Optimization of Injection Parameters for Profile Control and Flooding in an Oilfield during High Water Cut Period

In order to improve the effect of water control and oil stabilization during high water cut period, a mathematical model of five point method well group was established with the high water cut well group of an Oilfield as the target area, the variation law of water cut and recovery factor of different injection parameters was analyzed, and the optimization research of injection parameters of polymer enhanced foam flooding was carried out. The results show that the higher the injection rate, the lower the water content curve, and the higher the oil recovery rate. As the foam defoamed when encountering oil, when the injection time was earlier than 80% of water cut, the later the injection time was, the better the oil displacement effect would be. When the injection time was later than 80% of water cut, the later the injection time was, the worse the oil displacement effect would be. The larger the injection volume, the lower the water content curve and the higher the recovery rate. After the injection volume exceeded 0.2 PV, the amplitude of changes in water content and recovery rate slowed down. The optimal injection parameters of profile control agent for high water content well group in Oilfield A were: injection rate of 15 m3/d, injection timing of 80% water content, and injection volume of 0.2 PV.

Optimization of the Algorithm for Increasing Injection Rate in Water Injection Wells for Pressure Optimization in P Oilfield

In today’s society, with the continuous growth of energy demand, Bohai Oilfield, as an important offshore oil resource base in China, is facing increasingly severe challenges while contributing to national energy security. In order to improve the quality of water injection in the oilfield and gradually achieve efficient and stable production, Bohai Oilfield has launched a water injection well pressure optimization project, focusing on improving the efficiency and quality of water injection in the water injection wells, in order to achieve the optimal water injection plan. In practical work, P Oilfield continues to promote the development of water injection well pressure optimization projects, emphasizing practical exploration and continuous optimization of work plans. However, during the project implementation process, there were some problems, one of which was that the statistics of cumulative injection volume were not scientific enough, resulting in a more comprehensive and accurate presentation of the actual results of pressure optimization work. In the context of continuous improvement work, after careful analysis and research, P Oilfield has decided to optimize the cumulative injection rate algorithm to guide the oilfield’s water injection work in a more refined way, ensuring sufficient and good water injection, and enhancing the oilfield’s production efficiency and comprehensive competitiveness.

Research into polymer injection timing for Bohai heavy oil reservoirs

Polymer flooding has been proven to effectively improve oil recovery in the Bohai Oil Field. However, due to high oil viscosity and significant formation heterogeneity, it is necessary to further improve the displacement effectiveness of polymer flooding in heavy oil reservoirs in the service life of offshore platforms. In this paper, the effects of the water/oil mobility ratio in heavy oil reservoirs and the dimensionless oil productivity index on polymer flooding effectiveness were studied utilizing rel- ative permeability curves. The results showed that when the water saturation was less than the value, where the water/oil mobility ratio was equal to 1, polymer flooding could effectively control the increase of fractional water flow, which meant that the upper limit of water/oil ratio suitable for polymer flooding should be the value when the water/oil mobility ratio was equal to 1. Mean while, by injecting a certain volume of water to create water channels in the reservoir, the polymer flooding would be the most effective in improving sweep efficiency, and lower the fractional flow of water to the value corresponding to △Jmax. Considering the service life of the platform and the polymer mobility control capacity, the best polymer injection timing for heavy oil reservoirs was optimized. It has been tested for reservoirs with crude oil viscosity of 123 and 70 mPa s, the optimum polymer flooding effec- tiveness could be obtained when the polymer floods were initiated at the time when the fractional flow of water were 10 % and 25 %, respectively. The injection timing range for polymer flooding was also theoretically analyzed for the Bohai Oil Field utilizing which provided methods for effectiveness. relative permeability curves, improving polymer flooding

Optimization of DNA Staining Technology for Development of Autonomous Microbe Sensor for Injection Seawater Systems

Microbial activity in the water injection system in oil and gas industry leads to an array of challenges, including biofouling, injectivity loss, reservoir plugging, and microbiologically influenced corrosion (MIC). An effective mitigation strategy requires online and real-time monitoring of microbial activity and growth in the system so that the operators can apply and adjust counter-measures quickly and properly. The previous study [1] identified DNA staining technology-with PicoGreen and SYBR Green dyes—as a very promising method for automated, online determination of microbial cell abundance in the vast Saudi Aramco injection seawater systems. This study evaluated DNA staining technology on detection limit, automation potential, and temperature stability for the construction of automated sensor prototype. DNA staining with SYBR Green dye was determined to be better suited for online and real-time monitoring of microbial activity in the Saudi Aramco seawater systems. SYBR Green staining does not require sample pre-treatment, and the fluorescence signal intensity is more stable at elevated temperatures up to 30℃. The lower detection limit of 2 × 103/ml was achieved under the optimized conditions, which is sufficient to detect microbial numbers in Saudi Aramco injection seawater. Finally, the requirements for design and construction of SYBR-based automated sensor prototype were determined.

Research on subsidence method aided by water injection and its engineering application for the north anchor of Taizhou Bridge

The north anchorage caisson of Taizhou Bridge encountered some difficulties during the sinking process for the large sidewall frictional resistances. To solve this problem, a new concept and method called subsidence method aided by water injection is proposed. Numeral analysis is adopted to simulate the effects of this method for the north anchor of Taizhou Bridge, which confirmed the feasibility and validity. Finally, the method is applied to the north anchor caisson during the caisson sinking procedure and helps the caisson sink and embed to the designed position smoothly.

A New Method for the Dynamic Reserves of Gas Condensate Reservoir Using Cyclic Gas Injection Based on the Effects of Reinjection Ratio and Water Influx

As we all know, cyclic gas injection is one of the most effective development methods to improve condensate oil recovery. When dealing with the calculation of the reserves, the injection-production differences and water influx create great influence on the accuracy. Based on the existing research, we proposed a new material balance equation which considered the differences of composition between produced and injected fluids and the effect of water influx, and a solution was provided in this paper. The results of the method are closer to the actual situation because they are built on the law of conservation of mass, and the using of curve fitting method can not only avoid the use of water influx coefficient but also obtain the water influx rate and reserves at the same time. The YH-23 gas condensate reservoir is taking as a typical subject to do the research, which has been exploited by cycle gas injection for 14 years. Three different methods are used to calculate the reserves, and the results show that the method proposed in this paper has minimum error of 2.96%.

Timing of advanced water flooding in low permeability reservoirs

It is very important to design the optimum starting time of water injection for the development of low permeability reservoirs. In this type of reservoir the starting time of water injection will be affected by a reservoir pressure-sensitive effect. In order to optimize the starting time of water injection in low permeability reservoirs, this effect of pressure change on rock permeability of low permeability reservoirs was, at first, studied by physical simulation. It was shown that the rock permeability decreases exponentially with an increase in formation pressure. Secondly, we conducted a reservoir engineering study, from which we obtained analytic relationships between formation pressure, oil production rate, water production rate and water injection rate. After our physical, theoretical and economical analyses, we proposed an approach which takes the pressure-sensitive effect into consideration and designed the optimum starting time of water injection, based on the principle of material balance. Finally, the corresponding software was developed and applied to one block of the Jiangsu Oilfield. It is shown that water injection, in advance of production, can decrease the adverse impact of the pressure-sensitive effect on low permeability reservoir development. A water-flooding project should be preferably initiated in advance of production for no more than one year and the optimum ratio of formation pressure to initial formation pressure should be maintained at a level between 1.05 and 1.2.

Study on Advanced Water Injection Time in Low Permeability Reservoir

A certain formation pressure level must be kept due to the threshold pressure of the low-permeability reser-voir during the seepage. Advanced water injection can keep the formation pressure at a higher level and keep a higher pressure gradient, which is an effective way to develop low-permeability reservoir. Based on the mechanism of advanced water injection and characteristic of porous flow in low permeability reservoir, a seepage model considering threshold pressure gradient is established to determine the formation pressure distribution at anytime as the water is injected at a constant speed. The optimum water injection time for the advanced water injection technology can be determined by using this model. The calculated result coincides basically with the numerical simulation result, which indicates that the model put forward in this paper is feasible.

TWO-PHASE FLOW FOR A HORIZONTAL WELL PENETRATING A NATURALLY FRACTURED RESERVOIR WITH EDGE WATER INJECTION

This paper examines the two-phase flow for a horizontal well penetrating a naturally fractured reservoir with edge water injection by means of a fixed streamlinemodel,The mathematical model of the verical two-dimensional flow or oil-water for a horizontal well in a medium with double-porosity is established ,and whose accuratesolutions are obtained by using the characteristic method .The saturation distributionsin the fractured system and the matrix system as well as the formula of the time of water free production are presented .All these results provide a theoretical basis and a computing method for oil displacement by edge water from naturally fracturedreservirs.

Investigation of the performance of a pilot-scale barrel atmospheric plasma system for plasma activation of polymer particles

This study reports the development and performance of a pilot-scale barrel atmospheric plasma reactor for the atmospheric plasma activation treatment of polymer particles. The polymer particles treated included acrylonitrile butadiene styrene(ABS) and polypropylene(PP). These particles had diameters in the range of 3–5 mm. The initial studies were carried out using a laboratory-scale barrel reactor designed to treat polymer particle batch sizes of 20 g. A pilot-scale reactor that could treat 500 g particle batch sizes was then developed to facilitate pre-industrial-scale treatments. The effect of operating pulse density modulation(PDM) in the range 10%–100% and plasma treatment time on the level of activation of the treated polymers were then investigated. ABS revealed a larger decrease in water contact angle compared with PP after plasma treatment under the same conditions. The optimal treatment time of ABS(400 g of polymer particles) in the pilot-scale reactor was 15 min. The plasma-activated polymer particles were used to fabricate dog-bone polymer parts through injection molding.Mechanical testing of the resulting dog-bone polymer parts revealed a 10.5% increase in tensile strength compared with those fabricated using non-activated polymer particles.

TWO－PHASE FLOW FOR A HORIZONTAL WELL PENETRATING A NATURALLY FRACTURED RESERVOIR WITH EDGE WATER INJECTION

ＴＷＯ－ＰＨＡＳＥＦＬＯＷＦＯＲＡＨＯＲＩＺＯＮＴＡＬＷＥＬＬＰＥＮＥＴＲＡＴＩＮＧＡＮＡＴＵＲＡＬＬＹＦＲＡＣＴＵＲＥＤＲＥＳＥＲＶＯＩＲＷＩＴＨＥＤＧＥＷＡＴＥＲＩＮＪＥＣＴＩＯＮＧｕｏＤａｌｉ（郭大立）ＬｉｕＣｉｑｕｎ（刘慈群）（Ｒｅｃｅｉｖｅ...

Application of Polymers in Low Permeability Formations

For low-permeability sandstone reservoir with big channel, we researched the novel deep profile method alternative injection of anionic and cationic polymer. Evaluating various factors on adsorption capacity through lab test, the results show that with the increase of temperature, the adsorption capacity decreases and the cationic polymer is easier to be absorbed. With the increase of salinity, adsorption time or polymer concentration, the adsorption capacity increases. The adsorption equilibrium concentration of cationic polymer is 1500 mg/L;adsorption equilibrium time is 8 h. The adsorption equilibrium concentration of anionic polymer is 1000 mg/L;adsorption equilibrium time is 6 h. Physical simulation experiment shows that alternative injection of anionic and cationic polymer is better than injection of single polymer, and preferential injection of cationic polymer is better than preferential injection of anionic polymer. With the increase of injection rounds, sealing capacity gets better, but in view of cost, the rounds should not be more than 3. The profile control technique can obviously enhanced oil recovery, and water displacement recovery increases 41%. 2 wells were tested successfully in Henan Oilfield in June 2010. Approximate 154.47 tons of incremental oil was obtained with 2% water-cut decrease.

大庆油田二类B油层聚驱剖面动用规律及其改善

大庆油田聚合物驱应用规模不断扩大,开发对象转向性质较差的二类B油层,现有聚合物与油层适应性不强,剖面动用规律不明确,不同地区聚驱开发效果差异较大。针对上述问题,应用矿场剖面数据统计和室内实验分析,研究了二类B油层剖面动用规律和剖面改善方法。结果表明:从吸水层动用情况来看,喇嘛甸地区由于发育厚层河道砂,油层物性好,油层有效厚度动用比例最高,油层以多次动用为主,突进层多,相对吸液量高;萨中和萨南地区河道砂发育规模小,薄砂层较多,物性差,有效厚度动用比例较低,但聚驱后,有效厚度动用比例相比水驱分别增大了12.5%和15.4%,渗透率为100~300 mD的储集层吸入剖面改善明显;从未吸水层动用来看,二类B油层纵向非均质性强,导致层间有效厚度未动用比例较高,剖面改善应以均衡层间动用为主;抗盐聚合物高、低质量浓度交替注入可延缓含水率上升时间,增加低渗透层吸液量,聚驱采出程度提高显著。在喇嘛甸北北块A区开展了DS1200抗盐聚合物和高、低质量浓度交替注入试验,降水增油效果好,可为大庆油田二类B油层聚驱剖面改善提供技术指导。

气体辅助注射成型时间参数的CCD响应面法多目标优化

相比于传统塑料注射成型,延迟时长和注气时长是气体辅助注射成型(简称气辅成型)特有的工艺参数,增加了气辅成型的复杂性。为了精确设计延迟时长和注气时长的取值,获得理想的气体穿透效果和气指幅度,以具有典型气辅结构的塑件为研究对象,首先采用气辅成型全三维CAE研究了延迟时长和注气时长对气辅成型质量的影响。结果表明,适当增加延迟时长,可以减小或消除气指缺陷,提高气体穿透深度行程,但过长的延迟时长会导致“短射”,过短的延迟时长则会导致严重的气指缺陷;增加注气时长可以提高气体穿透效果,减少表面缺陷,降低内应力和翘曲变形,但注气时长过长时,气指内部的高压氮气会导致其撕裂而形成严重的气指缺陷,更甚者会使气辅塑件膨胀而报废。采用CCD响应面法进行多目标优化,精确设计了延迟时长和注气时长的取值,延迟时长为4 s、注气时长为10.37 s。通过CAE分析和成型试验验证,精确取值下成型的气辅塑件的气体穿透效果和气辅成型质量良好,提高了气辅成型质量和效率,可用于气辅成型实际生产。

水侵气藏型储气库全周期高效建设微观模拟实验

借助微观可视化模型与微流控技术,开展了水侵气藏型储气库初期建库阶段注气驱水及循环储采阶段采气底水上侵、储气排驱水体的模拟实验,分析气液界面稳定机制、气液渗流与赋存规律,探索储气库全周期高效运行的优化调控方式。研究表明:储气库初期建库阶段应调控注气速度,充分发挥重力作用保证气液界面宏观稳定运移,大幅度提高气体的波及能力,为储气库后续循环储采阶段提供更大的储气孔隙空间。储气库循环储采阶段,恒定的储采气速度导致孔隙空间利用率低,逐渐提高储采气速度,从“小吞小吐”逐渐过渡到“大吞大吐”,可以持续打破孔喉内流体的平衡受力状态,扩大储气孔隙空间与流动通道,有利于储气库扩容增效和调峰保供。

高效液相色谱法测定室温下硝酸甘油注射液的存贮期限

目的高效液相色谱法测定硝酸甘油注射液在室温下的含量变化,预测硝酸甘油注射液在室温下的存贮期限。方法(1)HPLC法测定硝酸甘油注射液的含量。采用色谱柱(Kromasil C18),以甲醇:水(59:41)为流动相,流速1.0 ml·min^(-1),检测波长215 nm,柱温30℃;(2)采用加速试验和长期留样试验对硝酸甘油注射液的稳定性进行研究,经典恒温试验预测其在室温下的有效期。结果硝酸甘油注射液检测浓度在10μg·ml^(-1)-600μg·ml^(-1)范围内与峰面积呈良好的线性关系(R=0.9999),日内精密度、日间精密度、稳定性试验、重复性实验RSD均小于2%,含量测定平均值在99.99μg·ml^(-1)(标准值100μg·ml^(-1)),加样回收率RSD为1.67%。经典恒温试验测得硝酸甘油的含量变化符合一级反应规律,在25℃,硝酸甘油注射液的速率变化常数K_(25)=7.1395×10^(-4),有效贮存期限为147 d;在30℃时,K_(30)=9.4175×10^(-4),有效贮存期限为111 d。长期留样观察实验可以验证该实验的可靠性。结论高效液相色谱法检测方法简单、快速、精密度高,重复性好。硝酸甘油注射液在室温(25℃)下的存储期限约5个月,可以为临床管理抢救车药品提供参考依据。

油藏型储气库库容影响因素及其变化规律研究

针对目前中、低含水饱和度对自由气库容量影响的研究较少的问题,开展室内实验模拟了多次注气-焖井-采气实验,并根据相似原理,利用实验数据建立了自由气库容量与初始含水饱和度、注采次数的量化表征模型。结果表明,自由气库容量随注采次数的增多而增大,但单次注采后的增幅快速降低;含水饱和度(初始含水饱和大于50%)的提高有利于油藏改建储气库,但是建库初期的注采能力和库容提高相对缓慢;当初始含水饱和度由50%提高到85%时,经过6次注采后,含气饱和度降低幅度约9.27%,而当注采次数分别增至20、30、50时,自由气库容量增加幅度分别为0.51%、3.34%、6.61%。研究结果可为油藏型储气库的注采能力及库容评价提供借鉴。

ITER气体加料仪控设计和系统验证

基于ITER气体加料的功能需求,及面临ITER超长注入管线、强磁场、高辐照及涉氚的特殊运行工况,并遵循ITER仪控系统的设计框架,完成了气体加料运行控制系统的设计和仪控器件改进。并依据GIS终期设计方案构建试验平台,对系统气体加料特性进行试验研究。获得了系统响应时间等关键技术指标,同时验证了预过充策略对长管道气体输运响应时间的优化,以及采用载气模式实现快速杂质气体注入的有效性。

薄板式静态混合器混合性能数值模拟

薄板式静态混合器内构件简单、通量高、压降低,可以有效降低稀释水掺混能耗。文中以不均匀系数ψ和管路压降Δp作为评价指标,利用CFD(计算流体动力学),对比分析单直管、单顺流羽状管、单逆流羽状管和双顺流羽状管等4种注水方式的混合效果和压降。研究发现,在注水管安装在L/D=5.3处,单管注入时,注水两侧形成的径向二次流强度Se变化缓慢,稳定的涡旋流在混合器内产生混合“死区”,降低了静态混合器的油水混合速度;当ψ降至0.05时,混合距离超过18D。此混合死区解释了单管注入时分散相注入点附近易出现局部高浓度区。双顺流羽状管注入时,对撞水相产生较高径向二次流强度Se,且迅速降低。快速变化的流场显著减少混合距离,与单管注入相比,ψ降至0.05时混合距离减少76.9%,Δp增加1.5%。

水/蒸汽喷射时刻对汽油机燃烧和排放影响研究

通过由试验验证的型号为LJ465Q汽油发动机热力学模型,研究了缸内水和蒸汽喷射时刻对发动机性能和排放的影响规律。结果表明,在发动机2000r/min及全负荷下,喷射质量为9mg,喷射压力为10bar,喷射时刻为(-110~-60)°CA时,水喷射工况输出功率随着喷射时刻滞后逐渐减小,功率最大可提高0.71%,燃油消耗率可降低0.74%,喷水后减少了局部高温和局部过浓区域,有助于明显降低NOx排放,其最大降低了66.3%,HC排放有所增加;过热蒸汽喷射工况输出功率随着喷射时刻滞后逐渐增大,功率最大可提高1.7%,燃油消耗率可降低1.8%,NOx排放量随喷射时刻增大而减少,最大降低了55.2%,HC排放降低了15.4%。综上,缸内蒸汽喷射相比于水对发动机性能和排放的影响效果具有一定优势。