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Forecasting and Modelling the Oil and Gas Reserves in Indonesia Using the Creaming Curve and Linear Regression Analysis 利用拟合曲线和线性回归分析对印尼油气储量进行预测和建模
Pub Date : 2019-03-15 DOI: 10.2118/194786-MS
A. Azizurrofi, Rikky Rahmat Firdaus
In early 2016, oil price has fallen to its lowest level (30.32 US$/bbl) over the last 12 years. Since then, petroleum exploration and exploitation activities are decreasing worldwide due to high production cost and low oil prices. As of December 2017, there were 435 projects approved by the government of Indonesia, which is expected to maintain the national energy supply and to increase national income from oil and gas industry. This paper will evaluate and analyze the oil and gas reserves per project to help Contractors to find the area in Indonesia that has the highest trend of oil and gas reserves per project so that they can produce big revenue. The purpose of this paper is, to divide the geographical areas of Indonesia into 5 different areas (Sumatera, Java, Kalimantan, Sulawesi and Papua). Then, to collect the data that related to projects and oil and gas discoveries and the trend of oil and gas discoveries per project are calculated and analyzed by using the creaming curve method, the result will be distributed to those aforementioned areas and finally define the area that has the highest and the lowest number (trend) of oil and gas discoveries per project. Based on the analysis of 435 Projects in Indonesia, Sulawesi is estimated to have the highest amount of oil and gas reserves by 111.24 MMBOE per project which means that these areas become the most interesting area for Contractors to produce profitable projects, meanwhile Sumatera is estimated to have the lowest amount of oil and gas reserves by 7.19 MMBOE per project which means that these areas are becoming the most mature area in Indonesia. Finally, this paper is expected to provide contractors a quick look at oil and gas industry in Indonesia especially the contractors who are looking for the giant oil and gas reserves and also help them create their petroleum exploration and exploitation strategy in Indonesia by considering on this information which will provide benefits for both government and contractor.
2016年初,油价跌至12年来的最低水平(30.32美元/桶)。从那时起,由于高生产成本和低油价,世界范围内的石油勘探和开发活动正在减少。截至2017年12月,印尼政府批准了435个项目,预计将维持国家能源供应,并增加石油和天然气行业的国民收入。本文将对每个项目的油气储量进行评估和分析,以帮助承包商在印度尼西亚找到每个项目油气储量趋势最高的区域,从而产生较大的收益。本文的目的是,将印度尼西亚的地理区域划分为5个不同的区域(苏门答腊,爪哇,加里曼丹,苏拉威西和巴布亚)。然后,收集与项目和油气发现相关的数据,并利用膏化曲线法对每个项目的油气发现趋势进行计算和分析,将结果分配到上述区域,最终确定每个项目油气发现数量(趋势)最高和最低的区域。根据对印度尼西亚435个项目的分析,估计苏拉威西岛的油气储量最高,每个项目111.24百万桶油当量,这意味着这些地区成为承包商最有兴趣开发有利可图项目的地区,同时苏门答腊的油气储量最低,每个项目7.19百万桶油当量,这意味着这些地区正在成为印度尼西亚最成熟的地区。最后,本文旨在为承包商提供印度尼西亚石油和天然气行业的快速了解,特别是那些正在寻找巨大石油和天然气储量的承包商,并帮助他们通过考虑这些信息来制定他们在印度尼西亚的石油勘探和开发战略,这将为政府和承包商提供利益。
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引用次数: 1
Simulation and Performance of Immiscible WAG Pilots in Mauddud Reservoir Using Three Phase Relative Permeability with Hysteresis Mauddud油藏非混相WAG导油系统的三相滞后相对渗透率模拟及性能研究
Pub Date : 2019-03-15 DOI: 10.2118/195103-MS
A. Al-Muftah, Yusuf Buali, A. Mahmoud, Hamed AlGhadhban
The Bahrain Field, being the first oil discovery in the gulf region in 1932, is now in a mature stage of development. Crestal gas injection in the Mauddud reservoir has continued to be the strongest driving mechanism since 1938. Over the last five years, gas injection and fluid production rates have grown three folds with expanded drilling, workovers, and high volume lift activities. However, there are significant opportunities to increase oil production and optimize gas injection. An Immiscible-Water-Alternating-Gas injection (IWAG) process was carried out on two composite samples extracted from the Mauddud reservoir of the Bahrain Field. The resulting production and pressure profiles were history matched by using hysteresis and three-phase relative permeability modeling options. Representative relative permeability and capillary pressure curves with the associated hysteresis and three- phase relative permeability parameters were obtained by history matching the experimental IWAG flood results. The history match was carried out by generating the hysteresis parameters and relative permeability curve sets. Experimental results, including two-phase water/gas flood steady state and unsteady state results, were honored to the degree possible. In both composite samples, the IWAG process showed incremental recovery compared to the base case water and gas injection cases. The incremental recovery obtained (above 10% PV) was largely due to the reduction of gas relative permeability during three-phase flow. A maximum trapped gas saturation of 23% was used to history match the core-flood results. A sector model of the Mauddud reservoir was run using the relative permeability and hysteresis model parameters obtained from the history matching of the composite core-floods. A water and gas flood base case was run and compared to the IWAG sequence. The IWAG process showed incremental recovery compared to the base case water injection. In the up-dip pattern where the water saturation is low, IWAG recovers 3% more than base case gas injection, while gas injection recovers 5% more than the IWAG sequence in the down-dip pattern where water saturation is higher. The objective of introducing the Immiscible Water Alternating Gas process (IWAG) in Mauddud was to reduce gas production by controlling the mobility during the three-phase flow. Incremental oil, compared with gas and water injection was also to be evaluated. Three IWAG pilots were introduced after an extensive study on optimum locations. Two inverted 5-spot patterns and one line drive pattern were selected; each pattern is around 40 acre spacing, targeting Mauddud B interval. The original Water Alternating Gas (WAG) ratio was designed to be 1:3 (Water: Gas) and the WAG period was originally designed to be from three to six months based on simulation work. WAG ratio and duration optimization were subject to performance. After one year of cyclic injection, both inverted 5-spot patterns showed lack of resp
巴林油田是1932年在海湾地区发现的第一个油田,目前已处于成熟开发阶段。自1938年以来,Mauddud储层的顶部注气一直是最强的驱动机制。在过去的五年中,随着钻井、修井和大规模举升活动的扩大,注气和产液速度增长了三倍。然而,在提高石油产量和优化注气方面仍有很大的机会。对从巴林油田Mauddud油藏中提取的两种复合样品进行了非混相水-交变气注入(IWAG)工艺。通过使用滞后和三相相对渗透率建模选项,对得到的产量和压力剖面进行历史匹配。通过对IWAG实验结果进行历史拟合,得到了具有代表性的相对渗透率和毛管压力曲线,以及相关的滞后和三相相对渗透率参数。通过生成滞后参数和相对渗透率曲线集进行历史拟合。实验结果,包括两相水/气驱稳态和非稳态结果,都尽可能地得到了尊重。在这两种复合样品中,IWAG工艺的采收率都比基本情况下的水和气注入情况有所增加。获得的增量采收率(高于10% PV)主要是由于三相流过程中气体相对渗透率的降低。最大捕获气饱和度为23%,用于历史匹配岩心驱油结果。利用复合岩心注水历史拟合得到的相对渗透率和滞后模型参数,建立了Mauddud油藏扇形模型。运行了一个水和气驱基础案例,并与IWAG序列进行了比较。与基本情况注水相比,IWAG工艺的采收率有所增加。在含水饱和度较低的上倾模式下,IWAG层序的注气采收率比基准情况高3%,而在含水饱和度较高的下倾模式下,IWAG层序的注气采收率比IWAG层序高5%。在Mauddud引入非混相水交替气工艺(IWAG)的目的是通过控制三相流的流动性来减少产气量。与注气和注水相比,增量油也将进行评估。在对最佳地点进行广泛研究后,引入了三个IWAG试点。选择两种倒5点模式和一种直线驱动模式;每个模式的间距约为40英亩,目标是Mauddud B层。最初的水-气交替(WAG)比设计为1:3(水:气),根据模拟工作,WAG周期最初设计为3至6个月。WAG比和持续时间优化取决于性能。经过一年的循环注射,两种倒5点模式对WAG循环缺乏反应。在后一种模式中,水循环严重影响了石油生产。在直线驱动模式下,WAG循环最初表现出良好的响应。经过一年的注入,水和气超过了油的产量,导致了更高的产油量下降,并由于限制和操作问题而终止了试验。
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引用次数: 1
OGIP Estimation from Boundary Dominated Data Using Normalized Variables: A Field Case Application in a Tight Gas HP/HT Field 基于归一化变量的边界主导数据OGIP估计:致密气高温高压油田实例应用
Pub Date : 2019-03-15 DOI: 10.2118/195152-MS
Adolfo D'Windt, A. Al-Saffar
Accurate estimation of the Original Gas in Place (OGIP) early in the reservoir life is fundamental as field development plans and ultimate recovery strongly depend on it. This is particularly relevant when the conventional material balance is not suitable due to the lack of pertinent shut-in pressure measurements. This paper presents a case history of a tight gas field in which we use flowing material balance technique and type curves for decline curve analysis to calculate OGIP by using only flowing pressure and rate data. The method uses fundamental pseudo-steady state theory, which determines that a plot of the rate-normalized pressure drop vs the pseudo-time produces a straight line with the slope of such line yielding the OGIP. The use of the pseudo time concept calls for the estimate of gas properties at the prevailing reservoir pressure which in turn is a function of the OGIP and the cumulative production. We propose an iterative scheme based on the Newton-Raphson method to compute the OGIP using the flowing material balance technique coupled with the conventional P/Z material balance. We illustrate the application of the method with the aid of synthetic examples as well as field cases obtained from low permeability gas reservoirs where no shut-in pressures are available. Results from the technique adequately compare with type-curve matching analysis. Furthermore, we demonstrate the problem can be transformed into an equivalent-liquid system and being analyzed with standard PTA techniques using the constant rate liquid solution. In absence of shut-in pressure information, the PSS analysis offers an attractive alternative to the conventional material balance method. Besides, the method only requires minimal phase behavior data in the case of gases rendering its application practical and convenient. Also, we describe how to transform the constant pressure problem into a constant rate one in order to apply standard PTA techniques. Additionally, this work demonstrates the importance of having automated wells with permanent gauges by enhancing the value of the information provided by them in the framework of an adequate and judicious reservoir management.
由于油田开发计划和最终采收率在很大程度上依赖于OGIP,因此在储层生命早期对OGIP的准确估计是至关重要的。当由于缺乏相关关井压力测量,传统的物料平衡不适合时,这一点尤为重要。本文以某致密气田为例,利用流动物质平衡技术和递减曲线分析的类型曲线,仅利用流动压力和流动速率数据计算出OGIP。该方法使用基本的伪稳态理论,该理论确定了速率归一化压降与伪时间的图产生一条直线,该直线的斜率产生OGIP。伪时间概念的使用要求估计当前储层压力下的气体性质,而这又是OGIP和累积产量的函数。我们提出了一种基于牛顿-拉夫森方法的迭代方案,利用流动物质平衡技术和传统的P/Z物质平衡来计算OGIP。我们通过综合算例以及从无关井压力的低渗透气藏获得的现场案例来说明该方法的应用。该方法的结果与类型曲线匹配分析有充分的比较。此外,我们还证明了该问题可以转化为等效液体系统,并使用恒速率液体溶液用标准PTA技术进行分析。在没有关井压力信息的情况下,PSS分析为传统的材料平衡方法提供了一个有吸引力的替代方案。此外,该方法只需要最少的气体相行为数据,使其应用更加实用和方便。此外,我们还描述了如何将恒压问题转化为恒速问题,以便应用标准的PTA技术。此外,这项工作还证明了配备永久性仪表的自动化井的重要性,因为它可以提高仪表提供的信息在充分和明智的油藏管理框架中的价值。
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引用次数: 0
Cost-Effective Sour Management in Mixed Production Systems 混合生产系统的成本效益管理
Pub Date : 2019-03-15 DOI: 10.2118/194884-MS
Soma Chakraborty, S. Lehrer, Jagrut Jani, S. Ramachandran
Sour production from offshore and land-based wells causes hydrogen sulfide (H2S) release during downhole and topsides operations. Improper handling of H2S can lead to serious environmental and safety concerns as well as numerous corrosion and compliance issues. Consequently, H2S can add significantly to the total cost of well operations. The application of efficient H2S management technologies can reduce environmental and safety concerns, enable the use of lower-cost materials, and comply with H2S specifications. To remove H2S from mixed production applications, several chemistries are commonly used. The most common are triazines, glyoxal, and metal-based chemistries. Although each can be effective to a certain extent, these technologies have issues with efficiency or they can create serious side issues. The reaction of triazines with H2S in mixed production is highly inefficient and it creates scaling. Glyoxals suffer from poor efficiency, thermal instability, and corrosivity. The metal-based chemistries are the most efficient in mixed production, but in certain application regimes they can create serious solids and emulsion issues. These challenges can increase CAPEX and OPEX as well as lead to significant downtime and lost production. To overcome issues with currently used chemistries in mixed sour production, extensive research was conducted to identify chemistry that would efficiently remove H2S while minimizing negative side effects. Systematic evaluation was performed for a series of chemistries to compare the scavenging efficiency, with a special emphasis on mixed production systems. Focus was also given on studying the associated side effects like emulsification tendency, scaling tendency, etc. to ensure the chemistry had no/minimal side effects seen by the more conventional chemistries. A high-throughput lab technique is presented that was designed to mimic scavenging tendency in sour mixed production environment. A continuous gas flow testing technique that helped study the reaction kinetics is also described. Laboratory and pre-field results proved the efficacy of the new non-MEA, non-triazine chemistry in mitigating H2S in upstream, midstream and downstream applications while being especially efficient in mixed production systems. Laboratory testing proved the chemistry to be highly efficient compared to triazine in mixed production systems. Results also indicated the chemistry is non-emulsion forming and has very little scaling tendency. Testing conducted in the field demonstrated that the new chemistry cost-effectively removes H2S and meets the operator specifications. The novel, non-triazine scavenger technology has significantly better performance than triazine, no emulsion concerns, acceptable HSE, non-corrosive effects, and less downstream concern than MEA triazine or metal-based scavengers. The new and differentiated chemistry reduces CAPEX and OPEX, drives productivity, improves reliability and reduces non-productive tim
海上和陆地油井的产酸会在井下和地面作业过程中释放硫化氢(H2S)。H2S处理不当会导致严重的环境和安全问题,以及许多腐蚀和合规问题。因此,H2S会显著增加钻井作业的总成本。高效的H2S管理技术的应用可以减少对环境和安全的担忧,使用更低成本的材料,并符合H2S规范。为了从混合生产应用中去除H2S,通常使用几种化学物质。最常见的是三嗪类、乙二醛和金属基化学物质。尽管每种技术在一定程度上都是有效的,但这些技术在效率方面存在问题,或者它们可能会产生严重的副作用。在混合生产中,三嗪与H2S的反应效率很低,而且会产生结垢。乙二醛具有效率低、热不稳定性和腐蚀性。金属基化学剂在混合生产中是最有效的,但在某些应用制度下,它们可能会产生严重的固体和乳液问题。这些挑战会增加资本支出和运营成本,并导致严重的停机时间和生产损失。为了克服目前混合酸生产中使用的化学物质存在的问题,研究人员进行了广泛的研究,以确定能够有效去除H2S的化学物质,同时将负面影响降到最低。对一系列化学物质进行了系统评价,比较了清除效率,特别强调了混合生产系统。我们还重点研究了相关的副作用,如乳化倾向、结垢倾向等,以确保该化学物质没有或只有更传统化学物质所见的副作用。提出了一种高通量实验室技术,旨在模拟酸性混合生产环境中的清除倾向。本文还介绍了一种有助于研究反应动力学的连续气体流量测试技术。实验室和现场前试验结果证明,新型非mea、非三嗪类化学物质在上游、中游和下游应用中具有降低H2S的效果,在混合生产系统中尤其有效。实验室测试证明,与混合生产系统中的三嗪相比,该化学物质具有很高的效率。结果还表明,化学性质不形成乳液,结垢倾向很小。现场测试表明,新型化学剂能够经济有效地去除H2S,并满足作业者的要求。这种新型的、不含三嗪的清除剂技术的性能明显优于三嗪,没有乳化液问题,可接受的HSE,无腐蚀影响,并且比MEA三嗪或金属基清除剂对下游的影响更小。新型的差异化化学产品降低了资本支出和运营成本,提高了生产率,提高了可靠性,减少了非生产时间。
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引用次数: 0
Proactive Utilization of ESP Performance Monitoring to Enhance Productivity 主动利用ESP性能监测,提高生产效率
Pub Date : 2019-03-15 DOI: 10.2118/194925-MS
Hashim Al-Sadah, Mohannad A. Abo Khamseen, A. Al-Ghamdi, Ali Fardan
As the electric submersible pump (ESP) population increases, the requirement for continuous operation is required to ensure optimum oil sweep rather than depending on fewer number of ESPs. ESP outages, shutdowns and underperforming pumps have to be minimized to reduce operational cost and deferred production. In efforts to reduce pumps downtime, ESP monitoring operations were centralized in a production surveillance and optimization center. This paper illustrates the practices followed in the hub to enhance productivity, by preventing ESP trips and failures, and conducting optimization initiatives through collaborative efforts with different parties. By remote monitoring of real-time data of downhole sensor readings and surface data, the hub can identify ESP units operating in conditions that could lead to shutdowns and are identified to be preventable ESP trips. By capturing and predicting the downtime events, the objectives of reducing ESP downtime and production deferral is achieved. The hub monitors the individual unit's parameters with its operational confines to ensure that the ESP is running within the preferred boundaries to preserve the equipment's electrical and mechanical health. The observed conditions are referenced against the design and actions are taken accordingly to avert unnecessary trips. Upon the deployment of ESP monitoring, many benefits were realized ranging from improved asset performance to raising efficiency of manpower usage besides saving time. Deferred production was avoided through eliminating preventable trips under ESP monitoring. This practice not only prevents ESP downtime, but also has the goal of improving ESP efficiency levels, regarding motor and pump performance. Proactive measures are crucial in ESP production operations. In events where a probable ESP trip is predicted and actions are taken to optimize its operating conditions to prevent the trip, the number of ESP outages at the field level is reduced, thereby helping to sustain a healthy ESP well life cycle.
随着电潜泵(ESP)数量的增加,需要连续作业以确保最佳的扫油效果,而不是依赖于更少的ESP数量。为了降低运营成本和延迟生产,必须尽量减少ESP故障、停机和性能不佳的泵。为了减少泵的停机时间,ESP监控作业集中在生产监控和优化中心。本文阐述了通过防止ESP起下钻和故障,以及通过与各方合作实施优化措施,来提高生产效率的做法。通过远程监控井下传感器读数和地面数据的实时数据,该轮毂可以识别出可能导致关井的ESP设备,并识别出可预防的ESP起下钻。通过捕获和预测停机事件,可以实现减少ESP停机时间和生产延迟的目标。该集线器监控单个装置的参数及其操作范围,以确保ESP在首选范围内运行,以保持设备的电气和机械健康。将观察到的情况与设计相对照,并采取相应的措施以避免不必要的起下钻。部署ESP监测后,除了节省时间外,还可以改善资产性能,提高人力使用效率。通过消除ESP监测下的可预防起下钻,避免了延迟生产。这种做法不仅可以防止ESP停机,还可以提高ESP的效率水平,包括电机和泵的性能。主动措施在ESP生产作业中至关重要。在预测到可能发生的ESP起下钻的情况下,采取措施优化其操作条件以防止起下钻,减少了现场的ESP停机次数,从而有助于维持健康的ESP井生命周期。
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引用次数: 2
Barrier and Thermal Performance of Graphene-HDPE Nanocomposites for Pipeline Liner Application 管道内衬用石墨烯-高密度聚乙烯纳米复合材料的阻隔与热性能研究
Pub Date : 2019-03-15 DOI: 10.2118/195069-MS
M.S.F. Samsudin, Murniyati Ahmad Mahtar, K. Leong
The water barrier performance of high density polyethyelene (HDPE) nanocomposites with different graphene thicknesses and aspect ratios was investigated. Three graphenes with differing thicknesses and aspect ratios were considered for this work. The graphene was blended into the polymer HDPE matrix using a heated internal mixer. The best performing graphene in terms of improved barrier performance was determined to be the one that is thinnest and with the highest aspect ratio. This graphene was further studied for the effects of loading, whereby samples with 0.005, 0.01 and 0.10 wt% graphene, revealed no significant difference between them for enhanced barrier performance. In addition, the degree of crystallinity was also measured and compared between the unmodified and the three graphene modified HDPE. Between the three graphene-HDPE variants, there was no discernible difference in the level of crystallisation of the HDPE. However, it was shown that crystallinity improves by some 15%, corresponding to a measured degree of crystallinity of 65% for the graphene-HDPE, versus 56% for the unmodified HDPE. Thermal stability, on the other hand, did not improve with addition of the three graphenes used in this work. It is believed that the graphene loading used in this work was is low to produce any observable enhancement in thermal stability.
研究了不同石墨烯厚度和长径比的高密度聚乙烯(HDPE)纳米复合材料的隔水性能。在这项工作中考虑了三种不同厚度和纵横比的石墨烯。利用加热的内部混合器将石墨烯混合到聚合物HDPE基体中。在改善势垒性能方面表现最好的石墨烯被确定为最薄和具有最高宽高比的石墨烯。该石墨烯进一步研究了负载的影响,其中0.005%,0.01和0.10 wt%石墨烯的样品在增强屏障性能方面没有显着差异。此外,还测量了未改性和三种石墨烯改性HDPE的结晶度并进行了比较。在三种石墨烯-HDPE变体之间,HDPE的结晶水平没有明显的差异。然而,研究表明,石墨烯-HDPE的结晶度提高了约15%,对应于测量的结晶度为65%,而未改性的HDPE为56%。另一方面,在本研究中使用的三种石墨烯的加入并没有改善热稳定性。人们认为,在这项工作中使用的石墨烯负载是低的,以产生任何可观察到的热稳定性增强。
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引用次数: 1
Use of Geological Constraints in Multi-Mineral Modeling for Unconventional Reservoirs 地质约束在非常规储层多矿物建模中的应用
Pub Date : 2019-03-15 DOI: 10.2118/194745-MS
Z. Hao, A. Nora, Mendez Freddy, Hanif Amer
Determination of mineral rock composition is an important part of unconventional reservoir formation evaluation because the mineral composition affects hydraulic fracture generation and propagation. Two types of models are usually used for mineralogy modeling—deterministic and stochastic. Both models apply mathematical representations of the logging tool responses; however, stochastic modeling has become more popular due to its consideration of random distributions in the predictor and target variables. Stochastic mineralogy modeling algorithms usually produce solutions by minimizing a function reflecting the differences between the measured and modeled responses. However, due to the non-uniqueness inherent in inversion methods, the solution may not provide petrophysically meaningful results. To avoid producing compromised results, the use of geological constraints is proposed to represent the geological relations between the unknown parameters (inversion variables), leading to a more meaningful mineralogy model. The proposed algorithm incorporates probability functions to generate mineralogical solutions representing geologically and petrophysically sound results. The weight assigned to the penalties in the cost function depends on the probability function assigned to the constraints. Two models are presented using the proposed algorithm: a pyrite-anhydrite constraint based on the iron and sulfur ratio, and a K-feldspar-albite constraint based on the thorium and potassium ratio. Data sets from several different shale plays, from across North America, are processed using the proposed algorithm. The mineral sets are complex and vary from one play to another. The results show excellent agreement with the available core X-ray diffraction measurements. The study demonstrates that the proposed constraints provide an effective improvement, in integrated formation evaluation, especially in unconventional reservoirs with highly complex mineralogy.
矿物岩石成分的确定是非常规储层评价的重要组成部分,因为矿物成分影响水力裂缝的产生和扩展。矿物学建模通常采用两种模型——确定性模型和随机模型。两种模型都应用了测井工具响应的数学表示;然而,随机建模由于考虑了预测变量和目标变量的随机分布而变得越来越流行。随机矿物学建模算法通常通过最小化反映测量和模拟响应之间差异的函数来产生解决方案。然而,由于反演方法固有的非唯一性,该解决方案可能无法提供有岩石物理意义的结果。为了避免产生折衷的结果,建议使用地质约束来表示未知参数(反演变量)之间的地质关系,从而产生更有意义的矿物学模型。所提出的算法结合概率函数来生成代表地质和岩石物理结果的矿物学解。代价函数中惩罚的权重取决于约束的概率函数。利用该算法提出了两个模型:基于铁硫比的黄铁矿-硬石膏约束模型和基于钍钾比的钾长石-钠长石约束模型。来自北美几个不同页岩区的数据集使用所提出的算法进行处理。矿物集是复杂的,从一个到另一个变化。结果与现有的岩心x射线衍射测量结果非常吻合。研究表明,所提出的约束条件对地层综合评价,特别是对矿物学高度复杂的非常规储层,提供了有效的改进。
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引用次数: 1
Comparative Analysis of Full-Cycle Cost of Oil and Gas Exploration, Development and Production World-Wide 全球油气勘探、开发、生产全周期成本比较分析
Pub Date : 2019-03-15 DOI: 10.2118/194906-MS
L. Virine, S. Mccoskey
Understanding the full-cycle cost of oil and gas exploration, development, and production is critical for petroleum producers and all players in the oil and gas industry. In particular, full-cycle cost assessment is used for corporate planning, acquisitions, operational improvements, project control, and risk management. The challenge is to ensure that full-cycle cost assessment is done accurately and on a consistent basis across different jurisdictions, companies, and geographic areas. Without knowing the full-cycle cost on a consistent basis worldwide, it is impossible to assess capital investment, forecast production from different areas, forecast prices, or assess other factors influencing the world market for oil and gas. This paper discusses the methodology for and the results of full-cycle cost assessment worldwide. This paper describes a methodology for full-cycle cost assessment that ensures data quality and consistency. It also provides examples of full-cycle cost assessment for major projects worldwide. The results of analysis help to predict long-term pricing trends, determine areas where production will grow or decline, and estimate capital expenditure in the next 10–20 years based on the most recent and most consistent data.
了解油气勘探、开发和生产的全周期成本对石油生产商和油气行业的所有参与者都至关重要。特别是,全周期成本评估用于公司计划、收购、操作改进、项目控制和风险管理。面临的挑战是确保在不同的司法管辖区、公司和地理区域准确且一致地完成全周期成本评估。如果不了解全球范围内一致的全周期成本,就不可能评估资本投资、预测不同地区的产量、预测价格或评估影响全球油气市场的其他因素。本文讨论了世界范围内全周期成本评估的方法和结果。本文描述了一种确保数据质量和一致性的全周期成本评估方法。它还提供了全世界主要项目的全周期成本评估的例子。分析结果有助于预测长期价格趋势,确定产量增长或下降的地区,并根据最新和最一致的数据估计未来10-20年的资本支出。
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引用次数: 0
Production Optimization Challenges and Solutions for Heavy Oil - North Kuwait 科威特北部重油生产优化面临的挑战和解决方案
Pub Date : 2019-03-15 DOI: 10.2118/194809-MS
Abdul-Aziz Bassam, Ghazi Al-Besairi, Sulaiman Al-Dahash, Tomas Sierra, A. Mohamed, K. Heshmat
The demand for digital oil field solutions in artificially lifted wells is higher than ever, especially for wells producing heavy oil with high sand content and gas. A real-time supervisory control and data acquisition solution has been applied in a large-scale thermal pilot for 28 instrumented sucker rod pumping wells in North Kuwait. This paper focuses on the advantages of real-time data acquisition for identifying production-optimization candidates, improving pump performance, and minimizing down time when using intelligent alarms and an analysis engine. Real-time surveillance provided a huge amount of information to be analyzed and discussed by well surveillance and field development teams to determine required actions based on individual well performance. Controller alarms and intelligent configurable alarms in one screen enabled early detection of unexpected/unwanted well behavior, re-investigating well potential, and taking necessary actions. The challenge was to handle heavy oil, sand, and gas production, maintain all wells at optimum running conditions before and after steam injections, and take into consideration the effect that injections would have on nearby wells. Recording in the database a "tracking item" for each well event enabled review and evaluation of the wells and creation of optimization reports. The daily, 24-hour surveillance of the wells resulted in observing common problems/issues on almost all wells and other individual issues for specific wells. The following are examples of problems identified in early stages: Detected wells with gas interference before they reached gas lockDetected wells with high flowline pressure before flowline blockage resulted from sand productionDetected wells with standing valve and/or traveling valve leak—resulting from sand production—before the pump stuck The availability of such a supervisory control and data acquisition (SCADA) system helped in guiding the operations team to further investigate only specific items from the field side to confirm the findings. The ability to remotely control the wells and remotely change configuration of the variable speed drive parameters enabled instant implementation and continuous production optimization. The powerful SCADA solution enabled creating short- and long-term plans and monitoring the behavior of wells while the implementation phase was executed. For the first time in South Ratqa in North Kuwait, the smart field approach was implemented in a thermal pilot using sucker rod pumps; and the results will be used as a reference for the upcoming projects in this area. Real-time monitoring and data storage in a single database with an analysis engine provided fully automated surveillance and the capability of remotely controlling and applying required actions for production optimization.
人工举升井对数字化油田解决方案的需求比以往任何时候都要高,特别是对于含砂量和含气量高的稠油井。一种实时监控和数据采集解决方案已应用于科威特北部28口仪器抽油机井的大型热试验。本文重点介绍了实时数据采集在识别生产优化候选产品、提高泵性能以及使用智能警报和分析引擎时最大限度地减少停机时间方面的优势。实时监控提供了大量的信息,供油井监控和现场开发团队分析和讨论,以根据单口井的性能决定所需的措施。控制器警报和智能可配置警报集中在一个屏幕上,可以早期发现意外/不想要的井行为,重新调查井的潜力,并采取必要的措施。面临的挑战是如何处理稠油、砂岩和天然气的生产,在注汽前后保持所有井的最佳运行状态,并考虑注汽对附近井的影响。在数据库中记录每个井事件的“跟踪项”,可以对井进行审查和评估,并创建优化报告。每天对井进行24小时监测,发现了几乎所有井的共同问题,以及特定井的其他个别问题。以下是在早期阶段发现的问题的例子:在出砂导致油管堵塞之前,检测出油管压力高的井;在泵卡钻之前,检测出出砂导致的活门和/或移动阀泄漏的井。这种监控和数据采集(SCADA)系统的可用性有助于指导作业团队进一步调查现场的具体问题,以确认发现的结果。远程控制井和远程改变变速驱动参数配置的能力,实现了即时实施和持续的生产优化。强大的SCADA解决方案能够制定短期和长期计划,并在实施阶段监控井的行为。在科威特北部的South Ratqa地区,首次使用有杆泵在热试验中实施了智能油田方法;研究结果将为该领域的后续项目提供参考。实时监控和数据存储在单个数据库中,具有分析引擎,提供全自动监控,远程控制和应用所需操作的能力,以优化生产。
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引用次数: 0
Real-Time Drilling Operation Activity Analysis Data Modelling with Multidimensional Approach and Column-Oriented Storage 基于多维方法和面向列存储的实时钻井作业活动分析数据建模
Pub Date : 2019-03-15 DOI: 10.2118/194701-MS
Basirudin Djamaluddin, P. Prabhakar, Baburaj James, Anas Muzakir, Hussain AlMayad
Real-time data stream in the format of WITSML which can have frequency as low as 1 Hz is one of the best candidate to produce KPIs for the drilling operation activity. The KPIs generated from this calculation will have a relationship with other information from other data sources, known as metadata. The question is how can this KPI information be utilized for further analysis, wider/more complex analysis process which needs to be combined with metadata? An OLTP model is not the recommended model for data analytics but OLAP is. Another question is how will this data be stored in terms of the physical storage? We argue to use column-oriented for the physical storage which can perform analytical queries 10x to 30x faster than the row-oriented storage. The implementation of an OLAP model for storing KPIs data is proven to improve the performance of the analytical query significantly and combined with the implementation of column-oriented in the OLAP model improves more performance. This concludes that the implementation of OLAP with column-oriented data model can be used as the solid foundation for storing KPI data.
WITSML格式的实时数据流的频率可低至1hz,是为钻井作业活动生成kpi的最佳候选之一。由此计算生成的kpi将与来自其他数据源的其他信息(称为元数据)具有关系。问题是如何将这些KPI信息用于需要与元数据相结合的进一步分析、更广泛/更复杂的分析过程?OLTP模型不是数据分析的推荐模型,但OLAP是。另一个问题是如何将这些数据存储在物理存储中?我们主张使用面向列的物理存储,它执行分析查询的速度比面向行存储快10到30倍。事实证明,用于存储kpi数据的OLAP模型的实现可以显著提高分析查询的性能,并且与OLAP模型中面向列的实现相结合可以提高性能。由此得出结论,使用面向列的数据模型实现OLAP可以作为存储KPI数据的坚实基础。
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引用次数: 3
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