Mechanical Earth Modeling for a vertical well drilled in a naturally fractured tight carbonate gas reservoir in the Persian Gulf

Kidambi, Tapan; Kumar, G. Suresh

doi:10.1016/j.petrol.2016.01.003

Cited by 85 publications

(16 citation statements)

References 24 publications

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“…Determining the magnitudes and orientations of the principal stresses is imperative in any fault reactivation analysis. The regional stress field at any given depth consists of three principal stress magnitudes: the vertical stress (σ V ) usually considered to be solely due to the weight of the overburden, the minimum horizontal stress (σ hmin ), and the maximum horizontal stress (σ Hmax ) (Kidambi and Kumar 2016). Mathematically, the magnitude of vertical stress σ V can be calculated by integration of rock densities from the surface to the depth of interest, z (Zoback et al 2003):…”

Section: In Situ Stresses Magnitudes and Orientationsmentioning

confidence: 99%

Estimation of the current stress field and fault reactivation analysis in the Asmari reservoir, SW Iran

et al. 2019

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Knowing the current condition of the faults and fractures in a reservoir is crucial for production and injection activities. A good estimation of the fault reactivation potential in the current stress field is a useful tool for locating the appropriate spot to drill injection wells and to calculate the maximum sustainable pore pressure in enhanced oil recovery and geosequestration projects. In this study, after specifying the current stress state in the Gachsaran oilfield based on Anderson's faulting theory, the reactivation tendency of four faults (F1, F2, F3, and F4) in the Asmari reservoir is analyzed using 3D Mohr diagrams and slip tendency factors. Results showed that all the faults are stable in the current stress state, and F2 has the potential to undergo the highest pore pressure build-up in the field. On the other hand, F3 has the proper conditions (i.e., strike and dip referring to σ Hmax orientation) for reactivation. Stress polygons were also applied to show the effect of the pore pressure increase on fault stability, in a graphical manner. According to the results, the best location for drilling a new injection well in this part of the field is the NW side of F2, due to the lower risk of reactivation. It was found that both methods of 3D Mohr diagrams and slip tendency factors predict similar results, and with the lack of image logs for stress orientation determination, the slip tendency method can be applied. The results of such studies can also be used for locating safe injection points and determining the injection pressure prior to numerical modeling in further geomechanical studies.

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Section: In Situ Stresses Magnitudes and Orientationsmentioning

confidence: 99%

Estimation of the current stress field and fault reactivation analysis in the Asmari reservoir, SW Iran

et al. 2019

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“…Fig. 9 illustrates the calculated values for S H max derived from three different poroelastic methods (Blanton and Olson, 1999;Fjar et al, 2008;Kidambi and Kumar, 2016) with those derived from breakout analysis (Barton et al, 1988). We have assigned the name "poroelastic" to the Fjar et al (2008)'s method in which tectonic strains are derived from the leakoff test.…”

Section: Resultsmentioning

confidence: 99%

“…Furthermore, to provide an additional comparison, Eq. ( 14) proposed by Kidambi and Kumar (2016) has also been also applied to estimate tectonic strain components (ε x and ε y ).…”

Section: Determination Of S H Max and Wellbore Rock Failure Typesmentioning

confidence: 99%

Breakouts derived from image logs aid the estimation of maximum horizontal stress: A case study from Perth Basin, Western Australia

Faraji

Rezagholilou

Ghanavati

et al. 2020

Adv. Geo-Energy Res.

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In-situ stresses are highly important for wellbore stability studies during drilling, completion and production. Different methods are available to estimate the horizontal stresses especially maximum horizontal stress. Typically, Circumferential Borehole Image Logs can be run to determine the direction and width of breakouts and then stresses at different depths based on the equation developed by Barton et al. (1988). This research focuses on image logs from Harvey-1 well located in the Southern Perth basin to compare the maximum horizontal stresses obtained by various methods. The magnitudes of stresses from the breakout width approach (Barton's method) exhibit a considerable offset in comparison with elastic methods. Further investigations show that the likely reason for the offset relates to the fundamental assumption of the breakout width approach in which shear failures are considered to be constrained to horizontal planes. Failures within the wellbore are not necessarily horizontal and can be developed in different non-planar trajectories with various angles to the horizontal plane. Furthermore, the possible in-situ stresses from regional studies are constrained by means of stress polygons against which the reliability of results from breakout methods can be checked. Results indicate that due diligence and special care must be exercised for determination of maximum stresses from breakouts and more reliable methods are required than those currently used.

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“…P p is pore pressure. ε x and ε y are a strain in σ h and σ H directions, respectively, as given in equation equations (11) and (12) [118,19]:…”

Section: -5 Horizontal Stress Magnitudes and Orientationsmentioning

confidence: 99%

Geomechanical Analysis to Avoid Serious Drilling Hazards in Zubair Oilfield, Southern Iraq

Shaban

Hadi

2020

eijs

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Zubair oilfield is an efficient contributor to the total Iraqi produced hydrocarbon. Drilling vertical wells as well as deviated and horizontal wells have been experiencing intractable challenges. Investigation of well data showed that the wellbore instability issues were the major challenges to drill in Zubair oilfield. These experienced borehole instability problems are attributed to the increase in the nonproductive time (NPT). This study can assist in managing an investment-drilling plan with less nonproductive time and more efficient well designing. To achieve the study objectives, a one dimension geomechanical model (1D MEM) was constructed based on open hole log measurements, including Gamma-ray (GR), Caliper (CALI), Density (RHOZ), sonic compression (DTCO) and shear (DTSM) wave velocities , and Micro imager log (FMI). The determined 1D MEM components, i.e., pore pressure, rock mechanical properties, in-situ principal stress magnitudes and orientations, were calibrated using the data acquired from repeated formation test (RFT), hydraulic fracturing test (Mini-frac), and laboratory rock core mechanical test (triaxial test). Then, a validation model coupled with three failure criteria, i.e., Mohr-Coulomb, Mogi-Coulomb, and Modified lade, was conducted using the Caliper and Micro-imager logs. Finally, sensitivity and forecasting stability analyses were implemented to predict the most stable wellbore trajectory concerning the safe mud window for the planned wells. The implemented wellbore instability analysis utilizing Mogi-Coulomb criterion demonstrated that the azimuth of 140o paralleling to the minimum horizontal stress is preferable to orient deviated and horizontal wells. The vertical and slightly deviated boreholes (1ess than 30o) are the most stable wellbores, and they are recommended to be drilled with 11.6 -12 ppg mud weight. The highly deviated and horizontal wells are recommended to be drilled with a mud weight of 12-12.6 ppg.

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Mechanical Earth Modeling for a vertical well drilled in a naturally fractured tight carbonate gas reservoir in the Persian Gulf

Cited by 85 publications

References 24 publications

Estimation of the current stress field and fault reactivation analysis in the Asmari reservoir, SW Iran

Estimation of the current stress field and fault reactivation analysis in the Asmari reservoir, SW Iran

Breakouts derived from image logs aid the estimation of maximum horizontal stress: A case study from Perth Basin, Western Australia

Geomechanical Analysis to Avoid Serious Drilling Hazards in Zubair Oilfield, Southern Iraq

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