Investigation of present-day in-situ stresses and pore pressure in the south Cambay Basin, western India: Implications for drilling, reservoir development and fault reactivation

Ganguli, Shib Sankar; Sen, Souvik

doi:10.1016/j.marpetgeo.2020.104422

Cited by 62 publications

(19 citation statements)

References 57 publications

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“…Direct measurements are performed by using various downhole instruments, and indirect methods are conducted by employing available geophysical logs like sonic, density, resistivity, etc. [75][76][77]. In well logging operations, the sonic log is the most common diagram that is usually driven from the ground to the bottom of the well along with the gamma-ray log.…”

Section: Resultsmentioning

confidence: 99%

Joint Application of Diagenetic, Petrophysical and Geomechanical Data for Selecting Hydraulic Fracturing Candidate Zone

Bakhshi¹,

Shahrabadi²,

Golsanami

et al. 2021

Int. J. Petrol. Technol.

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The more comprehensive information on the reservoir properties will help to better plan drilling and design production. Herein, diagenetic processes and geomechanical properties are notable parameters that determine reservoir quality. Recognizing the geomechanical properties of the reservoir as well as building a mechanical earth model play a strong role in the hydrocarbon reservoir life cycle and are key factors in analyzing wellbore instability, drilling operation optimization, and hydraulic fracturing designing operation. Therefore, the present study focuses on selecting the candidate zone for hydraulic fracturing through a novel approach that simultaneously considers the diagenetic, petrophysical, and geomechanical properties. The diagenetic processes were analyzed to determine the porosity types in the reservoir. After that, based on the laboratory test results for estimating reservoir petrophysical parameters, the zones with suitable reservoir properties were selected. Moreover, based on the reservoir geomechanical parameters and the constructed mechanical earth model, the best zones were selected for hydraulic fracturing operation in one of the Iranian fractured carbonate reservoirs. Finally, a new empirical equation for estimating pore pressure in nine zones of the studied well was developed. This equation provides a more precise estimation of stress profiles and thus leads to more accurate decision-making for candidate zone selection. Based on the results, vuggy porosity was the best porosity type, and zones C2, E2 and G2, having suitable values of porosity, permeability, and water saturation, showed good reservoir properties. Therefore, zone E2 and G2 were chosen as the candidate for hydraulic fracturing simulation based on their E (Young’s modulus) and ν (Poisson’s ratio) values. Based on the mechanical earth model and changes in the acoustic data versus depth, a new equation is introduced for calculating the pore pressure in the studied reservoir. According to the new equation, the dominant stress regime in the whole well, especially in the candidate zones, is SigHmax>SigV>Sighmin, while according to the pore pressure equation presented in the literature, the dominant stress regime in the studied well turns out to be SigHmax>Sighmin>SigV.

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Section: Resultsmentioning

confidence: 99%

Joint Application of Diagenetic, Petrophysical and Geomechanical Data for Selecting Hydraulic Fracturing Candidate Zone

Bakhshi¹,

Shahrabadi²,

Golsanami

et al. 2021

Int. J. Petrol. Technol.

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show abstract

“…Similar studies have been conducted in other regions for the in situ stress field [6,7]. Ganguli and Sen developed a comprehensive geomechanical model to evaluate the present-day stresses and pore pressures in a prolific onshore hydrocarbonbearing field located in the southern Cambay Basin, western India [8]. Ma et al proposed a hybrid neural network to predict horizontal in situ stresses based on logging data from X-1 and X-2 horizontal wells in the Sichuan Basin, southwestern China [9].…”

Section: Introductionmentioning

confidence: 89%

Understanding the Distribution Laws of In Situ Stress in Mines Based on Global Positioning System Data and Numerical Simulation Analysis

et al. 2023

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To ensure safe exploitation of the Muduchaideng Mine, we use a numerical simulation to invert the in situ stress field based on observation data from GPS stations, investigate differences in movement velocities at different locations, and analyze the lefthanded movement in the area around the wellfield. The relationship between the difference in motion velocity and the in situ stress field was explained through theoretical analysis. The law of in situ stress distribution was studied using data collected from the surrounding mines, and a regression equation as well as the relationship between the magnitudes of the three-way stresses was obtained. The inversion results were consistent with the measured data, indicating that inversion of the in situ stress field was accurate under the conditions found in the intact Ordos block. Additionally, the influence of tectonic stress on the key layer was larger than that on the bedrock of the coal seam roof, and the energy accumulated in the key layer was higher. The stress concentration coefficient of the key layer was similar to the variation law of the coal seam thickness. Therefore, the southwest area of the wellfield with a thicker coal seam is the key area for impact ground pressure prevention and control.

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“…Consequently, reduce drilling risk and related costs in these areas is achieved. In addition to pressure, other factors such as lithology also affect the speed of seismic waves; therefore, the use of available geological information and well logs can essentially prevent errors in estimating the pressure of the formation, especially in carbonate formations (Ganguli and Sen 2020;Ganguli et al 2016;Ganguli et al 2018;Kianoush et al 2022;Radwan 2021).…”

Section: Introductionmentioning

confidence: 99%

Determining the drilling mud window by integration of geostatistics, intelligent, and conditional programming models in an Oilfield of SW Iran

Kianoush

Mohammadi

Hosseini

et al. 2023

Preprint

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Accurate knowledge of pore and fracture pressures is essential for drilling wells safely with the desired mud weight (MW). Overpressure occurs when the pore pressure is higher than the normal hydrostatic pressure. There is a challenge regarding the pressure studies domain in an oilfield in SW Iran, where lack of geo-mechanical data limits exact mud window calculation. Also, the reservoir generally consists of carbonate rocks and contains no shale interbeds, so mechanical stratigraphy based on Gamma ray could not be applied. This study is to provide safe drilling considering MW to prevent the flow or loss in the vicinity of the new wells in the studied field. In this research the formation pressures and mud window models are determined by combining geostatistical, intelligent, and conditional programming models and compared with real data. The conditional programming was also used to correct small out-of-range data. The highest correlation between the final effective pressure and velocity cube was observed in lower Fahliyan Formation with 0.86 and Ilam with 0.71.The modeled MW difference ranged between 2.5 and 30 PCF. Also, the maximum modeled MW is 150 PCF in the upper Fahliyan Formation. Heavy mud of more than 130 PCF is suggested for drilling the Khalij member and continues to the end of stratigraphy column. Best observed correlation comparing the drilled and modeled MW, especially achieved in the Fahliyan reservoir Formation with more than 100 PCF and the Ilam Formation with 80-100 PCF. Finally, 3D formation pressures is presented and recommended for further safe drillings.

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Investigation of present-day in-situ stresses and pore pressure in the south Cambay Basin, western India: Implications for drilling, reservoir development and fault reactivation

Cited by 62 publications

References 57 publications

Joint Application of Diagenetic, Petrophysical and Geomechanical Data for Selecting Hydraulic Fracturing Candidate Zone

Joint Application of Diagenetic, Petrophysical and Geomechanical Data for Selecting Hydraulic Fracturing Candidate Zone

Understanding the Distribution Laws of In Situ Stress in Mines Based on Global Positioning System Data and Numerical Simulation Analysis

Determining the drilling mud window by integration of geostatistics, intelligent, and conditional programming models in an Oilfield of SW Iran

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