Microscopic characteristics of water invasion and residual gas distribution in carbonate gas reservoirs
We used the nuclear magnetic resonance online detection method to analyze the water invasion mechanism and residual gas distribution of a carbonate rock gas reservoir. The T2 spectra obtained by using the Carr‐Purcell‐Meiboom‐Gill (CPMG) pulse sequence were applied to characterize the invasion water...
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| Published in | Energy science & engineering Vol. 9; no. 11; pp. 2151 - 2164 |
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| Main Authors | , , , , , , , , , |
| Format | Journal Article |
| Language | English |
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London
John Wiley & Sons, Inc
01.11.2021
Wiley |
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| Abstract | We used the nuclear magnetic resonance online detection method to analyze the water invasion mechanism and residual gas distribution of a carbonate rock gas reservoir. The T2 spectra obtained by using the Carr‐Purcell‐Meiboom‐Gill (CPMG) pulse sequence were applied to characterize the invasion water and residual gas distribution. The results showed that (a) in the pore‐type gas reservoir, the water first invades the meso–macropores and then the small pores as the pressure decreases further. The fracture distribution in a fracture‐pore‐type gas reservoir has an effect on the water invasion mode. The water can enter the pores through the fracture wall after the water invades the fracture. (b) In the pore‐type gas reservoir, 37.7% of the residual gas resides in the small pores, while the rest resides in the macropores. While in the fracture‐pore‐type gas reservoir, 4.8% ~ 26.8% of the residual gas is in the smaller pores and 69.2% ~ 95.7% in the macropores. Barely, any residual gas resides in the fractures. The residual gas in the small pores is difficult to produce. (c) The residual gas is controlled by the fracture penetration, amount of bottom water, fracture width, and production rate. It is suggested the production rate decreased to induce the water to invade the meso–macropores after the gas well begins to produce water to reduce the amount of residual gas in the meso–macropores.
The nuclear magnetic resonance online detection method was used to analyze the water invasion mechanism and residual gas distribution of a carbonate rock gas reservoir, and theT2 spectra were obtained by using the Carr‐Purcell‐Meiboom‐Gill (CPMG) pulse sequence to characterize the intrusive water distribution |
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| AbstractList | We used the nuclear magnetic resonance online detection method to analyze the water invasion mechanism and residual gas distribution of a carbonate rock gas reservoir. The T2 spectra obtained by using the Carr‐Purcell‐Meiboom‐Gill (CPMG) pulse sequence were applied to characterize the invasion water and residual gas distribution. The results showed that (a) in the pore‐type gas reservoir, the water first invades the meso–macropores and then the small pores as the pressure decreases further. The fracture distribution in a fracture‐pore‐type gas reservoir has an effect on the water invasion mode. The water can enter the pores through the fracture wall after the water invades the fracture. (b) In the pore‐type gas reservoir, 37.7% of the residual gas resides in the small pores, while the rest resides in the macropores. While in the fracture‐pore‐type gas reservoir, 4.8% ~ 26.8% of the residual gas is in the smaller pores and 69.2% ~ 95.7% in the macropores. Barely, any residual gas resides in the fractures. The residual gas in the small pores is difficult to produce. (c) The residual gas is controlled by the fracture penetration, amount of bottom water, fracture width, and production rate. It is suggested the production rate decreased to induce the water to invade the meso–macropores after the gas well begins to produce water to reduce the amount of residual gas in the meso–macropores.
The nuclear magnetic resonance online detection method was used to analyze the water invasion mechanism and residual gas distribution of a carbonate rock gas reservoir, and theT2 spectra were obtained by using the Carr‐Purcell‐Meiboom‐Gill (CPMG) pulse sequence to characterize the intrusive water distribution Abstract We used the nuclear magnetic resonance online detection method to analyze the water invasion mechanism and residual gas distribution of a carbonate rock gas reservoir. The T2 spectra obtained by using the Carr‐Purcell‐Meiboom‐Gill (CPMG) pulse sequence were applied to characterize the invasion water and residual gas distribution. The results showed that (a) in the pore‐type gas reservoir, the water first invades the meso–macropores and then the small pores as the pressure decreases further. The fracture distribution in a fracture‐pore‐type gas reservoir has an effect on the water invasion mode. The water can enter the pores through the fracture wall after the water invades the fracture. (b) In the pore‐type gas reservoir, 37.7% of the residual gas resides in the small pores, while the rest resides in the macropores. While in the fracture‐pore‐type gas reservoir, 4.8% ~ 26.8% of the residual gas is in the smaller pores and 69.2% ~ 95.7% in the macropores. Barely, any residual gas resides in the fractures. The residual gas in the small pores is difficult to produce. (c) The residual gas is controlled by the fracture penetration, amount of bottom water, fracture width, and production rate. It is suggested the production rate decreased to induce the water to invade the meso–macropores after the gas well begins to produce water to reduce the amount of residual gas in the meso–macropores. We used the nuclear magnetic resonance online detection method to analyze the water invasion mechanism and residual gas distribution of a carbonate rock gas reservoir. The T2 spectra obtained by using the Carr‐Purcell‐Meiboom‐Gill (CPMG) pulse sequence were applied to characterize the invasion water and residual gas distribution. The results showed that (a) in the pore‐type gas reservoir, the water first invades the meso–macropores and then the small pores as the pressure decreases further. The fracture distribution in a fracture‐pore‐type gas reservoir has an effect on the water invasion mode. The water can enter the pores through the fracture wall after the water invades the fracture. (b) In the pore‐type gas reservoir, 37.7% of the residual gas resides in the small pores, while the rest resides in the macropores. While in the fracture‐pore‐type gas reservoir, 4.8% ~ 26.8% of the residual gas is in the smaller pores and 69.2% ~ 95.7% in the macropores. Barely, any residual gas resides in the fractures. The residual gas in the small pores is difficult to produce. (c) The residual gas is controlled by the fracture penetration, amount of bottom water, fracture width, and production rate. It is suggested the production rate decreased to induce the water to invade the meso–macropores after the gas well begins to produce water to reduce the amount of residual gas in the meso–macropores. Abstract We used the nuclear magnetic resonance online detection method to analyze the water invasion mechanism and residual gas distribution of a carbonate rock gas reservoir. The T 2 spectra obtained by using the Carr‐Purcell‐Meiboom‐Gill (CPMG) pulse sequence were applied to characterize the invasion water and residual gas distribution. The results showed that (a) in the pore‐type gas reservoir, the water first invades the meso–macropores and then the small pores as the pressure decreases further. The fracture distribution in a fracture‐pore‐type gas reservoir has an effect on the water invasion mode. The water can enter the pores through the fracture wall after the water invades the fracture. (b) In the pore‐type gas reservoir, 37.7% of the residual gas resides in the small pores, while the rest resides in the macropores. While in the fracture‐pore‐type gas reservoir, 4.8% ~ 26.8% of the residual gas is in the smaller pores and 69.2% ~ 95.7% in the macropores. Barely, any residual gas resides in the fractures. The residual gas in the small pores is difficult to produce. (c) The residual gas is controlled by the fracture penetration, amount of bottom water, fracture width, and production rate. It is suggested the production rate decreased to induce the water to invade the meso–macropores after the gas well begins to produce water to reduce the amount of residual gas in the meso–macropores. |
| Author | Su, Penghui Guo, Chunqiu Cheng, Muwei Chen, Pengyu Li, Yunzhu Liu, Huiqing Zhao, Hailong Xing, Yuzhong Shi, Haidong Zhang, Liangjie |
| Author_xml | – sequence: 1 givenname: Pengyu surname: Chen fullname: Chen, Pengyu email: chenpengyu@petrochina.com.cn organization: CNPC Research Institute of Petroleum Exploration & Development – sequence: 2 givenname: Huiqing surname: Liu fullname: Liu, Huiqing email: liuhq@cup.edu.cn organization: China University of Petroleum – sequence: 3 givenname: Hailong orcidid: 0000-0001-8760-3944 surname: Zhao fullname: Zhao, Hailong email: chenpengyu@petrochina.com.cn, liuhq@cup.edu.cn, zhl@upc.edu.cn organization: Ministry of Education – sequence: 4 givenname: Chunqiu surname: Guo fullname: Guo, Chunqiu organization: CNPC Research Institute of Petroleum Exploration & Development – sequence: 5 givenname: Yuzhong surname: Xing fullname: Xing, Yuzhong organization: CNPC Research Institute of Petroleum Exploration & Development – sequence: 6 givenname: Muwei surname: Cheng fullname: Cheng, Muwei organization: CNPC Research Institute of Petroleum Exploration & Development – sequence: 7 givenname: Haidong surname: Shi fullname: Shi, Haidong organization: CNPC Research Institute of Petroleum Exploration & Development – sequence: 8 givenname: Liangjie surname: Zhang fullname: Zhang, Liangjie organization: CNPC Research Institute of Petroleum Exploration & Development – sequence: 9 givenname: Yunzhu surname: Li fullname: Li, Yunzhu organization: Chuanqing Drilling Engineering Company, PetroChina – sequence: 10 givenname: Penghui surname: Su fullname: Su, Penghui organization: CNPC Research Institute of Petroleum Exploration & Development |
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| CitedBy_id | crossref_primary_10_1016_j_geoen_2024_212881 crossref_primary_10_1016_j_compag_2022_107188 crossref_primary_10_1016_j_energy_2024_131305 |
| Cites_doi | 10.1016/S1876-3804(14)60057-4 10.1016/S1876-3804(17)30093-9 10.3390/en13225952 10.1016/j.ngib.2020.06.003 10.1016/j.petrol.2012.04.002 10.3390/en13184645 10.1016/S1876-3804(16)30016-7 10.1007/s13202-018-0487-7 10.1016/j.jngse.2017.11.010 10.1016/S1876-3804(18)30074-0 10.1016/j.jngse.2017.04.027 10.1016/S1876-3804(17)30031-9 10.1016/S1876-3804(14)60094-X 10.1016/S1876-3804(17)30110-6 10.1016/S1876-3804(17)30041-1 10.1016/S1876-3804(18)30011-9 10.1016/S1876-3804(17)30070-8 10.3390/en14061734 10.1016/S1876-3804(17)30011-3 10.1016/j.ngib.2019.01.002 |
| ContentType | Journal Article |
| Copyright | 2021 The Authors. published by Society of Chemical Industry and John Wiley & Sons Ltd. 2021. This work is published under http://creativecommons.org/licenses/by/4.0/ (the “License”). Notwithstanding the ProQuest Terms and Conditions, you may use this content in accordance with the terms of the License. |
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| Snippet | We used the nuclear magnetic resonance online detection method to analyze the water invasion mechanism and residual gas distribution of a carbonate rock gas... Abstract We used the nuclear magnetic resonance online detection method to analyze the water invasion mechanism and residual gas distribution of a carbonate... Abstract We used the nuclear magnetic resonance online detection method to analyze the water invasion mechanism and residual gas distribution of a carbonate... |
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| SubjectTerms | Bottom water carbonate gas reservoir Carbonate rocks displacement experiment Experiments Fractures Gas wells Magnetic fields meso‐macropores NMR Nuclear magnetic resonance Permeability Pores Reservoirs Residual gas residual gas distribution Statistical analysis water invasion mechanism |
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| Title | Microscopic characteristics of water invasion and residual gas distribution in carbonate gas reservoirs |
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