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Journey of Effectively Using Real-Time Production Surveillance Tool in Digital Transformation and Well, Reservoir and Facility Management Improvements 在数字化转型和油井、油藏和设施管理改进中有效使用实时生产监控工具的历程
Pub Date : 2021-10-04 DOI: 10.2118/205623-ms
S. Sahu, C. Lauwerys, Zulfikri Abdullah, Mariana Jamil Muhammad, Divya Agrawal
In 2014, SPE-167857-MS was published highlighting how Real-Time Surveillance using the Shell proprietary Production Universe (PU) application helped to reduce deferment, improve production allocation, optimize test unit capacity, and track well operating envelope in Brunei Shell Petroleum BSP (company) operations in South East Asia. Since then, there has been significant progress in the application of PU to help the company meet Wells Reservoir Management (WRFM) requirements and Operational Excellence standards in areas such as Platform Production Reconciliation, Well Modeling, Production Estimation, and Exception based Surveillance helping the company to improve their Hydrocarbon and Energy Accounting. The wider introduction of the PU application in the allocation process significantly helped in Hydrocarbon Accounting (HCA), helping company's journey in moving from monthly to daily allocation and assisting to improve the field reconciliation factor (RF). The utilization of PU has also facilitated real-time monitoring of production parameters supporting engineers to safely and efficiently operate their wells within the Operating Envelopes while adhering to reservoir management guidelines. The optimization engine of the PU has been used to maximize the production of company contributing to two major success stories of Real-Time Condensate Optimization in a Gas-Constraint system and Gas Lift Optimization in a platform with limited lift gas availability amongst the producing wells. An Integrated Production Monitoring and Optimization System (IPMOS) provides asset-wide advice on optimally producing company's well within the constraints imposed by limitations on pipeline capacity, compressor throughput, and remote operability while satisfying customer demands. PU is additionally being used in Proactive Technical Monitoring (PTM) of rotating equipment to identify the critical parameters operating outside the set limits in an exception-based format. PU alerts & alarms have been configured in a wide range of operational monitoring such as Ensure Safe Production (ESP), Chemical Injection, Annulus Pressure Monitoring(APM), Control-Line pressure, Erosion-Corrosion Monitoring System(ECMS) to alert Production Engineers in case of any discrepancy or exception-based format for them to take remedial actions. This paper will explain how each of the above applications in PU has helped company in its journey of closing its gap to potential and achieving the digital transformation of its operations.
2014年,SPE-167857-MS发布,重点介绍了使用壳牌专有的Production Universe (PU)应用程序的实时监控如何帮助减少延迟,改善生产分配,优化测试单元容量,并跟踪文莱壳牌石油公司在东南亚的作业范围。从那时起,PU的应用取得了重大进展,帮助公司满足油井油藏管理(WRFM)的要求和卓越运营标准,如平台产量对账、井建模、产量估计和基于异常的监测,帮助公司改善其油气和能源会计。在分配过程中广泛引入PU应用,极大地帮助了油气会计(HCA),帮助公司从每月分配到每日分配,并帮助提高现场调节因子(RF)。PU的使用还有助于实时监测生产参数,支持工程师在遵守油藏管理准则的同时,在作业封隔层内安全高效地作业。PU的优化引擎已被用于最大限度地提高公司的产量,为两个主要的成功案例做出了贡献:在气体约束系统中的实时凝析油优化,以及在生产井中举升气可用性有限的平台中的气举优化。综合生产监控和优化系统(IPMOS)在满足客户需求的同时,在管道容量、压缩机吞吐量和远程可操作性的限制下,为公司的油井提供最佳生产建议。此外,PU还用于旋转设备的主动技术监测(PTM),以例外形式识别超出设定限制的关键参数。PU警报和警报已被配置在各种操作监控中,如确保安全生产(ESP)、化学注入、环空压力监测(APM)、控制线压力、侵蚀腐蚀监测系统(ECMS),以便在出现任何差异或异常时提醒生产工程师,以便他们采取补救措施。本文将解释PU中的上述每种应用程序如何帮助公司缩小其潜力差距并实现其运营的数字化转型。
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引用次数: 2
678 Challenges of Well Completion Design & Operation Solutions for Deep Gas Well with Multiple Producing Zone in Mildly Overpressured Reservoirs at Offshore Malaysia 678马来西亚海上轻度超压油藏多产层深层气井完井设计与作业解决方案的挑战
Pub Date : 2021-10-04 DOI: 10.2118/205634-ms
Hazirah Abdul Uloom, Asba Madzidah Abu Bakar, M. Hussain, F. Tusimin, Z. R. M. Ghazali, M. S. Salih, M. F. A. Rasid, Sunanda Magna Bela, L. Riyanto, M. Othman, Syazwan A Ghani, N. A. A. Fadzil
Based on the production data from first development campaign in 2017, contamination reading of CO2 and H2S from gas production wells were observed increasing from 3% to 10% and from 3ppm to 16ppm respectively within one year production. These findings have triggered the revisit in 2019 development campaign optimization strategy in terms of material selection, number of wells, reservoir targets, and completion design. Thus, tubing material was upgraded to HP1-13CR for the upper part of tubing up to 10,000 ft-MDDF (feet measure depth drilling rig floor) to avoid SSC risk due to the geostatic undisturbed temperature is less than 80 deg C, however the material of deeper tubing remains as 13CR-L80 as per 2017 campaign. Moreover, the mercury content from first campaign was observed to be above threshold limit from intermediate reservoir based on mercury mapping exercise done in August 2018.As the mercury removal system is not incorporated in the surface facilities, the mercury reading from the well in the 2019 campaign need a close monitoring during well testing so that appropriate action can be taken in case the recorded contaminant reading is high. Dedicated zonal sampling plan to be performed if the commingle zone (total) mercury reading was recorded to be above the threshold limit, and that zones will be shut off to preserve the surface facilities. Opportunity was grabbed to optimize number of wells by completing both shallow and intermediate sections in a single selective completion to maximize the project value. However, this combination will lead to major challenges during operation due to the huge difference in reservoir pressure and permeability contrast in each perforated reservoir as the required overbalanced pressure of completion brine for shallow reservoir is much lesser than the requirement for the mildly overpressure intermediate reservoir. Thus, a potential risk of severe losses and well control is present at shallow reservoir. To mitigate this risk, loss circulation material was pre-spotted in the TCP (Tubing conveyed perforation) BHA prior to fire the gun to allow for self-curing process should losses take place. During the first development campaign, the completion tubing was running in hole in two stages. The lower completion was deployed via drill pipe and the perforated zones was secured with fluid loss device located between lower completion tubing and gravel pack packer. The upper completion tubing was then deployed and tied back to the lower completion packer. This approach was applied as mitigation to prevent fluid losses and to ensure the tubing can be safely deployed to the intended final depth. However, based on the actual performance and losses rate data during the first campaign, the completion design in second campaign was optimized and deployed in single stage. Since shallow and intermediate reservoir were combined in multiple production zones where five SSD (Sliding Side Door) were installed, the slickline option
根据2017年第一次开发活动的生产数据,在一年的生产中,产气井的CO2和H2S污染读数分别从3%增加到10%,从3ppm增加到16ppm。这些发现引发了2019年开发活动优化策略的重新审视,包括材料选择、井数、储层目标和完井设计。因此,油管上部的材料升级为HP1-13CR,最高可达10,000 ft-MDDF(英尺测量深度的钻井平台),以避免由于静地不受干扰的温度低于80℃而产生的SSC风险,但根据2017年的活动,深层油管的材料仍为13CR-L80。此外,根据2018年8月进行的汞测绘工作,观察到第一次活动的汞含量高于中间水库的阈值限制。由于地面设施没有安装除汞系统,因此在2019年的测试过程中,需要密切监测井中的汞读数,以便在记录的污染物读数过高时采取适当的措施。如果记录到混合区(总)汞读数高于阈值限制,将执行专门的分区采样计划,并关闭该区域以保护地面设施。通过在一次选择性完井中完成浅段和中间段,优化井数,以最大化项目价值。然而,由于每个射孔油藏的储层压力和渗透率对比差异巨大,这种组合在作业过程中会带来重大挑战,因为浅层油藏所需的完井盐水过平衡压力远低于中度超压油藏的要求。因此,浅层油藏存在严重漏失和井控的潜在风险。为了降低这种风险,在射孔枪发射之前,在TCP(油管输送射孔)底部钻具组合中预先定位了漏失循环材料,以便在发生漏失时进行自固化。在第一次开发过程中,完井油管分两个阶段下入井中。下部完井通过钻杆下入,在下部完井油管和砾石封隔器之间使用降滤失装置对射孔区域进行保护。然后下入上部完井油管,并与下部完井封隔器连接。该方法用于缓解流体漏失,并确保油管可以安全地下入到预期的最终深度。然而,根据第一次作业的实际性能和损失率数据,对第二次作业的完井设计进行了优化,并进行了单级部署。由于浅层和中层储层位于多个生产区域,并且安装了5个SSD(滑动侧门),因此由于在深井中存在坐封油管塞的风险,因此放弃了坐封封隔器的钢丝绳选择。泵出桥塞被认为是一种选择,但由于高静水压力而放弃。封隔器坐封压力与桥塞剪切压力太接近。因此,采用了一种自动消失的桥塞,因为它不需要任何钢丝干预,而且可以通过压力循环破裂。采用这种方法,可以消除桥塞过早破裂的风险。本文将详细讨论上述每个挑战,以及在选择最佳解决方案之前,在整个评估和选择过程中进行的详细计算,因为这些优化节省了近三天的钻机时间,降低了2.6%的井成本,并且所需的井数被优化为3口而不是4口。此外,通过选择合适的油管材料,消除产汞超过上述阈值限制的风险,可以提高油井的生产寿命。
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引用次数: 0
Precise Cement Displacement with a New Cement Plug Tracking Method 一种新的水泥塞跟踪方法的精确水泥置换
Pub Date : 2021-10-04 DOI: 10.2118/205691-ms
A. Kabannik, R. Korkin, D. Demidov, Andrey O. Fedorov, Aleksandra Khudorozhkova, Micaela Nieczkoski
During the primary well cementing operation, when the cement slurry is pumped into the annulus around the outside of the casing string, it is very critical not to over displace and let the displacement fluid enter the annulus. Traditionally, to determine when to stop the cement displacement operation, the top cement plug position is tracked volumetrically by dividing the displaced volume by the casing internal cross-sectional area. However, the volumetric method is prone to uncertainties related to displacement fluid compressibility, high-pressure pump inefficiency, flowmeter inaccuracy, and variance in casing joint diameters. The new cost-effective cement displacement monitoring method is based on the analysis of the pressure pulses generated by the top cement plug passing the casing. These pressure pulses are detected by the standard pressure transducer installed at the cementing head. When correlated with the casing tally, these pulses identify the plug position related to the completion elements that provide better accuracy than the volumetric method used conventionally. The case studies include the successful cement displacement monitoring example and the case where the plug was prematurely stopped 90 meters above the landing collar, which was revealed by the subsequent drilling and confirmed independently by the new plug tracking method.
在第一次固井作业中,当将水泥浆泵入套管柱外部的环空时,至关重要的是不要过度置换,以免置换液进入环空。传统上,为了确定何时停止水泥顶替作业,通过将顶替体积除以套管内部截面积来跟踪顶部水泥塞的位置。然而,容积法容易存在与驱油流体可压缩性、高压泵效率低下、流量计不准确以及套管接头直径变化等相关的不确定性。新的水泥位移监测方法是基于分析顶部水泥塞通过套管时产生的压力脉冲。这些压力脉冲由安装在固井头的标准压力传感器检测。当与套管计数相关联时,这些脉冲识别出与完井元件相关的桥塞位置,比传统的体积法提供更高的精度。案例研究包括成功的水泥位移监测案例,以及桥塞过早停在离接箍90米处的案例,这是后续钻井发现的,并由新的桥塞跟踪方法独立确认。
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引用次数: 0
Kedung Keris Full Well Stream Pipeline Fiber Optic Leak Detection System Kedung Keris全井流管道光纤泄漏检测系统
Pub Date : 2021-10-04 DOI: 10.2118/205776-ms
C. Chairunissa, D. K. Amanu, G. Astari, Eska Indrayana
Kedung Keris (KK) is a sour oil field based in Cepu Block, Indonesia. KK field was originally planned to have a processing facility with separate pipelines to deliver crude & produced water, while the gas was planned to be flared. To reduce cost, this concept was changed to a wellpad with full well stream pipeline with new technology of Fiber Optic Leak Detection Sensing System (LDSS) as a key enabler. The fiber optic LDSS functions by leveraging fiber optic cable attached to the pipeline to detect leak as well as intrusion to the pipeline's Right-of-Way through real-time analysis of physical characteristics of a leak and intrusion, such as changes in temperature, pressure, ground strain and acoustics. The implementation of LDSS, together with other safeguards built into the pipeline design, operations and maintenance, allowed the KK Project to eliminate the separation facility at KK wellpad and an additional water pipeline. It also reduces the flaring by billions of standard cubic feet of gas cumulative until end of PSC life as originally all gas planned to be flared. The change of KK Project concept altogether yielded tens of millions of US dollar gross cost savings (~30% of CAPEX + OPEX reduction) following the KK startup in late 2019. The installed LDSS proven to detect leak for up to few meters location accuracy and has intrusion detection capability. KK Project has pioneered the implementation of fiber optic leak detection system for Indonesia oil and gas companies. This work provided further insight to the utilization of such technology in full well stream pipeline where traditional leak detection system implementation will not be acceptable. Consecutively, full well stream pipeline deployment can lead to future CAPEX + OPEX efficiency in facility project design and operation, as well as flaring reduction opportunity.
Kedung Keris (KK)是印度尼西亚Cepu区块的一个含硫油田。KK油田最初计划有一个处理设施,有单独的管道来输送原油和采出水,而天然气则计划燃烧。为了降低成本,这一概念被转变为具有全井流管道的井垫,并以光纤泄漏检测传感系统(LDSS)的新技术作为关键推动因素。光纤LDSS的功能是利用连接在管道上的光纤电缆,通过实时分析泄漏和侵入的物理特征,如温度、压力、地面应变和声学的变化,来检测泄漏和侵入管道的权利。LDSS的实施,以及在管道设计、操作和维护中内置的其他保障措施,使KK项目省去了KK井场的分离设施和额外的输水管道。它还减少了数十亿标准立方英尺的天然气累积燃烧,直到PSC寿命结束,因为最初所有的天然气都计划燃烧。在2019年底启动KK项目后,KK项目概念的改变总共节省了数千万美元的总成本(约30%的资本支出+运营支出减少)。已安装的LDSS已被证明可以检测泄漏,定位精度可达几米,并具有入侵检测能力。KK项目率先为印尼石油和天然气公司实施光纤泄漏检测系统。这项工作为这种技术在全井流管道中的应用提供了进一步的见解,传统的泄漏检测系统实施将无法接受。连续地,全井流管道的部署可以提高设施项目设计和运营的CAPEX + OPEX效率,以及减少燃除的机会。
{"title":"Kedung Keris Full Well Stream Pipeline Fiber Optic Leak Detection System","authors":"C. Chairunissa, D. K. Amanu, G. Astari, Eska Indrayana","doi":"10.2118/205776-ms","DOIUrl":"https://doi.org/10.2118/205776-ms","url":null,"abstract":"\u0000 Kedung Keris (KK) is a sour oil field based in Cepu Block, Indonesia. KK field was originally planned to have a processing facility with separate pipelines to deliver crude & produced water, while the gas was planned to be flared. To reduce cost, this concept was changed to a wellpad with full well stream pipeline with new technology of Fiber Optic Leak Detection Sensing System (LDSS) as a key enabler.\u0000 The fiber optic LDSS functions by leveraging fiber optic cable attached to the pipeline to detect leak as well as intrusion to the pipeline's Right-of-Way through real-time analysis of physical characteristics of a leak and intrusion, such as changes in temperature, pressure, ground strain and acoustics.\u0000 The implementation of LDSS, together with other safeguards built into the pipeline design, operations and maintenance, allowed the KK Project to eliminate the separation facility at KK wellpad and an additional water pipeline. It also reduces the flaring by billions of standard cubic feet of gas cumulative until end of PSC life as originally all gas planned to be flared. The change of KK Project concept altogether yielded tens of millions of US dollar gross cost savings (~30% of CAPEX + OPEX reduction) following the KK startup in late 2019. The installed LDSS proven to detect leak for up to few meters location accuracy and has intrusion detection capability. KK Project has pioneered the implementation of fiber optic leak detection system for Indonesia oil and gas companies. This work provided further insight to the utilization of such technology in full well stream pipeline where traditional leak detection system implementation will not be acceptable. Consecutively, full well stream pipeline deployment can lead to future CAPEX + OPEX efficiency in facility project design and operation, as well as flaring reduction opportunity.","PeriodicalId":11017,"journal":{"name":"Day 2 Wed, October 13, 2021","volume":"33 3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90451642","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
引用次数: 0
Additive Scale Removal Based on Noncorrosive Organic Acid for Handling Silica and Carbonate Scale in Oil and Gas and Geothermal Wells 基于无腐蚀性有机酸的添加剂除垢法处理油气井和地热井中二氧化硅和碳酸盐结垢
Pub Date : 2021-10-04 DOI: 10.2118/205739-ms
U. Pasarai, S. PancaWahyudi, A. Haans, I. Widiantara, Budi Saroyo
The silica and carbonate scale that forms along the production pipeline is a significant problem in the oil and gas and geothermal industry because it disrupts production operations. Silica and carbonate scales on the inside of the pipe cause blockage of flow and an increase in pressure. Failure of downhole settlement equipment will reduce the production capacity of the well, and the maintenance burden will increase. The main objective of this research is to test the reactivity of an environmentally friendly non-corrosive organic acid system based on vegetable fatty acids and carbohydrates with high dissolution efficiency for the treatment of silica and carbonate scales in geothermal and oil and gas fields. This paper provides information on laboratory analysis in terms of analysis of the composition of scale samples obtained through XRD analysis, acid system developed testing for dissolution efficiency at 50°C and 100°C for 1 hour, compatibility and stability testing, and testing the corrosive impact on coupon metal AISI CS-1019 samples at 100°C for seven days in a closed aging cell. Testing the concentration of the new organic acid system in high dissolution efficiency and low corrosion effect was carried out through laboratory-scale studies before being applied to field-scale operations. The results showed that the dissolution efficiency of the scale sample against the developed organic acid system (100% concentration) at 50 and 100°C for 1 hour showed reactive effect. Reduction rate of silicate-07; silicate-29; silicate-L1; silicate-KB1; carbonate-A3 at 50°C were 7.825%; 3.823%; 6.177%; 2.014%; 8.211%, and at 100°C were 12.884%; 0.631%; 15.047%; 0.103%; and 32.909%. The newly developed organic acid system demonstrates stability and compatibility with formation waters with low formed solids, and it has a pH of 6. The results of the corrosion rate test were carried out without an inhibitor at 100°C for seven days and gave a yield of 77.340 mils per year, while other commercial additives gave a yield of 2,525.120 mils per year. The new eco-friendly organic acid system has a good effect in helping dissolve silica and carbonate scales, safe for production equipment, and lowers high maintenance costs. Keywords: Organic Acid Scale Remover, Silica and Carbonate Scale, Environmentally friendly
在油气和地热行业中,沿生产管道形成的二氧化硅和碳酸盐结垢是一个严重的问题,因为它会破坏生产作业。管道内部的二氧化硅和碳酸盐结垢会导致流体堵塞和压力增加。井下沉降设备的故障会降低油井的生产能力,增加维修负担。本研究的主要目的是测试一种基于植物脂肪酸和碳水化合物的环保型无腐蚀性有机酸体系的反应性,该体系具有高溶解效率,用于处理地热和油气田中的二氧化硅和碳酸盐结垢。本文提供了实验室分析方面的信息,包括通过XRD分析获得的水垢样品的组成,开发的酸体系在50°C和100°C下1小时溶解效率测试,相容性和稳定性测试,以及在封闭老化槽中在100°C下7天对残余金属AISI CS-1019样品的腐蚀影响测试。在应用于现场作业之前,通过实验室规模的研究测试了新型有机酸体系在高溶解效率和低腐蚀效应方面的浓度。结果表明,在50℃和100℃条件下,水垢样品对所制备的有机酸体系(100%浓度)的溶解效率均为反应性效果。硅酸盐-07的还原率;silicate-29;silicate-L1;silicate-KB1;50℃时碳酸盐- a3为7.825%;3.823%;6.177%;2.014%;8.211%, 100℃时为12.884%;0.631%;15.047%;0.103%;和32.909%。新开发的有机酸体系具有稳定性和与低固相地层水的相容性,pH值为6。在不添加缓蚀剂的情况下,在100℃下进行了7天的腐蚀速率测试,结果表明,缓蚀剂的收率为每年77.340 mils,而其他商业添加剂的收率为每年2525.120 mils。新型环保型有机酸体系具有良好的溶解二氧化硅和碳酸盐垢的效果,对生产设备安全,降低了高昂的维护成本。关键词:有机酸除垢剂,二氧化硅和碳酸盐结垢,环保型
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引用次数: 0
Improves Sucker Rod and Tubing Lifetime Applying the Wear Predict 99 Equation 应用磨损预测99方程提高抽油杆和油管寿命
Pub Date : 2021-10-04 DOI: 10.2118/205670-ms
T. Hidayat, F. Kurniawan, Jalu Waskito Aji Nugroho, A. Wibowo, P. I. Amal, Sebastianus Riskadarto
Finding new oil and gas that can be developed economically is getting more difficult and challenging today. To meet the oil and gas demand, it is therefore important to focus on the existing and already developed assets by applying new and more efficient technology and optimizing the use of existing equipment to increase production performance of the asset thus better recovery. Sangasanga Field as mature oil field of Pertamina EP is producing its oil by the assistance of artificial lift. The artificial lifts applied in Sangasanga field are Sucker Rod Pump (SRP), Electrical Submersible Pump (ESP) and Hydraulic Pumping Unit (HPU) where SRP dominates with 84 units installed while ESP and HPU are 25 units and 15 units respectively. According to the data of well service work history from 2018 to 2020, the failure of SRP and HPU was quite high. The main problem observed were the occurrence of leaking tubing and broken sucker rods. The study gathered the occurrence of failure and a method so called "WEAR PREDICT 99" was created to estimate SRP's buckling point and lifetime. WEAR PREDICT 99 is a correlation derived from comparing neutral point calculated from formula with actual leak data of broken pipe or suction rod. The correlation then used for predicting the buckling point that represents the probable location of the leaking pipe or damaged suction rod. This correlation allows to predict when and where the sucker rod will leak or break, therefore preventive measures to increase the lifetime of the SRP and HPU wells can be taken.
如今,寻找可以经济开发的新石油和天然气变得越来越困难和具有挑战性。因此,为了满足油气需求,重点关注现有和已经开发的资产,应用新的、更高效的技术,优化现有设备的使用,以提高资产的生产性能,从而提高采收率。作为Pertamina EP的成熟油田,Sangasanga油田正在利用人工举升技术进行采油。Sangasanga油田应用的人工举升主要有有杆泵(SRP)、电潜泵(ESP)和液压抽油机(HPU),其中SRP占主导地位,安装了84台,而ESP和HPU分别为25台和15台。根据2018年至2020年的井服工作历史数据,SRP和HPU的故障率相当高。观察到的主要问题是油管泄漏和抽油杆断裂。该研究收集了失效的发生情况,并创建了一种称为“磨损预测99”的方法来估计SRP的屈曲点和寿命。磨损预测99是将公式计算的中性点与破裂管道或抽油杆的实际泄漏数据进行比较得出的相关性。然后用这种相关性来预测屈曲点,该屈曲点代表泄漏管道或损坏吸油杆的可能位置。这种相关性可以预测抽油杆何时何地会泄漏或断裂,因此可以采取预防措施来延长SRP和HPU井的使用寿命。
{"title":"Improves Sucker Rod and Tubing Lifetime Applying the Wear Predict 99 Equation","authors":"T. Hidayat, F. Kurniawan, Jalu Waskito Aji Nugroho, A. Wibowo, P. I. Amal, Sebastianus Riskadarto","doi":"10.2118/205670-ms","DOIUrl":"https://doi.org/10.2118/205670-ms","url":null,"abstract":"\u0000 Finding new oil and gas that can be developed economically is getting more difficult and challenging today. To meet the oil and gas demand, it is therefore important to focus on the existing and already developed assets by applying new and more efficient technology and optimizing the use of existing equipment to increase production performance of the asset thus better recovery.\u0000 Sangasanga Field as mature oil field of Pertamina EP is producing its oil by the assistance of artificial lift. The artificial lifts applied in Sangasanga field are Sucker Rod Pump (SRP), Electrical Submersible Pump (ESP) and Hydraulic Pumping Unit (HPU) where SRP dominates with 84 units installed while ESP and HPU are 25 units and 15 units respectively.\u0000 According to the data of well service work history from 2018 to 2020, the failure of SRP and HPU was quite high. The main problem observed were the occurrence of leaking tubing and broken sucker rods. The study gathered the occurrence of failure and a method so called \"WEAR PREDICT 99\" was created to estimate SRP's buckling point and lifetime.\u0000 WEAR PREDICT 99 is a correlation derived from comparing neutral point calculated from formula with actual leak data of broken pipe or suction rod. The correlation then used for predicting the buckling point that represents the probable location of the leaking pipe or damaged suction rod.\u0000 This correlation allows to predict when and where the sucker rod will leak or break, therefore preventive measures to increase the lifetime of the SRP and HPU wells can be taken.","PeriodicalId":11017,"journal":{"name":"Day 2 Wed, October 13, 2021","volume":"26 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89747788","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
引用次数: 0
Successful Lifting of Oil with High Concentration of Hydrogen Sulfide by Artificial Lift System – Case Study 人工举升系统成功举升高浓度硫化氢油-案例分析
Pub Date : 2021-10-04 DOI: 10.2118/205732-ms
Abid Rehman, M. Abdelbary
Due to the low cost of crude oil, it is highly unusual for the operators to drill exploration wells, for the past few years. Adding that as well to the world's economy collapse due to the pandemic at the start of 2020, it is now more than ever a necessity to use artificial lift methods to lift from previously shut-in wells or maximize current production of the wells, as to grapple with the running expenses of operators. The artificial lift is a vast field with different lift methods applicable to a single well. Hence, the selection of an optimum lift method is critical. During the worst economic slump, the economic analysis will play a decisive role in the application of an artificial lift system (ALS) along with a technical review. The jet pump system is one of the most reliable artificial lift systems for lifting shut-in wells. The installation time of this system is minimal, and production starts right away. However, the system can prove to be very expensive, if the design is not done critically. This paper is about lifting a well that was not able to flow naturally. The vertical well B3 located in northern Iraq was drilled in May 2018 to a total depth of 521 meters. But the well was not able to flow naturally, and the jet pump was designed for the well based on well completion, downhole pressures, temperature and reservoir fluid properties. The evaluation and design of the downhole jet pump and surface pumping unit requirements were performed on Jet Pump Evaluation and Modeling Software. This well produced approximately 1700 BOPD. Since, the well was not flowing before the installation of the jet pump, most of the production data was obtained after deployment of ALS and production was optimized accordingly. The production had a high content of Hydrogen Sulfide as well, which was treated accordingly for safety of personnel, equipment, flow lines and environment. This paper describes the details about the application, optimization and operation of the jet pump system deployed on inactive wells with a high concentration of sour gas.
由于原油成本较低,在过去的几年里,运营商很少钻探井。再加上2020年初全球大流行导致的世界经济崩溃,为了应对运营商的运营费用,现在比以往任何时候都更有必要使用人工举升方法从先前关闭的井中举升或最大化当前井的产量。人工举升是一个广阔的领域,单井举升方式不同。因此,选择最佳举升方法至关重要。在经济最不景气的情况下,经济分析和技术审查将对人工举升系统(ALS)的应用起决定性作用。喷射泵系统是关井举升最可靠的人工举升系统之一。该系统的安装时间非常短,可以立即开始生产。然而,如果设计不严谨,该系统可能会非常昂贵。这篇论文是关于提升一口不能自然流动的井。位于伊拉克北部的B3直井于2018年5月钻探,总深度为521米。但由于该井无法实现自然流动,因此根据完井情况、井下压力、温度和储层流体性质等因素设计了喷射泵。利用喷射泵评估与建模软件对井下喷射泵和地面抽油机的需求进行评估与设计。该井的产量约为1700桶/天。由于在安装喷射泵之前,该井没有流动,因此大部分生产数据是在部署ALS之后获得的,并相应地优化了生产。该产品硫化氢含量也很高,为了人员、设备、管线和环境的安全,需要进行相应的处理。本文详细介绍了喷射泵系统在高浓度含酸气井中的应用、优化和运行情况。
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引用次数: 0
Application of Due Diligence Audit for Value Creation: Case Study from Gas PSC of Malaysia 尽职调查审计在价值创造中的应用——以马来西亚天然气公司为例
Pub Date : 2021-10-04 DOI: 10.2118/205714-ms
A. Sinha, Hue Teng Lim
As resource owner of all hydrocarbon assets of Malaysia, Petroliam Nasional Berhad (PETRONAS) through Malaysia Petroleum Management (MPM) is responsible for providing asset integrity assurance, maintaining producing assets in safe and operable conditions and ensuring compliance to data management by Petroleum Agreement Contractors (PACs). For mature fields nearing expiry of production sharing contracts (PSCs), it is even more critical to safeguard the integrity of petroleum facilities and to conduct an inventory check of acquired data during transition from existing to new PACs. A Due Diligence Audit (DDA) provides an important milestone to benchmark the health of existing assets (subsurface and surface) and outlining roadmap for future development opportunities for the PSC fields. This paper presents key technical results and value creation areas from the DDA conducted for one of the largest gas field PSC in Malaysia. This gas PSC consisted of multiple gas fields and production hubs catering to a majority of gas production in the region. Although the fields had been in production for more than 20 years, maintaining production plateau rate and optimizing operating cost were identified as key concerns for long term sustainability. New development opportunities were also needed to mitigate the same. For existing fields, incremental recovery projects focused on lowering the abandonment pressure are planned. To maximize the utilization of gas processing capacity in production hubs, nearby gas fields have also been identified for cluster development and evacuation. Assurance on long-term gas supply is targeted through fast pace exploration in the early years of new PSCs to discover new gas development areas and to further increase the operating life of these hubs. As ageing assets, each of the fields also faced unique challenges such as liquid handling, subsidence issues and increasing inventory of idle wells. Through successful application of the DDA framework, a detailed technical assessment of deliverables was conducted along with liability management to address these asset integrity risks. With the successful completion of DDA for these fields, the technical assessment deliverables have created significant PSC value by securing identified opportunities under minimum work commitments. In addition, it facilitated a roadmap for idle wells management plan and new technology in "Implement Replicate" phasing. This has helped PETRONAS to further monetize opportunities in ageing assets, and safeguard producing hubs for long-term gas supply. This paper presents an efficient Due Diligence Audit workflow for long term value creation in mature fields and assets.
作为马来西亚所有碳氢化合物资产的资源所有者,马来西亚国家石油公司(PETRONAS)通过马来西亚石油管理公司(MPM)负责提供资产完整性保证,维护生产资产处于安全和可操作状态,并确保遵守石油协议承包商(pac)的数据管理。对于即将到期的生产分成合同(psc)的成熟油田,在从现有pac过渡到新的pac期间,保护石油设施的完整性并对获取的数据进行盘点就更加重要了。尽职调查审计(DDA)提供了一个重要的里程碑,可以对现有资产(地下和地面)的健康状况进行基准测试,并为PSC油田的未来发展机会制定路线图。本文介绍了马来西亚最大的天然气田PSC之一进行的DDA的关键技术成果和价值创造领域。该天然气PSC由多个气田和生产中心组成,满足了该地区的大部分天然气生产。尽管该油田已经投产20多年,但保持生产平台率和优化运营成本是长期可持续发展的关键问题。还需要新的发展机会来缓解这种情况。对于现有油田,计划进行以降低放弃压力为重点的增量采收率项目。为了最大限度地利用生产中心的天然气处理能力,附近的气田也被确定为集群开发和疏散。通过在新psc的早期快速勘探,以发现新的天然气开发区域,并进一步延长这些枢纽的使用寿命,确保长期的天然气供应。随着资产的老化,每个油田都面临着独特的挑战,如液体处理、下沉问题和闲置井库存的增加。通过成功应用DDA框架,对可交付成果进行了详细的技术评估,并进行了负债管理,以解决这些资产完整性风险。随着这些领域DDA的成功完成,技术评估成果通过在最小的工作承诺下确保确定的机会,创造了重要的PSC价值。此外,它还为闲置井管理计划和“实施复制”阶段的新技术制定了路线图。这有助于马来西亚国家石油公司进一步从老化资产中获利,并保护生产中心的长期天然气供应。本文介绍了一种有效的尽职调查审计工作流程,用于成熟油田和资产的长期价值创造。
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引用次数: 0
New Digital Well Construction Planning Solution: Improving Efficiency & Quality of Well Design through Collaboration and Automation 新的数字井建设规划解决方案:通过协作和自动化提高井设计的效率和质量
Pub Date : 2021-10-04 DOI: 10.2118/205701-ms
H. Suryadi, Haifeng Li, Diego Medina, Alex Celis
Drilling wells with minimum risk and optimizing well placement with the least possible cost are key goals that companies strive to achieve. The major contributor to the successful execution of the well is the quality of the drilling program. Well design is a complex process, which requires full collaboration of multiple domain roles & expertise working together to integrate various well-planning data. Many design challenges will be encountered, such as risk assessments, domain-specific workflows, geological concerns, technology selections, cost & time estimation, environmental and safety concerns. Design process efficiency depends on effective communication between parties, quickly adapting to any changes, reducing the number of changes, and reducing complicated & manual processes. Current existing workflow and tools are not promoting an excellent collaborative environment among the different roles involved. Engineers utilize multiple engineering applications, which involved many manual data transfers and inputs. The different party is still working in a silo and sharing the design via email or other manual data transfer. Any changes to the design cause manual rework, leading to inconsistency, incoherency, slow decision & optimization process, and failure to identify all potential risks, increasing the well planning time. The new digital planning solution based on cloud technology allows the design team to maximize the results by giving them access to all the data and science they need in a single, standard system. It's a radical new way of working that gives engineers quicker and better-quality drilling programs by automating repetitive tasks and validation workflows to ensure the entire plan is coherent. This new planning solution allows multiple roles & domain collaboration to break down silos, increase team productivity through tasks assignment, and share all data. An automated trajectory design changes the way engineers design trajectory from manually connecting the path from a surface location to the target reservoir location to automatically calculate & propose multiple options with various KPIs allowing the engineer to select the best trajectory option. The system reinforces drilling program quality through auto engineering analysis, which provides quick feedback for any design changes and provides an integrated workflow from the trajectory design to operational activity planning and AFE. The automation of repetitive tasks, such as multiple manual inputs, frees domain experts to have more time to focus on creating new engineering insights while still maintaining design traceability to review updates over the life of the projects and see how the design changes have optimized the drilling program. This new solution solves some of the significant challenges in the current well-planning workflow.
以最小的风险钻井和以最低的成本优化井位是各公司努力实现的关键目标。钻井计划的质量是成功钻井的主要因素。井设计是一个复杂的过程,需要多个领域的角色和专业知识的充分协作,共同整合各种井规划数据。许多设计挑战将会遇到,如风险评估、特定领域的工作流程、地质问题、技术选择、成本和时间估计、环境和安全问题。设计流程的效率取决于各方之间的有效沟通,快速适应任何变化,减少变化的数量,减少复杂的手工流程。当前现有的工作流和工具并没有在涉及的不同角色之间促进良好的协作环境。工程师利用多种工程应用程序,其中涉及许多手动数据传输和输入。另一方仍在各自工作,并通过电子邮件或其他手动数据传输共享设计。对设计的任何更改都会导致人工返工,导致不一致、不连贯、决策和优化过程缓慢,无法识别所有潜在风险,从而增加了井计划时间。新的基于云技术的数字规划解决方案使设计团队能够在一个单一的标准系统中访问所需的所有数据和科学,从而最大限度地提高结果。这是一种全新的工作方式,通过自动化重复任务和验证工作流程,确保整个计划的一致性,为工程师提供了更快、更高质量的钻井计划。这个新的规划解决方案允许多个角色和领域协作来打破孤岛,通过任务分配提高团队生产力,并共享所有数据。自动化轨迹设计改变了工程师设计轨迹的方式,从手动连接地面位置到目标储层位置的路径,到自动计算并提出具有各种kpi的多个选项,从而使工程师能够选择最佳轨迹选项。该系统通过自动工程分析来提高钻井程序的质量,为任何设计更改提供快速反馈,并提供从轨迹设计到作业活动计划和AFE的集成工作流程。重复任务的自动化,如多次人工输入,使领域专家有更多的时间专注于创造新的工程见解,同时保持设计可追溯性,以审查项目生命周期内的更新,并查看设计更改如何优化钻井计划。这种新的解决方案解决了当前井计划工作流程中的一些重大挑战。
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引用次数: 0
Viscous Crude Oil Production Facilitated by Flow Improver Technology: A Holistic Chemical Approach with Successful Field Application 流动改善技术促进稠油开采:一种成功应用于油田的整体化学方法
Pub Date : 2021-10-04 DOI: 10.2118/205570-ms
J. A. Mcrae, Bianca Daniela Covarrubias Rosas
This paper describes the approach taken to evaluate and successfully treat flow assurance challenges associated to high viscosity produced fluids in an oil producing field, offshore Gulf of Mexico. The first section of the paper outlines primary evaluation criteria: discussing base line modeling of crude oil characteristics at various points of the production system, laboratory analyses, detailed explanation of the chemistries considered for reducing the viscosity, and the strategy to remediate multiple flow assurance challenges with subsequent performance testing. The second section presents field trial data from the application of the selected flow improver and its longer-term performance. Initial evaluation of high viscosity was required due to deposition of asphaltene, high levels of emulsion, increased pressure and resultant decrease in production All of these production issues caused increased spending on fluids treatment in a field that is mature and becoming more marginal to produce. Initial analysis of the produced fluid did not result in an immediate, clear approach to address the concern, without considering the multiple factors that can contribute to flow assurance challenges. Organic deposition, such as waxes and asphaltenes, were found to increase fluid viscosity and worsen highly stabilized emulsions. Crude oil/water emulsions also cause increased viscosity and needed to be addressed as part of any holistic solution. Each issue was studied and experimented on its own and in combination to ensure there was no reductive effect in a final chemical application that needed to treat them all. Successful field application of the selected flow improver technology exceeded the performance at laboratory scale achieving over 30% reduction in total fluid viscosity over long-term field deployment with associated benefits to the offshore operator which will be elaborated further in this paper. As an outcome of this field trial, this paper also presents a proposed generic approach in devising chemical solutions for treatment of high viscosity fluids.
本文介绍了墨西哥湾近海某油田高粘度采出液流动保障问题的评估和成功处理方法。论文的第一部分概述了主要的评估标准:讨论了生产系统各点原油特性的基线建模、实验室分析、降低粘度的化学物质的详细解释,以及在随后的性能测试中解决多重流动保证挑战的策略。第二部分介绍了所选流量改进剂的现场试验数据及其长期性能。由于沥青质沉积、高水平的乳化液、压力升高以及由此导致的产量下降,需要对高粘度进行初步评估。所有这些生产问题都导致了成熟油田的流体处理支出增加,且产量越来越小。对产出液的初步分析并没有立即得出解决问题的明确方法,也没有考虑到可能导致流动保障挑战的多种因素。有机沉积,如蜡和沥青质,会增加流体粘度,使高度稳定的乳剂变差。原油/水乳液也会导致粘度增加,需要作为整体解决方案的一部分加以解决。每个问题都被单独研究和实验,以确保在需要处理所有问题的最终化学应用中没有还原作用。选定的流动改进剂技术的成功现场应用超过了实验室规模的性能,在长期的现场部署中,总流体粘度降低了30%以上,并为海上运营商带来了相关的好处,这将在本文中进一步阐述。作为现场试验的结果,本文还提出了设计处理高粘度流体的化学溶液的通用方法。
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引用次数: 0
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