SPE has recognized Eric Delamaide for his exceptional service and contribution in the Canadian Region.
Eric Delamaide of IFP Canada has been selected to receive international recognition for his outstanding service in 2017 as a Technical Editor of SPE’s peer-reviewed scholarly journal under Reservoir Evaluation and Engineering. This prestigious accolade is exclusively awarded to only 1% of SPE’s 110,000 members worldwide.
Tristan Euzen was nominated on the Board of Directors of the GeoConvention Partnership by the Canadian Society of Petroleum Geologist.
His mission involves defining strategies to ensure high quality technical content for the conference, to benefit delegates, exhibitors, sponsors, as well as the members of the partner societies.
Expressing surprise that T&T had not taken advantage of the latest oil production technology despite the crisis in oil production, Canadian reservoir engineer Eric Delamaide is recommending that polymer flooding and foam flooding be used in Trinidad to extract oil.
Eric Delamaide of IFP Canada has been selected to receive international recognition for his outstanding service in 2016 as a Technical Editor of SPE’s peer-reviewed scholarly journal under Reservoir Evaluation and Engineering and of the SPE Journal. These prestigious accolades are exclusively awarded to only 1% of SPE’s 110,000 members worldwide.
Eric Delamaide of IFP Canada has been selected to receive international recognition for his outstanding service in 2015 as a Technical Editor of SPE’s peer-reviewed scholarly journal under Reservoir Evaluation and Engineering. This prestigious accolade is exclusively awarded to only 1% of SPE’s 110,000 members worldwide.
Find out more about IFP Canada experts here: https://ifp-canada.com/about-us/management-team/
Nowadays steam injection is commonly used as a thermal EOR method. However this process is also associated with chemical reactions in the reservoirs, called aquathermolysis, which produce the highly toxic and corrosive acid gas H2S in the presence of sulfur-rich heavy oil.
The overall objective of this work is to understand the aquathermolysis reactions in reservoirs undergoing steam injections and provide Oil companies with a numerical model for reservoir simulators that forecasts H2S production risk.
Heavy oil extraction is mostly based on thermal EOR processes. Warming up the reservoir reduces oil viscosity, makes it more mobile and in turn enhances heavy oil recovery. The most prominent thermal heavy oil EOR method relies on steam injection. This recovery process consumes high quantities of fresh water and energy to produce the steam, and heat loss due to reservoir heterogeneities and thief zones must be minimized. For that purpose, steam foams can be used to decrease steam mobility and improve its utilization by a better distribution in the reservoir. Selection of appropriate products for steam harsh temperature conditions poses several challenges regarding chemicals stability and foam durability. We have shown in previous papers that synergistic association of thermally stable surfactants can highly improve high temperature foaming performances. Here, we extend these results to specific surfactant formulations designed to provide enhanced bulk viscosity. These formulations are intended to compensate for the strong decrease of water viscosity with temperature. This is expected to enhance steam foams lifetime and in turn provide a better steam mobility control in application conditions.
Bulk foam half-life is highly dependent on experimental conditions, in particular on the initial state of the foam in terms of quality and bubble size. This is even truer for steam foams that are also highly sensitive to possible temperature gradients. An optimized experimental setup has been developed to evaluate high temperature foam half-life obtained with standard and enhanced viscosity formulations. We couple these measurements with rheology and mobility reduction evaluation in sandpack experiments.
Based on these various parameters, we try to extract correlations between bulk steam foam half-life, bulk viscosity and mobility reduction in porous media.
This paper describes the characteristics of newly developed enhanced viscosity surfactant formulations, and also provides data regarding impact of viscosity on high temperature foam stability and mobility reduction.
This document will highlight the challenges with produced water treatments that facility engineers and operators will have in preparing for a chemical EOR project. The methodology used will help identify common issues, and then emphasize procedures to mitigate the risk to the operations. The complete water cycle will be analyzed and topics will include chemical interactions of the EOR products and production chemistry as well as EOR chemicals preparation.
Chemical Enhanced Oil Recovery (EOR) has seen numerous applications worldwide onshore but very few offshore. The reasons for that are mostly related to the technical and logistical challenges that need to be overcome for the successful implementation of chemical EOR: transporting various chemicals to the platforms, the need for space for the mixing skids and storing chemicals on the platforms, the need to use sea water as the injection fluid among others. As primary and secondary recovery reach their technical and economical limits in offshore fields, the operators are faced with the dilemma of abandoning the field and the platforms or resorting to EOR to increase recovery and extend the life of the field. Non chemical EOR techniques face their own challenges such as the need for large gas supply for gas injection so chemical methods cannot be ruled out so easily. However new approaches need to be defined to make chemical EOR a realistic method for offshore reservoirs. A large part of these issues arise from the mindset which associates chemical EOR with Alkali-Surfactant-Polymer injection. The approach proposed is to use only surfactant in cases where polymer is not absolutely required and to eliminate alkali altogether. This will eliminate various obstacles such as deck space limitations and the need to soften the injection water. This approach opens new doors for chemical Enhanced Recovery offshore. Such an approach is possible thanks to the progress in surfactant formulation and the development of adsorption inhibitors which allow dealing with seawater as an injection fluid. The novelty is not the technology but the way the standard approach is discarded to the benefit of a simpler solution.