Day 3 Wed, August 29, 2018最新文献

{"title":"Managing Uncertainties and Surprises in Carbonate Gas Reservoir through Lower Completion Design Optimisation","authors":"H. Bakar, C. Bernard, Karim Ahmed Shata, Muhamad Ridzuan Shaedin, C. H. Roh, Khairul EzeeAzreen B M Khir","doi":"10.2118/191041-MS","DOIUrl":"https://doi.org/10.2118/191041-MS","url":null,"abstract":"\u0000 There are three (3) requirements of any completion in common; safe, economical efficient and reliable. 76% of PETRONAS CarigaliSdnBhd's wells in Sarawak Gas are completed in porous, heterogeneous and complex carbonate reservoirs. Four (4) types of lower completions are implemented for carbonatereservoir: barefoot, open hole Pre-Drilled Liner (PDL) with isolation packer, open hole blank liner with isolation packer with post perforation and cemented cased hole. This paper shares the best practices, lessons learnt, risks and performance from recent experiences at field FX, FY and N which are used to support the proposed lower completion design and selection criteria workflow.\u0000 Other than risk of wellbore collapse, early water breakthrough and fluid losses to formation, the provision for zonal isolation, cost, well productivity and complexity of operation have been part of the critical elements to be considered in the proposed process workflow from planning to execution phase. Dedicated studies such as wellbore stability analysis, critical drawdown requirement over time and well modeling are also being carried out to provide enhancment of lower completion design.\u0000 This selection criteria and lower completion design process flow has been applied in recent FY field development campaign which resulted 32% of cost saving in 3 horizontal wells and met the production gas target with zero Lost Time Injury (LTI).\u0000 The other particular merit of this paper is to share some the best practices and lessons learnt from FX, FY and N field case histories and the approaches taken to manage the risks.","PeriodicalId":133825,"journal":{"name":"Day 3 Wed, August 29, 2018","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-08-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128971460","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":"Performance Improvement from Drilling Control Systems Alarm Management and Analytics","authors":"C. Goetz","doi":"10.2118/191016-MS","DOIUrl":"https://doi.org/10.2118/191016-MS","url":null,"abstract":"\u0000 Control Systems Alarms on offshore rigs are inarguably poorly designed. Drilling Control Alarms Systems (DCAS) in particular, are notorious and the pack leaving much to be desired. Excessive alarm volumes on these Integrated Control Systems (ICS) lead to Driller alarm blindness and exceed all industry recognized standards. The problem is exacerbated by the general lack of a Human Machine Interface (HMI) console dedicated to the maintenance crews or other roles to leverage for equipment insight and preventative maintenance.\u0000 Because of these conditions, Drillers are inundated, and critical alarms are often ignored. Maintenance crews are reactive, resulting in missed preventative maintenance opportunities and equipment failure or non-productive time (NPT). The result is a general opinion that these DCAS are poorly designed, and the alarms themselves are not useful.\u0000 This paper will work to alter that perception through illustrating that the DCAS do indeed contain useful information if examined with the correct lens. Additionally, this paper shows that Drilling Contractors have the tools at their disposal to leverage this lens on any ICS. It will illustrate how that can be done, as well as discuss some of the best practices that Drilling Contractors ought to adopt to improve the capabilities of their DCAS.","PeriodicalId":133825,"journal":{"name":"Day 3 Wed, August 29, 2018","volume":"42 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-08-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126830739","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":"Effective Approach to Wellbore Clean Out Operation: A Case Study from Zawtika Phase 1B","authors":"Attawit Choodesh, M. Rutland, C. Grant","doi":"10.2118/190971-MS","DOIUrl":"https://doi.org/10.2118/190971-MS","url":null,"abstract":"\u0000 Free sand movement and fines mobilization during production in Zawtika field is one of the main challenges and can result in failures of production systems leading to SSHE exposure, loss of production or even well suspended. The optimum completion design Cased Hole Gravel Pack (CHGP) allows the well to maintain solid-free gas production with (limiting skin) selectivity, longevity and integrity throughout the life cycle.\u0000 The Sand Control completion deployment, effectiveness and well productivity is directly related to the cleanliness of cased well bore and completion brine. The Total Solid Suspension (TSS) and Nephelometric Turbidity Units (NTU) or clarity of the fluid is the key indicator of well cleanliness. Zawtika Phase 1A post job review highlighted that Wellbore Cleanout (WBCO) is one of the most time consuming operation. To overcome this challenge and create areas of opportunities for improvement based on efficiencies, several possible solutions identified below.\u0000 Excessive pipe dope, metal debris and rust from casing can collect within the well bore, bridge in perforation tunnels and ultimately damage reservoir or seriously hinder running completion components. The correct combination of Pipe Dope applying procedure, Chemical Displacement, Mechanical Movement and Hydraulic Displacement are the main key contributing factors to improved operation safety, deployment operational efficiency. Lab scale test conducted to simulate test for pipe dope removal chemical, Mechanical Casing Scraper and casing brush simulate testing in order to remove casing vanishing coating, also applying wellbore cleaning concept from drilling - rotational, pump rate and trip speed\u0000 Recovery of metal or other debris in a limited number of runs gives several advantages: - Minimize reservoir damage - Reduces risks of screen plugging - Saves rig time. This paper will describe planning process, pipe dope procedure, wellbore clean out chemical / mechanical tool selection based on laboratory testing, displacement techniques, and operation summary. The potential cost saving to project can be more than 5 Million USD. The combination of this improvement in WBCO operation is able to reduce the operation time and cost in Phase 1B more than 71% comparing to Phase 1A performances in 2014-2015","PeriodicalId":133825,"journal":{"name":"Day 3 Wed, August 29, 2018","volume":"42 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-08-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131334530","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":"Well Control for Offshore High-Pressure/High-Temperature Highly Deviated Gas Wells Drilling: How to Determine the Kick Tolerance?","authors":"Chen Xuyue, Jin Yang, D. Gao, Yi Huang, Yanjun Li, M. Luo, Li Wentuo","doi":"10.2118/190969-MS","DOIUrl":"https://doi.org/10.2118/190969-MS","url":null,"abstract":"\u0000 Kick tolerance is a vital parameter for well control. It indicates if a shut-in operation can be performed or not, an appropriate method of well killing should be selected. However, the kick tolerance determination for offshore high-pressure/high-temperature (HP/HT) highly deviated gas wells drilling still remains as a challenge to the oil and gas industry due to the presence of narrow safe mud weight window of the HP/HT well section, complex borehole temperature profile, influx distribution and high frictional pressure loss. In this work, a model of volume kick tolerance specific for offshore HP/HT highly deviated gas wells drilling was presented based on the pressure bearing capacity of highly deviated open hole, casing shoe, casing, blowout preventer (BOP) and choke valve. Meanwhile factors affecting the volume kick tolerance were also investigated. The result shows that both of the volume kick tolerance for shut-in and the volume kick tolerance of well killing increase with wellbore inclination of the highly deviated section, and the highly deviated wellbore or highly deviated wellbore may have a much higher volume kick tolerance than that in vertical wellbore. With other parameters values setting constant in this case, the volume kick tolerance of well killing increases with the geothermal gradient while the increase rate is not obvious. This work provides a practical tool for enhancing well control in offshore HP/HT highly deviated gas wells drilling.","PeriodicalId":133825,"journal":{"name":"Day 3 Wed, August 29, 2018","volume":"156 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-08-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126735938","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":"Integrated Reservoir Modeling while Drilling Enhances Horizontal Well Placement and Productivity in a Complex Offshore Field, Bohai Bay","authors":"Min Mao, Linlong Bai, Wenzhong Shen, Xiao Qiang Li, Z. Xia","doi":"10.2118/191065-MS","DOIUrl":"https://doi.org/10.2118/191065-MS","url":null,"abstract":"\u0000 Horizontal wells are being a common practice in offshore field development in Bohai Bay recently. Maintaining well trajectory in sweep spot while drilling is one of the key factors to optimize horizontal well’s productivity. However, great challenges are often faced in Bohai Bay area including survey uncertainties while drilling and reservoir geology variation. On the one hand, successful placement of a horizontal well requires accurate landing of the well in the right position and orientation in the reservoir. On the other hand, the trajectory is optimized based on structural geobody variation resulted from the uncertainty of parameters governing the static behavior of the field. Therefore, the ability to update geosteering model in timely manner and to proactively adjust well trajectory in real time are required.\u0000 This paper presents an innovative method in Bohai Bay by applying the technology of integrated seismic volume and reservoir geosteering model while drilling to achieve very promising productivity. That is to say, the new geosteering method includes seismic inversion of checkshot calibrating, single/multi-wells reservoir model updating, conventional logging while drilling, and mud logging etc. How to develop new horizontal well steering methodology and software integrated seismic volume of time (or depth) domain, logging while drilling, reservoir modeling result to optimize well planning and placement for high productivity?\u0000 Results from lower Neogene Minghuazhen formation tests executed in SuiZhong 36-1, Bozhong oilfield of Bohai Bay clearly demonstrate the following capabilities of the technology.Reduction of the steering need for the tools of distance to boundary included Directional and deep well placement tool.A bridge from three-dimensional geology model to two-dimensional geosteering model before drilling; vice versa, 2D geosteering model update 3D geological model after drilling.\u0000 More People grasp the systematical methodology of integrated reservoir geosteering model and trajectory optimizing while drilling which provide a higher degree of confidence in the drilling process.","PeriodicalId":133825,"journal":{"name":"Day 3 Wed, August 29, 2018","volume":"6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-08-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115296231","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":"Fracture Packing in Previously Gravel-Packed Well Using Single-Trip Multizone System","authors":"Deng Jianming, Ma Yingwen, Zhang Ming, Qiang Wang, Xiaobo Wang, Chaoyong Fang, Jiacheng Qian","doi":"10.2118/182242-MS","DOIUrl":"https://doi.org/10.2118/182242-MS","url":null,"abstract":"\u0000 This paper details the process of designing and executing a frac pack operation in a previously gravel-packed formation. Challenges and solutions are discussed as well as the methods used to properly squeeze fluid and proppant into the formation.\u0000 During the last 13 years in China, a single-trip multizone (STMZ) gravel-packing system has been widely used in Bohai Bay for sand control. Most of the wells were initially completed using high-rate water packing methods and then were sidetracked once production reduced to a certain level. However, operators desired a lower-cost work over plan. The proposed method involved recompleting a previous well by running service tools into the well to perform fracture packing within the existing multizone gravel-pack completion. High-viscosity fluid was pumped into the formation as a prepad, and then formation fracture packing was performed.\u0000 The successful treatment execution presented in this paper demonstrates the process of cleaning the wellbore for recompletion. Using the STMZ system proved the downhole service tool could be safely tripped back in and out of hole in the same trip following fracture packing of a previously gravel-packed multizone well completion. The method also shows that, through careful preplanning and designing of the tool and treatment, the risk of failure caused by a stuck tool string, unwanted fluid loss, or premature screenout can be minimized. The job execution and lessons learned along the way can also provide a guideline for improvement of future treatments in similar situations.\u0000 This paper presents the first successful fracture packing application in a previously gravel-packed well. The method presented provides a new method to enhance production of mature wells without performing a sidetrack, significantly reducing costs by recompleting the well.","PeriodicalId":133825,"journal":{"name":"Day 3 Wed, August 29, 2018","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2016-10-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127660193","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}