新疆某地衰竭气藏地下储气库地应力特征研究
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摘要
储气库的建库、运行是一个综合诸多高新技术的领域。本文在常规地质研究的基础上，开展了影响储气库建库运行的包括应力、渗流特征等地质特征研究。利用成像测井资料，定量评价了地应力大小和方向，构建了储层的孔隙压力、坍塌压力和破裂压力等三压力剖面。在测井解释进行物性分析的基础上，利用试井分析成果开展了储气库衰竭开采后物性随孔隙压力的变化特征，定量确定了渗透率变化对储气库运行时对单井注采能力的影响。
本次研究还作为储气库研究的国内先例引进了将储层、单井和地面集输一体化研究的数值模拟技术，利用该技术将储气库的气藏工程问题和开发过程中的应力与应变关系等复杂物理问题耦合在一起，开展储气库的各项指标的模拟和预测，本文侧重分析了储气库运行时的孔隙压力变化、裂缝、水体入侵情况、储气库的注采调峰能力以及库容等储气库运行的关键指标。
主要结论：长期衰竭式开采对储层的物性有所影响，渗透能力略有下降。对单井产能有一定影响；目前储层段最大水平主地应力方向为N23°，孔隙压力13.7MPa，储层段的破裂压力为57MPa。为了防止突破两个主要断裂带及盖层，储层最高压力应低于69.16MPa，盖层的突破压力为49MPa。推荐方案可以在满足储气库调峰要求的前提下，确保储层的地应力在安全范围内，储气库运行过程中不会出现应力导致的裂缝。
气藏工作气量达到45.1×10~8m~3时，库容为127.7×10~8m~3，大于设计库容107×10~8m~3，气藏压力为30.38MPa，小于设计压力34MPa，进一步的模拟结果表明在气藏压力上升至上限压力34MPa时的库容为145×10~8m~3。储气库目前控制边底水效果较好。水侵对储气库建库运行影响较大，因此，业内常会使用的压边底水扩容的做法在本地区不适用；
数值模拟预测系统最大产气量为2535×10~4m~3/d，最小产气量为252×10~4m~3/d。单井最大注入量范围为35～314×10~4m~3/d。
本次研究为储气库建库运行实施方案的编制提供了强有力的技术支撑，利用一体化模型跟踪模拟可以作为储气库的运行监测手段指导生产。
The building and operation of underground gas storage after reservoir depletionis a comprehensive technique. In this paper, on the basis of conventional geologicalresearch, the study including stress-strain characteristics and seepage characteristicswhich effect gas storage rebuilt is carried out. Using FMI well logging data, in-situstress of the work area has quantitative evaluated, pore pressure, collapse pressure,and fracture pressure profile of reservoir has constructed. On the basis of physicalproperty analysis in well logging interpretation, using the well test analysis wascarried out in order to understand the physical characteristics changes alongdevelopment with the change of pore pressure, and further quantitatively determinesthe permeability change, which effects the injection&production capacity while gasstorage operating. Using stress coupling numerical simulator to forecast the porepressure change according to the injection scheme, the stress change caused by porepressure will not damage the faults stability and crack also won't appear under thecondition of the recommend scheme.
This research also introduce a new simulation technology which integratedreservoir model, well model, and surface gathering model together to predict theproduction performance for gas storage. This integrated application is the domesticfirst time for gas storage. This integrated model coupling the gas reservoirengineering problems and the physical problems such as stress and strain relationscaused by development process together to carry out simulation and forecast of theKPI of gas storage, this paper focuses on analyzing the variation of pore pressure ingas storage operation, crack, water invasion, load of gas storage capacity and theKPI of gas storage operation.
Main conclusion:
Long-term depletion influence physical properties of researvoir and reduce wellproductivity because of permeability decreased. SH_(MAX)of in-situ stress direction isN23°. The gas bearing layer’s pore pressure is lower to13.7MPa, the fracturepressure is57MPa. In order to prevent break through two main fault zone and cap,the critical reservoir pressure should be less than69.16MPa, the cap breakthrough pressure is49MPa. Recommendations can be on the premise of meet therequirements of gas storage load regulation, to ensure the safety of the reservoirin-situ stress during operation and no cracks appearence.
This Gas storage is in better control of edge-bottom water effect on the current.Water influx cause reservoir damage in this area therefore, gas injection to drive theedge-bottom water to expand the capacity of gas storage shall not apply in this area.
When work volume of the gas storage is45.1×10~8m~3, reservoir capacity is upto127.7×10~8m~3, which greater than the design capacity of107×10~8m~3. Gasreservoir pressure is up to30.38MPa, which less than the design pressure of34MPa.Further simulation results show that when gas reservoir pressure rise to34MPa, theupper limit storage capacity will be145×10~8m~3.
The upper productivity is2535×10~4m~3/d, the lower gas production is252×10~4m~3/d. The upper productivity of each well is from35×10~4m~3/d to314×10~4m~3/d。
Through this study, the stress numerical model of the work area is established;the quantitative research of reservoir physical properties change and its impact onproduction capacity of gas storage is researched.
The integration of numerical simulation methods has been introduced forsimulate the key production index of gas storage operation. The study also providesa strong technical support for gas storage operation scheduling research. Theintegrated model also can be a monitor for safe operation to ensure the long-termoperation of the gas storage.
本次研究还作为储气库研究的国内先例引进了将储层、单井和地面集输一体化研究的数值模拟技术，利用该技术将储气库的气藏工程问题和开发过程中的应力与应变关系等复杂物理问题耦合在一起，开展储气库的各项指标的模拟和预测，本文侧重分析了储气库运行时的孔隙压力变化、裂缝、水体入侵情况、储气库的注采调峰能力以及库容等储气库运行的关键指标。
主要结论：长期衰竭式开采对储层的物性有所影响，渗透能力略有下降。对单井产能有一定影响；目前储层段最大水平主地应力方向为N23°，孔隙压力13.7MPa，储层段的破裂压力为57MPa。为了防止突破两个主要断裂带及盖层，储层最高压力应低于69.16MPa，盖层的突破压力为49MPa。推荐方案可以在满足储气库调峰要求的前提下，确保储层的地应力在安全范围内，储气库运行过程中不会出现应力导致的裂缝。
气藏工作气量达到45.1×10~8m~3时，库容为127.7×10~8m~3，大于设计库容107×10~8m~3，气藏压力为30.38MPa，小于设计压力34MPa，进一步的模拟结果表明在气藏压力上升至上限压力34MPa时的库容为145×10~8m~3。储气库目前控制边底水效果较好。水侵对储气库建库运行影响较大，因此，业内常会使用的压边底水扩容的做法在本地区不适用；
数值模拟预测系统最大产气量为2535×10~4m~3/d，最小产气量为252×10~4m~3/d。单井最大注入量范围为35～314×10~4m~3/d。
本次研究为储气库建库运行实施方案的编制提供了强有力的技术支撑，利用一体化模型跟踪模拟可以作为储气库的运行监测手段指导生产。
The building and operation of underground gas storage after reservoir depletionis a comprehensive technique. In this paper, on the basis of conventional geologicalresearch, the study including stress-strain characteristics and seepage characteristicswhich effect gas storage rebuilt is carried out. Using FMI well logging data, in-situstress of the work area has quantitative evaluated, pore pressure, collapse pressure,and fracture pressure profile of reservoir has constructed. On the basis of physicalproperty analysis in well logging interpretation, using the well test analysis wascarried out in order to understand the physical characteristics changes alongdevelopment with the change of pore pressure, and further quantitatively determinesthe permeability change, which effects the injection&production capacity while gasstorage operating. Using stress coupling numerical simulator to forecast the porepressure change according to the injection scheme, the stress change caused by porepressure will not damage the faults stability and crack also won't appear under thecondition of the recommend scheme.
This research also introduce a new simulation technology which integratedreservoir model, well model, and surface gathering model together to predict theproduction performance for gas storage. This integrated application is the domesticfirst time for gas storage. This integrated model coupling the gas reservoirengineering problems and the physical problems such as stress and strain relationscaused by development process together to carry out simulation and forecast of theKPI of gas storage, this paper focuses on analyzing the variation of pore pressure ingas storage operation, crack, water invasion, load of gas storage capacity and theKPI of gas storage operation.
Main conclusion:
Long-term depletion influence physical properties of researvoir and reduce wellproductivity because of permeability decreased. SH_(MAX)of in-situ stress direction isN23°. The gas bearing layer’s pore pressure is lower to13.7MPa, the fracturepressure is57MPa. In order to prevent break through two main fault zone and cap,the critical reservoir pressure should be less than69.16MPa, the cap breakthrough pressure is49MPa. Recommendations can be on the premise of meet therequirements of gas storage load regulation, to ensure the safety of the reservoirin-situ stress during operation and no cracks appearence.
This Gas storage is in better control of edge-bottom water effect on the current.Water influx cause reservoir damage in this area therefore, gas injection to drive theedge-bottom water to expand the capacity of gas storage shall not apply in this area.
When work volume of the gas storage is45.1×10~8m~3, reservoir capacity is upto127.7×10~8m~3, which greater than the design capacity of107×10~8m~3. Gasreservoir pressure is up to30.38MPa, which less than the design pressure of34MPa.Further simulation results show that when gas reservoir pressure rise to34MPa, theupper limit storage capacity will be145×10~8m~3.
The upper productivity is2535×10~4m~3/d, the lower gas production is252×10~4m~3/d. The upper productivity of each well is from35×10~4m~3/d to314×10~4m~3/d。
Through this study, the stress numerical model of the work area is established;the quantitative research of reservoir physical properties change and its impact onproduction capacity of gas storage is researched.
The integration of numerical simulation methods has been introduced forsimulate the key production index of gas storage operation. The study also providesa strong technical support for gas storage operation scheduling research. Theintegrated model also can be a monitor for safe operation to ensure the long-termoperation of the gas storage.
引文
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