In 1993, Richard D’Souza (Fellow), the principal author and his co-authors presented a landmark paper reviewing the Semisubmersible Floating Production System (FPS) technology at the SNAME centennial meeting in New York. (D’Souza et al., 1993a). The paper captured the twenty year progression of the FPS beginning with the Argyll field in the UK Sector of the North Sea in 80 meters of water that was converted from a semisubmersible Mobile Offshore Drilling Unit (MODU) and began producing in 1975. During this period about twenty five FPSs were installed, primarily in the North Sea and Brazil. Most were converted from semisubmersible MODUs. The deepest was in 625 m, the largest displacing 45,000 mt and the maximum oil rate was 70,000 bopd.
Over forty FPSs have been installed since then, most of which are purpose built platforms. The technology has expanded to a maximum water depth of 2400 m, displacements exceeding 150,000 mt and production rates of 300,000 boepd. The inherent versatility and flexibility of the FPS to adapt to a wide range of water depths, payloads, metocean conditions and future expansion, has resulted in the FPS superseding the Tension Leg Platform (TLP) and the Spar platform as the most widely used floating production platform after the Floating Production Storage and Offloading (FPSO) platform. Its field development applications range from marginal reservoirs to giant deepwater oil and gas fields across the globe.
This paper, authored by Richard D’Souza with a new team of co-authors, is a sequel to the 1993 paper and is intended as a historical and technical archive of the evolution of the FPS technology in the ensuing twenty five years. It highlights the importance of the Naval Architect and Ocean Engineer whose role has evolved from a peripheral to a major player in the design, fabrication and installation of the FPS. This paper has two objectives. One is to inform Operators and Contractors engaged in developing deepwater fields by providing a historical overview of lessons learned and technology evolution of the FPS. The other is to inspire graduate and post graduate Naval Architects and Ocean Engineers to consider a career in the offshore industry where they will have an impactful role in shaping the future of deepwater floating production platforms.
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The DMCC Free Zone, one of the world’s leading hubs for commodities, trade and enterprise successfully attracts key participants throughout the entire value chain of a wide range of commodity sectors along with a range of businesses from shipping to trade, recruitment, to IT and advertising, through to restaurants, retail stores, gyms, nurseries, luxury brands, universities and more. Industry participants and Free Zone member companies enjoy access to market infrastructure and physical facilities such as gold and diamond vaults, trading platforms like the Dubai Gold & Commodities Exchange, Dubai Diamond Exchange, the Dubai Pearl Exchange and DMCC Tradeflow, the dedicated online platform for registering possession and ownership of commodities stored in UAE-based storage facilities; the DMCC Tea Centre and a range of commodities backed financial investment tools. Oil Review Middle East is the region's leading oil and gas magazine. Edited in both English and Arabic, Oil Review offers authoritative coverage of upstream and downstream developments in the Middle East and North Africa. Each issue contains a potent mix of industry & technology news, business intelligence & analysis, country reports, sector surveys, technical features and event previews.
Lv, Mingsheng (Al Yasat Petroleum Operations Company Ltd) | Al Suwaidi, Saeed K. (Al Yasat Petroleum Operations Company Ltd) | Ji, Yingzhang (Al Yasat Petroleum Operations Company Ltd) | Swain, Ashis Shashanka Sekhar (Al Yasat Petroleum Operations Company Ltd) | Al Shehhi, Maryam (Al Yasat Petroleum Operations Company Ltd) | Luo, Beiwei (Al Yasat Petroleum Operations Company Ltd) | Mao, Demin (Al Yasat Petroleum Operations Company Ltd) | Jia, Minqiang (Al Yasat Petroleum Operations Company Ltd) | Zi, Douhong (Al Yasat Petroleum Operations Company Ltd) | Zhu, Jin (Al Yasat Petroleum Operations Company Ltd) | Ji, Yu (Al Yasat Petroleum Operations Company Ltd)
Western Abu Dhabi locates in the west of Rub Al Khali Basin, which is an intra-shelf basin during the Late Cretaceous. The Shilaif source, Mishrif reservoir and Tuwayil seal forms one of the Upper Cretaceous important petroleum systems in the western Abu Dhabi Onshore. However, less commercial discoveries have been achieved within Mishrif Formation during the past 60 years since the large scale structures were not developed in western Abu Dhabi and the stratigraphic traps have not been attracted attention.
This study aims to investigate the exploration potential of both Mishrif structural and stratigraphic traps. It provided detailed study on Shilaif source rock, Mishrif shoal/reef reservoir and Tuwayil seal capability. Oil-source rock correlation, reservoir predication and basin modeling have been carried out for building Mishrif hydrocarbon accumulation model by integration of samplings, wire loggings and 2D&3D seismic data. Shilaif Formation is composed of laminated, organic-rich, bioclastic and argillaceous lime-mudstones and its generated hydrocarbon migrated trending to high structures. Three progradational reefs/shoals in Mishrif Formation were deposited along the platform margin, which are characterized by high porosity and permeability. Tuwayil Formation consists of 10-15ft shale interbedding with tight sandstone, acting as the cap rock of Mishrif reservoirs.
Mishrif hydrocarbon accumulation mechanism has been summarized as a model of structural background controls on hydrocarbon migration trend and shoal/reef controls on hydrocarbon accumulation. It is consequently concluded that Mishrif reefs/shoals overlapping with structural background are the favorable exploration prospects, and oil charging is controlled by heterogeneity inside a reef/shoal, the higher porosity and permeability, the higher oil saturation. Two wells have been proposed based on the hydrocarbon accumulation model, and discovered a stratigraphic reservoir with high testing production. This discovery encourages a new idea for stratigraphic traps exploration, as well as implicates the great exploration potential in western Abu Dhabi.
Pang, Mengqiang (Hohai University) | Ba, Jing (Hohai University) | Yu, Cun (Hohai University) | Zhou, Jian (Hohai University) | Wang, Enjiang (Hohai University) | Jiang, Ren (China Petroleum Exploration and Development Research Institute, Langfang Branch)
The attenuation (Q−1) of medium is a parameter more sensitive to pore fluid than seismic velocities for gas-bearing reservoirs, thus accurate estimation of seismic attenuation is very meaningful for exploration of natural gas reservoirs. In this paper, we used the quality factor to carry out the seismic identification of carbonate reservoirs and estimate the Q values point by point of the target layer by using S transform and improved frequency shift method. In addition, the two-dimensional Q profiles of some survey lines and the three-dimensional Q section of the whole area were extracted. The results show that the Q value is low in the gas-bearing area with high-porosity, and the attenuation is anomalously high. And in the non-gas-bearing area with low-porosity, the Q value is higher, with no attenuation anomaly. The analysis method of attenuation effectively reflects the absorption characteristics and gas-bearing differences of the stratum, and can be effectively used in reservoir prediction.
Presentation Date: Monday, October 15, 2018
Start Time: 1:50:00 PM
Location: Poster Station 5
Presentation Type: Poster
A power plant has operated for approximately 25 years at Brady Natural Lab where both artificial and natural recharge keep the reservoir pressurized (Cardiff et al., 2018; Folsom et al., 2018, Feigl et al., 2018). A vibrating source injected the 3 modes (P, transverse S, and longitudinal S) at 191 source locations during four stages of the 15-day field experiment. The four stages describe different production and injection regimes performed vary depending on if the fiber is installed behind casing or in tubing (Raterman et al., 2017). Specifically, this paper focuses on understanding the vertical DAS (DASV) data and the extent to which DASV can be used for imaging of the steeply dipping faults. The DASV have potential to be more sensitive to the faults than the horizontal DAS and surface geophones, which given the acquisition geometry are prone to spatial aliasing (Jreij et al., 2018). However, DASV are only recorded in Well 56-1 location, and unfortunately, the fiber is not securely coupled to the casing but is hanging freely (Feigl et al., 2017). However, the frictional coupling allowed for reflection signals to be detected, similar to what is seen and described in Munn et al. (2017) and Lindsey et al. (2017).
Dai, Jianfang (CNOOC(China National Offshore Oil Corporation) Ltd Tianjin Branch, Tianjin, P.R.China) | Wang, Mingchun (CNOOC(China National Offshore Oil Corporation) Ltd Tianjin Branch, Tianjin, P.R.China) | Jiang, Liqun (CNOOC(China National Offshore Oil Corporation) Ltd Tianjin Branch, Tianjin, P.R.China) | Qin, Dehai (CNOOC(China National Offshore Oil Corporation) Ltd Tianjin Branch, Tianjin, P.R.China)
The characterization of volcanic rocks, especially the identification of the bottom interface is the key to reservoir exploration. Based on the veriety of the volcanic rock's response in petrophysical analysis and the difficulty to identify volcanic rock in the profile, we use pre-stack AVO attribute analysis and post-stack amplitudevariations-with frequency (AVF) inversion on the study of volcanic rock type and logging response characteristics to avoid the limitation of single seismic data and single attribute. By using this method, the top and bottom interfaces of volcanic rocks are clear and it provides a strong support for reservoir research and well deployment. Introduction With the continuous deepening of geological understanding, the volcanic rock, once known as the'restricted zone', has become a hot spot for oil exploration, but due to the diversity of volcanic lithofacies, it is difficult to be recognized. In recent years, the use of seismic response characteristics of volcanic rocks, wave impedance inversion, and seismic attribute prediction methods have become important means of describing volcanic rocks.
Acoustic impedance (AI) is the key elastic parameter for seismic inversion and is generally divided into background AI and relative AI for linear inversion. Ideally, to obtain the accurate absolute AI model, the estimated background AI and relative AI should be merged seamlessly. However, in practice, the intermediate frequency components of the AI model are usually poorly reconstructed, so the merged AI will suffer the error caused by the frequency gap. To remedy this error, priori information should be incorporated to narrow down the gap. With the knowledge that the reflectivity series underground is sparse, we solve an L1 norm constrained problem to seek for a more broadband reflectivity section. The absolute AI mode is then estimated with the broadband reflectivity section and the given background AI. The combined first and second order total variation (TV) regularization is introduced to preserve the geological structure of the AI model while eliminating the staircase effect caused by the single first-order TV norm. The numerical examples tested on Marmousi AI model demonstrate the effectiveness of the proposed methods.
Presentation Date: Wednesday, October 17, 2018
Start Time: 8:30:00 AM
Location: 206A (Anaheim Convention Center)
Presentation Type: Oral
Jreij, Samir F. (Department of Geophysics, Colorado School of Mines) | Trainor-Guitton, Whitney J. (Department of Geophysics, Colorado School of Mines) | Simmons, James L. (Department of Geophysics, Colorado School of Mines)
Distributed sensors have widely been used in boreholes and their added value is apparent in these environments. Surface acquisitions with distributed sensors have not been quite as successful due to the limited understanding of the types of waves that the instrument records. This paper discusses experiments to identify if there is any added value to using distributed acoustic sensors with sparse geophone arrays in 2-D surface acquisition. The results qualitatively show that 2-D surface DAS arrays are able to recover migrated images similar to sparse, multi-component geophone arrays. Quantitative analysis was also performed using transfer learning in a convolutional neural network. The quantitative analysis shows that adding distributed sensors for this experiment only helped in decreasing false negatives and increasing the true negatives in identifying reflectors. This paper provides the framework for future quantitative analysis in the geophysics field using machine learning.
Presentation Date: Thursday, October 18, 2018
Start Time: 8:30:00 AM
Location: 212A (Anaheim Convention Center)
Presentation Type: Oral
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