Pressure transient testing for assessment of wellbore integrity in the IEAGHG Weyburn–Midale CO2 Monitoring and Storage Project

Hawkes, Christopher D.; Gardner, Craig

doi:10.1016/j.ijggc.2012.12.022

Cited by 26 publications

(14 citation statements)

References 4 publications

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“…CO2 storage in depleted oil and gas reservoirs is considered as one of the most effective storage options because of several advantages including: (a) depleted oil and gas reservoirs have been extensively studied before and during the hydrocarbon exploration stage, including the storage capacity, (b) surface and underground infrastructure, e.g., injection wells and pipelines, already exist and can be utilised for the storage process either without or with only minor modifications [33,45,[68][69][70][71], and (c) the injection of gases such as CO2 as an EOR technique has been widely known and employed within the oil and gas industry and, therefore, such experience can be used for the storage process [43]. In addition, oil and gas reservoirs are valuable hydrocarboncontaining analogues that can be used to demonstrate the effectiveness of caprock or seal over geological periods [72], since if this was not the case, the oil and gas in such reservoirs would have escaped long ago.…”

Section: Depleted Oil and Gas Reservoirsmentioning

confidence: 99%

A review of developments in carbon dioxide storage

et al. 2017

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Carbon capture and storage (CCS) has been identified as an urgent, strategic and essential approach to reduce anthropogenic CO2 emissions, and mitigate the severe consequences of climate change. CO2 storage is the last step in the CCS chain and can be implemented mainly through oceanic and underground geological sequestration, and mineral carbonation. This review paper aims to provide state-of-the-art developments in CO2 storage. The review initially discussed the potential options for CO2 storage by highlighting the present status, current challenges and uncertainties associated with further deployment of established approaches (such as storage in saline aquifers and depleted oil and gas reservoirs) and feasibility demonstration of relatively newer storage concepts (such as hydrate storage and CO2-based enhanced geothermal systems). The second part of the review outlined the critical criteria that are necessary for storage site selection, including geological, geothermal, geohazards, hydrodynamic, basin maturity, and economic, societal and environmental factors. In the third section, the focus was on identification of CO2 behaviour within the reservoir during and after injection, namely injection-induced seismicity, potential leakage pathways, and long-term containment complexities associated with CO2-brine-rock interaction. In addition, a detailed review on storage capacity estimation methods based on different geological media and trapping mechanisms was provided. Finally, an overview of major CO2 storage projects, including their overall outcomes, were outlined. This review indicates that although CO2 storage is a technically proven strategy, the discussed challenges need to be addressed in order to accelerate the deployment of the technology. In addition, beside the necessity of technoeconomic aspects, public acceptance of CO2 storage plays a central role in technology deployment, and the current ethical mechanisms need to be further improved.

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Section: Depleted Oil and Gas Reservoirsmentioning

confidence: 99%

A review of developments in carbon dioxide storage

et al. 2017

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“…[] have measured permeability values between 1E‐19 m 2 and 6.5E‐20 m 2 for a class G cement). The large range of published effective well permeability values (7–80×10 −21 m 2 for Hawkes and Gardner []; 5–10×10 −16 m 2 for Crow et al . []; 2.5×10 −14 m 2 and 1.6×10 −13 m 2 for Duguid et al .…”

Section: Discussion On the Well‐system Evolutionmentioning

confidence: 99%

“…Hydro tests have been proposed in the literature [ Crow et al ., ; Duguid et al ., ; Hawkes and Gardner , ]. They all assess the well integrity by using the concept of effective well permeability presented by Gasda et al .…”

Section: Methodsmentioning

confidence: 99%

Well integrity assessment under temperature and pressure stresses by a 1:1 scale wellbore experiment

Manceau

Trémosa

Audigane

et al. 2015

Water Resources Research

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A new in situ experiment is proposed for observing and understanding well integrity evolution, potentially due to changes that could occur during a well lifetime. The focus is put on temperature and pressure stresses. A small section of a well is reproduced at scale 1:1 in the Opalinus Clay formation, representative of a low permeable caprock formation (in Mont Terri Underground Rock Laboratory, Switzerland). The well-system behavior is characterized over time both by performing hydro-tests to quantify the hydraulic properties of the well and their evolution, and sampling the fluids to monitor the chemical composition and its changes. This paper presents the well integrity assessment under different imposed temperature (17-528C) and pressure (10-28 bar) conditions. The results obtained in this study confirm the ability of the chosen design and observation scale to estimate the evolution of the well integrity over time, the characteristics of the flow along the well-system and the reasons of the observed evolution. In particular, the estimated effective well permeability is higher than cement or caprock intrinsic permeability, which suggest preferential flow pathways at interfaces especially at the very beginning of the experiment; the significant variations of the effective well permeability observed after setting pressure and temperature stresses indicate that operations could influence well integrity in similar proportions than the cementing process.

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“…Before a monitoring technology ranking could be developed it was important to review the previous WMP work relating to risk assessment, leakage scenarios, and monitoring. The Best Practice Manual from the WMP (PTRC, 2012a) was reviewed along with the following data and results provided by the PTRC including (URS, 2010b) (URS, 2010a), (Irani, 2012) (PTRC, 2012a), (Crow, et al, 2010), (Duguid, et al, 2013), (Duguid, et al, 2014), (Hawkes & Gardner, 2013), (Cavanagh, 2013).…”

Section: Site Specific Project Reviewmentioning

confidence: 99%

Monitoring technology ranking methodology for CO2-EOR sites using the Weyburn-Midale Field as a case study

Zaluski

El-Kaseeh

Lee

et al. 2016

International Journal of Greenhouse Gas Control

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In a carbon dioxide (CO 2) enhanced oil recovery (EOR) operation, CO 2 is injected into a hydrocarbon reservoir to enhance hydrocarbon production. Much of this CO 2 is recycled for reinjection when the hydrocarbons are produced; however, a large amount is permanently stored in the reservoir. If a CO 2-EOR operation intends to claim CO 2 storage credit for this stored CO 2, it needs to demonstrate that the CO 2 is safely stored in the subsurface by strategically deploying monitoring technologies. For the operation to maintain profitability goals, these monitoring technologies also need to be cost-effective. If the safety of the CO 2 storage is demonstrated, the project will be classified a carbon capture, utilization, and storage (CCUS) project. The main goal of CO 2-EOR is oil production, not CO 2 storage. Because CO 2-EOR originated as an oil production technique, the EOR process is subject to a less stringent regulatory environment than CCUS projects. These differences in the CO 2 storage accounting and the regulatory environment mean that CO 2-EOR projects need to demonstrate the long-term containment of CO 2 within the reservoir with additional monitoring in order to claim any CO 2 emission credits. Converting a CO 2-EOR project to a CCUS project requires a tailored site-specific approach. The methodology employed will differ from project to project due to differences in project risk, geology, operations history, and regulatory environment. This paper takes the CO 2-EOR Weyburn-Midale Field (WMF) as a case study to rank monitoring strategies that may be required to shift the WMF from CO 2-EOR to CCUS. This study consisted of an in-depth review of the identified risks, the potential leakage pathways, various regulatory requirements, and the already deployed monitoring techniques. The goal was to develop a risk-, economic-, and regulatory-based monitoring technology ranking system that is suitable for the WMF. While specific to the WMF, the methodology presented here can be adapted by other CO 2-EOR operators who endeavor to demonstrate that the non-recycled portion of the CO 2 injected into the formation(s) by their project(s) is permanently stored.

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Pressure transient testing for assessment of wellbore integrity in the IEAGHG Weyburn–Midale CO2 Monitoring and Storage Project

Cited by 26 publications

References 4 publications

A review of developments in carbon dioxide storage

A review of developments in carbon dioxide storage

Well integrity assessment under temperature and pressure stresses by a 1:1 scale wellbore experiment

Monitoring technology ranking methodology for CO2-EOR sites using the Weyburn-Midale Field as a case study

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