Day 3 Fri, October 18, 2019最新文献

{"title":"Successfully Navigating the Narrow Pressure Window in an HPHT Offshore Well","authors":"L. Devadass, Sasha Syrapushchynski, Jené Rockwood","doi":"10.2118/198407-ms","DOIUrl":"https://doi.org/10.2118/198407-ms","url":null,"abstract":"\u0000 While the main objective for Well #1 was to appraise the hydrocarbon potential at depths below a known gas reservoir, the operator was able to drill a high-pressure, high-temperature (HPHT) reservoir section with a mud density of 18.4-lb/gal (2.2 sg) with zero fluid losses. The highly deviated appraised interval had both very low and extremely high pore pressures, with the maximum overbalance of approximately 6,800 psi(46,900 kPa).\u0000 Compared to offset appraisal wells, downhole losses, hole instability, differentially stuck pipe and well control issues were avoided through the adoption of a low-invasion synthetic fluid system designed with wellbore shielding technology. During the planning phase, the operator conducted extensive laboratory testing to assure technical performance, as well as cost reductions, were achieved by optimizing the drilling fluid design. Best practices from previous HPHT wells were carefully studied and replicated to ensure the success of the well.\u0000 Wellbore stability was achieved and the 8½-in. hole section was drilled into the targeted formation tops. In the reservoir hole section, the mud weight was increased to 18.4-lb/gal (2.2 sg) in order to compensate for high pore pressures up to 14,000 psi (96,500 kPa); the highest overbalanced pressure measured was 6,800 psi (46,900 kPa) due to the low pore pressure in the sands above. The drilling fluid was designed with wellbore shielding technology to create an impermeable barrier across low-pressure zones and minimize pressure transmission from high mud density. The rheological properties of the drilling fluid were monitored along with maintaining a thin filter cake and low solids content.\u0000 Operational issues and challenges to drilling exploration wells in HPHT environments with high differential pressures continue to be an ongoing industry concern. The drilling fluid design used in this well shows great potential to eliminate drilling hazards in tough downhole conditions.","PeriodicalId":406524,"journal":{"name":"Day 3 Fri, October 18, 2019","volume":"76 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126200402","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}

{"title":"The Results Implementation of a Set of Measures to Enhance the Production Efficiency of High-Viscosity Oil","authors":"A. A. Isaev, M. M. Aliev, R. Takhautdinov, V. I. Malykhin, A. A. Sharifullin","doi":"10.2118/198416-ms","DOIUrl":"https://doi.org/10.2118/198416-ms","url":null,"abstract":"\u0000 It was shown in [1] that the directional structure of the wellbore profile is one of the factors complicating the operation of the wells with the PCP units.\u0000 It was found that the maximum inclination angle of the well in a certain way reduces the MTBF of the rods. The maximum inclination angles of the wells with the known operating time in millions of cycles (revolutions) that had experienced rod failures have been calculated with the help of dipmeter logs of the group of directional wells.\u0000 The analyzed group includes PCP units with the number of pump shaft revolutions: Up to 100 min-1; 100…200 min-1; 200…300 min-1; 300…400 min-1.","PeriodicalId":406524,"journal":{"name":"Day 3 Fri, October 18, 2019","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125240126","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}

{"title":"Development of Novel Methods and Devices for Measuring the Total Gas-Oil Ratio, Oil and Water Production Rates and Fluid Viscosity","authors":"A. A. Isaev, R. Takhautdinov, V. I. Malykhin, A. A. Sharifullin","doi":"10.2118/198421-ms","DOIUrl":"https://doi.org/10.2118/198421-ms","url":null,"abstract":"\u0000 The production of associated petroleum gas in the Russian Federation is the most important component of the country's energy supply. Natural gas consumption is increasing annually, both in Russia and in other countries. For example, gas consumption in Europe in the first quarter of 2018 has reached its peak level for five years - 194.3 billion m3 [1]. The increase in exports of Russian natural gas to Germany by 12.4%, Austria - by 62.5%, to the Netherlands - by 80.5%, Croatia - by 2.5 times, China - by 36% is observed. It is a strategic task for oil and gas companies to account for the production of associated gas, because there is a discrepancy between the production of gas and the volume of the combusted part of the gas, which is primarily due to the lack of effective technologies for measuring the amount of gas, including gas-oil ratio. It is necessary to measure both the free gas phase released from the oil under the pressure at the oil sampling point and the residual amount of dissolved gas in the oil, as well.\u0000 The most appropriate and effective way to measure the total gas oil ratio is to measure it with portable devices. According to the Ruling Document (RD) [2], the measurement of the GOR at the wells must be carried out annually when the formation pressure is higher than the saturation pressure. The designers of gas factor measurement units are faced with the task of improving the quality of oil separation from gas under surface conditions and increasing the accuracy of GOR measuring. Measurement of oil, gas and water flow rates at oil production sites can be carried out by immobile or portable automated group metering stations.\u0000 A method is known to measure the flow rates of oil, gas and water that is based on determining the filling rates of two successive measuring vessels and their subsequent emptying [3]. The flow rate of the water-oil mixture is determined by the time of filling the vessels, and the flow rate of the gas phase is determined by the speed of emptying the vessels. Water cut of oil or water flow rate is determined by the difference of the reflection coefficient of electromagnetic waves along the height of the liquid column in the cylinder at the moment of its filling. The drawback of this method is that there are dispersed water and gas phases in the form of droplets and bubbles present in a liquid that fills the cylindrical vessel during measurements, which leads to a significant measurement error. In addition, a sufficient amount of dissolved associated gas remains in the oil phase, which does not escape from oil at the operating pressure (usually the pressure of the pressure manifold) and therefore cannot be taken into account in the calculations of the gas content in oil or the gas flow rate.","PeriodicalId":406524,"journal":{"name":"Day 3 Fri, October 18, 2019","volume":"20 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128070949","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}

{"title":"Development and Field Applications of Novel Oil-Based Mud in Western South China Sea","authors":"Yongbin Guo, Zhiqin Liu, S. Guan","doi":"10.2118/198404-ms","DOIUrl":"https://doi.org/10.2118/198404-ms","url":null,"abstract":"\u0000 The conventional oil-based mud used in the second member of Weizhou formation in Beibu Gulf Oilfield is of character of low oil-water ratio and electric voltage, which makes the water phase activity in mud unable to be adjusted during drilling operation to balance the water activity in collapse-prone formation, and causes the shale to hydrate and disperse. At the same time, the sealing material and mechanism are relatively simple, making it difficult to fill the irregular micro-crack in the collapse-prone formation, and downhole problem for wellbore instability, resulting in poor reservoir protection effect. In order to solve the aforementioned problems, the collapse mechanism of hard brittle gray mudstone in the second member of Weizhou formation was analyzed. The oil-water ratio was improved on the basis of the oil-based mud formula used in the collapse-prone formation of Weizhou formation in the early stage, and the electric voltage of mud was improved by the compoound emulsifier. Also with the optimization of composite particle size plugging materials and with compound plugging mechanism, a novel oil-based mud system was established. The performance evaluation shows that the optimized oil-based mud is of high oil-water ratio (95:5 or higher). The electric voltage is greater than 2000V, and the plastic viscosity is small (PV: 36-50) and less amount of filtration (1mL). The sealing pressure is outstanding (the compressive strength of mud cake is greater than 20MPa), and the water/soil pollution resistance is promising. In the aspect of reservoir protection effect, the reservoir core permeability recovery rate reaches 98.70%. Moreover, in the aspect of inhibition performance evaluation, the shale hot-rolling recovery rate is up to 99.10%. And the cuttings remain intact after a long period of soaking for rock samples. Field application shows that novel oil-based mud system can solve the problem of wellbore instability in the collapse-prone formation of the second member of Weizhou formation. The borehole remained stable, and the casing was run smoothly after drilling. At the same time, the reservoir protection effect is good, with production rate three times higher than estimation. The successful application of this system can effectively solve the problem of drilling and reservoir protection in the collapse-prone Weizhou formation of Beibu Gulf.","PeriodicalId":406524,"journal":{"name":"Day 3 Fri, October 18, 2019","volume":"6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127167921","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}

{"title":"APC for Wellhead Chokes to Optimize Plant Performance in Tengiz Field","authors":"Arman Tanzharikov, R. Cernik, Arman Shantayev","doi":"10.2118/198399-ms","DOIUrl":"https://doi.org/10.2118/198399-ms","url":null,"abstract":"\u0000 Tengizchevroil (TCO) has implemented Advanced Process Control (APC) to automatically control the feed into the plant by adjusting the chokes of selected wells in the field. The automated choke operations are closely monitored and thoroughly discussed during daily Field-Plant interface meetings to confirm overall stability of the plant performance and improvement in plant efficiency. With the use of a dynamic multivariable model-based controller we are now able to predict the demands from the production facility and automatically deliver the exact amount of field production to meet plant's ever-changing production capabilities while minimizing the pressure losses between the field and the operating plant.\u0000 The early APC deployments demonstrated the opportunity in delivering highly significant value to TCO. TCO had implemented numerous APC throughout the plants to optimize complicated processes and developed the necessary organizational capability (OC) to implement the Field APC. The Field APC project was the first joint project involving both the field and the plant assets. This APC project demonstrated the \"One TCO\" approach, with support and buy in from a cross functional team of Automation, Reservoir Management, Process Engineering and Plant Operations personnel.\u0000 TCO is now able to automatically react to changes in both the field and plant to deliver the maximum plant capacity at any given moment. Since plant throughput limitations are constantly changing due to changes in ambient temperature, H2S content or gas-oil ratio (GOR) of the inlet feed, etc.; the APC is automatically adjusting the output from the wells to match the inlet requirements of the plants. The solution uses dynamic models to predict constraints and drive operations to an economic optimum while honoring an everchanging set of constraints. The APC allows the plant and field operators to spend more time addressing non-routine problems by automating one of the operator's routine duties.","PeriodicalId":406524,"journal":{"name":"Day 3 Fri, October 18, 2019","volume":"100 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123786615","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}

{"title":"HSE Orientation Process - Green Hat","authors":"Aleksandra Krujalo, Ayaz Hasanguluyev","doi":"10.2118/198414-ms","DOIUrl":"https://doi.org/10.2118/198414-ms","url":null,"abstract":"\u0000 The main objective of the HSE Orientation process - Green Hat (hereinafter Green Hat) is ensuring the awareness of the new hires about the potential hazards at the worksites and increase their safety competency level based on the unique training program connected to the staff performance management and competency assurance systems.\u0000 The Green Hat program is comprised of theoretical and on-the-job training phases, which are aligned with the probation period of employees and lasts 3 months. The program covers specific HSE topics related to operations in the O&G services industry. New hires complete the practical part of the program under the supervision of the mentor. To ensure safety of operations, new hires must wear a green hard hat in order to stand out from experienced employees. Once new hires successfully graduate the program, they become eligible to wear a white hard hat and move into the ranks of the regular operations team.\u0000 The Green Hat program enables new hires to become fully operational and adapt to the company's Safety culture and HSE standards in the shortest period of time. In addition, the program has generated the following benefits since its application:\u0000 Educated employees about safety, including its theoretical and practical aspects, with strong on-the-job training components;\u0000 Raised awarness and knowledge of new hires about safety policies, instructions and procedures in the short period of time;\u0000 Developed new hires’ skills allowing them to become proactive in all HSE matters, asessed the risk level of potential hazards and implemented adequate preventive actions in their daily activities;\u0000 Reduced incidents of safety violations;\u0000 Minimized injuries to and caused by new hires;\u0000 Improved mentoring and the learning culture at the work sites;\u0000 Improved operational performance of the company by reducing NPT and LTI;\u0000 Enhanced corporate financial performance by sustaining a strong safety culture and minimizing injuries, accidents, operational losses, and NPTs.\u0000 Several external audits have revealed and confirmed the strong safety performance benefits of the Green Hat program. The robustness of the program has been attested successful by ISO 9001, ISO 45001, ISO 14001 certification audits of the company.\u0000 Training of new employees on safety topics, achieving their full application of the safety culture and rules of the company at the work sites, on time feedback and assessment of new hires will lead to reduction in the number of accidents and hazards driven by human factors. The Green Hat program presents a full- cycle, cost-effective and feasible HSE orientation system that can be successfully applied in the circumstances of relatively young company operating in developing economies.","PeriodicalId":406524,"journal":{"name":"Day 3 Fri, October 18, 2019","volume":"17 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122343190","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}

{"title":"Workflow of Oil Spill Estimation","authors":"E. Motaei, Dh Chen, R. Tewari, E. Mammadov, Jazael Ballina Ruvalcaba","doi":"10.2118/198406-ms","DOIUrl":"https://doi.org/10.2118/198406-ms","url":null,"abstract":"\u0000 Blowouts have catastrophic consequences and can potentially occur during any exploration or development projects. The situations that could lead to a blowout are underestimated pore pressure, rapid change in pressure, abnormal pressure or operation complexities such as complete fluid loss and thief zones. Blowouts are the most destructive and dangerous disaster in the oil and gas operations. Apart from causing fatalities and injuries, a blowout also causes ecological and environmental damages. While there is remedial work that can be done to manage the side effect of a blowout, an analysis has to be done to evaluate the extent of the damage. The oil spill analysis has to include all parameters and take into consideration all scenarios which would cater for the remedial work needed to address the aftermath of the blowout.\u0000 In this paper, the entire spill process beginning from the reservoir up to the surface is reviewed. The review covers the phenomenon involved in a spill process, the related HSE concerns, remedial work and spill modelling. The initial conditions, boundary conditions, and media transfer functions such as porous media properties, sand face and wellbore geometry are fully captured in the study and is reflected in the workflow. These parameters would affect the plume shape, size and geometry, blowout duration and oil spill volume estimation. The workflow presented in this paper is an effective technique for efficient decision making and remedial work in case of an oil spill resulting from an uncontrolled blowout.","PeriodicalId":406524,"journal":{"name":"Day 3 Fri, October 18, 2019","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116195237","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}

{"title":"First Implementation of High-Rate Pinpoint Technology in an Extremely Challenging Multilateral Well: Successful Lessons Learned From Tight Carbonate - Minagish Field, West Kuwait","authors":"M. Mofti, L. Sierra, Alaeldin Saad Alboueshi, M. Patra, Sulaiman Ali, A. Abu-Eida, Saad Matar, Nasser Al-Shemali, N. Al-Azmi","doi":"10.2118/198365-ms","DOIUrl":"https://doi.org/10.2118/198365-ms","url":null,"abstract":"\u0000 A significant challenge in the tight Mishrif oil reservoir of the Minagish field is ensuring hydrocarbon flow through the complex and highly damage-susceptible carbonate intervals. In recent years, field development strategies have begun to prioritize multilateral well technology over vertical and deviated wells because of the advantages of maximized reservoir contact, higher production rates, and improved access to reserves (hydrocarbon in place). The downside of most unconventional multilateral wells is that laterals are open hole, completed with much complexity, and pose challenges for effective acid stimulation because of poor acid distribution over the long interval.\u0000 The Mishrif formation in the Minagish field in west Kuwait is a challenging tight carbonate with poor reservoir quality, relatively low pressure, and no external pressure support. The stimulation methodology was highly modified as fit-for-purpose to address the unique challenges of multilateral well operations, formation technical difficulties, high-stakes economics, and untapped potential from these formations. Furthermore, to enhance production, the lateral lengths of the well were designed as an optimum solution. To maximize and sustain hydrocarbon flow and production, a multiple stage acid pinpoint treatment was performed by dividing the wellbore into small intervals, based on petrophysical and reservoir properties evaluations; a high-rate pinpoint technique was used for both laterals individually. The selected sections were individually acid stimulated, and the inflow contribution from the entire productive sections of both laterals was maximized with a highly reliable and effective multistage continuous operation.\u0000 The post-operation well test and production data show a significant production increase; long-term production data show a sustained production increase, stable pump intake pressure, and low water cut, demonstrating the success of the pinpoint technique as an optimized solution for the first multilateral well. The success of this well stimulation method has enabled the use of this pinpoint-squeeze as the best technique for all horizontal wells in this field.\u0000 This paper summarizes the design processes, challenges encountered, production response, and lessons learned from applying this pinpoint acidizing technique. It can be considered as a potential approach for addressing stimulation challenges in similar tight carbonate reservoir conditions in other fields.","PeriodicalId":406524,"journal":{"name":"Day 3 Fri, October 18, 2019","volume":"62 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124859486","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}

{"title":"Formation Pressure While Drilling Technology: Game Changer in Drilling Overpressured Reservoirs","authors":"Samat Ramatullayev, A. Makhmotov, M. Zhabagenov, M. Cesari, Sal Torrisi, Graziano Capone, F. Ferrari","doi":"10.2118/198367-ms","DOIUrl":"https://doi.org/10.2118/198367-ms","url":null,"abstract":"\u0000 The Formation Pressure While Drilling (FPWD) has been widely used in the industry in different downhole environments for formation evaluation purposes – pressure gradients, fluid identification and contacts, and reservoir pressure management. However, there is a niche application of this tool that no wireline formation tester could provide – real-time drilling optimization.\u0000 Drilling reservoirs with abnormal high pressure is a complex process. The overpressure can cause a well to blowout or become uncontrollable during drilling leading to catastrophic outcome if too low mud weight is selected. On the other hand, too high mud weight can lead to lost circulation, decrease in rate of penetration, stuck pipe and most importantly it can damage the formation hindering productivity of the well. The monitoring of actual pore pressures in real-time with FPWD tool is critical to make proper mud weight adjustments, rather than relying on inferred pore pressure from either predictive models or offset wells.\u0000 The paper discusses a case study of application of FPWD in a well drilled in a fault block never drilled before, where pore pressure data from wells located in nearby blocks indicated that there may be abnormal high-pressure zones. Pressure measurements were performed while drilling after every 100 m upon reaching a certain depth. Since downhole BHA included gamma ray and resistivity tools along with FPWD tool, the combination of this data was used to select the intervals to be tested.\u0000 The study shows how real-time pore pressure measurements helped to adjust mud weight from 1.45 to 1.80 sg to avoid the risk of formation fluid influx into the well, optimize drilling operations and, based on the acquired results, an operator decided on the total depth (TD) of the well. Since pretests were performed at targeted layers, formation pressure and mobility data also aided in reservoir characterization.\u0000 The paper presents the first successful application of FPWD technology in Russia and Caspian region for drilling optimization purposes in overpressured reservoirs. Real-time data availability allowed making quick operational decisions to safely drill the well until planned TD.","PeriodicalId":406524,"journal":{"name":"Day 3 Fri, October 18, 2019","volume":"21 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125362577","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}

{"title":"Hybrid Swell Packer - Water Prone Zone Isolation","authors":"Shian Ee Ma, Siti Nur Mahirah Bt M. Zain, M. F. Ishak, M. A. Omar, Jennie Chin Pui Ling","doi":"10.2118/198368-ms","DOIUrl":"https://doi.org/10.2118/198368-ms","url":null,"abstract":"\u0000 Conventionally, for an oil development field with the risk of water breakthrough during its life time of production, a cased hole with perforation method will usually be chosen. This is a proven method of completion strategy that enable an effective way to provide proper water isolation.\u0000 Project B is an oil development project in Malaysia with 3 wells in total, which were drilled and completed by early February 2019. During the early stage of the project at Front End Planning, offset well data suggested that there are 2 target zones of hydrocarbon in the field being separated by a thin layer of shale (3meters), dividing them into upper and lower lobe of oil reservoir. It was expected to see a water reservoir below these two reservoirs and hence, the proposed completion strategy was to perform Cased Hole with Perforation and Gravel Pack. Further studies between Production technology and Completion team had raised the concern on the integrity on the water isolation due to the shunt tube system used for the gravel pack job.\u0000 To effectively isolate cross flow between the upper and lower lobe of the oil zone and delay the water break through from the lower water reservoir section, project team modified the completion strategy from Cased Hole Gravel Pack to Open Hole with Stand-Alone Screen (OHSAS). Hybrid Swell Packers will be installed at the thin shake layer to provide the zonal isolation.\u0000 The completion strategy modification had simplified not only the offshore completion operation, but also the logistic planning and footprint allocation due to lesser equipment required. Total cost saving had been achieved at USD 1.44 Milliom with around 2.4 days reduction on completion operation timing.\u0000 This paper will discuss the rational to modify completion strategy, cost comparison and operational sequence between these 2 methods of completion. This paper will also cover the challenges, limitation to deliver the well.","PeriodicalId":406524,"journal":{"name":"Day 3 Fri, October 18, 2019","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126254311","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}