对油田注水系统节能降耗的探讨

从能耗及地面效率公式的分析出发，提出了提高注水泵效率、合理匹配电机、合理确定泵压、优化井站布局、减少管网损失等措施，为注水系统节能的主攻方向，从而达到降低注水耗电的目的。     

差动柱塞往复式增压注水泵的液力平衡分析

差动柱塞往复式增压注水泵采用差动柱塞结构使泵的高压吸入工况能够模拟常规柱塞式注水泵的低压吸入工况，模拟过程是一个液力平衡过程。借助于平衡率及平衡常数的概念，可以实现对这类泵型液力平衡效果的定量描述，从而为其进一步优化设计和现场造型提供参考依据。     

注水系统节能技术的探讨

大庆油田第二采油厂注水系统由于耗电最大,进行节能改造。采用注水泵高压变频技术,单耗可降至5．6（kW·h）／m^3,需3a收回成本,适用于单耗及泵管压差大的注水泵;采用注水泵减级技术,单耗可降至5．82（kW·h）／m^3,需69d收回成本,适用于区块注入压力低、泵管门压差大的注水泵;采用前置喂液泵技术,单耗可降至5．5（kW·h）／m^3,需1．5a收网成本;采用注水泵涂膜技术应用于泵效低的注水泵,单耗可下降0．2（kW·h）／m^3,需150d收回成本;应用液体黏性调速离合器．单耗可下降0．47（kW·h）／m^3,需要2．2a收回成本。     

碳酸盐岩油藏注水吞吐闷井时间初探

对于一个裂缝和溶洞大量发育的碳酸盐岩油藏,当没有外界能量补给的情况下,产量下降较快。通过单井注水吞吐．可以补充地层能量,恢复油井产量。对于注水后的闷井时间,往往是通过经验确定,并没有过定量的研究。文章在一定的简化条件下,推导了注水后合理闷井时间的计算公式。该公式能为现场的施工作业人员在控制闷井时间时提供有利的理论依据,这对油田的经济开采是很有帮助的。     

表面活性剂在单井注水吞吐采油中的应用研究

单井注水吞吐采油是开发无能量补充小型油藏的一种有效方法,但关井平衡时间长达1年以上,经济效益较低。在注入水中加入表面活性剂和粘土防膨胀剂的全模拟对比实验结果表明,关井时间可缩短50％,并保护了储层,其采出程度可提高3．15％。     

延迟神经网络测井资料评价水淹层的方法及应用

以取心分析的孔隙度和水饱和度为基础,建立测井信息与这些地居参数之间的非线性计算关系.用这种方法进 行参数解释,测井信息与油层参数之间的复杂关系不需要具体的数学物理模型描述,而只需要合适的样本集对网络进行 训练来获得解释模型,避开了油层水淹后,混合水电阻率求不准的问题.不同于已有的点对点的建模方法,本方法采用延迟神经网络模型,在建模和计算过程中自动考虑了测井响应上下围岩的影响.从而较好地解决了测井资料解释中地层厚度自适应校正和地层参数计算同时进行的问题.对一个油田注水开发后期 50口井的测井资料计算表明,这种方法具有良好的效果.     

MCS集散控制系统在孤东油田的应用

自动化技术可以提高计量准确度、数据可靠性和及时性,为优化生产运行、核算经济效益、强化生产调度和有效监控生产过程以及节能降耗工作起到积极作用。文章系统地介绍了MCS集散控制系统的组成、工作原理、技术指标、功能特点以及在油田注水系统中的现场应用情况等。     

The Productivity Equation for a Horizontal Well in a Fault Block,Rectangular Reservoir With Multiple Wells Flooding

It is suitable and practical as well as economical for many oilfield to deploy irregular patterns—vertical injection and horizontal production well group due to the geology complexity (e.g., as fault, structure), development cost and field operation of the actual reservoir. The authors present steady state productivity equations for a horizontal well in a fault block, rectangular reservoir with multiple wells flooding. The new equations, which are based on potential-flow theory, conformal mapping method, and superposition principle, are simple, accurate, and easy to use in field practice. In addition, the authors also give corresponding methods for calculating productivity. They conduct a comparison analysis by combining the practical field data, and this method can be applied to field productivity predication.     

Profile modification using in situ gelation technology — a review

Oil production during the primary stage is achieved due to the natural energy stored in the reservoir. Upon depletion of this energy, the production ceases or the oil production rate becomes so small that it will not be economical to operate. At this stage, a large fraction of the initial oil in place is still trapped under the ground. The oil recovery efficiency during the primary stage is within 10% to 30% depending on the nature of the reservoir. This means that more than70% of the initial oil in place is the target for the secondary and/or improved oil recovery techniques.During the secondary recovery stage, some kind of fluid is injected to push the oil from the injection well toward the producer. Water and gases are the most commonly used displacing fluids in this process. Waterflood is the most common practice of secondary oil recovery techniques. Injection of carbon dioxide or other gases is also a common practice to improve oil recovery efficiency. Regardless of the type of the fluid used to displace the oil, the displacing fluid could bypass the oil and early breakthrough could occur. In the case of waterflood, the water/oil ratio could become so high that the process ceases to be economical any more. For injection of CO₂ or other gases, the high gas/oil ratio renders the process uneconomical. This is more dramatic for heterogeneous and layered reservoirs with contrasting permeability variation among the layers. To remedy the above problem, some kind of polymer solution is injected into the reservoir and is allowed to gel under certain conditions. The gel viscosity being much higher than the displacing fluid could impede the flow of displacing fluid through the already flooded regions; therefore, the displacing fluid is bound to find new paths which means additional oil can be displaced. Profile modification based on in situ gelation technology is an already proven economical process for improving oil recovery. There is a variety of gelation systems available in the market for the treatment of the reservoir. Most of the gelation systems in the market are based on cross-linking of polyacrylamide-type polymers by some kind of heavy metal ions such as chromium to produce a three-dimensional gel structure in situ in the reservoir. Recent research efforts at the University of Kansas have produced a new type of bio-polymer which gels without cross-linker. Gelation occurs by reducing the pH of the alkaline solution and the gelation process is reversible. This paper will discuss the in situ gelation techniques based on the commercially available systems and the newly discovered bio-polymer as mentioned above.     

卫95块调剖提高水驱采收率应用研究

马寨油田卫９５块是典型的低渗透复杂断块砂岩油藏，已进入高含水期，水驱动用程度较低。为了提高水驱采收率，根据卫９５块地质特征等研制了纸浆系列调剖剂，确定了与之配套的选井、选层原则及四段封堵最佳注入方式等调剖工艺技术，提高了水驱波及体积。卫９５块经调剖后，含水上升率由２．４％降至１．５４％，水驱动用程度提高了６．３个百分点，自然递减率由２３．６％降至２１．１％，可采储量增加了４４×１０４ｔ，水驱采收率由标定的３１．５％提高到３８．１％，增油２１６３８ｔ。卫９５块调剖的投入产出比为１∶７．３，经济效益显著。研究表明：对于注水开发的低渗透、低孔隙度油田，利用调剖工艺提高水驱采收率是技术可行、经济实惠的。