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In response to the Alberta Government announcement of a State of Public Health Emergency, and in line with our commitment to your safety, we have made the difficult decision to postpone the Global Energy Show 2021.

We know how important this show is to our global energy community, and we did not take this decision lightly. Planning is underway for 2022 with themes and ideas to continue our mission of shaping the future of energy at North America's most important energy event.

The 2022 Global Energy Show will take place June 7-9, 2022 at the BMO Centre, Calgary Stampede.

To our loyal exhibitors, delegates and attendees from around the world, rest assured your bookings will be transferred to 2022. Please keep an eye on your inbox for full details.

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North America's Leading Energy Event
September 21-23, 2021
BMO Centre at Stampede Park - Calgary, Canada

Co-Host

2021 Poster Session

Technical posters cover a wide range of topics in the energy industry and will be presented on the exhibition floor during specific scheduled times throughout the three days at Global Energy Show.

Poster topics covered include:

  • Cleaner Hydrocarbon Production & Enhanced Oil Recovery
  • Drilling & Completion
  • Field Development & Infrastructure
  • Future of Fuels
  • Pipeline & Processing Facilities
  • Post-Production
  • Reservoir Engineering
  • Sustainable Electricity Generation and Grid Modernization
  • Water & Environmental Management

Free to view and attend with exhibition visitor and conference registration badge

Location: Hall DE, BMO Centre, Stampede Park

Come and meet the authors of the posters at designated times throughout the three days of the exhibition and conference.

September 21, 2021

12:00 PM – 1:30 PM

2:30 PM – 3:00 PM

September 22, 2021

10:00 AM – 10:30 AM

12:00 PM – 1:30 PM

2:30 PM – 3:00 PM

September 23, 2021

10:00 AM – 10:30 AM

12:00 PM – 1:30 PM

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

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

Presented By:
Gray Alton
VP, Project Development
Terrapin Geothermics

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

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

Presenter By:
Ronald Schmitz
Executive Advisor
Trax Electronics Inc.

AI Enabled Autonomous Renewable Energy based Smart Microgrids

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

Presented By:
Amardeep Sibia
CEO

Drishya AI Labs Inc.

Automating Liquid & NGL Leak Detection at Above-Ground Facilities Using AI-Powered Imaging

In the oil and gas industry, it is critical to stop leaks before they impact asset safety, business operations, the community, and the environment. Response times, however, are dependent upon the time it takes to detect and confirm a leak. Sufficiently monitoring upstream and midstream facilities that are partially manned or remote (e.g.: pump stations, pig trap stations, block valve sites and onshore and offshore well pads) have been economically challenging using traditional methods. Currently adopted technologies and processes (CPM, acoustic, sniffers, manned surveillance) do not provide the high level of confidence needed to take immediate action, requiring personnel to verify alarms by traveling to the potentially hazardous site.

The poster presentation will offer insight into the current challenges of monitoring remote assets and how they influence response times, and introduce a better and cost-effective modern alternative. Learn how fixed thermal imaging combined with real-time artificial intelligence and deep machine learning technologies provides an effective solution for automating leak detection and reporting.

Analytic thermal imaging is a relatively new, non-traditional fluid leak detection method adopted in the middle of the last decade by major oil and gas operators in North America. The edge-based technology is being used to continuously and autonomously monitor facilities of major oil and gas operators in North America and the Gulf of Thailand, and has over 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. Leaks of 1L/s and lower can be detected and alarmed on in less than 30 seconds, and visually verified remotely 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 site visits and manpower, low bandwidth consumption from only transmitting alarms rather than continuous raw data, integrating security/intrusion analytics, and distributed assets monitoring.

AI-powered imaging delivers reliable round-the-clock leak detection and asset surveillance across a wide range of applications. This solution supplements existing external sensing technologies and improves asset operational management capabilities through speed. This technology solution aligns with the industry best practice of layering multiple methods to achieve a more comprehensive and robust coverage.

Presented By:
Alex Haworth
Chief Revenue Officer
Intelliview Technologies Inc.

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

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

Presented By:
Hossam Gharib
Senior Product Engineer
Stream-Flo Industries Ltd.

Exothermic Chemical Treatment? Innovation Method for EOR

Category: Cleaner Hydrocarbon Production & Enhanced Oil Recovery

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

Presented By:
Ferdinand Lobkowicz
Consulting Geologist (Retired)
Lobkowicz Geological

Green Hydrogen from Upstream Oil & Gas Facilities

Category: Future of Fuels

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

Presented By:
Richard Enns
Process Lead
Acero Engineering

How to Prevent Insoluble Dithiazine Solids Utilizing Triazine-Free Hydrogen Sulfide Scavengers

Category: Cleaner Hydrocarbon Production & Enhanced Oil Recovery

Energy efficiency, net-zero, de-carbonation of the Oil & Gas industry has made it to the top list of initiatives since the start of the pandemic. As Hydrogen Sulfide (H₂S) continues to increase in oil and gas production, operators are now faced with reliability challenges as a side-effect with traditional triazine based H₂S scavenger applications. Triazene-free scavengers are on the verge of an industry wide solution. Over the last 20 years triazine based H₂S scavengers have predominately been used to reduce H₂S concentrations in production applications. Without proven economic alternatives, the use of highly toxic triazine scavengers has evolved into a global industry practice for H₂S management. Triazines are created by reacting formaldehyde and monoethanolamine (MEA). The result is a mixture of water and triazine, and possibly with some unreacted formaldehyde. When used for H₂S management, triazine scavengers create insoluble dithiazine solids as a by-product when reacting with H₂S molecules. Previous research has demonstrated that dithiazine causes scaling and corrosion on processing equipment and deposits within gas systems. Additives, including methanol, are used to keep dithiazine in solution to prevent adverse effects. In dry gas systems, the gas is found to evaporate the methanol, resulting in concentrated dithiazine deposits, which can cause blockages. Over the last decade, new chemistry has been developed, tested, and trialed for safe-replacement Triazine-free H₂S scavenger technology. The proprietary chemistry irreversibly reacts with H₂S to creating water-soluble salts. Previous research and lab tests demonstrate that the trace amounts of salt generated naturally mix with liquids and gas precipitate and do not result in corrosion or deposits. As a result, by-product treatment and downstream retrieval are not required. Supported by four patents, tests validate that the developed chemistry results in considerable cost saving for H₂S management compared to triazine scavengers. The scavenger solution is non-regulated, safe-to-handle, biodegradable, near odourless, and has a low toxicity with no flashpoint. The chemistry's unique properties allow the scavenger to be blended for various winter or summer applications. Tests have concluded that the chemistry remains effective after freeze-thawing, does not react with CO2, and will not foam from agitation. Proven as commercially viable chemistry by lab and field tests, the scavenger is undergoing trials by leading operators in sour water systems as a direct-replacement technology using existing injection equipment. With initial field trial results expected by mid-2021, the chemistry will continue to be field trialed in various oil and gas applications. As Triazene-free H₂S scavenger technology continues to be trialed and adopted, the energy industry can unlock widespread benefits, including reduced chemical and maintenance costs, improved reliability, and the elimination of scavenger safety and environmental hazards.

Presented By:
Brett Lovas 
Director
Kaliber Chemicals Limited

 

Integrated Planning and Construction Methodology for Energy Projects

Category: Pipeline & Processing Facilities

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

Presented By:
Williams Chirinos
President
Inexertus, Inc.

inVision™ Remote Wireline Supervision Module - Automating Wireline Perforation and Frac Plug Set Depth Reporting

Category: Drilling & Completions

Objectives/Scope: Capturing incorrect perforation depths plagues the future use of this data. Most 4-D production models are currently running on the assumptions of where perforations should be - not using inputs of where they actually are. Reservoir, production or exploitation engineers are often left questioning production data modelling accuracy - as-built perforations are possibly not where they thought they were? The entry points to the reservoir and stimulation schedule may have left considerable bypassed pay. These models may not require calibration, they simply required accurate data inputs from the outset, or better yet on-the-fly corrections to access the entire pay zone. Procedure: A project collaboration started with an operator priority to auto-import wireline perforation and frac plug setting depths into an industry recognized wellsite reporting software. The project then revealed itself to be much more ? an exercise in ensuring quality depth data from site. This is a game-changing tool for service companies and operators alike. Unique automation capabilities were developed that unified several processes and IIOT data on a completions site. Process: Depths are auto-captured directly into a data platform, eliminating manual entry and administrative time. Data is collected by means of proprietary and off-the-shelf IIOT sensors, which is congruently merged with third party service data on the pad site to create a real-time, time-synchronous view of the entire operation. Copy-paste, keyed-in and transcription errors as well as omissions in data entry are a thing of the past. Results and Conclusion: A customer case study comparing auto-generated and manually input records for 120 stages and 830 perforations indicated 31 cluster or stage spacing deviations from plan and 78 notable input errors. 5% of the 830 perforations contained significant manual depth input errors that were greater than 130ft or 40m, with a maximum error of 252ft or 77m off actual the perforating depth. With this novel solution now in-place with past and ongoing operations, this particular operator will be able to ratify production data models with accurate well construction values ?" eliminating unknowns and forming a more complete view of their assets.

Presented By:
Chad Van Buskirk
Innovation Subject Matter Expert
Intelligent Wellhead Systems

 

Saving $1000's with Medium Voltage Active Front End Drive

Category: Pipeline & Processing Facilities

Energy efficiency, net-zero, de-carbonation of the Oil & Gas industry has made it to the top list of initiatives since the start of the pandemic. Further, the huddle" rate for new installations or facility improvements are increasing to make projects viable. 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. However, using MV ASDs for power factor improvement and corresponding electric bill savings / electric efficiency is unheard. In a recent request for quotation (RFQ) for seven ASDs ranging from 750HP ?" 2,600HP, ASDs based on a voltage source active front end inverter (AFE) topology was able to demonstrate a six-figure reduction in CAPEX savings by eliminating capacitor banks for power factor correction (PFC) and five-figure per year in electric bill savings due to reduction in power factor penalties. A typical electric tariff rate for a large industrial user is composed of energy plus a power factor component. While ASD has historically been used to impact the bill's energy component, it's only recently that multi-MW ASDs gained capabilities to influence the power factor. This is a powerful capability that makes a case for applying drives very compelling. Why not kill two birds with a stone! In this presentation, we first describe the AFE capability of the drive and how it works. We then focus on how this topology impacts the overall power delivery apparatus, capital expenditure, electric billing, and facility operating expenses. The presentation demonstrates the preceding with one or two representative case studies by considering several operating scenarios in a typical pipeline station. In particular, we show how these drives reduce the overall power demand (kVA), reactive power demand (kVAR), materially improve the power factor at the utility interconnect, and lower the copper losses in the facility. We then compare and contrast each of the above parameters with conventional drives available in the market. The presentation aims to open new engineering and economic thinking lines to select and apply large drives for pumping and compression applications. The talk is bound to provoke widespread commentary in engineering, application, procurement, and other stakeholders responsible for investment decisions and efficient facility operations.

Presented By:
Stephan Bondy
Business Development Manager, Energy & Infrastructure Solutions
TMEIC Corporations Americas

 

The Benefits of Direct Contact Steam Generation for Enhance Oil Recovery

Category: Cleaner Hydrocarbon Production & Enhanced Oil Recovery

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

Presenter By:
Brian Kay
Chief Technology Officer
General Energy Recovery Inc. (GERI)

Thermal Energy Storage: Path to Decentralizing Our Grid

Category: Sustainable Electricity Generation and Grid Modernization

SAIT’s Green Building Technologies (GBT) research group has partnered with Home Completions, Scout Energy, ATCO, and Sunamp to demonstrate and adapt the Sunamp Thermal Energy Storage batteries for North America, and run a series of simulated scenarios for use in Canada’s cold-climate residential sector in the GBT lab on SAIT campus. Using the Phase Change Material (PCM) based Thermal Energy Storage (TES) battery appliance, we will be running simulations for specific residential/commercial scenarios to demonstrate the integrated performance with micro Combined Heat and Power (mCHP), Solar Thermal, and Solar PV technologies with application for cold-climate. GBT lab will integrate the TES appliance first with the mCHP unit to study the combined performance of these appliances and produce data to support their usage in Demand-Side Management (DSM), and second with Solar Thermal and Solar PV to study the TES units’ applicability to arbitrage thermal heat from the Solar Thermal system, and also to convert electricity generated from Solar PV into thermal heat and use during low Solar Thermal and Solar PV production hours (cloudy, night time). Along with studying the combined performance of these integrated technologies, we will be collecting data pertaining to the applicability of DSM. This will include data that shows the amount of time needed between a call for a heat source, the availability of heat and electricity sinks during typical times needed for DSM, and studying the scalability and practical use cases for DSM with these technologies. A series of scenarios will be designed and executed to mimic residential and commercial thermal and electrical demands (and supply) at the GBT lab using the existing controls infrastructure. With the help of SAIT students, the scenario designs will be translated into programs to be run for a set period of time and under the conditions outlined. Data is collected and stored in a SQL data warehouse, where it will be pulled for analysis. Sensors are used to gather thermal and electrical exchange throughout the system, and to calculate overall performance with standard household and commercial appliance data as the benchmark. The BMS will be used to operate the on/off and run-level of the mCHP, domestic water “consumption”, thermal fluid transfer between appliances, and transfer to end-use loads. With the project still underway, we expect to see a greater utilization of the thermal byproduct from the mCHPs that will enable them to be a more practical option for Canadian households and commercial buildings. In comparison to benchmark data, GHG and energy advantages will be reported. Further to our studies with mCHP, Solar Thermal, and Solar PV, we expect TES technology to be a reliable thermal and electricity sink for surplus thermal and electrical energy generated from alternative energy resources.

Presented By:
Tyler Willson
Principal Investigator
SAIT

The Key to Project Success? It's All in How you Start!

Category: Future of Fuels

Companies know projects almost always take longer and cost more than expected. Every project is at risk for budget and schedule overruns  and the bigger the project, the bigger the risk. The problems are recognized industry-wide and are significant. Without effective knowledge transfer from departing and existing talent the challenges, costs, and risks are escalated. Learn how to lead your projects to success with knowledge transfer and: 1. Reduce the risk of budget and schedule overruns; 2. Improve processes that are easier for teams and suppliers to execute; and, 3. Enhanced your reputation for consistent on-budget and on-time project delivery. Effective knowledge transfer involves: • Coaching, mentoring, training, and workshops for project teams; • Guidelines, with instructions and procedures; and, • Standardized terminology, using a glossary with industry and project terminology.

Presented By:
Roy Christensen
Project Success Coach 
KT Project