Day 2 Wed, March 23, 2022最新文献

{"title":"Concerted Approach for Annular Pressure Build-Up APB Mitigations to Safeguard Well Integrity of Subsea, High Temperature Carbonate Exploration Well","authors":"Raja Muhammad Hafizi Raja Ismail, Faieqah Zainal Abidin, Mya Thuzar, M. F. Rameli, Avinash Kishore Kumar, M. W. Moh Wahi, Yap Yun Thiam","doi":"10.4043/31689-ms","DOIUrl":"https://doi.org/10.4043/31689-ms","url":null,"abstract":"\u0000 Exploration well with carbonate reservoir is a challenging well to plan for due to risk of total losses because of karst presence. It became even more challenging for a subsea well with high bottom hole temperature (BHT) and prospect of well testing. Flow of HT reservoir fluids (BHT up to 175 deg C) to surface will resulted in significant heat transfer to adjacent casing & its annulus fluids, and lead to annular pressure build-up (APB). High APB will lead to loss of well integrity via 13-3/8\" intermediate casing burst and 9-7/8\" production casing collapse if left unmitigated. As per The Company technical standards, two APB mitigations were required in a subsea well. The first selected mitigation is an open casing shoe. The exposed shoe will act as a natural relief valve whenever APB exceeding its fracture pressure (FP), therefore, limit the APB to its FP. However, it is challenging to keep the 9-7/8\" casing top of cement (TOC) below the 13-3/8\" casing shoe and fulfil the open shoe barrier requirement for this well where the open hole interval is relatively short and subject to be plugged off by barite sagging, insufficient open shoe length for safety margin of excess cement and requirement of minimum annulus cement length for shoe integrity. Extra mitigations were addressed through extensive lab tested solids-free annulus fluid to mitigate barite sagging. Open shoe interval also designed with multiple weak sands exposure and higher FP were considered for worst-case APB simulation. The second barrier is the 13-3/8\" intermediate casing and 9-7/8\" production casing itself. Based on WellCAT simulation, the intermediate casing unable to meet The Company standards of burst (safety factor, SF < 1.1) in the worst-case scenario whereby APB is unmitigated. The casing burst pressure rating was recalculated using API Bulletin 5C3 equation with the inputs taken from minimum actual casing wall thickness measurement and internal yield pressure from its mill certificate. Technical derogations were raised and approved once the casing passed all the load cases using the revised burst rating by minimum SF of 1.0. The well was delivered successfully with the open hole barrier for both casing was executed flawlessly despite the complex fluid train while cementing.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87124568","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 Versatile and Tunable Metal-Organic Framework MOF for Condensate Decontamination","authors":"Sunatda Arayachukiat, Taradon Pironchart, Kanokwan Kongpatpanich","doi":"10.4043/31664-ms","DOIUrl":"https://doi.org/10.4043/31664-ms","url":null,"abstract":"\u0000 Contamination of heavy metals especially for Mercury (Hg) and Arsenic (As) in condensates becomes one of major concerns in Natural Gas production due to theirs high toxicity and carcinogenicity. The key challenge to develop adsorbents for Hg/As removal is to find suitable porous materials with high adsorption capacity, long-term stability and easy to handle the toxic wastes after the adsorption process. Metal-organic frameworks (MOFs) are one of promising porous materials constructed from metal clusters and organic linkers to create the 3D framework structures. MOFs are one of the promising adsorbents for removal of Hg/As from condensates owning to their versatile structures, tunable porosity, and tailorable chemical functionalities. In this work, Zr-based MOFs have been developed for dual removal of Hg and As species owning to their chemical stability in moisture conditions, which is highly desirable for industrial processes. Zr-based MOFs with different topology and pore size distribution have been synthesized for Hg/As adsorption to understand the contribution of porous structure on the removal of Hg/As species in condensates. The performance of Zr-based MOFs results showed Hg and As removal up to 99.5% in condensates from several petroleum sources. The removal efficiencies were found to be influenced by topology of MOF adsorbents and the speciation of Hg/As in different petroleum sources. In addition, Zr-based MOFs have proposed some future trends and challenges of porous material that can be used as an alternative to the conventional metal oxides and zeolites.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"21 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"72959470","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":"Determination of Fluid Properties and Reservoir Net Pay Cutoffs by Production Logging and Conventional Logs in Exploration Wells :A Case Study of the Granite Fractured Reservoir in JZ Oilfiled in Bohai Sea","authors":"Xinlei Shi, Yunjiang Cui, Sainan Xu, Ruihong Wang, Hao Zhang","doi":"10.4043/31347-ms","DOIUrl":"https://doi.org/10.4043/31347-ms","url":null,"abstract":"\u0000 Since resistivity logging is much more sensitive to rocks than to hydrocarbons in granite reservoirs, conventional logging methods cannot always accurately evaluate fluid properties and identify pay zones. Drill Stem Test (DST) is often used to identify fluid properties and hydrocarbon production potentials. However, DST in granite reservoirs cannot accurately determine production from sub-layers which leads to inaccurate net pay zone identification and reserve estimation. The accurate determination of fluid properties and net pay zones in fractured granite reservoirs remains a challenging topic.\u0000 This study proposes the use of Production Profile Logging (PLT)Logging in exploration wells in JZ oilfield characterized by fractured granite reservoirs, where DST could not characterize the sub-layers’ PLTs with in the thick layer of the combined test. With the use of open hole completion test, PLT logging can easily identify the production from sub-layers. The fluid density and water hold-up are consistent with the response of flowmeter logs. The method not only identifies production from sub-layers but also determines fluid properties. Meanwhile, it can quantify the production from each sub-layer according to PLT logging interpretation. It has satisfactory application in productivity evaluation in JZ oilfield.\u0000 Results indicate that the use of PLT logging in four exploration wells in JZ oilfield is successful. Sub-layers are identified in DST based on PLT logging interpretations of flow rate, density, and water hold-up. The productivity index of each sub-layer is calculated by PLT logging interpretation. Combining lateral resistivity logs with sonic logging data, Draw porosity and ratio of the deep and shallow lateral resistivity plot based on each sub-layer’ production with PLT interpretation Logging results. Net pay cutoffs of JZ oilfield is determined to be φ≥3.0% and (RD/RS) *DT≥90. This method improves the accuracy of reserve evaluation and solves the problem that the estimates of net pay cutoffs are larger than actual values in DST. Compared with DST in fractured granite reservoirs, PLT logging not only leads to accurate determination of fluid properties and identification of net pay cutoffs but also largely reduces the costs.\u0000 PLT logging is conventionally used to dynamically monitor cased hole wells. The novelty of this study is the successful application of PLT logging in reserve estimation. Compared to the conventional reserve estimation method based on DST, this new strategy accurately identifies net pay zones and determines net pay cutoffs in fractured granites to improve the accuracy of reserve estimation. Thus, the field can be developed more economically when oil prices are low.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"25 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77626714","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":"A Technical Limits Weight Control Tool for Integrity Management of Aging Offshore Structures","authors":"S. M. Ng, R. Khan, Luong Ann Lee, Biramarta Isnadi, Horng Eng Tang, Fahima M Salleh","doi":"10.4043/31655-ms","DOIUrl":"https://doi.org/10.4043/31655-ms","url":null,"abstract":"\u0000 This paper presents a digitized Technical Limits Weight Control (TLWC) tool for integrity management of existing fixed offshore structures. The tool is currently integrated into PETRONAS's Structural Integrity Compliance System (SICS), which is a web-based application for Structural Integrity Management (SIM) of fixed offshore structures.\u0000 The main capability of the TLWC tool is to allow a user (engineer/ manager) to determine the fitness for purpose of an offshore facility quickly and efficiently for the inclusion of additional topsides loading at various locations on the platform decks. The tool makes use of global ultimate strength analyses results which considers the acceptance criteria for each operating region in Malaysian Waters. The limits of these criteria are used to create contour boundaries, which depending on Centre of Gravity (CoG) shifts due to topsides loading patterns.\u0000 The tool can provide a high-level check on platform suitability for such increase in loading to cater for further development or operational needs. This quick check enables decision making at early engineering stage without the use of further elaborate and costly analyses. The contour plot shown in the results indicates the limiting acceptable Reserved Strength Ratio (RSR) for that platform.\u0000 The TLWC decision-making tool is ideal for practicing offshore structural integrity engineers in operations to make a quick decision with regards to addition of topside loading for platforms with marginal reserved strength. Detailed assessment is required to address potential local member overstress for the topside structural members.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76859080","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":"Case Study: How the Newest Generation of Autonomous Inflow Control Device Helps to Control Excessive Wells Water Production within a Major Sultanate of Oman Oilfield","authors":"Salim Buwauqi, Ali Al Jumah, Abdulhameed Shabibi, Ameera Harrasi, M. Abd el-Fattah, Tejas Kalyani, A. Fahmy","doi":"10.4043/31483-ms","DOIUrl":"https://doi.org/10.4043/31483-ms","url":null,"abstract":"\u0000 The field is located in the south of Sultanate of Oman and was discovered in 1980 The field produces from sandstone reservoirs a heavy crude with high viscosity (up to 2000 cP) value that contains no appreciable solution gas. Production is supported by a bottom active water drive aquifer. An unfavourable mobility contrast between the oil and formation water results in rapid water breakthrough and a large portion of a well's reserves are produced at high water cuts. The average economic limit of wells in the field is about 98% water cut. Thus, water management plays a key role in well economics. The new horizontal producer wells target is to drain by-passed oil with only 30 ~ 80 m spacing. Injectors are at the flank and are injecting deep into the aquifer. Water breakthrough occurs at high sand permeability and once happened; water will dominate well production due to unfavourable mobility ratio. Some of the new producer wells are completed with Wire-Wrapped Screen (WWS) – Stand Alone Screen, and swellable packers to isolate higher water-saturated zones. However, most of these wells start typically with a 60% water cut (BSW) or more and rapidly reach +90%.\u0000 To overcome current reservoir/production challenges; The operator has used the latest Autonomous Inflow Control Device (AICD) Technology called Autonomous Inflow Control Valves (AICV). ICD's and previous generation Autonomous Inflow Control Devices (AICD) has shown in many cases increased oil production and higher recovery with better fluid influx balance along the well. However, neither ICD nor AICD can shut off the water production completely without well intervention. The AICV can restrict unwanted water significantly and autonomously. The AICV are based on different flow behaviour for laminar and turbulent flow that is utilized in a pilot flow to actuate a piston position to restrict unwanted fluids. The design with two parallel flow paths ensures the AICV is open for oil, and close for water autonomously.\u0000 The AICV technology is based on Hagen-Poiseuille and Bernoulli's principles and is truly autonomous as it can identify the fluid flowing through it based on fluid properties such as viscosity, density and flowrate. For unwanted fluid such as water and Gas, AICV can generate enough force that will shut off the device if required. This makes it more robust than any other commercially available AICDs. AICV effect is reversible i.e. when the saturation of unwanted fluid (Sg or Sw) around the wellbore reduces, AICV will re-open for the oil production, thus draining all possible oil around the wellbore.\u0000 In this paper, AICV performance will be discussed and comparative analysis with production performance of wells completed with WWS completed in the same reservoir will be presented. Based on the regular well testing and production analysis, it is evident that AICV technology has helped the operator in managing/shutting off the unwanted water production autonomously. This new AICV technology ","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"54 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80109807","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":"Supercritical Methane Adsorption in Shale: Isothermal Adsorption and Desorption of Eagle Ford Shale Gas","authors":"Aminah Qayyimah Mohd Aji, B. Maulianda, D. Mohshim, Khaled Abdalla Elraeis, K. E. H. Ku Ishak","doi":"10.4043/31615-ms","DOIUrl":"https://doi.org/10.4043/31615-ms","url":null,"abstract":"\u0000 Gas adsorption-desorption highly affect gas storage and production behaviour in shale nanopores. The study of methane adsorption isotherm in shale has been extensively conducted experimentally. The shale compositions and reservoir conditions prominently control the adsorption capacity of methane. However, to date, there is a lack of discussion on the effect of heterogeneous TOC towards the adsorption isotherm and comparison with adsorption isotherm modelling. This study used the gravimetric method for supercritical methane adsorptions - desorption isotherms measurements. Isotherms measurements were conducted with three shale samples with various TOC values (9.67, 13.9, and 15.4 wt.%) from the Eagle Ford formation at pressure up to 10 MPa and temperature at 120 °C. The isotherms gathered were fitted with standard adsorption-desorption isotherm models, Langmuir, Freundlich and extended Sips to test the applicability of these models depicted the adsorption of supercritical methane. The results show that EF C with the highest TOC content (15.4 wt.%) has the highest adsorption-desorption methane capacity, more than 0.7 mmol/g, compared to other samples. The composition differences between these samples indicate that the organic contents were likely a major controlling factor of the adsorption capacities obtained. The TOC provides a higher surface area for adsorption to occur. Thus, a higher adsorption-desorption capacity was observed through this study. On the other hand, the adsorption and desorption curves did not intercept due to the hysteresis caused by the capillary condensation. The significant binding capacity of the shale surface for methane gas molecules leads to the hysteresis observed during methane desorption. It was observed that the Freundlich model was the most accurate adsorption model in describing the adsorption-desorption behaviour with tested shales with average R2 more than 0.90 and ARE (%) less than 10 % compared to other models with 15.8 % (Langmuir) and 18.9 % (Sips). This study also proved the influence of organic matter on predicting the adsorption-desorption capacity with adsorption isotherms highlighting the importance of modelling the TOC of shale with adsorption isotherm to determine the adsorption-desorption properties.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"38 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80323037","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":"Successful Development and Deployment of a Global ROP Optimization Machine Learning Model","authors":"T. S. Robinson, P. Batruny, Dalila Gomes, M. Hashim, M. H. Yusoff, M. Arriffin, A. Mohamad","doi":"10.4043/31680-ms","DOIUrl":"https://doi.org/10.4043/31680-ms","url":null,"abstract":"\u0000 Drilling rate of penetration (ROP) is a major contributor to drilling costs. ROP is influenced by many different controllable and uncontrollable factors that are difficult to distinguish with the naked eye. Thus, machine learning (ML) models such as neural networks (NN) have gained momentum in the drilling industry. Existing models were either field-based or tool-based, which impacted the accuracy outside of the trained field. This work aims to develop one generally applicable global ROP model, reducing the effort needed to re-develop models for every application.\u0000 A drilling dataset was gathered from exploration and development wells in both onshore and offshore operations from a variety of fields and regions. The wells were curated to have different water depths, down hole drive such as Rotary Steerable System (RSS), PDM, Standard Rotary, bit types (Mill Tooth, TCI, PDC) and inclinations (vertical or deviated). A deep neural network was used for modelling the relationship between ROP and inputs taken from real-time surface data, such as Torque, Weight-on-Bit (WOB), rotary speed (RPM), flow and pressure measurements. The performance of the ROP model was analyzed using historical data via summary statistics such as Mean Absolute Percentage Error, as well as graphical results such as residuals distributions, cumulative distribution functions of errors, and plots of ROP vs depth for independent holdout testing wells not included in the model fitting process. Analysis was done both in aggregate, and for each specific well.\u0000 The ROP model was demonstrated to generalize effectively in all cases, with only minor increases in error metrics for the holdout test wells, where the Mean Absolute Percentage Error averaged across wells was ~20%, compared to 17.5% averaged across training wells. Furthermore, residuals distributions were centered close to zero, indicating low systematic error. This work proves the case for a \"global\" ROP prediction model applicable \"out-of-the-box\" to a broad set of drilling operations.\u0000 A global ROP model has the potential to eliminate learning curves, reducing time and costs associated with having to develop a new model for every field. Furthermore, a model that effectively captures the relationships between parameters controllable by drillers and ROP can be used for automatically identifying drilling parameters that improve ROP. Preliminary field-testing of the ROP optimization system yielded positive results, with many examples of increased ROP realized after following drilling parameter recommendations provided by the software.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"136 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80309952","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 FEL-Agile Hybrid Approach to Selecting the ‘Right’ Oil & Gas project","authors":"Ashvin Nesan","doi":"10.4043/31659-ms","DOIUrl":"https://doi.org/10.4043/31659-ms","url":null,"abstract":"\u0000 The front-end loading (FEL) project management process is a method that is trusted and ingrained into most Exploration and Production oil and gas companies worldwide. The entire FEL is modeled after the Waterfall model which is sequential in nature. The waterfall model can be construed to be too slow in adapting to changes resulting in a significant number of oil and gas projects having a high tendency of cost overruns, schedule delays and not meeting stakeholder objectives. On the other hand, the agile model employed by IT, software and technology companies offers a refreshing view to achieving the desired result in projects. However, these two industries have substantial differences between them, for example in project value and regulation. This explains the reluctance by major oil and gas companies to implement agile as part of their project management approach. Nevertheless, as the environmental and organizational factors in project management in all sectors are changing at a rapid pace, seeking alternative and workable approach is vital. The paper seeks to evaluate the concept of adapting the agile methodology for FEL in oil and gas field development projects. The paper identifies areas for integrating agile such as in FEL selection criteria and further suggests to seek a balance between the two contrasting methods. Overall, the results from a case study in the oil and gas industry indicates that by adapting agile approach into the current FEL practice, it's more likely that the right project would be sanctioned, therefore, increasing the chances of project success.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"42 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88934637","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":"Lookback Analysis and Benchmarking to Improve Success Rate of Thru Tubing Perforations for Accessing Behind Casing Opportunities in Brown Fields","authors":"Saurabh Anand, M. A. Hamzah, B. Madon, Kok Kin Chun, Anis Izzuddin Othman, M. S. B. M. Ismail, M. Rahim","doi":"10.4043/31642-ms","DOIUrl":"https://doi.org/10.4043/31642-ms","url":null,"abstract":"\u0000 Accessing behind casing opportunities plays a key role in ensuring that production targets are achieved in the PETRONAS operated fields in Malaysian basin. This is however getting more challenging as these fields comprising mostly of stacked clastic reservoirs get matured. This paper provides a comprehensive review of all thru tubing perforation jobs done over last two years in PETRONAS operated fields in the region with focus on failure reasons and future mitigation measures to ensure higher rate of success.\u0000 As a part of this study, all the historical thru tubing perforation jobs done to access behind casing opportunities over last 2 years across more than 22 producing fields in the region with PETRONAS as the operator were analyzed in detail. These jobs were then studied with respect to the main factors which impacts overall job success or failure. These included but was not limited to fluid contacts, gun, and charge type, nearby well performance, zone saturation data availability, completion type, contractor performance etc. In addition, post job details like sand production, artificial lift performance which contributed to well behavior post perforation were also evaluated. Exhaustive gun perforation and well model simulations were conducted to model post perforation well performance. Actual data with distribution and impact of the above-mentioned parameters will be discussed at length in the paper. Key findings which contribute to the overall successful thru tubing perforation jobs and lessons learnt for future perforation jobs will be presented in the paper.\u0000 Based on the comprehensive review and in-depth analysis, the operator has gained great visibility on key focus areas for thru tubing perforation jobs to increase success rate for completing the behind casing opportunities. Results specially re-iterate the importance of saturation data, gun selection and sand control among other parameters for successful thru tubing perforation jobs in matured stacked reservoirs. The study also indicate why these parameters are even more important for multiple tubular perforations such as cement packers, complex dual string completions, multiple tubular perforation etc. Based on the findings from the study, the paper will recommend key points to consider while completing behind casing opportunities in challenging environment.\u0000 While a lot of literature and study is available on perforations in general, the author could not find any noticeable work which is based on large amount of actual field data on how to improve thru tubing perforation jobs in matured stacked reservoirs in complex completions. This paper aims to help operators improve on the existing practices to ensure better and more successful results while completing behind casing opportunities using thru tubing perforations.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"81 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86219138","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":"Challenges in Planning and Designing for the Sea Transportation of Heavy Modules of a Modularized Plant, an EPC Contractor's Perspective","authors":"Zunaidi Ahmad Nazari, Madada Mashari, Mukesh Kumar, Eldho Paul","doi":"10.4043/31658-ms","DOIUrl":"https://doi.org/10.4043/31658-ms","url":null,"abstract":"\u0000 The ocean transportation of heavy modules on heavy transportation vessels (HTV) has a large influence on the design and construction of modularized plants. In some instances, it governs structural design loads and influences the layout and commissioning plan of modules. Proper selection of transportation routes, seasons, and vessels will reduce the impact of transportation loads and constraints on the overall module design. Details presented in this paper are based on an EPC Modularization project involving the sea transportation of 5 mega modules weighing between 5000MT to 9000MT, totaling 34000MT, which took place between November 2020 and February 2021. A summary of planning and execution strategy together with key solutions to deal with challenges faced during this project can serve as a guide for future projects.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"4 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78782528","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}