Day 4 Thu, May 09, 2019最新文献

{"title":"Review of Technical Challenges, Risks, Path Forward, and Economics of Offshore CO2 Transportation and Infrastructure","authors":"D. Sachde, Ray W. McKaskle, J. Lundeen","doi":"10.4043/29253-MS","DOIUrl":"https://doi.org/10.4043/29253-MS","url":null,"abstract":"\u0000 Offshore storage capacity has been identified as an essential part of long-term Carbon Capture, Utilization, and Storage (CCUS) strategies. Transporting the CO2 from the source onshore to the offshore storage site will be a critical aspect of the technical and economic viability of offshore storage projects. Transport of CO2 will include all processes and equipment from the preparation of CO2 for transport at the source to the wellhead at the offshore storage site. This paper will review the technology required at each step, identify risks/key knowledge gaps specific to the offshore transport process, suggest steps to be taken to advance the technology, and provide an overview of cost/economics for each step in the process.\u0000 The authors use existing literature, an analysis of analog industries (e.g., offshore natural gas transport), knowledge from CO2 onshore transport, and a technical review of the processes and equipment required for offshore CO2 transportation. This analysis is based on a hypothetical CO2 source and transport process, but will highlight some project and site-specific challenges and decisions for each step.\u0000 Specific results from the review of offshore transport process include the following:\u0000 Impact of CO2 source on transport processes, including purification and preparation for transport (e.g., dehydration/compression processes);\u0000 Comparison of offshore pipeline specifications and costs to comparable onshore applications;\u0000 Review of scenarios where alternate transportation methods (e.g., ship transport) may be considered;\u0000 Technical review of wellhead and injection facility in the offshore CO2 application in comparison to onshore analogs;\u0000 Review of the impact of CO2 utilization (e.g., enhanced oil recovery) of CO2 on transport processes;\u0000 Tabulation of gaps in data or knowledge to guide further research or industry input.\u0000 The limited experience with offshore CO2 transport projects leaves significant gaps in available data and information on these projects. By aggregating the available information on offshore CO2 transport projects, supplementing with knowledge and data from related processes (offshore natural gas transport, onshore CO2 transport), and performing a technical review of the offshore transport processes and infrastructure, some specific data needs and risks for offshore CO2 transport projects are identified.","PeriodicalId":214691,"journal":{"name":"Day 4 Thu, May 09, 2019","volume":"34 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121346600","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":"Offshore Project Standardization: Harmonized Set of Standards and Specifications for Cost Reduction in Offshore Projects","authors":"Hoseong Lee, Mathew Chakala","doi":"10.4043/29574-MS","DOIUrl":"https://doi.org/10.4043/29574-MS","url":null,"abstract":"\u0000 Many oil majors have their own in-house safety standards, engineering and design practices. At the same time, industry groups and various local authorities have developed their own codes, standards and recommended practices. On top of this, each classification society has its own set of rules for building offshore structures and machinery.\u0000 As a result of the various requirements, highly complex specifications unique to each project are developed. The offshore project standardization effort seeks to find acceptable common ground between the numerous individual standards and requirements to reduce costs and increase efficiency in offshore engineering, procurement and construction (EPC) projects. As part of the standardization project, the specifications for the major topside equipment were developed to simplify procurement of machinery packages. In addition, bulk materials, outfitting design and the best practices for welding and inspection were standardized for construction efficiency.\u0000 A gap analysis was performed, comparing executed project specifications, industrial standards, and international and local regulations. The specifications were then harmonized focusing on construction efficiency, compatibility and operational maintenance, and with the safety requirements. A major driver in this activity was to adopt marine practices for offshore application without compromising safety and quality. Feedback on the process was obtained from an advisory group made up of owners, operators, engineering companies, vendors and shipbuilders.\u0000 Two standardization cases are presented as examples. The first is the standardization of topside piping material which resulted in the enhanced compatibility of materials and provision of greater construction flexibility, addressing material chemical composition, sour service application, wall thickness, test procedures and acceptance criteria. Secondly, a harmonized specification was developed for an air compressor package which meets the requirements for the design, inspection, testing, installation and commissioning for offshore application. The proposed standard project specifications help to reduce the potential for a manufacturer to misunderstand an owner's unique standards and requirements, and provide an opportunity to bring about cost reduction especially in unnecessary engineering and documentation.","PeriodicalId":214691,"journal":{"name":"Day 4 Thu, May 09, 2019","volume":"19 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121190243","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":"Forward Scouting: Use of Sediment Profile Imagery in Conjunction with Multibeam Echosounder Mapping for Offshore Wind Cable Routes and Site Characterization","authors":"D. Carey, D. Doolittle, Kevin H. Smith","doi":"10.4043/29220-MS","DOIUrl":"https://doi.org/10.4043/29220-MS","url":null,"abstract":"\u0000 Selection of cable routes and wind turbine site assessments for offshore energy projects in the often-complex geology of the North American Atlantic coast entails very high risks for developers as well as state agencies: limited desktop data, patchy distribution of critical or sensitive habitats, and use conflicts, are a sampling of the risks encountered. The costs required to conduct multi-disciplined geophysical spreads including weather delays during marine mammal transit windows does not support exploring multiple or alternative routes. A novel approach was developed by Fugro and INSPIRE Environmental to reduce the risks and costs of required geophysical and benthic assessment surveys for offshore wind projects. Collection of field data is required by the Bureau of Ocean Energy Management (BOEM) as part of the Site Assessment Plan (SAP) for geophysical and biological characterization in offshore wind development. Collection of Sediment Profile Imagery (SPI) and Plan View (PV) imagery was integrated with multibeam echosounder (MBES) acoustic data collection to optimize route selection, provide ground-truth of acoustic data, and characterize benthic habitats in survey campaigns at three offshore wind projects. The SPI/PV data were downloaded daily and combined with on-board processed MBES data to provide near real-time guidance for optimizing survey operations. BOEM requires the mapping of sensitive habitats such as deepwater corals, eelgrass beds, and hard bottom environments including bedrock, boulder and cobble habitats as well as habitat characterization for a full benthic assessment.\u0000 The data presented from these three projects using the Forward Scouting approach illustrates the utility of rapid data acquisition and interpretation to support project-critical acoustic surveys. The SPI/PV data will be presented in an innovative visualization that integrates the profile and plan view imagery and processed MBES data. The visualization of the ground-truthed and benthic assessment data with landscape-scale seabed features has provided valuable decision-making support for archeological, benthic, fisheries, and engineering assessments. These combined technologies demonstrated the success of a collaborative approach to cable route and site characterization and led to development of the Forward Scouting approach to further reduce risk to schedules and assets, reduce site investigation costs, and incorporate multi-discipline (engineering and environmental) site data during early stages of project planning that is beneficial to stake-holder engagement activities.\u0000 Cable routing and site assessment is optimized when engineering and restricted-habitat constraints are minimized prior to full geophysical and geotechnical (G&G) survey operations with large assets. The SPI/PV Forward Scouting survey team can be deployed with high-frequency (>200 kHz) acoustic reconnaissance tools on small vessels that do not require permits or protected species observers","PeriodicalId":214691,"journal":{"name":"Day 4 Thu, May 09, 2019","volume":"11 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125487528","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":"Revolutionizing Subsea Field Development Planning Through System Integration and Advanced Diagnostics","authors":"C. Chidiac, Simon Holyfield, I. Roberts, R. Sauve, N. Simpson, U. Huynh, J. Torres","doi":"10.4043/29453-MS","DOIUrl":"https://doi.org/10.4043/29453-MS","url":null,"abstract":"\u0000 Field development planning (FDP) is a multidisciplinary process that is complex, time consuming, and inefficient. Existing workflows are domain centric and involve many discrete software programs, making the process linear, limiting optimization, and often preventing cross-domain collaboration.\u0000 Although a few software tools exist for parts of the field layout design, no existing software integrates the equipment selection, systems knowledge, field layout, economics, and software simulations spanning the entire planning process from feasibility studies to detail design and optimization.\u0000 This paper demonstrates how a novel FDP software package revolutionizes integrated concept development within the industry, supporting the process from reservoir engineering through to definition of the subsea system.\u0000 In early FDP stages, including feasibility and concept selection, operators plan for the development of a field that will produce for 20 years or more, making critical decisions with very limited reservoir information and a high level of uncertainty. Because these early stages are short, operators rarely have the time or resources necessary to evaluate all possible development scenarios, and decisions are delivered with less conviction than is desirable. Hence, operators are in constant search for tools and processes that enable evaluation of more options to help them make better-quality decisions in these early stages, where reducing uncertainty and making decisions are critical to achieving first oil faster.\u0000 The paper describes an innovative FDP methodology that utilizes the industry's first cloud-based collaborative subsea FDP software environment and provides efficiency and optimization by combining full-field economic calculations with reservoir engineering, production assurance, systems engineering, subsea technology selection and installation knowledge spanning the entire planning process in one visually rich environment.\u0000 The paper demonstrates how the solution provides the ability to evaluate technical feasibility and economic viability of hundreds of development scenarios during early FDP stages more accurately and in less time compared with traditional methods. The impacts on the industry are numerous and include efficiency gains, risk reduction, and significant system cost savings, thereby improving cash flow and reducing payback periods.","PeriodicalId":214691,"journal":{"name":"Day 4 Thu, May 09, 2019","volume":"90 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126247637","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":"Polymers for EOR in Offshore Reservoirs: Recommended Practices for Laboratory Screening","authors":"Yani C. Araujo de Itriago, Mariela G. Araujo Fresky","doi":"10.4043/29260-MS","DOIUrl":"https://doi.org/10.4043/29260-MS","url":null,"abstract":"\u0000 Most EOR methods, and hence most EOR screening criteria, traditionally focus on onshore applications due to lower cost and complexity in the implementation. Despite the challenges associated to offshore environments, EOR application in offshore fields is receiving increasing attention since the size of the prize is significantly large to overcome the high costs associated to the development.\u0000 The oil and gas community is evaluating and testing potential applications of chemical EOR to offshore assets based on the need to develop increasingly deeper reservoirs. Some of these reservoirs are characterized by having relative high temperature and high salinity, conditions where most available chemicals for EOR have limited applicability. Recent efforts to develop high temperature polymers have been reported, however, there is no clear understanding of what would work best in those harsh environments.\u0000 In this work, we propose an integrated workflow for laboratory screening of polymers for application in offshore reservoirs with high temperature and high salinity. We provide an overview of the main steps of the workflow and recommended protocols for the different laboratory measurements. The proposed workflow has been derived from best practices reported in the literature and our experimental work over the last two decades. We also provide a summary of the latest polymers developed for application in high temperature and high salinity reservoirs and point out the required testing that we recommend for an appropriate screening of chemicals for offshore EOR applications.\u0000 Each of the steps of the recommended workflow is described showing with actual data the limitations used in some prior screening work. We emphasize the need to move away from ‘ideal’ lab conditions by using representative rock and fluid samples and doing the experiments at reservoir conditions of pressure, temperature and representative saturation, and to consider a variety of scenarios for the testing that describe the expected changes that the polymer solutions will experience during their lifetime in the application, and give a list of the minimal testing needed to get a proper understanding of the potential polymer performance.\u0000 We provide recommendations on the best available polymers for EOR application in offshore assets to date. In summary, for temperatures greater than 95°C and salinity above 90,000 ppm standard polymers like acrylamide, polyacrylamide and partially hydrolyzed polyacrylamide (HPAM) cannot be used, and the promising newly developed polymers include modifications of acrylamide, thermal associated polymers and HPAM functionalized with AMPS monomers.\u0000 In this study, it has been developed an integrated workflow for laboratory screening of polymers for EOR applications in offshore assets and provide recommendations for the selection of polymers for use in high temperature and high salinity assets.","PeriodicalId":214691,"journal":{"name":"Day 4 Thu, May 09, 2019","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130487898","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":"Long Term Well Plug Integrity Assurance – A Probabilistic Approach","authors":"B. Willis, J. Strutt, R. Eden","doi":"10.4043/29259-MS","DOIUrl":"https://doi.org/10.4043/29259-MS","url":null,"abstract":"\u0000 Well plugging and abandonment (P&A) poses significant long-term risks for the industry with thousands of onshore and offshore wells requiring P&A in the coming decades. Historically, operators have typically followed a prescribed P&A approach to meet regulatory requirements. However, a risk-based approach allows bespoke abandonment strategies for individual wells, with the potential to reduce the time and effort needed for low-risk wells, while justifying any necessary additional P&A resources for managing higher risk wells. An advance computational risk-based, predictive well integrity model, STEM-flow, has been developed to support risk-based P&A and new plug technology qualification, and to compliment an extensive material test programme for structural bismuth alloys for plugging and abandonment and carried out as part of a collaborative research program.\u0000 The model enables assessment of leak paths and leak rates with time, addressing multiple plugs and well barrier elements, degradation of barrier materials, cross-flow potential and reservoir re-pressurization. The mathematical model is based on a connectivity matrix, whose elements are effective permeability values, derived from well barrier models, which separate isolated pressurized zones, along a potential leak pathway. Key elements of the approach include the focus on fundamental models for barrier failure mechanisms and the handling of uncertain model parameters through Monte Carlo Simulation to calculate statistical life and probability of failure of plugs and complete well P&A designs. The paper outlines the approach employed by STEM-flow for evaluating and comparing the effectiveness of different P&A designs, plugging technologies, cement plugs and new sealing materials such as creep resisting structural bismuth alloys. Two cases are studied, involving the prediction of plug life and overall life of a specific well P&A design. These cases compare a typical well P&A design for a subsea well in the Central North Sea using conventional cement barriers with that of structural bismuth alloy plugs under development.","PeriodicalId":214691,"journal":{"name":"Day 4 Thu, May 09, 2019","volume":"77 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131015061","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":"Progressive Subsea Field Construction Benefits Projects Net Present Value","authors":"P. d'Huart, V. Cocault-Duverger","doi":"10.4043/29640-MS","DOIUrl":"https://doi.org/10.4043/29640-MS","url":null,"abstract":"\u0000 In the \"lower for longer\" barrel price environment, new projects and field developments need cost effective improved approaches; amongst them, the concept of \"Progressive Subsea Field Construction\". In this alternative concept, construction of elements that are not critical to first oil but only here to support the assets integrity - typically subsea pipelines foundations and consolidating structures - is deferred to the operational life of the facilities, thus benefiting the cash-flow and net present value of a project. This principle is well known to field architects that strive at ensuring that the cash generated from early production is used to finance the rest of the development - \"Production while drilling\" is a typical example of such approach.\u0000 In the vision conveyed in this paper, part of the structural construction can be delivered as a continuous (staged) service rather than an initial investment.\u0000 The paper analyzes two real cases of pipelines in deep-water West Africa, representing the evolution of the state of the art over the past 15 years. It then benchmarks these real cases against a novel approach, to demonstrate the benefits of continuous service in staged construction and integrity management.\u0000 Results provided in this paper demonstrate that there is benefit to the economics of a project, a minimal increase of 2% of a pipeline system Net Present Value, in setting a monitoring procedure, a monitoring device (like a resident subsea inspection vehicle) and data management system to allow for continuous construction. The paper also demonstrates that economic benefit is furthermore amplified when time comes to extend the life of the asset, in such case the Net Present Value of the same system increases by 5%.\u0000 Since the case study focuses on pipeline anchoring, the paper also attempts at showing this concept could be used more extensively in full field developments.\u0000 Indeed, the novel approach proposed in this paper opens the door to a completely novel collaboration model between contractors and operators, establishing continuity of construction during the full life cycle of a field. It aims at generating discussions and new ways of thinking to help the industry evolve towards lower costs of development and more sustainable contracting models.","PeriodicalId":214691,"journal":{"name":"Day 4 Thu, May 09, 2019","volume":"61 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131869301","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":"Applying Depth Correction to Improve Deepwater Reservoir Development","authors":"B. Poedjono, Nnadozie Nwosu, Albert Martin","doi":"10.4043/29345-MS","DOIUrl":"https://doi.org/10.4043/29345-MS","url":null,"abstract":"\u0000 The industry is making discoveries and drilling in areas and formations where along hole depth is of increasing importance. It is essential that the LWD depth meets positional objectives. The driller’s depth, which is the sum of the pipe strap measured while the pipes are on the surface, is used to calculate the logging-while-drilling (LWD) depth. However, environmental corrections must be applied to the driller’s depth resulting from the dynamic mechanical changes pipes undergo while in the borehole, with these corrections applied at the surface. These dynamic changes are due to drilling activities, temperature, and changes in the wellbore profiles and often result in LWD depth being shallower than the actual depth.\u0000 While drilling, dynamic and borehole conditions are known to significantly impact drilling operations and at best a block shift correction or depth matching to wireline depth is applied to the driller’s depth. However, an accurate drill pipe depth determination must include environmental corrections for the dynamic changes in the pipe stretch and compression, which vary with weight on bit, in addition to wellbore profile, torque, drag, friction factor, and borehole temperature.\u0000 In recent years, depth correction has been incorporated successfully in deepwater wells to environmentally correct for these errors and to improve the accuracy of the depth measurement. The challenge for drillers is overcoming the variations in depth measurements, to ensure wellbores are accurately and safely placed in the reservoir. Multiple techniques can be implemented to ensure this occurs, from drill pipe stretch modelling to depth measurements systems. The effect of depth correction has been observed in the multi-well pressure analysis for reservoir compartmentalization studies and fluid contacts.\u0000 Case studies are presented from wells drilled in deepwater where correction was applied to demonstrate its importance in reservoir development. In one case, the placement of pressure and sample points on the most accurate true vertical depth was achieved. By placing the pressure and sample points on the actual depth, a more precise assessment of sand continuity and oil/water contacts was obtained across the field. In another case, determination of the casing landing depth was obtained. In this case, correction was run in near real time to calculate casing stretch, helping to set the casing depth within the expected rathole while running in the hole. The effect of heave on depth on floating rigs often complicates image interpretation. One case study is presented to demonstrate improvement on the image after applying correction.\u0000 Modeling of depth uncertainties prior to drilling to understand the nature and magnitude of the correction is a novel approach and should be utilized in determining in the driller’s depth. The ability to maximize production and optimize drilling time requires LWD/MWD to play a significant role to get it right the first time. Accurat","PeriodicalId":214691,"journal":{"name":"Day 4 Thu, May 09, 2019","volume":"115 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133813306","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":"Design, Testing, and Operation of a Completion Deflector Running and Test Tool for Efficient Multilateral Completions","authors":"M. Stokes, Boris Lajesic, Christian Ramírez, Lester Barett Dupler","doi":"10.4043/29481-MS","DOIUrl":"https://doi.org/10.4043/29481-MS","url":null,"abstract":"\u0000 Trip optimization is essential in multilateral well construction, especially for extended-reach drilling (ERD) wells. This paper describes the design, testing, and operation of a completion deflector running and test tool (RTT) that was recently used during completion of one of the industry's deepest extended-reach multilateral wells. The RTT allows for running and pressure testing of a completion deflector and lower completion components in a single trip, thus saving at least one trip, and up to three trips.\u0000 The challenge was to develop the capability to run a completion deflector with an existing pressure test tool. This was accomplished by converting the pressure test tool into a running tool. The new pressure actuated mechanism built into the tool releases the completion deflector automatically after a successful pressure test. A secondary release mechanism was also incorporated for contingency options. Extensive engineering qualification tests validated the new features to be highly reliable.","PeriodicalId":214691,"journal":{"name":"Day 4 Thu, May 09, 2019","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121191653","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":"Standardization of Procurement Equipment Specifications: A Step Change in Facility Cost and Schedule Reduction","authors":"A. Postema, Dave Wish","doi":"10.4043/29385-MS","DOIUrl":"https://doi.org/10.4043/29385-MS","url":null,"abstract":"\u0000 Over the past decade, projects across the oil and gas industry have been plagued by cost and schedule overruns, exacerbating underlying cost escalation. Rising project costs must be addressed to ensure long term viability of the future capital programs. Standardization is widely recognized as part of the solution, and individual companies have been progressing standardization of specifications within their own businesses. However, the standardization journey is only just beginning: the oil and gas industry still lags others such as the automotive and aviation, as individual companies each maintain their own amendments on otherwise established industry or international standards.\u0000 Joint Industry Program 33 (JIP33), now in its third phase, aims to unlock significant value and drive a permanent reduction in project costs through the development and use of industry-level, global technical specifications for procurement of bulk materials, packages, modules and potentially, even projects.","PeriodicalId":214691,"journal":{"name":"Day 4 Thu, May 09, 2019","volume":"64 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127225549","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}