CARBONATE RESERVOIR ROCKS AT GIANT OIL AND GAS FIELDS IN SW IRAN AND THE ADJACENT OFFSHORE: A REVIEW OF STRATIGRAPHIC OCCURRENCE AND PORO‐PERM CHARACTERISTICS

SW Iran and the adjacent offshore are prolific petroleum‐producing areas with very large proven oil and gas reserves and the potential for significant new discoveries. Most of the oil and gas so far discovered is present in carbonate reservoir rocks in the Dehram, Khami and Bangestan Groups and the Asmari Formation, with smaller volumes in the Dashtak, Neyriz, Najmeh, Gurpi, Pabdeh, Jahrum, Shahbazan, Razak and Mishan (Guri Member) Formations. The Permo‐Triassic Dehram Group carbonates produce non‐associated gas and condensate in Fars Province and the nearby offshore. The Jurassic – Lower Cretaceous Khami Group carbonates are an important producing reservoir at a number of offshore fields and in the southern Dezful Embayment, and are prospective for future exploration. Much of Iran's crude oil is produced from the Oligo‐Miocene Asmari Formation and the mid‐Cretaceous Sarvak Formation of the Bangestan Group in the Dezful Embayment. This review paper is based on data from 115 reservoir units at 60 oil‐ and gasfields in SW Iran and the adjacent offshore. It demonstrates that the main carbonate reservoir units vary from one‐another significantly, depending on the particular sedimentary and diagenetic history. Ooidal‐grainstones and rudist‐ and Lithocodium‐bearing carbonate facies form the most important reservoir facies, and producing units are commonly dolomitised, karstified and fractured. In general, reservoir rocks in the study area can be classified into six major types: grainstones; reefal carbonates; karstified, dolomitised and fractured carbonates; and sandstones. The stratigraphic distribution of these reservoir rocks was principally controlled by the palaeoclimatic conditions existing at the time of deposition. A comparative reservoir analysis based on core data shows that dolomitised and/or fractured, grain‐dominated carbonates in the Dehram Group, Lower Khami Group and Asmari Formation typically have better reservoir qualities than the Cretaceous limestones in the Upper Khami and Bangestan Groups.     

Thermal performance of a packed bed reactor for a high‐temperature chemical heat pump

The thermal performance of a chemical heat pump that uses the reaction system of calcium oxide/lead oxide/carbon dioxide, which is developed for utilization of high‐temperature heat above 800°C, is studied experimentally. The thermal performance of a packed‐bed reactor of a calcium oxide/carbon dioxide reaction system, which stores and transforms a high‐temperature heat source in the heat pump operation, is examined under various heat pump operation conditions. The energy analysis based on the experiment shows that it is possible to utilize high‐temperature heat with this heat pump. This heat pump can store heat above 850°C and then transform it into a heat above 900°C under an approximate atmospheric pressure. An applied system that combines the heat pump and a high‐temperature process is proposed for high‐efficiency heat utilization. The scale of the heat pump in the combined system is estimated from the experimental results. Copyright © 2001 John Wiley & Sons, Ltd.     

哈拉哈塘碳酸盐岩储层井壁失稳动态评价及失稳形态分析

井壁失稳是碳酸盐岩储层钻完井及开发过程中十分常见的工程难题.塔里木盆地哈拉哈塘油田奥陶系碳酸盐岩油藏油井井壁失稳、出泥砂严重,井壁失稳给油井投产、生产等带来一系列问题.为了对失稳现象进行有效分析,明确失稳来源和失稳形态,发挥油井产能,基于工程表象和作业数据提出井壁失稳程度动态评价指标体系,在生产动态和探冲砂作业基础上,...     

碳酸盐岩烃源岩不同热模拟方式下气体碳同位素演变特征

我国海相烃源岩普遍处于高—过成熟阶段,现有的烃气碳同位素指标不能直接应用于判识海相碳酸盐岩天然气成因类型以及进行油气源对比。利用云南禄劝Ⅱ₁型低成熟海相碳酸盐岩烃源岩,开展了不同热模拟方式下的系列热解生烃实验,对收集的气体产物进行碳同位素分析。结果表明：①在整个热演化阶段,干酪根碳同位素值随成熟度变化不大,而甲、乙烷碳同位素值均随成熟度增加先变轻再变重,具有相似的演变特征,在油气生成的主要阶段,明显小于其母质干酪根碳同位素值,在过成熟阶段,乙烷碳同位素变重的趋势明显加快,甚至大于其母质干酪根的碳同位素值,呈现出“煤型气”特征,故单纯地采用甲、乙烷碳同位素值来判识天然气类型时需要慎重;②在成熟度相同时,半封闭—半开放体系模拟实验所得气体碳同位素值相比封闭体系模拟实验的要轻,这指示同一烃源岩排出烃气所形成的常规天然气藏,其烃气碳同位素值与滞留在源内的页岩气碳同位素值存在一定的差异,显示出似乎“不同源”的特征,在利用碳同位素模版或回归公式开展气源对比时也需要注意;③两种热模拟方式下、同一种烃源岩在全演化阶段,甲烷碳同位素值总是比乙烷的要小,这表明由单一烃源岩直接供气形成的常规天然气藏,不会发生甲、乙烷碳同位素的“倒转现象”。     

塔里木盆地顺北地区中-下奥陶统“断控”缝洞系统划分与形成机制

碳酸盐岩地层普遍发育各类成因机制的非均质性缝洞储层,其孔隙系统的形成演化受岩石的地质演化控制。一般情况下,这类非均质性缝洞储层的形成与地层流体系统中各种不饱和性流体的热化学作用方式和所能带走的物质体积总和有关。但是,塔里木盆地顺北地区发现的“断控”缝洞储层未经历不饱和性流体的溶蚀改造作用,其空间展布明显受到断裂带边界约束,勘探证实可以形成商业价值储层。因此,断裂活动能否发生大规模的物质体积调整,形成完整的缝洞储集系统,需要引起重视。通过应用三维地震、钻井异常工况、测井、元素录井、压恢试井、干扰试井和生产动态资料等,综合表征“断控”储层特征,反演“断控”缝洞单元和储集系统。针对走滑断裂活动过程中的岩石物理特性、构造增容机理和流体改造机制,开展了脆性岩层应变方式、断层封闭性控制因素、水-岩作用方式等研究,提出断裂带内部受岩体错动、破碎及力学-热化学作用而发生的物质体积调整是顺北地区“断控”缝洞储层形成的主导因素,其孔隙系统的形成、演化与断裂活动关系密切。当“断控”缝洞系统形成、演化过程中无法忽视流体影响时,可依据流体性质和作用方式等,细分出“岩溶型”和“热溶型”亚类,作为“断控”储层概念的理论衍生。     

塔里木盆地塔河油田托甫台区奥陶系碳酸盐岩断溶体系层次建模方法

断控岩溶储集体(断溶体)作为缝洞型碳酸盐岩储层的一种特殊类型,受大型走滑断裂带影响,其空间结构复杂、形态不规则且随机性强,给三维精细描述及地质建模带来新的挑战.基于多元、多尺度研究资料,对塔里木盆地塔河油田断溶体系结构层次进行了划分,并提出了断溶体系"层次约束、成因控制、逐级建模"的建模思路.结果 表明:断溶体系按照形...     

中东地区碳酸盐岩油藏分类评价方法与注水开发对策

针对中东地区碳酸盐岩油藏类型复杂多样、缺乏分类开发模式指导的问题,提出基于主成分双标图和K-均值聚类图的油藏分类评价方法。采用定性分析与多元统计分析相结合,从16个典型碳酸盐岩油藏中选取能够反映岩石学、储集层结构、储集层物性、隔夹层、流体性质及非均质性的8个油藏特征参数并构造数据矩阵,然后应用奇异值分解协方差矩阵实现主成分分析,进而构造主成分双标图,对油藏、油藏特征参数及两者关系进行图解分析,最后结合K-均值聚类法开展油藏分类评价。研究结果表明：微观孔隙结构、储集层厚度和非均质性等关键参数对油藏的区分能力较强,据此将中东地区碳酸盐岩油藏划分为3种类型。薄层碳酸盐岩油藏内部贼层不规则分布导致水平井水淹严重,厚层层状碳酸盐岩油藏纵向物性差异大影响储量动用程度,巨厚似块状碳酸盐岩油藏微观孔隙体系复杂且隔夹层发育"隐蔽"、强非均质性加剧了1套层系笼统开发的矛盾。基于此,有针对性地制定了薄层油藏水平井井网低注高采、厚层层状油藏边缘递进和巨厚似块状油藏利用隐蔽隔夹层分层系注水的开发对策,为中东地区碳酸盐岩油藏高效注水开发实现上产稳产提供一定技术支持。