Calculation of micro-annulus size in casing-cement sheath-formation system under continuous internal casing pressure change

Chu, W.Y.; Shen, Jiyun; Yang, Yunfei; Li, Yong; Gao, Deli

doi:10.1016/s1876-3804(15)30033-1

Cited by 93 publications

(28 citation statements)

References 5 publications

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“…24 Nonetheless, the cementing technology is hard to achieve because that the top of the formation under the deepwater is weak and the cementing fluid may loss. 24 Nonetheless, the cementing technology is hard to achieve because that the top of the formation under the deepwater is weak and the cementing fluid may loss.…”

Section: Comparison Of Pressure Relief Effect With Other Mitigationmentioning

confidence: 99%

“…Full sealing cementing is used to eliminate annulus, which seems effectively avoid APB produce. 24 Nonetheless, the cementing technology is hard to achieve because that the top of the formation under the deepwater is weak and the cementing fluid may loss. Besides, the method may cement the subsea wellhead without accurate operation.…”

Section: Comparison Of Pressure Relief Effect With Other Mitigationmentioning

confidence: 99%

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Mitigation of annular pressure buildup for deepwater wells using a recovery relief method

Tang

Chen

et al. 2019

Energy Science & Engineering

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Annular pressure buildup (APB) is induced by high‐temperature tubing fluid heating the trapped annular fluid, which leads to liquid thermal expansion at the production stage in deepwater wells. Casing would be burst or collapsed without APB mitigation. A novel recovery relief method was adopted to mitigate APB through the principle of differential pressure. To assess the application effect of the method, APB prediction model and pressure relief threshold determination method were proposed, where the transient heat transfer and volume and pressure coupling were involved. The laboratory test of the principle prototype was conducted so that the feasibility of the recovery relief method was validated. The numerical APB mitigation effect was simulated by the field example. The production simulation results indicated that the high‐temperature‐induced APB caused casing failure. The simulation of APB mitigation with both inward and outward directions demonstrated that the casings using outward mitigation method were safer with lower safe factor. Besides, comparing the mitigating effect to the rupture disk, the recovery relief method had more maximum allowable APB of annulus A. Additionally, compared to other 11 ordinary mitigation methods with the qualities of engineering reliability, technology feasibility, and economy, the recovery relief method had best mitigation performance. Therefore, the recovery relief method was recommended for APB mitigating practice.

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Section: Comparison Of Pressure Relief Effect With Other Mitigationmentioning

confidence: 99%

Section: Comparison Of Pressure Relief Effect With Other Mitigationmentioning

confidence: 99%

Mitigation of annular pressure buildup for deepwater wells using a recovery relief method

Tang

Chen

et al. 2019

Energy Science & Engineering

View full text Add to dashboard Cite

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“…In equation (11), parameter A is used to distinguish the maximum and minimum principal stress; A 1 when σ θθ > σ rr , while A − 1 for σ θθ < σ rr . When the failure coe cient F is positive, shear failure occurs.…”

Section: Cement Setting Stagementioning

confidence: 99%

“…e high casing pressure encountered in hydraulic fracturing tremendously challenges the well integrity [5][6][7]. e sealing failure could be in different types including shear or tensile failure of cement sheath [8] and microannulus at the cement-casing interface (first interface) or cement-formation interface (second interface) [9][10][11]. If the potential failure mode is correctly estimated, measures can be accordingly taken to ensure the well integrity.…”

Section: Introductionmentioning

confidence: 99%

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Full‐Life‐Cycle Analysis of Cement Sheath Integrity

Wang

Feng

et al. 2019

Mathematical Problems in Engineering

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This paper addresses evaluating the evolution of stress inside the casing-cement sheath-formation system during the cement injection, setting, completion, and production stages of hydrocarbon recovery. This full-life-cycle analysis of cement sheath integrity gives rise to assessment of potential failure mode (i.e., tensile mode, shear mode, and microannulus) in different stages, and the prevention measures can be proposed accordingly. Considering the loading history, two regimes should be distinguished. Before the accomplishment of cementation, as the cement slurry can merely withstand its hydraulic pressure, the in situ stress and the wellbore pressure are withstood by the rock and the casing, respectively. Once the cementation process is completed, the stress increment (e.g., hydraulic fracturing pressure) is withstood by the casing-cement sheath-formation system. The autogenous shrinkage of cement adversely affects the resistance of the system to all types of failure, whereas a moderate swelling of cement is favorable to the cement sheath integrity. In addition, the cement sheath integrity is strongly influenced by the depth: the failure is encountered more easily at the shallow layer. Both the hydraulic fracturing pressure in the completion stage and the increase in casing temperature in the production stage may lead to tensile circumferential stress, and the hydraulic fracturing is the most critical stage for the integrity of cement sheath.

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Formation mechanism of continuous gas leakage paths in cement sheath during hydraulic fracturing

Lian

Qian

et al. 2020

Energy Science & Engineering

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Shale gas reservoirs are characterized by low porosity and permeability. As a result, conventional development methods cannot be used for commercial production of the gas. Therefore, hydraulic fracturing technology is required to achieve higher yields. [1][2][3][4][5] However, this method can seriously threaten the integrity (eg, sealing failure) of the cement sheath, leading to sustained casing pressure (SCP). 6 The reason for SCP is that the down-hole fluid migrates to the wellhead through continuous leakage paths, such as a microannulus between the casing and cement sheath or between the cement sheath and formation, microcracks in cement sheath, and casing threads, and then, the gas accumulates at the wellhead. [7][8][9] That is, the formation of SCP has two necessary conditions. 10,11 One is the gas/fluid source, and the other is the continuous leakage paths.Because the cement sheath is an important part of the wellbore barrier, it has been the focus of extensive research. The failure modes of the cement sheath usually include debonding,

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Calculation of micro-annulus size in casing-cement sheath-formation system under continuous internal casing pressure change

Cited by 93 publications

References 5 publications

Mitigation of annular pressure buildup for deepwater wells using a recovery relief method

Mitigation of annular pressure buildup for deepwater wells using a recovery relief method

Full‐Life‐Cycle Analysis of Cement Sheath Integrity

Formation mechanism of continuous gas leakage paths in cement sheath during hydraulic fracturing

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