Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs

Abstract This study aims to analyze in situ stresses and wellbore stability in one of the Iranian gas reservoirs by using well log data, including density, sonic (compressional and shear slowness), porosity, formation micro-image (FMI) logs, modular formation dynamics tester (MDT), and rock mechanic...
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Gespeichert in:

Autor*in:	Sobhani, Alireza [verfasserIn] Kadkhodaie, Ali [verfasserIn] Nabi-Bidhendi, Majid [verfasserIn] Tadayoni, Mehdi [verfasserIn]

Format:	E-Artikel
Sprache:	Englisch

Erschienen:	2024

Schlagwörter:	Geomechanics parameters Wellbore stability Poroelastic modulus In situ stresses

Anmerkung:	© The Author(s) 2024

Übergeordnetes Werk:	Enthalten in: Journal of petroleum exploration and production technology - Springer International Publishing, 2011, 14(2024), 4 vom: 03. Feb., Seite 1035-1052
Übergeordnetes Werk:	volume:14 ; year:2024 ; number:4 ; day:03 ; month:02 ; pages:1035-1052

Links:	Volltext

DOI / URN:	10.1007/s13202-024-01750-6

Katalog-ID:	SPR055445810

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allfields	10.1007/s13202-024-01750-6 doi (DE-627)SPR055445810 (SPR)s13202-024-01750-6-e DE-627 ger DE-627 rakwb eng 540 VZ Sobhani, Alireza verfasserin aut Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs 2024 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © The Author(s) 2024 Abstract This study aims to analyze in situ stresses and wellbore stability in one of the Iranian gas reservoirs by using well log data, including density, sonic (compressional and shear slowness), porosity, formation micro-image (FMI) logs, modular formation dynamics tester (MDT), and rock mechanical tests. The high burial depth, high pore pressure, and strike-slip stress regime of the field require an optimal design of geomechanical parameters based on an integrated data set consisting of static and dynamic data, which is available for this study. Firstly, poroelastic modulus and vertical stress were calculated. Afterward, the Eaton’s equation was used to estimate pore pressure from well logging data. The geomechanical parameters were also calibrated through the interpretation of image data, the use of the modular formation dynamics tester (MDT), and laboratory rock mechanic tests. Employing poroelastic equations, the lowest and highest horizontal stresses were calculated. It was shown that the maximum horizontal stress and minimum horizontal stress correspond to sigma H and sigma h, indicating the strike-slope fault regime. The findings of this research indicated that the equivalent mud weight (EMW) resulted in 10–13 ppg suitable for the Kangan Formation and 11–14 ppg suitable for the Dalan Formation. Additionally, the well azimuth in the NE-SW direction provided the best stability for drilling the encountered formations. Therefore, the results of this study serve as cost-effective tools in planning adjacent wells in carbonate formations of gas field to predict the wellbore stability and safe mud window. Geomechanics parameters (dpeaa)DE-He213 Wellbore stability (dpeaa)DE-He213 Poroelastic modulus (dpeaa)DE-He213 In situ stresses (dpeaa)DE-He213 Kadkhodaie, Ali verfasserin aut Nabi-Bidhendi, Majid verfasserin aut Tadayoni, Mehdi verfasserin aut Enthalten in Journal of petroleum exploration and production technology Springer International Publishing, 2011 14(2024), 4 vom: 03. Feb., Seite 1035-1052 (DE-627)647654148 (DE-600)2595714-4 2190-0566 nnns volume:14 year:2024 number:4 day:03 month:02 pages:1035-1052 https://dx.doi.org/10.1007/s13202-024-01750-6 X:VERLAG 0 kostenfrei Volltext SYSFLAG_0 GBV_SPRINGER SSG-OLC-PHA GBV_ILN_20 GBV_ILN_22 GBV_ILN_23 GBV_ILN_24 GBV_ILN_31 GBV_ILN_39 GBV_ILN_40 GBV_ILN_60 GBV_ILN_62 GBV_ILN_63 GBV_ILN_65 GBV_ILN_69 GBV_ILN_70 GBV_ILN_73 GBV_ILN_95 GBV_ILN_105 GBV_ILN_110 GBV_ILN_151 GBV_ILN_161 GBV_ILN_170 GBV_ILN_213 GBV_ILN_230 GBV_ILN_285 GBV_ILN_293 GBV_ILN_602 GBV_ILN_2009 GBV_ILN_2014 GBV_ILN_2027 GBV_ILN_2055 GBV_ILN_2111 GBV_ILN_2129 GBV_ILN_4012 GBV_ILN_4037 GBV_ILN_4046 GBV_ILN_4112 GBV_ILN_4125 GBV_ILN_4126 GBV_ILN_4249 GBV_ILN_4305 GBV_ILN_4306 GBV_ILN_4307 GBV_ILN_4313 GBV_ILN_4322 GBV_ILN_4323 GBV_ILN_4324 GBV_ILN_4325 GBV_ILN_4338 GBV_ILN_4367 GBV_ILN_4700 AR 14 2024 4 03 02 1035-1052
spelling	10.1007/s13202-024-01750-6 doi (DE-627)SPR055445810 (SPR)s13202-024-01750-6-e DE-627 ger DE-627 rakwb eng 540 VZ Sobhani, Alireza verfasserin aut Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs 2024 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © The Author(s) 2024 Abstract This study aims to analyze in situ stresses and wellbore stability in one of the Iranian gas reservoirs by using well log data, including density, sonic (compressional and shear slowness), porosity, formation micro-image (FMI) logs, modular formation dynamics tester (MDT), and rock mechanical tests. The high burial depth, high pore pressure, and strike-slip stress regime of the field require an optimal design of geomechanical parameters based on an integrated data set consisting of static and dynamic data, which is available for this study. Firstly, poroelastic modulus and vertical stress were calculated. Afterward, the Eaton’s equation was used to estimate pore pressure from well logging data. The geomechanical parameters were also calibrated through the interpretation of image data, the use of the modular formation dynamics tester (MDT), and laboratory rock mechanic tests. Employing poroelastic equations, the lowest and highest horizontal stresses were calculated. It was shown that the maximum horizontal stress and minimum horizontal stress correspond to sigma H and sigma h, indicating the strike-slope fault regime. The findings of this research indicated that the equivalent mud weight (EMW) resulted in 10–13 ppg suitable for the Kangan Formation and 11–14 ppg suitable for the Dalan Formation. Additionally, the well azimuth in the NE-SW direction provided the best stability for drilling the encountered formations. Therefore, the results of this study serve as cost-effective tools in planning adjacent wells in carbonate formations of gas field to predict the wellbore stability and safe mud window. Geomechanics parameters (dpeaa)DE-He213 Wellbore stability (dpeaa)DE-He213 Poroelastic modulus (dpeaa)DE-He213 In situ stresses (dpeaa)DE-He213 Kadkhodaie, Ali verfasserin aut Nabi-Bidhendi, Majid verfasserin aut Tadayoni, Mehdi verfasserin aut Enthalten in Journal of petroleum exploration and production technology Springer International Publishing, 2011 14(2024), 4 vom: 03. Feb., Seite 1035-1052 (DE-627)647654148 (DE-600)2595714-4 2190-0566 nnns volume:14 year:2024 number:4 day:03 month:02 pages:1035-1052 https://dx.doi.org/10.1007/s13202-024-01750-6 X:VERLAG 0 kostenfrei Volltext SYSFLAG_0 GBV_SPRINGER SSG-OLC-PHA GBV_ILN_20 GBV_ILN_22 GBV_ILN_23 GBV_ILN_24 GBV_ILN_31 GBV_ILN_39 GBV_ILN_40 GBV_ILN_60 GBV_ILN_62 GBV_ILN_63 GBV_ILN_65 GBV_ILN_69 GBV_ILN_70 GBV_ILN_73 GBV_ILN_95 GBV_ILN_105 GBV_ILN_110 GBV_ILN_151 GBV_ILN_161 GBV_ILN_170 GBV_ILN_213 GBV_ILN_230 GBV_ILN_285 GBV_ILN_293 GBV_ILN_602 GBV_ILN_2009 GBV_ILN_2014 GBV_ILN_2027 GBV_ILN_2055 GBV_ILN_2111 GBV_ILN_2129 GBV_ILN_4012 GBV_ILN_4037 GBV_ILN_4046 GBV_ILN_4112 GBV_ILN_4125 GBV_ILN_4126 GBV_ILN_4249 GBV_ILN_4305 GBV_ILN_4306 GBV_ILN_4307 GBV_ILN_4313 GBV_ILN_4322 GBV_ILN_4323 GBV_ILN_4324 GBV_ILN_4325 GBV_ILN_4338 GBV_ILN_4367 GBV_ILN_4700 AR 14 2024 4 03 02 1035-1052
allfields_unstemmed	10.1007/s13202-024-01750-6 doi (DE-627)SPR055445810 (SPR)s13202-024-01750-6-e DE-627 ger DE-627 rakwb eng 540 VZ Sobhani, Alireza verfasserin aut Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs 2024 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © The Author(s) 2024 Abstract This study aims to analyze in situ stresses and wellbore stability in one of the Iranian gas reservoirs by using well log data, including density, sonic (compressional and shear slowness), porosity, formation micro-image (FMI) logs, modular formation dynamics tester (MDT), and rock mechanical tests. The high burial depth, high pore pressure, and strike-slip stress regime of the field require an optimal design of geomechanical parameters based on an integrated data set consisting of static and dynamic data, which is available for this study. Firstly, poroelastic modulus and vertical stress were calculated. Afterward, the Eaton’s equation was used to estimate pore pressure from well logging data. The geomechanical parameters were also calibrated through the interpretation of image data, the use of the modular formation dynamics tester (MDT), and laboratory rock mechanic tests. Employing poroelastic equations, the lowest and highest horizontal stresses were calculated. It was shown that the maximum horizontal stress and minimum horizontal stress correspond to sigma H and sigma h, indicating the strike-slope fault regime. The findings of this research indicated that the equivalent mud weight (EMW) resulted in 10–13 ppg suitable for the Kangan Formation and 11–14 ppg suitable for the Dalan Formation. Additionally, the well azimuth in the NE-SW direction provided the best stability for drilling the encountered formations. Therefore, the results of this study serve as cost-effective tools in planning adjacent wells in carbonate formations of gas field to predict the wellbore stability and safe mud window. Geomechanics parameters (dpeaa)DE-He213 Wellbore stability (dpeaa)DE-He213 Poroelastic modulus (dpeaa)DE-He213 In situ stresses (dpeaa)DE-He213 Kadkhodaie, Ali verfasserin aut Nabi-Bidhendi, Majid verfasserin aut Tadayoni, Mehdi verfasserin aut Enthalten in Journal of petroleum exploration and production technology Springer International Publishing, 2011 14(2024), 4 vom: 03. Feb., Seite 1035-1052 (DE-627)647654148 (DE-600)2595714-4 2190-0566 nnns volume:14 year:2024 number:4 day:03 month:02 pages:1035-1052 https://dx.doi.org/10.1007/s13202-024-01750-6 X:VERLAG 0 kostenfrei Volltext SYSFLAG_0 GBV_SPRINGER SSG-OLC-PHA GBV_ILN_20 GBV_ILN_22 GBV_ILN_23 GBV_ILN_24 GBV_ILN_31 GBV_ILN_39 GBV_ILN_40 GBV_ILN_60 GBV_ILN_62 GBV_ILN_63 GBV_ILN_65 GBV_ILN_69 GBV_ILN_70 GBV_ILN_73 GBV_ILN_95 GBV_ILN_105 GBV_ILN_110 GBV_ILN_151 GBV_ILN_161 GBV_ILN_170 GBV_ILN_213 GBV_ILN_230 GBV_ILN_285 GBV_ILN_293 GBV_ILN_602 GBV_ILN_2009 GBV_ILN_2014 GBV_ILN_2027 GBV_ILN_2055 GBV_ILN_2111 GBV_ILN_2129 GBV_ILN_4012 GBV_ILN_4037 GBV_ILN_4046 GBV_ILN_4112 GBV_ILN_4125 GBV_ILN_4126 GBV_ILN_4249 GBV_ILN_4305 GBV_ILN_4306 GBV_ILN_4307 GBV_ILN_4313 GBV_ILN_4322 GBV_ILN_4323 GBV_ILN_4324 GBV_ILN_4325 GBV_ILN_4338 GBV_ILN_4367 GBV_ILN_4700 AR 14 2024 4 03 02 1035-1052
allfieldsGer	10.1007/s13202-024-01750-6 doi (DE-627)SPR055445810 (SPR)s13202-024-01750-6-e DE-627 ger DE-627 rakwb eng 540 VZ Sobhani, Alireza verfasserin aut Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs 2024 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © The Author(s) 2024 Abstract This study aims to analyze in situ stresses and wellbore stability in one of the Iranian gas reservoirs by using well log data, including density, sonic (compressional and shear slowness), porosity, formation micro-image (FMI) logs, modular formation dynamics tester (MDT), and rock mechanical tests. The high burial depth, high pore pressure, and strike-slip stress regime of the field require an optimal design of geomechanical parameters based on an integrated data set consisting of static and dynamic data, which is available for this study. Firstly, poroelastic modulus and vertical stress were calculated. Afterward, the Eaton’s equation was used to estimate pore pressure from well logging data. The geomechanical parameters were also calibrated through the interpretation of image data, the use of the modular formation dynamics tester (MDT), and laboratory rock mechanic tests. Employing poroelastic equations, the lowest and highest horizontal stresses were calculated. It was shown that the maximum horizontal stress and minimum horizontal stress correspond to sigma H and sigma h, indicating the strike-slope fault regime. The findings of this research indicated that the equivalent mud weight (EMW) resulted in 10–13 ppg suitable for the Kangan Formation and 11–14 ppg suitable for the Dalan Formation. Additionally, the well azimuth in the NE-SW direction provided the best stability for drilling the encountered formations. Therefore, the results of this study serve as cost-effective tools in planning adjacent wells in carbonate formations of gas field to predict the wellbore stability and safe mud window. Geomechanics parameters (dpeaa)DE-He213 Wellbore stability (dpeaa)DE-He213 Poroelastic modulus (dpeaa)DE-He213 In situ stresses (dpeaa)DE-He213 Kadkhodaie, Ali verfasserin aut Nabi-Bidhendi, Majid verfasserin aut Tadayoni, Mehdi verfasserin aut Enthalten in Journal of petroleum exploration and production technology Springer International Publishing, 2011 14(2024), 4 vom: 03. Feb., Seite 1035-1052 (DE-627)647654148 (DE-600)2595714-4 2190-0566 nnns volume:14 year:2024 number:4 day:03 month:02 pages:1035-1052 https://dx.doi.org/10.1007/s13202-024-01750-6 X:VERLAG 0 kostenfrei Volltext SYSFLAG_0 GBV_SPRINGER SSG-OLC-PHA GBV_ILN_20 GBV_ILN_22 GBV_ILN_23 GBV_ILN_24 GBV_ILN_31 GBV_ILN_39 GBV_ILN_40 GBV_ILN_60 GBV_ILN_62 GBV_ILN_63 GBV_ILN_65 GBV_ILN_69 GBV_ILN_70 GBV_ILN_73 GBV_ILN_95 GBV_ILN_105 GBV_ILN_110 GBV_ILN_151 GBV_ILN_161 GBV_ILN_170 GBV_ILN_213 GBV_ILN_230 GBV_ILN_285 GBV_ILN_293 GBV_ILN_602 GBV_ILN_2009 GBV_ILN_2014 GBV_ILN_2027 GBV_ILN_2055 GBV_ILN_2111 GBV_ILN_2129 GBV_ILN_4012 GBV_ILN_4037 GBV_ILN_4046 GBV_ILN_4112 GBV_ILN_4125 GBV_ILN_4126 GBV_ILN_4249 GBV_ILN_4305 GBV_ILN_4306 GBV_ILN_4307 GBV_ILN_4313 GBV_ILN_4322 GBV_ILN_4323 GBV_ILN_4324 GBV_ILN_4325 GBV_ILN_4338 GBV_ILN_4367 GBV_ILN_4700 AR 14 2024 4 03 02 1035-1052
allfieldsSound	10.1007/s13202-024-01750-6 doi (DE-627)SPR055445810 (SPR)s13202-024-01750-6-e DE-627 ger DE-627 rakwb eng 540 VZ Sobhani, Alireza verfasserin aut Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs 2024 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © The Author(s) 2024 Abstract This study aims to analyze in situ stresses and wellbore stability in one of the Iranian gas reservoirs by using well log data, including density, sonic (compressional and shear slowness), porosity, formation micro-image (FMI) logs, modular formation dynamics tester (MDT), and rock mechanical tests. The high burial depth, high pore pressure, and strike-slip stress regime of the field require an optimal design of geomechanical parameters based on an integrated data set consisting of static and dynamic data, which is available for this study. Firstly, poroelastic modulus and vertical stress were calculated. Afterward, the Eaton’s equation was used to estimate pore pressure from well logging data. The geomechanical parameters were also calibrated through the interpretation of image data, the use of the modular formation dynamics tester (MDT), and laboratory rock mechanic tests. Employing poroelastic equations, the lowest and highest horizontal stresses were calculated. It was shown that the maximum horizontal stress and minimum horizontal stress correspond to sigma H and sigma h, indicating the strike-slope fault regime. The findings of this research indicated that the equivalent mud weight (EMW) resulted in 10–13 ppg suitable for the Kangan Formation and 11–14 ppg suitable for the Dalan Formation. Additionally, the well azimuth in the NE-SW direction provided the best stability for drilling the encountered formations. Therefore, the results of this study serve as cost-effective tools in planning adjacent wells in carbonate formations of gas field to predict the wellbore stability and safe mud window. Geomechanics parameters (dpeaa)DE-He213 Wellbore stability (dpeaa)DE-He213 Poroelastic modulus (dpeaa)DE-He213 In situ stresses (dpeaa)DE-He213 Kadkhodaie, Ali verfasserin aut Nabi-Bidhendi, Majid verfasserin aut Tadayoni, Mehdi verfasserin aut Enthalten in Journal of petroleum exploration and production technology Springer International Publishing, 2011 14(2024), 4 vom: 03. Feb., Seite 1035-1052 (DE-627)647654148 (DE-600)2595714-4 2190-0566 nnns volume:14 year:2024 number:4 day:03 month:02 pages:1035-1052 https://dx.doi.org/10.1007/s13202-024-01750-6 X:VERLAG 0 kostenfrei Volltext SYSFLAG_0 GBV_SPRINGER SSG-OLC-PHA GBV_ILN_20 GBV_ILN_22 GBV_ILN_23 GBV_ILN_24 GBV_ILN_31 GBV_ILN_39 GBV_ILN_40 GBV_ILN_60 GBV_ILN_62 GBV_ILN_63 GBV_ILN_65 GBV_ILN_69 GBV_ILN_70 GBV_ILN_73 GBV_ILN_95 GBV_ILN_105 GBV_ILN_110 GBV_ILN_151 GBV_ILN_161 GBV_ILN_170 GBV_ILN_213 GBV_ILN_230 GBV_ILN_285 GBV_ILN_293 GBV_ILN_602 GBV_ILN_2009 GBV_ILN_2014 GBV_ILN_2027 GBV_ILN_2055 GBV_ILN_2111 GBV_ILN_2129 GBV_ILN_4012 GBV_ILN_4037 GBV_ILN_4046 GBV_ILN_4112 GBV_ILN_4125 GBV_ILN_4126 GBV_ILN_4249 GBV_ILN_4305 GBV_ILN_4306 GBV_ILN_4307 GBV_ILN_4313 GBV_ILN_4322 GBV_ILN_4323 GBV_ILN_4324 GBV_ILN_4325 GBV_ILN_4338 GBV_ILN_4367 GBV_ILN_4700 AR 14 2024 4 03 02 1035-1052
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The findings of this research indicated that the equivalent mud weight (EMW) resulted in 10–13 ppg suitable for the Kangan Formation and 11–14 ppg suitable for the Dalan Formation. Additionally, the well azimuth in the NE-SW direction provided the best stability for drilling the encountered formations. 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author	Sobhani, Alireza
spellingShingle	Sobhani, Alireza ddc 540 misc Geomechanics parameters misc Wellbore stability misc Poroelastic modulus misc In situ stresses Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs
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topic_title	540 VZ Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs Geomechanics parameters (dpeaa)DE-He213 Wellbore stability (dpeaa)DE-He213 Poroelastic modulus (dpeaa)DE-He213 In situ stresses (dpeaa)DE-He213
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title	Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs
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title_full	Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs
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title_sort	analyzing in situ stresses and wellbore stability in one of the south iranian hydrocarbon gas reservoirs
title_auth	Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs
abstract	Abstract This study aims to analyze in situ stresses and wellbore stability in one of the Iranian gas reservoirs by using well log data, including density, sonic (compressional and shear slowness), porosity, formation micro-image (FMI) logs, modular formation dynamics tester (MDT), and rock mechanical tests. The high burial depth, high pore pressure, and strike-slip stress regime of the field require an optimal design of geomechanical parameters based on an integrated data set consisting of static and dynamic data, which is available for this study. Firstly, poroelastic modulus and vertical stress were calculated. Afterward, the Eaton’s equation was used to estimate pore pressure from well logging data. The geomechanical parameters were also calibrated through the interpretation of image data, the use of the modular formation dynamics tester (MDT), and laboratory rock mechanic tests. Employing poroelastic equations, the lowest and highest horizontal stresses were calculated. It was shown that the maximum horizontal stress and minimum horizontal stress correspond to sigma H and sigma h, indicating the strike-slope fault regime. The findings of this research indicated that the equivalent mud weight (EMW) resulted in 10–13 ppg suitable for the Kangan Formation and 11–14 ppg suitable for the Dalan Formation. Additionally, the well azimuth in the NE-SW direction provided the best stability for drilling the encountered formations. Therefore, the results of this study serve as cost-effective tools in planning adjacent wells in carbonate formations of gas field to predict the wellbore stability and safe mud window. © The Author(s) 2024
abstractGer	Abstract This study aims to analyze in situ stresses and wellbore stability in one of the Iranian gas reservoirs by using well log data, including density, sonic (compressional and shear slowness), porosity, formation micro-image (FMI) logs, modular formation dynamics tester (MDT), and rock mechanical tests. The high burial depth, high pore pressure, and strike-slip stress regime of the field require an optimal design of geomechanical parameters based on an integrated data set consisting of static and dynamic data, which is available for this study. Firstly, poroelastic modulus and vertical stress were calculated. Afterward, the Eaton’s equation was used to estimate pore pressure from well logging data. The geomechanical parameters were also calibrated through the interpretation of image data, the use of the modular formation dynamics tester (MDT), and laboratory rock mechanic tests. Employing poroelastic equations, the lowest and highest horizontal stresses were calculated. It was shown that the maximum horizontal stress and minimum horizontal stress correspond to sigma H and sigma h, indicating the strike-slope fault regime. The findings of this research indicated that the equivalent mud weight (EMW) resulted in 10–13 ppg suitable for the Kangan Formation and 11–14 ppg suitable for the Dalan Formation. Additionally, the well azimuth in the NE-SW direction provided the best stability for drilling the encountered formations. Therefore, the results of this study serve as cost-effective tools in planning adjacent wells in carbonate formations of gas field to predict the wellbore stability and safe mud window. © The Author(s) 2024
abstract_unstemmed	Abstract This study aims to analyze in situ stresses and wellbore stability in one of the Iranian gas reservoirs by using well log data, including density, sonic (compressional and shear slowness), porosity, formation micro-image (FMI) logs, modular formation dynamics tester (MDT), and rock mechanical tests. The high burial depth, high pore pressure, and strike-slip stress regime of the field require an optimal design of geomechanical parameters based on an integrated data set consisting of static and dynamic data, which is available for this study. Firstly, poroelastic modulus and vertical stress were calculated. Afterward, the Eaton’s equation was used to estimate pore pressure from well logging data. The geomechanical parameters were also calibrated through the interpretation of image data, the use of the modular formation dynamics tester (MDT), and laboratory rock mechanic tests. Employing poroelastic equations, the lowest and highest horizontal stresses were calculated. It was shown that the maximum horizontal stress and minimum horizontal stress correspond to sigma H and sigma h, indicating the strike-slope fault regime. The findings of this research indicated that the equivalent mud weight (EMW) resulted in 10–13 ppg suitable for the Kangan Formation and 11–14 ppg suitable for the Dalan Formation. Additionally, the well azimuth in the NE-SW direction provided the best stability for drilling the encountered formations. Therefore, the results of this study serve as cost-effective tools in planning adjacent wells in carbonate formations of gas field to predict the wellbore stability and safe mud window. © The Author(s) 2024
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title_short	Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs
url	https://dx.doi.org/10.1007/s13202-024-01750-6
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author2	Kadkhodaie, Ali Nabi-Bidhendi, Majid Tadayoni, Mehdi
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up_date	2024-07-03T15:42:34.351Z
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The findings of this research indicated that the equivalent mud weight (EMW) resulted in 10–13 ppg suitable for the Kangan Formation and 11–14 ppg suitable for the Dalan Formation. Additionally, the well azimuth in the NE-SW direction provided the best stability for drilling the encountered formations. 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Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs

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