing Diluent in Oil Sands Processes

  • pr-alarm9:30 AM - 3:00 PM
  • pr-locationROOM A

Recent growth of bitumen production in the Oil Sands has outpaced the construction of new takeaway capacity, causing a widening of the heavy-to-light differential and a deterioration in the profitability of many SAGD producers. Coupled with staunch opposition to the timely approval and construction of new pipelines, this environment is set to remain for the near-term, causing many to search for cost-effective alternatives for bitumen transportation. Within this paper, we describe the development of a novel technology, which represents a viable and actionable process for reducing the volume of diluent required to produce a transportable product by up to 50% while simultaneously increasing existing transportation infrastructure by 15%. The approach detailed here centers on building a fundamental understanding of the asphaltenic fraction of a given bitumen - believed to drive the viscous nature of heavier crudes - followed by the rational design of a catalyst system best-suited to breakdown these larger and less-mobile components. While virtually impossible to completely describe native asphaltene structure, the use of powerful analytical tools and techniques does allow for the direct characterization of various structural moieties present within the range of asphaltene molecules. Provided this information, molecular models are deployed to evaluate the near-infinite number of possible chemical conformations, proposing a most energetically-favoured, and therefore, statistically-likely, asphaltene molecule that satisfies said analytical analysis. Lastly, quantum mechanical methods are applied to identify and rationally design reaction conditions tailored for the target chemical structure to maximize reactivity. The ultimate result is a mild-catalytic system capable of significant modification of the heavier components of bitumen, drastically reducing viscosity by more than 95%, while utilizing a lower thermal input (below 350ºC) than traditional catalytic approaches deployed at the refinery. An intended side-effect of this low-severity approach is the suppression of elimination reaction products, minimizing the formation of undesired by-products such as olefins (confirmed via 1H NMR), the existence of which prohibits the ability to blend the crude product with existing market pools. By avoiding the formation of olefins, this approach negates the need for post-reaction hydrotreatment, thereby minimizing process complexity, leading to a more seamless integration into existing upstream facilities. In addition to the presentation of extensive laboratory data supporting the viability of this approach, recent results generated at the field-level will also be presented as we are currently operating a 500 barrel per day (emulsion basis) demonstration unit at a SAGD facility in a joint project with a prominent Canadian firm.

Sivaram Pradhan 300x300.jpg
Sivaram Pradhan Research Scientist Nextstream
  • 2 30 PM

Strategic Development Plan and Techno-Economic Aspects of Compressed Air Energy Storage (CAES) in Subsurface Porous Formations

Sustainable Electricity Generation and Grid Modernization

Compressed Air Energy Storage (CAES) generally consists of electricity conversion to compressed air, underground storage, and compressed air utilization to generate electricity mostly during peak-s...

Sponsored By : INNIO Group

  • locationROOM B
  • small-arm2:30 PM - 3:00 PM
thursday September 23, 2021
Sustainable Electricity Generation and Grid Modernization

Strategic Development Plan and Techno-Economic Aspects of Compressed Air Energy Storage (CAES) in Subsurface Porous Formations

  • pr-alarm2:30 PM - 3:00 PM
  • pr-locationROOM B
Sponsored By
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Compressed Air Energy Storage (CAES) generally consists of electricity conversion to compressed air, underground storage, and compressed air utilization to generate electricity mostly during peak-shaving, resulting in higher revenues due to higher electricity prices. CAES can be utilized with renewable energies for power balancing and lowering environmental impacts by achieving low-carbon targets. In the CAES process, according to the power grid requirement, the stored underground compressed air is produced, heated, and used in turbines to produce electricity. Underground storage can be in salt caverns and porous formations. However, the beneficial potentials of CAES on large industrial scales can be mostly realized through the use of underground porous media like saline aquifers and depleted hydrocarbon reservoirs. Subsurface geological porous formations have significant storage potentials to provide high energy production capabilities on long- time scales required by electrical power providers. Saline aquifers and depleted oil and gas fields are promising large-scale energy storage options. The essential factor in establishing the feasibility of underground formations for compressed air energy storage is the rate of air injection and production from wells designated as injectors and producers. The porous formation properties directly affect the capability of wells. The electricity demand controls the number of injection and production wells required. The effects of pressure and reservoir property on storage performance and the number of wells are discussed. In this paper, the main differences between salt caverns and porous formations as compressed air storage candidates and the merits and challenges of storage in saline aquifers and depleted oil and gas reservoirs are presented. The multidiscipline expertise required for compressed air storage in saline aquifers and depleted oil and gas reservoirs are addressed. The professional expertise for successful development, implementation, and management of a CAES project with porous formation needs special consideration. CAES with underground porous formation is a challenging multidiscipline venture which requires various technologies and experts with extensive reservoir engineering industrial experience and a high level of technical engineering knowledge. Several case studies regarding the development of compressed air energy storage in underground porous formations and the outcomes and the advantages, challenges, and potentials of underground porous formations for future air energy storage plants are addressed. A general strategic plan for compressed air storage in depleted oil and gas fields and saline aquifers and the typical economic characteristics and benefits presented.

Coauthor: Geoff Martin BSc, MIM, International Energy Consultant, Associate, Alconsult International, Senior Associate, Canadian Energy Systems Analysis Research (CESAR), The University of Calgary

Davood Khairkhah 300x300
Davood Khairkhah Senior Advisor, Upstream DavFaye
  • 3 00 PM
End of Day Three and Conclusion of Technical Conference