Papers & Publications
Papers
Microfluidic Constant Composition Expansion for Black Oils and Retrograde Gas Condensates
Sourabh Ahitan, Ali Abedini, Josh Genereux, Taylor Latorre, John Ratulowski, Zhidong Li, Edward C. Wanat, Hussein Alboudwarej, Jon Burger, Frode Ungar, Tao Yang
SPE-214948-PA, December 2024
A B S T R A C T
Building a robust pressure/volume/temperature (PVT) model critically relies on accurate phase behavior data, traditionally obtained using PVT cells. While the PVT cell can provide accurate data, it requires a large volume of downhole or recombined samples, which are usually expensive to collect or time-consuming to create. A novel microfluidic chip design and method are presented in this work to rapidly measure saturation pressure, relative volume, and liquid volume percentages of black oils and retrograde gas condensates (RGCs).
A Novel On-Chip Oil Swelling Measurement Platform for Gas Injection EOR Processes
Z. Barikbin, S. Ahitan, J. Genereux, and A. Abedini, Interface Fluidics Ltd., Calgary, Canada; F. Ungar and T. Yang,Equinor ASA, Stavanger, Norway; E. Wanat and Z. Li, ExxonMobil, Houston, USA; H. Alboudwarej and J. Burger,Chevron Technical Center, a division of Chevron U.S.A. Inc., Houston, USA
SPE-218253-MS, April 2024
A B S T R A C T
Oil swelling test data is essential to tune the EOS models to simulate gas injection EOR processes and evaluate the reservoir-scale recovery performances. PVT cells are typically used to measure this property; however, it may involve some challenges with runtime, fluid handling, and test operations. Here, a high-pressure high-temperature microfluidic approach is developed to measure the oil swelling in response to gas exposure under step-wise increasing pressure with different injection gas mole fractions.
A Novel Method to Measure the Phase Behavior of Black Oils: Saturation Pressure and Liquid-Vapor Fractions
S. Ahitan, A. Abedini, and T. Latorre, Interface Fluidics Ltd., Calgary, Canada; E. Wanat, Z. Li, and M. Velasquez,ExxonMobil, Houston, USA; H. Alboudwarej and J. Burger, Chevron Technical Center, a division of Chevron U.S.A.Inc., Houston, USA; F. Ungar and T. Yang, Equinor ASA, Stavanger, Norway
SPE-214948-MS, October 2023
A B S T R A C T
Building a robust PVT model critically relies on accurate phase behavior data which has been traditionally obtained using PVT cells. While the PVT cell can provide accurate data, it requires a large volume of downhole or recombined samples which are usually expensive to collect. A novel microfluidic chip design and method is presented in this work to rapidly measure bubble point and liquid-vapor volume fractions of black oil systems at multiple pressures and temperatures.
Large-Scale High-Throughput Sensitivity Analysis of CO2 MMP to Optimize Gas Injection EOR Processes
A. Abedini, Z. Qi, T. de Haas, and D. O’Brian, Interface Fluidics Ltd., Calgary, Alberta, Canada
SPE-216683-MS, October 2023
A B S T R A C T
Performance of CO2 injection relies on accurate CO2 MMP/miscibility data at reservoir conditions. The CO2 stream typically contains gas impurities, and in most cases CO2 is combined with recycled gasses, which in either case the MMP changes – imposing additional uncertainties to deviate from expected CO2-MMP. Slim-tube is the most reliable tool; however, it is very time- and capital-intensive, making it impossible to provide high-throughput data to assess the impact of other gasses.
Learnings from the Planning and Execution of a Heavy Oil Polymer Flood Pilot in North Saskatchewan, Canada
Duilio Raffa, Baytex Energy Corp.; Ali Abedini, Interface Fluidics Limited
SPE-212760-MS, March 2023
A B S T R A C T
The oil recovery in Section 14-50-25W3 (province of Saskatchewan, Canada) has evolved through multiple stages as technology has changed over time. Oil was initially produced through vertical wells beginning in the early 1970s. In the 2010s horizontal drilling was established and the Lloydminster sandstone formation was produced on primary with horizontal wells. In 2014 the secondary waterflooding was implemented. At the beginning of 2018 a tertiary polymer flood was implemented and is still running (year 2022).
Microfluidic-Based Optimization of Polymer flooding for Heavy Oil Recovery
Zhenbang Qi, Xingyu Fan, and Ali Abedini, Interface Fluidics Limited; Duilio Raffa, Baytex Energy Corp
SPE-212758-MS, March 2023
A B S T R A C T
Polymer flooding has been implemented in Western Canada, specifically in Saskatchewan and Alberta since 2000s. Flooding with polymer has been more effective than with water in heavy oil reservoirs due to a more favorable mobility ratio, resulting in more a stable front and less fingering. Optimization of polymer flood strategies is essential for successful implementation of field-scale operations. Core and sand-pack flood testing have been a reliable method for laboratory evaluation of different injection methods and chemicals as the cores are representative of the reservoir geometries and rock chemistries.
Microfluidic Pore-scale Analysis of Polymer Flooding Effects of Polymer Molecular Weight and Viscosity
Z. Qi, X. Fan, O. Serediak, A. Abedini, P. Ghosh and R. Wilton
Second EAGE Workshop on EOR in Latin America, Oct 2022, Volume 2022, p.1 – 7
A B S T R A C T
Polymer flooding is a widely applied EOR method to increase oil recovery from heavy oil reservoirs by improving the mobility and conformance control of the displacement process. Core and sandpack floodings have been mostly applied to evaluate the polymer flooding performance for a given reservoir; but the associated pore-scale dynamics with varying polymer MW and chemistry remains unclear in these experiments. Hence, a synergistic approach of coreflood testing along with visual experiments can provide the detailed insight of polymer flow behavior and performance.
Bioremediation Study on Formation Damage Caused by Hydraulic Fracturing: A Microfluidic Approach
Songyuan Liu, Chao-yu Sie, Fatee Malekahmadi, Bo Lu, and Yifan Li, Rockwater Energy Solutions; Cara Fan,Xinyue Zhang, Owen Serediak, Jelayne Fortin, and Ali Abedini, Interface Fluidics Ltd
SPE-210089-MS, October 2022
A B S T R A C T
Hydraulic fracturing has been applied to unconventional reservoirs with low permeability to achieve higher productivity and economic potential. However, polyacrylamide-based friction reducer and guar gum, two of the most common components in fracturing fluid could cause formation damage by penetrating into the matrix and blocking the flow path. To regain the conductivity of the damaged area, a bioremediation method was developed and validated by a microfluidic approach. Modified nutrients were used to stimulate the indigenous bacteria that could consume or break the polymer residues.
Effects of thief zones on displacement efficiency: Microfluidic pore-scale
ZhenBang Qi, Scott Pierobon, Owen Serediak, Jonathon Le, Adam Pettigrew, Ali Abedini
Fuel
Volume 316, 15 May 2022, 123371
A B S T R A C T
Thief zones are regions with high permeability, usually formed in mature or depleted reservoirs after water flooding, which can further reduce the overall recovery during subsequent EOR stages. While existing conformance control solutions alleviate the impact of thief zones, selecting an optimal solution based on current laboratory methods is challenging, since current methods fail to isolate the impact of thief zones, lack tight control of initial conditions, and use long evaluation times as well as large sample volumes.
A new fluidics method to determine minimum miscibility pressure
Frode Ungar, Sourabh Ahitan, Shawn Worthing, Ali Abedini, Knut Uleberg, Tao Yang
Journal of Petroleum Science and Engineering
Volume 208, Part B, January 2022, 209415
A B S T R A C T
Micro and nano-fluidic devices have attracted increasing attention in the oil industry. In this study, we designed a new slim-tube method to determine MMP on a microfluidic chip. The design is significantly different from previous efforts on fluidics chips with an open flowing tube. The new design contains porous media similar to that found in the slim-tube apparatus. The objective is to produce a true multi-contact process in the gas displacement. We tested the new fluidics device at reservoir conditions with three reservoir oils displaced by two hydrocarbon gases and CO2 gas.
Screening High-Temperature Foams with Microfluidics for Thermal Recovery Processes
Thomas W. de Haas, Bo Bao, Hugo Acosta Ramirez, Ali Abedini, and David Sinton
Energy Fuels 2021, 35, 7866−7873
A B S T R A C T
Thermal recovery processes, and in particular, Steam-assisted gravity drainage (SAGD), are the most common and practical in situ technology for bitumen extraction. While SAGD is effective, steam injection results in poor steam chamber growth and distribution with poor conformance specifically in areas with poor formation geology and bedding properties. These factors result in economic and environmental costs.
High-temperature high-pressure microfluidic system for rapid screening of superficial CO2 foaming agents
Ayrat Gizzatov, Scott Pierobon, Zuhair AlYousef, Guoqing Jain, Xingyu Fan, Ali Abedini & Amr I. Abdel-fattah
Scientific Reports
11, Article number 3360 (2021)
A B S T R A C T
CO2 foam helps to increase the viscosity of CO2 flood fluid and thus improve the process efficiency of the anthropogenic greenhouse gas’s subsurface utilization and sequestration. Successful CO2 foam formation mandates the development of high-performance chemicals at close to reservoir conditions, which in turn requires extensive laboratory tests and evaluations. This work demonstrates the utilization of a microfluidic reservoir analogue for rapid evaluation and screening of commercial surfactants (i.e., Cocamidopropyl Hydroxysultaine, Lauramidopropyl Betaine, Tallow Amine Ethoxylate, N,N,N′ Trimethyl-N′-Tallow-1,3-diaminopropane, and Sodium Alpha Olefin Sulfonate) based on their performance to produce supercritical CO2 foam at high salinity, temperature, and pressure conditions.
A New Fluidics Method to Determine Minimum Miscibility Pressure
F. Ungar, S. Ahitan, T. Yang, S. Worthing, A. Abedini and K. Uleberg
EarthDoc
Apr 2021, Volume 2021, p.1 – 14
A B S T R A C T
The miscible gas injection has been broadly used in many oil fields as an enhanced oil recovery (EOR) method. Minimum Miscibility Pressure (MMP) is a critical parameter both for modeling and field operations. The slim-tube method is recognized as the most reliable for MMP measurement. However, conducting the experiment takes a long time (4–6 weeks), and the sample volume requirement is substantial. Therefore, the slim-tube experiment is very costly and sometimes is not possible due to a lack of sample volume.
Visualization of Flowback Aid Mechanisms Utilizing a Microfluidic Pore-Scale Device
Ginger Ren, Stepan Oilfield Solutions; Ali Abedini, Interface Fluidics Ltd.; Hyuntae Yang and Aaron Sanders,Stepan Oilfield Solutions
SPE-199269-MS, February 2020
A B S T R A C T
Using flowback additives in slickwater fracturing fluids is a relatively recent innovation, and regained permeability testing using corefloods is the preferred performance evaluation method. The coreflood rig simulates the hydraulic fracturing process by injecting the fracturing fluid through a core under relevant pressure and temperature conditions, and measures the permeability and relative permeability changes during injection. Permeability measurements indicate whether the fracturing fluid damages the formation during hydraulic fracturing that in turn reduces oil productivity during flowback.
Nanofluidic Analysis of Flowback Enhancers for the Permian Basin:Unconventional Method for Unconventional Rock
Harvey Quintero, ChemTerra Innovation; Ali Abedini, Interface Fluidics Limited; Mike Mattucci and Bill O’Neil,ChemTerra Innovation; Raphael Wust, AGAT Laboratories; Robert Hawkes, Trican Well Service LTD; Thomas De Hass and Am Toor, Interface Fluidics Limited
SPE-195880-MS, October 2019
A B S T R A C T
For optimizing and enhancing hydrocarbon recovery from unconventional plays, the technological race is currently focused on development and production of state-of-the-art surfactants that reduce inter facial tension to mitigate obstructive capilary forces and thus increase the relative permeability to hydrocarbon(kro). This study provides insight into the pore-scale evaluation of the latest flowback enhancer technologies currently applied in the Permian Basin, Texas, USA. A multidisciplinary approach, including concepts of nanotechnology, was used to assess fluid-fluid and rock-fluid interactions occurring at the nanopore scale and their implications on enhancing oil recovery.
A Set of Successful Chemical EOR Trials in Permian Basin: Promising Field and Laboratory Results
Mehrnoosh Moradi Bidhendi, Mahdi Kazempour, Uwana Ibanga, Duy Nguyen, Justin Arruda, Mike Lantz, Cooper Mazon, NALCO Champion, an Ecolab Company
URTEC-2019-881-MS, July 2019
A B S T R A C T
Unconventional liquid reservoirs are currently one of the most important sources of oil in North America. Oil production experiences a rapid decline in these reservoirs and this has been a major issue faced by many operators. Low oil recovery has been attributed to ultralow permeability, low porosity and oil-wet nature of the reservoir rock. Hence, wettability alteration using chemicals could provide a viable chemical enhanced oil recovery method (cEOR) to increase oil production from these reservoirs.
Novel Oil Flow Enhancement Chemistry for Unconventional Formations Evaluated and Optimized by Cutting-Edge Methodology
E. Cambre, A. Abedini, X. Zhang; K. Boyle, E. Hughes
URTEC-2019-648-MS, July 2019
A B S T R A C T
The objective of this paper is to present a new innovative methodology that can be used to develop and evaluate the efficacy of enhanced flowback chemistries such as a novel
oil-based surface modifier. This unique chemistry has been optimized to penetrate into the nanonetwork of formations, such as the Wolfcamp, with pore throat sizes as low as 110 nm at pressure differentials of only 225 psi, thereby demonstrating the ability to increase the volume of oil recovered during flowback by 250% and increasing the average producing flowrate by 194% during testing.
Measurement of Propane and Butane Diffusion into Heavy Oil using Microfluidics - Is Small Better?
Hongying Zhao; Scott Pierobon; Adam Pettigrew; Jacques Doan-Prevost; Olivier-Francois Garnier; Thomas de Haas
SPE-193015-MS, November 2018
A B S T R A C T
A common issue in thermal oil recovery is that a high-permeability path in the reservoir diverts steam from reaching the bulk of the pay region. Injection of thermal foams is an effective approach to improve the oil recovery factor by increasing the effective viscosity of gas phase. Conducting conventional laboratory testing on thermal foams is time consuming, often not representative of field conditions, and delivers limited amount of data.
Rapid Microfluidic Analysis of Thermal Foam Stability at 250 Degrees Celsius
Bo Bao; Aaron Sanders; Ginger Ren; Thomas de Haas
SPE-18895-MS, November 2017
A B S T R A C T
A common issue in thermal oil recovery is that a high-permeability path in the reservoir diverts steam from reaching the bulk of the pay region. Injection of thermal foams is an effective approach to improve the oil recovery factor by increasing the effective viscosity of gas phase. Conducting conventional laboratory testing on thermal foams is time consuming, often not representative of field conditions, and delivers limited amount of data.
Publications
What's New in Production - Interface Fluidics
Leonard Kalfayan
World Oil, August, 2024
Abstract:
With hydraulic fracturing, especially in unconventional wells, the industry has moved to the “well factory” approach. I used to called that the “cookie cutter” approach, which in my mind is the same thing, but with man (or all) industries, terminology is developed to pain a positive picture or even one suggesting advancing technology rather than stagnation.
Wicked Energy Podcast
The conversation expands to address the importance of water compatibility with oil field fluids and its effect on well performance, regulatory changes in fluid management, and the integration of fluid analysis technology for sustainability in the industry. Stuart also emphasizes competitive differentiation and the need for companies to focus on their areas of expertise.
Sensitivity Analysis of CO2 Minimum Miscibility Pressure Optimizes Gas‑Injection EOR
Journal of Petroleum Technology, June 1, 2024
A B S T R A C T
The authors present an efficient microfluidic platform to measure high-quality minimum miscibility pressure data of CO2 with various impurities faster and easier.
How Edmonton’s Interface Fluidics is ‘Breathing New Life’ into Petroleum Industry
Thomas Knowlton
Calgary Tech, March 23, 2023
A B S T R A C T
The oil and gas sector’s digitization presents an opportunity to the tune of $2.5 trillion of value, according to an Accenture report titled “The Digital Energy Revolution: Are You Ready?”
However, the World Economic Forum reports the industry has been slow to adapt to the ongoing digital transition.
Interface Fluidics has nonetheless been making waves in Alberta’s oil and gas industry with cutting-edge technology since the firm was founded in Edmonton in 2015.
Interface Fluidics: Calgary tech for faster data and lower emissions
Calgary Economic Development, October 13, 2022
A B S T R A C T
Calgary-based tech firm Interface Fluidics helps energy companies reduce their carbon footprint with faster access to data that makes a difference. An example of homegrown innovation that solves global challenges, its SapphireLab platform is the world’s first microfluidic system that simplifies data collection in high-pressure and high-temperature conditions.
Interface Fluidics Announces Joint Industry Project with Equinor and ExxonMobil to Bring PVT Testing Into the Field
Business Wire, January 18, 2022
A B S T R A C T
CALGARY, Alberta–Two months after closing a Series B fundraise, Interface Fluidics has announced a joint industry project (JIP) with Equinor and ExxonMobil to accelerate the deployment of the world’s first compact, rapid fluid screening equipment for oil and gas. Essentially a portable laboratory, this technology will revolutionize pressure-volume-temperature (PVT) testing, an essential part of the exploration and production process for the oil and gas industry.
Alumni Tips at the Equinor & Techstars Energy Accelerator
Trupti Suryawanshi
Techstars November 18, 2021
A B S T R A C T
Like all Techstars programs, the Equinor & Techstars Energy Accelerator is a mentorship-driven program but with a twist – it takes place inside an energy major and receives full-time support from a team of Capgemini consultants!
Interface Fluidics raises $6.7 million CAD to accelerate deployment of oil recovery tech
A B S T R A C T
Calgary-based Interface Fluidics has raised $6.7 million CAD ($5.4 million USD) in a Series B investment round led by Equinor Ventures, the corporate venture arm of energy company Equinor.
Can Fracturing Chemicals Hurt Production? There Are Some Good Reasons To Think So
Journal of Petroleum Technology, September 9, 2021
A B S T R A C T
The obsession with better hydraulic fracturing has steadily pushed on shale production in year one, but the decline remains steep. Chemistry could help explain, and perhaps extend, the short productive life of these wells.
Inside a Venture-Backed Tech Company’s Dash To Make Oilfield Fluid Testing More Accessible
Journal of Petroleum Technology, March 10, 2021
A B S T R A C T
Microfluidics—the study of fluid interaction in micro- or nanometer-sized channels—is a science that has existed in the biomedical field for decades. In fact, it is used quite extensively in many everyday objects, such as pregnancy tests or inkjet printers. Only more recently has the science been broadly adopted in the energy sector. Microfluidics, fluid mechanics, and fluid transport have been studied extensively in academia, and it is from these academic labs that brilliant ideas give way to potential commercial success.
Micro-Slimtube Shrinks EOR Screening From Months to a Week
Journal of Petroleum Technology, February 9, 2021
A B S T R A C T
Interface Fluidics carved out a niche for itself in the oilfield testing sector a few years ago with a new alternative to coreflooding. Now, along with Equinor, the Calgary-based company is taking on another industry laboratory stalwart: the slimtube test.
Oilfield testing firm Interface Fluidics says it is one step closer to reinventing the industry’s pressure-volume-temperature (PVT) testing portfolio after the development of a smaller, faster version of yet another laboratory stalwar
Interface Fluidics Secures $4.5M in Series A Funding - Helping Operators Increase Oil Recovery and Reduce Environmental Impact Using Disruptive Technology Platform
Financial Post, August 27, 2019
A B S T R A C T
Equinor Technology Ventures (ETV) and Techstars Co-Lead Investment into Nanotechnology Company.
CALGARY, Alberta — Interface Fluidics Limited (Interface) today announced a Series A fundraise of $4.5M USD from leading multinational energy company, Equinor, and global accelerator, Techstars.
Reservoir-on-a-Chip Technology Opens a New Window Into Oilfield Chemistry
Trent Jacobs
Journal of Petroleum Technology, December 31, 2018
A B S T R A C T
An oil and gas startup has attracted the business with a major operator thanks to its ability to forecast whether production-enhancing chemicals will work as advertised.
Ten companies selected for Techstars Energy Accelerator in partnership with Equinor
Equinor, August 23, 2018
A B S T R A C T
Equinor today announces the inaugural class of global start-up companies selected to participate in the Techstars Energy Accelerator.
The ten start-up companies have been selected from hundreds of applicants across 38 countries. They will seek to accelerate their development through an intensive 13-week program, tapping into a global network of experts from Equinor and Techstars as well as the partnering companies KONGSBERG and McKinsey & Company.
2017 Winner: Outstanding Science And Technology Start-Up
Minimizing Risk Through Microfluidic Solutions
Jessica Luc
ASTech Awards, 2017
A B S T R A C T
Running a field pilot for an oil reservoir is a risky endeavour.
Although the rewards can be great, a very simple field pilot it will cost a minimum of $10 million and the venture will put the reserve on the line. If the calculations and chemistry of the extraction fluids aren’t thoroughly tested in the specific reservoir environment, injecting these chemical compositions into the well can damage these valuable assets.
Startup of the Week: Interface Fluidics builds a new way to model petroleum reservoirs
Lloyed Lobo
Calgary Herald, April 15, 2016
A B S T R A C T
Oil and gas producers are always looking for new technologies and processes to increase productivity while reducing their environmental impact, specifically in steam assisted gravity drainage (SAGD) projects.
Producers and the Alberta Energy Regulator both require very high levels of confidence before anything new is deployed in the field.