Abdul Ghani, Mohamad (IFP Energies nouvelles) | Ayache, Simon Victor (IFP Energies nouvelles) | Batôt, Guillaume (IFP Energies nouvelles) | Gasser-Dorado, Julien (IFP Energies nouvelles) | Delamaide, Eric (IFP Technologies Canada Inc)
Although SAGD is a very popular in-situ extraction method in Canada, this thermal process relies on huge energy and water consumption to generate the steam. Irregular growth of the steam-chamber due to heterogeneities further degrades its yield. Contact between the steam chamber and the overburden also leads to heat losses. The objective of this paper is to investigate how Foam Assisted-SAGD could mitigate these technical issues and improve the efficiency of the SAGD process. Compositional thermal reservoir simulations are used to simulate and analyze a Foam Assisted-SAGD pilot. The shear-thinning effect close to the wells is also accounted for. The simulations are run on a homogeneous model mimicking the Foster Creek project in Alberta, Canada. Several type of injection sequences have been analyzed in terms of foam formation, back-produced surfactants and cumulative Steam-Oil-Ratio. Results are compared with the original SAGD performance. In order to propagate the foaming surfactants throughout the steam chamber the injection sequence needs to be properly determined. A simple continuous Foam Assisted-SAGD injection would lead to an accumulation of surfactant between the wells due to gravity segregation, preventing the foam from acting on the upper part of the steam chamber. Furthermore surfactant production occurs after a few weeks due to the proximity of the producer and the injector. A proper injection strategy of the type SAGD/slug/SAGD/slug is found to delay the chemical breakthrough and increase the amount of surfactant retained in the reservoir while allowing the surfactant propagation throughout the steam chamber. After optimization the Foam Assisted-SAGD process appears to be technically promising.
Rizzato, Paolo (Eni S.p.A.) | Castano, Daniele (Eni S.p.A.) | Moghadasi, Leili (Eni S.p.A.) | Renna, Dario (Eni S.p.A.) | Pisicchio, Patrizia (Eni S.p.A.) | Bartosek, Martin (Eni S.p.A.) | Suhardiman, Yohan (Eni Australia Ltd.) | Maxwell, Andrew (Eni Australia Ltd.)
This paper describes the results of an integrated reservoir study aimed at producing hydrocarbons through a sustainable development from a green High Temperature (HT) giant CO2-rich gas field in the Australian offshore. The development concept addressed the complex challenge of exploiting resources while minimizing the carbon impact.
In order to characterize the reservoir in the most detailed way and to describe the fluids behaviour, a 1.8 million active cells compositional model has been built. An analytical aquifer has been coupled in order to represent the boundary conditions of the area.
The faults system, interpreted on seismic data by geophysicists, has been included in the simulation model. The selected development plan includes the re-injection of the produced CO2 into the aquifer of the reservoir itself. The supercritical CO2-brine relative permeability curves at reservoir conditions have been provided by Eni laboratories, where the experiments were performed.
Therefore, a detailed model has been built with the purpose of: Defining producing well and CO2 injector well locations, numbers and phasing to evaluate expected CO2 injectivity and CO2 breakthrough issues; Optimizing the development concept through a risk analysis approach; Estimating the CO2-rich gas injectivity and storage capacity in the saline aquifer of the reservoir; Predicting the behavior of the CO2-rich gas after re-injection (breakthrough timing and plume migration); Maximizing the CO2 sequestration in the reservoir.
Defining producing well and CO2 injector well locations, numbers and phasing to evaluate expected CO2 injectivity and CO2 breakthrough issues;
Optimizing the development concept through a risk analysis approach;
Estimating the CO2-rich gas injectivity and storage capacity in the saline aquifer of the reservoir;
Predicting the behavior of the CO2-rich gas after re-injection (breakthrough timing and plume migration);
Maximizing the CO2 sequestration in the reservoir.
Gasser-Dorado, Julien (IFP Energies nouvelles) | Ayache, Simon Victor (IFP Energies nouvelles) | Lamoureux-Var, Violaine (IFP Energies nouvelles) | Preux, Christophe (IFP Energies nouvelles) | Michel, Pauline (IFP Energies nouvelles)
SAGD is commonly used as a thermal EOR method to produce heavy oil. However it suffers from the production of acid gases formed by aquathermolysis chemical reactions that occur between the steam, the sulfur-rich oil and the mineral matrix. The objectives of this paper are to take advantage of a comprehensive chemical model coupled to compositional thermal reservoir simulations to predict and understand the H2S production variation at surface according to the type of reservoir.
Thermal reservoir simulations coupled to both a SARA based 10-component / 5-reaction chemical model fully calibrated against laboratory data and a compositional PVT are used to simulate SAGD processes on heavy oil fields in Athabasca, Canada. Numerical results are then analyzed to provide a comprehensive analysis of the mechanisms leading to in-situ H2S generation and its production at wellheads based on compositional thermal simulations coupled to a fully laboratory calibrated SARA-based chemical model. Composition of the pre-steam, post-steam and produced oil are compared to understand the effect of the aquathermolysis reactions. The impact of heterogeneities on H2S production both in-situ and at surface can also be observed and explained, especially the variations in vertical permeability. Then simple reservoir models with two facies are used to further understand the impact of heterogeneities on H2S production at surface. Overall heterogeneous cases show important changes in the temperature distribution, fluid flows, reactions kinetics and steam chamber shape that lead to H2S production variations at surface. This detailed description of the involved mechanisms in acid gases production will allow operators to better forecast their H2S risks according to their reservoir properties.
Ten years ago, news reports frequently cited peak oil as a looming problem facing our world. Technology and innovation has since been developed that allows us to tap into rocks that were previously deemed impossible to extract oil from, reversing this trend. The Western Canadian Sedimentary Basin has been a leader in this movement with entrepreneurs using new technology to develop our resources in a safe and reliable way. Ten years ago, news reports frequently cited peak oil as a looming problem facing our world. Technology and innovation has since been developed that allows us to tap into rocks that were previously deemed impossible to extract oil from, reversing this trend.
Previous studies demonstrate that Montney rock samples present a dual-wettability pore network. Recovery of the oil retained in the small hydrophobic pores is uniquely challenging. This study compares the performance of openhole-packer completion systems with that of cemented-liner completion systems in the northern Montney gas resource play. The Montney formation in Canada is one of the largest resource plays in North America.
Study Says Taylor Oil Spill Is up to 1,000 Times Worse Than Rig Owner's Estimate A new federal study estimates that, each day, about 380 to 4,500 gal of oil are flowing at the site where a company's oil platform was damaged after a hurricane. Up to 1,000 gallons of oil per day are being removed from the site of the Taylor Energy spill, says the owner of the company that installed a containment system. The Gulf Research Program of the National Academies of Sciences, Engineering, and Medicine has announced a new collaboration to support a pilot effort to convert an existing ocean mooring owned by Shell into the first long-term deep ocean observatory in the Gulf of Mexico. An oil spill that has been quietly leaking millions of barrels into the Gulf of Mexico has gone unplugged for so long that it now verges on becoming one of the worst offshore disasters in US history. Improved understanding of the coupled natural/human coastal system will help promote resilience of coastal communities and ecosystems under rapidly changing environmental conditions, says a new report from the National Academies of Sciences, Engineering, and Medicine.
Cenovus Energy announced that it reached 1 billion bbl of cumulative production from its oil sands facilities in northern Alberta, becoming the first company to reach this milestone using SAGD technology. Steam-assisted gravity drainage (SAGD) is a prime example of how structured research and development (R&D) has led to the commercial implementation of technology, helping unlock hydrocarbon resources to fulfill society’s energy demands.
Cenovus Energy announced that it reached 1 billion bbl of cumulative production from its oil sands facilities in northern Alberta, becoming the first company to reach this milestone using SAGD technology. Kevin Birn is part of the IHS North American Crude Oil Markets’ team and leads the IHS Energy Oil Sands Dialogue.
An improved occupational health and safety system comes into effect on 1 June to better protect Alberta workers and ensure they have the same rights as other Canadians. The Alberta Energy Regulator has issued two draft directives that will require upstream oil and gas operators to reduce methane emissions from upstream oil and gas sites by 45% from 2014 levels by 2025. On 16 June 2017, the Alberta Oil Sands Advisory Group released its report Recommendations on Implementation of the Oil Sands Emissions Limit Established by the Alberta Climate Leadership Plan.
One of the most important environmental issues of openpit mining is the closure of mine pit lakes. This article from Mining Engineering provides an account by Gerry Stephenson, who was chief mining engineer of Canmore Mines and was instrumental in the reclamation of Canmore Creek Mine pit lakes. Among other things, Bill C-69 has replaced the Canadian Environmental Assessment Act, 2012, with an Impact Assessment Act, replaced the National Energy Board Act with a Canadian Energy Regulator Act, and made changes to the Navigation Protection Act. A new regulation includes provisions related to the timely abandonment of "dormant sites," a new site classification that refers to inactive wellsites operated by solvent companies. "I have some patients whose symptoms I can’t explain," physician Ulrike Meyer said, describing nosebleeds, rare cancers, and respiratory illness among a dearth of data.