SAGD添加非凝析气技术研究

利用数值模拟和物理模拟方法对蒸汽辅助重力泻油(SAGD)技术进行研究,对比分析了非凝析气在SAGD中的增产机理,跟踪分析国外UTF项目中SAGP应用情况和效果,认为向蒸汽中添加非凝析气体是一项技术上可行的方法,非凝析气体在蒸汽的前面运动,具有较高的驱油效率,能够维持成熟SAGD蒸汽腔的有效扩展,可以取得较好的产油速度和油汽比,节约了蒸汽的用量;UTF现场试验数据和所得的结论对SAGD的后续开发具有重要的借鉴作用,证明了该工艺具有广泛的推广应用价值.     

蒸汽辅助重力泄油渗流机理研究

针对双水平井及直井与水平井组合蒸汽辅助重力泄油(SAGD)两种常用布井方式,利用数值模拟方法及Surfer制图软件制作出重力过程中泄油初期、高峰期及泄油后期不同泄油阶段蒸汽腔截面的温度场、压力场、剩余油饱和度场的场图,更直观、形象的描述了SAGD的蒸汽腔形成及扩展过程以及不同泄油阶段蒸汽腔形状及泄油机理,并对两种布井方式的重力泄油效果进行了比较,为SAGD技术的应用提供决策依据.     

油砂油电加热开采技术应用

目前现有的油砂开采技术,无法开采地下100~250 m位置的油砂资源,本文介绍的ET-DSPTM电加热技术能有效解决此问题,并且工艺技术安全、环保、可靠。     

Sensitivity Analysis to Operational Parameters of the Offset Well During Fast-SAGD Process in Naturally Fractured Reservoir

Few studies were done to investigate performance of the Fast steam-assisted gravity damage (SAGD) recovery method especially in naturally fractured reservoirs (NFR). The authors studied some cyclic steam stimulated operational parameters effects on the Fast-SAGD performance in NFR. A synthetic 2D homogenous model was constructed by Computer Modelling Group's (CMG) and simulated using the STARS module. Comparison between SAGD and Fast-SAGD recovery methods in this model shows great increase in the oil production but small increase of thermal efficiency in the Fast-SAGD recovery method. Simulation outcomes represent 17% increment in ultimate recovery factor but small reduction in steam-oil ratio. Results show that increasing the number of offset cycles and injection period yield increment in the oil production. Increasing the offset injection rate causes growth in the oil production, but has an optimal value. By increasing the distance between the offset well and SAGD well pairs up to a certain value, oil production increases but decreases after that point. This is due to the ability of the fractures in making connection between the steam chambers in higher distances. When production bottom-hole pressure decreases, the heated oil in near well region is subjected to more pressure drop and causes more oil to be produced. More offset wells result in higher production but simultaneously lower recovery factors. Increasing and decreasing soak time as the last investigated parameter did not affect the trend of production anyway.     

直井与水平井组合的蒸汽辅助重力泄油产量预测

蒸汽辅助重力泄油（SAGD）是一种利用液体自身重力作为主要驱动力的热采方式。国外的SAGD先导实验，大多数是利用双水平井的组合方式进行，注入井和采出井都是水平井，而在辽河油田进行的先导实验，是利用直井作为注入井、水平井作为生产井的组合方式。针对辽河油田先导实验的注采方式，利用保角变换，将水平井转化为像平面上一口环形生产井的一部分；垂直注汽井变成像平面上的原点。对直井与水平井组合的SAGD井组，按照直井划定流动单元，分别计算叠加，可以得到水平井的产量，提供了直井和水平井组合的重力泄油产量预测方法。依据辽河油田杜84块SAGD先导实验区实际生产数据，利用文中提供的方法进行计算，预测的产量结果与油田实际数据非常吻合，证明文中推导的直井与水平井组合的SAGD预测方法是可靠的。     

中深层超稠油SAGD开发动态调控技术

SAGD作为超稠油蒸汽吞吐开发的接替技术,2005年在曙一区杜84块馆陶油藏进行SAGD先导试验.实施过程中,先后遇到汽液界面不合理、水平段动用状况不均匀、水平井汽窜以及注采不均衡等问题.以SAGD操作理念为指导,以动态生产曲线为基础,以动态监测系统为手段,在借鉴国外成功经验的基础上,坚持自主创新,不断优化调整,研究出适合油藏特点的配套动态调控方法.综合利用阻汽控制、水平段均匀动用、水平井防窜以及注采平衡等调控技术.使先导试验操作平稳,达到或超过方案设计指标.     

风城油田重18井区浅层SAGD双水平井钻井技术

SAGD钻井技术是开发超稠油油藏的一种前沿技术,在国内外的超稠油油藏开发中已经被大规模采用。2008年新疆油田公司开辟先导试验区并尝试使用SAGD技术开采风城油田重18井区超稠油油藏,取得了一定的效益。在此基础上,近年来开始进行大规模的SAGD钻井。本文结合近年来施工的SAGD双水平井中其中的一对井——FHW117P生产水平井和FHW117I注汽水平井,对SAGD双水平井钻井技术进行了介绍。塔式满眼防斜钻具、磁性定位导向技术、针对性的钻井液技术等,是该对双水平井顺利完钻的关键。另外,通过保持钻井液良好的润滑性、使用可循环式加压装置和大质量钻铤对筛管施加下压力的措施,使Φ177.8 mm筛管顺利下入Φ215.9 mm井眼内。     

蒸汽辅助重力驱产量预测

蒸汽辅助重力驱（SAGD）是水平井结合注蒸汽开采稠油的一种较为新颖的开采方式。针对目前蒸汽辅助重力驱的研究现状,在前人研究的基础上,进行SAGD生产的产量动态预测,将其结果与现场数据进行对比。探讨超稠油油藏蒸汽辅助重力泄油的渗流机理和渗流规律,从而为油田进行蒸汽辅助重力泄油的开发提供理论依据。     

Asphaltene Deposition During Steam-Assisted Gravity Drainage: Effect of Non-Condensable Gases

Asphaltene deposition was investigated during laboratory-scale steam-assisted gravity drainage (SAGD) experiments to probe in situ upgrading of a heavy oil. Tests were conducted with and without the addition of non-condensable gases (carbon dioxide or n-butane) to the steam. The apparatus was a three-dimensional scaled physical model packed with crushed limestone saturated with 12.4° API heavy-crude oil. Temperature, pressure, and production data, as well as the asphaltene content of the produced oil, were monitored continuously during the experiments. For small well separations, as the fraction of non-condensable gas in the steam increased, the steam condensation temperature and the steam-oil ratio decreased. As a result of lower temperature, the heavy oil was less mobile in the steam chamber relative to pure steam injection. Thus, the heating period was prolonged and the recovery, as well as the rate of oil recovery, decreased. Asphaltene content of the oil produced as a result of pure steam injection decreased initially showing deposition of asphaltene within the porous matrix of the model. As the steam injection continued, the asphaltene content of the produced oil increased but remained below the initial value. Thus, the produced oil indicated some in situ upgrading. As the carbon dioxide concentration in the steam increased, greater asphaltene deposition occurred; however, no significant change in asphaltene content was found when n-butane was added to the steam. Post-experimental analyses of the porous media for asphaltene content confirmed retention for the pure steam and steam with added CO₂ experiments. Numerical simulation of the asphaltene deposition process using a pure solid deposition model corroborated experimental findings and showed that deposition occurred mainly at the steam-chamber boundary.