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North America's Leading Energy Event
June 9 - 11, 2020
Stampede Park - Calgary, Canada

  • 12 00 AM

Welcome & Opening Ceremonies - Day 2

Drilling & Completion

Smart Remote Operations: Realties, Risks and Rewards: Remote Operations, enabled by the latest data and information technologies, is a current hot topic within the industry...

  • locationPALOMINO ROOM G
  • small-arm10:00 AM - 12:00 AM
monday January 01, 0001
Drilling & Completion

Welcome & Opening Ceremonies - Day 2

  • pr-alarm10:00 AM - 12:00 AM
  • pr-locationPALOMINO ROOM G

Smart Remote Operations: Realties, Risks and Rewards: Remote Operations, enabled by the latest data and information technologies, is a current hot topic within the industry...

  • 2 16 PM
Tea Break
  • 2 17 PM

The standard Lorem Ipsum passage, used since the 1500s

Alternative Energy

"Lorem ipsum dolor sit amet, consectetur adipiscing elit, sed do eiusmod tempor incididunt ut labore et dolore magna aliqua. Ut enim ad minim veniam, quis nostrud exercitation ullamco laboris nisi...

  • locationPALOMINO ROOM G
  • small-arm11:00 - 12:00 AM
friday November 29, 2019
Alternative Energy

The standard Lorem Ipsum passage, used since the 1500s

  • pr-alarm11:00 - 12:00 AM
  • pr-locationPALOMINO ROOM G

"Lorem ipsum dolor sit amet, consectetur adipiscing elit, sed do eiusmod tempor incididunt ut labore et dolore magna aliqua. Ut enim ad minim veniam, quis nostrud exercitation ullamco laboris nisi ut aliquip ex ea commodo consequat. Duis aute irure dolor in reprehenderit in voluptate velit esse cillum dolore eu fugiat nulla pariatur. Excepteur sint occaecat cupidatat non proident, sunt in culpa qui officia deserunt mollit anim id est laborum."

speakers
Afshin Ahmady
Afshin Ahmady Principal Technical Professional Halliburton
Afshin-Esmaeili-300x300
Afshin Esmaeili Co-Founder and CEO Aimsio
  • 2 18 PM

Section 1.10.32 of "de Finibus Bonorum et Malorum", written by Cicero in 45 BC

Drilling & Completion

Sed ut perspiciatis unde omnis iste natus error sit voluptatem accusantium doloremque laudantium, totam rem aperiam, eaque ipsa quae ab illo inventore veritatis et quasi architecto beatae vitae dic...

  • locationPALOMINO ROOM ABCDE
  • small-arm11:30 - 12:00 AM
friday November 29, 2019
Drilling & Completion

Section 1.10.32 of "de Finibus Bonorum et Malorum", written by Cicero in 45 BC

  • pr-alarm11:30 - 12:00 AM
  • pr-locationPALOMINO ROOM ABCDE

Sed ut perspiciatis unde omnis iste natus error sit voluptatem accusantium doloremque laudantium, totam rem aperiam, eaque ipsa quae ab illo inventore veritatis et quasi architecto beatae vitae dicta sunt explicabo. Nemo enim ipsam voluptatem quia voluptas sit aspernatur aut odit aut fugit, sed quia consequuntur magni dolores eos qui ratione voluptatem sequi nesciunt. Neque porro quisquam est, qui dolorem ipsum quia dolor sit amet, consectetur, adipisci velit, sed quia non numquam eius modi tempora incidunt ut labore et dolore magnam aliquam quaerat voluptatem.

speakers
Chelsea O'Connor.jpg (1)
Chelsea O'Connor Business Development - Energy Simark
Carol Howes.jpg
Carol Howes Vice President of Communications and the PetroLMI Division Energy Safety Canada
Cara Wolf
Cara Wolf Founder and CEO Ammolite Analytics
Christian Smith.jpg
Christian Smith President Interactive Aerial
  • 8 00 AM
Registration
  • 10 00 AM

Opening Plenary Session

Our show opening is for strategic and technical conference delegates , XTL Summit delegates & invited guests.

  • locationPALOMINO ROOM DE
  • small-arm10:00 AM - 12:00 PM
tuesday June 09, 2020

Opening Plenary Session

  • pr-alarm10:00 AM - 12:00 PM
  • pr-locationPALOMINO ROOM DE

Our show opening is for strategic and technical conference delegates , XTL Summit delegates & invited guests.

  • 10 30 AM

The Necessity of a Third Option – Sustainable Hydrocarbons

The time is now to work together to develop of a new path, a practical compromise solution that accommodates the needs and aspirations of all stakeholders. How is industry evolving to meet the need...

  • locationPALOMINO ROOM DE
  • small-arm10:30 AM - 11:00 AM
tuesday June 09, 2020

The Necessity of a Third Option – Sustainable Hydrocarbons

  • pr-alarm10:30 AM - 11:00 AM
  • pr-locationPALOMINO ROOM DE

The time is now to work together to develop of a new path, a practical compromise solution that accommodates the needs and aspirations of all stakeholders. How is industry evolving to meet the needs of the future, while maintaining the needs of today?

  • 11 00 AM

Executive Panel: The Roadmap to a Lower Carbon Energy Company

The world needs more energy but with fewer emissions. How are energy companies supporting and leading the low carbon transformation? What new business models and thinking is required to provide a p...

  • locationPALOMINO ROOM DE
  • small-arm11:00 AM - 12:00 PM
tuesday June 09, 2020

Executive Panel: The Roadmap to a Lower Carbon Energy Company

  • pr-alarm11:00 AM - 12:00 PM
  • pr-locationPALOMINO ROOM DE

The world needs more energy but with fewer emissions. How are energy companies supporting and leading the low carbon transformation? What new business models and thinking is required to provide a practical and realistic roadmap for the future? Is there a scenario where hydrocarbons can be sustainable in the long term?

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

Integration of Renewable Power and Hydrogen Production with Gas-to-Liquids

Alternative Energy

This paper investigates two alternative flow schemes for the co-production of hydrogen and Gas-to-Liquid (GTL) hydrocarbons such as methanol, gasoline, diesel or jet fuel. Various flow scheme confi...

  • locationPALOMINO ROOM A
  • small-arm1:30 PM - 2:00 PM
tuesday June 09, 2020
Alternative Energy

Integration of Renewable Power and Hydrogen Production with Gas-to-Liquids

  • pr-alarm1:30 PM - 2:00 PM
  • pr-locationPALOMINO ROOM A

This paper investigates two alternative flow schemes for the co-production of hydrogen and Gas-to-Liquid (GTL) hydrocarbons such as methanol, gasoline, diesel or jet fuel. Various flow scheme configurations and utility options are explored as a means of reducing the Greenhouse Gas (GHG) emissions intensity associated with the manufacturing of GTL hydrocarbons. In the first flow scheme hydrogen is generated through electrolysis, with the electrolysis power requirement supplied by the exothermic GTL process and supplemented with a renewable power source. The oxygen by-product from electrolysis is fed with natural gas to an Autothermal Reforming (ATR) unit to generate syngas for syngas conversion processes such as Fischer-Tropsch (FT) or methanol synthesis. The availability of renewable power also allows for the syngas generation process to be configured to significantly increase the carbon efficiency of the overall GTL process. Furthermore, the co-production of Hydrogen allows changes in the GTL flow scheme which increases the amount of high-pressure CO2 that can be captured for storage or for use in Enhanced Oil Recovery (EOR). The co-produced GTL products can be blended with conventional products from a refinery/upgrader or used as diluents or solvents for blending or product upgrading in the oil sand industry, resulting in further indirect GHG emissions reduction when viewed from a “well to wheels” perspective. Furthermore, hydrogen production may be scaled relative to the availability of renewable power, with excess hydrogen produced during periods of peak electricity production and stored to supplement periods of renewable power intermittency. The second flow scheme investigated is that of a more conventional process in which oxygen is supplied to the autothermal reformer via an Air Separation Unit (ASU) making use of renewable power sources. During times of peak renewable power production, cryogenic nitrogen, a co-product of the ASU, is stored to later be vaporized by process waste heat and passed through a turbine as a means of producing supplemental electricity. This more conventional flow scheme could also be configured to increase Hydrogen generation and CO2 capture for EOR. The complementary nature of cryogenic energy storage and the requirement for Air Separation for most GTL, Biomass-to-Liquids, Waste-to-Liquids and Coal-to-Liquids facilities (collectively also called “XTL”), means that fossil fuel power may be replaced by renewable power import for a range of both existing and newly build “XTL” facilities. A high-level economic analysis and qualitative assessment of potentials for process integration is performed to compare the proposed low GHG flow schemes to that of conventional GTL processes that produces naphtha, jet fuel and diesel.

Presenter
Wessel Nel 300x300.jpg
Wessel Nel Senior Process Engineer Hatch
  • 1 30 PM

Natural Gas-Based Fracturing Fluids - A Technical & Cost Comparison vs. Water-Based and Nitrogen Fluids

Drilling & Completion

Water-based fracturing fluids (e.g., slickwater) are by far the most common fluids used for hydraulic fracturing today. However, scarcity of water, environmental impacts, and the high total costs a...

  • locationPALOMINO ROOM B
  • small-arm1:30 PM - 2:00 PM
tuesday June 09, 2020
Drilling & Completion

Natural Gas-Based Fracturing Fluids - A Technical & Cost Comparison vs. Water-Based and Nitrogen Fluids

  • pr-alarm1:30 PM - 2:00 PM
  • pr-locationPALOMINO ROOM B

Water-based fracturing fluids (e.g., slickwater) are by far the most common fluids used for hydraulic fracturing today. However, scarcity of water, environmental impacts, and the high total costs and logistical complexity (from sourcing to transport to disposal & treatment) of relying on water-based fluids result in high costs in every region and limited use in water-constrained regions. Additionally, water can constrict the flow of hydrocarbons from the formation due to surface tension, swelling of clays and other factors. Alternative fluids such as proppant-carrying nitrogen foams have been used for decades, often with much higher production levels and shallower decline curves than can be achieved with water, while using less proppant. However, N2 fluid is expensive and needs to be trucked to the well site in large volumes, both of which make it economically or logistically unfeasible in many fields. Also, N2 contaminates initial gas flow, which then needs to be flared off for up to several weeks before it is pure enough to meet pipeline requirements. CO2 shows promise as a fracturing fluid, but high volumes of CO2 are only available in a few places, and not in nearly enough volume to develop an entire unconventional field. A newer alternative -- cryogenically processed natural gas (NG) in a pumpable liquid (LNG) or quasi-liquid (CCNG) phase, either foamed or non-foamed -- combines the well performance benefits of N2 with the lower cost and wider availability of water-based fluids. In fact, when the NG is obtained and cryogenically processed at the well site itself instead of relying on truck-delivered LNG from offsite, NG-based fracturing fluids can cost significantly LESS than the total cost of water-based fluids -- as much as $1-2 million less per horizontal well. The proposed presentation will present a technical overview of the cryogenic processing, blending and pumping steps for using cold, pumped NG as a fracturing fluid, plus the findings of a detailed comparison of the cost/economics of a horizontal well frac job using cryogenically processed NG vs. a slickwater frac and a N2 foam frac. The paper and presentation will also cover the physical characteristics of NG-based foams (such as stability, viscosity and rheology) versus N2 foams ? in particular the NG foam’s structural integrity, ability to be highly pressurized, and ability to carry and place proppant. The ability to alter viscosity of NG foams by varying their temperature instead of adding chemicals will also be discussed. Also presented will be the propensity for NG pumped into the formation to physically and chemically react with hydrocarbons residing in targeted formation, thereby liberating oil & gas into the well. This indicates that NG-based fluids are also a good candidate for EOR, such as for “huff-and-puff” techniques."

Presenter
Jeremy Dockter 300x300.jpg
Jeremy Dockter Co-Founder & Managing Director Expansion Energy LLC
  • 1 30 PM

Extraction of Bitumen from Surface Mined Oil Sands using Non-aqueous Liquid Catalyst (LC), a Proprietary Solvent

Environmental Management

Extraction of bitumen from surface mined oil sands using non-aqueous Liquid Catalyst (LC), a proprietary solvent Rasel Hossain, M.Sc., P.Eng., MBA Principal, GAT Energy Resources Inc. Non-aqueous...

  • locationPALOMINO ROOM C
  • small-arm1:30 PM - 2:00 PM
tuesday June 09, 2020
Environmental Management

Extraction of Bitumen from Surface Mined Oil Sands using Non-aqueous Liquid Catalyst (LC), a Proprietary Solvent

  • pr-alarm1:30 PM - 2:00 PM
  • pr-locationPALOMINO ROOM C

Extraction of bitumen from surface mined oil sands using non-aqueous Liquid Catalyst (LC), a proprietary solvent Rasel Hossain, M.Sc., P.Eng., MBA Principal, GAT Energy Resources Inc. Non-aqueous Liquid Catalyst (LC) is designed to chemically recover hydrocarbons from geological materials; with a focus on bitumen recovery from oil sands ore. The overall intention of developing the non-aqueous LC technology is to improve the efficiency of bitumen extraction from the Canadian oil sands ore, to eliminate water usage for extraction and to minimize energy use at the mine site. This technology has so far been tested within GAT Energy Inc. facilities and University of Calgary at bench-scale for small volumes of material. We tested the efficacy of LC for extraction of bitumen from surface mined Alberta oil sands. We found that in a single stage operation, LC is able to extract at least 80?85% of bitumen. Oilsands/solvent ratio of 1:1 was found to be the most optimal for this extraction. The LC compound was recovered up to 99% from the oil phase by heating to 60°C to then be recycled and reused. Recovery of LC is an energy inexpensive process as it forms a low-boiling mixture with bitumen. From visual observation of the distillates, it can be concluded that LC is able to clearly leave behind mid and heavier components of bitumen during distillation as well as very likely didn’t carry the lighter components of bitumen with it. A final key results from our preliminary work is that the LC has the ability to drain the bitumen from oil sands through gravity process alone (without clogging) in a single flow through set-up while maintaining its maximum extraction efficiency. Key findings from the lab data hold promise to move forward the development and potential upscaling of the non-aqueous liquid catalyst to transform Alberta’s oil sands process. Non-aqueous LC will eliminate Alberta’s fresh water usage and tailings ponds with progressive reclamation, and minimize energy use at the mine site.

Presenter
Rasel Hossain 300x300.jpg
Rasel Hossain Chief Operating Officer Global Advanced Technology Energy Resources Inc.
  • 2 00 PM

Zero Emissions, Low Cost Hydrogen Production from Oil Reservoirs

Alternative Energy

The oil sands deposits in Western Canada not only represent a vast store of hydrocarbons (oil) that can be converted into fuel and petrochemicals but also a vast hydrogen store ? a super clean valu...

  • locationPALOMINO ROOM A
  • small-arm2:00 PM - 2:30 PM
tuesday June 09, 2020
Alternative Energy

Zero Emissions, Low Cost Hydrogen Production from Oil Reservoirs

  • pr-alarm2:00 PM - 2:30 PM
  • pr-locationPALOMINO ROOM A

The oil sands deposits in Western Canada not only represent a vast store of hydrocarbons (oil) that can be converted into fuel and petrochemicals but also a vast hydrogen store ? a super clean valuable energy vector and chemical feedstock. With the need to find new energy recovery processes for oil sands reservoirs that have low energy and emissions intensities, hydrogen production is a viable alternative for energy production from heavy oil and oil sands reservoirs by using in situ gasification technology. Gasification reactions, together with the water-gas shift reaction, enable the generation of hydrogen from both bitumen and water within the oil sands reservoir. With hydrogen separation membranes in the production wells, other products from the reactions remain in the reservoir. Thus, there is potential for hydrogen production processes from oil sands reservoirs. The research documented here describes an optimized design for an in-situ gasification of bitumen process for surface production of hydrogen only, as well as an operating design for application in a heavy oil reservoir located in Saskatchewan, Canada.

Presenter
Grant Strem300x300.jpg
Grant Strem Chairman and CEO Proton Technologies
  • 2 00 PM

Rapid, Rigless, Live Well ESP or PCP Deployment System

Drilling & Completion

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

  • locationPALOMINO ROOM B
  • small-arm2:00 PM - 2:30 PM
tuesday June 09, 2020
Drilling & Completion

Rapid, Rigless, Live Well ESP or PCP Deployment System

  • pr-alarm2:00 PM - 2:30 PM
  • pr-locationPALOMINO ROOM B

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

Presenter
Jerry Chalifoux 300x300.jpg
Gerry Chalifoux President and CEO Petrospec Engineering
  • 2 00 PM

Blockchain & Environment, Social and Governance (ESG) Measurement

Environmental Management

ESG metrics are increasingly used by investors to assess investments, particularly for assets that may be susceptible to risk associated with carbon pricing or environmental instability. In some ca...

  • locationPALOMINO ROOM C
  • small-arm2:00 PM - 2:30 PM
tuesday June 09, 2020
Environmental Management

Blockchain & Environment, Social and Governance (ESG) Measurement

  • pr-alarm2:00 PM - 2:30 PM
  • pr-locationPALOMINO ROOM C

ESG metrics are increasingly used by investors to assess investments, particularly for assets that may be susceptible to risk associated with carbon pricing or environmental instability. In some cases?such as heavy oil from unconventional resources?"this may impact commodities that are governed by low carbon fuel standards or subject to market acceptability. Despite its rigorous regulatory regime, and attendant improvement in performance, Alberta still struggles to address the label of “dirty oil”. The data required to counter this narrative is either unavailable or out of date. In September 2019, Premier Kenney told CBC radio that ESG investment decisions are being made “on the basis of 10- and 15-year old data.” As such, data management?"not ESG performance?"is the major obstacle to attracting capital. Blockchain technologies can address this. Blockchain is a shared, open, cryptographically secured database on which all permitted parties hold an updated copy of the ledger. All authorized parties can view the data, and no changes can be made to the data without the knowledge and consent of the involved parties. Blockchain includes smart contracts that automate transactions on the fulfillment of contract terms and updates the ledger accordingly. In 2018, GuildOne conducted the world’s first oil and gas royalty transaction on blockchain. It has since developed new use cases to reduce dispute, administrative burden and costs in energy transactions. Blockchain isn’t an environmental technology per se, but it can drastically streamline monitoring, automate reporting and make data much more accessible and transparent. It can thus not only drive a tremendous ESG narrative but also support business and regulatory objectives by reducing costs, eliminating delays and freeing up administrative resources for productive use. Blockchain can provide a platform to integrate data from Internet of Things-connected measurement devices throughout the hydrocarbon value chain, managing that data on the distributed ledger and using smart contracts to automate reporting, providing a platform for clear, accessible and immutable performance data. The platform could also integrate with a web-based interface, which would allow any interested party to view real-time performance data throughout the value chain. Such a platform could provide for the demonstration of Alberta hydrocarbons as being compliant with the highest environmental standards on a real-time, immutable (and thus auditable) and transparent basis. This would create a powerful tool to help Alberta energy companies to re-establish a positive narrative and properly inform ESG-minded investors of the environmental value of their commodity. The Project: Blockchain for ESG Measurement The purpose of the project is to develop and demonstrate a data platform based on GuildOne’s ConTracks, its patent pending smart contract engine. The project will apply blockchain technology to manage data for purposes of compliance reporting and the generation and exchange of marketable environmental performance credits.

Presenter
James Graham
James Graham President & CEO GuildOne
  • 2 30 PM
Coffee Break
  • 3 00 PM

Understanding the Bottom Line: Identifying and Quantifying ROI in Digital Oil and Gas IIoT

Alternative Energy

When it comes to Return on Investment, Digital Oil and Gas IIoT applications are difficult to understand. The largest barrier to obtaining value from Digital Oil and Gas IIoT is cross-organizationa...

  • locationPALOMINO ROOM A
  • small-arm3:00 PM - 3:30 PM
tuesday June 09, 2020
Alternative Energy

Understanding the Bottom Line: Identifying and Quantifying ROI in Digital Oil and Gas IIoT

  • pr-alarm3:00 PM - 3:30 PM
  • pr-locationPALOMINO ROOM A

When it comes to Return on Investment, Digital Oil and Gas IIoT applications are difficult to understand. The largest barrier to obtaining value from Digital Oil and Gas IIoT is cross-organizational confusion and mistrust. Even after coordinating the efforts between the IT and OT groups, it is still a challenge to identify ROI and relate it back to the general ledger. This presentation will go over some of the key opportunities IIoT has to offer and will illustrate how the leading and lagging indicators can relate back to the general ledger, allowing you to fully understand the bottom line for your IIoT applications and initiatives. With traditional products and projects, ROI may be easily understood. When you automate a process, or install an upgraded piece of equipment, the value is easily calculated. By processing more raw material, producing more of a product, or by eliminating a certain amount of waste, this value can be directly traced to the general ledger. IIoT applications offer a different challenge. The value might not be immediately apparent, and IIoT devices are constantly updating and adapting as their processes improve. Deep machine learning for predictive insight and action must be tracked across multiple groups within the organization, and where you expect to find the value in the general ledger is not always where it appears. This presentation will highlight how to follow the performance increases and cost savings through the general ledger and will enable you to more accurately identify and quantify the ROI for Digital Oil and Gas IIoT applications.

Presenter
Dave Shook
Dave Shook President and CEO ShookIOT
  • 3 00 PM

Impact of Stress Shadowing and Perforation Friction on Perforation Cluster Efficiency

Drilling & Completion

Objectives/Scope: Perforation cluster efficiency has a critical impact on effective reservoir stimulation and drainage. It can also impact communication with adjacent well bores, referred to as we...

  • locationPALOMINO ROOM B
  • small-arm3:00 PM - 3:30 PM
tuesday June 09, 2020
Drilling & Completion

Impact of Stress Shadowing and Perforation Friction on Perforation Cluster Efficiency

  • pr-alarm3:00 PM - 3:30 PM
  • pr-locationPALOMINO ROOM B

Objectives/Scope: Perforation cluster efficiency has a critical impact on effective reservoir stimulation and drainage. It can also impact communication with adjacent well bores, referred to as well hits." This presentation investigates the impact of stress shadowing and perforation friction on cluster efficiency. Methods, Procedures, Process:Numeric fracture simulations were conducted using the Gohfer fracture simulator in combination with spreadsheet based calculations of limited entry design to assess the impact of stress shadowing and perforation friction. Results, Observations, Conclusions: Results indicate: 1) Stress shadowing can restrict slurry placement into middle perforations as well as those closest to a preceding fracture stage. This can be offset to some degree in theory by using fewer perforation in some clusters and more in others. However, whether this will work in actual practice is also discussed. 2) Limited Entry design is certainly not new but has seen renewed interest and application in recent years. In particular attention is being paid to the magnitude of perforation friction designed for as well as changes in the coefficient of discharge in the perforations during pumping due to perforation erosion. Novel/Additive Information: There have been recent field observations made using downhole fiber and cameras to further validate theory and optimize design. However, specific examples cannot be discussed due to confidentiality. The general principles of these type of measurements and the benefits in understanding they provide will be discussed.

Presenter
Robert Taylor
Robert Taylor Manager of the Canadian Reservoir Studies Team Halliburton
  • 3 00 PM

Innovation and Disruptive Technology

Technical Panel Session

Speakers to be announced.

  • locationPALOMINO ROOM C
  • small-arm3:00 PM - 4:30 PM
tuesday June 09, 2020
Technical Panel Session

Innovation and Disruptive Technology

  • pr-alarm3:00 PM - 4:30 PM
  • pr-locationPALOMINO ROOM C

Speakers to be announced.

  • 3 30 PM

Exploitation of Waste Energy within the O&G Sector: How Orc Technology and Gas Turbo-Expanders Can Support the Decarbonization Path of the O&G Companies

Alternative Energy

Nowadays people consciousness about global warming and climate change issues is increasing day by day. Several solutions are available to shift to a low-carbon economy on a global scale and they co...

  • locationPALOMINO ROOM A
  • small-arm3:30 PM - 4:00 PM
tuesday June 09, 2020
Alternative Energy

Exploitation of Waste Energy within the O&G Sector: How Orc Technology and Gas Turbo-Expanders Can Support the Decarbonization Path of the O&G Companies

  • pr-alarm3:30 PM - 4:00 PM
  • pr-locationPALOMINO ROOM A

Nowadays people consciousness about global warming and climate change issues is increasing day by day. Several solutions are available to shift to a low-carbon economy on a global scale and they could bring substantial benefits to avoid the critical consequences of the ongoing climate changes. Global warming must be curbed, therefore the reduction of the energy consumption is becoming increasingly important among all the industrial fields. Following the increasingly trend of energy efficiency, the Oil&Gas sector is looking continuously at the development and implementation of new solutions. A clever solution in the O&G field is the implementation of Organic Rankine Cycle technology, which turns waste heat into useful power. An ORC unit enables power production by recovering waste heat from the exhaust of gas turbines or reciprocating engines or the processes hot streams. ORC turbogenerators enhance the efficiency of O&G processes, allowing users to reduce their environmental footprint through converting waste heat into mechanical or electric power. An ORC system, based on a Rankine cycle where the working fluid is an organic compound rather than steam, offers several advantages: high availability, high flexibility, high automation and integration with the plant, coupled with low-enthalpy drop, low-pressure drop and low O&M costs. Thanks to these features, the system has been employed in many fields over the Oil&Gas industry, such as renewables, heat recovery in energy-intensive industries, waste-to-energy. Beside those waste streams, exploitable through ORC technology, other ones are available in the O&G sector, like the energy lost within pressure letdown stations, where lamination valves dissipate the potential energy contained in the pressurized gas. This kind of functioning, albeit effective, isn’t efficient since it inherently wastes energy. In this scenario, the gas expander technology - similar to the ORC one as it involves the expansion of an organic fluid, natural gas in this case, can be an interesting alternative and likely a more efficient solution. A natural gas expander consists in a turbine through which the natural gas at high pressure, rather than being laminated, is expanded to produce work, which is converted into electricity by a generator. In this regards gas expanders represent a solution to improve the energy efficiency of natural gas transmission and distribution networks, as well as upstream and downstream facilities (with a relevant gas consumption), in the pursuit to achieve the carbon neutrality target. This paper will present the above-mentioned solutions, treating also specific cases (in Canada as well as worldwide) where they are employed individually or in combination. Considering a large-scale application, the paper will show also how the implementation of these recovery systems would represent not only a way to meet sustainability targets, but also a remarkable and profitable business for O&G companies.

Presenter
Nicola Rossetti 300x300.jpg
Nicola Rossetti Sales & Business Development Leader Oil&Gas and Combined Cycles Turboden SpA
  • 3 30 PM

Smart Assistant Guided Flowback Data Analysis

Drilling & Completion

The Oilfield is a cash flow dependent business, which makes the speed of decision making very important. Our industry collects a lot of data, but the volume of this data, coupled with inefficient o...

  • locationPALOMINO ROOM B
  • small-arm3:30 PM - 4:00 PM
tuesday June 09, 2020
Drilling & Completion

Smart Assistant Guided Flowback Data Analysis

  • pr-alarm3:30 PM - 4:00 PM
  • pr-locationPALOMINO ROOM B

The Oilfield is a cash flow dependent business, which makes the speed of decision making very important. Our industry collects a lot of data, but the volume of this data, coupled with inefficient oilfield software, slows down analysis and decision making. As a result, decisions are delayed and decision quality is affected. Smart Assistants like Siri and Alexa have become extraordinarily popular lately due to their ability to perform routine tasks and make information readily accessible. Considering the oil industry's drive towards enhanced speed and efficiency, there is considerable upside in applying the concept of a Smart Assistant to oil and gas applications. This Smart Assistant for Oil and Gas would consolidate massive amounts of data, derive knowledge from it, automate workflows, and provide faster and consistent insights. This paper will look closely at a specific application of this Smart Assistant: analyzing flowback data from newly drilled wells. Engineers at Equinor have recently leveraged learnings from this Smart Assistant to increase efficiency in day-to-day tasks and realize results. Flowback after hydraulic fracturing operation can last anywhere between a couple of days to a few months. Analyzing flowback data can provide valuable insights regarding the short and long term behavior of the well. However, this data is often underutilized due to the disparate nature of the data, which is commonly transmitted via emails. To maintain a live flowback database with up-to-date data for all the wells, and make sense of it, is an uphill task and uses up costly time. This problem affects the entire industry, with engineers across the board missing out on otherwise valuable insights from analyzing this data. A Smart Assistant for Oil and Gas provides a clear solution to this problem. Instead of requiring engineers to open up individual flowback emails, the Smart Assistant is copied on these emails and extracts the valuable data. The data is then able to be cleaned, analyzed, and stored in a central database with live links to in-house databases. Moving forward, the engineers can interface directly with the Smart Assistant, getting answers to most of their flowback related questions. Applying machine learning, the Smart Assistant can also identify rate and pressure trends, correlate these with short and long term performance, and suggest choke strategies to enhance productivity. The Smart Assistant is routinely trained on new data and commands, continuously improving results. This paper will cover the different commands and underlying models in more detail. After the application of the Smart Assistant at Equinor, flowback data was updated regularly and was readily available for analysis. As a result, engineers were able to consolidate geological, reservoir and production data, along with flowback data, to make meaningful recommendations on well operations and design.

Presenter
Beni Chelinsky Jeyachandra 300x300.jpg
Benin Chelinsky Vice President Nesh
  • 4 00 PM

Small Modular Nuclear Reactors as a Source of Heat and Power for Petroleum Extraction and Processing

Alternative Energy

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...

  • locationPALOMINO ROOM A
  • small-arm4:00 PM - 4:30 PM
tuesday June 09, 2020
Alternative Energy

Small Modular Nuclear Reactors as a Source of Heat and Power for Petroleum Extraction and Processing

  • pr-alarm4:00 PM - 4:30 PM
  • pr-locationPALOMINO ROOM A

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

Presenter
EvanKonarek 300x300.png
Evan Konarek Senior Engineer Nuclear Technologies Hatch Ltd.
  • 4 00 PM

Big Data Insight towards Well Planning, A case study for Offset Wells Analysis

Drilling & Completion

Objective / Proposal: - Describe the use of big data insight for offset wells analysis towards well planning. - Transformation of a manual process to automated and smart In-house web interface app...

  • locationPALOMINO ROOM B
  • small-arm4:00 PM - 4:30 PM
tuesday June 09, 2020
Drilling & Completion

Big Data Insight towards Well Planning, A case study for Offset Wells Analysis

  • pr-alarm4:00 PM - 4:30 PM
  • pr-locationPALOMINO ROOM B

Objective / Proposal: - Describe the use of big data insight for offset wells analysis towards well planning. - Transformation of a manual process to automated and smart In-house web interface application - Optimize well drilling based on best scenarios using offset wells data. - Extract insights from large amount of Data - Identify Different data sources. - Optimize Planning Time - Benchmark point for drilling optimization from real time data source. Method, Procedures, Process: There are various factors that contribute well planning in drilling such as complexity of the reservoir, safety measures, isolating problem areas, engineering, and the amount of data available. The whole process of well analysis takes a lot of time and efforts, as the method used is mostly manual. In this abstract, we explain the Big Data approach used to perform offset Well analysis for drilling a new well using an automated and smart In-house web interface application for generating the Offset wells analysis report. The solution Uses: EDM data as the main Drilling data management system. Uses GIS and Web based interface, various other data sources, reports and In-House system that host valuable information related to drilling. For losses map creation, cutoff values and a color coding mechanism are used to highlight wells and their losses criticality. For KPI’s benchmark, the application is linked to the RTOC database to provide insight for drilling targets and drilling optimization. The developed solution allowed the user to easily select the planned well and its coordinates, plot it instantly on the location map from GIS, retrieve and plot the offset wells and select nearby wells. Then, the system automatically reads those wells DDR's data from EDM, automatically applying the analysis logic and calculation algorithms to the data and generates a standard and consistent analysis report, that contained the predefined data elements and report layout. It allows the user to search through the DDRs easily by means of search feature, and highlighting keywords feature, then copy and paste within the report, allowing more customization and flexibility all within the same interface screen without the need to navigate to any of the other systems. Results / Conclusion: Make a “Simple” offset wells analysis - All the main drilling data is brought together. Transforms the process from manual to a “Dynamic and Automatic Reporting System” Enhance the Drilling Engineer performance & Planning Time optimization & communication, collaboration and knowledge sharing between the Teams. Build up the Drilling Division Offset Wells Data base. Assess to identify the potential areas of losses and the implementation of contingency plan. Provide the insight to the DE & DS for approach the targets drilling KPI’s from dynamic RTOC database.

Presenter
Roswall Bethancourt 300x300.jpg
Roswall Enrique Bethancourt Drilling Engineer ADNOC Onshore
  • 4 30 PM
Networking Reception (Delegate Lounge)
  • 6 00 PM
DAY 1 OF TECHNICAL CONFERENCE CONCLUDES FOR THE DAY
  • 7 30 AM
Registration
  • 8 30 AM

Reservoir Characterization Utilizing Pre-Inverted Seismic Volumes and Machine Learning

Geoscience

Fossil fuels, especially petroleum, have been projected to be the primary fuel source, supplying 30% of the world’s energy needs by 2035. Subsequently, to be able to support this demand, production...

  • locationPALOMINO ROOM A
  • small-arm8:30 AM - 9:00 AM
wednesday June 10, 2020
Geoscience

Reservoir Characterization Utilizing Pre-Inverted Seismic Volumes and Machine Learning

  • pr-alarm8:30 AM - 9:00 AM
  • pr-locationPALOMINO ROOM A

Fossil fuels, especially petroleum, have been projected to be the primary fuel source, supplying 30% of the world’s energy needs by 2035. Subsequently, to be able to support this demand, production of high-quality oil and gas is of paramount importance. Towards that goal, identifying potent and rich oil and gas reservoirs is key for operators as a means for sustaining the cost of operations. Consequently, being able to characterize the reservoir, followed by reservoir quality determination, then becomes the key steps in this pipeline. Reservoir characterization is the process of classifying the reservoir into its component minerals and fluids, which involves mapping signals acquired during well logging or seismic exploration to reservoir rocks and fluids followed by the classification process. While, well logging is a standard and well utilized technique in the petroleum industry, it involves drilling the well first, which, due to the inherent uncertainty surrounding the sub-surface space, may not be an entirely profitable decision, to begin with. As a result, 2D or 3D seismic is rapidly gaining ground as a reliable technology to map out the reservoir, especially for regions which do not have any wells and thus no available well logs. However, in spite of being a reputable resource for reservoir mapping, seismic interpretation requires multiple pre-processing steps (pre-stack to post-stack and then, post stack to post inversion) before an experienced geologist is able to characterize the reservoir. In this manuscript, a preliminary machine learning approach for reservoir characterization is proposed, based on post-stack, pre-inverted seismic volumes and available well logs. The method involves two steps: 1) using a machine learning based approach to label the seismic data utilizing all available well logs (co-located or otherwise) and 2) using a machine learning based approach to characterize or classify the reservoir based on the auto-generated labels. The advantages of this technique are: 1) reducing time and improving efficiency for geologists to be able to execute this pipeline faster and with greater repeatability, 2) an objective way of evaluating the results across big organizations, and 3) saving further time and effort by applying machine learning on the pre-inverted volumes as opposed to the commonly-used post-inverted volumes, thus reducing time and introduction of noise during the pre to post inversion conversion process. The novelty of this work lies around the use of a first-of-its-kind machine learning solution to characterize the reservoir based on pre-inverted seismic volumes. A couple case studies were carried out and the results prove the veracity of the proposed machine learning based technique by showing that the pre-inverted volumes can indeed be automatically used to classify or characterize the reservoir successfully.

Presenter
Sagar Neel Purkayastha New
Sagar Neel Purkayastha Senior Data Scientist and Senior Consultant IBM
  • 8 30 AM

Stranded Gas Utilization via Small Scale LNG

Field Development & Infrastructure

Stranded gas fields make up an estimated 40 ? 60% of the world’s current proven gas reserves and cannot be exploited usually due to either Geographical remoteness from consuming markets or unfavora...

  • locationPALOMINO ROOM B
  • small-arm8:30 AM - 9:00 AM
wednesday June 10, 2020
Field Development & Infrastructure

Stranded Gas Utilization via Small Scale LNG

  • pr-alarm8:30 AM - 9:00 AM
  • pr-locationPALOMINO ROOM B

Stranded gas fields make up an estimated 40 ? 60% of the world’s current proven gas reserves and cannot be exploited usually due to either Geographical remoteness from consuming markets or unfavorable Economics through conventional development approach due to insufficient Gas Reserves. This has resulted in a drive to develop technologies to allow efficient and cost-effective monetization of these Resources. Using a case study of a field in Kalimantan, Indonesia with 25 MMSCFD production potential as base case, this project reviews Market dynamics, evaluates virtual pipeline applications for gas distribution, available technologies and explores value chain to identify best offering to deliver gas to Market. Study further analyzes the Economic viability of chosen LNG small-scale solution with focus on key parameters including project CAPEX, OPEX, Gas volumes and realizable gas sales price and their impact on project Economic indicators. Economic analysis of the base case shows project is only marginally positive, but can be improved through capacity upscaling when more gas supply from neighboring fields become available, so modularized package type plants can offer advantages in terms of flexibility for future integration. This ensures that the system is optimally sized at all times, allowing minimization of CAPEX. All the economic analysis indicator show that the project is profitable at the moment (NPV 10% = 8.47 MMUSD, IRR = 11.1%, payback period is 9.3 year). Sensitivity analysis shows that production, gas prices and CAPEX give great impact into economic viability of the project. There are two ways to make the project more profitable: Field management is one of the most essential solution (current recovery factor is 66%, the operator must increase recovery factor or must find additional gas sources to increase daily production of the project). Operator also need to control CAPEX very strictly to keep the project profitable during both development phase and production phase. It was found that this business case has demonstrated project viability, through small scale LNG. Moreover, it can be illustrated that the production, price and capital expenditure have massive impact into economic viability. Likewise, the project profitability can be improved by integrated field management and additional gas supplies. Furthermore, with anticipated growth in gas demand, small scale LNG is expected to play a bigger role in the future in monetizing stranded gas. In addition to that, the integrated value chain approach and development concept can be adapted to utilize not only similar stranded field opportunities but also flared gas resources. Finally, exploiting and developing the micro-LNG business could provide added enhancement in the oil and gas industry as it could possibly be replacing diesel and fuel oil with natural gas which will have a huge positive environmental impact in terms of reduced greenhouse gas emissions. "

Presenter
Dwi Nuraini Siregar 300x300.jpg
Dwi Nuraini Siregar Project Management Staff SKK Migas
  • 8 30 AM

The Future Workforce of Oil & Gas

People & Talent

OBJECTIVE To review how advancements in tech and the demand for digital skills will shape the future workforce landscape of oil & gas. METHODS Primary research: Industry key informant interviews a...

  • locationPALOMINO ROOM C
  • small-arm8:30 AM - 9:00 AM
wednesday June 10, 2020
People & Talent

The Future Workforce of Oil & Gas

  • pr-alarm8:30 AM - 9:00 AM
  • pr-locationPALOMINO ROOM C

OBJECTIVE To review how advancements in tech and the demand for digital skills will shape the future workforce landscape of oil & gas. METHODS Primary research: Industry key informant interviews and focus groups. Secondary research: LMI forecasting and trend analysis RESULTS While it is not necessarily true that all jobs that can be automated, will be, a recent report identified that automation driven by technologies like AI and robotics can lead to more than 350 million workers globally needing to acquire new skills or even shift occupational categories by 2030. NOVEL/ADDITIVE INFORMATION How will our advancements in laser scanning, the creation of digital twins, and VR serve the welding inspector of tomorrow and enable a global expansion of their services right from there home in Red Deer, AB? The opportunity for marrying human industrial experience and soft skills with tomorrow's technology will allow regional experts to open up their skills to the global market in a way they've never been able to before as the energy sector fully enters the digital age. Economic diversification is a long-held pillar of resilient economies around the world and current strong investments in technological enhancement and digitization are proving to be one of the best levers for both public and private sectors to consider. These investments are undoubtedly changing the employment landscape though, especially in the energy sector where companies are being forced to fight for key digitally-skilled labour to complete with an increasingly competitive global economy that has begun to value data as much as oil. Around the world, businesses are looking to automation as a solution for enhancing efficiencies, boosting productivity, and ultimately, growing profit margins in an increasingly competitive global marketplace (ex. the unmanned oil rigs). While it is not necessarily true that all jobs that can be automated, will be, a recent report identified that automation driven by technologies like AI and robotics can lead to more than 350 million workers globally needing to acquire new skills or even shift occupational categories by 2030. In a future shaped by ongoing change, an agile and adaptable workforce is essential. Software developers, data scientists, cybersecurity analysts, and other highly-skilled roles will be crucial in building, supporting, safeguarding, and commercializing not only our digital economy but our energy sector and non-digital experts as well. The growing emergence and falling costs of IoT devices, AI, advanced data analytics, cloud storage, and satellite imaging tech will bring to the forefront questions related to governance, infrastructure, mobility needs, environmental considerations, safety, resource discovery and many others. New opportunities will emerge not only for the emerging digital workforce but for our industrial experts, especially for those that understand how to successfully marry data with oil.

Presenter
Tyler Farmer 300x300.jpg
Tyler Farmer Manager, Business Transformation & Partnerships Information Communication Technology Council (ICTC)
  • 9 00 AM

Unconventional Resource Potential of Ordovician Shales, Onshore Canning Basin, Australia

Geoscience

Theia Energy Pty Ltd (Theia Energy) discovered a potential unconventional hydrocarbon resource in the Ordovician Lower Goldwyer Formation shale and the Nambeet Formation located on the Broome Platf...

  • locationPALOMINO ROOM A
  • small-arm9:00 AM - 9:30 AM
wednesday June 10, 2020
Geoscience

Unconventional Resource Potential of Ordovician Shales, Onshore Canning Basin, Australia

  • pr-alarm9:00 AM - 9:30 AM
  • pr-locationPALOMINO ROOM A

Theia Energy Pty Ltd (Theia Energy) discovered a potential unconventional hydrocarbon resource in the Ordovician Lower Goldwyer Formation shale and the Nambeet Formation located on the Broome Platform of the onshore Canning Basin in North-western Australia. The collation, processing, analysis and interpretation of all available regional data culminated in a successful exploration well, Theia-1 (drilled in 2015), which, based upon petrophysical and core analyses, intersected a 70 m gross oil column within the Lower Goldwyer Formation at 1500?1570m depth. Theia-1 recovered essential core and wireline log data required to analyse and assess the play elements and reservoir properties necessary for a viable shale oil and gas development. Utilisation of an ‘Unconventional Play Element’ methodology has demonstrated the unconventional hydrocarbon potential of the Lower Goldwyer Formation, and preliminary modelling indicates that economic stimulated flow rates may be achieved. Moreover, Petroleum Systems Modelling utilising the results obtained from Theia-1 has also culminated in a high likelihood of success in the Nambeet Formation which may hold up to 700m of liquid-rich tight gas resources. Further operations (a test well with multi-stage hydraulic fracture stimulation of both the Lower Goldwyer and Nambeet Formations) are scheduled in the coming permit year to further quantify the presence of extractable organic matter in the Lower Goldwyer and Nambeet Formations, assess hydrocarbon flow rates, determine fluid composition and appraise commercial viability. This paper will outline Theia Energy’s exploration campaign in the onshore Canning Basin starting with the regional evaluation, which encompassed all available geoscience data (offset wells, pre-existing seismic and potential analogue fields) and modern specialised shale analysis (sequence stratigraphy, paleogeography, geochemistry, unconventional petrophysics and petroleum systems modelling), to develop a robust regional geological model for the Canning Basin. Pre-drill analysis reduced exploration risk and successfully identified the key geological play elements essential for the successful Theia-1 exploration evaluation program. Early volumetric assessments, based on petroleum systems modelling of the Lower Goldwyer and Nambeet Formations, indicate that some 170 billion barrels of equivalent (boe) may have been retained within the Basin with preliminary prospective resource estimates ranging from 3 to 5 billion boe. This discovery is of strategic importance to Australia due to the potential size of the resource as well as the high liquids content distinguishing this resource from Australia’s other large gas resource plays. Keywords: chemo-stratigraphy, discovery, drilling, exploration, gas, geochemistry, geochemical analysis, geomechanics, Goldwyer, Nambeet, Great Sandy Desert, Broome Platform, Canning Basin, hydraulic fracturing, hydrocarbon resource, oil, palynology, petrophysics, play, shale, unconventional, Ordovician."

Presenter
Jop van Hattum 300x300.jpg
Jop van Hattum Chief Operating Officer Theia Energy Pty Ltd
  • 9 00 AM

Petronas Opportunity Management System ? Digital Way for Maturing and Realizing Production Opportunities"

Field Development & Infrastructure

Petronas Production Opportunity Management System, known as OMS is an integrated tool that captures, tracks and reports the progress of all production opportunities for an asset. OMS is a primary t...

  • locationPALOMINO ROOM B
  • small-arm9:00 AM - 9:30 AM
wednesday June 10, 2020
Field Development & Infrastructure

Petronas Opportunity Management System ? Digital Way for Maturing and Realizing Production Opportunities"

  • pr-alarm9:00 AM - 9:30 AM
  • pr-locationPALOMINO ROOM B

Petronas Production Opportunity Management System, known as OMS is an integrated tool that captures, tracks and reports the progress of all production opportunities for an asset. OMS is a primary tool supporting the opportunity management process and acts as a single point reference for all opportunities. For the assets which have various different potentials, the production rate of the assets can be increased by; 1) increasing potential (sub-surface capacity, production system capacity, commercial potential, etc.), and 2) reducing constraints (reservoir, well, utilization, commercial, deferment, etc. The OMS is developed to resolve constraints and unlock potential towards ultimate goals of to sustain production and ensure sales target is met. OMS has been completed in 2017 under the direction of Petronas Upstream Digital using the existing digital infrastructure. In the ecosystem of digital production solution, OMS is integrated with other solutions such as Field Performance Center (captures the subsurface potential for individual wells), Integrated Activity Planning (plan, integrate and optimize activities) and Integrated Production Performance Management (performance management dashboard). OMS system has been facing declining utilization rates since mid-last year due to non-intuitive user interface and limited functionalities, which decrease the users’ interface/ users’ experience (UI/UX). For a digital solution, UI/UX is important criteria in ensuring its utilization and sustainability. Due to this low utilization, the company was losing opportunities for production growth and risk not meeting sales target. Well performance data from Field Performance Centre was unable to be matured and analyzed for improvement opportunities. However, due to the low utilization of the system, none of the opportunities were tracked and executed. Realizing the value leakages due to low utilization, a team under Center of Excellence have initiated revamping the system. They began by collecting feedback from the end users on ways to improve the system and increase take-up rates. The close out of action items based on users’ feedback are expected to increase take up rate and sustain utilization of OMS by the users. The team are also working on change management to initiate change to the current batch of users, set new mindset for digital solution and prepare users with new capability in adapting new system as a new way of working. The enhancement efforts are expected to result in completing all outstanding action items, increase high users’ take-up rate and utilization, creating effective monitoring of opportunity maturing process, providing opportunities efficient decision making process based on integrated solutions and the most importantly, elevating digital as the new way for maturing and realizing production opportunities.

Presenter
M. Amirulnizam Ahmad 300x300.jpg
M. Amirulnizam Ahmad Head Production & Operations Petronas Carigali
  • 9 00 AM

The Oil & Gas Industry Approach to Indigenous Reconciliation in Canada

People & Talent

Mutually beneficial relationships with Canada’s Indigenous Peoples are critical to the success of Canada’s energy industry. And, it turns out, industry is critical to theirs too: the Canadian Asso...

  • locationPALOMINO ROOM C
  • small-arm9:00 AM - 9:30 AM
wednesday June 10, 2020
People & Talent

The Oil & Gas Industry Approach to Indigenous Reconciliation in Canada

  • pr-alarm9:00 AM - 9:30 AM
  • pr-locationPALOMINO ROOM C

Mutually beneficial relationships with Canada’s Indigenous Peoples are critical to the success of Canada’s energy industry. And, it turns out, industry is critical to theirs too: the Canadian Association of Petroleum Producers (CAPP) reports that in 2015-16, the upstream industry procured $3.3B in goods and services from oil sands operators, working with 399 companies and 65 different communities. When safety and environmental issues were first recognized as important to the industry a generation ago, they were at first addressed as “bolt-on” matters but are now considered integral to all work activity. This presentation will argue that the same sort of integration is necessary to ensure industry consistently and effectively partners with Indigenous people. The presentation will discuss the socioeconomic strategy taken by an oil and gas company in Canada that both progresses Reconciliation with Indigenous people and builds competitive advantage. It will frame this approach as the right thing to do that also makes business sense. An Indigenous strategy built on the four pillars of workforce, business development, consultation and community relations will be described. A model to structure more formal communication between proponants and Indigenous groups will be put forward. Sharing examples of recent work progressed under each of these pillars, the presentation will illustrate some real progress towards shared prosperity, making the case that it is possible and that by working together in partnership with Indigenous communities, resources can be sustainably developed. The presentation will conclude with lessons learned, and thoughts about the path forward. The presentation will challenge industry to think about their role in Reconciliation, and, more broadly with all local communities. It will encourage thinking and action to be integrated throughout the full life cycle starting with project planning, construction, ongoing operations and through to final decommissioning and reclamation.

Presenter
Helga Shield 300x300.jpg
Helga Shield Environment, Regulatory & Socioeconomic Manager Imperial
  • 9 30 AM

Innovative Ring for Improved MWD

Geoscience

The development of Logging while drilling (LWD) and measurement while drilling (MWD) techniques started late 1970s as part of many efforts to support and enhance the decisions being made during com...

  • locationPALOMINO ROOM A
  • small-arm9:30 AM - 10:00 AM
wednesday June 10, 2020
Geoscience

Innovative Ring for Improved MWD

  • pr-alarm9:30 AM - 10:00 AM
  • pr-locationPALOMINO ROOM A

The development of Logging while drilling (LWD) and measurement while drilling (MWD) techniques started late 1970s as part of many efforts to support and enhance the decisions being made during complex rotary drilling operations. LWD and MWD procedures can provide a snapshot of data relating to the drilling operations and the conditions of the well, such as weight on bit (WOB), porosity, resistivity, formation pressure, borehole inclination and azimuth, and other formation properties and drilling mechanics information. In some currently available systems the MWD and LWD tools are attached to the bottom hole assembly and provide a discrete snapshot of the information only as the bottom hole assembly passes through the formation. Such currently available systems are unable to capture logging and measurement data at a target location after the bottom hole assembly has already passed through such a target location. Conditions within a well can change over time. We propose systems and method that are able to capture such changes by providing continuous, intermittent, or on demand real time logging or measurement data. The proposed systems and methods provide a ring assembly that can be secured around the tubular string and lowered from the surface at any time during drilling or post drilling operations. The ring assembly has measurement tools for gathering logging and measurement data. The ring assemblies can also perform intervention operations on the tubular string, bore of the subterranean well, or the formation. An internal scanner can assess the tubular string. Wheels that are located on an inner diameter of the ring assembly can allow for the ring assembly to move over joint connections and other obstructions along the tubular string. The ring assemblies can be deployed in arrays and can move both uphole and downhole, as desired, for gathering the logging and measurement data.

Presenter
Abdulaziz Al-Qasim 300x300.jpg
Abdulaziz Al-Qasim Champion of CCUS/EOR M&S Saudi Aramco
  • 9 30 AM

Advanced Remote Monitoring

Field Development & Infrastructure

Objectives: • Update audience on the most current trends and applications in securing the Energy Critical Infrastructure in Oil and Gas in the Energy Sector from a Physical Security, Process Secu...

  • locationPALOMINO ROOM B
  • small-arm9:30 AM - 10:00 AM
wednesday June 10, 2020
Field Development & Infrastructure

Advanced Remote Monitoring

  • pr-alarm9:30 AM - 10:00 AM
  • pr-locationPALOMINO ROOM B

Objectives: • Update audience on the most current trends and applications in securing the Energy Critical Infrastructure in Oil and Gas in the Energy Sector from a Physical Security, Process Security and Safety Security standpoint. • Discuss current remote monitoring techniques for upstream, midstream and downstream including turnkey equipment, connectivity and solar power/data management. • Discuss sensor evolution to help achieve data acquisition and SCADA verification for remote processing and critical asset monitoring • Mitigating the cyber threat. Scope: The Scope of the discussion will focus on the evolution of the IP security cameras where they have come and what to expect in the next 5 years from a usability standpoint. A breakdown of advanced analytics in both physical and process security and safety. Introduction of turnkey solutions geared for the oil and gas industry in the Energy Sector for Class 1 Div. 1 Zone 1 areas. Lastly mitigating your cyber risk. Methods and Procedures and process IP Security cameras have become so much more than just a device that provides a video Image. Today’s IP cameras is a computer with a highly developed optical lens system. Today’s IP camera can take an image in the form of data and extract information from analytics and algorithms and then correct the image data through processing to make what was once and unusable image to a very usable image. New compression technology cuts band width requirements to make remote monitoring now less costly. Axis Communications overall approach is to develop solutions related to the O&G industry for Physical, Process and Safety Security using various IP Sensors and Ecco Partners to make the world a smarter-safer place. Results Observations and Conclusions Utilizing sensors like radar, IP visible and thermal cameras IP Speakers, IP Audio and analytics on the edge of the devices or server based can protect your Perimeter and Sub Perimeter areas better than ever before. Utilizing the processing ability of both visible camera sensors 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 and 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 and all areas offer a layered approach for personnel monitoring in entry/exit points and critical sub perimeter areas. 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 Physical, Process and Safety Security.

Presenter
Joe Morgan 300x300.jpg
Joe Morgan Segment Development Manager-Critical Infrastructure Axis Communications, Inc.
  • 9 30 AM

Human Factors Impact on Industry and the Environment

People & Talent

New technology is evolving rapidly, creating new environmental and industrial challenges that must be considered. Technology continues to focus on the demands of industry to increase efficiency an...

  • locationPALOMINO ROOM C
  • small-arm9:30 AM - 10:00 AM
wednesday June 10, 2020
People & Talent

Human Factors Impact on Industry and the Environment

  • pr-alarm9:30 AM - 10:00 AM
  • pr-locationPALOMINO ROOM C

New technology is evolving rapidly, creating new environmental and industrial challenges that must be considered. Technology continues to focus on the demands of industry to increase efficiency and production output. At the same time, industry must quickly adapt to these new advances in order to compete and grow and yet also must focus on increased awareness for the need to evaluate and mitigate environmental impact. Recent studies indicate that the use of automation in the workplace will nearly double in the next few years. If we look at the control room as being the core of the industrial environment, the focus has been mainly centred on the advances in technology. Little focus has been on the humans that control this technology ? there is still not enough consideration for the most critical component that can not only impact production and output but also create a negative impact on the environment as a result of human error. With Industry 4.0 focusing on the latest and greatest technology, the concern is that the human involved in developing, implementing and monitoring this technology will be overshadowed by technology itself. No matter how quickly technology advances, it will always ultimately be controlled by humans. And human error must be mitigated ?" one mistake can result in huge and in some cases irreversible environmental damage. The increasing need for a focus on the psycho-social work environment must be considered. The challenge in today’s industrial control room environment is not only with the transition to more technologically advanced operations, but also to the need for more technologically advanced operators as a result. However, at the same time, the risk of human error must be mitigated ?" one mistake can result in huge and in some cases irreversible environmental damage. How has this critical element been downplayed to a point that it is almost non-existent when evaluating environmental risk? The purpose of this presentation is to take a step back and identify some key considerations of human factors within the control room, and how ignoring this critical element can impact not only production but also the environment. What is being lost in the rapid changes we are facing in this newest phase of the industrial revolution is the impact of the control room environment on the human, and the resulting potential negative impact of the human on the environment."

Presenter
Fiona Campbell
Fiona Campbell Senior Consultant Control Room Design and Human Factors ABB AB
  • 10 00 AM
Coffee Break & Visit Exhibition
  • 10 30 AM

Decision Making in Pipeline Operations using Big Data

Pipeline & Processing Facilities

Pipeline Operations may involve complexities that require robust decision making to generate optimal results. These complications may be due to involvement of multiple products, received from vario...

  • locationPALOMINO ROOM A
  • small-arm10:30 AM - 11:00 AM
wednesday June 10, 2020
Pipeline & Processing Facilities

Decision Making in Pipeline Operations using Big Data

  • pr-alarm10:30 AM - 11:00 AM
  • pr-locationPALOMINO ROOM A

Pipeline Operations may involve complexities that require robust decision making to generate optimal results. These complications may be due to involvement of multiple products, received from various sources and delivered to numerous locations with ever changing dynamics. These dynamics such as, Products supplies, intermix handling, operational constraints, product quality assurance, custody transfer issues, condition of Installations, machinery and equipment performance, pipeline safety, fluctuating product demands, inventory costs etc., added to aforementioned operational permutations makes a challenging task. These scenarios demand that all decision making should be made by dynamic computations involving processing of large amount of data being generated at each instance from multiple variables. Scheduling of Multi batch Pipeline Operation depends on various factors such as Ocean Tankers schedule, readiness of products at Local refineries and terminals, possibility of simultaneous receiving operations, maintenance schedules, capacities of storage tanks relying on the market demands, Transmix generation and its processing capacities at delivery end. This presentation outlines how operational constraints can be avoided by developing algorithms which processes available data and predicts for upcoming days, batch positions, passing quantities of each product through intermediate terminals/stations, stock positions at delivery stations, Transmix generation in Multiproduct pipeline and load of Transmix processing facilities. Such programs ensure hassle free operation, preventing Pipeline and Client companies from any disturbances in supply chain. The presentation will also discuss the analysis of chronological changes in Storage tanks` shell due to extensive operations and ambient pressures. For this purpose, data collected from previous and revised tank calibrations is compared and volumetric change at each levels is determined. Considering these differences at various levels of tanks, planning of receipt and delivery operations involving custody transfer can be worked out accordingly, resulting in considerable positive variances. Pipeline Operation often involves pumping of such products whose demands have seasonal patterns usually depending on agricultural transportation and machinery usage. Moreover, annual demands may also over the period of time, change according to variance in industrial activities, technological advancement altering product demands and other reasons. Accurate forecasting of such trends helps in earliest planning of carrying out critical projects giving competitive edge. By computationally observing the data, impact of various chemicals used during pipeline operations such as Drag Reducing agents can be analyzed, and predicted. This helps in optimal utilization of such costly chemicals depending on flow rate requirements. As they say “Proper prior planning, prevents poor performance”. Using these examples, this paper/presentation discusses how various aspects of pipeline operations can be managed and optimized through analyzing and processing data acquired during these operations. Such optimization may contribute towards ease of operations, cost savings, best utilization and allocation of resources, foreseeing market patterns, future projects requirements, and predictive maintenance enabling pipeline transportation company.

Presenter
Mohsin Ali Khan 300x300.jpg
Mohsin Ali Khan Oil Movement Engineer Pak Arab Refinery Limited
  • 10 30 AM

Fracking Clean-Up Strategies and ALS Multi-Layer Well´s Design in Waterflooding Recovery Development

Field Development & Infrastructure

The purpose of this paper is to show the different strategies carried out to optimize completion times and select the appropriate ALS design during the development of a new secondary pattern. Havin...

  • locationPALOMINO ROOM B
  • small-arm10:30 AM - 11:00 AM
wednesday June 10, 2020
Field Development & Infrastructure

Fracking Clean-Up Strategies and ALS Multi-Layer Well´s Design in Waterflooding Recovery Development

  • pr-alarm10:30 AM - 11:00 AM
  • pr-locationPALOMINO ROOM B

The purpose of this paper is to show the different strategies carried out to optimize completion times and select the appropriate ALS design during the development of a new secondary pattern. Having Slim well completed in 5 ½ casing and Multilayers produced in commingle. San Jorge Gulf basin has multilayer reservoirs that have high declination rates and poor petrophysics properties, in which bind to make a considerable amount of fractures per well. Fracturing requires cleaning which increases time to completion. The challenge is to improve fracture-cleaning performance during completion with ESP instead of Swabbing method which is normally done in our operation. Also to select considering test data acquired, the appropriate ALS to extract efficiently the primary production and the subsequent water flooding response. This method was run in two areas in order to analyse and compare costs, consumption, rig-times and well performances. Also, this technique allows to change completion strategies by saving rig hours and choosing the appropriate ALS for the wells in the long term. In addition, in a few cases the cleaning ESP has kept as ALS with acceptable average run-life expectations. Another challenge of this experience is to assess if its method reduces skin effects (or formation damage) caused by completion fluid exposition time. This paper will show the experience and technical and economical advantages of using ESP as cleaning method to reduce completion time and cost, alternative to swabbing /plug and packer and improve fracking flowback recovery. Opex reduction by mean of ALS runlife increase, ensuring a better well cleaning during its evaluation. Better well characterization (like multilayer combined production index) for proper ALS selection. Downtime reduction and Improve the early oil production

Presenter
Ricardo Teves 300x300.jpg
Ricardo Teves Sr. Engineering Manager Baker Hughes
  • 10 30 AM

Monetization of Assets

Technical Panel Session

Speakers to be announced.

  • locationPALOMINO ROOM C
  • small-arm10:30 AM - 12:00 PM
wednesday June 10, 2020
Technical Panel Session

Monetization of Assets

  • pr-alarm10:30 AM - 12:00 PM
  • pr-locationPALOMINO ROOM C

Speakers to be announced.

  • 11 00 AM

Ultrasonic Health Monitoring and Predictive Analytics

Pipeline & Processing Facilities

The objective of this paper is to increase efficiency and reliability of pipeline system by using data driven technology to maximize asset utilization and achieve compliance with regulatory standar...

  • locationPALOMINO ROOM A
  • small-arm11:00 AM - 11:30 AM
wednesday June 10, 2020
Pipeline & Processing Facilities

Ultrasonic Health Monitoring and Predictive Analytics

  • pr-alarm11:00 AM - 11:30 AM
  • pr-locationPALOMINO ROOM A

The objective of this paper is to increase efficiency and reliability of pipeline system by using data driven technology to maximize asset utilization and achieve compliance with regulatory standards, and Industry best practices. Ultrasonic flow meter (UFM) with its unique performance characteristics plays a critical role in the leak detection system which ensures the ability to detect a pipeline leak quickly, efficiently, and reliably. Currently UFM has been identified as a significant contributor to issues in the LD system leading to degradation of LD system and revenue loss to pipeline operators. The UFM data and alarms provide critical information to various stakeholders throughout the organization, such as Leak Detection, Control Center Operations, and Instrumentation & Process groups. Depending on the criticality, an alarm shall trigger various workflows such as: shutting down the pipeline, dispatching a maintenance crew to the effected meter, and manually verifying if the alarm event is actual or false. All these actions cost money in term of revenue, extended shutdowns and resource allocation, which can be either curtailed or minimized by using advanced data analytics on the available records and data. This shall also help the company in shifting from reactive to proactive maintenance and ensure optimum performance of its UFM assets. This paper describes the metrics developed to monitor health and performance of UFM assets. Successful implementation of this initiative shall lead to performance learning and failure pattern diagnostics. This enables operators to forecast UFM performance and predict UFM failure on the mainline and terminal network in the future.

Presenter
Noman-Rasool-300x300
Noman Rasool Specialist Measurement and Leak Detection Enbridge Inc.
  • 11 00 AM

Duvernay Oil: Resources, Costs, and Production Forecast

Field Development & Infrastructure

The Duvernay shale formation in Alberta contains between 1.6 and 5.6 billion barrels of oil resources. These resources are less than in Permain, Bakken, Eagle Ford and Niobrara, however size of the...

  • locationPALOMINO ROOM B
  • small-arm11:00 AM - 11:30 AM
wednesday June 10, 2020
Field Development & Infrastructure

Duvernay Oil: Resources, Costs, and Production Forecast

  • pr-alarm11:00 AM - 11:30 AM
  • pr-locationPALOMINO ROOM B

The Duvernay shale formation in Alberta contains between 1.6 and 5.6 billion barrels of oil resources. These resources are less than in Permain, Bakken, Eagle Ford and Niobrara, however size of the resource assessment will grow as Duvernay exploration and development continues. The presentation includes geological description, resource assessment, analysis of full cycle cost, as well as production, well count, initial productivity and rig count forecast. The presentation is particularly focused on Duvernay East (East Shale basin). Production forecast for Divernay oil is performed based on analysis of full cycle cost associated with certain resources based on assumptions that development will focus on areas with lower full cycle cost. In order to assess Duvernay oil resource areas associated with different ranged of new well initial productivity were estimated. The full cycle cost, including finding and development cost, operating cost, basis differential, cost of capital, and overhead was estimated for these ranges. In order to forecast basis differentials to WTI detailed analysis of existing and future pipeline infrastructure for light oil and condensate was performed. The average initial productivity for Duvernay oil wells and estimated ultimate recovery are lower than in Permian, Bakken, and Eagle Ford. Duvernay oil average full-cycle cost is around 43.80 USD/bbl, which includes the price differential to WTI. Since Duverney produces light oil the basis differential is lower than differential for heavy oil. This full cycle cost and differential is expected to remain within flat until 2022. This average full-cycle cost is only slightly higher than in the Permian and Bakken and very close to full cycle cost of Eagle Ford and Niobrara. There are a number of factors, which improve economics of Duvernay oil. Most Duvernay oil wells produce condensate, which is used as a diluent for heavy oil pipeline transportation. In addition Duvernay oil well economics benefit from a relatively low average royalty rate and low Canadian dollar. The number of Duvernay oil wells drilled before August 2019 totals approximately 250. Due to the Alberta government’s production curtailment over a lack of pipeline capacity less than 50 oil wells are expected to be drilled in the Duvernay in 2019. Once pipeline constraints are resolved and the price differential narrows. As a result Duvernay full-cycle cost will be comparable to the Permian, and Bakken plays. The production will start to grow after 2022. The analysis shows that Duvernay oil production will reach 300M bbl/d in 2030.

Presenter
Lev Virine.png
Lev Virine Manager, Consultant HSB Solomon Associates Canada
  • 11 30 AM

Novel Ammonia Refrigeration Compared to Traditional Propane Refrigeration for Natural Gas Liquids Recovery

Pipeline & Processing Facilities

Colin Nikiforuk, PTX Technologies Inc., Calgary, AB Jared Peterson, PhD, Bryan Research and Engineering, LLC, Bryan, TX Taylor Delk, Bryan Research and Engineering, LLC, Bryan, TX While the price...

  • locationPALOMINO ROOM A
  • small-arm11:30 AM - 12:00 PM
wednesday June 10, 2020
Pipeline & Processing Facilities

Novel Ammonia Refrigeration Compared to Traditional Propane Refrigeration for Natural Gas Liquids Recovery

  • pr-alarm11:30 AM - 12:00 PM
  • pr-locationPALOMINO ROOM A

Colin Nikiforuk, PTX Technologies Inc., Calgary, AB Jared Peterson, PhD, Bryan Research and Engineering, LLC, Bryan, TX Taylor Delk, Bryan Research and Engineering, LLC, Bryan, TX While the price of natural gas remains low, liquids recovery from natural gas will remain crucial to operational profitability. There is often a need for mechanical refrigeration in gas processing facilities, especially when an inlet gas is rich with heavier hydrocarbons. If the mechanical refrigeration system can be further optimized, a gas processing facility stands to make substantial savings while maintaining their liquids recovery or even increasing it. The first consideration when optimizing a refrigeration system is the choice of refrigerant. While ammonia has not traditionally been used as the refrigerant in mechanical refrigeration systems, a novel configuration allows ammonia to reach lower operational temperatures than it has in the past. This work compares the traditional propane refrigeration system to an innovative configuration of an ammonia absorption refrigeration system. Using process simulation to compare the two systems, this work then determines the differences in utility requirements, achievable recoveries of propane, and necessary construction materials before estimating capital and operating costs of the two systems.

Presenter
Taylor Delk 300x300.jpg
Taylor Delk Consulting Engineer Bryan Research and Engineering LLC
  • 11 30 AM

A Targeted Catalytic Approach Towards Reducing Diluent in Oil Sands Processes

Field Development & Infrastructure

Sivaram Pradhan*, Michael Shammai, Jacob Gibson, Manjusha Verma, Amin Haghmoradi, Kyle Cattanach, Scott Henshaw, Harry ‘Wade’ Bullock Recent growth of bitumen production in the Oil Sands has outp...

  • locationPALOMINO ROOM B
  • small-arm11:30 AM - 12:00 PM
wednesday June 10, 2020
Field Development & Infrastructure

A Targeted Catalytic Approach Towards Reducing Diluent in Oil Sands Processes

  • pr-alarm11:30 AM - 12:00 PM
  • pr-locationPALOMINO ROOM B

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

Presenter
Sivaram Pradhan 300x300.jpg
Sivaram Pradhan Lead Scientist Nextstream
  • 12 00 PM
Lunch & Visit Exhibition
  • 1 30 PM

Methane Recovery for Low Producing Marginal Gas Field with Pressure Swing Adsorption (PSA)

Pipeline & Processing Facilities

In 2018, Indonesia's natural gas consumption increased by 0.4 million tons of oil equivalent from the previous year and met 18.06% of national energy needs. This increase in consumption causes the...

  • locationPALOMINO ROOM A
  • small-arm1:30 PM - 2:00 PM
wednesday June 10, 2020
Pipeline & Processing Facilities

Methane Recovery for Low Producing Marginal Gas Field with Pressure Swing Adsorption (PSA)

  • pr-alarm1:30 PM - 2:00 PM
  • pr-locationPALOMINO ROOM A

In 2018, Indonesia's natural gas consumption increased by 0.4 million tons of oil equivalent from the previous year and met 18.06% of national energy needs. This increase in consumption causes the development of marginal oil and gas fields to be re-evaluated. Marginal oil and gas fields with small amounts of natural gas production, ranging from 1-4 MMSCFD and high CO2 levels (30-60%) cannot further utilized and only burned before being flared into the atmosphere. CO2, as well as H2S and other acid gases, must be removed from natural gas because in the presence of water these impurities can form acids that corrode pipelines and other equipment. CO2 needs to be reduced because it can increase global warming, reduce energy content and selling value of natural gas. Amine absorption technologies for CO2 and H2S removal (acid gas treating) are well-established in the natural gas industry and is expected to remain the first choice in gas processing technology in the future, but this technology is not applicable for marginal gas fields with small production. To overcome this, Pressure Swing Adsorption (PSA) can be used as an alternative method of separating CO2 from natural gas to obtaining pipeline-quality methane and integrated CO2 capture. Pressure Swing Adsorption with zeolite based adsorbent was applied at the Randegan structure in Jatibarang Field PT Pertamina EP Asset 3 to process natural gas with a CO2 content of 40% mol. Results showed that 69% hydrocarbons was recovered with CO2 content in the lean gas is 0.2 - 0.74% mol. It is expected that hydrocarbon recovery can be improved by choosing better adsorbents or by using dual PSA technology.

Presenter
Wiwin Lukman 300x300.jpg
Wiwin lukman Febrianto Process Engineer PT Pertamina EP
  • 1 30 PM

Automatic Production Forecasts Generated by a Data-Driven Model Can Indeed by Trusted

Reservoir Engineering

Objectives/Scope: The oil and gas industry’s technological innovation over the last 150 years is truly astonishing, which is why our somewhat slow adoption of analysis methods that fall under the b...

  • locationPALOMINO ROOM B
  • small-arm1:30 PM - 2:00 PM
wednesday June 10, 2020
Reservoir Engineering

Automatic Production Forecasts Generated by a Data-Driven Model Can Indeed by Trusted

  • pr-alarm1:30 PM - 2:00 PM
  • pr-locationPALOMINO ROOM B

Objectives/Scope: The oil and gas industry’s technological innovation over the last 150 years is truly astonishing, which is why our somewhat slow adoption of analysis methods that fall under the broad artificial intelligence umbrella is so surprising. Petroleum engineers and geoscientists have collected tens of billions of data points from hundreds of thousands of data sources over the decades, but when it comes to using that data to train machines and models that generate actionable, trustworthy insights, the industry falls short. At the core of this study is a data-driven, fully automatic, probabilistic model that generates production forecasts. The Model was put head-to-head against a 3rd-party team of geoscientists and engineers to evaluate the EUR for over 400 oil pools (> 13,000 producing oil wells) across Alberta. The questions investigated were as follows: • Did the Model generate reliable and accurate forecasts/EURs (compared to the team of humans)? • Will this technology take my job away? Methods, Procedures, Process: The EUR for the 424 oil pools were evaluated by a team of professionals at the AER (with the results published in its annual ST98: Alberta Energy Outlook report). The same 424 oil pools were evaluated by the Model using identical production data inputs. The per cent difference between the EUR results was calculated and compared using the traditional percent error bins. The AER’s EUR results were also compared to the Model’s decile confidence intervals for a more in-depth comparison. A number of outliers (where the EUR delta was significant) were studied in more detail to identify reasons why. Results, Observations, Conclusions: Of the 424 pools, 162 (38%) of them fell inside the ±5% difference bin, and 289 (68%) of them fell within ±15% of each other, which we found quite remarkable. When we put the AER team’s results into bins defined by the Model’s probabilistic confidence intervals, we saw that 58% of them fell within the Model’s P40 and P60 results, and 81% of the cases fell within its P30 and P70. The case study concluded that the Model can generate realistic results that can indeed be trusted; expedite the time it takes to make informed decisions, and save time and money. Novel/Additive Information: The paper addresses the trust factor that often makes it difficult for our industry to adopt disruptive technologies that generate answers with little human intervention. Previous works have not put a machine head-to-head against a team of experienced engineers and geoscientists to evaluate technical reserves over a scope of over 400 oil pools (or 13,000 oil producing wells). This unique approach illustrates the benefit of using such predictive analytical forecasting tools in everyday

Presenter
Alex Renaud 300x300.jpg
Alex Renaud Senior Engineering Advisor geoLOGIC systems ltd.
  • 1 30 PM

The Impact on Carbon Emissions in Downstream through Applied AI

Post Production

This session will discuss the challenges of reducing carbon emissions in the midstream and downstream sectors of the Energy industry, and how these challenges may be met through newer IIoT applicat...

  • locationPALOMINO ROOM C
  • small-arm1:30 PM - 2:00 PM
wednesday June 10, 2020
Post Production

The Impact on Carbon Emissions in Downstream through Applied AI

  • pr-alarm1:30 PM - 2:00 PM
  • pr-locationPALOMINO ROOM C

This session will discuss the challenges of reducing carbon emissions in the midstream and downstream sectors of the Energy industry, and how these challenges may be met through newer IIoT applications. By digitalizing and creating dynamic energy profiles of equipment and operational processes such as heating or blending, operators gain real-time visibility, and a much more detailed understanding of energy use. Predictions of electricity usage are made by applying artificial intelligence-based analytics, using forecasted activities for the plant, while taking into account operational constraints such as production requirements or schedules based on customer delivery timelines. Optimization algorithms are applied to smooth peak energy use and reduce overall energy use, thus reducing energy costs as well as the carbon emissions. Similarly, AI-based steam demand predictions, coupled with optimized supply-side sourcing reduces over-production of steam, thereby reducing greenhouse gas emissions. Case studies of digital innovation projects in the midstream and downstream sectors using applied AI will be shared, showing how energy optimization reduces electricity usage and steam over-production by 20% and 15%, resulting in lower costs and reduced environmental emissions.

Presenter
Ann Sun 300x300.jpg
Ann Sun VP, Market Development Atomiton
  • 2 00 PM

Phased Array Technology Serving Combo Metal Loss, Cracks & Dents Inline Inspection

Pipeline & Processing Facilities

As exposed in the 2018 Concawe Report N°6/18, pipeline operators are confronted with multiple sources of risk to pipeline integrity, including spillage incidents caused, for example, by mechanical...

  • locationPALOMINO ROOM A
  • small-arm2:00 PM - 2:30 PM
wednesday June 10, 2020
Pipeline & Processing Facilities

Phased Array Technology Serving Combo Metal Loss, Cracks & Dents Inline Inspection

  • pr-alarm2:00 PM - 2:30 PM
  • pr-locationPALOMINO ROOM A

As exposed in the 2018 Concawe Report N°6/18, pipeline operators are confronted with multiple sources of risk to pipeline integrity, including spillage incidents caused, for example, by mechanical failure, operational activities, corrosion, natural causes, third party activities or other factors. Over the years, technically advanced devices and non-destructive testing methodologies have been developed in order to reduce these risks. However, until recently, operators have been using individual inspection tools or very large size combined tools to detect and measure specific defects, such as lamination, corrosion, dent with or without metal loss or cracks. This means that operators around the world have to manage multiple inspection runs or alter facilities, requiring subsequent correlation of separate sets of inspection data. In order to avoid these unnecessary processes, to minimize costs, sources of error, operational conflicts and to improve safety, Trapil has designed and produced a new inline inspection tool, XTRASONIC-NEO. This new inline inspection tool is now available to liquid lines which can inspect for cracks and metal loss in a single pass. It is a single module ultrasonic tool, requiring no trap modifications or at least minimum modification costs for lines with short or no trap barrels. The tool is equipped with Phased Array sensors allowing to achieve - in a very compact design ? a comprehensive high resolution inspection of the pipeline. Indeed the tool is able to detect and finely characterize and discriminate geometry defects including dents, metal loss defects and cracks in a single run. Moreover, depending on the defects we are looking for, it is possible to preprogram the sensors before the inspection to send sound waves in different directions to achieve the needed detection. This means optimization of a pipeline’s inspection integrity budget to inspect a line with cracks, and later optimization of the maintenance and repair programs thanks to a better sizing and FFS analysis of defects made possible by the Phased Array technology. The first diameter was qualified in 2018 on the proprietary network of TRAPIL and it has already shown very promising results. The tool’s features and qualification process will be discussed in the paper as well as applications where it has proven to provide a unique benefit. "

Presenter
Manon Servais 300x300.jpg
Manon Servais Business Development Manager TRAPIL
  • 2 00 PM

Case Study: The Mature Field in Alberta - One's Trash is Another's Treasure

Reservoir Engineering

The landscape of WCSB field development has changed in last 10 years due to multi challenges operators facing: low oil price, high property tax, increasing burden on the liability, HSE standard req...

  • locationPALOMINO ROOM B
  • small-arm2:00 PM - 2:30 PM
wednesday June 10, 2020
Reservoir Engineering

Case Study: The Mature Field in Alberta - One's Trash is Another's Treasure

  • pr-alarm2:00 PM - 2:30 PM
  • pr-locationPALOMINO ROOM B

The landscape of WCSB field development has changed in last 10 years due to multi challenges operators facing: low oil price, high property tax, increasing burden on the liability, HSE standard required by regulator. Many of the conventional fields in WCSB have coming into the mature status: high water cut, high operating cost, low production, high liability, close to abandonment. There are many mature field asset are on the market to sell, but could be a painful or fatal deal for the buyers if not studied carefully. How to select and operate the asset with potential to realize the high return to the shareholder? We believe that the operators who focus on the cost optimization with lowest capital/operating cost are the ultimate winners. This case study illustrated how to increase the case field oil production from 80 bopd to 1200 bopd in less than one year through integrated work flow including detailed geological and reservoir study, field production optimization, horizontal drilling, practical well completion, facility upgrading, pipeline bottleneck solving to achieve field records production. The capital cost optimization started with development planning, well placement and completion design, worked through drilling and completion operation efficiency improvement. The asset reserve volume and value increased multi fold, achieved the highest production rate and lowest operating cost in asset development history. Mostly importantly the asset delivered the overall investment return to the shareholders.

Presenter
Minglin Li 300x300.jpg
Minglin Li VP Reservoir and Production Rockeast Energy Corp
  • 2 00 PM

Partial Upgrading in Alberta - Still on the Horizon?

Post Production

Background The Province of Alberta has contemplated options on how to monetize its vast bitumen reserves for over thirty years. Two possible options are to upgrade the bitumen to higher value produ...

  • locationPALOMINO ROOM B
  • small-arm2:00 PM - 2:30 PM
wednesday June 10, 2020
Post Production

Partial Upgrading in Alberta - Still on the Horizon?

  • pr-alarm2:00 PM - 2:30 PM
  • pr-locationPALOMINO ROOM B

Background The Province of Alberta has contemplated options on how to monetize its vast bitumen reserves for over thirty years. Two possible options are to upgrade the bitumen to higher value products or export the unconverted bitumen directly. The first option requires significant capital outlay. The second option requires the addition of diluent or keeping the bitumen at elevated temperatures to meet pipeline specifications, (driven primarily by viscosity). Most Alberta bitumen is currently exported as dilbit, i.e. bitumen with added diluent. Diluent is expensive, and in many instances, producers are forced to recycle the diluent back to Alberta. This requires significant incremental infrastructure including a return diluent pipeline and storage facilities. The added diluent also takes away approximately 30% of the pipeline capacity to deliver the bitumen to market. The viability of full upgrading requires a minimum price differential of $30+ between WTI and WCS. A differential of $30+ has not been seen for some time, and future predictions do not support any positive investment decisions. A third option, Partial Upgrading has been considered by various parties for some time. There are two basic premises which differentiate Partial Upgrading: • Compared to full upgrading the capital investment is significantly lower, while still providing significant value addition to the bitumen • Compared to dilbit it eliminates the need for diluent, which decreases the pipeline capacity needed to transport the product, while offering a downstream refinery friendlier feedstock, (no asphaltenes, lower metals, TAN and CCR, etc.) Partial Upgrading has received varying degrees of attention from producers, investors and governments over time. We believe that Partial Upgrading is a feasible economic option for the monetization of Alberta’s bitumen. The only questions are HOW and WHEN? Partial Upgrading is not a question of technology, but economic viability, market accessibility and social acceptance. Partial Upgrading Status and Drivers Several new and novel technologies have been contemplated and evaluated over the last decade. Some are still at laboratory scale, some are in the pilot plant stage, and few have progressed to field trials. Some proponents have also considered and/or constructed small scale demonstration facilities. All these technologies are based on the premise of high bitumen yields with a significant reduction (or elimination), of diluent while meeting pipeline specifications, (driven primarily by viscosity and olefin content). Without taking anything away from the ingenuity of these various novel technologies, we believe that a partial upgrader can be built with confidence, using a combination of proven downstream oil refinery processes, e.g. thermal cracking, deasphalting and mild hydrotreating. Using proven refinery technologies, upgraders can be configured as either large merchant type centralized facilities, or several smaller capacity satellite plants. A combination of both the above concepts is also a feasible

Presenter
Jan Wagner 300x300.jpg
Jan Wagner Principal Consultant Advisian, Worley Group
  • 2 30 PM
Coffee Break & Visit Exhibition
  • 3 00 PM

How Micro Co-generation Can Help Reduce Emissions in B.C.’s Upstream Natural Gas Sector

Pipeline & Processing Facilities

British Columbia has mandated the development of an “energy roadmap” to help the province meet its ambitious carbon reduction targets. The February 2019 Service Plan released by the Ministry of Ene...

  • locationPALOMINO ROOM A
  • small-arm3:00 PM - 3:30 PM
wednesday June 10, 2020
Pipeline & Processing Facilities

How Micro Co-generation Can Help Reduce Emissions in B.C.’s Upstream Natural Gas Sector

  • pr-alarm3:00 PM - 3:30 PM
  • pr-locationPALOMINO ROOM A

British Columbia has mandated the development of an “energy roadmap” to help the province meet its ambitious carbon reduction targets. The February 2019 Service Plan released by the Ministry of Energy, Mines and Petroleum Resources includes expanding the electrification of the upstream oil and gas industry as one of its key strategies. However, there are challenges to the electrification of remotely located natural gas facilities. According to the B.C. Oil and Gas Commission (BCOGC), just 13 of 110 natural gas plants are electrified in northeast B.C. Three main roadblocks identified by industry include: • A need for new towers and transmission lines to rugged and remote locations • The labour and material costs of connections to a newly expanded power grid • The impact on project schedules, given the timeline for building more power distribution infrastructure An alternative approach to power generation at remote locations that could both limit energy waste and help reduce upstream natural gas emissions is the implementation of micro” co-generation systems. With a generating capacity of 5-10 MW and a condensed footprint of only 1,250 m2 (25m x 50m), micro co-generation units represent a viable off-grid, carbon-reducing option for natural gas plants located in remote regions where it may be too expensive to reach with transmission lines. In this presentation, Shane Torwalt, Engineering Director with a leading combined heat and power (CHP) engineering firm, will share insights from his co-generation experience while exploring the use of small-scale CHP systems within natural gas facilities. The presentation will walk the audience through the basics of micro co-generation and explain how combining simple cycle power generation from a gas turbine (GT) with a heat recovery steam generator (HRSG), will allow plant operators to use the by-products of combustion to reduce overall plant emissions. The benefits of micro co-generation include: • Reduced physical footprint (land disturbance) • Decreased CO2 emissions when compared to a plant operating with standalone power generation and utility heating equipment • Accelerated implementation timeline versus waiting to access future power distribution infrastructure This presentation should be of interest to operators of small to mid-sized off-grid natural gas plants in northeast B.C. or other remote locations. Operators dealing with the decreasing efficiency of aging utility boilers may be particularly interested in the opportunities of micro co-generation units. "

Presenter
Adan Springfield 300x300.jpg
Shane Torwalt Principal, Engineering Director Vista Projects
  • 3 00 PM

The Effects of Infill Drilling on Midterm Well Productivity: A Montney Case Study

Reservoir Engineering

Objectives/Scope As fields are discovered, and subsequently developed, operators experiment with a variety of well spacing, landing depths and hydraulic fracture designs. This study focuses on Mont...

  • locationPALOMINO ROOM B
  • small-arm3:00 PM - 3:30 PM
wednesday June 10, 2020
Reservoir Engineering

The Effects of Infill Drilling on Midterm Well Productivity: A Montney Case Study

  • pr-alarm3:00 PM - 3:30 PM
  • pr-locationPALOMINO ROOM B

Objectives/Scope As fields are discovered, and subsequently developed, operators experiment with a variety of well spacing, landing depths and hydraulic fracture designs. This study focuses on Montney development and examines the effect that adding wells to an existing pad has on midterm production forecasts for all wells involved. The work is based on a rich variety of publicly available production and completions data that is common place in the Western Canadian Sedimentary Basin due to regulatory practices. Methods/Procedure/Process: Pads with some level of infill drilling since 2018 were identified and grouped by azimuthal direction to assign families. The production forecasting tool used is a physio-statistical method that yields more reliable results when peak rate is achieved or with at least 6 months of production (URTEC-2019-264-MS). Wells with fewer than 6 months of production were filtered out. There were 32 pads identified, 13 of which were in the same field (Heritage) and producing zone (Montney). Each pad was studied while considering fracture treatment design, spacing (inter wellbore and in the stratigraphic column) and timing. Results/Observations/Conclusions: Of these 13 pads, 2 pads showed an improvement to the parent wells’ forecast, 2 showed no change, and the majority (9) showed a decrease in parent well midterm (3-5 year) production forecast. Finally, a study of the effect of shutting wells in on both the individual well and the pad was conducted to evaluate if the production handicap was a result of competitive drainage (parent-child interactions) or near wellbore phase behaviors (shut in effects). Application/Significance/Novelty: This paper attempts to answer the question: how would the parent well have produced if it had not been impacted by infill activity? A large majority of work presented focuses on either the short term (immediate fracture hits) or the long term (25 and 30 year EUR), whereas this focuses on midterm production forecasts (3-5 years of total well life), which would be the desired payout period for unconventional well development of this nature.

Presenter
Melanie Popp 300x300.jpg
Melanie Popp Senior Engineering Advisor Geologic Systems Ltd
  • 3 00 PM

ESG in Alignment with Regulations

Technical Panel Session

Speakers to be announced.

  • locationPALOMINO ROOM C
  • small-arm3:00 PM - 4:30 PM
wednesday June 10, 2020
Technical Panel Session

ESG in Alignment with Regulations

  • pr-alarm3:00 PM - 4:30 PM
  • pr-locationPALOMINO ROOM C

Speakers to be announced.

  • 3 30 PM

Successful Reinforced Thermoplastic Pipe (RTP) Offshore Insertion

Pipeline & Processing Facilities

Reinforced Thermoplastic Pipe (RTP) design has been improved to meet the very specific requirement of handling corrosive fluids such as crude oil and sour gas up to certain pressure. RTP might have...

  • locationPALOMINO ROOM A
  • small-arm3:30 PM - 4:00 PM
wednesday June 10, 2020
Pipeline & Processing Facilities

Successful Reinforced Thermoplastic Pipe (RTP) Offshore Insertion

  • pr-alarm3:30 PM - 4:00 PM
  • pr-locationPALOMINO ROOM A

Reinforced Thermoplastic Pipe (RTP) design has been improved to meet the very specific requirement of handling corrosive fluids such as crude oil and sour gas up to certain pressure. RTP might have been widely used for onshore application. However, its application as offshore pipeline is not common compared to carbon steel or flexible steel pipeline due to some limitations. PETRONAS Carigali Sdn. Bhd (PCSB) has undertook a pipeline replacement project at offshore Terengganu, Malaysia to reverse flow 17km of existing 12” carbon steel pipeline with 3” Reinforced Thermoplastic Pipe (RTP) pipeline from Platform-A to Platform-B for crude and condensate services. This technology was the first being implemented by PETRONAS and in Asia Pacific region for offshore application. RTP pipeline was installed from the Shut Down Valve (SDV) of Platform A to SDV of Platform B by insertion methodology into existing 12” carbon steel pipeline. Special inline connectors were used to connect different sections of RTP pipeline, which came in several reels. Specific inspection to be performed at the connection considering the swaging method used and its effect. RTP hang-off and end termination was conducted upon completion of RTP insertion. Specific RTP pre-commissioning and hydrotest procedure was developed and executed with certain acceptance criteria. The pipeline was then commissioned smoothly indicating the successful completion of the project. It has proven that RTP pipeline offshore insertion was technically feasible for a long pipeline. This technology of offshore RTP pipeline provides alternative to the conventional carbon steel pipeline with the advantages of anti-corrosion, high flexibility and low total lifecycle cost. The aim of this paper is to highlight the methodology for RTP Pipeline offshore insertion and the technical challenges during offshore execution. Having RTP pipeline insertion of 17km at offshore has set a new benchmark in the industry as the World Longest RTP Insertion. It was a great success, and would be an example for future projects undertaking the same approach.

Presenter
Azlan Abu Bakar 300x300.jpg
Azlan Abu Bakar Technical Professional (Installation) PETRONAS
  • 3 30 PM

Insights from Inter-well Gas Tracer Test Deployment

Reservoir Engineering

Tracer technology has gained considerable attention recently as an effective tool in the reservoir monitoring and surveillance toolkit, particularly in IOR operations. Gas flow paths within the res...

  • locationPALOMINO ROOM B
  • small-arm3:30 PM - 4:00 PM
wednesday June 10, 2020
Reservoir Engineering

Insights from Inter-well Gas Tracer Test Deployment

  • pr-alarm3:30 PM - 4:00 PM
  • pr-locationPALOMINO ROOM B

Tracer technology has gained considerable attention recently as an effective tool in the reservoir monitoring and surveillance toolkit, particularly in IOR operations. Gas flow paths within the reservoir can be quite different from liquid (oil and water) flow path. This is primarily due to gravity override, and differences in density and relative permeability between the gas and liquid phases. Inter-well gas tracer test (IWGTT) is a key monitoring and surveillance tool for any IOR projects. IWGTT should be designed and implemented to track the flow behavior of gas phase. The test generally entails injecting a small amount of unique perflouro-hydrocarbon tracers into the gas phase injectant stream. IWGTT have been conducted on a limited number of fields across the globe, and sample results of some will be presented. The sampling frequency of the tracers from the producers should be designed carefully to collect the necessary data that will provide insights about the connectivity between the injectors and producers well pairs, gas breakthrough times (“time of flight”), and possible inter-well fluid saturations. Different fit-for-purpose unique tracers can be deployed in the subject injector(s) stream and their elution can be monitored in the corresponding up-dip producer(s). In addition to reservoir connectivity and break-through times between injector and producer pairs, an IWGTT helps in optimizing WAG operations and production strategies for gas injection projects, improve sweep efficiency and ultimately enhance oil recovery. It can also be used to identify source of inadvertent gas leakage into shallow aquifers or soil gas, and help in the planning and placement of future wells. This paper reviews the workflow and necessary logistics for the successful deployment of an inter-well gas tracer test. It will provide the best practices for designing, sampling, analyzing and interpretation of a gas tracer deployment. The paper also highlights the benefits of gas tracer data and their usefulness in understanding well interconnectivity and dynamic fluid flow in the reservoir. The results can be used to refine the reservoir simulation model and fine tune its parameters. This effort should lead to better reservoir description and an improved dynamic simulation model. The challenges associated with IWGTT will also be shared.

Presenter
Abdulaziz Al-Qasim 300x300.jpg
Abdulaziz Al-Qasim Champion of CCUS/EOR M&S Saudi Aramco
  • 4 00 PM

Advancing Pipeline Safety with UAS-based Inspection Programs

Pipeline & Processing Facilities

The use of UAS for augmented pipeline inspections is transforming pipeline integrity management. Drone-based inspections increase efficiencies, reduce costs and provides increasingly more precise d...

  • locationPALOMINO ROOM A
  • small-arm4:00 PM - 4:30 PM
wednesday June 10, 2020
Pipeline & Processing Facilities

Advancing Pipeline Safety with UAS-based Inspection Programs

  • pr-alarm4:00 PM - 4:30 PM
  • pr-locationPALOMINO ROOM A

The use of UAS for augmented pipeline inspections is transforming pipeline integrity management. Drone-based inspections increase efficiencies, reduce costs and provides increasingly more precise data that can be used to detect and mitigate hazardous risks, improving safety for inspectors and employees and reducing the environmental impact of large-scale projects. Today, innovation though cloud computing, AI and machine learning, predictive analytics and big data are opening up new opportunities and accelerating time to value while removing barriers to adoption. This session will explore how the use of drones and advanced data analytics are helping midstream pipeline construction companies and operators monitor and identify possible vulnerabilities before they become safety hazards. It will also cover best practices for developing a successful UAS program built for scale. Attendees will learn 1) Learn about emerging aerial analytics and practices for improving pipeline integrity management 2) best practices and techniques for identifying possible vulnerabilities before they become safety hazards

Presenter
Bryan Crowe
Bryan Crowe Chief Operating Officer and Executive Vice President SolSpec, Inc.
  • 4 00 PM

Machine Learning Driven Reserves Estimation

Reservoir Engineering

Estimating the reserve recoverable of CHOPS reservoirs (Cold Heavy Oil Production with Sand) is a popular approach for assessing reservoir potential and prioritizing optimization opportunities. How...

  • locationPALOMINO ROOM B
  • small-arm4:00 PM - 4:30 PM
wednesday June 10, 2020
Reservoir Engineering

Machine Learning Driven Reserves Estimation

  • pr-alarm4:00 PM - 4:30 PM
  • pr-locationPALOMINO ROOM B

Estimating the reserve recoverable of CHOPS reservoirs (Cold Heavy Oil Production with Sand) is a popular approach for assessing reservoir potential and prioritizing optimization opportunities. However, the process is known to be both time consuming and data heavy involving experienced Subject Matter Experts (SMEs) (e.g., engineers, geologists, etc.) spending weeks or months to review huge volumes of geological and petrophysical data as well as historical fluid behavior of hundreds of wells across wide geographical sites. With shrinking budget and limited technical resources, the majority of CHOPS assets across the industry often go unreviewed thereby risking missing potential opportunities or financial loss from optimizing the wrong reservoir. The process also suffers from a high degree of subjectivity due to the reliance on experiential and tribal knowledge, which is further aggravated by the fact that, the mostly public, logs, completions, and production data are of questionable quality. The objective therefore is to build a data-driven solution that can leverage the multitude of CHOPS wells data, while being robust to quality and reliability issues therein, and can aid Engineers in efficiently assessing reserve potentials of CHOPS reservoirs, speed up review turn-around time and improve overall outcomes. To overcome the aforementioned challenges, this solution presents an end-to-end machine learning based approach that consolidates diverse oil well data, automatically rank offsets based on geological and geographical proximity to a subject well, and forecasts unknown reserves of subjects as a partial function of aggregated fluid behavior of offsets. The solution leverages the power of distributed data processing and cloud computing for scaling both the data preparation and analytics pipelines while adopting a hybrid machine learning and physics-based technique for modeling. To boost confidence in the solution, the architecture and model parameterization are, wherever necessary, carefully informed by experiential knowledge from engineers and geologists. The results from the experiments performed have showed that the solution aids engineers in making the right optimization decision in 69% of cases as compared to much less than 50% accuracy using traditional approaches. Additionally, aside speeding up the review process by orders of magnitude, the solution has demonstrated capacity to improve the SMEs productivity, as well as save cost.

Presenter
Emmanuel Ibidunmoye 300x300.jpg
Emmanuel Ibidunmoye Senior Data Scientist Consultant IBM
  • 4 30 PM
DAY 2 OF TECHNICAL CONFERENCE CONCLUDES FOR THE DAY
  • 7 30 AM
Registration
  • 8 30 AM

Zero GHG Production Of Oil Sands Reservoirs Using RF Heating

Enhanced Oil Recovery (EOR)

Objectives/Scope: Thermal recovery is one of the most effective approaches in recovering heavy oil or bitumen. Radio frequency (RF) energy has been considered for downhole heating as early as the 1...

  • locationPALOMINO ROOM A
  • small-arm8:30 AM - 9:00 AM
thursday June 11, 2020
Enhanced Oil Recovery (EOR)

Zero GHG Production Of Oil Sands Reservoirs Using RF Heating

  • pr-alarm8:30 AM - 9:00 AM
  • pr-locationPALOMINO ROOM A

Objectives/Scope: Thermal recovery is one of the most effective approaches in recovering heavy oil or bitumen. Radio frequency (RF) energy has been considered for downhole heating as early as the 1940’s. Recent developments in this technology have generated new interest due to its economic and environmental benefits and for its ability to produce a wide range of reservoirs including many that to date have not been considered commercially viable. This presentation will cover the economic and operational realities of producing a zero-GHG barrel of heavy oil or oil sands by applying renewable sources of energy to power a RF heating system. Methods, Procedures, Process: The technology operates by delivering controlled electromagnetic energy (EM) directly into an oil-bearing formation. The electromagnetic energy raises the temperature of existing water in the formation, enabling production. Important properties for the success of this technology are: porosity, permeability and oil saturation. Performance is less sensitive to initial reservoir conditions (low pressure and temperature), reservoir thickness or low depth. As an all-electric process, RF heating lends itself to zero GHG production of such reservoirs where the power provided to generate the RF energy is a renewable source. Results, Observations, Conclusions: The presentation will share the results of simulations for the use of RF heating to produce the oil, along with techno-economic analysis of the current commercial state of the art sources for renewable power sources to deliver the energy required for the RF heating system. Simulations will take into account the operational realities of the selected power sources, and will provide a comparison of the economic impact of those different sources. • Simulations will be completed on a single oil sands reservoir for RF heating and SAGD • The economics resulting from the application of several different renewable power sources will be calculated • Production levels and economics of those different power sources will be compared • Economic results and production forecasts for zero GHG RF heating will be compared to results for the use of SAGD. Novel/Additive Information: The presentation will capture the operational and economic realities of zero GHG production of heavy oil and oil sands reserves using RF heating. With increasing pressure on the industry to improve ESG performance, RF heating offers a path to zero emissions where it can rely on entirely renewable sources of power in addition to eliminating the use of fresh water . While the cost of such renewable sources has prevented it’s use on commercial scale, advances in RF heating technologies and in renewable power generation are making this concept a viable alternative for the near future.

Presenter
Mike Tourigny 300x300.jpg
Mike Tourigny VP Commercialization, RF Heating Acceleware Limited
  • 8 30 AM

A New Approach to Eliminating Pneumatic Methane Venting on Wellsites

Environmental Management

Methane has a greenhouse gas intensity 25 times greater than CO2 and the practice of venting gas through pneumatic devices makes up about 35% of the oil and gas industry’s total methane emissions i...

  • locationPALOMINO ROOM B
  • small-arm8:30 AM - 9:00 AM
thursday June 11, 2020
Environmental Management

A New Approach to Eliminating Pneumatic Methane Venting on Wellsites

  • pr-alarm8:30 AM - 9:00 AM
  • pr-locationPALOMINO ROOM B

Methane has a greenhouse gas intensity 25 times greater than CO2 and the practice of venting gas through pneumatic devices makes up about 35% of the oil and gas industry’s total methane emissions in Canada ? some 18,000,000 tonnes of CO2e annually. Fixing the methane emission problem is top priority for the Oil and Gas Industry. In gas-driven pneumatic systems, the pressure of the natural gas provides the motive force to shift a valve or stroke a pump, then the spent gas discharges into the atmosphere. These types of systems have been popular for controlling wellsites across the globe, as they have low capital and operating costs, leveraging the gas produced at the site. In addition to the substantial greenhouse gas emissions, gas driven pneumatic system have increased maintenance costs, reduced reliability due to freeze off issues, and incur carbon taxes. To operate control systems electrically or with compressed instrument air requires approximately 5 to 30 kW of power, depending on site design and size. Historically, remote power generation options for wellsites have been limited to under approximately 1.5 kW through use of Thermal Electric Generators (TEG’s), solar panels and fuel cells, or over approximately 35 kW through use of traditional reciprocating engines and turbines Low power range internal combustion engines have not been used in this application due to two technical limitations: short service interval and inability to handle variable fuel quality and heat content. Westgen has developed technology to overcome these limitations and enable reliable power generation in the range of 5 to 30 kW which enables cost effective instrument air on large multi-well pad wellsites for the first time. Westgen will present the case study of the first remote power generation instrument air deployment on a wellsite in Northern British Columbia in Q4 2019 and discuss the potential environmental impact of cost effective instrument air on wellsites. It is estimated that this technology has the potential to reduce 123 million tCO2e in Alberta alone over the next 25 years. "

Presenter
Connor O'shea 300x300.jpg
Connor O'shea President Westgen Technologies Inc
  • 8 30 AM

Artificial Intelligence Implementation

Technical Panel Session

Speakers to be announced.

  • locationPALOMINO ROOM C
  • small-arm8:30 AM - 10:00 AM
thursday June 11, 2020
Technical Panel Session

Artificial Intelligence Implementation

  • pr-alarm8:30 AM - 10:00 AM
  • pr-locationPALOMINO ROOM C

Speakers to be announced.

  • 9 00 AM

Experimental Study of Surfactant Polymer for a Heavy Oil Field in South of Oman

Enhanced Oil Recovery (EOR)

Heavy oil reservoirs remain challenging for surfactant-based EOR, particularly in selecting fine-tuned chemical formulations which combine high performance and guarantee trouble-free operations. Th...

  • locationPALOMINO ROOM A
  • small-arm9:00 AM - 9:30 AM
thursday June 11, 2020
Enhanced Oil Recovery (EOR)

Experimental Study of Surfactant Polymer for a Heavy Oil Field in South of Oman

  • pr-alarm9:00 AM - 9:30 AM
  • pr-locationPALOMINO ROOM A

Heavy oil reservoirs remain challenging for surfactant-based EOR, particularly in selecting fine-tuned chemical formulations which combine high performance and guarantee trouble-free operations. This requires substantial laboratory work and a solid methodology. This paper reports a laboratory feasibility study aiming at designing a surfactant-polymer pilot for a heavy oil field in the South of Oman. The workflow was organized as follows: (i) oilfield initial assessments ; (ii) selection and preparation of the rock and fluids ; (iii) initial design of the surfactant-polymer formulation involving an extensive screening of surfactants and polymer combinations using a robotic platform ; (iv) pre-qualification tests involving in-vitro adsorption and assays for emulsion risk at surface conditions ; (v) demonstration coreflood test aiming at determining the ultimate oil recovery achievable with the formulation and (vi) optimization study involving coreflood test and formulation fine tuning to design the most adapted injection strategy. An extensive screening study was carried out to select representative core and fluid materials. To enable comparative coreflood tests, an analogue granular porous medium was built, with mineralogical composition mimicking that of the reservoir rock. The design of the surfactant-polymer formulation relied on hundreds of automated salinity screening phase behavior and solubility assays. Polymer selection was achieved by membrane injection tests performed under imposed velocity conditions to determine resistance factors versus pore size, velocity, concentration and salinity. This procedure resulted in the successful design of a surfactant-polymer formulation that provided o/w IFT of less than 10-2 mN/m at 50°C over a relatively broad range of salinities, including the injection water salinity. A first coreflood test performed on a reservoir rock plug demonstrated that injecting the formulation as an infinite slug in post-polymer flooding conditions led to 100% recovery of the remaining oil with a very good in-depth propagation of the formulation. The optimization study was then carried out and led to designing injection sequences that allowed minimizing the surfactant losses due to both retention on the rock and dissolution in oil. The results demonstrate that a surfactant-polymer formulation can successfully be designed and evaluated for heavy oil reservoirs. They also provide practical guidelines for the pilot implementation and pave the way for the next stage of the feasibility study which will focus on generating data for reservoir simulation, operational design and improving the economics.

Presenter
Eric Delamaide 300x300.jpg
Eric Delamaide General Manager IFP Technologies (Canada) Inc.
  • 9 00 AM

Drilling Waste Recycling

Environmental Management

The goal of our work is to offer industry a better solution for the disposal of oil-based drilling waste as opposed to onsite deep burial, land farming or land fill disposition. Currently, the wast...

  • locationPALOMINO ROOM B
  • small-arm9:00 AM - 9:30 AM
thursday June 11, 2020
Environmental Management

Drilling Waste Recycling

  • pr-alarm9:00 AM - 9:30 AM
  • pr-locationPALOMINO ROOM B

The goal of our work is to offer industry a better solution for the disposal of oil-based drilling waste as opposed to onsite deep burial, land farming or land fill disposition. Currently, the waste stream is simply disposed in one form or another, however, we seek to recycle this waste stream into reusable end products using a new proprietary and patented clean solvent extraction technology, resulting in cost savings to operators and significant reductions in harmful emissions. The past 12 years we have spent conducting extensive scientific research and experimental development through widespread small-scale pilot field trials and laboratory analysis to develop a propriety technology that can very efficiently recover high quality refinery grade base oil from drilling waste. The base oil that is recovered is sold back to industry for reused as a drilling fluid. Our organization has constructed a first-of-its-kind commercial scale solvent extraction facility in Alberta, Canada, which is presently operating at commercial levels. The commercial scale facility operating in Alberta, Canada has proven that our proprietary solvent extraction technology is not only economically viable but offers superior environmental performance to current industry operating practices. Deploying our company’s propriety technology to recycle the waste stream can reduce harmful emissions by up to 85%. We are able to consistently recycle the waste stream into a recovered high-quality refinery grade base oil and the cleaned solids (drill cuttings) contain only 1 ? 3% residual hydrocarbons. Oil based drilling fluids are the predominant drilling fluid used to drill unconventional long reach horizontal wells. The increase in horizontal drilling lengths and now pad drilling, means industry is creating more of this waste stream than ever before and in increasingly concentrated measures. Every current disposal method for this waste stream has the potential for environmental contamination, but with our new technology we can recycle virtually all of the oil contamination off of this waste stream and in doing so we not only save operators money, but we also significantly reduce harmful environmental emissions in the process. This is not only good for operators, but for all industry stakeholders because anytime we can recycle waste streams and keep them out of the landfills, everyone wins. "

Presenter
Shane Kozak 300x300.jpg
Shane Kozak Vice President Finance & CFO Recover Energy Services Inc.
  • 9 30 AM

Polymer Flood Design in Heavy Oil Fields: Best Practices

Enhanced Oil Recovery (EOR)

A new approach to laboratory testing and modeling of polymer flooding is proposed. Best practices in the field design and operational management are also proposed to reduce the uncertainties of fie...

  • locationPALOMINO ROOM A
  • small-arm9:30 AM - 10:00 AM
thursday June 11, 2020
Enhanced Oil Recovery (EOR)

Polymer Flood Design in Heavy Oil Fields: Best Practices

  • pr-alarm9:30 AM - 10:00 AM
  • pr-locationPALOMINO ROOM A

A new approach to laboratory testing and modeling of polymer flooding is proposed. Best practices in the field design and operational management are also proposed to reduce the uncertainties of field operations. The conventional way of predicting oil recovery for a polymer flood is to run a number of coreflood experiments, history match the results to prepare relative permeability curves, and run a simulator based on Darcy-flow principles to estimate oil recovery in the field. Injection facilities are often designed as an afterthought and independently of the reservoir studies. Predicted oil recovery often does not match well to the actual oil recovery for western Canadian polymer floods. Some of the mismatch is due to the processes described above, and some is due to operational issues. This paper discusses both. An extensive review covers the application of corefloods and simulation to predict oil recovery for polymer flooding of heavy oil. That prediction faces the challenges posed by the differences between field and corefloods. These include at least: heterogeneity of the field; stability of the polymers in the field; viscous instabilities owing to the differences in viscosity of the oil and the injected fluid; and capillary end effects of the coreflood. The nature of the fluid flow is different for corefloods and in the field. Coreflooding of heavy oils creates flow described as in the transition region, whereas in the field, fluid flow is described as being in the pseudo stable region. In the transition region, parameters like core diameter affect the oil recovery; in the pseudo stable region, these parameters do not affect oil recovery. Corefloods are then followed by simulation, which leads to more uncertainty, and overestimating oil recovery. The challenges of simulation include: the flow functions applied in simulation are based on stable flow, which overestimates oil recovery; and accounting for the propagation of fingers from viscous flow. The review is supplemented by an analysis of over 20 coreflood experiments investigating polymer injection in oils with viscosity up to 10,400 mPa·s, which showed that aspect ratio significantly affected the oil recovery. Traditional-sized corefloods have always been assumed to have one-dimensional flow, but we found that they yielded lower oil recovery for an initial waterflood, likely owing to viscous fingering. Gaps in the design of the polymer injection facilities and process monitoring results in more complications. We present general guidelines to deal with blending plant design to reduce the likelihood and impact of the various common operational issues.

Presenter
Petro Nakutnyy 300x300.jpg
Petro Nakutnyy Manager, EOR Processes Saskatchewan Research Council
  • 9 30 AM

Reducing Methane Emissions and Costs with Smart Electric Chemical Pump

Environmental Management

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

  • locationPALOMINO ROOM B
  • small-arm9:30 AM - 10:00 AM
thursday June 11, 2020
Environmental Management

Reducing Methane Emissions and Costs with Smart Electric Chemical Pump

  • pr-alarm9:30 AM - 10:00 AM
  • pr-locationPALOMINO ROOM B

In the coming years, heavy regulations are planned for pneumatic fuel gas driven equipment on oil and gas sites across Western Canada. Pneumatic pumps use pressurized natural gas as a power source and then release the spend low pressure gas directly to the atmosphere. As Pneumatic pumps vent significant amount of methane they will not be allowed on a new site in British Columbia after 2022. In addition, the overall vent limit comes into effect in Alberta 2023 and existing sites that have multiple fuel gas driven pneumatic devices will likely breach the overall vent gas limit threshold. Sirius Controls designs and manufactures electric chemical injection packages that are engineered not only to eliminate green house gas emissions, but also to reduce two of the largest expenses for operating companies: manpower and chemical cost. These cost reductions and increased reliability are due in a large part to Autonomous local control, a topic that Sirius has recently published an article about in the World Oil magazine https://www.siriuscontrols.com/cmsAdmin/uploads/world-oil-advances-in-production.pdf Autonomous local control is local monitoring of multiple parameters combined with intelligent control adjustments, automatically made without manual interaction, human input. Upstream Oil and Gas production companies are adopting these new digital technologies to optimize production, reduce manpower, adopt predictive maintenance, and reduce chemical consumption. Putting smart controllers at the wellsite is a step forward in creating the Digital Oilfield as producers look to increase profitability When Sirius initially introduced the solar chemical injection system to the market, emissions reduction targets were not as prevalent as they are today, so the technology had to make a compelling economic case. Sirius designed its chemical injection systems to optimize the amount of chemical injected, reduce disposal costs, reduce maintenance costs, and reduce the risk of chemical spills. Solar has been infamous for not being well suited to cold climates. Sirius spent a long time building an exceptional reputation in the industry for the use of solar and is now one of the leading providers of chemical injection systems in Canada. Sirius has installed close to 10,000 solar chemical injection systems, reducing upstream oil and gas emissions by almost 4 MT CO2e per year. Through constant customer driven improvement, lean thinking and a dynamic engineering team, Sirius focuses on helping the Canadian and International Oil and Gas industry reduce its environmental footprint in an economical and cost-effective manner.

Presenter
Tyler Teece 300x300.jpg
Tyler Teece Corporate Sales Representative Sirius Instrumentation & Controls
  • 10 00 AM
Coffee Break & Visit Exhibition
  • 10 30 AM

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

Enhanced Oil Recovery (EOR)

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

  • locationPALOMINO ROOM A
  • small-arm10:30 AM - 11:00 AM
thursday June 11, 2020
Enhanced Oil Recovery (EOR)

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

  • pr-alarm10:30 AM - 11:00 AM
  • pr-locationPALOMINO ROOM A

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

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

Technology Driving Efficiency in Alberta’s Oil and Gas Sector

Environmental Management

Opportunities for efficiency in the oil and gas sector are substantial and largely untapped according to a recent study on Alberta’s energy efficiency potential. This study suggests $1.6 billion in...

  • locationPALOMINO ROOM B
  • small-arm10:30 AM - 11:00 AM
thursday June 11, 2020
Environmental Management

Technology Driving Efficiency in Alberta’s Oil and Gas Sector

  • pr-alarm10:30 AM - 11:00 AM
  • pr-locationPALOMINO ROOM B

Opportunities for efficiency in the oil and gas sector are substantial and largely untapped according to a recent study on Alberta’s energy efficiency potential. This study suggests $1.6 billion in savings and 8.9 Mt CO2e in GHG emission reductions are there for the taking in the sector by the end of the study period. This sector has proven especially interested in energy efficiency initiatives with projects since 2017 representing more than 400,000 tCO2e. This presentation will discuss efficiency initiatives and technology that could be leveraged by oil and gas companies to increase competitiveness and get more product to market, and present two case studies ? one classified as a Large Final Emitter (LFE) and one smaller in scale ?" where companies have leveraged efficiency initiatives and technology to meet their Environmental, Social, and Governance (ESG) goals. In addition to technology deployment, this presentation will also outline examples of successful programs and initiatives and how the industry can move forward with integrated energy strategies necessary to implement strategic energy management. One example that has produced incredible results in a short period of time is having dedicated employees responsible for the energy management system. These employees spend approximately 20 per cent of their time on energy management, but can produce noticeable energy savings through energy scans, management plans, energy modelling and quantification. . These are no or low cost ways on-site energy managers at oil and gas facilities can identify energy saving opportunities, production efficiencies as well as dramatic emissions reductions -- which improves the balance sheet in addition to ESG benefits. "

Presenter
Jessica Shumlich300x300.jpg
Jessica Shumlich Program Manager Energy Efficiency Alberta
  • 10 30 AM

A Knowledge Translation Tool for Improved Health and Safety

Health & Safety

Changes in safety best practices and technology are happening faster and faster. To limit liability and stay competitive, organizations need to stay on top of these. Maintaining a competitive edg...

  • locationPALOMINO ROOM C
  • small-arm10:30 AM - 11:00 AM
thursday June 11, 2020
Health & Safety

A Knowledge Translation Tool for Improved Health and Safety

  • pr-alarm10:30 AM - 11:00 AM
  • pr-locationPALOMINO ROOM C

Changes in safety best practices and technology are happening faster and faster. To limit liability and stay competitive, organizations need to stay on top of these. Maintaining a competitive edge over competitors requires up-to-date knowledge of rapid changes in the literature and regulations; for example, it’s not unusual for a field to generate tens to hundreds of papers a year, each of which requires a critical review. A health and safety specialist with working knowledge of the field understands where risks are and how regulations may change. Where new knowledge impacts regulations, being unaware of changes in safety or environmental regulations can lead to increased risk and liability. Historically, staying on top of new research and changes in regulation and best practices was the responsibility of in-house health and safety staff. Maintaining that staff is increasingly difficult in a resource-constrained economy and they often themselves do not have the right tools to ensure that they are staying on top of changes in the field. It is becoming increasingly apparent that this knowledge translation ? moving scientific information to decision making ?" is an important gap. We combine artificial intelligence literature search capabilities with expert opinion to ensure that your organization understands changes in regulations and best practices in the field of health and safety. Blending the approaches of systematic reviews of scientific literature and regulations and knowledge translation, we provide a subscription-based service that provides reviews and briefing notes to improve the ability of your organization to maintain needed health and safety certification, reduce liability and risk, and protect your people. "

Presenter
Carla Davidson 300x300.jpg
Carla Davidson President Emergent Knowledge
  • 11 00 AM

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

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...

  • locationPALOMINO ROOM A
  • small-arm11:00 AM - 11:30 AM
thursday June 11, 2020
Enhanced Oil Recovery (EOR)

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

  • pr-alarm11:00 AM - 11:30 AM
  • pr-locationPALOMINO ROOM 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). Methods, Procedures, Process (75-100 words): This approach analyzes the additional recovery from the sustaining production which uses the heat stored within the steam chamber. The additional bitumen to be recovered during the wind-down is assumed to be proportional to the previous heat added to the reservoir or the cumulative production of bitumen during the normal steam injection period. In another word, the wind-down ratio is defined as the ratio between the incremental recovery factor during wind-down and the reservoir recovery factor at the starting point of the wind-down process. Results, Observations, Conclusions (100-200 words): A numerical sensitivity study was conducted on 2D SAGD/SA-SAGD mechanism models. The wind-down ratio is plotted against the recovery factor at the starting point of wind-down. It was found that the wind-down ratio is almost a constant value (~ 10% for blowdown) over a wide recovery range (e.g., 35% ~ 80%), which is consistent with our concept model. A pseudo-continuous steam injection curve was also introduced to the analysis to provide an upper bound for the incremental ratios. With sufficient energy but limited availably of bitumen ahead in reservoir, this curve also explains why the wind-down ratio drops sharply if it starts at a certain higher recovery level. Novel/Additive Information (25-75 words): The concept of wind-down ratio was introduced to the thermal gravity drainage processes for analyzing their late life recovery. This proposed, physics-based ratio is able to give an estimate of wind-down performance over a wide range of recovery factor. Numerical sensitivity studies confirm the consistency of the concept.

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

Advances in Automated Methane Detection using InfraRed Cameras

Environmental Management

In addressing this new industry requirement, accurate and reliable detection and monitoring are key capabilities and are increasingly mandated by regulatory bodies. Unfortunately in many cases the...

  • locationPALOMINO ROOM B
  • small-arm11:00 AM - 11:30 AM
thursday June 11, 2020
Environmental Management

Advances in Automated Methane Detection using InfraRed Cameras

  • pr-alarm11:00 AM - 11:30 AM
  • pr-locationPALOMINO ROOM B

In addressing this new industry requirement, accurate and reliable detection and monitoring are key capabilities and are increasingly mandated by regulatory bodies. Unfortunately in many cases the current methods such as point sensors and periodic manual inspections are not sufficient to meet the requirements of these policies. In response to this need, the industry is generating new technologies and solutions including recent advances in InfraRed (IR) camera technology and Machine Learning that have provided new and innovative methods to reliably detect methane and establish automated monitoring of above ground Natural Gas facilities. In addition to documenting the industry, regulatory and political forces that are driving this requirement, this presentation provides a background of IR technology as applied to the O&G industry, outlines the overall challenges of methane detection and the current methods of detection. Detailed focus will be provided on several recent advances in IR sensor technology, signal processing and AI that are allowing new and more cost effective solutions to be introduced to the industry. A short tutorial of the IR spectrum will be presented with emphasis on describing the Short Wave InfraRed (SWIR), Medium InfraRed (MWIR) and Long Wave InfraRed (LWIR) bands as they relate to spectral signatures of Methane and other Petroleum gases along with the role of atmospheric absorption. Products employing these technological advances are being introduced to the market and early trial results are promising. These results will be presented together with deployment procedures, detection results and anticipated false positive estimates. Other factors such as camera range, release target size, methods of reporting, confirmation and acknowledgement will also be covered. The presentation will provide an overview of Methane detection as it relates to Industry and regulatory requirements, current methods and challenges finishing with a new and innovative approach (intelligent optical gas imaging) that offers cost effective automated methane monitoring, detection, visualization and reporting at above ground facilities for the Natural Gas Industry.

Presenter
Shane Rogers300x300.jpg
Shane Rogers VP of Research and Development IntelliView Technologies Inc
  • 11 00 AM

Non Destructive Testing (NDT) 4.0: Robotic Technology Applied for the Floor Thickness Monitoring of Hazardous Liquid Storage Tanks

Health & Safety

Aboveground Storage Tanks (ASTs) corrode over time leading to possible leakage of contents, resulting in severe economic losses and pollution. To avoid these consequences, inspection and repair act...

  • locationPALOMINO ROOM C
  • small-arm11:00 AM - 11:30 AM
thursday June 11, 2020
Health & Safety

Non Destructive Testing (NDT) 4.0: Robotic Technology Applied for the Floor Thickness Monitoring of Hazardous Liquid Storage Tanks

  • pr-alarm11:00 AM - 11:30 AM
  • pr-locationPALOMINO ROOM C

Aboveground Storage Tanks (ASTs) corrode over time leading to possible leakage of contents, resulting in severe economic losses and pollution. To avoid these consequences, inspection and repair activities are performed periodically according to international regulations. Manual inspections require the tank to be off line for weeks and these inspections are also subject to Health and Safety (H&S) risks. In line with the vision of Industry 4.0 to make manufacturing operations and maintenance engineering services smart, this project (called nautilUS) aims at development of a small intrinsically safe and ATEX certified robot to carry out in-service inspection on Above Storage Tanks (ASTs). This robot is capable of moving around a tank (internal) floor and make measurements of the floor thinning using an ultrasound probe attached to it. The measurements along with location data would be then recorded for post-processing after the robot is retrieved. This is a £1M InnovateUK (UK's Innovation Agency) grant project and a consortium of 5 partners are collaborating on it. This project is to end around July 2020 , when the inspection robot is ready to be commercially deployed.

Presenter
Amir Rahbarimanesh 300x300.jpg
Amir Rahbarimanesh R&D Project Manager RS Components
  • 11 30 AM

A Novel Screening Methodology for Thermal EOR technologies to Support Well Development Plans

Enhanced Oil Recovery (EOR)

Steam injection and specifically cyclic steam stimulation (CSS), represents the most relevant production method of heavy crude oil reservoirs in Colombia. However, a significant number of CSS proje...

  • locationPALOMINO ROOM A
  • small-arm11:30 AM - 12:00 PM
thursday June 11, 2020
Enhanced Oil Recovery (EOR)

A Novel Screening Methodology for Thermal EOR technologies to Support Well Development Plans

  • pr-alarm11:30 AM - 12:00 PM
  • pr-locationPALOMINO ROOM A

Steam injection and specifically cyclic steam stimulation (CSS), represents the most relevant production method of heavy crude oil reservoirs in Colombia. However, a significant number of CSS projects are approaching a mature stage that include multiple wells with ten or more steam cycles. On the other hand, in the country there is also an important volume of heavy oil reserves that are still under (cold) production, which means that different technogies can be implemented according to the condition of the field. This situation represents an opportunity to incorporate and optimize technologies to increase heavy oil production in the country. The implementation of heat injection strategies, including steam-based hybrid methods and downhole heating technologies (DHHT) are under evaluation at Ecopetrol. The proposed hybrid CSS methods include steam injection combined with solvents, gases (relevant as part of Paris Agreement), chemicals (e.g. foams) or nanoparticles, among others. Depending on the maturity level of CSS in particular well, it is necessary to understand the timing to evaluate and implement a specific hybrid CSS methods. The implementation of DHHT at a particular stage of well development is also considered. The methodology proposed in this paper includes three important steps for screening technologies: a technical feasibility through numerical simulation, a simplified benefit/cost ratio as an economic indicator and an energy balance index. Considering these three phases a novel index was stablished to support the screening of thermal methods. Based on the uncertainties associated with the numerical simulation of the hybrid CSS processes and the incremental oil recoveries predicted for each of the methods in different stages of the well production history, the economic evaluation and the amount of energy injected in comparison with the energy produced, an optimum well development plan was generated. The results of this study demonstrate the feasibility of combining different heating technologies during the production history according to the conditions of the well / reservoir. However, the applicability window of each technology is depends on the maturity of CSS that limits the options as the number of steam cycles increases.

Presenter
Romel Perez 300x300.jpg
Romel Perez Reservoir Engineer Ecopetrol
  • 11 30 AM

Towards Sustainable Production of Oil and Gas Resources

Environmental Management

Oil and natural gas account for roughly 54% of the world’s energy supply. However, because modern climate change is attributed to the consumption of fossil fuels, the oil and gas industry is facing...

  • locationPALOMINO ROOM B
  • small-arm11:30 AM - 12:00 PM
thursday June 11, 2020
Environmental Management

Towards Sustainable Production of Oil and Gas Resources

  • pr-alarm11:30 AM - 12:00 PM
  • pr-locationPALOMINO ROOM B

Oil and natural gas account for roughly 54% of the world’s energy supply. However, because modern climate change is attributed to the consumption of fossil fuels, the oil and gas industry is facing increasing demand to become more environmentally responsible. Although it is desirable to have a perfectly green energy landscape, the realities about energy physics, the scale of energy demand, and energy economics mean that fossil fuels will remain relevant in the foreseeable future. Regardless of people’s bias for or against fossil fuels, what can generally be agreed on is that it would be beneficial to reduce the carbon footprint of oil and gas fields. The objective of this study is to identify and quantify opportunities for improving the energy efficiency and carbon footprint of oil and gas production systems. The general energy equation for flowing fluid and the law of conservation of energy were applied to trace the energy transformations of fluids as they travel from the reservoir to the surface. Then, an equation that describes the energy transformations in each segment of the production system was generated. Subsequently, this equation was used to assess the viability of reducing the energy loss in each segment. It was found that, in the reservoir-bottomhole segment, it is technically difficult to reduce the energy loss without jeopardizing oil/gas production. In the bottomhole-wellhead segment, an easy but expensive way of conserving energy is to insulate the tubing string; whereas a complicated and seemingly cheap way is to manipulate the wellhead flowing pressure. In the flowline-separator segment, without insulating the line, there is little or no room for improving energy efficiency. However, we have demonstrated that the choke presents an opportunity to significantly improve the energy efficiency and, by extension, the carbon footprint of oil and gas production systems. In the case study presented, it was shown that, within the parameter space examined, a theoretical maximum of 24 kW can be generated from the well. This energy saving translates to emissions reduction of 38.4 tCO2/year and 52.8 tCO2/year, from a gas- and diesel-powered system, respectively. A key product of this study is an equation that serves as a framework for improving energy efficiency in the various segments that make up an oil and gas production system. By replacing the surface choke with a hybrid choke-turbine device, the energy efficiency and carbon footprint of oil and gas production systems can be improved significantly. With a hybrid choke-turbine device, it is possible to achieve pressure/rate control and generate electricity simultaneously. As the fluid rotates the turbine blades, fluid pressure drops (for pressure/rate control) and mechanical energy is converted to electrical energy.

Presenter
Asekhame Yadua 300x300.jpg
Asekhame Yadua Petroleum Engineer Nigerian National Petroleum Corporation
  • 11 30 AM

Design and Evaluation of an HF Scrubber for Management of Alkylation Process Hazards in a Petroleum Refinery

Health & Safety

Of all the chemicals used or produced in petroleum refining, hydrogen fluoride (HF) may present the greatest risk to the public. HF is an additive used by about 50 refineries in the USA as a cataly...

  • locationPALOMINO ROOM C
  • small-arm11:30 AM - 12:00 PM
thursday June 11, 2020
Health & Safety

Design and Evaluation of an HF Scrubber for Management of Alkylation Process Hazards in a Petroleum Refinery

  • pr-alarm11:30 AM - 12:00 PM
  • pr-locationPALOMINO ROOM C

Of all the chemicals used or produced in petroleum refining, hydrogen fluoride (HF) may present the greatest risk to the public. HF is an additive used by about 50 refineries in the USA as a catalyst in the alkylation process to help produce gasoline suitable for vehicles. For some, there are real concerns that refiners using HF do not have adequate safety systems in place and are not prepared to handle a major release. This corrosive gas is deadly in high concentrations and burns the skin and lungs. A worst-case scenario release from a single facility would cover a radius that could encompass an entire populated area. This assumes a highly unlikely, though technically possible, event: a full tank of nearly 78,000 pounds of HF emptying in 10 minutes. A vapor cloud could travel up to 25 miles and depending on wind speed and direction it could sicken thousands of people. The number of people affected would vary by season and current weather conditions but would range in the thousands any time of year. The most probable worst-case scenario would be a failure of an unloading hose from an HF tank truck or the failure of a flange or fitting. If either of these events were to happen it is unlikely that the contents of the entire tank would be released, although significant amounts of HF could still be released into the refinery itself. This presents the requirement for the protection of site personnel from exposure to HF. A new gas-phase air filtration system incorporating a dry-scrubbing chemical medium for use against HF was evaluated for the potential to incorporate into new and existing control rooms that could be designated as safe havens in the event of a potentially catastrophic release of HF at a refinery. A research project was developed with the objective of evaluating the feasibility of adding a chemical scrubber to a refinery’s central control building to reduce the risk to site personnel from a possible toxic vapor cloud caused by a release of HF. This project evaluated what type of filtration medium would be appropriate for a safe havens’ air intake, the selected medium’s HF scrubbing capacity, the potential for production of carbon dioxide (CO2) and water from the reaction of HF with the selected medium, and the temperature increase from the reaction of HF with the selected medium. This paper will report the results of a successful test of the selected chemical scrubber design at representative combinations of HF concentrations and humidity levels. The results include the effectiveness of removing HF from a moving air stream, generation of water and CO2, and the effects of HF loading on temperature of the medium. For future applications,

Presenter
Christopher Muller 300x300.jpg
Christopher Muller Technical Director Purafil, Inc.
  • 12 00 PM
Lunch & Visit Exhibition - END OF DAY 3 AND CONFERENCE CONCLUDES