The Experts below are selected from a list of 318 Experts worldwide ranked by ideXlab platform

J J K Daemen - One of the best experts on this subject based on the ideXlab platform.

  • determination of the maximum allowable gas pressure for an underground gas storage salt cavern a case study of jintan china
    Journal of rock mechanics and geotechnical engineering, 2019
    Co-Authors: Tongtao Wang, Jianjun Li, Gang Jing, Qingqing Zhang, Chunhe Yang, J J K Daemen
    Abstract:

    Abstract Increasing the allowable gas pressure of underground gas storage (UGS) is one of the most effective methods to increase its working gas capacity. In this context, hydraulic fracturing tests are implemented on the target formation for the UGS construction of Jintan salt caverns, China, in order to obtain the minimum principal in situ stress and the fracture breakdown pressure. Based on the test results, the maximum allowable gas pressure of the Jintan UGS salt cavern is calibrated. To determine the maximum allowable gas pressure, KING-1 and KING-2 caverns are used as examples. A three-dimensional (3D) geomechanical model is established based on the sonar data of the two caverns with respect to the features of the target formation. New criteria for evaluating gas penetration failure and gas seepage are proposed. Results show that the maximum allowable gas pressure of the Jintan UGS salt cavern can be increased from 17 MPa to 18 MPa (i.e. a gradient of about 18 kPa/m at the Casing Shoe depth). Based on numerical results, a field test with increasing maximum gas pressure to 18 MPa has been carried out in KING-1 cavern. Microseismic monitoring has been conducted during the test to evaluate the safety of the rock mass around the cavern. Field monitoring data show that KING-1 cavern is safe globally when the maximum gas pressure is increased from 17 MPa to 18 MPa. This shows that the geomechanical model and criteria proposed in this context for evaluating the maximum allowable gas pressure are reliable.

  • Determination of the maximum allowable gas pressure for an underground gas storage salt cavern – A case study of Jintan, China
    Journal of rock mechanics and geotechnical engineering, 2019
    Co-Authors: Tongtao Wang, Gang Jing, Chunhe Yang, Zhang Qingqing, J J K Daemen
    Abstract:

    Abstract Increasing the allowable gas pressure of underground gas storage (UGS) is one of the most effective methods to increase its working gas capacity. In this context, hydraulic fracturing tests are implemented on the target formation for the UGS construction of Jintan salt caverns, China, in order to obtain the minimum principal in situ stress and the fracture breakdown pressure. Based on the test results, the maximum allowable gas pressure of the Jintan UGS salt cavern is calibrated. To determine the maximum allowable gas pressure, KING-1 and KING-2 caverns are used as examples. A three-dimensional (3D) geomechanical model is established based on the sonar data of the two caverns with respect to the features of the target formation. New criteria for evaluating gas penetration failure and gas seepage are proposed. Results show that the maximum allowable gas pressure of the Jintan UGS salt cavern can be increased from 17 MPa to 18 MPa (i.e. a gradient of about 18 kPa/m at the Casing Shoe depth). Based on numerical results, a field test with increasing maximum gas pressure to 18 MPa has been carried out in KING-1 cavern. Microseismic monitoring has been conducted during the test to evaluate the safety of the rock mass around the cavern. Field monitoring data show that KING-1 cavern is safe globally when the maximum gas pressure is increased from 17 MPa to 18 MPa. This shows that the geomechanical model and criteria proposed in this context for evaluating the maximum allowable gas pressure are reliable.

Tongtao Wang - One of the best experts on this subject based on the ideXlab platform.

  • determination of the maximum allowable gas pressure for an underground gas storage salt cavern a case study of jintan china
    Journal of rock mechanics and geotechnical engineering, 2019
    Co-Authors: Tongtao Wang, Jianjun Li, Gang Jing, Qingqing Zhang, Chunhe Yang, J J K Daemen
    Abstract:

    Abstract Increasing the allowable gas pressure of underground gas storage (UGS) is one of the most effective methods to increase its working gas capacity. In this context, hydraulic fracturing tests are implemented on the target formation for the UGS construction of Jintan salt caverns, China, in order to obtain the minimum principal in situ stress and the fracture breakdown pressure. Based on the test results, the maximum allowable gas pressure of the Jintan UGS salt cavern is calibrated. To determine the maximum allowable gas pressure, KING-1 and KING-2 caverns are used as examples. A three-dimensional (3D) geomechanical model is established based on the sonar data of the two caverns with respect to the features of the target formation. New criteria for evaluating gas penetration failure and gas seepage are proposed. Results show that the maximum allowable gas pressure of the Jintan UGS salt cavern can be increased from 17 MPa to 18 MPa (i.e. a gradient of about 18 kPa/m at the Casing Shoe depth). Based on numerical results, a field test with increasing maximum gas pressure to 18 MPa has been carried out in KING-1 cavern. Microseismic monitoring has been conducted during the test to evaluate the safety of the rock mass around the cavern. Field monitoring data show that KING-1 cavern is safe globally when the maximum gas pressure is increased from 17 MPa to 18 MPa. This shows that the geomechanical model and criteria proposed in this context for evaluating the maximum allowable gas pressure are reliable.

  • Determination of the maximum allowable gas pressure for an underground gas storage salt cavern – A case study of Jintan, China
    Journal of rock mechanics and geotechnical engineering, 2019
    Co-Authors: Tongtao Wang, Gang Jing, Chunhe Yang, Zhang Qingqing, J J K Daemen
    Abstract:

    Abstract Increasing the allowable gas pressure of underground gas storage (UGS) is one of the most effective methods to increase its working gas capacity. In this context, hydraulic fracturing tests are implemented on the target formation for the UGS construction of Jintan salt caverns, China, in order to obtain the minimum principal in situ stress and the fracture breakdown pressure. Based on the test results, the maximum allowable gas pressure of the Jintan UGS salt cavern is calibrated. To determine the maximum allowable gas pressure, KING-1 and KING-2 caverns are used as examples. A three-dimensional (3D) geomechanical model is established based on the sonar data of the two caverns with respect to the features of the target formation. New criteria for evaluating gas penetration failure and gas seepage are proposed. Results show that the maximum allowable gas pressure of the Jintan UGS salt cavern can be increased from 17 MPa to 18 MPa (i.e. a gradient of about 18 kPa/m at the Casing Shoe depth). Based on numerical results, a field test with increasing maximum gas pressure to 18 MPa has been carried out in KING-1 cavern. Microseismic monitoring has been conducted during the test to evaluate the safety of the rock mass around the cavern. Field monitoring data show that KING-1 cavern is safe globally when the maximum gas pressure is increased from 17 MPa to 18 MPa. This shows that the geomechanical model and criteria proposed in this context for evaluating the maximum allowable gas pressure are reliable.

Andrew K. Wojtanowicz - One of the best experts on this subject based on the ideXlab platform.

  • Shallow Casing Shoe integrity interpretation technique
    Journal of Petroleum Science and Engineering, 2010
    Co-Authors: Andrew K. Wojtanowicz, Desheng Zhou
    Abstract:

    Abstract Unlike the leak-off testing (LOT) in deep wells, the LOT plots from shallow well sections subsea are often inconclusive due to the lack of an obvious point of deflection from their initial linear behavior. In the paper, simultaneous effects of geo-mechanical factors and fall-off mechanism have been combined to explain and analyze the tests in shallow marine sediments (SMS). Based on theoretical analysis, three main stages of leak-off plot from SMS, pressure buildup, stabilization and fall-off are identified and explained. Non-linearity of the pressure buildup and mechanisms controlling pressure stabilization are explained and used to develop a method to analyze LOT. The presented interpretation procedure considers separately the pressure stabilization and the pressure buildup and fall-off sections of the LOT plot. The procedure combines well data with pressure testing record. Well data includes overburden pressure — calculated from correlations specific for SMS, and the maximum cementing pressure at the time of slurry placement. The stabilized LOT pressure analysis identifies the maximum strength of the Casing Shoe controlled by the rock stress (overburden pressure) and the failure by rock fracturing. Also presented is a graphical procedure for comparing the plots of actual and equivalent pressure fall-off. The graphical procedure provides a pattern-recognition method to distinguish the mechanism of cement–rock parting from the fluid loss mechanism.

  • Cement Seal Failure at Casing Shoe in Shallow Marine Sediments
    Journal of Energy Resources Technology-transactions of The Asme, 2009
    Co-Authors: Desheng Zhou, Andrew K. Wojtanowicz
    Abstract:

    This paper describes the hypothetical mechanisms of cement seal failure during Casing Shoe leak-off testing (LOT) of surface holes in the shallow-marine sediments (SMSs)—parting of cement sheath from formation by LOT wellbore pressure. Presented is a theoretical proof—supported by LOT field data—explaining why, in SMSs, Casing Shoe failure occurs at pressures smaller than the rock fracturing pressures. Hence, for upper well sections in SMSs the prediction of Casing Shoe strength should be based on critical conditions for cement seal failure rather than rock fracturing. It is also shown that pressure required for cement seal failure can be determined from contact stress between cement and wellbore. Contact stress develops during the process of cement setting as a result of volumetric changes in the annulus. Proposed is a mathematical model of contact stress based on cement volume reduction compensated by compressibility of the Casing string, cement, and wellbore. An example demonstrates potential application of the model. The study identifies two factors resulting from drilling process, which may control the critical pressure of cement seal failure in SMSs: contact stress at Casing Shoe, from cementing operations, and liquid penetration, an invasion of drilling fluid into the cement-rock interface around the Casing Shoe. It is shown that changes in cementing and drilling practices may increase Casing Shoe integrity and reduce the need for cement squeeze treatments.

  • Analysis of Leak-off Tests in Shallow Marine Sediments
    Journal of Energy Resources Technology-transactions of The Asme, 2002
    Co-Authors: Desheng Zhou, Andrew K. Wojtanowicz
    Abstract:

    Typical analysis of the Leak-off testing (LOT) in wells assumes elastic wellbore and involves identification of diversion points from linear trends of the recorded plots. However, LOTs from wells in the shallow marine sediments (SMS) are inherently nonlinear and their analysis becomes a problem. The paper presents mathematical models of the pressure-volume behavior for two different possible failures around the Casing Shoe, annular crack (cement-rock parting) and formation fracture. The study submits that these two failure modes would control abnormal LOT patterns. A general pressure-volume model of LOT has been developed including volumetric effects of wellbore expansion, mud loss into the rock, and propagation of an annular crack or plastic fracture. A diagnostic method is proposed to identify LOT-control mechanisms (i.e., formation fracture, annular crack, or mud loss) by analyzing the shut-in section of the LOT's plot.

  • Leakoff pressure estimation from cementing and Casing data
    Journal of Petroleum Technology, 2000
    Co-Authors: Desheng Zhou, Andrew K. Wojtanowicz
    Abstract:

    During leakoff tests (LOTs) in shallow marine sediments, Casing Shoe failure may be caused by cement channeling at pressures lower than the rock-fracture pressure. Pressure required for leakoff behind the cement can be determined from contact stress between cement and wellbore. Contact stress develops during cement setting as a result of volumetric changes in the annulus. Changes in cementing and drilling practices can increase Casing Shoe integrity and reduce the need for cement squeeze operations. The full-length paper presents a mathematical model of contact stress around the Casing Shoe based on cement volume reduction and compensation from Casing string elongation, cement compressibility, and wellbore shrinkage. The study identifies two factors directly related to drilling technology that control critical pressure of cement channeling: contact stress at the Casing Shoe and drilling fluid invasion of rock around the Casing Shoe.

  • Estimation of Leakoff Pressure Gradient from Cementing and Casing Data
    SPE Annual Technical Conference and Exhibition, 1999
    Co-Authors: Desheng Zhou, Andrew K. Wojtanowicz
    Abstract:

    The paper describes the development and use of a new procedure for finding safe value of Casing Shoe leak-off pressure in surface holes in the shallow-marine sediments (SMS). Presented is a theoretical proof, supported by field data from leak-off tests, that, in SMS, annulus channeling outside cement occurs more likely at pressure values smaller than the rock fracturing pressure. Hence, for upper well sections in SMS the prediction of Casing Shoe strength should be based on critical conditions for annulus channeling rather than rock fracturing. It is also shown that pressure required for Casing Shoe leak off behind cement can be determined from contact stress between cement and wellbore. Contact stress deveiops during the process of cement setting as a result of volumetric changes in the annulus. Set up is a mathematical model of contact stress around Casing Shoe based on cement volume reduction and compensation from Casing string, cement compressibility and wellbore. Using readily available data of well geometry, Casing properties and cementing operation, simple procedure, explained in this paper, gives a good estimation of cement fracture compared with actual leak-off test values. The study identifies two factors, related directly to drilling technology, that control critical pressure of cement channeling in SMS: contact stress at Casing Shoe - resulting from cementing operations, and rock penetration by liquid an invasion of drilling fluid into the lock around the Casing Shoe. It is shown in the paper that changes in cementing and drilling practices may increases Casing Shoe integrity and reduce the need for cement squeeze treatments.

Desheng Zhou - One of the best experts on this subject based on the ideXlab platform.

  • Shallow Casing Shoe integrity interpretation technique
    Journal of Petroleum Science and Engineering, 2010
    Co-Authors: Andrew K. Wojtanowicz, Desheng Zhou
    Abstract:

    Abstract Unlike the leak-off testing (LOT) in deep wells, the LOT plots from shallow well sections subsea are often inconclusive due to the lack of an obvious point of deflection from their initial linear behavior. In the paper, simultaneous effects of geo-mechanical factors and fall-off mechanism have been combined to explain and analyze the tests in shallow marine sediments (SMS). Based on theoretical analysis, three main stages of leak-off plot from SMS, pressure buildup, stabilization and fall-off are identified and explained. Non-linearity of the pressure buildup and mechanisms controlling pressure stabilization are explained and used to develop a method to analyze LOT. The presented interpretation procedure considers separately the pressure stabilization and the pressure buildup and fall-off sections of the LOT plot. The procedure combines well data with pressure testing record. Well data includes overburden pressure — calculated from correlations specific for SMS, and the maximum cementing pressure at the time of slurry placement. The stabilized LOT pressure analysis identifies the maximum strength of the Casing Shoe controlled by the rock stress (overburden pressure) and the failure by rock fracturing. Also presented is a graphical procedure for comparing the plots of actual and equivalent pressure fall-off. The graphical procedure provides a pattern-recognition method to distinguish the mechanism of cement–rock parting from the fluid loss mechanism.

  • Cement Seal Failure at Casing Shoe in Shallow Marine Sediments
    Journal of Energy Resources Technology-transactions of The Asme, 2009
    Co-Authors: Desheng Zhou, Andrew K. Wojtanowicz
    Abstract:

    This paper describes the hypothetical mechanisms of cement seal failure during Casing Shoe leak-off testing (LOT) of surface holes in the shallow-marine sediments (SMSs)—parting of cement sheath from formation by LOT wellbore pressure. Presented is a theoretical proof—supported by LOT field data—explaining why, in SMSs, Casing Shoe failure occurs at pressures smaller than the rock fracturing pressures. Hence, for upper well sections in SMSs the prediction of Casing Shoe strength should be based on critical conditions for cement seal failure rather than rock fracturing. It is also shown that pressure required for cement seal failure can be determined from contact stress between cement and wellbore. Contact stress develops during the process of cement setting as a result of volumetric changes in the annulus. Proposed is a mathematical model of contact stress based on cement volume reduction compensated by compressibility of the Casing string, cement, and wellbore. An example demonstrates potential application of the model. The study identifies two factors resulting from drilling process, which may control the critical pressure of cement seal failure in SMSs: contact stress at Casing Shoe, from cementing operations, and liquid penetration, an invasion of drilling fluid into the cement-rock interface around the Casing Shoe. It is shown that changes in cementing and drilling practices may increase Casing Shoe integrity and reduce the need for cement squeeze treatments.

  • Analysis of Leak-off Tests in Shallow Marine Sediments
    Journal of Energy Resources Technology-transactions of The Asme, 2002
    Co-Authors: Desheng Zhou, Andrew K. Wojtanowicz
    Abstract:

    Typical analysis of the Leak-off testing (LOT) in wells assumes elastic wellbore and involves identification of diversion points from linear trends of the recorded plots. However, LOTs from wells in the shallow marine sediments (SMS) are inherently nonlinear and their analysis becomes a problem. The paper presents mathematical models of the pressure-volume behavior for two different possible failures around the Casing Shoe, annular crack (cement-rock parting) and formation fracture. The study submits that these two failure modes would control abnormal LOT patterns. A general pressure-volume model of LOT has been developed including volumetric effects of wellbore expansion, mud loss into the rock, and propagation of an annular crack or plastic fracture. A diagnostic method is proposed to identify LOT-control mechanisms (i.e., formation fracture, annular crack, or mud loss) by analyzing the shut-in section of the LOT's plot.

  • Leakoff pressure estimation from cementing and Casing data
    Journal of Petroleum Technology, 2000
    Co-Authors: Desheng Zhou, Andrew K. Wojtanowicz
    Abstract:

    During leakoff tests (LOTs) in shallow marine sediments, Casing Shoe failure may be caused by cement channeling at pressures lower than the rock-fracture pressure. Pressure required for leakoff behind the cement can be determined from contact stress between cement and wellbore. Contact stress develops during cement setting as a result of volumetric changes in the annulus. Changes in cementing and drilling practices can increase Casing Shoe integrity and reduce the need for cement squeeze operations. The full-length paper presents a mathematical model of contact stress around the Casing Shoe based on cement volume reduction and compensation from Casing string elongation, cement compressibility, and wellbore shrinkage. The study identifies two factors directly related to drilling technology that control critical pressure of cement channeling: contact stress at the Casing Shoe and drilling fluid invasion of rock around the Casing Shoe.

  • Estimation of Leakoff Pressure Gradient from Cementing and Casing Data
    SPE Annual Technical Conference and Exhibition, 1999
    Co-Authors: Desheng Zhou, Andrew K. Wojtanowicz
    Abstract:

    The paper describes the development and use of a new procedure for finding safe value of Casing Shoe leak-off pressure in surface holes in the shallow-marine sediments (SMS). Presented is a theoretical proof, supported by field data from leak-off tests, that, in SMS, annulus channeling outside cement occurs more likely at pressure values smaller than the rock fracturing pressure. Hence, for upper well sections in SMS the prediction of Casing Shoe strength should be based on critical conditions for annulus channeling rather than rock fracturing. It is also shown that pressure required for Casing Shoe leak off behind cement can be determined from contact stress between cement and wellbore. Contact stress deveiops during the process of cement setting as a result of volumetric changes in the annulus. Set up is a mathematical model of contact stress around Casing Shoe based on cement volume reduction and compensation from Casing string, cement compressibility and wellbore. Using readily available data of well geometry, Casing properties and cementing operation, simple procedure, explained in this paper, gives a good estimation of cement fracture compared with actual leak-off test values. The study identifies two factors, related directly to drilling technology, that control critical pressure of cement channeling in SMS: contact stress at Casing Shoe - resulting from cementing operations, and rock penetration by liquid an invasion of drilling fluid into the lock around the Casing Shoe. It is shown in the paper that changes in cementing and drilling practices may increases Casing Shoe integrity and reduce the need for cement squeeze treatments.

Chunhe Yang - One of the best experts on this subject based on the ideXlab platform.

  • determination of the maximum allowable gas pressure for an underground gas storage salt cavern a case study of jintan china
    Journal of rock mechanics and geotechnical engineering, 2019
    Co-Authors: Tongtao Wang, Jianjun Li, Gang Jing, Qingqing Zhang, Chunhe Yang, J J K Daemen
    Abstract:

    Abstract Increasing the allowable gas pressure of underground gas storage (UGS) is one of the most effective methods to increase its working gas capacity. In this context, hydraulic fracturing tests are implemented on the target formation for the UGS construction of Jintan salt caverns, China, in order to obtain the minimum principal in situ stress and the fracture breakdown pressure. Based on the test results, the maximum allowable gas pressure of the Jintan UGS salt cavern is calibrated. To determine the maximum allowable gas pressure, KING-1 and KING-2 caverns are used as examples. A three-dimensional (3D) geomechanical model is established based on the sonar data of the two caverns with respect to the features of the target formation. New criteria for evaluating gas penetration failure and gas seepage are proposed. Results show that the maximum allowable gas pressure of the Jintan UGS salt cavern can be increased from 17 MPa to 18 MPa (i.e. a gradient of about 18 kPa/m at the Casing Shoe depth). Based on numerical results, a field test with increasing maximum gas pressure to 18 MPa has been carried out in KING-1 cavern. Microseismic monitoring has been conducted during the test to evaluate the safety of the rock mass around the cavern. Field monitoring data show that KING-1 cavern is safe globally when the maximum gas pressure is increased from 17 MPa to 18 MPa. This shows that the geomechanical model and criteria proposed in this context for evaluating the maximum allowable gas pressure are reliable.

  • Determination of the maximum allowable gas pressure for an underground gas storage salt cavern – A case study of Jintan, China
    Journal of rock mechanics and geotechnical engineering, 2019
    Co-Authors: Tongtao Wang, Gang Jing, Chunhe Yang, Zhang Qingqing, J J K Daemen
    Abstract:

    Abstract Increasing the allowable gas pressure of underground gas storage (UGS) is one of the most effective methods to increase its working gas capacity. In this context, hydraulic fracturing tests are implemented on the target formation for the UGS construction of Jintan salt caverns, China, in order to obtain the minimum principal in situ stress and the fracture breakdown pressure. Based on the test results, the maximum allowable gas pressure of the Jintan UGS salt cavern is calibrated. To determine the maximum allowable gas pressure, KING-1 and KING-2 caverns are used as examples. A three-dimensional (3D) geomechanical model is established based on the sonar data of the two caverns with respect to the features of the target formation. New criteria for evaluating gas penetration failure and gas seepage are proposed. Results show that the maximum allowable gas pressure of the Jintan UGS salt cavern can be increased from 17 MPa to 18 MPa (i.e. a gradient of about 18 kPa/m at the Casing Shoe depth). Based on numerical results, a field test with increasing maximum gas pressure to 18 MPa has been carried out in KING-1 cavern. Microseismic monitoring has been conducted during the test to evaluate the safety of the rock mass around the cavern. Field monitoring data show that KING-1 cavern is safe globally when the maximum gas pressure is increased from 17 MPa to 18 MPa. This shows that the geomechanical model and criteria proposed in this context for evaluating the maximum allowable gas pressure are reliable.