Digitalization is disrupting how offshore oil and gas industries conduct and manage operations. By 2025, it is projected that there will be more than 50 billion devices connected to the internet. This is having a disruptive effect on many industries, including transportation, financial services, and the media, among others. The oil-and-gas sector in Newfoundland and Labrador is also experiencing significant changes as a result of digital computing technologies. Disruptive technologies of digitalization are changing traditional business models and giving rise to the digital economy.
Installation of a fiber optic cable between Newfoundland and offshore installations on the Grand Banks has enabled implementation of digital technologies which can improve safety, reliability, and profitability of offshore operations. An overview of the fiber optic infrastructure and recently established Onshore Support & Control Center (OSCC) is presented along with technical, organizational, and operational considerations for its design. To date, use of the OSCC has improved operator training, allowed shifting of offshore roles to onshore, and enhanced support of and collaboration with offshore operations. In order to implement future digital technology opportunities and capture additional benefits, a digital roadmap has been developed along with associated organizational changes to manage implementation.
The Hebron Offshore platform is an oil drilling, production, living quarters and storage facility planned to be installed in the Jeanne d’Arc basin on the Grand Banks approximately 350 km east, southeast of St. John’s, Newfoundland and Labrador, Canada in 2017.
The platform has three major elements: the modular topside facilities, the reinforced concrete gravity base structure (GBS), and crude oil offloading system (OLS). This paper addresses the current engineering and ongoing construction of the Hebron modern iceberg resistant GBS solution.
Based on the relevant environmental conditions and functional requirements specific to the Hebron GBS project, the following areas will be discussed, focusing on general learnings with future applicability: HSSE Design considerations and constructability Project execution Construction Local content
Design considerations and constructability
Fog in northern climates and Arctic environs can be a risk to helicopter operations and shipping interests, as are high seas from severe storms that frequent these regions. Visibility conditions and forecasts determine whether helicopters can safely land on offshore facilities, or if personnel will need to be transferred by ship. High sea state conditions can affect offshore oil and gas exploration and production operations, including drilling, logistics, crane operations and emergency response.
A workshop on Metocean Monitoring and Forecasting for the Newfoundland & Labrador Offshore, held 22-24 September 2014, identified the need of improving the visibility and severe sea state forecasting for Grand Banks which can have a positive contribution to safety and operations in the harsh North Atlantic Canada offshore environment. This has led to an open and collaborative multi-year Metocean Research and Development Project that is presently in its third year. Some twenty government, academic, and industry agencies are participating in this project.
Detailed buoy and offshore installations-based scientific measurements have been collected over the past three years where previously there has been a lack of good quality observations. A climatology of low visibility (less than 1km) events shows a high frequency (about 55% of the time) during summer months. A "conceptual model" of Grand Banks fog has been developed, that defines the physical conditions under which fog develops, is maintained, moves and dissipates. The conceptual model will be the basis for the development of new visibility prediction systems which currently are not well established or verified. High seas, with wave heights over 6m, occur more frequently during winter. Sea state prediction systems are being evaluated for severe ocean wave conditions where they have reduced predictive skill. Currently, work is underway to establish the accuracy and consistency of several existing visibility and sea state prediction systems.
This paper will illustrate results from the climatological studies and some of the unique metocean monitoring data being collected. The forecasting techniques (e.g. numerical atmospheric and oceanic prediction models, satellite-based schemes, and rules based systems) being evaluated, are outlined.
Shafrova, Svetlana (ExxonMobil Upstream Research Company) | Holub, Curtis (ExxonMobil Upstream Research Company) | Harris, Matthew (ExxonMobil Upstream Research Company) | Cheng, Tao (ExxonMobil Upstream Research Company) | Matskevitch, Dmitri (ExxonMobil Upstream Research Company) | Foltz, Raymond (ExxonMobil Upstream Research Company) | Mitchell, Douglas (ExxonMobil Upstream Research Company)
A Common Operational Picture (COP) can generally be described as a system of hardware and software that produces a shared display of information to facilitate situational awareness and decision making. A brief history of the development and use of COP technology in Arctic operations is provided. Experience and learnings from ExxonMobil's research into the use of COPs in ice management and Arctic floating drilling is described. Experience gained from simulations, desktop studies, and field observations is used to frame preliminary functional requirements for such technology needed for future Arctic floating drilling operations in high concentration ice. The COP must facilitate the planning and execution of complex and remote operations with many geographically distributed assets (e.g., drilling rig; icebreakers; shore base; manned or unmanned aviation) and stakeholders (e.g., icebreaker captains, drilling management, ice analysts, weather forecasters) at times communicating over limited bandwidth channels. The COP will serve to collect, store, communicate, and display the necessary data and information. The role of COP components (e.g., databases; communication network, displays) is described and functional requirements are outlined.
This paper introduces a potential novel concept for glacial ice management. The concept involves the capability of a platform and its riser and mooring systems to shift for a relatively large distance— hence the ‘sidestep’ term—in order to bypass the glacial ice. However, in order for the platform to be able to sidestep, the platform needs to be equipped with features which support the large distance movement.
For floating platforms like semi-submersibles, the sidestep movement may be accomplished by varying the tension rate of the mooring system to make it more slack or taut. However, a turret-moored FPSO needs to have a larger thruster capability, since the sidestep movement will be executed by the use of thrusters. This sidestep capability can be used as an additional safety measure for floaters operating in deep-water regions, which are susceptible to glacial ice. In particular for a turret-moored FPSO, this capability may be beneficial as an option prior to the turret disconnection.
For this concept, the configuration of risers and mooring system should be carefully designed to withstand the shifting conditions, as the riser and mooring system will still be attached to the platform during the sidestep process. A steel riser in a lazy wave configuration (SLWR) is proposed to fulfill this requirement.
This paper discusses the benefits and challenges of the sidestep concept. This paper also presents the analysis results of a lazy wave riser during the sidestep condition. Analysis works are carried out using the OrcaFlex simulation program.
Oil and gas activities have now reached the ‘new frontier’ areas within the Arctic Circle. This area has always been regarded as challenging due to the harsh environmental conditions, which are characterized by sub-zero temperatures, severe sea-states, intensive seasonal fog and glacial ice masses.
Glacial ice occurs in many areas of the Arctic and sub-Arctic regions, for example west and south east of Greenland, west of Baffin Island, on the Green Banks and in the Russian Arctic. Each of the field developments in the area above has its own specific ice management strategies. However, the strategies generally have two objectives: to ensure the safety of the assets (people, installations and environment) and to maximize operational efficiency.
Copyright 2014, Offshore Technology Conference This paper was prepared for presentation at the Arctic Technology Conference held in Houston, Texas, USA, 10 - 12 February 2014. This paper was selected for presentation by an ATC program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Offshore Technology Conference and are subject to correction by the author(s). The material does not necessarily reflect any position of the Offshore Technology Conference, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Offshore Technology Conference is prohibited.
Subsea structures on the seabed may be impacted by free-floating or scouringicebergs. A drift-based Monte Carlo iceberg contact model was developed as partof the SIRAM (Subsea Ice Risk Assessment and Mitigation) program forcalculating iceberg impact risk for subsea structures on the northeast GrandBanks offshore Newfoundland and the Makkovik Bank on the Labrador Shelf. Themotivation for developing this model was to characterize the influence ofbathymetry (i.e., seabed orientation, ridges and basins) on iceberg interactionrates with subsea structures. Results were incorporated into a GIS-basedapplication to allow iceberg contact rates to be calculated for structures witha range of plan dimensions and elevations at various locations.
Copyright 2012, Offshore Technology Conference This paper was prepared for presentation at the Offshore Technology Conference held in Houston, Texas, USA, 30 April-3 May 2012. This paper was selected for presentation by an OTC program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Offshore Technology Conference and are subject to correction by the author(s). The material does not necessarily reflect any position of the Offshore Technology Conference, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Offshore Technology Conference is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. Abstract The emergence and near exponential growth of regional gas markets has been driven by a number of factors, including a decisive shift of the power sector to natural gas fired power stations, the burgeoning demand for gas at city gates, and switch of industrial consumers to natural gas from other fossil fuels. The pressure to bring these mid-tier reserves (estimated to be in the excess of 2,000 Tcf) to the market is compelling.