河流相稠油油田合理注水时机实验研究
|
摘要
针对河流相稠油油藏衰竭开发转注水开发注水时机难以确定的问题,以渤海秦皇岛32-6油田油藏参数为基础,通过物理模拟的手段寻求最佳注水时机。首先确定油田各区块的最佳衰竭压力,然后在原始地层压力和最佳衰竭压力之间选取5个压力点进行注水时机模拟实验,同时开展注水过程中是否需要恢复压力至原始地层压力的对比实验。结果表明:各区块最佳衰竭压力为饱和压力的90%~96%,且原油黏度越大,最佳衰竭压力越接近饱和压力;注水时机选择在最佳衰竭压力时,可获得较高的无水采油期和采收率,且累计注水量最少;注水恢复压力至原始地层压力开发并不能提高开发效果,反而耗水量增多。因此,河流相稠油油田合理注水时机推荐最佳衰竭压力附近,能有效利用天然能量,获得较高的采收率,且可减小注水量,降低生产成本。该结论和认识在数值模拟中也得到了验证,对同类油藏的开发具有指导和借鉴意义。
For solving the problem that the water injection opportunity changed from depletion development of heavy oil reservoirs in fluvial facies is hard to confirm,on the basis of reservoir parameters of the Qinhuangdao 32-6 oilfield in Bohai Sea,we tried to find the optimum water injection opportunity by physical simulation. Firstly,we confirmed the optimum depletion pressure for each block of this oilfield; after that,we selected five pressure values between the initial formation pressure and the optimum depletion pressure to do physical simulation experiments for confirming water injection opportunity; meanwhile,we conducted comparison experiments for determining whether it is necessary to restore the pressure to initial formation pressure during water injection. The study result shows that:( 1) the optimum depletion pressure of each block is 90%-96% of the saturation pressure;( 2) the bigger crude oil viscosity,the closer of the optimum depletion pressure to the saturation pressure;( 3) if the water injection is conducted at the optimum depletion pressure,we can obtain longer water free oil production period and higher recovery ratio,and the total injected water quantity is the minimum;( 4) the development effect cannot be improved by restoring the pressure to the initial formation pressure,but leading to more water consumption. Hence,we recommend the reasonable water injection opportunity to be near the optimum depletion pressure,which can effectively utilize natural energy,obtain higher recovery ratio,reduce injected water quantity,and decrease production cost. This conclusion and cognition has been verified by numerical simulation,thus it has guiding and referring significance for developing similar oil reservoirs.
For solving the problem that the water injection opportunity changed from depletion development of heavy oil reservoirs in fluvial facies is hard to confirm,on the basis of reservoir parameters of the Qinhuangdao 32-6 oilfield in Bohai Sea,we tried to find the optimum water injection opportunity by physical simulation. Firstly,we confirmed the optimum depletion pressure for each block of this oilfield; after that,we selected five pressure values between the initial formation pressure and the optimum depletion pressure to do physical simulation experiments for confirming water injection opportunity; meanwhile,we conducted comparison experiments for determining whether it is necessary to restore the pressure to initial formation pressure during water injection. The study result shows that:( 1) the optimum depletion pressure of each block is 90%-96% of the saturation pressure;( 2) the bigger crude oil viscosity,the closer of the optimum depletion pressure to the saturation pressure;( 3) if the water injection is conducted at the optimum depletion pressure,we can obtain longer water free oil production period and higher recovery ratio,and the total injected water quantity is the minimum;( 4) the development effect cannot be improved by restoring the pressure to the initial formation pressure,but leading to more water consumption. Hence,we recommend the reasonable water injection opportunity to be near the optimum depletion pressure,which can effectively utilize natural energy,obtain higher recovery ratio,reduce injected water quantity,and decrease production cost. This conclusion and cognition has been verified by numerical simulation,thus it has guiding and referring significance for developing similar oil reservoirs.
引文
[1]葛丽珍,张鹏.秦皇岛32-6油田含水上升快原因分析[J].中国海上油气,2005,17(6):394-397.
[2]陈文将,张浩男,周治刚,等.岩心润湿性对油水相对渗透率和采收率影响[J].石油化工高等学校学报,2016,29(5):65-69.
[3]罗情勇,钟宁宁,李可文.油显示岩心样品Slice实验研究及其启示[J].石油实验地质,2015,37(2):252-258.
[4]李波,李廷礼,张迎春.高渗透砂岩油藏注水时机实验研究[J].石油学报,2007,28(1):78-82.
[5]ANDARCIA L.Heavy oil solution gas drive in the venezuelan orinoco belt:laboratory experiments and field simulation[C].SPE69715,2001:1-8.
[6]徐守余,朱连章,王德军.微观剩余油动态演化仿真模型研究[J].石油学报,2005,26(2):69-72.
[7]贾忠伟,杨清彦,兰玉波,等.水驱油微观物理模拟实验研究[J].大庆石油地质与开发,2002,21(1):46-49.
[8]殷代印,巩象珠.特低渗透油藏超前注水合理技术参数实验研究[J].石油化工高等学校学报,2016,29(4):18-24.
[9]彭松,郭平.缝洞型碳酸盐岩凝析气藏注水开发物理模拟研究[J].石油实验地质,2014,36(5):645-649.
[10]段昌旭.孤岛常规稠油油藏[M].北京:石油工业出版社,1997:36-57.
[11]王爱景.埕岛油田馆陶组上亚段油藏注水时机动态评价[J].油气地质与采收率,2003,10(1):43-45.
[12]徐春碧,黄小亮,唐海,等.低渗透油藏注水开发时机研究[J].钻采工艺,2011,34(2):53-55.
[13]谢晓庆,姜汉桥,王全柱,等.低渗透油藏压敏效应与注水时机研究[J].石油学报,2009,30(4):574-582.
[14]王黎,饶良玉,李薇,等.苏丹P油田注水时机实验及数值模拟研究[J].西南石油大学学报(自然科学版)2011,33(3):109-114.
[15]王小林,王杰祥.层状非均质油藏不稳定注水室内实验研究[J].特种油气藏,2009,16(4):79-81.
[16]孙孟茹,崔文富.胜沱油田沱28块沙二段9-103层系特高含水期地层压力保持水平研究[J].油气地质与采收率,2003,10(6):37-39.
[17]单亦先,劳海港,王永诗,等.岩性差异变化对断层带结构影响的物理模拟[J].石油实验地质,2016,38(1):108-112.
[18]李留仁,袁士义,胡永乐.合理注采井数比与合理压力保持水平的确定[J].西安石油大学学报(自然科学版),2011,26(3):59-61.
[19]田仲强,王奎升,等.不稳定注水模拟实验及其在不同类型砂岩油藏中的应用[J].石油大学学报,2000,24(5):28-31.
[20]苑登御,侯吉瑞,宋兆杰,等.塔河油田缝洞型碳酸盐岩油藏注水方式优选及注气提高采收率实验[J].东北石油大学学报,2015,39(6):102-110.
[21]张学刚,王秀宇,代春明,等.周期注水实验研究及力学机理探讨[J].石油化工高等学校学报,2015,28(6):66-70.
[22]王涛,颜明,郭海波.一种新的回归分析方法——响应曲面法在数值模拟研究中的应用[J].岩性油气藏,2011,23(2):100-104.
[23]王涛.响应曲面法在油藏提液效果影响因素研究中的应用[J].重庆科技学院学报(自然科学版),2015,17(3):66-70.
[24]杨新平,陈光喜,姜瑞忠,等.砾岩油藏采收率理论公式推导与应用[J].特种油气藏,2016,23(5):96-99.
[25]朱卫红,吴胜和,韩尚儒,等.哈得A-39-2J注水井异常压降资料分析与应用[J].特种油气藏,2016,23(6):60-63.
[26]程亮,石磊,王娟,等.塔中高——特高含凝析油凝析气藏注水驱油研究[J].特种油气藏2016,23(3):86-89.
[27]孙林,孟向丽,蒋林宏,等.渤海油田注水井酸化低效对策研究[J].特种油气藏,2016,23(3):144-147.
[2]陈文将,张浩男,周治刚,等.岩心润湿性对油水相对渗透率和采收率影响[J].石油化工高等学校学报,2016,29(5):65-69.
[3]罗情勇,钟宁宁,李可文.油显示岩心样品Slice实验研究及其启示[J].石油实验地质,2015,37(2):252-258.
[4]李波,李廷礼,张迎春.高渗透砂岩油藏注水时机实验研究[J].石油学报,2007,28(1):78-82.
[5]ANDARCIA L.Heavy oil solution gas drive in the venezuelan orinoco belt:laboratory experiments and field simulation[C].SPE69715,2001:1-8.
[6]徐守余,朱连章,王德军.微观剩余油动态演化仿真模型研究[J].石油学报,2005,26(2):69-72.
[7]贾忠伟,杨清彦,兰玉波,等.水驱油微观物理模拟实验研究[J].大庆石油地质与开发,2002,21(1):46-49.
[8]殷代印,巩象珠.特低渗透油藏超前注水合理技术参数实验研究[J].石油化工高等学校学报,2016,29(4):18-24.
[9]彭松,郭平.缝洞型碳酸盐岩凝析气藏注水开发物理模拟研究[J].石油实验地质,2014,36(5):645-649.
[10]段昌旭.孤岛常规稠油油藏[M].北京:石油工业出版社,1997:36-57.
[11]王爱景.埕岛油田馆陶组上亚段油藏注水时机动态评价[J].油气地质与采收率,2003,10(1):43-45.
[12]徐春碧,黄小亮,唐海,等.低渗透油藏注水开发时机研究[J].钻采工艺,2011,34(2):53-55.
[13]谢晓庆,姜汉桥,王全柱,等.低渗透油藏压敏效应与注水时机研究[J].石油学报,2009,30(4):574-582.
[14]王黎,饶良玉,李薇,等.苏丹P油田注水时机实验及数值模拟研究[J].西南石油大学学报(自然科学版)2011,33(3):109-114.
[15]王小林,王杰祥.层状非均质油藏不稳定注水室内实验研究[J].特种油气藏,2009,16(4):79-81.
[16]孙孟茹,崔文富.胜沱油田沱28块沙二段9-103层系特高含水期地层压力保持水平研究[J].油气地质与采收率,2003,10(6):37-39.
[17]单亦先,劳海港,王永诗,等.岩性差异变化对断层带结构影响的物理模拟[J].石油实验地质,2016,38(1):108-112.
[18]李留仁,袁士义,胡永乐.合理注采井数比与合理压力保持水平的确定[J].西安石油大学学报(自然科学版),2011,26(3):59-61.
[19]田仲强,王奎升,等.不稳定注水模拟实验及其在不同类型砂岩油藏中的应用[J].石油大学学报,2000,24(5):28-31.
[20]苑登御,侯吉瑞,宋兆杰,等.塔河油田缝洞型碳酸盐岩油藏注水方式优选及注气提高采收率实验[J].东北石油大学学报,2015,39(6):102-110.
[21]张学刚,王秀宇,代春明,等.周期注水实验研究及力学机理探讨[J].石油化工高等学校学报,2015,28(6):66-70.
[22]王涛,颜明,郭海波.一种新的回归分析方法——响应曲面法在数值模拟研究中的应用[J].岩性油气藏,2011,23(2):100-104.
[23]王涛.响应曲面法在油藏提液效果影响因素研究中的应用[J].重庆科技学院学报(自然科学版),2015,17(3):66-70.
[24]杨新平,陈光喜,姜瑞忠,等.砾岩油藏采收率理论公式推导与应用[J].特种油气藏,2016,23(5):96-99.
[25]朱卫红,吴胜和,韩尚儒,等.哈得A-39-2J注水井异常压降资料分析与应用[J].特种油气藏,2016,23(6):60-63.
[26]程亮,石磊,王娟,等.塔中高——特高含凝析油凝析气藏注水驱油研究[J].特种油气藏2016,23(3):86-89.
[27]孙林,孟向丽,蒋林宏,等.渤海油田注水井酸化低效对策研究[J].特种油气藏,2016,23(3):144-147.
© 2004-2018 中国地质图书馆版权所有 京ICP备05064691号 京公网安备11010802017129号 地址：北京市海淀区学院路29号 邮编：100083 电话：办公室：(+86 10)66554848；文献借阅、咨询服务、科技查新：66554700 |