最小二乘法在聚合物有效物含量评价方法研究中的应用

为了彻底排除各种无机盐杂质的影响,真实地评价聚合物产品的有效成分含量,研究了醇酸共洗法测试钻井液用聚合物类降滤失剂有效物的可行性。该方法不但可有效地去除样品中的残留碱、水溶性无机盐类,同时还可以有效地去除样品中的酸溶性无机盐(如碳酸盐等)。在进行实验数据处理时,考虑标准碳酸钙的加入量与样品有效物含量测试结果间有较明显的线性关系,运用最小二乘法及加标回测外推法等统计学工具,最大限度地降低了测试结果的不确定度,提高了方法的准确度与可靠性,形成了较完善的钻井液用聚合物类降滤失剂产品有效物含量的评价方法。目前该方法已成功地应用于Q/SHCG 35-201《2钻井液用合成聚合物降滤失剂技术要求》等多个石化行业一级企业技术标准。     

新型超支化大分子季铵型抑制剂的制备及性能评价

以二乙醇胺、丁二酸酐为原料,合成端羟基超支化大分子；用环氧丙基三甲基氯化铵进行末端基团改性，引入季铵盐阳离子基团制备了一种新型季铵盐抑制剂HBP-TAC，其结构经红外光谱、核磁和元素分析表征。考察了端基取代度与浓度对抑制膨润土水化膨胀性能影响，并对滚动回收率及与钻井液配伍性进行了评价、实验结果表明：该类抑制剂对膨润土的水化膨胀有一定抑制作用，加入1%多取代HBP-T2，抑制效果能达到95.31%；在高温130℃条件下，页岩滚动回收的一次回收率为91.8%，二次回收率为80.1%；抑制剂与水基钻井液体系相容性较好，并对滤失性有一定改善效果。      

磁场特性与作用方式对HCFC-141b气体水合物生成过程的影响

通过实验研究考察了静态磁场和旋转磁场下磁场特性与作用方式对低压制冷剂HCFC-141b气体水合物生成过程特性影响, 重点研究在不同磁场条件下的气体水合物结晶形态、生成温度和引导时间三个重要因素. 试验结果发现, 适当的旋转磁场对提高水合物生成温度、降低过冷度、减少引导时间、提高生成速度有显著的作用, 使结晶形态混杂致密; 而适当的静态磁场则使水合物形态规整, 有利于提高传热性能.     

新型两亲性聚酰胺的合成及性质

为了设计天然气水合物抑制剂和了解作用机理提供依据,分析两亲性聚酰胺与水相互作用的特征与本质,本文合成了新型水溶性高分子聚柠檬酰丙二胺,在此基础上合成了一种含环己基基团的两亲性聚柠檬酰丙二胺。通过核磁共振波谱、凝胶渗透色谱和示差扫描量热法对产物的结构和性能进行了表征。研究表明,改性的聚柠檬酰胺能形成不可冰冻束缚水,而且比传统的天然气水合物抑制剂聚(N-乙烯基己内酰胺)和聚维酮形成的不可冰冻束缚水多1倍。改性后聚合物中水的比热容增加约36%。聚合物和水之间产生的疏水相互作用,可将水分子更紧密地束缚在聚合物中。改性后的聚合物的疏水性强,造成了水分子彼此紧密束缚程度提高,为不可冰冻束缚水含量的增加提供了必要的环境。     

天然气水合物研究进展

本文介绍了天然气水合物研究的历史和现状, 天然气水合物的结构, 它在冻土地带和海洋底部地表层的形成过程, 它对石油天然气工业的影响以及抑制生成天然气水合物的方法。介绍了天然气水合物作为潜在能源的巨大优势以及它对地球气候变化--温室效应的潜在危险性。     

天然气水合物合成与分解模拟实验研究与设计

针对大学化学中有关天然气水合物的内容,设计了天然气水合物的教学实验和模拟实验装置,实现了天然气水合物在不同实验条件下的合成与分解等多个实验。仪器操作简单,实验可重复性高,可通过多种方式判断水合物是否生成或分解。     

新型双亲性水基钻井液页岩抑制剂的合成及应用

针对河南油田泌阳泥页岩井段钻井施工过程中, 因频繁出现水化膨胀而导致井壁失稳、剥落掉块等问题,本文以月桂酰氯改性超支化聚乙烯亚胺(HPEI)为原料,于室内合成了一种新型的双亲性页岩抑制剂(HPEI-C₁₂ ),并对其合成条件和页岩水化抑制性能进行了评价。结果表明:在引发剂N,N-二乙基乙胺加量(质量分数,下同)为8%、月桂酰氯加量为30%、反应时间为24 h和反应温度为25 ℃条件下合成的HPEI-C₁₂性能最佳;通过线性膨胀实验和岩屑滚动回收实验对HPEI-C₁₂抑制性能进行评价结果表明:HPEI-C₁₂具备优异的抑制性能和耐温性能,在120 ℃条件下,岩屑滚动回收率为65.0%;此外,HPEI-C₁₂与现场钻井液体系具备良好的适配性,对体系流变性能影响极小,加入体系后岩屑滚动回收率提升至82.0%,能够满足目标井段对钻井液性能的要求。     

应用废弃果皮制备绿色钻井液添加剂的综合性实验

设计了应用废弃果皮制备绿色钻井液添加剂的综合性实验,评价其对钻井液性能的影响.该实验将油田化学理论基础与实验技术、现场实践相结合,能够提高学生的专业实验技能、分析和解决问题的能力,同时采用废弃果皮作为实验原料,可提高学生的环保意识,有助于将环保理念注入日后油田生产中.     

基于量子化学计算方法的天然气水合物稳定性研究进展

天然气水合物以资源丰富、优质、洁净等特点,被视为21世纪新能源。天然气水合物稳定性的研究对天然气水合物资源勘探开发具有重要意义。本文简述了微观、介观、宏观、矿藏四个尺度天然气水合物稳定性的研究,重点从微观量子尺度介绍了量子化学计算方法对水合物晶体结构及其稳定性以及水合物宏观物理特性微观表征的计算研究。应用量子化学计算方法可以对天然气水合物的晶体结构、电子轨道分布、振动光谱、成键特性及主客体相互作用进行计算研究,其结果能够为天然气水合物在油气储运、水合物成藏、开采及其综合利用等方面的研究提供理论支持。目前,量子化学计算方法的优化与分子动力学模拟、分子力学模拟等方法的结合将有助于水合物形成和分解微观机理研究的发展,提升计算精度和扩大研究体系,为矿场尺度的天然气水合物资源开采利用提供理论支持。     

天然气水合物抑制剂的分子动力学研究进展

大力开发深海天然气资源是发展清洁能源的一种重要手段,但是天然气水合物的形成会给开采作业带来严重的挑战,水合物动力学抑制剂是一类可以解决深海开采技术问题的高分子化合物。分子动力学(MD)模拟对于研究水合物抑制剂具有很好的理论指导作用,文中综述了近年来利用MD评判抑制剂性能,分析可能发生的抑制方式和机理,研究影响抑制剂效果的因素及开发新型抑制剂的方法,并对今后MD模拟在天然气水合物抑制剂领域的发展方向进行展望。     

Comparison and application of different empirical correlations for estimating the hydrate safety margin of oil-based drilling fluids containing ethylene glycol

As the oil and gas industries continue to increase their activity in deep water, gas hydrate hazards will become more serious and challenging, both at present and in the future. Accurate predictions of the hydrate-free zone and the suitable addition of salts and/or alcohols in preparing drilling fluids are particularly important both in preventing hydrate problems and decreasing the cost of drilling operations. In this paper, we compared several empirical correlations commonly used to estimate the hydrate inhibition effect of aqueous organic and electrolyte solutions using experiments with ethylene glycol (EG) as a hydrate inhibitor. The results show that the Najibi et al. correlation (for single and mixed thermodynamic inhibitors) and the Ostergaard et al. empirical correlation (for single thermodynamic inhibitors) are suitable for estimating the hydrate safety margin of oil-based drilling fluids (OBDFs) in the presence of thermodynamic hydrate inhibitors. According to the two correlations, the OBDF, composed of 1.6 L vaporizing oil, 2% emulsifying agent, 1% organobentonite, 0.5% SP-1, 1% LP-1, 10% water and 40% EG, can be safely used at a water depth of up to 1900 m. However, for more accurate predictions for drilling fluids, the effects of the solid phase, especially bentonite, on hydrate inhibition need to be considered and included in the application of these two empirical correlations.     

Gas-hydrate formation, agglomeration and inhibition in oil-based drilling fluids for deep-water drilling

One of the main challenges in deep-water drilling is gas-hydrate plugs, which make the drilling unsafe. Some oil-based drilling fluids (OBDF) that would be used for deep-water drilling in the South China Sea were tested to investigate the characteristics of gas-hydrate formation, agglomeration and inhibition by an experimental system under the temperature of 4 ℃ and pressure of 20 MPa, which would be similar to the case of 2000 m water depth. The results validate the hydrate shell formation model and show that the water cut can greatly influence hydrate formation and agglomeration behaviors in the OBDF. The oleophobic effect enhanced by hydrate shell formation which weakens or destroys the interfacial films effect and the hydrophilic effect are the dominant agglomeration mechanism of hydrate particles. The formation of gas hydrates in OBDF is easier and quicker than in water-based drilling fluids in deep-water conditions of low temperature and high pressure because the former is a W/O dispersive emulsion which means much more gas-water interfaces and nucleation sites than the later. Higher ethylene glycol concentrations can inhibit the formation of gas hydrates and to some extent also act as an anti-agglomerant to inhibit hydrates agglomeration in the OBDF.     

Gas-hydrate formation,agglomeration and inhibition in oil-based drilling fluids for deep-water drilling

One of the main challenges in deep-water drilling is gas-hydrate plugs,which make the drilling unsafe.Some oil-based drilling fluids(OBDF) that would be used for deep-water drilling in the South China Sea were tested to investigate the characteristics of gas-hydrate formation,agglomeration and inhibition by an experimental system under the temperature of 4 ?C and pressure of 20 MPa,which would be similar to the case of 2000 m water depth.The results validate the hydrate shell formation model and show that the water cut can greatly influence hydrate formation and agglomeration behaviors in the OBDF.The oleophobic effect enhanced by hydrate shell formation which weakens or destroys the interfacial films effect and the hydrophilic effect are the dominant agglomeration mechanism of hydrate particles.The formation of gas hydrates in OBDF is easier and quicker than in water-based drilling fluids in deep-water conditions of low temperature and high pressure because the former is a W/O dispersive emulsion which means much more gas-water interfaces and nucleation sites than the later.Higher ethylene glycol concentrations can inhibit the formation of gas hydrates and to some extent also act as an anti-agglomerant to inhibit hydrates agglomeration in the OBDF.     

Predicting hydrate stability zones of petroleum fluids using sound velocity data of salt aqueous solutions

Predicting hydrate stability zones of petroleum fluids from the aqueous phase properties can have a practical application as measuring these properties is normally easier than hydrate phase equilibrium measurement and can reduce experimental costs and efforts. In this work, the possibility of estimating hydrate stability zone from sound velocity data of salt aqueous solutions is investigated using a feed-forward artificial neural network method with a modified Levenberg–Marquardt algorithm. The method considers the changes of sound velocity in salt (NaCl, KCl, NaBr, KBr, BaCl₂, MgCl₂, Na₂SO₄, HCOONa) aqueous solution with respect to sound velocity in pure water and therefore there is no need to have a quantitative analysis of the aqueous solution. Independent data (not used in training and developing of the method) are used to examine the reliability of this tool. The predictions of this method are in acceptable agreement with independent experimental data, demonstrating the reliability of this tool for estimating the hydrate stability zone in the presence of salt aqueous solutions.     

Clathrate hydrate equilibria in mixed monoethylene glycol and electrolyte aqueous solutions

Monoethylene glycol (MEG) is commonly added in the formulation of hydraulic and drilling fluids and injected into pipelines to prevent the formation of gas hydrates. It is therefore necessary to establish the effect of a combination of salts and thermodynamic inhibitors on gas hydrate equilibria.In this communication, water activity of five ternary solutions (MEG–H₂O–NaCl, MEG–H₂O–CaCl₂, MEG–H₂O–MgCl₂, MEG–H₂O–KCl and MEG–H₂O–NaBr) and four multicomponent solutions have been measured by a reliable resistive electrolytic humidity sensor. We also report new experimental measurements of the locus of incipient hydrate-liquid water–vapour curve for systems containing methane or natural gas with aqueous solution of ethylene glycol and NaCl over a wide range of concentrations, pressures and temperatures.A thermodynamic approach in which the Cubic-Plus-Association equation of state is combined with a modified Debye Hückel electrostatic term is employed to model the phase equilibria. These new data have been used to optimise binary interaction parameters between salts and MEG implemented in the modified Debye Hückel electrostatic term. The model developed has been evaluated using the new generated hydrate data and literature data. Good agreement between predictions of the modified model and experimental data is observed, supporting the reliability of the developed model.     

Characterisation of gas hydrates formation using a new high pressure Micro-DSC

Gas hydrates are solid structures formed from water and gas under low temperature and high pressure conditions. Differential scanning calorimeter, operating under high pressure, is a very useful technique for the determination of the thermodynamic properties and the kinetics of gas hydrate formation. Specific gas tight controlled pressure vessels have to be used to obtain the hydrate formation in complex fluids. Based on the MicroDSC technology, a new High Pressure MicroDSC with a vessel (0.7 cm³) operating up to 400 bars between -45 and 120°C is introduced for this type of research. An example of the use of the HP MicroDSC is given with the formation of gas hydrates in drilling muds. With the increasing number of deep offshore drilling operations, operators and service companies have to solve more and more complex technical challenges. Extreme conditions encountered at these depths require an adaptation of the drilling muds. The range of temperature (down to -1°C) and pressure (up to 400 bars) are favorable conditions to the formation of hydrates. HP MicroDSC is used to determine the thermodynamic properties and kinetics of hydrate formation in mud formulations, particularly in the presence of large amounts of minerals. The technique allows the detection of phase transitions vs. time, temperature and pressure. Using such a technique, dangerous areas of hydrate formation in drilling muds formulations (water-base and oil-base) can be predicted. This revised version was published online in July 2006 with corrections to the Cover Date.     

Intensification of methane and hydrogen storage in clathrate hydrate and future prospect

Gas hydrate is a new technology for energy gas (methane/hydrogen) storage due to its large capacity of gas storage and safe. But industrial application of hydrate storage process was hindered by some problems. For methane, the main problems are low formation rate and storage capacity, which can be solved by strengthening mass and heat transfer, such as adding additives, stirring, bubbling, etc. One kind of additives can change the equilibrium curve to reduce the formation pressure of methane hydrate, and the other kind of additives is surfactant, which can form micelle with water and increase the interface of water-gas. Dry water has the similar effects on the methane hydrate as surfactant. Additionally, stirring, bubbling, and spraying can increase formation rate and storage capacity due to mass transfer strengthened. Inserting internal or external heat exchange also can improve formation rate because of good heat transfer. For hydrogen, the main difficulties are very high pressure for hydrate formed. Tetrahydrofuran (THF), tetrabutylammonium bromide (TBAB) and tetrabutylammonium fluoride (TBAF) have been proved to be able to decrease the hydrogen hydrate formation pressure significantly.     

Effect of Electrolytes and Polymers on the Thixotropy of Mg‐Al‐Layered Double Hydroxides/Kaolinite Dispersions

The effect of electrolytes (NaCl and CaCl₂) and polymers (CPAM and HPAM) on the thixotropy of Mg‐Al‐layered double hydroxide (LDHs)/kaolinite dispersions has been investigated. It was observed that the type of thixotropy in LDH/kaolinite dispersions may be affected by NaCl, but not by CaCl₂ in range of concentration of interest. The type of thixotropy in LDH/kaolinite dispersion with R=0 transformed from positive thixotropy to complex thixotropy and at last positive thixotropy again with the concentration of NaCl in range of 0.00–0.10 mol·L⁻¹; the type of thixotropy in LDHs/kaolinite dispersions with R=0.25 transformed from complex thixotropy to positive thixotropy and then complex thixotropy again with the concentration of NaCl in range of 0.00–0.10 mol·L⁻¹. The type of thixotropy in LDH/kaolinite dispersion with R=0 may be not affected by cationic polyacrylamide (CPAM) and hydrolyzed polyacrylamide (HPAM); but the LDHs/kaolinite dispersions with R=0.25 transformed from complex thixotropy to positive thixotropy with the both polymers concentration in range of interest, which indicated that the microstructure of the dispersion changed from weak folc sediments structure to steric network structure.     

Gas hydrate phase equilibria for propane in the presence of additive components

A proper discussion on the possibility and feasibility of technological applications for gas hydrates requires knowledge of the phase behaviour and its relation to the gas hydrate structure and its occupation. This paper presents experimental data on gas hydrate phase equilibria for the system water+propane and for various systems of the kind water+propane+additive. The additives considered are tetrahydropyran, cyclobutanone and cyclohexane, which are assumed to occupy the large cavity of structure II (sII) hydrate, and methylcyclohexane that is a typical structure H (sH) hydrate former. All additives have in common that they are very poorly soluble in water and, therefore, an additional liquid phase is present in these systems. The pressure for the equilibrium hydrate–liquid water–vapour (H–L_w–V) in the system water+propane is reduced upon addition of each of these components. Simultaneously, the hydrate equilibrium hydrate–liquid water–liquid propane (H–L_w–L_C3H8) is shifted to lower temperatures. These observations can be explained in terms of mutual miscibility of propane and the additive component. However, it cannot be excluded that propane molecules are exchanged by additive molecules in occupying the large cavity of sII.     

Intensification of methane and hydrogen storage inclathrate hydrate and future prospect

Gas hydrate is a new technology for energy gas(methane/hydrogen)storage due to its large capacity of gas storage and safe.But industrial application of hydrate storage process was hindered by someproblems.For methane,the main problems are low formation rateand storage capacity,which can be solved by strengthening mass andheat transfer,such as adding additives,stirring,bubbling,etc.Onekind of additives can change the equilibrium curve to reduce the formation pressure of methane hydrate,and the other kind of additivesis surfactant,which can form micelle with water and increase the interface of water-gas.Dry water has the similar effects on the methanehydrate as surfactant.Additionally,stirring,bubbling,and sprayingcan increase formation rate and storage capacity due to mass transferstrengthened.Inserting internal or external heat exchange also canimprove formation rate because of good heat transfer.For hydrogen,the main difficulties are very high pressure for hydrate formed.Tetrahydrofuran(THF),tetrabutylammonium bromide(TBAB) andtetrabutylammonium fluoride(TBAF) have been proved to be able todecrease the hydrogen hydrate formation pressure significantly.