Microstructural characteristics of the Whitby Mudstone Formation (UK)

When trying to improve gas productivity from unconventional sources a first aim is to understand gas storage and gas flow potential through the rock by investigating the microstructure, mineralogy and matrix porosity of unfractured shale. The porosity and mineralogy of the Mulgrave Shale member of the Whitby Mudstone Formation (UK) were characterized using a combination of microscopy, X-ray diffraction and gas adsorption methods on samples collected from outcrops. The Whitby Mudstone is an analogue for the Dutch Posidonia Shale which is a possible unconventional source for gas. The Mulgrave shale member of the Whitby Mudstone Formation can microstructurally be subdivided into a fossil rich (>15%) upper half and a sub-mm mineralogically laminated lower half. All clasts are embedded within a fine-grained matrix (all grains < 2 μm) implying that any possible flow of gas will depend on the porosity and the pore network present within this matrix. The visible SEM porosity (pore diameter > 100 nm) is in the order of 0.5–2.5% and shows a non-connected pore network in 2D. Gas adsorption (N2, Ar, He) porosity (pore diameters down to 2 nm) has been measured to be 0.3–7%. Overall more than 40% of the visible porosity is present within the matrix. Comparing the Whitby Mudstone Formation to other (producing) gas shales shows that the rock plots in the low porosity and high clay mineral content range, which could imply that Whitby Mudstone shales could be less favourable to mechanical fracturing than other gas shales. Estimated permeability indicates values in the micro-to nano-darcy range.     

Investigation of gas content of organic-rich shale:A case study from Lower Permian shale in southern North China Basin,central China

Measuring gas content is an essential step in estimating the commerciality of gas reserves. In this study,eight shale core samples from the Mouye-1 well were measured using a homemade patented gas desorption apparatus to determine their gas contents. Due to the air contamination that is introduced into the desorption canister, a mathematical method was devised to correct the gas quantity and quality.Compared to the chemical compositions of desorbed gas, the chemical compositions of residual gas are somewhat different. In residual gas, carbon dioxide and nitrogen record a slight increase, and propane is first observed. This phenomenon may be related to the exposure time during the transportation of shale samples from the drilling site to the laboratory, as well as the differences in the mass, size and adsorptivity of different gas molecules. In addition to a series of conventional methods, including the USBM direct method and the Amoco Curve Fit(ACF) method, which were used here for lost gas content estimation, a Modified Curve Fit(MCF) method, based on the 'bidisperse' diffusion model, was established to estimate lost gas content. By fitting the ACF and MCF models to gas desorption data, we determined that the MCF method could reasonably describe the gas desorption data over the entire time period, whereas the ACF method failed. The failure of the ACF method to describe the gas desorption process may be related to its restrictive assumption of a single pore size within shale samples. In comparison to the indirect method, this study demonstrates that none of the three methods studied in this investigation(USBM, ACF and MCF) could individually estimate the lost gas contents of all shale samples and that the proportion of free gas relative to total gas has a significant effect on the estimation accuracy of the selected method. When the ratio of free gas to total gas is lower than 45%, the USBM method is the best for estimating the lost gas content, whereas when the ratio ranges from 45% to 75% or is more than 75%, the ACF and MCF methods, are the best options respectively.     

Multi-factor sensitivity analysis on the stability of submarine hydrate-bearing slope

There are many factors affecting the instability of the submarine hydrate-bearing slope (SHBS), and the interaction with hydrate is very complicated. In this paper, the mechanical mechanism of the static liquefaction and instability of submarine slope caused by the dissociation of natural gas hydrate (NGH) resulting in the rapid increase of pore pressure of gas hydrate-bearing sediments (GHBS) and the decrease of effective stress are analyzed based on the time series and type of SHBS. Then, taking the typical submarine slope in the northern South China Sea as an example, four important factors affecting the stability of SHBS are selected, such as the degree of hydrate dissociation, the depth of hydrate burial, the thickness of hydrate, and the depth of seawater. According to the principle of orthogonal method, 25 orthogonal test schemes with 4 factors and 5 levels are designed and the safety factors of submarine slope stability of each scheme are calculated by using the strength reduction finite element method. By means of the orthogonal design range analysis and the variance analysis, sensitivity of influential factors on stability of SHBS are obtained. The results show that the degree of hydrate dissociation is the most sensitive, followed by hydrate burial depth, the thickness of hydrate and the depth of seawater. Finally, the concept of gas hydrate critical burial depth is put forward according to the influence law of gas hydrate burial depth, and the numerical simulation for specific submarine slope is carried out, which indicates the existence of critical burial depth.     

川东南丁山地区龙马溪组页岩裂缝特征及对含气性的影响

川东南丁山地区是近年来四川盆地页岩气勘探开发的热点区域,裂缝的发育对页岩含气性及保存条件有重要的影响。综合运用野外露头、岩心、测井资料,结合岩石脆性矿物含量、岩石力学参数等数据,深入分析龙马溪组页岩裂缝发育特征和控制因素,并探讨了裂缝发育对含气性的影响。结果表明,丁山地区龙马溪组页岩裂缝主要以构造成因的剪切缝为主,裂缝优势方位共6组,主要包括4组平面剪切缝和2组剖面剪切缝,其发育主要受2个方向、3个阶段的构造应力场影响而成;裂缝延伸稳定,平均密度小,宽度小,充填程度高,主要被方解石和黄铁矿等充填。裂缝受控因素主要包括古构造应力场、构造部位、脆性矿物组分、岩石力学性质等;断层对裂缝发育具有明显的控制作用,其中断层两盘均存在裂缝发育程度急剧下降的临界范围,临界范围内裂缝发育程度高,超过此临界范围,裂缝发育程度变差且变化趋于平缓;不同期次的裂缝中,形成时间晚、规模过大、充填程度不高、与现今地应力方向一致或呈低角度相交的裂缝易造成页岩气的散失,对提高页岩含气性不利;龙马溪组岩石脆性矿物含量高,脆性指数属中等偏上程度,有利于构造缝发育且可压性较好。随着距齐岳山断裂距离的适当增加,龙马溪组页岩埋藏深度适中,地层压力增大,抗压强度增强高,脆性指数适中,构造保存条件变好,有利于不同方位的裂缝发育和页岩含气量的增加,位于该区域的DY2井与DY4井均位于该有利区域,含气性良好。研究结果对下一步深化页岩气勘探开发具有重要指导作用。     

川东北普光地区深层富钾卤水钾资源提取研究

四川盆地地下卤水资源丰富,尤其川东北地区地下卤水富含高品质钾资源。本项目以四川普光地区富钾卤水为研究对象,根据卤水组成,采用模拟计算并结合实验验证的方法,研究了高温蒸发时,氯化钠、氯化钾、光卤石、硼酸等矿物的析出阶段及特点。研究结果表明,当蒸失水率约80%时,体系中约85%的NaCl析出,同时KCl达到饱和,继续蒸发可获取钾石盐。控制总蒸失水率94%~95%时分离,体系中大于80%的钾可在这一阶段析出,且湿基中KCl品位可高达约45%;析出钾石盐后的卤水降至室温可获得NaCl、KCl、KCl·MgCl₂·6H₂O及H₃BO₃的混合物,硼的析出率可达到约80%。同时,研究表明,将蒸失水率约80%时分离石盐后的卤水直接降温可以获得湿基品位约高达70%的钾石盐矿,钾析出率约50%。综合对比分析,提出两条以钾资源开发为主的工艺路线:其一为“高温蒸发析氯化钠-高温蒸发析氯化钾-冷却析钾硼混盐”,通过加工获得KCl及H₃BO₃产品;其二为“高温蒸发析氯化钠-冷却析钾”,通过加工获得高端KCl产品。     

地磁匹配特征量的选择

论文旨在选择合适的地磁特征量用于匹配制导.从地磁匹配的实际要求出发,提出了选择匹配特征量时应重点考虑的几个因素,通过理论分析初步拟定了选取准则,并针对特定区域,依据IGRF(International Geomagnetic Reference Field)和WMM(World Magnetic Model)计算出的地磁数据,结合选取准则进行了综合分析,给出了初选结果,对地磁匹配基准图的制备、实时图的获取、匹配算法的研究,以及地磁场资源应用于其他领域的相关研究有一定的借鉴意义.     

Effective medium modeling to assess gas hydrate and free-gas evident from the velocity structure in the Makran accretionary prism, offshore Pakistan

Seismic properties of sediments are strongly influenced by pore fluids. Stiffness of unconsolidated marine sediment increases with the presence of gas hydrate and decreases with the presence of gas. A strong bottom-simulating reflector (BSR) observed on a seismic profile in the Makran accretionary prism, offshore Pakistan, indicates the presence of gas hydrate and free-gas across the BSR. Elastic properties of gas depend largely on pressure and temperature. We, therefore, first determine the elastic modulus of gas at pressure and temperature calculated at the BSR depth in the study region. The interval velocities derived from the seismic data are interpreted by the effective medium theory, which is a combination of self-consistent approximation and differential effective medium theories, together with a smoothing approximation, for assessment of gas hydrate and free-gas. The results show the saturations of gas hydrate and free-gas as 22 and 2.4% of pore space, respectively, across the BSR.     

Geochemistry of pore waters from the Xisha Trough, northern South China Sea and their implications for gas hydrates

This paper reports all available geochemical data on sediments and pore waters from the Xisha Trough on the northern continental margin of the South China Sea. The methane concentrations in marine sediments display a downhole increasing trend and their carbon isotopic compositions (δ ¹³C = −25 to −51‰) indicate a thermogenic origin. Pore water Cl⁻ concentrations show a range from 537 to 730 mM, and the high Cl⁻ samples also have higher concentrations of Br⁻, Na⁺, K⁺, and Mg²⁺, implying mixing between normal seawater and brine in the basin. The SO₄ ²⁻ concentrations of pore waters vary from 19.9 to 36.8 mM, and show a downhole decreasing trend. Calculated SMI (sulfate-methane interfaces) depths and sulfate gradients are between 21 and 47 mbsf, and between −0.7 and −1.7 mM/m, respectively, which are similar to values in gas hydrate locations worldwide and suggest a high methane flux in the basin. Overall, the geochemical data, together with geological and geophysical evidence, such as the high sedimentation rates, high organic carbon contents, thick sediment piles, salt and mud diapirs, active faulting, abundant thermogenic gases, and occurrence of huge bottom simulating reflector (BSR), are suggestive of a favorable condition for occurrence of gas hydrates in this region.     

Wave run-up on bermed coastal structures

Reliable estimation of wave run-up is required for the effective and efficient design of coastal structures when flooding or wave overtopping volumes are an important consideration in the design process. In this study, a unified formula for the wave run-up on bermed structures has been developed using collected and existing data. As data on berm breakwaters was highly limited, physical model tests were conducted and the run-up was measured. Conventional governing parameters and influencing factors were then used to predict the dimensionless run-up level with 2% exceedance probability. The developed formula includes the effect of water depth which is required in understanding the influence of sea level rise and consequent changes of wave height to water depth ratio on the future hydraulic performance of the structures. The accuracy measures such as RMSE and Bias indicated that the developed formula is more accurate than the existing formulas. Additionally, the new formula was validated using field measurements and its superiority was observed when compared to the existing prediction formulas. Finally, the new design formula incorporating the partial safety factor was introduced as a design tool for engineers.     

国外海相油气田勘探实例之三美国得克萨斯州法尔韦油田

美国法尔韦油田位于东得克萨斯盆地中心附近。油田发现于1960年,同年投入生产。原始地质储量为4亿桶,至2003年累计产油2.17亿桶。原油具挥发性,接近饱和。主要储层为下白垩统James组礁石灰岩,主要为骨架粒状灰岩/泥粒灰岩和富含双壳类粒泥状灰岩,各岩相的平均孔隙度一般在7%～11%,但平均渗透率在各岩相中不均,最高达(37～44)×10-3"m2。介绍了该油田的勘探史,描述了盆地构造演化史、含油气系统、地层沉积相和储层特征。