The Experts below are selected from a list of 609 Experts worldwide ranked by ideXlab platform
Shib Sankar Ganguli - One of the best experts on this subject based on the ideXlab platform.
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characterization of pore pressure fracture pressure shear failure and its implications for drilling wellbore stability and Completion design a case study from the takouazet field illizi basin algeria
Marine and Petroleum Geology, 2020Co-Authors: Rafik Baouche, Souvik Sen, Moussa Sadaoui, Khadidja Boutaleb, Shib Sankar GanguliAbstract:Abstract This work presents the assessment of overburden stress, pore pressure and fracture pressure distribution in the Paleozoic stratigraphic units in the Takouazet field, eastern Illizi basin, Algeria. We studied a vertical exploration well, where significant hydrocarbon discoveries have been established in Devonian and Ordovician sandstone reservoirs. Overburden stress interpreted from density log has an average 1.07 PSI/ft (24204.04 Pa/m) gradient. Pore pressure derived from sonic log reveals that hydrostatic conditions prevail in Devonian and Ordovician units, whereas abnormal pore pressure with a maximum 0.66 PSI/ft (14929.60 Pa/m) gradient was recorded against the marine Silurian shale. Fracture pressure was modeled using effective stress ratio models as well as a Poisson's ratio based approach. Rock property based fracture pressure estimate is more sensitive to lithological variations and hence this estimate was used for determining safe drilling mud window and casing placements. The estimated pore pressure and fracture pressure were calibrated with direct downHole formation pressure measurements and leakoff test (LOT)measurements, respectively. Shear failure using Mohr- Coulomb rock failure criterion detected the minimum allowable mud pressure to avoid wellbore instability issues and the result was validated with caliper log observations. It indicated that solid production from the reservoir is very likely during initial production from the reservoir and a solid control mechanism has been suggested. Also widening of breakouts and deteriorating wellbore interpreted from time lapse formation imaging logs strongly suggest against Open-Hole Completion. Based on interpreted pressure gradients and image log analyses, optimum drilling (mud and casing design) and Completion policies were recommended for safe and successful operational planning.
Rafik Baouche - One of the best experts on this subject based on the ideXlab platform.
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characterization of pore pressure fracture pressure shear failure and its implications for drilling wellbore stability and Completion design a case study from the takouazet field illizi basin algeria
Marine and Petroleum Geology, 2020Co-Authors: Rafik Baouche, Souvik Sen, Moussa Sadaoui, Khadidja Boutaleb, Shib Sankar GanguliAbstract:Abstract This work presents the assessment of overburden stress, pore pressure and fracture pressure distribution in the Paleozoic stratigraphic units in the Takouazet field, eastern Illizi basin, Algeria. We studied a vertical exploration well, where significant hydrocarbon discoveries have been established in Devonian and Ordovician sandstone reservoirs. Overburden stress interpreted from density log has an average 1.07 PSI/ft (24204.04 Pa/m) gradient. Pore pressure derived from sonic log reveals that hydrostatic conditions prevail in Devonian and Ordovician units, whereas abnormal pore pressure with a maximum 0.66 PSI/ft (14929.60 Pa/m) gradient was recorded against the marine Silurian shale. Fracture pressure was modeled using effective stress ratio models as well as a Poisson's ratio based approach. Rock property based fracture pressure estimate is more sensitive to lithological variations and hence this estimate was used for determining safe drilling mud window and casing placements. The estimated pore pressure and fracture pressure were calibrated with direct downHole formation pressure measurements and leakoff test (LOT)measurements, respectively. Shear failure using Mohr- Coulomb rock failure criterion detected the minimum allowable mud pressure to avoid wellbore instability issues and the result was validated with caliper log observations. It indicated that solid production from the reservoir is very likely during initial production from the reservoir and a solid control mechanism has been suggested. Also widening of breakouts and deteriorating wellbore interpreted from time lapse formation imaging logs strongly suggest against Open-Hole Completion. Based on interpreted pressure gradients and image log analyses, optimum drilling (mud and casing design) and Completion policies were recommended for safe and successful operational planning.
Økland Andreas - One of the best experts on this subject based on the ideXlab platform.
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A Comprehensive Completion Method Selection Based on Probability and Impact Matrix for Iris Production HPHT Well
University of Stavanger Norway, 2020Co-Authors: Økland AndreasAbstract:HPHT well Completion require special attention to well design. The conservatism of well Completion is constantly put to the test by introducing and qualifying new equipment meant to enhance well performance, minimize HS&E risks, and provide a cost-effective design. Multiple operators on the Norwegian Continental Shelf has completed high-pressure, high-temperature wells with different Completions and results. OMV (Norge) AS is set to look into a field development for PL 644 Hades/Iris field, and operational experience become highly valuable for their well Completion strategy. Completing a well requires the need to select the most ideal method. The reservoir Completion needs to be designed to provide the most optimal exposure and flow of hydrocarbons. Providing an Open Hole Completion introduce specific risks and considerations, so will a perforated liner. Completion fluids, perforation explosives, Completion limitations and operational readiness for HPHT field is among many factors to influence the selection. The need for reservoir isolation contributes to additional considerations and risks, which again will influence the method selection with respect to well integrity. Tubing selection, packer design and load cases will dictate the upper Completion method selection. This thesis shall provide a general method assessment of important Completion components from reservoir to wellhead, where risks encountered from previous field developments is included. By using real well information obtained from 6506/11-11S Iris Appraisal, a new production well shall be studied and completed. The method selection process will be carried out by a risk assessment matrix. Basing the likelihood and consequence of the identified risks, the risk level can be determined. This qualitative methodology is common in the industry and provide a straightforward overview of the mapped risks. Based on the results from the risk register presented in this thesis, a method selection of lower, middle, and upper Completion will be presented. Full Completion proposals will be investigated and integrated, covering advantages and disadvantages, before concluding on a final proposal
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A Comprehensive Completion Method Selection Based on Probability and Impact Matrix for Iris Production HPHT Well
University of Stavanger Norway, 2020Co-Authors: Økland AndreasAbstract:Master's thesis in Petroleum EngineeringHPHT well Completion require special attention to well design. The conservatism of well Completion is constantly put to the test by introducing and qualifying new equipment meant to enhance well performance, minimize HS&E risks, and provide a cost-effective design. Multiple operators on the Norwegian Continental Shelf has completed high-pressure, high-temperature wells with different Completions and results. OMV (Norge) AS is set to look into a field development for PL 644 Hades/Iris field, and operational experience become highly valuable for their well Completion strategy. Completing a well requires the need to select the most ideal method. The reservoir Completion needs to be designed to provide the most optimal exposure and flow of hydrocarbons. Providing an Open Hole Completion introduce specific risks and considerations, so will a perforated liner. Completion fluids, perforation explosives, Completion limitations and operational readiness for HPHT field is among many factors to influence the selection. The need for reservoir isolation contributes to additional considerations and risks, which again will influence the method selection with respect to well integrity. Tubing selection, packer design and load cases will dictate the upper Completion method selection. This thesis shall provide a general method assessment of important Completion components from reservoir to wellhead, where risks encountered from previous field developments is included. By using real well information obtained from 6506/11-11S Iris Appraisal, a new production well shall be studied and completed. The method selection process will be carried out by a risk assessment matrix. Basing the likelihood and consequence of the identified risks, the risk level can be determined. This qualitative methodology is common in the industry and provide a straightforward overview of the mapped risks. Based on the results from the risk register presented in this thesis, a method selection of lower, middle, and upper Completion will be presented. Full Completion proposals will be investigated and integrated, covering advantages and disadvantages, before concluding on a final proposal
Khadidja Boutaleb - One of the best experts on this subject based on the ideXlab platform.
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characterization of pore pressure fracture pressure shear failure and its implications for drilling wellbore stability and Completion design a case study from the takouazet field illizi basin algeria
Marine and Petroleum Geology, 2020Co-Authors: Rafik Baouche, Souvik Sen, Moussa Sadaoui, Khadidja Boutaleb, Shib Sankar GanguliAbstract:Abstract This work presents the assessment of overburden stress, pore pressure and fracture pressure distribution in the Paleozoic stratigraphic units in the Takouazet field, eastern Illizi basin, Algeria. We studied a vertical exploration well, where significant hydrocarbon discoveries have been established in Devonian and Ordovician sandstone reservoirs. Overburden stress interpreted from density log has an average 1.07 PSI/ft (24204.04 Pa/m) gradient. Pore pressure derived from sonic log reveals that hydrostatic conditions prevail in Devonian and Ordovician units, whereas abnormal pore pressure with a maximum 0.66 PSI/ft (14929.60 Pa/m) gradient was recorded against the marine Silurian shale. Fracture pressure was modeled using effective stress ratio models as well as a Poisson's ratio based approach. Rock property based fracture pressure estimate is more sensitive to lithological variations and hence this estimate was used for determining safe drilling mud window and casing placements. The estimated pore pressure and fracture pressure were calibrated with direct downHole formation pressure measurements and leakoff test (LOT)measurements, respectively. Shear failure using Mohr- Coulomb rock failure criterion detected the minimum allowable mud pressure to avoid wellbore instability issues and the result was validated with caliper log observations. It indicated that solid production from the reservoir is very likely during initial production from the reservoir and a solid control mechanism has been suggested. Also widening of breakouts and deteriorating wellbore interpreted from time lapse formation imaging logs strongly suggest against Open-Hole Completion. Based on interpreted pressure gradients and image log analyses, optimum drilling (mud and casing design) and Completion policies were recommended for safe and successful operational planning.
Moussa Sadaoui - One of the best experts on this subject based on the ideXlab platform.
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characterization of pore pressure fracture pressure shear failure and its implications for drilling wellbore stability and Completion design a case study from the takouazet field illizi basin algeria
Marine and Petroleum Geology, 2020Co-Authors: Rafik Baouche, Souvik Sen, Moussa Sadaoui, Khadidja Boutaleb, Shib Sankar GanguliAbstract:Abstract This work presents the assessment of overburden stress, pore pressure and fracture pressure distribution in the Paleozoic stratigraphic units in the Takouazet field, eastern Illizi basin, Algeria. We studied a vertical exploration well, where significant hydrocarbon discoveries have been established in Devonian and Ordovician sandstone reservoirs. Overburden stress interpreted from density log has an average 1.07 PSI/ft (24204.04 Pa/m) gradient. Pore pressure derived from sonic log reveals that hydrostatic conditions prevail in Devonian and Ordovician units, whereas abnormal pore pressure with a maximum 0.66 PSI/ft (14929.60 Pa/m) gradient was recorded against the marine Silurian shale. Fracture pressure was modeled using effective stress ratio models as well as a Poisson's ratio based approach. Rock property based fracture pressure estimate is more sensitive to lithological variations and hence this estimate was used for determining safe drilling mud window and casing placements. The estimated pore pressure and fracture pressure were calibrated with direct downHole formation pressure measurements and leakoff test (LOT)measurements, respectively. Shear failure using Mohr- Coulomb rock failure criterion detected the minimum allowable mud pressure to avoid wellbore instability issues and the result was validated with caliper log observations. It indicated that solid production from the reservoir is very likely during initial production from the reservoir and a solid control mechanism has been suggested. Also widening of breakouts and deteriorating wellbore interpreted from time lapse formation imaging logs strongly suggest against Open-Hole Completion. Based on interpreted pressure gradients and image log analyses, optimum drilling (mud and casing design) and Completion policies were recommended for safe and successful operational planning.
