激光对生产β-胡萝卜素的藻种——盐生杜氏藻(Dunaliella salina)诱变的研究

用激光(335nm,0.014MW/mm~2)对产生6-胡萝卜素的盐生杜氏藻(Dunaliella Salina)进行了诱变研究,藻的存活率为90％。诱导后筛选到三个盐生杜氏藻的品系。生长速度较原藻最高增加20％,长度增加7.5％,萨-胡萝卜素生产能力为0.48mg·100ml~(-1)天~-1),比原藻增加19％。     

核泵浦~3He-Ne激光增益实验

在稳态核反应堆上,测定了热中子辐照下,~3He-Ne激光体系(P_(He:P_(Ne)=5:1,P_总=4×10~4Pa)的增益系数(丸=632.8nm,跃迁3S_2-2P_4)。当热中子通量为2×10~(12)n/cm~2·时,其增益系数为1.7×10~(-2)/cm。研究了增益系数随热中子通量的变化关系,讨论了温度对增益的影响。实验表明核泵浦~3He-Ne体系有可能实现激射。     

准连续Ti~(3+):Al_2O_3可调谐激光的研究

本文给出了Ti~(3+):Al_2O_3的准连续可调谐激光的实验结果。采用Nd:YAG内腔倍频532nm的准连续输出作为泵浦源,得到Ti~(3+):Al_2O_3的连续可调谐输出。波长覆盖范围为685nm到821nm。最大输出功率为293mW,斜率效率为20％,在805nm处的窄谱输出功率达240mW,总体转换效举为26％。     

单晶硅化物及其应用

本文评述了单晶CoSi_2和NiSi_2的结构特点、各种制备方法、器件应用和发展前景。采用分子束外延(MBE)和“内延”法(Mesotaxy)制备的单晶硅化物质量,电学性能和热稳定性较好。由于首次得到理想的突变的金属——半导体接触,使对金属——半导体接触的理论分析成为可能。硅/单晶硅化物/硅结构在实际应用中非常重要,如单晶硅化物作集电极埋层,能降低集电极串联电阻,克服重掺杂埋层的横扩和自掺杂问题,提高了电路工作速度,减小了器件面积。埋层硅化物也可作为微波传输线的地线,是实现高频集成电路互连的好方法。而采用该结构制备的高速器件——金属基区晶体管(MBT)和穿透基区晶体管(PBT),具有很好的应用前景。     

复杂三维走向三铰链管路补偿工况下的补偿器角位移研究

为了适应复杂的边界条件,新一代液体运载火箭管路系统中通常使用三铰链管路作为补偿导管.由于三铰链管路的补偿能力取决于铰链补偿器的变形能力,因此在管路设计时需要对给定补偿工况下各补偿器的变形情况进行评估,确保各铰链补偿器的角位移值均在设计允许范围之内.以某型号三铰链增压管为例,分别采用理论计算、有限元仿真以及试验测量3种方...     

克劳斯装置中温有机硫水解催化剂研究

针对硫磺回收装置克劳斯二级反应器有机硫水解率较低的问题,采用新型共浸技术研发了中温有机硫水解催化剂。考察了催化剂的耐硫性能及温度对催化剂性能的影响。实验结果表明,在220~300℃的温度范围内,催化剂表现出较高的有机硫水解性能;且在H_2S、SO_2、CS_2体积分数变化的范围内,均优于现阶段二级反应器中装填的活性氧化铝催化剂。     

强水敏低渗油藏酸化防膨研究及现场应用

针对石西油田低渗油藏强水敏性伤害储层,油井转注水初期,普遍存在注入压力高、注不进的实际问题,基于黏土矿物的防膨原理和现场防膨经验,为了提高XH-F3防膨剂的防膨效果,采用乙醇与注入水混配,其防膨率得到显著提高,满足了油田指标要求。静态实验结果表明,采用该防膨技术,岩心破碎率低、腐蚀率低,配伍性好。现场实验表明,注入该防膨型醇水配制的酸液,酸化后注入压力大大下降,注水量增加3~5倍,达到了防止黏土矿物膨胀、实现近井地带酸化解堵的目的。     

Biomarker geochemistry of Eq34-10 cyclothem shale in Qianjiang Depression of the Jianghan salt lake facies Basin

The objective of this study is to provide biomarker geochemistry information on shale between sheet-like salts from Qianjiang Depression of the Jianghan salt lake facies Basin, and illustrate the depositional conditions, source organic matter input and maturation. 7 shale samples from Eq3⁴-10 rhythmic were analysed with gas chromatography-mass spectrometry. The investigated biomarkers show that the shale oil are charactertized by an apperent odd-even preference of n-alkane, low Pr/Ph values and a high content of gammacerane and C₃₀+ hopanes, maderate C_21-/C₂₁₊ ratios, the high relative content of C₂₇ 5α(H), 14α(H), 17α(H)- steranes (20R), and an anomaly high C₂₉ sterane ββ/(ββ + αα) value. These biomarker geochemistry characterizations suggested that the shale oils were derived from mixed aquatic organisms and land plants, and deposited in an anoxic and saline-hypersaline depositional environment.     

Influence of pressure and CO2 content on the asphaltene precipitation and oil recovery during CO2 flooding

During CO₂ flooding, the crude oil is treated with CO₂, and meanwhile it is displaced by CO₂. Based on the two processes, the influence of pressure and CO₂ content on the asphaltene precipitation and oil recovery efficiency are systematically investigated by indoor simulation experiment. With the increase of the pressure or CO₂ content during CO₂ treatment, the amount of asphaltene precipitation can be increased to a certain value. Correspondingly, the degrees of the changes of oil-water interface, the compositions of crude oil, and reservoir permeability are positively correlated with the amount of asphaltene precipitation. However, during the process, the oil recovery has an optimal value due to the combined action of asphaltene precipitation and the improvement of flow performance of the crude oil. These conclusions can provide a basis for high efficiency development of low permeability oil reservoirs by CO₂ flooding.     

A numerical simulation study of CO 2 injection for enhancing hydrocarbon recovery and sequestration in liquid-rich shales

Less than 10% of oil is usually recovered from liquid-rich shales and this leaves much room for improvement, while water injection into shale formation is virtually impossible because of the extremely low permeability of the formation matrix. Injecting carbon dioxide (CO₂) into oil shale formations can potentially improve oil recovery. Furthermore, the large surface area in organicrich shale could permanently store CO₂ without jeopardizing the formation integrity. This work is a mechanism study of evaluating the effectiveness of CO₂-enhanced oil shale recovery and shale formation CO₂ sequestration capacity using numerical simulation. Petrophysical and fluid properties similar to the Bakken Formation are used to set up the base model for simulation. Result shows that the CO₂ injection could increase the oil recovery factor from 7.4% to 53%. In addition, petrophysical characteristics such as in situ stress changes and presence of a natural fracture network in the shale formation are proven to have impacts on subsurface CO₂ flow. A response surface modeling approach was applied to investigate the interaction between parameters and generate a proxy model for optimizing oil recovery and CO₂ injectivity.