Interface debonding as a controlling mechanism for loss of well integrity: Importance for CO2 injector wells

Lecampion, Brice; Quesada, Daniel; Loizzo, Matteo; Bunger, Andrew P.; Kear, James; Deremble, Laure; Desroches, J.

doi:10.1016/j.egypro.2011.02.500

Cited by 46 publications

(11 citation statements)

References 3 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…It should be emphasized that Eq. A-10 is a more correct expression relating flow and pressure in mechanically generated pathways, such as those described in Lecampion et al (2010). The elasticity of the defect, and thus the dependence of hydraulic resistance on pressure, would make the use of equivalent permeability ineffective.…”

Section: Appendix A-simplified Correlation Between Wellhead Pressure mentioning

confidence: 99%

Quantifying the Risk of CO2 Leakage Through Wellbores

Loizzo

Akemu

Jammes

et al. 2011

SPE Drilling &Amp; Completion

View full text Add to dashboard Cite

Leakage through new or existing wellbores is considered a major risk for carbon dioxide (CO 2 ) geological storage. Long-term effective containment of CO 2 is required, and the presence of millions of suspended or abandoned wells exacerbates the potential risk in mature hydrocarbon provinces. Accurate estimates of risk profiles can support the acceptance of geological storage and the adoption of economically effective risk-prevention and -mitigation measures.Reliable data about long-term containment of CO 2 are almost nonexistent, so wells that exhibit a similar risk profile (such as gas storage, gas production, and steam injection) should be used as a proxy to assess failure rates and consequences for cemented wellbores.Statistical data about occurrence of leaks and their consequences are analyzed to determine the risk profile of CO 2 leaks. A smaller sample of data about leak rates is also analyzed to provide their statistical distribution. Rates and consequences are then compared to try to assess the order of magnitude of major and catastrophic leaks.Hydrothermal CO 2 leaks in natural analogs are also reviewed to compare the distribution of leak rates and the consequences upon health, safety, and environment of CO 2 releases to soil and atmosphere.Analysis of existing data will show that major leaks are likely to occur in less than two wells per 1,000, with the overwhelming majority of CO 2 leaks being small and with limited or negligible consequences.Given their risk profile, CO 2 wellbore leaks should be addressed through a routine risk-management approach. Their frequent occurrence requires effective prevention measures, such as understanding leaks and adapting and deploying practices to minimize their occurrence. On the other hand, their low impact ensures maximum effectiveness of mitigation measures, such as monitoring. Because leaks can be detected long before damage ensues, they can be observed to predict their long-term consequences and to plan the most effective intervention without unnecessary immediate operation shutdowns.In conclusion, the recommended course of action is to focus on risk prevention and early detection. This implies the evolution from a "no-leaks" attitude (even for negligible leak consequences) to one that seeks no damage and relies on tight surveillance.

show abstract

Section: Appendix A-simplified Correlation Between Wellhead Pressure mentioning

confidence: 99%

Quantifying the Risk of CO2 Leakage Through Wellbores

Loizzo

Akemu

Jammes

et al. 2011

SPE Drilling &Amp; Completion

View full text Add to dashboard Cite

show abstract

“…The defect is set in an elastic system: its width may vary when it is pressurized or when the surrounding stress changes, due for example to a pressure increase in the innermost casing (Brice Lecampion et al 2010). The corresponding elastic response is calculated by integrating the mechanical properties of the constitutive materials of the wellbore and the geometry of the defect in a 2D plain strain elasticity approach.…”

Section: Mechanicsmentioning

confidence: 99%

“…A pathway is defined as a zone of low hydraulic resistance. It can originate in the well construction -a poor cement job may not ensure the efficiency of the seal -or being the result of usual operations performed during the life of the well, such as temperature and pressure cycling (Brice Lecampion et al 2010). The resulting defects hydraulically connect portions of the cement sheath: a micro-annulus or a crack provides vertical connection (Figure 1-a) whereas a disking crack provides horizontal connection.…”

Section: Introductionmentioning

confidence: 99%

Assessment of Leakage Pathways Along a Cemented Annulus

et al. 2010

View full text Add to dashboard Cite

Well integrity is one of the major concerns when assessing the containment of a geological CO 2 storage. Whereas defect-free cement sheaths provide reliable barriers that prevent vertical migration or leakage of the stored CO 2 , significant leakage can occur if pathways appear in the cement seal: the stored fluid can flow through and alter their initial properties. A simulator has been built to numerically investigate the leakage rate of CO 2 rich fluid through a pathway along a cemented annulus. Careful analysis of the physics and characteristic dimensions of the phenomena allows coupling of the flow, the mechanics of any defect and the chemical reactions that take place in the materials (fluid and cement). Results of the simulation, besides predicting the instantaneous flow rate and hydraulic conductivity of the defect, show different mechanisms of flow rates variation with time: in particular, coupling between flow along the defect and chemical reaction between cement and CO 2 can lead to the deposition of minerals within the defect space. This may lead to a total plugging of the pathway -a self-healing of the cement. Based on dimensional analysis and semi-analytical solution, a criterion is defined in order to assess the long-term stability of the pathway.

show abstract

“…Tan et al [35] established a two-dimensional fluid-solid coupling model based on the discrete element method (DEM) and discussed the influence of cementation strength of rock bedding surfaces on hydraulic fracture propagation. Lecampion et al [36][37] used CZM to study the mechanical competition between transverse and longitudinal fractures, but the interfacial cracks were not considered. Integrated the relationship between the effective normal stress and fracture aperture into DDM, the dynamic behavior of the fracture apertures and the stress subjected are rigorously modeled [38].…”

Section: Introductionmentioning

confidence: 99%

Study on Synchronous Propagation Behavior of Hydraulic Fractures and Cementing Interfacial Cracks during Fracturing of Shale Horizontal Wells

et al. 2021

View full text Add to dashboard Cite

Large-scale staged hydraulic fracturing stimulation technology is an effective method to increase shale oil and gas recovery. However, cracks will appear along with the cementing interface and expand under the drive of fluid while hydraulic fracturing, failing wellbore sealing. To solve this problem, the synchronous propagation model of hydraulic fractures and cementing interfacial cracks in hydraulic fracturing is established. The Newton iteration method and displacement discontinuity method are used to solve the propagation length of each fracture, and the effects of cement sheath parameters and fracture parameters on the interface failure range are studied. The results show that when multiple hydraulic fractures expand, the interfacial cracks are also affected by “stress shadow,” offering an asymmetric expansion, and the cementing interfacial cracks in the area between hydraulic fractures are easier to expand. The failure range of interface between the hydraulic fractures expands rapidly if the cement elastic modulus increases from 5 GPa to 10 GPa; while the cement elastic modulus is higher than 10 GPa, the failure area is mainly affected by the number of hydraulic fractures; the failure range is not affected by the number of hydraulic fractures if the hydraulic fracture spacing is less than 10 m or more than 30 m; while the crack spacing is between 10 m and 30 m, the more the number of hydraulic fractures, the easier it is to cause the interface failure range to increase and connect. The research results can provide a theoretical basis for the optimization of cement slurry systems and fracturing parameters.

show abstract

Interface debonding as a controlling mechanism for loss of well integrity: Importance for CO2 injector wells

Cited by 46 publications

References 3 publications

Quantifying the Risk of CO2 Leakage Through Wellbores

Quantifying the Risk of CO2 Leakage Through Wellbores

Assessment of Leakage Pathways Along a Cemented Annulus

Study on Synchronous Propagation Behavior of Hydraulic Fractures and Cementing Interfacial Cracks during Fracturing of Shale Horizontal Wells

Contact Info

Product

Resources

About