Day 1 Mon, August 16, 2021最新文献

{"title":"Normalized Modulus Reduction and Damping Ratio Curves for Bay of Campeche Calcareous Clay to Carbonate Mud","authors":"V. M. Taboada, S. Cao, F. A. F. López, D. C. Roque, P. B. Nabor","doi":"10.4043/31153-ms","DOIUrl":"https://doi.org/10.4043/31153-ms","url":null,"abstract":"\u0000 Equations to calculate the modulus reduction curve (G/Gmax-γ) and material damping ratio curve (D-γ) of calcareous clay and clayey carbonate mud of the Bay of Campeche and Tabasco Coastline are developed. This was achieved using a database of 156 resonant column tests and 468 strain-controlled cyclic direct simple shear tests performed in clays with 10 % ≤ CaCO3 ≤90 %. The effects of carbonate content (CaCO3), mean effective confining pressure (σ′m), plasticity index (PI), and overconsolidation ratio (OCR) on the shape of the modulus reduction and material damping ratio curves are shown based on the available laboratory data and the equations developed to calculate these curves. It is shown that as CaCO3 increases, the normalized shear modulus (G/Gmax) curve tends to shift downward and the damping ratio (D) curve tends to shift upward; as σ′m and PI increase, the G/Gmax curve tends to shift upward and the damping ratio curve tends to shift downward; and the value of OCR has practically no effect on the position of the curves. The validation of the calculated values of G/Gmax and D shows the best predictions are found at low shear strains for G/Gmax and at large shear strains for D, falling within ± 25 % of the measured values, and shows that due to limitations in the model at large strains (γ > 1 %) for G/Gmax and at low strains (γ < 0.05 %) for D, the calculated values fall within ± 50 % of the measured values. The equations developed to calculate the curves of G/Gmax-γ and D-γ of calcareous clay and clayey carbonate mud are recommended for preliminary or perhaps even final seismic site response evaluations. However, considering the scatter of the data points around the curves, the equations should be used with caution, and parametric and sensitivity studies are strongly recommended to assess the importance of this scatter. In large critical projects, direct experimental determinations of G/Gmax and D for the soils of interest are suggested to be more appropriate.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84862561","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":"Riser Robotic Inspection - Reducing Safety Risk While Improving Efficiency and Effectiveness","authors":"Neré J. Mabile, Alessandro Vagata","doi":"10.4043/31200-ms","DOIUrl":"https://doi.org/10.4043/31200-ms","url":null,"abstract":"\u0000 Integrity management is an ongoing lifecycle process for ensuring safe operation and fitness for service of offshore oil and gas production systems, including risers. Risers offer a means of transporting fluids between subsea wells and the host platform crossing the splash zone that is probably the most critical region for corrosion and exposure to external damages. Furthermore, with their proximity to the personnel on the platform and to the topside equipment, risers are considered safety critical, and are therefore, subject to planned inspections followed by an engineering assessment of the findings. This paper discusses the motivation and business driver for developing and implementing a new and cost effective risers’ inspection methodology in the splash zone based on innovative robotic platforms. The technical features and the capabilities of the robot are outlined.\u0000 Traditionally, risers’ inspections are carried out by rope access technicians and divers or ROV below the water line using conventional technologies as spot ultrasonic thickness measurements, traditional radiography and visual assessment. This type of inspection is based on a first visual assessment followed by NDE testing only if some finding is spotted. Internal defects or defect under coating, e.g. splashtron, can be easily overlooked, compromising the entire assessment process. Additionally such activities are often limited by accessibility, weather, and Personnel On-Board (POB) accommodations, but primarily they involve risks to inspector's safety.\u0000 Backbone of the presented methodology is the use of a robotic crawler that has the key advantage to inspect autonomously the risers, navigating over obstacles like clamps and supports. The robot can carry a variety of payloads for visual inspections, surface profiling, and NDE examinations with the ability to scan large surfaces with or without coating and detect internal and external defects. It can operate in the topside, splash zone and subsea sections of the riser. The inspection data are processed in real time for an immediate assessment of the integrity of the asset.\u0000 Examples are presented and comparison is made between traditional inspection methodologies and robotic autonomous methodologies to demonstrate the improvement of inspection effectiveness and efficiency.\u0000 The paper also discusses the potential areas of future development, which include Artificial Intelligence (AI) algorithms to further automatize the process and methodologies of risers’ inspection and data analysis.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"18 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75400885","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 Challenge of the West Nile Delta Gas Development: The Rosetta Channel Crossing","authors":"Leonardo Gitahy, D. Manso, Guilherme Carvalho, M. Lewis, Dario Migliaresi","doi":"10.4043/31257-ms","DOIUrl":"https://doi.org/10.4043/31257-ms","url":null,"abstract":"\u0000 Raven is the third stage of the West Nile Delta development (following Taurus / Libra and Giza / Fayoum) from two BP-operated offshore concession blocks, North Alexandria and West Mediterranean Deepwater. The Raven project included the design of various rigid pipelines, of which one specifically is the subject of this paper. The 16\" RSM to RP in-field flowline is approximately 4.8 km long, connecting a manifold (RSM) to a PLEM (RP) through a route that crosses a prominent geological feature identified as the Rosetta Channel, a submerged canyon that extends for about 30 km. The Rosetta Channel is about 2.5 km wide at the location of the 16\" flowline route crossing, with steep slopes going down for approx. 40m (in height) on the RSM side, and then climbing up approx. 150m (in height) towards the RP side.\u0000 Although it is typically preferred to avoid very rough geophysical features, this is not always possible or practicable and it is not uncommon to come across challenging seabed features that demand complex engineering solutions in order to minimise risks and associated costs.\u0000 This paper addresses the numerous technical challenges involved in the design of the 16\" flowline that crosses the Rosetta Channel. Following close collaboration between all involved stakeholders, a robust, reliable and cost-effective solution was achieved after a detailed engineering process, where the final design required a unique combination of mitigations including seabed excavation, pre-lay rock carpets, post-lay rock berms, cable jetting, curve bollards and sleepers.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73076960","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":"Early Interventions for Guyanese Business Development and Optimization","authors":"Treacy Roberts, N. Gaskin-Peters","doi":"10.4043/31016-ms","DOIUrl":"https://doi.org/10.4043/31016-ms","url":null,"abstract":"\u0000 \u0000 \u0000 Esso Exploration and Production Guyana Limited (\"ExxonMobil\"), an affiliate of Exxon Mobil Corporation, and its co-venturers Hess Guyana Exploration Limited and CNOOC Petroleum Guyana Limited, discovered oil in the Stabroek block offshore Guyana during the first half of 2015. The success of safely drilling their first well (Liza-1), followed a history of 40 dry holes in the Guiana Basin prior to ExxonMobil beginning ultra-deepwater oil and gas exploration in 2008 (Varga et al. 2021). Guyana, with a small population of 750,000, was primarily economically focused on agriculture, manufacturing, and the mining of bauxite and gold. ExxonMobil identified the need for an early, focused, coordinated, and long-lasting approach to local content planning to provide tangible results for Guyana. Developing local businesses to actively participate in the industry and enter the supply chain while raising awareness of how the oil and gas industry operates was paramount, as was managing expectations of the Guyanese government and populace about local content.\u0000 ExxonMobil recognized that the established mining sector in Guyana had the potential to provide a base of local suppliers able to transition into the emerging oil and gas sector. It subsequently undertook a number of assessments and studies on the local economy to further understand the local context. The finding of these assessments highlighted that most Guyanese companies were operating in the small local economy or working within the Caribbean region, limiting their exposure to international standards and providing little impetus to become globally competitive. Despite having technical competencies that could be utilized in the oil and gas industry, shortfalls were apparent in the areas of auditable systems, business processes, quality assurance, and safety. Closing the gaps would take time and investment, and a shift in culture in some parts. An internal assessment of ExxonMobil's supplier development programs was conducted, and a Guyana supplier development program was developed by drawing from best practices around the globe. ExxonMobil, with the support of its Stabroek Block co-venturers, took a proactive decision and devised a plan to engage an independent third party to run a \"fit for purpose\" enterprise development centre (EDC) to support the technical development in country through local content prior to final investment decision (FID).\u0000 In order to be equipped to provide early roll out of local content development, and 6 months before FID for Liza 1, ExxonMobil released a Request for Proposal (RFP). Bidders were invited to submit proposals on how the EDC would function \"fit for purpose\" and compliment rather than compete with current Guyanese activities and vendors. The successful bidder, DAI Global LLC (DAI), had a proven track record of international socioeconomic project successes and was selected to form a unique and collaborative, strategic relationship with ExxonMobil. Although DAI h","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"62 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73707852","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":"Innovation and Integration: Exploration History, ExxonMobil, and the Guyana-Suriname Basin","authors":"Audrey L. Varga, M. Chandler, Worth B. Cotton, Erik A. Jackson, Ross J. Markwort, Randy A. Perkey, B. Renik, Tina Riley, S. I. Webb","doi":"10.4043/30946-ms","DOIUrl":"https://doi.org/10.4043/30946-ms","url":null,"abstract":"\u0000 Exploration in the Guyana-Suriname Basin has been a decades-long endeavor, including technical challenges and a lengthy history of drilling with no offshore success prior to the Liza discovery. The 1929 New Nickerie well was the first onshore well in Suriname, and was followed by 30 years of dry holes before the heavy-oil Tambaredjo field was discovered in the 1960s. In the 1990s, nearly 40 years after the Tambaredjo discovery, ExxonMobil utilized the 1970s-vintage, poor-to moderate-quality, 2D seismic and gravity data available to create a series of hand-drawn, level-of-maturity (LOM) source and environments-of-deposition (EOD) maps over the basin to move their exploration efforts forward. This work established the genetic fundamentals necessary for understanding the hydrocarbon system and led to negotiation for and capture of the Stabroek Block in 1999.\u0000 The Liza-1 success in 2015 spurred extensive activity in the Basin by ExxonMobil and the Stabroek Block co-venturers, Hess Guyana Exploration Limited and CNOOC Petroleum Guyana Limited (Austin et al. 2021). The collection of extensive state-of-the art seismic data has been leveraged to enable successful exploration of multiple play types across the Guyana-Suriname Basin. Further data collection, including over 2 km of conventional core and additional seismic data acquisition and processing, has enabled ExxonMobil to adopt interpretation techniques that are applied across the entire basin to characterize and understand the subsurface better.\u0000 From initial hand-drawn maps to the use of advanced technology today, ExxonMobil's work in the Guyana-Suriname Basin has relied on integration of geologic and geophysical understanding as well as the ability to leverage new technology to continue a successful exploration program with 8 billion barrels discovered to date.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"25 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81994974","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":"Innovation to Reduce Operation Downtime in Sulfate Removal Offshore Applications","authors":"Yolanda Cuenca, Àngels Tejero, S. Das, Daniel Brooke-Peig, Philip Martin, F. Bechir","doi":"10.4043/31279-ms","DOIUrl":"https://doi.org/10.4043/31279-ms","url":null,"abstract":"\u0000 Sulfate removal in injection water is standard practice to prevent scaling and souring in subsea oil reservoirs. Nanofiltration membranes have been used to this purpose since 1987, when FilmTec™ SR90-400 elements were installed in an offshore platform in the North Sea. The most pressing concern in this type of systems is membrane fouling, with the associated reduction in effective plant operation time and shorten element lifespan caused by the standard Clean-in-Place (CIP) protocols. The object of this research has been to test the latest developments in biofouling-resistant sulfate removal membranes to achieve oil and gas (O&G) industry requirements. Improved chemistry and improved module engineering have enabled the production of new membrane elements that represent the next-generation in sulfate removal nanofiltration. Next-generation sulfate removal membranes have been trial-tested. In pilot testing, target performance was validated in terms of productivity, permeate quality and fouling resistance. The results of this testing indicate that improvements in membrane chemistry and module engineering have resulted in a 63% decrease in pressure drop and a much slower fouling trend over the total of 6 elements. This significant improvement should allow an important reduction in the number of cleanings, which the authors have estimated to be of 50%. Moreover, sulfate rejection values are in the range of 99.9% (below 1 ppm of sulfate in the permeate), providing great injection- quality water. Full-scale testing in a production site in the Atlantic Ocean was done to validate pilot testing results, showing a continued operation of 100 days without any need for a clean-in-place (CIP) procedure. The results obtained in the extensive testing carried out on these new antifouling elements, show that the improvements implemented in its design have the ability to improve the operation of Sulfate Removal Units (SRU). These improvements are the results of reducing maintenance costs and downtime on offshore platforms, resulting in increased operation and improved productivity.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"10 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90535121","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":"Seismic Attributes and Acoustic Inversion for Shallow Marine Slope Stratigraphy Analysis","authors":"J. Son, Rebecca Boon, Julien Kuhn de Chizelle","doi":"10.4043/31102-ms","DOIUrl":"https://doi.org/10.4043/31102-ms","url":null,"abstract":"\u0000 Geophysical seismic surveys have been used in marine site characterization for subsea engineering and the design of offshore structures. Signal processing plays a key role in obtaining seismic attributes from observed seismic data to identify subsurface geological features within complex shallow sediments. Instantaneous amplitude, phase, and frequency are the most widely used seismic attributes to indicate geological features, but those time-domain data are too limited to define an accurate subsurface model in depth. Therefore, seismic inversion is also required to generate additional geospatial subsurface model information to aid in shallow stratigraphy interpretation. In this paper, we applied both geophysical signal processing and stochastic seismic inversion to a high-resolution multichannel seismic dataset from the Eastern North American Margin (ENAM). Seismic attributes from the Hilbert transform and inversion modeling results (acoustic impedance and modeling uncertainty) were integrated to define better geological horizons and discontinuities. The results show the integrated geophysical subsurface models can support seismic interpretation and improve shallow marine site characterization.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"15 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90771634","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":"Water Injection Pipeline Repair Offshore Angola Enhances Production","authors":"Kamil Sobolewski","doi":"10.4043/31015-ms","DOIUrl":"https://doi.org/10.4043/31015-ms","url":null,"abstract":"\u0000 An international operating company detected a leak during an annual ROV inspection of a water injection (WI) pipeline offshore Angola in the Gulf of Guinea. The pipeline owner made the decision to repair the damaged line using clamps, but there were multiple challenges involved in executing the repair. First was the depth of the pipeline, which was on the seabed across an area that ranged from 1,170 m to 1,410 m (3,839 ft – 4,626 ft). Additional challenges included potential complications for clamp installation because of the location of the pipe welds and the physical condition of the pipe, which had experienced considerable wall thinning in multiple areas. Bringing the pipeline back into safe service required repairs to the aging pipe within a scope of work that included site preparation, the installation of two 12-in clamp connectors, and inspection services following clamp placement to verify proper installation.\u0000 Because there were welds in the WI pipeline, there was a risk that the clamp installation site would correspond with an area of the pipe that was welded, which would impact the ability of the clamps to fit snugly over the damaged area. Survey data were cross-referenced with the client's data to determine that the weld locations would not interfere with the installation. Coating removal was critical, so a purpose-built mechanical tool was designed to prepare the pipeline for clamp installation. The project also required finite element analysis (FEA) to confirm that the pipeline could withstand the seal load applied by the repair clamps.\u0000 The project was carried out in three steps. The objective of the first step was to prepare and stabilize the seabed to ensure it could bear the weight of the clamp installation frame and the impact of the ROV working nearby. The second phase focused on preparing the repair locations for installation of the clamps, a process that included coating removal and surface cleaning to return the WI pipeline to bare metal finish in the clamp areas. The third phase was the preparation and installation of the 12-in repair clamps. This included the inspection and spot cleaning of pipeline surfaces, clamp installation, and clamp seal verification.\u0000 The two clamps were successfully installed and passed pressure testing in February 2020, enabling the operator to bring the WI line back online and functioning safely at reduced pressure.\u0000 This repair employed the highest-pressure clamp of this type installed to date (138 bar / 2,000 psi).","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"29 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76916114","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":"Nanomaterials Improve Polymer-Based Gravel-Packing Fluids at High Temperature","authors":"R. Prabhu, J. Santamaría, Nirupama A Vaidya, P. Abivin, V. Lafitte, B. Gadiyar","doi":"10.4043/30967-ms","DOIUrl":"https://doi.org/10.4043/30967-ms","url":null,"abstract":"\u0000 A gravel packing fluid system was developed for elevated temperature applications above 290°F comprised of xanthan gum and a high-temperature gravel suspension additive. This fluid system has been successfully pumped in four openhole gravel packing operations so far, validating its suitability for Alternate Path gravel packing technology involving shunt tubes. Laboratory qualification testing for this fluid showed excellent gravel suspension, rheology, and breaking profiles for cleanup and minimal damage during production.\u0000 Xanthan gels have been used in gravel packing applications for many years. However, by itself, xanthan was unable to suspend gravel at temperatures above 290°F possibly due to onset of thermally activated polymer degradation. This paper demonstrates that gravel suspension ability can be vastly improved with the addition of a recently developed nano-additive. This additive is a specially designed versatile nanosized material that has a proven track record with visco-elastic surfactant fluids in the past. In the present study, we show the successful application of this additive with polymer-based carrier fluids such as xanthan, effectively increasing their application range to 325°F. With the inclusion of this suspension additive, xanthan concentration in the fluid system can also be reduced, which has other potential benefits such as better cleanup after gel break.\u0000 Extensive laboratory evaluation for fluid qualification was performed prior to the job. High-pressure/high-temperature (HP/HT) rheology measurements were performed using industry-standard rheometers at various shear rates to match specific viscosity requirements for shunt tube applications. Gravel suspension tests performed using special pressurized cells immersed in oil bath at the required bottomhole static temperature showed improved gravel suspension with the nano-additive. Fluid breaking with conventional oxidative breaker was also demonstrated with viscosity measurements. Formation response tests showed very good fluid cleanup with 90% regained permeability.\u0000 Laboratory testing and successful field applications have proven the effectiveness of this new fluid system.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"75 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79357162","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":"Guyana: Liza Phase 2 Novel Execution to Accelerate Field Development","authors":"Lawson Burns, Theresa Allen, Jeff Karlik, J. Ding, Rea Cauthen, Mita Das, Guy Ashley, R. Szafranski","doi":"10.4043/30948-ms","DOIUrl":"https://doi.org/10.4043/30948-ms","url":null,"abstract":"\u0000 The Liza Phase 2 Project combines a novel execution approach and forward-looking technology components to develop more complex areas of the Liza resource. The project delivers technology to optimize resource development through efficient Subsea, Umbilicals, Risers, and Flowlines (SURF) equipment designs and digital elements to enable future capabilities, such as a fiber optic cable to shore. For a new approach to Floating, Production, Storage and Offloading (FPSO) delivery, the project is partnering with SBM for the first ever use of their Fast4Ward® concept.\u0000 The SBM Fast4Ward® program utilizes the Multi-Purpose Floater (MPF) hull design and provides the benefits of a new build FPSO with a reduced project development time similar to that of conversions. With almost double the SURF infrastructure as Liza Phase 1, Liza Phase 2 uses learnings and standardized SURF architecture to deliver one of the industry's largest subsea developments. Establishment of win-win partnerships with the primary contractors to achieve best overall value and strategic use of part number duplication contribute to the overall success.\u0000 Based on the work of ExxonMobil proprietary reservoir modelling, infrastructure is being installed to enable Water Alternating Gas (WAG) injection for the complex development while a subsea fiber optic cable enables data to shore for optimized reservoir management and advanced facilities surveillance.\u0000 The project is on track to deliver ~2 years after first oil was achieved for Liza Phase 1 by building on design replication and common methodologies where possible. Through thoughtful application of standardization, learnings, and incorporation of new technologies, the project efficiently delivers advanced capabilities to the Liza field. This also enables a \"Design One, Build Multiple\" (D1BM) approach for future developments in Guyana.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"43 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82206394","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}