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North America's Leading Energy Event
June 13-15, 2023
BMO Centre at Stampede Park - Calgary, Canada

Co-Host
  • 8 00 AM
Registration Opens
  • 9 00 AM

Opening Plenary

  • locationPALOMINO ROOM ABCDE
  • small-arm9:00 AM - 12:00 PM
tuesday June 07, 2022

Opening Plenary

  • pr-alarm9:00 AM - 12:00 PM
  • pr-locationPALOMINO ROOM ABCDE
  • 12 00 PM
Networking Luncheon & Visit Exhibition
  • 1 25 PM
TECHNICAL CONFERENCE
  • 1 30 PM

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

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

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 gen...

  • locationROOM A
  • small-arm1:30 PM - 2:00 PM
tuesday June 07, 2022
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

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

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

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). 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. 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 availability 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. 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
  • 1 30 PM

Low Carbon Power Generation

Sustainable Electricity Generation & 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...

  • locationROOM B
  • small-arm1:30 PM - 2:00 PM
tuesday June 07, 2022
Sustainable Electricity Generation & Grid Modernization

Low Carbon Power Generation

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

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, & 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 industrial 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

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

Drilling & Completion

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-arm1:30 PM - 2:00 PM
tuesday June 07, 2022
Drilling & Completion

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

  • pr-alarm1:30 PM - 2:00 PM
  • 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 Alberta. The prediction accuracy of the various combinations was measured by using the mean average percent error and mean absolute error 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
  • 2 00 PM

Hydrochemolytic Processing at Low Temperatures: A New Way of Processing Heavy Oils

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

The 2018 whitepaper study on partial upgrading of heavy bituminous oils, produced for Alberta Innovates by Jacobs Consultancy, points towards four critical categories: viscosity and density reducti...

  • locationROOM A
  • small-arm2:00 PM - 2:30 PM
tuesday June 07, 2022
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Hydrochemolytic Processing at Low Temperatures: A New Way of Processing Heavy Oils

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

The 2018 whitepaper study on partial upgrading of heavy bituminous oils, produced for Alberta Innovates by Jacobs Consultancy, points towards four critical categories: viscosity and density reduction; value enhancement; product fungibility; and CAPEX reduction. We describe a new process termed “hydrochemolytic” for bitumen upgrading that addresses these categories while obtaining yields in excess of 90%, depending on operating severity. Operating at temperatures much lower than those used in traditional thermolytic processes (290 ºC ? 390 ºC versus 400 ºC ?" 1100 ºC), the process deconstructs the larger, heavier Hydrochemolytic™ Technology (HCT) is being developed to process heavy oils into lighter, pipeline ready oils. It is a relatively simple water-based process that uses water instead of heat to maximize the efficiency of the process. HCT uses a unique chemical conversion process, requiring only low-value, readily available metals as catalysts, along with co-processed biobased material. Hydrogen equivalents are used in the process, and these are generated in situ from renewable sources, such as glycerol, cellulose, and other biobased materials—replacing the need for the hydrogen gas needed when using traditional technologies. Hydrochemolytic conversion is very efficient compared to traditional technologies, with high yields realized, and only relatively low temperatures (<375 degrees C) required.

Hydrochemolytic™ Technology offers a unique and promising approach to upgrading of heavy oils. This paper will share new data for the process based on recently completed continuous flow testing.
In addition, we will discuss the extension of HCT into upcycling post-use polyethylene and other plastics, with an end product of high-value hydrocarbon feedstocks.

Gene Cammack 300x300
Gene Cammack Chief Operating Officer Aduro Clean Technologies Inc.
  • 2 00 PM

Small Modular Nuclear Reactors as a Source of Heat and Power Production for the O&G Industry

Sustainable Electricity Generation & 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...

  • locationROOM B
  • small-arm2:00 PM - 2:30 PM
tuesday June 07, 2022
Sustainable Electricity Generation & Grid Modernization

Small Modular Nuclear Reactors as a Source of Heat and Power Production for the O&G Industry

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

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 gas production, processing, and transmission, 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 either existing or new operations. This paper will introduce SMNRs and how they could be used to support the heat and power needs of the oil and gas industry. This will include an overview of various SMNR technologies and the current state of the industry as well as an examination of potential uses of an SMNR for typical oil and gas processes including resource extraction, processing, and refining. Consideration will also be given to an economic comparison of SMNRs to incumbent technologies to highlight the potential value of SMNR deployment to the oil and gas industries.

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

Rapid, Rigless, Live-Well Deployment System for ESP or ESPCP

Drilling & Completion

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

  • locationROOM C
  • small-arm2:00 PM - 2:30 PM
tuesday June 07, 2022
Drilling & Completion

Rapid, Rigless, Live-Well Deployment System for ESP or ESPCP

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

The objective is to introduce a rapid, rigless, live-well ESP or PCP deployment system. The presentation 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 30 PM
Coffee Break & Visit Exhibition
  • 3 00 PM

Update/Initial Results from the Marwayne RF XL Pilot and CTI (Clean Tech Inverter) Potential

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Acceleware’s clean-tech commercial pilot project ? a world first for electrification of heavy oil and oil sands production, is expected to reach power-up stage in Q1 2022. Once the RF XL electrific...

  • locationROOM A
  • small-arm3:00 PM - 3:30 PM
tuesday June 07, 2022
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Update/Initial Results from the Marwayne RF XL Pilot and CTI (Clean Tech Inverter) Potential

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

Acceleware’s clean-tech commercial pilot project ? a world first for electrification of heavy oil and oil sands production, is expected to reach power-up stage in Q1 2022. Once the RF XL electrification technology behind the pilot is proven, it could deliver major progress in decarbonization milestones within Canada and could help to the oil and gas sector achieve net zero greenhouse gas (GHG) emissions by 2050. Acceleware’s $20 million fully-funded commercial scale pilot of RF XL in Marwayne, Alberta, will demonstrate a next-gen transitional technology that will replace natural gas generated steam with radio frequency (“RF”) energy. This technology could quickly produce vastly cleaner heavy oil and oil sands production ?" essentially providing a much-needed mechanism to ‘connect the dots’ between the old and the new during the energy transition. In short, RF XL is a decarbonization technology that could eliminate Scope 1 and Scope 2 GHG emissions without the need for carbon capture or the use of carbon offsets in Canada’s heavy oil and oil sands production. It also eliminates fresh water use entirely. Production using this technology could quickly and effectively function as an economic means to cleaning up heavy oil and oil sands production while other energy transition innovations are maturing, drive strong investment growth and lead to much needed diversification and sector sustainability while creating jobs. Our modelling predicts heavy oil and oil sands producers deploying RF XL could see cash flow breakeven in two to three years driven by capital cost reductions of 50% and operating cost reductions of 40%. Emissions Reduction Alberta, Alberta Innovates and Sustainable Development Technology Canada are supporting the pilot with a combined $15.5 million commitment. The pilot is also supported by three major oilsands partners (Suncor, Cenovus, and one confidential partner who, in aggregate, represent well over one million barrels of oil sands and heavy oil production per day) who are providing technical expertise and have each committed to provide up to $2 million in cash funding. In addition to the support noted above, Acceleware has an Indigenous-owned partnership ?" Acceleware | Kisâstwêw ?" with Chief Jim Boucher and Jauvonne Kitto of the Saa Dene Group of Companies, which firmly supports energy initiatives that protect our land, our water and our air while helping to develop sustainable economies for all. We are looking forward to ensuring those initiatives materialize. In this presentation we will provide an overview of the pilot project at Marwayne, test results to date, next steps in the commercialization of RF XL, and insights into the future potential applications of the Clean Tech Inverter (CTI) to support the energy transition by decarbonizing other industrial heating processes.

Mike Tourigny 300x300.jpg
Mike Tourigny Chief Operating Officer Acceleware Limited
  • 3 00 PM

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

Sustainable Electricity Generation & 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. T...

  • locationROOM B
  • small-arm3:00 PM - 3:30 PM
tuesday June 07, 2022
Sustainable Electricity Generation & Grid Modernization

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

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

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
  • 3 00 PM
tuesday June 07, 2022
Technical Panel Session

Panel: CCUS Global Hubs and the Opportunity to Meet Net Zero Goals

  • pr-alarm3:00 PM - 4:30 PM
  • pr-locationROOM C
Moderator
Marla Orenstein 300x300
Marla Orenstein Director, Natural Resources Centre Canada West Foundation
Greg Maidment 300x300
Greg Maidment Director of Operations and Applied Research Carbon Management Canada
Anamika-Mukherjee-300x300
Anamika Mukherjee Director, Innovation Cenovus Energy
Candice Paton 300x300
Candice Paton Executive Director, Regulatory Affairs & External Relations Enhance Energy Inc.
  • 3 30 PM

In-Situ Combustion as a Post-Steam Drive Oil Recovery Process. From Pilot to Commercial Operation

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Authors: Dr. Alex Turta, A T EOR Consulting Inc., Calgary Nicolae Ilie, Former PETROM/OMV, Romania, presently Consultant Dr. Ashok Singhal, Premier Reservoir Engineering Services Ltd, Calgary I...

  • locationROOM A
  • small-arm4:00 PM - 4:00 PM
tuesday June 07, 2022
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

In-Situ Combustion as a Post-Steam Drive Oil Recovery Process. From Pilot to Commercial Operation

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

Authors: Dr. Alex Turta, A T EOR Consulting Inc., Calgary Nicolae Ilie, Former PETROM/OMV, Romania, presently Consultant Dr. Ashok Singhal, Premier Reservoir Engineering Services Ltd, Calgary In-situ combustion (ISC) was successfully applied after steam drive in a recent commercial heavy oil recovery project in China. In this paper, two main aspects are discussed: 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 four 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 analyses have appeared in the open literature. Our analysis yielded suggestions for improvement. Feasibility of ISC application in a tertiary mode (following steam flooding) was assessed by analysing the performance of one pilot, two semi-commercial operations and one commercial operation in three different oil fields. The pilot consisted in one inverted 5-spot pattern operated in a heavy oil field (oil viscosity 1600cp) at a depth of 500 m for a pay zone of 28 m. The pattern was operated for 2 years by ISC after a steamdrive, which lasted 4 years. Oil recovery increased from 36% (for steamdrive) to 73%, and it was obtained at a low air-oil ratio of 1,700 sm3/m3 The first semi-commercial project involved application of ISC at a depth of 120 m for a pay zone of 6-8 m. This happened in a heavy oil reservoir (oil viscosity 2000cp), which has been under exploitation by commercial ISC for longer than 50 years. Six inverted nine-spots were steam flooded for 6 years, and were subsequently harvested by line-drive ISC in a period of 5 years. The oil recovery increased from 35% to 52% at an air-oil ratio not higher than in other regions exploited by ISC after primary recovery. The second semi-commercial project involved application of ISC at a depth of 550 m for an 8 m pay zone; oil viscosity was higher than 16,00cp. Initially, 7 air injectors were used, 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 - which occurred after 10 years of suspension of any field activity - the water cut was almost 100%. After 4 years of ISC, the water cut decreased to 60%; air-oil ratio started around 5,000 sm3/m3, but continually decreased to as low as 2,200 sm3/m3. After 8 years of operation the project was evaluated as a successful tertiary process and extended to commercial operation; as of 2021, 68 air injection wells and more than 300 production wells were part of this commercial project. The process recorded upgrading of the produced oil. On average, oil produced had a viscosity 5 times less than that of original oil, and API of the oil increased from 15 to 17 0API.

Alexandru Turta 300x300
Alexandru Turta CEO and President A T EOR Consulting Inc.
  • 3 30 PM

The Role of Natural Gas in a Deeply Decarbonized Economy

Sustainable Electricity Generation & Grid Modernization

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-arm3:30 PM - 4:00 PM
tuesday June 07, 2022
Sustainable Electricity Generation & Grid Modernization

The Role of Natural Gas in a Deeply Decarbonized Economy

  • pr-alarm3:30 PM - 4:00 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 00 PM

Demonstration Project Reduces Energy Consumption by 35% for Horizontal Wells

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Oil producers typically install VFD controllers with high efficiency Nema B motors on new horizontal wells in an attempt to reduce the energy intensity of reciprocating artificial lift. This combin...

  • locationROOM A
  • small-arm4:00 PM - 4:30 PM
tuesday June 07, 2022
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Demonstration Project Reduces Energy Consumption by 35% for Horizontal Wells

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

Oil producers typically install VFD controllers with high efficiency Nema B motors on new horizontal wells in an attempt to reduce the energy intensity of reciprocating artificial lift. This combination usually provides a 20% improvement in energy cost over the use of Nema D motors. Unfortunately, for existing wells this reduction in cost is not enough to generate the payback horizon required for replacing the existing Nema D motors with VFD controllers coupled with high efficiency Nema B motors. Additionally, attempts to use more expensive regenerative units increases capital costs which cancels out the added energy savings leaving producers with no option forward for existing wells. In contrast to this traditional approach, our modeling indicated that it should be possible to achieve more than a 30% reduction in energy costs through the use of more advanced control methods for a VFD coupled with an existing Nema D motor. To validate our modeling, we partnered with an oil producer and Alberta Innovates to demonstrate energy intensity reduction on a large number of wells in real-field conditions over a year-long period. The goal was to demonstrate a viable path to permanent reduction in operating cost and energy intensity for existing oil production and make investing in energy intensity and lifting cost reduction more appealing. We will present results from our product demonstration field trial in South-East Saskatchewan that was initiated in the fall of 2020. We installed our advanced IIoT automation VFD controllers and coupled them with existing Nema D motors on 24 wellsites, collected power consumption and productivity data for each well before and documented power consumption and well productivity post installation. 12 months of data from this demonstration, including cost analysis, energy reduction results, and methodology demonstrates that our proprietary VFD control technology coupled with our machine learning analytics minimizes lifetime energy intensity by over 35% creating a strong financial incentive for oil producers to invest in energy intensity reduction.

Krzysztof Palka 300x300
Krzysztof Palka Founder and CEO Akinê Inc.
  • 4 00 PM

Digitalization of Mission Critical Calibration Processes

Sustainable Electricity Generation & Grid Modernization

Speed and accuracy of information is more important than ever. When it comes to calibration this has never been truer. Increased regulation, oversight and the demand for up-to-the-minute data req...

  • locationROOM B
  • small-arm4:00 PM - 4:30 PM
tuesday June 07, 2022
Sustainable Electricity Generation & Grid Modernization

Digitalization of Mission Critical Calibration Processes

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

Speed and accuracy of information is more important than ever. When it comes to calibration this has never been truer. Increased regulation, oversight and the demand for up-to-the-minute data requires an adaptive and automated calibration process. But how can you implement a digital process when faced with issues such as budget restrictions, overextended IT resources, and regulatory uncertainties.
Because Industry 4.0 is closely interlinked with information and communication technologies, a strategy that includes an integrated Calibration Solution (ICS) provides a digital backbone to mission critical processes.
A “top to bottom” ICS includes not only hardware and software, but support components such as integration services as well. A well-designed and expertly deployed ICS provides users with a scalable solution that offers the choice of locally installed or cloud-based software, multi-function and customizable field equipment, and program integration knowledge & experience.
In an increasingly competitive and global business environment, business leaders must consider and explore all avenues for process improvement. The benefits of deploying an ICS far outweigh the costs and risks of not making that investment.

Peter Hachey 300x300
Peter Hachey Director of Sales Beamex Canada
  • 5 00 PM
Day One of Technical Conference Concludes for the Day
  • 7 30 AM
Registration Opens
  • 8 30 AM

AI-Powered Imaging for Continuous, Automated Offshore Platform Leak Detection

Clean Technology & 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...

Sponsored by: : Uptake Engineering

  • locationROOM A
  • small-arm8:30 AM - 9:00 AM
wednesday June 08, 2022
Clean Technology & Environmental Management

AI-Powered Imaging for Continuous, Automated Offshore Platform Leak Detection

  • pr-alarm8:30 AM - 9:00 AM
  • pr-locationROOM A
Sponsored by:
Uptake Technologies, Inc..png

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 therefore 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 thermography (using uncooled microbolometer) powered by edge-based artificial intelligence at remote platforms to automate detection of leaks as soon as they start and provide operators with tools to visually validate alarms quickly and cost effectively. The technology capabilities, installation process and set up configuration recommendations will also be covered. Analytic thermal imaging is a relatively new, non-traditional fluid leak detection method adopted in recent years by major oil and gas operators in North America. The site-installed 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), two to three weeks of calibration, and training of operators and administrators. All installed systems are currently running without downtime, resulting in a low/no maintenance solution to date. Leaks, large and small (as little as 1L/s), can be detected and alarmed on in less than 30 seconds, and visually verified offsite 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 a more 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.

Mike Mckay 300x300
Mike Mckay Director of Customer Engineering Services Intelliview Technolgies Inc.
  • 8 30 AM

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 so...

  • locationROOM B
  • small-arm8:30 AM - 9:00 AM
wednesday June 08, 2022
Reservoir Engineering

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

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

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.
  • 8 30 AM

Clean Energy Future with INNIO Group

Hydrogen

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

  • locationROOM C
  • small-arm8:30 AM - 9:00 AM
wednesday June 08, 2022
Hydrogen

Clean Energy Future with INNIO Group

  • pr-alarm8:30 AM - 9:00 AM
  • pr-locationROOM C
Sponsored by:
INNIO Group

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.

Jon Rowland 300x300
Jon Rowland Senior Sales Manager, Canada INNIO Group
Sean Manz 300x300
Sean Manz Lead Sales Manager, Canada INNIO Group
  • 9 00 AM

Utilizing Electrolysis to Reduce Greenhouse Gas Emissions in Gas-to-Liquids Processes

Clean Technology & Environmental Management

This paper seeks to investigate and benchmark the performance of two integrated flow schemes developed with the intent of reducing the process scope carbon emissions intensity and improving overall...

Sponsored by: : Uptake Engineering

  • locationROOM A
  • small-arm9:00 AM - 9:30 AM
wednesday June 08, 2022
Clean Technology & Environmental Management

Utilizing Electrolysis to Reduce Greenhouse Gas Emissions in Gas-to-Liquids Processes

  • pr-alarm9:00 AM - 9:30 AM
  • pr-locationROOM A
Sponsored by:
Uptake Technologies, Inc..png

This paper seeks to investigate and benchmark the performance of two integrated flow schemes developed with the intent of reducing the process scope carbon emissions intensity and improving overall gas conversion efficiencies of conventional gas-to-liquids (GTL) Fischer-Tropsch (FT) synthesis processes. The presented reference case represents a conventional FT synthesis process utilizing a natural gas feedstock and autothermal reforming (ATR) unit for syngas generation. A carbon capture and sequestration (CCS) system is deployed within the process off-gas stream with the aim of abating process scope carbon emissions, representing a minimally invasive step change over more conventional FT synthesis flowsheets. In contrast, the primary study case that was developed leverages a hydrogen import generated through electrolysis, with the electrolysis power requirement supplied by the exothermic FT-synthesis process and supplemented with a renewable power source. The oxygen by-product from electrolysis is fed with natural gas to a partial oxidation (POx) unit to generate syngas for conversion within the FT synthesis loop. Furthermore, the co-production of hydrogen allows for changes in the GTL flow scheme, significantly decreasing the amount of CO2 generated. Specifically, the deployment of a POx unit reduces steam, oxygen, and fuel gas consumption when compared to more conventional reforming technologies such as ATR at the sacrifice of reduced H2:CO ratios. For the purposes of this study, the FT synthesis process was paired with a mild hydrocracker and product work-up unit to generate a mixture of naphtha, kerosene, and diesel end products. The balance of the plant systems, including steam, power, and fuel gas balances, were developed to maximize process efficiency based on the unique operating characteristics and parameters of the identified processes. Ultimately a direct comparison between the identified flow schemes is drawn wherein the presented study case exhibits an estimated gas conversion efficiency of 7,460 Standard Cubic Feed (SCF) per bbl of liquid product with a carbon conversion of 93.7%, representing a marked improvement over not only conventional FT synthesis processes but also over the presented reference case. This work ultimately demonstrates the potential benefits that can be achieved by customizing GTL designs to optimally accommodate a decarbonized hydrogen import stream. The results of this work have broader implications for not only the decarbonization of conventional GTL pathways but also less conventional waste and/or biomass to fuels processes that are similarly deficient in hydrogen, wherein analogous principles may potentially be applied to maximize product yields.

Patrick Mraz 300x300
Patrick Mraz Process Specialist Hatch Ltd.
  • 9 00 AM

Novel Solution to Reservoir Upscaling 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 la...

  • locationROOM B
  • small-arm9:00 AM - 9:30 AM
wednesday June 08, 2022
Reservoir Engineering

Novel Solution to Reservoir Upscaling for Large Models

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

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 10**9 grid 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 changes 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 petrophysical 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 passed into 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.
  • 9 00 AM

Low-Cost Hydrogen and RNG from Minimally Prepared Waste

Hydrogen

In this presentation the author describes a novel approach to making hydrogen today at less than half the cost of electrolysis, with a low or negative CO2 footprint, or alternatively renewable natu...

Sponsored by: : Innio

  • locationROOM C
  • small-arm9:00 AM - 9:30 AM
wednesday June 08, 2022
Hydrogen

Low-Cost Hydrogen and RNG from Minimally Prepared Waste

  • pr-alarm9:00 AM - 9:30 AM
  • pr-locationROOM C
Sponsored by:
INNIO Group

In this presentation the author describes a novel approach to making hydrogen today at less than half the cost of electrolysis, with a low or negative CO2 footprint, or alternatively renewable natural gas suitable for pipelines. This is done by converting minimally prepared MSW, RDF, biomass, ICI, or C&D waste to a clean syngas, then converting the syngas to fuel with standard unit processes, fully integrated to the syngas production for minimal risk and maximum conversion efficiency. The Larsen Lam Climate Change Initiative recently announced their full funding of a unit for a MSW to hydrogen plant in California. Their selection was made after examining 60 technologies, then conducting deep due diligence for several months on the six (6) finalists. OMNI’s Gasification and Plasma Refining System (OMNI 5000TM GPRSTM) for converting waste to syngas won the competition. On Bloomberg News, Ripple founder and billionaire Chris Larsen explained that the OMNI GPRSTM solves two very important world problems, namely making energetic waste “disappear” cleanly while extracting maximum value in low carbon fuels and avoiding methane in landfills. The syngas produced by the GPRSTM can be tailored to make hydrogen, liquid fuels, or power. By avoiding methane from landfills, the CO2e footprint can be negative. CO2 capture can allow for further reduction through sequestration. To make green hydrogen, waste is first converted to syngas using OMNI’s GPRSTM. The syngas is then converted to hydrogen and CO2 using a sour gas shift reactor designed and supplied by KP Engineering. Each unit will produce approximately 5000 tonnes/year of hydrogen. The process guarantee is backed by an insurance wrap and supported by data from over a decade of demonstration at a commercial scale. Delivery is de-risked by delivery in 200 tpd shop assembled modular units and choices made to ensure high availability. Commercial projects are being engineered and manufactured for California and China, with more in the pipeline. The conference presentation will also describe a hybrid approach, that of combining the OMNI unit with electrolysis. In this scheme, oxygen from electrolysis is used directly in the OMNI unit, and waste heat from the unit increases the efficiency of the electrolyser. The hybrid system combines the best of both alternatives for a flexible, low-cost solution, with significantly better economics than the electrolyser alone. Finally, the speaker will describe how OMNI has integrated its unit with methanation to produce renewable natural gas for injection into conventional pipelines, along with a short overview of projects in Canada and the U.K.

Chris Mamen 300x300
Chris Mamen Vice-President, Engineering Omni Conversion Technologies
  • 9 30 AM

Innovation and Collaboration is Driving Canada’s Energy Transition

Clean Technology & Environmental Management

Canada is racing to meet climate targets while producing the energy Canadians and the world needs today and in the foreseeable future. The oil sands industry is at the forefront of this energy tran...

Sponsored by: : Uptake Engineering

  • locationROOM A
  • small-arm9:30 AM - 10:00 AM
wednesday June 08, 2022
Clean Technology & Environmental Management

Innovation and Collaboration is Driving Canada’s Energy Transition

  • pr-alarm9:30 AM - 10:00 AM
  • pr-locationROOM A
Sponsored by:
Uptake Technologies, Inc..png

Canada is racing to meet climate targets while producing the energy Canadians and the world needs today and in the foreseeable future. The oil sands industry is at the forefront of this energy transition, a fundamental shift away from carbon-intensive energy production.. Canada and the industry’s goal is to produce energy with net zero emissions by 2050, while sustainably addressing other important aspects of the environment. What will it take? Ground-breaking innovation and intense collaboration like the world has never seen before. Canada’s Oil Sands Innovation Alliance (COSIA) sits at the juncture of both where it drives the research and development that will be critical to sustainable energy success. Made up of an alliance of producers that represent 90% of total oil sands production, COSIA’s track record of improving environmental performance in the region is second to none. In fact, Canadian oil sands companies are recognized as world leaders when it comes to Environmental, Social, Governance (ESG) performance. COSIA’s made-in-Canada model catalyzes extreme innovation and collaboration by bringing together leading thinkers from industry, government, academia and the broader public ?" at home and abroad ?" to solve tough environmental challenges. The focus is on reducing greenhouse gas emissions, minimizing the land footprint and stepping up water and tailings management. At its launch in 2012, COSIA was considered one of the most unique models of open innovation and collaboration the world had ever seen. It still is. Think innovation such as Carbon Capture Utilization and Storage (CCUS), natural gas decarbonization technologies, boiler flue gas heat recovery, satellite-enabled measurement and management of fugitive emissions, novel In-Pit Extraction Processes (IPEP) to eliminate tailings ponds and sunlight-powered emissions capture. Even geothermal energy! Key to these breakthroughs is the sharing of expertise, resources, technologies and intellectual property that allows COSIA members to go farther, faster with less cost and less risk. These efforts drive a vast array of incremental improvements to operations, and spur development of transformational technologies. Many of these innovations offer environmental benefits to other industries and countries around the world. The results speak for themselves. • COSIA and Industry innovations have resulted in a 20 per cent reduction in GHG emissions intensity between 2009 and 2018. • Technological and operational efficiency improvements have decreased per-barrel GHG emissions by 28 per cent from 2000 to 2017. • Freshwater use intensity at in situ operations has been reduced by 47 per cent and water use intensity from the Athabasca river at mining operations reduced by 36 per cent since 2012. • To date, COSIA members have invested $1.8 billion to develop 1,143 technologies to improve tailings management and reduce industrial impacts on air, land and water. $531 million is currently dedicated to a total of 233 active projects.

Wes Jickling 300x300
Wes Jickling Chief Executive Canada's Oil Sands Innovation Alliance
  • 9 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 B
  • small-arm9:30 AM - 10:00 AM
wednesday June 08, 2022
Reservoir Engineering

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

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

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
  • 9 30 AM

Hydrogen from Upstream Oil & Gas Facilities

Hydrogen

ALBERTAH2 CORPORATION (AH2) has developed a patent-pending system for generating hydrogen (H2) utilizing produced water as the primary feedstock. The process was designed to enhance and supplement...

Sponsored by: : Innio

  • locationROOM C
  • small-arm9:30 AM - 10:00 AM
wednesday June 08, 2022
Hydrogen

Hydrogen from Upstream Oil & Gas Facilities

  • pr-alarm9:30 AM - 10:00 AM
  • pr-locationROOM C
Sponsored by:
INNIO Group

ALBERTAH2 CORPORATION (AH2) has developed a patent-pending system for generating hydrogen (H2) utilizing produced water as the primary feedstock. The process was designed to enhance and supplement existing oil and gas assets in Western Canada and will be of primary interest to producers interested in reducing their carbon emission intensity (CI). The key component of this modular system is the Produced Water Electrolyzer (PWE), which employs a unique two-step method to avoid the issues associated with oxygen (O2) generation at the anode of other electrolyzers. The intent of the technology is to utilize existing infrastructure and expertise in Western Canada. The PWE employs a simple, bipolar design for H2 generation in the electrolyser cell, followed by a downstream reactor for O2 generation. Resistance to the effects of both sour and hard water components have been addressed by this unique two step design. Appropriately configured, component change-out is readily and efficiently carried out on-line. Target hydrogen costs are expected to fall between those of Blue and (currently) Conventional Green Hydrogen. This technology will act as a “battery” for solar and wind installations and, as such, there has been strong support for this technology from renewable energy developers for both stand-alone and grid-based installations.

John Sutherland 300x300
John Sutherland CEO ALBERTAH2 CORPORATION (AH2)
  • 10 00 AM
Coffee Break & Visit Exhibition
  • 10 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-arm10:30 AM - 11:00 AM
wednesday June 08, 2022
Pipeline & Processing Facilities

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

  • pr-alarm10:30 AM - 11:00 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 Vice-President, Geospatial and Advanced Technology GeoVerra
  • 10 30 AM

Direct Contact Steam Generation - Increased Production with Lower Carbon Intensity

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Direct Contact Steam Generation (DCSG) injects both steam and hot combustion flue gases into the reservoir. Oil production is increased by reducing oil viscosity through heat while repressuring the...

  • locationROOM B
  • small-arm10:30 AM - 11:00 AM
wednesday June 08, 2022
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Direct Contact Steam Generation - Increased Production with Lower Carbon Intensity

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

Direct Contact Steam Generation (DCSG) injects both steam and hot combustion flue gases into the reservoir. Oil production is increased by reducing oil viscosity through heat while repressuring the reservoir with flue gases and improving miscibility with the CO2 that remains in the reservoir. This combination greatly improves the Steam-Oil-Ratio (SOR) for increased oil recovery as well as delivering environmental benefits related to reduced water requirements and lower emissions resulting in a much lower carbon intensity. DCSG water requirements are 13% less than OTSG methods as water is created by the combustion process, this water is then injected into the reservoir rather than lost to the atmosphere. As most of the DCSG process emissions are indirect, emissions can be further reduced by as much as 30% with the use of electric compressors. GERI’s portable DCSG system has successfully completed four heavy oil pilots in post-CHOPS wells in the Lloydminster, Canada area in partnership between GERI, a service and technology company, and major oil operators. Each pilot test included at least one steam and production cycle. For two pilots, a history matched reservoir model was first developed to assess the feasibility and approach for injection and production. A third-party 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/puff test followed by a second injection cycle with noticeable production gains in the offset wells resulting in a combined SOR of less than 0.6 compared to typical industry SOR of 3.0 or more. To date over 18,000 barrels of incremental oil production has been realized from the test well and surrounding offset wells. Furthermore, the field trials were able to quantify the environmental benefits. The pilot results show that DCSG used less water, with 70% of the CO2 retained in the formation. Lower SOR and CO2 retained demonstrates lower carbon intensity relative to current technologies. 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. DCSG offers operators a novel, viable, method to economically extract currently uncoverable reservoirs at a lower carbon intensity than traditional methods. Furthermore, GERI’s portable unit can stimulate standalone or small pools with much lower capital outlay or offers for inexpensive, short term pilots to confirm the opportunity. GERI’s DCSG technology can create anywhere from 0-80% steam quality by adjusting the water rates. Although the four previously completed pilots were focused on steam injection, GERI is currently investigating testing hot water and flue gas injection into a tight reservoir with clay content.

Brian Kay 300x300
Brian Kay Chief Technology Officer General Energy Recover Inc. (GERI)
  • 10 30 AM

Panel: Innovative Solutions for a Sustainable Future

Technical Panel Session

No country can fully realize the transition to a sustainable future on its own. We must collaborate and learn from each other.

Icelandic companies and innovators are active players in the global c...

Sponsored by: : Business Iceland

  • locationROOM C
  • small-arm10:30 AM - 12:00 PM
wednesday June 08, 2022
Technical Panel Session

Panel: Innovative Solutions for a Sustainable Future

  • pr-alarm10:30 AM - 12:00 PM
  • pr-locationROOM C
Sponsored by:
Business Iceland.png

No country can fully realize the transition to a sustainable future on its own. We must collaborate and learn from each other.

Icelandic companies and innovators are active players in the global context when it comes to developing solutions to use in the battle against climate change. Icelanders are experts in many areas, notably in utilizing renewable energy, cascaded use of geothermal, CCUS and more. Our experience has made Icelandic experts sought-after worldwide and put Iceland at the forefront of innovation in the energy and sustainability sectors.

Climate issues have no boarders, and the Icelandic expertise, knowhow and solutions can be applied anywhere. In that context we would like to gather Icelandic players on the stage in Calgary at the Global Energy Show.

Together we are stronger and together we can reach a carbon neutral, fossil fuel free and climate friendly future.

Join us for a panel discussion from our participating companies, Q&A, and networking.

Moderator
Claude Ghazer 300x300
Claude Ghazar Director, Recovery Technologies & Methane Emissions Reduction Alberta Innovates
Rikardur Rikardsson 300x300 (1)
Rikardur Rikardsson EVP, Business Development and Innovation Landsvirkjun/the National Power Company of Iceland
Kristjana Kristjansdottir 300x300
Kristjana Kristjansdottir Chief Commercial Officer Carbon Recycling International
Kristinn Ingi Lárusson 300x300
Kristinn Ingi Lárusson Head of Business Development and Commercialization Carbfix
  • 11 00 AM

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

Pipeline & Processing Facilities

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 A
  • small-arm11:00 AM - 11:30 AM
wednesday June 08, 2022
Pipeline & Processing Facilities

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

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

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 plants and ensure the customer has a profitable “total cost of ownership”. This presentation will review the overall ZR-LNG 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 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
  • 11 00 AM

Aqueous Formate Solution for Geological Carbon Storage and Enhanced Oil Recovery

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Objectives/Scope Carbon dioxide (CO2) has been used as a carbon carrier for geological carbon storage. However, various shortcomings come from its physical properties, such as low carbon density a...

  • locationROOM B
  • small-arm11:00 AM - 11:30 AM
wednesday June 08, 2022
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

Aqueous Formate Solution for Geological Carbon Storage and Enhanced Oil Recovery

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

Objectives/Scope Carbon dioxide (CO2) has been used as a carbon carrier for geological carbon storage. However, various shortcomings come from its physical properties, such as low carbon density at low to moderate pressure, low mass density, low viscosity, immiscibility with water, and corrosivity. This paper presents the first study of using aqueous formate solution as carbon-bearing water for carbon storage and enhanced oil recovery. Existing technologies can generate formate anions (HCOO-) via electrochemical reduction of CO2 from flue gas. Methods, Procedures, Process Properties of formate solutions in brines were measured for the first time, such as solubilities, densities, and viscosities, at different temperatures, brine compositions, and pH values. Coreflooding experiments were performed for displacement of oil by brine with/without formate. Then, numerical reservoir simulations were performed for a 3-D heterogeneous reservoir model for carbon storage and enhanced oil recovery (EOR) by aqueous formate solution and by CO2. Simulation results were used for an economic analysis of the carbon storage/EOR processes. Results, Observations, Conclusions New data indicated that the solution viscosities ranged from 5 to 11 cp at high concentrations of formate; that is, formate anions viscosify the water phase with no other chemicals. Furthermore, formate solutions with/without crushed rock samples were confirmed to be stable at different temperatures up to 90°C for months. Subsequent corefloods conclusively showed the oil displacement front was more stable with an increased formate concentration. A simulation case study showed that the two cases exhibited entirely different flow regimes; the formate injection case resulted in a greater amount of oil recovery and carbon storage, primarily because of more stable fronts of oil and water displacement. Also, aqueous formate solution did not show any potential risk of CO2 leakage to the surface since it did not involve CO2 as a carbon-bearing species and it was slightly denser than the formation brine. An economic analysis based on numerical reservoir simulations gave the equivalent cost of CO2 reduction into formate for the same net present value as the CO2 injection case, and the breakeven cost of the reaction process for the formate injection case. Novel/Additive Information This is the first time aqueous formate solution was demonstrated as both a carbon carrier and a viscosifier to reduce the carbon emission of enhanced oil recovery processes. Formate anions can be a new viscosifier that is more environmentally safe and stable at elevated temperatures than conventional polymers. Unlike CO2 injection, there is no risk of leaking CO2 from the formation to the surface. Aqueous formate solution can be used in combination of miscible or chemical EOR agents as a viscous chase fluid.

Ryosuke Okuno 300x300
Ryosuke Okuno Associate Professor, Hildebrand Department of Petroleum & Geosystems Engineering University of Texas at Austin
  • 11 30 AM

Supporting Pipeline Integrity and Planning through Collaboration and Data Capture

Pipeline & Processing Facilities

Millions of kilometres of pipelines traverse thousands of municipal jurisdictions throughout North America. These pipelines and their related facilities are located in many different contexts, fro...

  • locationROOM A
  • small-arm11:30 AM - 12:00 PM
wednesday June 08, 2022
Pipeline & Processing Facilities

Supporting Pipeline Integrity and Planning through Collaboration and Data Capture

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

Millions of kilometres of pipelines traverse thousands of municipal jurisdictions throughout North America. These pipelines and their related facilities are located in many different contexts, from sparsely populated rural areas to high-density urban centres, but are primarily on lands not owned by the operator. While pipelines are generally underground and therefore “out of site, out of mind” to most, challenges and conflicts can arise as a result of new development in proximity to or crossing these pipelines. Many municipal jurisdictions, landowners, and developers are not fully aware of the obligations related to developing in proximity to pipeline infrastructure ? it can oftentimes be an afterthought. If a plan has already been prepared and approved without adequately considering these matters, last-minute delays, additional costs, and frustrations can occur amongst both the municipal regulator, project proponent, and pipeline operator. Early engagement, awareness, and collaboration are key to mitigating these issues and are mutually beneficial for all stakeholders, including landowners, developers, municipalities, other government agencies, and pipeline operators. B&A has created an innovative land use planning and development monitoring program which has assisted pipeline operators and municipalities with collaborative planning in proximity to pipelines since 2016. Developed in conjunction with some of Canada’s major pipeline operators, this program has been refined and automated to facilitate early awareness of land use planning and development in proximity to pipeline systems and to support collaboration between pipeline operators and development stakeholders. Key program components and processes include: • Jurisdictional and stakeholder inventories; • Stakeholder outreach and communications; • Intake and analysis of land use planning, subdivision, and development application notifications; • Spatial referencing and mapping of notification boundaries in relation to pipeline infrastructure, viewable on an interactive web map; • Analysis and data collection summarizing impacts of notification on/from pipeline infrastructure, which can be tied to spatial boundaries; • Circulation and engagement with operator SMEs to facilitate a technical review; • Distribution of response to a municipal jurisdiction and/or development stakeholder detailing recommendations and requirements specific to their application; • Analysis of data collected over time to identify program effectiveness and trends in development patterns in the proximity of pipeline infrastructure. At the heart of this program are data and information sharing. The program has been developed to share information in an efficient manner while collecting data that can support decision-making in the long term.

Daniel MacGregor 300x300
Daniel MacGregor Associate B&A Planning Group
  • 11 30 AM

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

Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

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 B
  • small-arm11:30 AM - 12:00 PM
wednesday June 08, 2022
Cleaner Hydrocarbon Production & Enhanced Oil Recovery (EOR)

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

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

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
  • 12 00 PM
Lunch Break & Visit Exhibition
  • 1 30 PM

Connected, Lone Worker Safety Solutions for the Petroleum Industry

Pipeline & Processing Facilities

Objectives/Scope: Lone workers go out into new, and often hazardous locations, with little to no support to aid them. Historically, they have run into many dangers and lives have been lost in their...

  • locationROOM A
  • small-arm1:30 PM - 2:00 PM
wednesday June 08, 2022
Pipeline & Processing Facilities

Connected, Lone Worker Safety Solutions for the Petroleum Industry

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

Objectives/Scope: Lone workers go out into new, and often hazardous locations, with little to no support to aid them. Historically, they have run into many dangers and lives have been lost in their attempts to complete tasks that power and move the world around us. This no longer needs to be the case. Through connected technologies, wearable devices, automated hazard sensing, and notifications and workflows, organizations can integrate a wide range of already fielded and new solutions that not only make lone work safer, but ease the job while improving quality, productivity and more. Currently, most of these solutions rely on smart phones and tablet, not purpose-built for the tasks of lone work in the petroleum industry. This means technologies like GPS, WiFi, 4G/cellular, and Bluetooth ? that enable consumer and enterprise connectivity ?" often fall woefully short in lone worker protection applications. In this presentation we will showcase/discuss the emerging technologies changing the game for lone worker safety, including: • Heads-up, hands free remote expert support • Real-time hazard monitoring and alerts • Environmental and biometric monitoring • Location and GIS ?" for real-time insights • Emerging integrations across devices, operational and safety dispatch systems and enterprise compliance and BI systems Methods, Procedures, Process: This will be a conversational presentation between end-users and Guardhat technologist covering the state of lone worker safety, threats/obstacles in the field and at corporate HQ, and demos of cutting-edge connected wearable technologies and a lone worker solution. Followed by a prompted Q&A session on the topic of lone worker solutions in energy. Results, Observations, Conclusions: The International Data Corporation (IDC) reports that in 2020 there were approximately 78.5 million lone or remote workers the United States alone, with a global estimate of approximately 1.3 billion in 2015. This has only been made more complicated by the Covid-19 pandemic. Regardless of what tools are used, investing effective worker safety is never a waste of money. Hundreds of lone and remote workers across North America, and across many industries, employ connected worker tools to protect themselves and their team, finding it a cost- and safety-effective solution to their lone worker-safety challenges. Novel/Additive Information: This presentation provides new and innovative methods for dealing with lone worker safety by utilizing advanced technologies with a people-centric approach. It informs and educates the audience of different and innovative solutions present in the markets today for protecting and enhancing their lone worker personnel.

Doug Matthews 300x300
Doug Matthews Chief Growth Officer Guardhat
Tim Wallace 300x300
Tim Wallace Executive Vice President United Safety
  • 1 30 PM

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

Methane Emissions Reduction

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 B
  • small-arm1:30 PM - 2:00 PM
wednesday June 08, 2022
Methane Emissions Reduction

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

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

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 EPOD-Mini 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 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 EPOD-Mini in 2021. In the final phase of the project, EPOD-Minis were deployed to remote wellsites for testing. The units were closely monitored throughout 2021 to gather learnings and inform product improvements. The Westgen team compiled 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.
  • 1 30 PM

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 C
  • small-arm1:30 PM - 2:00 PM
wednesday June 08, 2022
Field Development & Infrastructure

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

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

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 the SSV or any of its control elements can delay or prevent the shutdown. The reliability of the SSV system has been managed through routine in-person visual inspection, which contributes to higher operational cost and worker safety incidents. In recent years, reduction in operational cost while maintaining (or improving) safety and production efficiency has become an industry requirement. This presentation discusses the recent development of a self-contained electro-hydraulic actuated SSV with an autonomous remote condition monitoring system. Methods, Procedures, Process: The developed system is instrumented with multiple sensors including pressure transmitters, position transmitter, temperature sensor, 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 ESD event to provide an evaluation of the condition of the SSV and its 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: Logged sensor data was used to evaluate the time-based response of the valve position, actuator pressure, signal pressure, and temperature under different applied line pressures. Diagnostic algorithms were developed to evaluate the response time and pressure signatures during valve full and partial stroking to be used towards predicting potential SSV component and system failure. The response time of the solenoid valve (SOV), as a control element, during valve closing exhibited a relatively fast response of around 60 ms. Also, a distinctive signal pressure signature was observed for each tripping method; SOV, mechanical pilot, and manual over-ride (MOV). Valve diagnostic parameters were evaluated including actuator pressure/position hysteresis, break-to-open (BTO) pressure, and break-to-close (BTC) pressure. These results demonstrate the ability to monitor and provide digitalized feedback for real-time condition monitoring towards autonomous predictive maintenance. 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 an electro-hydraulic actuated SSV with instrumentation and control logic to develop an autonomous condition monitored SSV.

Hossam Gharib 300x300
Hossam Gharib Senior Product Engineer Stream-Flo Industries Ltd.
  • 2 00 PM

Operating 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-arm2:00 PM - 2:30 PM
wednesday June 08, 2022
Pipeline & Processing Facilities

Operating By Exception Using Remote Video Analytics and Automation

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

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

Methane Emissions Reduction

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 B
  • small-arm2:00 PM - 2:30 PM
wednesday June 08, 2022
Methane Emissions Reduction

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

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

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).

Keegan Shaw 300x300
Keegan Shaw Lead Data Scientist and Software Developer Highwood Emissions Management
  • 2 00 PM

Retrofitting Existing Pipelines for Fiber Optic Monitoring

Field Development & Infrastructure

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 C
  • small-arm2:00 PM - 2:30 PM
wednesday June 08, 2022
Field Development & Infrastructure

Retrofitting Existing Pipelines for Fiber Optic Monitoring

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

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.

Steve-Koles-300x300
Steven Koles President & CEO Hifi Engineering
  • 2 30 PM
Coffee Break & Visit Exhibition
  • 3 00 PM

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. Solving this problem does not have to be as costly as you may think. In fact, there are prac...

  • locationROOM A
  • small-arm3:00 PM - 3:30 PM
wednesday June 08, 2022
Pipeline & Processing Facilities

A Practical Approach To Achieving Environmental Goals Through Your Electrical Equipment

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

Oil & Gas companies face mounting pressure from all sides to achieve net-zero greenhouse gas emissions. Solving this problem 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 emissions while at the same time offer sizeable returns on investment to the operator. Electric motors are the workhorses in a pipeline and processing facility. 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. Finally, MV drives that are treated with special enclosures eliminate the need for HVAC and thereby eliminate the energy consumption arising from the operation of the HVAC and the corresponding emissions to maintain the built environment around the VFD. In this presentation, we give an overview of the several practical solutions that MV drives can bring to overall sustainability of operations. The risks of not thinking about large VFDs as a strategic piece of equipment to reduce carbon emissions and electric costs in an environment of climate change pressures have become too large to ignore.

Manish Verma
Manish Verma Business Development Specialist TMEIC
  • 3 00 PM

Biomineralization: A Natural Solution to Eliminate Gas Migration

Methane Emissions Reduction

Every year oil and gas wells worldwide leak millions of tons of greenhouse gases into the atmosphere and groundwater. Traditional technologies, such as cements, are ineffective 20-30% of the time d...

  • locationROOM B
  • small-arm3:00 PM - 3:30 PM
wednesday June 08, 2022
Methane Emissions Reduction

Biomineralization: A Natural Solution to Eliminate Gas Migration

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

Every year oil and gas wells worldwide leak millions of tons of greenhouse gases into the atmosphere and groundwater. Traditional technologies, such as cements, are ineffective 20-30% of the time due to their inability to seal tiny fissures and micro annuli that leak gas. A series of carbon sequestration projects undertaken by researchers at Montana State University and funded by the U.S. Department of Energy explored the viability of biomineralization as a solution to this issue. Biomineralization is the process by which living organisms produce minerals. Research for this project focused on common, naturally occurring soil bacteria, which produce crystalline calcium carbonate under certain conditions. These bacteria were chosen for the project for their non-hazardous nature and the strength & bond of the mineral they produce. A low-viscosity mineralizing fluid (1.05 cP) composed of widely available food-grade chemicals is also used in the process. Laboratory research proved encouraging as biomineralization was able to effectively seal fractures in a simulated cement/steel interface with fracture width varying from two microns to four millimeters. This project culminated in several successful field demonstrations on test wells in Alabama and Indiana which proved the technology could seal micro-fractures and eliminate annular gas leakage. At the conclusion of this highly successful collaboration, three engineers involved in the project formed BioSqueeze Inc. which has since commercialized this technology and eliminated annular casing pressure in over 40 wells in six states throughout the U.S. The following example demonstrates the potential of this technology to solve this increasingly important issue. A Pennsylvania gas well scheduled to be plugged and abandoned was leaking methane from both the 13”x 9” and the 9”x 7” cemented annuli. Pressure was 55 psi on the outside annulus and 85 psi on the inside annulus. At a depth of approximately 500 feet multiple circumferential notches were cut through both casing strings all the way to the formation to allow fluid injection into the annuli. After 1.5 days of treatment, the biomineralization fluid injection rate dropped by several orders of magnitude. Subsequent monitoring by a state regulator, determined surface pressure had been reduced to zero and there were no escaping hydrocarbons. The well was then approved for permanent abandonment.

Robert Hyatt 300x300
Robert Hyatt Co-Founder and Vice President of Engineering BioSqueeze Inc.
  • 3 00 PM

Panel: 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 being...

Sponsored by: : IBS Software

  • locationROOM C
  • small-arm3:00 PM - 4:30 PM
wednesday June 08, 2022
Technical Panel Session

Panel: 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?

Remasankar S 300x300
Remasankar S Vice President & Client Advisor IBS Software
Cara Wolf 300x300
Cara Wolf Founder and CEO Ammolite Analytx
Peter Warren 300x300
Peter Warren Vice President, Energy and Utilities Global Industry Lead CGI
Sheldon Wall 300x300
Sheldon Wall Manager, Advanced Analytics Suncor Energy
Viren Parikh 300x300
Viren Parikh Business Development - Energy Ericsson North America
  • 3 30 PM

Optimizing Pipelines with Machine Learning Decision Support (Case Study)

Pipeline & Processing Facilities

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 A
  • small-arm3:30 PM - 4:00 PM
wednesday June 08, 2022
Pipeline & Processing Facilities

Optimizing Pipelines with Machine Learning Decision Support (Case Study)

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

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?

Ramin Vali 300x300
Ramin Vali Business Alliance Director Willowglen Systems Inc.
  • 3 30 PM

Monitoring Methane Emissions Using a Satellite-Aircraft Hybrid System

Methane Emissions Reduction

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 B
  • small-arm3:30 PM - 4:00 PM
wednesday June 08, 2022
Methane Emissions Reduction

Monitoring Methane Emissions Using a Satellite-Aircraft Hybrid System

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

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. 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.
  • 4 00 PM

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 experience difficulties meeting the three successful criteria; delivered on time, with a fi...

  • locationROOM A
  • small-arm4:00 PM - 4:30 PM
wednesday June 08, 2022
Pipeline & Processing Facilities

Integrated Planning and Construction Methodology for Energy Projects

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

Although there is an effort to implement the best project management practices worldwide, energy projects experience difficulties meeting the three successful criteria; delivered on time, with a final actual cost on or below budget, and in full compliance with the technical and regulatory requirements. 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 industry. Two 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 starts by determining the project scope with a 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. Both are credited as work packages are completed using the binary theory. Using this theory, it is possible to implement a simplified approach by crediting value only for the physical work completed, increasing objectivity in determining the project percent complete and forecasting the final cost and completion date during construction. Combining a 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 integrated planning and construction methodology also enables monitoring programs and portfolios more effectively due to the consistency in recording productivity and efficiency indices (CPI and SPIt, respectively), project percent complete, and forecasts of final cost and completion date when closing each measurement reporting period during the construction phase of energy projects. This integrated planning and construction methodology was developed to encourage private companies and government organizations to make changes to the way construction projects are handled nowadays to track margins, improve performance, and increase profits. It also represents an opportunity to reduce waste by adopting the Lean Construction approach and measure performance by implementing the LEED rating system. 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.
  • 4 00 PM

Revealing and Quantifying Methane Emissions Through Innovative Infrared Imaging

Methane Emissions Reduction

The oil and natural gas industry includes a wide range of operations and equipment, from wells to natural gas gathering lines and processing facilities, to storage tanks, and transmission and distr...

  • locationROOM B
  • small-arm4:00 PM - 4:30 PM
wednesday June 08, 2022
Methane Emissions Reduction

Revealing and Quantifying Methane Emissions Through Innovative Infrared Imaging

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

The oil and natural gas industry includes a wide range of operations and equipment, from wells to natural gas gathering lines and processing facilities, to storage tanks, and transmission and distribution pipelines. The industry is a significant source of emissions of methane, a potent greenhouse gas. In order to reduce methane emissions, operators must regularly monitor their entire network to detect methane leaks. A reliable gas identification and quantification imaging system represents an upgrade to the current gas detection technologies. Infrared hyperspectral imaging can visualize fugitive emissions and gas leaks under various environmental conditions and industrial contexts. Aerial gas detection and quantification is an efficient way to survey large assets for possible leaks. This work will present the methane emission detection and quantification capabilities of Telops’ Hyper-Cam Airborne mini an airborne hyperspectral imaging system. The system weights less than 24 kg which makes it perfectly suitable for ultralight aircraft and drones, thus allowing to cover large areas in less time compared to helicopter mounted solutions, hence lowering operational cost. The flexibility of the system allows to tailor and optimize parameters based on the application of interest, either the the methane distribution or production sectors. In flight the system dynamically adapts to ever changing flight conditions. Data acquisition is fully automated requiring minimal to no operator intervention. Detection and quantification reporting is done in real-time which allows rapid and critical decision making. The data presented comes from controlled releases of methane at flow rates between 1,8 to 1,082 kg per hour conducted over various sites over the last 3 years. At the detection limit determined from the results, the system is able to detect 90% of the emissions found by Omara et al. in 2018 and ~100% of the ones found by Cusworth et al. in 2021. Using measured wind data, it is possible to calculate leak rate values and compare them to commanded leak rate values. Results show excellent correlation with a fitted slope of 0.99 (1 would be perfect correlation) and a R2 value of 0.89. In addition, the collected data spans a wide range of atmospheric conditions and flight parameters. This paper will also include a discussion on how methane detection and leak rate quantification accuracy depends on the atmospheric conditions.

Jean Phillipe Gagnon 300x300
Jean-Philippe Gagnon Field Application Scientist Telops
  • 5 00 PM
Day Two of Technical Conference Concludes for the Day
  • 7 30 AM
Registration Opens
  • 8 30 AM

Clean Energy from Natural Gas, Without Combustion

Clean Technology & Environmental Management

Every year, gigawatts of power are wasted in natural gas pipelines around the world. The energy is wasted through pressure-regulating valves that drop natural gas pressure from transmission to end-...

Sponsored by: : SAIT

  • locationROOM A
  • small-arm8:30 AM - 9:00 AM
thursday June 09, 2022
Clean Technology & Environmental Management

Clean Energy from Natural Gas, Without Combustion

  • pr-alarm8:30 AM - 9:00 AM
  • pr-locationROOM A
Sponsored by:
SAIT_150x150.png

Every year, gigawatts of power are wasted in natural gas pipelines around the world. The energy is wasted through pressure-regulating valves that drop natural gas pressure from transmission to end-use levels. By installing a turboexpander-generator in-parallel with the regulating valve, natural gas pipelines can generate power from the pressure and flow of natural gas through the pipe, without combustion. While turboexpanders have been around for almost a century, the technology has not gained traction in the natural gas transmission/distribution market, despite the enormous opportunity. Several attempts to develop this market failed due to poor technical performance and insufficient ROI. Turboexpander manufacturers failed because of their attempt to re-engineer and adapt cryogenic and/or air-separation turboexpanders for natural gas pipelines ? two markets with distinct natural gas conditions. Anax Power uses recent technology advancements to design a turboexpander specifically for the natural gas transmission market, and the result is a technically viable and commercially attractive option for pipeline operators, natural gas power plants, utilities, and large industrial users of natural gas and power. Since there is no combustion, gas transmission companies, producers, utilities, and large industrial sites can improve their return on existing infrastructure, reduce their carbon emissions, and create value through the sale of power. This system also enables these companies to offset their existing power consumption with cleaner and more cost-effective power. Generating power on pipeline assets creates innovative business models that align with global decarbonization trends. For example, the turboexpander can be combined with a hydrogen electrolyzer to produce hydrogen for downstream blending into the pipeline. This geographic advantage eliminates the storage and transportation costs associated with hydrogen. Furthermore, the turboexpander system uses waste heat from the electrolyzer to maintain the appropriate temperature in the gas after the pressure cut. This process can eliminate gas burned in pipeline heaters and creates a super efficient turboexpander-electrolyzer system. Turboexpanders provide a carbon-free source of power that, on average, removes 0.71 metric tons of CO2 per MWh of generation (based on Alberta’s grid). To give you an idea of the power potential, one refinery in Alberta can generate 5MW+ (ten 500kW Anax Turboexpanders) of power and avoid 25,000 tons of CO2, according to the US EPA carbon equivalency calculator. Globally, there are thousands of pressure regulating sites that can benefit from this technology.

Michael Longo 300x300
Michael Longo Head of Business Development Anax Power
  • 8 30 AM

Hydrogen Blending to Reduce GHG Emissions Reductions

Hydrogen

As the pressure to act on climate change builds, natural gas utilities are looking to hydrogen to support environmental initiatives. Gas utilities are now talking about decarbonizing their systems...

Sponsored by: : Innio

  • locationROOM B
  • small-arm8:30 AM - 9:00 AM
thursday June 09, 2022
Hydrogen

Hydrogen Blending to Reduce GHG Emissions Reductions

  • pr-alarm8:30 AM - 9:00 AM
  • pr-locationROOM B
Sponsored by:
INNIO Group

As the pressure to act on climate change builds, natural gas utilities are looking to hydrogen to support environmental initiatives. Gas utilities are now talking about decarbonizing their systems by blending in hydrogen or biogas — or even supplying pure hydrogen to industrial users. With hydrogen blending, utilities continue to leverage valuable energy and infrastructure assets, including fossil fuel reserves and natural gas pipelines while playing a key role in the clean energy transition. Blending provides the largest potential demand opportunity for hydrogen. Increasing the demand for hydrogen would lead to an increased hydrogen supply that could significantly decrease the cost associated with hydrogen supply technologies. In this session, Stewart will share his views on the future of hydrogen blending in the natural gas utility space, how utilities can get started implementing hydrogen into their systems and provide perspective on the size of the hydrogen opportunity.

Stewart Stewart 300x300
Stewart Stewart Chief Commercial Officer BayoTech
  • 8 30 AM

Panel: 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 in...

Sponsored by: : Cisco

  • locationROOM C
  • small-arm8:30 AM - 10:00 AM
thursday June 09, 2022
Technical Panel Session

Panel: Going Autonomous: The Future of Human Free Operations

  • pr-alarm8:30 AM - 10:00 AM
  • pr-locationROOM C
Sponsored by:
cisco_300x300.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?

Moderator
Roland Plett 300x300
Roland Plett Business Development Manager, Energy and Mining Cisco Systems
Indy Kar 300x300
Indy Kar Vice President of Strategic Growth FTP Solutions
Steve Barker 300x300
Steve Barker Manager, Digital Foundations Spartan Controls
Mark van Engelen 300x300
Mark van Engelen Vice President Emerging Technology Western Canada CGI
  • 9 00 AM

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

Clean Technology & 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...

Sponsored by: : SAIT

  • locationROOM A
  • small-arm9:00 AM - 9:30 AM
thursday June 09, 2022
Clean Technology & Environmental Management

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

  • pr-alarm9:00 AM - 9:30 AM
  • pr-locationROOM A
Sponsored by:
SAIT_150x150.png

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)
  • 9 00 AM

Global Perspective for Canada In a Developing Hydrogen Economy to 2030

Hydrogen

Global Perspective for Canada In a Developing Hydrogen Economy to 2030 Geoff Martin, BSc, MIM Dr. Davood Khairkhah, Ph.D., P.Eng. Concerns about climate change mitigation and the various elements...

Sponsored by: : Innio

  • locationROOM B
  • small-arm9:00 AM - 9:30 AM
thursday June 09, 2022
Hydrogen

Global Perspective for Canada In a Developing Hydrogen Economy to 2030

  • pr-alarm9:00 AM - 9:30 AM
  • pr-locationROOM B
Sponsored by:
INNIO Group

Global Perspective for Canada In a Developing Hydrogen Economy to 2030 Geoff Martin, BSc, MIM Dr. Davood Khairkhah, Ph.D., P.Eng. Concerns about climate change mitigation and the various elements of the energy transition present both opportunities and challenges across the entire energy sector. This will be an important decade. Net zero plans and the growth of renewables all exist within global regional and geopolitical competitive considerations and tie to the renewed interest in hydrogen. Canada, as an energy producer, can take nothing for granted on what opportunities may be available. Can we compete, and where are the opportunities with hydrogen. Our paper will paint a picture of what is happening with hydrogen developments and plans for the regions of Asia Pacific, Europe and North and South America. The most important words in the energy transition: Collaboration, Innovation, Acceleration. Collaborate as no one company can handle all of the technological advances and developments themselves. Innovate as this is the way forward, building on advances in various technologies. Accelerate development of technologies and projects as this is now a part of the global competitive arena. The pandemic provided good examples of companies advancing technologies in just months, years ahead of their pre-pandemic schedules. We will explore how these three words fit in the Canadian paradigm? Hydrogen market potential is related to increasing its scale of production to reduce its cost/kilogram. Current targets by several countries suggest green hydrogen (via electrolysis) at $1 USD/kg by or before 2030. Over 90% of the 70 M tonnes annual global H2 production is produced through SMR (Steam Methane Reforming) at a cost as low as $0.80/kg. However, 8-10 tonnes of emissions/tonne H2 are associated with SMR. Renewables are expected to play a significant part in electricity generation that can be used for green hydrogen generation, especially offshore wind. Offshore wind can be a major source of renewable power for hydrogen generation at the turbine site with hydrogen transported from there by pipeline or offshore vessel. Alberta is focused on blue hydrogen (from natural gas with sequestration of up to 90% of associated emissions). Lowering the cost of hydrogen is one component. How to build the infrastructure to generate and transport it to end users is another consideration. Producing and exporting liquid hydrogen (H2) is expensive at this time. Transportation as ammonia (NH3) is another option. Shipments in both forms have already happened globally. Ammonia tankers deliver about 16 million tonnes globally; a fraction of the 180 million tonnes annual production. We will examine pricing and the hydrogen/ammonia situation Moving forward will have its hiccups. It will require policies and regulations, by governments, for and with industries, in the mix of molecules and electrons. Every region is different and there is no “one size fits all” schema.

Davood Khairkhah 300x300
Davood Khairkhah Senior Advisor, Upstream DavFaye
Geoff Martin 300x300
Geoff Martin International Energy Research Consultant DavFaye/University of Southern California
  • 9 30 AM

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

Clean Technology & 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 s...

Sponsored by: : SAIT

  • locationROOM A
  • small-arm9:30 AM - 10:00 AM
thursday June 09, 2022
Clean Technology & Environmental Management

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

  • pr-alarm9:30 AM - 10:00 AM
  • pr-locationROOM A
Sponsored by:
SAIT_150x150.png

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 vapours 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. Nelson will discuss the performance factors that the consultant must be considered in order to successfully use Low Temperature Thermal Desorption.. These factors include proper up logistical planning, site requirement issues equipment operating factors, logistical planning, soil’s physical properties of the soil, contaminant characteristics and concentration, volume of contaminated soil, by-products of the treatment process, and fuel sources, all factors that can affect the effectiveness of the treatment process. Operational issues; like frost and frozen ground conditions, plant operations, treated stockpile confirmation sampling and reinstatement/backfilling will be discussed to help understand the real issues that occur after the selection of the technology

John Tucker 300x300
John Tucker Chief Technical Officer Nelson Environmental Remediation Ltd.
  • 9 30 AM

Operating Canada’s First Hydrogen Fueling Station Network

Hydrogen

Scope: HTEC has been developing and operating a network of stations since June 2018 in the Metro Vancouver region, in partnership with vehicle manufacturers, retail stations owners, provincial and...

Sponsored by: : Innio

  • locationROOM B
  • small-arm9:30 AM - 10:00 AM
thursday June 09, 2022
Hydrogen

Operating Canada’s First Hydrogen Fueling Station Network

  • pr-alarm9:30 AM - 10:00 AM
  • pr-locationROOM B
Sponsored by:
INNIO Group

Scope: HTEC has been developing and operating a network of stations since June 2018 in the Metro Vancouver region, in partnership with vehicle manufacturers, retail stations owners, provincial and federal government agencies. During this time, HTEC has learned much about the integration of equipment and dispensers into existing stations, fuel supply and delivery approaches, and station operation. HTEC proposes to provide a snapshot of the current network, delivery approaches and the associated advantages and disadvantages. Challenges in the field will also be presented. Methods, procedures, process: HTEC will provide insights into what it takes to be operating Canada’s First Hydrogen Fueling Station Network. The presentation will demonstrate how HTEC works with its partners and suppliers to provide fueling solutions that take into considerations consumer experience, site constraints and fuel delivery options. HTEC monitors key performance indicators that are used to adjust operating procedures and guide equipment selection. The company also had to learn to operate in particularly hot, cold and wet operating environments throughout 2021, allowing for further understanding and adaptation. For fuel supply and distribution, HTEC evaluated and experimented with different approaches each of which hold advantages and disadvantages. These learnings and consequent solutions will be discussed in HTEC’s presentation. Finally, operating and growing this network comes with several challenges such as extreme weather, predicting growing customer usage, educating customers about new fueling nozzles and different interfaces, to name a few. The presentation will delve on the various solutions adopted by HTEC ranging from installation to maintenance to storage resolutions to reviewing interfaces. Results, observations, conclusions ?" While building hydrogen capacity and growing the fueling station network is not devoid of challenges, HTEC has carefully assessed and formulated various solutions to address these. HTEC’s presentation will provide insights into how we are effectively supporting a sustainable transportation future. Novel/additive information: The presentation will showcase how HTEC is the ‘glue’ of the clean hydrogen value chain, integrating technologies, systems, people, and partnerships, for hydrogen’s role in our zero-emission future. Using on-ground experience and learnings, HTEC will discuss novel approaches and solutions that can help the industry collectively grow and compete on a global scale.

Patric Ouellette 300x300
Patric Ouellette Vice President, Infrastructure HTEC
  • 10 00 AM
Coffee Break & Visit Exhibition
  • 10 30 AM

Changing the EHS Compliance Ecosystem from the Inside Out

Clean Technology & Environmental Management

The development of new technologies is changing how industries and their processes are operating. This is also true for the Environmental, Health, and Safety (EHS) field, where many innovations are...

Sponsored by: : SAIT

  • locationROOM A
  • small-arm10:30 AM - 11:00 AM
thursday June 09, 2022
Clean Technology & Environmental Management

Changing the EHS Compliance Ecosystem from the Inside Out

  • pr-alarm10:30 AM - 11:00 AM
  • pr-locationROOM A
Sponsored by:
SAIT_150x150.png

The development of new technologies is changing how industries and their processes are operating. This is also true for the Environmental, Health, and Safety (EHS) field, where many innovations are revolutionizing how professionals address traditional complex processes. Early processes include the development of Geographic Information Systems to analyze large environments for planning and assessment purposes from the 1980s and 1990s, with more advanced and detailed uses with the addition of remotely piloted aircraft or drones. Over the last decade, there has been an explosion of new technologies affecting and improving how EHS professionals are managing the process for the industry. A quick review of successful technologies includes a) smart glasses, head seats, and augmented reality to improve remote audits, training, and testing of new facilities; b) data analytics improved by artificial intelligence (AI) to identify environmental and safety trends; c) robotics to assist and improve ergonomics of workers; e) digitalization and mobile applications that facilitate field data collection and democratization of the EHS process among workers. This session will analyze the current and potential use of one specific aspect of AI’s Natural Language Processing and Machine Learning (ML) to assist EHS professionals in reading, analyzing, and extracting relevant information from large regulatory, management systems and documents. Natural Language Processing (NLP) is a discipline within AI and ML that allows machines to read human languages, understand their meanings, and turn them into action. By separating words into fragments, computers can process large amounts of information. This technology is currently applied to analyze regulatory documents, such as laws, regulations, permits, licenses, and others, to extract relevant information for the operation to fulfill regulatory requirements. Furthermore, the same process can be applied to standards, plans, and procedures, facilitating how workers and EHS professionals can easily access and digest information to optimize conformance with management systems. This process reduces the time and cost and increases the accuracy of these administrative processes, helping set up EHS software and develop compliance self-assessment checklists, audit protocols, and compliance calendars. Other technologies close to NLP, Sentiment Analysis, is also used to read, analyze, and categorize EHS related public information, such as sustainability reports, media, social media to help corporate reporting on aspects associated with corporate responsibility and ESG. During this session, we’ll dive into the new opportunities that continue to emerge to facilitate the use of NLP to convert complex legal, regulatory compliance into simpler tasks, identify relevant changes in new regulatory requirements, analyze reports to confirm compliance, and facilitate ESG reporting.

Marcel Guevara 300x300
Marcel Guevara Vice President, EHS ehsAI
  • 10 30 AM

Optimizing Canadian Oil Sands for a More Volatile and Decarbonized Future

Field Development & Infrastructure

The objective of this presentation is to explain how Canada’s oil sands players have prepared for longer-term price and demand uncertainty through field optimization activities and project reconcep...

  • locationROOM B
  • small-arm10:30 AM - 11:00 AM
thursday June 09, 2022
Field Development & Infrastructure

Optimizing Canadian Oil Sands for a More Volatile and Decarbonized Future

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

The objective of this presentation is to explain how Canada’s oil sands players have prepared for longer-term price and demand uncertainty through field optimization activities and project reconceptualization, and the resulting downwards trajectory of oil sands breakeven prices over the past few years. It will also touch on oil sands companies’ long-term plans for decarbonization through deployment of carbon capture utilization and storage (CCUS) and other technologies. The analysis will utilize Rystad Energy’s proprietary databases, which provide global oil and gas supply and emissions forecasts through asset-level production and economic modeling. The analysis of optimized field development will use bottom-up, asset-by-asset modeling data from Rystad’s UCube to assess the various project reconfigurations that have been floated since the mid-2010s to improve capital efficiencies and support future growth at a competitive cost of supply. Meanwhile, potential oil sands emissions projections will utilize Rystad’s EmissionsCube, which relies on similarly granular field-by-field modeling of upstream CO2 emissions. Oil sands players initially began shifting away from large-scale greenfield designs towards less capital-intensive brownfield expansions following the first oil price crash in the mid-2010s. This trend has only accelerated in recent years and is now the main development approach for both mining and thermal projects. The rise of brownfield expansions means that approximately 2.7 billion barrels of sanctionable mid-term oil sands resources would be competitive at a go-forward WTI-equivalent breakeven price of less than US$35 per barrel. Project reconfigurations have thus helped oil sands players meet the economic challenges historically associated with the sector and will support steady?albeit less aggressive?"long-term output growth. On the CO2 front, however, Canadian oil sands remain the most emissions-intensive part of the upstream sector globally. Recent industry initiatives to achieve net zero emissions against 2018 levels will likely lead to significant long-term emissions reductions assuming successful deployment of CCUS and other technologies, such as in-field solvent co-injection. Based on the most recent GHG intensity figures, however, achieving complete net zero emissions in the oil sands remains highly uncertain under Rystad’s base case production scenario. The asset-level granularity that underlies the analysis in this presentation will be a valuable addition to the state of knowledge in the energy industry. 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. Additionally, the use of our EmissionsCube data will provide key insights into potential oil sands emissions associated with our base case production forecast, as well as offer a timely comparison against industry aspirations towards net zero.

Mark Quesada 300x300
Mark Quesada Senior Analyst Rystad Energy
  • 10 30 AM

Stimulation of Extended Reach Wells without the Need of Intervention: a Case Study of the Montney Formation, Canada

Drilling & Completion

OBJECTIVES / SCOPE The scope of the paper is design and results of a field trial of a new fracturing system in the Montney formation, Canada. The system allows improved project economics and lower...

  • locationROOM C
  • small-arm10:30 AM - 11:00 AM
thursday June 09, 2022
Drilling & Completion

Stimulation of Extended Reach Wells without the Need of Intervention: a Case Study of the Montney Formation, Canada

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

OBJECTIVES / SCOPE The scope of the paper is design and results of a field trial of a new fracturing system in the Montney formation, Canada. The system allows improved project economics and lower environmental impact, in particular by reducing water use and the amount of green house gas emissions. This helps ARC Resources to build a culture that fosters responsible resource development and delivers strong financial and operational results. METHODS, PROCEDURES, PROCESS The new intelligent fracturing system features a compact, programmable dart made of magnesium alloy. The dart is programmed and launched at surface to land in a specific sleeve. The sleeves contain hardened nozzles ensuring no erosion through the frac port. 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. The system was used in a 9500 ft lateral length well. Contactless Sleeve Recognition technology enabled opening of 74 sleeves. Total of 20 stages were successfully treated leaving behind 95% drift. A single dart allowed opening of 4 entry points per stage (3 cluster sleeves and 1 landing sleeve). Acoustic monitoring was used to verify opening of all sleeves. RESULTS, OBSERVATIONS, CONCLUSIONS The field trial of the new fracturing system was successful. Darts landed at the specified locations and sleeves opened. No undesired sleeve activation was detected. The field data show that the new fracturing technology allows stimulation of horizontal wells without the need for intervention. The system is of a specific value for extended reach wells and casing deformation risked areas. The system can maintain maximum wellbore insider diameter before and after completion, eliminates issues of mechanical indexing, ensures continuous pumping without rate limitations, does not require milling out and allows to avoid casing erosion. Additional field data are to be collected to optimize the process and drive continuous improvement of the technology and hydraulic fracturing operations of ARC Resources by prioritizing environmental and social responsibility efforts. NOVEL / ADDITIVE INFORMATION The new fracturing system allows reduced risks and costs. The system enables operators to successfully complete extended reach wells without need of intervention, overcome issues of casing deformation, improve operational efficiency and reduce environmental impact.

M.Larsen, ARC Resources; J. Najafov, T. Watkins, Advanced Upstream

Alex Baranov 300x300
Alex Baranov Business Development Manager Advanced Upstream
  • 11 00 AM

Water and Environmental Management

Clean Technology & Environmental Management

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 lea...

Sponsored by: : SAIT

  • small-arm11:00 AM - 11:30 AM
thursday June 09, 2022
Clean Technology & Environmental Management

Water and Environmental Management

  • pr-alarm11:00 AM - 11:30 AM
Sponsored by:
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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: Briefly explain your overall approach, including your methods, procedures, and 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. Draft for discussion 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.
Carol Crowe 300x300
Carol Crowe Founder & President Indigenous Visions Inc.
  • 11 00 AM

A Novel Approach to Utilizing Fit for Purpose Turnkey HIPPS

Field Development & Infrastructure

Field development teams are facing increased technical and financial pressures in the current energy landscape. While the challenge to reduce CAPEX has always been at the forefront, emissions reduc...

  • locationROOM B
  • small-arm11:00 AM - 11:30 AM
thursday June 09, 2022
Field Development & Infrastructure

A Novel Approach to Utilizing Fit for Purpose Turnkey HIPPS

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

Field development teams are facing increased technical and financial pressures in the current energy landscape. While the challenge to reduce CAPEX has always been at the forefront, emissions reduction and OPEX are becoming increasingly more important. Coupled with tightening regulatory requirements and ESG targets, infrastructure developers need repeatable, reliable, fit-for-purpose, performance-based solutions to develop their assets economically. Over pressure protection and management is a heavily regulated aspect of facility design. Conventional solutions such as pressure relief valves, rupture disks, flare systems and incinerators are typically applied to address these requirements. Due to changing regulations, increased importance of lifecycle costs, emissions penalties and GHG reduction targets, alternative approaches are needed. An improved approach to over pressure protection and management is the use of High Integrity Pressure Protection Systems (HIPPS). HIPPS is a safety instrumented system, designed in a manner to avoid over pressure incidents by removing the source of over pressure or by reducing the probability of an over pressure contingency to such a low level that it is no longer considered to be a credible case. Canadian regulators are now permitting performance-based HIPPS designs based on evaluations of end user’s specific applications instead of enforcing a one-solution-fits-all approach. These changes are enabling industry to benefit from the deployment of HIPPS designs. Implementing repeatable turnkey fit-for-purpose HIPPS solutions enables the end user to benefit from reduced or eliminated relief cases and can positively impact field development. Case-dependent benefits can include: • Reduced relief manifold/header sizes, • Eliminated flare/vent systems, • Reduced emissions from flare/vent systems during purge/sweep and relief events, • Reduced overall facility CAPEX and OPEX, • Reduced facility footprint based on the impact to the flare/vent system, • Improved flexibility for future expansion as equipment sizing can be decoupled from increased new trains of equipment, and • Improved residual risk of the overpressure protection systems. HIPPS has been deployed across multiple sectors in the past. However, because of changing regulations and shifting pressures in the industry, reliable turnkey HIPPS solutions using new design approaches are becoming a leading option for field development teams to solve the challenges faced in the energy sector. The collaboration between Solaris and Ensol has successfully implemented fit-for-purpose HIPPS in the upstream, midstream, and downstream Canadian market. In this presentation we will be sharing our lessons learned and potential opportunities for others to benefit from deploying this technology.

Reza Rasooli 300x300
Reza Rasooli Senior Instrumental & Controls Engineer Ensol Systems, Inc.
  • 11 00 AM

Leveraging Cameras, AI, and Machine Learning to Improve Hazardous Drilling Operations

Drilling & Completion

Objectives: • Present a case study on real-time insight into hole behavior using optical sensors, Artificial Intelligence, and Deep learning to shorten drill times and confirm bore integrity. • H...

  • locationROOM C
  • small-arm11:00 AM - 11:30 AM
thursday June 09, 2022
Drilling & Completion

Leveraging Cameras, AI, and Machine Learning to Improve Hazardous Drilling Operations

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

Objectives: • Present a case study on real-time insight into hole behavior using optical sensors, Artificial Intelligence, and Deep learning to shorten drill times and confirm bore integrity. • Highlight current trends and applications in securing oil and gas upstream drilling operations. • Discuss current remote monitoring techniques for drilling operations • Discuss sensor evolution and the adaptations of on the edge Artificial Intelligence and Deep Learning Scope: This discussion will focus on: • The evolution of IP security cameras and the emerging capabilities expected in the next five years. • A breakdown of advanced analytics in process security and safety. Introduction of turnkey solutions geared towards the oil and gas industry in the energy sector. • Presentation of case study using optical sensors and analytics in a Class 1 Div. 1 area to evaluate mud particles in the primary and secondary shakers. Methods and Procedures and process IP surveillance cameras have become more than a device that provides a video image for security. Modern IP cameras feature highly developed optical lens systems that can extract and process information from images using analytics, Artificial Intelligence, and Deep Learning. New compression technology cuts bandwidth requirements to make remote monitoring less costly. Results Observations and Conclusions Utilizing the processing ability of both visible cameras and thermal cameras, you are now able to achieve double and triple duties from one device. Advance analytics can now detect if a plume is present and what molecule makeup the plume is. Radiometric thermal cameras measure surface temperature to monitor critical rotating equipment or leaking pipes using color pallets. Remote communications utilizing VoIP tightens your remote landscape from a monitoring and communication standpoint. Access control to all areas offer a layered approach for personnel monitoring at entry/exit points and critical sub perimeter areas. Power processing allows for on the edge applications of sensors utilizing Artificial Intelligence and Deep Learning to combine data such as drilling aspect to actual analyzing material “mud” to confirm critical aspects to confirm bore integrity and shorten drill times. Novel/Additive Information: This presentation will explain how new technology is being developed in the form of advanced sensors and applications to address the criticality associated in the energy sector with process monitoring and operational efficiencies. A case study outlining advanced technology to monitor mud particles shape, size, and spacing as it relates to bore integrity during drill operations will be presented.

Calvin Holt 300x300
Calvin Holt Co-Founder and CEO DrillDocs
Francois Ruel 300x300
Francois Ruel Co-Founder and CTO DrillDocs
  • 11 30 AM

Natural Gas Assisted Heavy Oil Upgrading

Clean Technology & Environmental Management

Due to a decline in light crude oil supply, crude oils with inferior quality, including heavy oil, super heavy oil and oil sands have gradually become predominant in refineries. Besides, the produc...

Sponsored by: : SAIT

  • locationROOM A
  • small-arm11:30 AM - 12:00 PM
thursday June 09, 2022
Clean Technology & Environmental Management

Natural Gas Assisted Heavy Oil Upgrading

  • pr-alarm11:30 AM - 12:00 PM
  • pr-locationROOM A
Sponsored by:
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Due to a decline in light crude oil supply, crude oils with inferior quality, including heavy oil, super heavy oil and oil sands have gradually become predominant in refineries. Besides, the production of natural gas has substantially grown over the past decades, resulting in its depreciated market value compared with crude oil. If methane, the main component of natural gas, can be creatively used as a source of hydrogen and carbon for the upgrading of heavy oil, the resulting process will significantly be more environmentally conscious and economically competitive. Here, several examples of methane-assisted heavy oil upgrading will be presented, including but not limited to, asphaltene conversion, vacuum residue upgrading and desulfurization. The catalysts are specifically designed and optimized for each application. The reactions are carried out in both a batch mode and a continuous fixed bed mode at mild conditions (400-430 oC, 3-5 MPa). The natural crude feedstocks are directly introduced into the reactor without pretreatment. After the reaction, the gas, liquid and solid products were separated, collected and comprehensively analyzed. It is observed that the quality of crude oils, such as density, viscosity, total acid number, asphaltene content, olefin content, water content, ash content, carbon residue, average molecular weight, the content of light fractions, as well as contents of heteroatoms and metal impurities, can be dramatically improved after the methane-assisted catalytic upgrading process. The important role played by methane is repeatedly confirmed by control experiments, product analyses, catalyst characterizations and theoretical calculations. The reaction mechanisms are also proposed and methane is confirmed to participate in the reaction through various pathways including hydrogen transfer, co-aromatization and methylation, tuning the elemental composition and structure of oil molecules and generating new products. As a result, the presence of methane exhibits positive influences on heavy oil upgrading, in terms of promoting the conversion of big molecules, inhibiting over-cracking, triggering deoxygenation and desulfurization reactions and incorporating into final products. Besides, compared to nitrogen, methane exhibits a protective effect on the charged catalyst, leading to better catalyst stability. This protective effect is attributed to the interaction between methane and catalytic active sites, which mainly occurs in the internal pores of the zeolitic catalyst support, resulting in unique coke distribution and inhibition of metal deposition. Long-term operation results further demonstrate the feasibility, long-term stability and versatility of the process and successful scaling up to pilot plants is also achieved. With continuous efforts spent in this field, methane-assisted catalytic heavy oil upgrading demonstrates a promising potential for the energy industry.

Hao Xu 300x300
Hao Xu Postdoctoral Associate University of Calgary
  • 11 30 AM

SaaS Based AI Enabled Engineering Digitalization Platform for Field and Performance Optimization of Digital Oil & Gas and Energy Sectors

Field Development & Infrastructure

Onshore oil fields fall under two categories - Brownfield and Greenfield. Greenfield means a new oil and gas field development. Brownfield on the other hand, is an oil or gas accumulation that ha...

  • locationROOM B
  • small-arm11:30 AM - 12:00 PM
thursday June 09, 2022
Field Development & Infrastructure

SaaS Based AI Enabled Engineering Digitalization Platform for Field and Performance Optimization of Digital Oil & Gas and Energy Sectors

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

Onshore oil fields fall under two categories - Brownfield and Greenfield. Greenfield means a new oil and gas field development. Brownfield on the other hand, is an oil or gas accumulation that has matured to a production plateau or even progressed to a stage of declining production. Operating companies seek to extend the economic producing life of the field using cost-effective, low-risk technologies. While with Greenfield you have a clean slate to set up field operations, when it comes to brownfield, EPCs & asset owners often end up spending a lot of manpower to study and understand the existing systems. The study further supports baselining the brownfield facility digitally through combined field verification and digitization programs. Non-availability of digital engineering drawings and diagrams makes future expansions challenging. Moreover, older facilities are left saddled with higher costs of maintenance and increased costs to de-bottleneck or upgrade facilities. An engineer has to manually go through reams of paper & PDF engineering and P&IDs to identify the various equipment and their redundancy, design pressure/temperature etc. There are 1000s of engineering drawings in such projects. To manually review these drawings, engineers spend 10s if not 100s of engineering hours. It’s tedious, error-prone & costly. Current digital baselining of historian engineering drawings, can cost up to $7,500 to $15,000 per drawing. Large scale industrial facilities can range from 200 - 600 P&IDs for digital baselining for brownfield expansions making the existing solutions expensive. Drishya helps Oil & Gas producers, EPCs and companies in the energy sector achieve improved efficiency & productivity while reducing cost, emissions & manpower requirements through our Engineering Digitalisation solution - Artisan We train AI to read drawings. As AI builds digital twins, it learns relationships between components. This digital twin technology powers Artisan. Tasks like fugitive emissions studies which take 50 to 60 hours are done in mins, leading to 80 to 90% savings in time & money. It acts as a single source of truth, automatically visualizes a digitised version of the plant going forward and reduces wasteful activities in, sustaining CAPEX Projects, Change Tracking, Inventory Updates, Maintenance Planning, Operations Debottlenecking, etc. Artisan addresses the following challenges that are of interest to the Oil & Gas plant owners CAPITAL PROJECT EXECUTION AND OPERATIONAL EXCELLENCE & EFFICIENCY Reduces project cycle time and cost Improves productivity by providing digital access across the organization to processes, workflows, and records Detecting early risks, reducing shutdowns and construction rework Eliminates siloed data and systems, improves data accuracy and leads to gains in back-office productivity ENVIRONMENTAL MONITORING Reduces costs of field work, evaluation, assessments for fugitive emission studies HEALTH AND SAFETY Reduces travel by employees to remote and harsh operating environments Prevents health and safety incidents and protect employees during work.

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

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

Drilling & Completion

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...

  • locationROOM C
  • small-arm11:30 AM - 12:00 PM
thursday June 09, 2022
Drilling & Completion

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

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

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. The system described incorporates the automated generation of a digital three-dimensional visualization 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. 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, including identifying drilling dysfunctions. The resulting data can then be used to modify bit designs and/or operational parameters to optimize drilling performance.

Ron Schmitz 300x300
Ronald Schmitz Executive Advisor Trax Electronics Inc.
  • 12 00 PM
Lunch Break & Visit Exhibition
  • 1 30 PM

Geothermal Energy: The Full Value Chain in a Decarbonizing World

Renewables

SCOPE Our energy industry faces the triple goal of decreasing greenhouse gas emissions while increasing capacity and ensuring reliability. To meet growing energy demands, the decarbonization of en...

  • locationROOM A
  • small-arm1:30 PM - 2:00 PM
thursday June 09, 2022
Renewables

Geothermal Energy: The Full Value Chain in a Decarbonizing World

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

SCOPE Our energy industry faces the triple goal of decreasing greenhouse gas emissions while increasing capacity and ensuring reliability. To meet growing energy demands, the decarbonization of energy generation and deployment of intermittent renewables must be supported by clean, baseload energy solutions. In the Western Canada Sedimentary Basin (WCSB), one solution is an underground renewable resource: geothermal energy. The WCSB has low-moderate temperature (enthalpy) geothermal resources that can produce power through Organic Rankine Cycle technology and can also be used for direct-use applications. Geothermal energy has the potential to be not just carbon zero, but carbon-negative with the addition of geological carbon sequestration. Within the WCSB, Alberta is uniquely positioned to deploy a comprehensive geothermal value chain due to its geography, oil and gas legacy, and technological innovations. METHODS/PROCEDURES/PROCESS In Alberta, conventional geothermal energy production starts with drilling multiple wells (typically 2-4 kilometres deep) to reach hot brines that are pumped to surface, where the energy content is put to work. Using its Alberta No. 1 geothermal energy project as a case study, Terrapin presents the full value chain of what can be done after brine production to surface: baseload power and heat generation; potential hydrocarbon separation; potential mineral production; and carbon sequestration. RESULTS/OBSERVATIONS/CONCLUSIONS Studies conducted for Alberta No. 1 demonstrate that specific formations in western and northern parts of the WCSB contain fluids hot enough for geothermal power generation. A 2021 temperature log returned a bottomhole temperature of 118°C from 3,800 metres, a promising result for Alberta’s geothermal power industry. Following electrical conversion, remaining heat can be put to useful work, creating “dual purpose” heat and power facilities. Fluids with insufficient temperature to produce electricity can be used for direct-use applications, supporting co-located industrial facilities requiring large amounts of heat, such as chemical processing, timber kilns, and commercial greenhouses. The drilling of large diameter wells to support electricity generation provides opportunities for carbon sequestration, transforming geothermal from zero-carbon to carbon-negative energy. NOVEL/ADDITIVE INFORMATION Geothermal energy is environmentally advantageous in that it has the smallest surface area footprint per megawatt of all renewable resources; can utilize existing oil and gas infrastructure and previously disturbed land; can support carbon sequestration; and can use air-cooled systems, negating the need for water diversion. Globally installed capacity for geothermal power and heat increased significantly over the past 20 years. Since 2000, electrical capacity has nearly doubled, and heating capacity has experienced a 611% increase. Canada’s geothermal energy industry is relatively nascent but will become more relevant as the federal carbon tax rate increases from $50/tonne to $170 by 2030. A geothermal regulatory framework has also been adopted in Alberta, which the Alberta government hopes will set the foundation for geothermal resource development.

Catherine Hickson 300x300
Catherine Hickson CEO Alberta No. 1.
  • 1 30 PM

Wearables PLUS Digital EHS = Best in Class Safety Programs

Field Development & Infrastructure

In his session, Doug Junor, Field Safe's Director of Innovation and Strategic Partnerships will explain the emerging field of using wearable technology to collect field data. He will then share rea...

  • locationROOM B
  • small-arm1:30 PM - 2:00 PM
thursday June 09, 2022
Field Development & Infrastructure

Wearables PLUS Digital EHS = Best in Class Safety Programs

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

In his session, Doug Junor, Field Safe's Director of Innovation and Strategic Partnerships will explain the emerging field of using wearable technology to collect field data. He will then share real-world examples of how, when that field data is integrated into EHS solutions, it can then be used to improve worker safety, create efficiencies (especially faster incident response times), and lowers costs.

Doug Junor 300x300
Doug Junor Director, Innovation & Strategic Partnerships Field Safe Solutions
  • 1 30 PM

Panel: Methane Detection and Mitigation Technologies: Paving the Road to Net-Zero

Technical Panel Session

The Panel will discuss the advancement made in increasing the technology capacity to reduce methane emissions. PTAC's consortia alone have helped developed the collective methane detection and miti...

  • locationROOM C
  • small-arm1:30 PM - 3:00 PM
thursday June 09, 2022
Technical Panel Session

Panel: Methane Detection and Mitigation Technologies: Paving the Road to Net-Zero

  • pr-alarm1:30 PM - 3:00 PM
  • pr-locationROOM C

The Panel will discuss the advancement made in increasing the technology capacity to reduce methane emissions. PTAC's consortia alone have helped developed the collective methane detection and mitigation technology capacity capable of reducing over 45% of oil and gas sector’s methane emissions.

The panel will also discuss the challenges facing the Small and Medium Enterprises (SMEs) and technology providers to securing sites and funds to field test their technologies and increase market uptake of their technologies, and provide updates on regulations.

Moderator
Soheil Asgarpour 300x300
Soheil Asgarpour President PTAC
jackson_300x300.jpg
Jackson Hegland President Modern West Advisory
Sean Hiebert 300x300
Sean Hiebert Emissions Management Engineer, Environment & Regulatory - Air Management Cenovus Energy
Gerald Palanca 300x300
Gerald Palanca Manager, Emissions Management Team AER
  • 2 00 PM

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

Renewables

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 A
  • small-arm2:00 PM - 2:30 PM
thursday June 09, 2022
Renewables

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

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

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 low carbon intensity electricity as feedstock for the process. Fischer Tropsch Gas to Liquids Expander (through its affiliate company Rocky Mountain GTL) plan to start-up its first Natural Gas to Liquids (EGTL™) facility in Carseland Alberta in January 2022. The Facility will produce 500 BPD (28 million liters/year) of Synthetic Paraffinic Diesel (SPD) and Naphtha. The facility can also produce 12 tonnes / day of surplus hydrogen for transportation, industrial and residential use. Biomass / Gas to Liquids (BGTL™) Expander is in the final stages of developing a Biomass to Diesel Facility in Carseland Alberta. The 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 2023. The commercial demonstration facility will utilize 80 t/day of waste wood and some natural gas to produce 150 BPD (8 million liters/year) of renewable diesel (SPD) with Carbon Intensity of under 10 gCO2/MJ. Front End Engineering for the gasifier addition project is complete, and we expect to have project financing finalized and kick off the project in Q1 2022. The Carseland gasifier will utilize waste wood (construction / demolition material) as feedstock. Expander plans to demonstrate the gasifier using osb cut-offs, agricultural by-products, forestry residual hog material, municipal sludge and railway ties. We expect that on completion of our commercial demonstration, a second large scale facility in Slave Lake Alberta will be immediately constructed, and several other prospect locations will be developed.   “Fossil Free” Biomass / Electrolysis to Liquids (BETL™) On successful commercial demonstration in Carseland, Expander will construct a commercial demonstration of our “Fossil Free” next generation Biomass / Electrolysis to Liquids (BETL™) technology. Electrolysis of water/steam is utilized to generate hydrogen and oxygen in lieu of natural gas to balance the H:CO ratio for FT conversion. This technology will use Low CI hydro or nuclear electricity to produce “Fossil Free” near zero CI fuel Initial engineering review shows that Diesel or Jet produced using the BETL™ process will have a CI as low as 11 gCO2/MJ (88 % reduction). Engineering development and evaluation of prospect locations is underway with a target operational date for the commercial demonstration in 2024. Expander facilities can be adjusted to also produce FT Synthetic Paraffinic Kerosene jet fuel (FT-SPK) as part of the fuel product mix to support the aviation industry going forward. Expander will utilize plentiful non-food related biomass to create a sustainable supply of low CI Synthetic Diesel / Jet fuel.

Gord Crawford 300x300
Gord Crawford President and Chief Operating Officer Expander Energy Inc.
  • 2 00 PM

How Asset-Intensive Organizations Employ Predictive Analytics, Machine Learning and AI to Monitor, Maintain and Optimize Assets for Better Availability, Utilization and Performance

Field Development & Infrastructure

Asset-intensive industries like oil & gas, mining, energy and utilities use complex equipment such as rotary, compressors, haul trucks, and turbines in their day-to-day operation. Any unplanned dow...

  • locationROOM B
  • small-arm2:00 PM - 2:30 PM
thursday June 09, 2022
Field Development & Infrastructure

How Asset-Intensive Organizations Employ Predictive Analytics, Machine Learning and AI to Monitor, Maintain and Optimize Assets for Better Availability, Utilization and Performance

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

Asset-intensive industries like oil & gas, mining, energy and utilities use complex equipment such as rotary, compressors, haul trucks, and turbines in their day-to-day operation. Any unplanned downtime or major unforeseen equipment failure negatively impacts production, which affects the organization’s financial performance. However, increasing instrumentation (“smart technology”) of equipment and infrastructure and wireless communications are enabling organizations to acquire volumes of asset performance data and become proactive in monitoring the condition of these assets. Furthermore, analytics are enabling organizations to develop sophisticated models of asset performance, predict component and equipment failure and assess the health of in-service equipment. Driven by predictive analytics you can now detect even minor anomalies and failure patterns to determine the assets and operational processes that are at the greatest risk of problems or failure. Advances in analytic algorithms enable organizations to identify signs of possible failure well in advance of previous methods. What-if analysis allows an organization to investigate potential scenarios to determine the most appropriate (economic, efficient, safe) means of responding to pending equipment failure. Automated decision management can then recommend the best action to take in anticipation of equipment problems. This session will explain how the capabilities of Predictive Maintenance and Quality solution are being used by oil & gas, mining, energy and utility organizations worldwide to integrate relevant equipment data, including real-time, build models that predict maintenance needs, monitor asset performance, provide timely alerts, and recommended appropriate actions. These integrated capabilities allow these organizations to deploy limited resources more cost effectively, maximize equipment uptime and enhance quality and supply chain processes. use-case examples: • Predict the failure of a monitored asset in order to fix it and avoid costly downtime • Identify the root causes of asset failure to take corrective actions • Minimize product quality and reliability issues to meet customer delivery schedules • Others...

Oscar Cruz 300x300
Oscar Cruz Sr. Predictive Analytics Professional Bow River Solutions Inc.
  • 2 30 PM

Printed Energy Conversion Devices

Renewables

Organic photovoltaics (solar cells) are a viable clean energy technology. The potential to convert light energy into electric energy in an affordable and versatile manner using such ‘plastic’ photo...

  • locationROOM A
  • small-arm2:30 PM - 3:00 PM
thursday June 09, 2022
Renewables

Printed Energy Conversion Devices

  • pr-alarm2:30 PM - 3:00 PM
  • pr-locationROOM A

Organic photovoltaics (solar cells) are a viable clean energy technology. The potential to convert light energy into electric energy in an affordable and versatile manner using such ‘plastic’ photovoltaics cannot be denied. These devices can be rendered flexible and light weight, transparent or colored, and fabricated in many different form factors. Most important is that owing to the printing processes and organic materials used for cell fabrication, manufacturing can be carried out locally reducing costs and eliminating supply chain issues. Applications include solar fields, solar windows, building integrated photovoltaics, indoor light harvesting, and agrivoltaics. Researchers around the world continue to develop new materials, optimize devices, and understand operation resulting in excellent performance metrics, but commercialization has yet been realized. As chemists at the University of Calgary we are developing new photoactive materials and processes to aid in the commercialization of this technology. This presentation will explain what Printed Organic Photovoltaics are, current state-of-art in industry and academia and efforts at the University of Calgary to develop home-grown photovoltaics and use/be inspired by components of bitumen.

Gregory Welch 300x300
Gregory Welch Professor University of Calgary
  • 2 30 PM

Industrial Control System Device Management and Cybersecurity

Field Development & Infrastructure

Modern industrial control systems in the energy sector typically integrate a variety of different makes and models of devices, each designed to perform some task effectively or economically. The co...

  • locationROOM B
  • small-arm2:30 PM - 3:00 PM
thursday June 09, 2022
Field Development & Infrastructure

Industrial Control System Device Management and Cybersecurity

  • pr-alarm2:30 PM - 3:00 PM
  • pr-locationROOM B

Modern industrial control systems in the energy sector 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.

Jim Atkins 300x300
Jim Atkins Account Manager, Eastern Region North America SUBNET Solutions Inc.
  • 4 00 PM
End of Day 3 and Technical Conference Concludes