The journey towards the realization of the subsea factory is well on its way, promising the benefits of subsea processing and production. This "Grand Challenge" places extreme demands on the reliability, uptime and safety of the technology for distributing, delivery and control of the power system. ABB Oil & Gas is running a Joint Industry project together with Statoil, Total and Chevron to develop technologies for subsea power transmission, distribution and conversion at greater distances, in deeper waters, and in harsher environments. The project started up in 2013 and is targeting a 3000-hour shallow-water system test in 2018, including the qualification of pressure tolerant medium voltage switchgear, medium voltage drives, as well as supporting controls and auxiliary supplies. The project budget is in excess of 100 MUSD, funded by ABB, Statoil, Total, Chevron as well as The Research Council of Norway. The target environment is water depths up to 3000 meters, transmission distances up to 600 km, and power levels up to 100 MW. The project follows the TRL development stages for technology qualification applied to components, sub-assemblies and equipment. This is a systematic approach ensuring that the technology will function reliably within specified limits, and it provides a common understanding and terminology of technology status and risk management. Qualification includes extensive testing of components subjected to test conditions derived from a common understanding of realistic component/equipment specific stresses throughout an agreed life-cycle mission profile, with particular emphasis on learning the behavior and limits of different designs. Comprehensive confirmation of the desired function as well as reliability testing is primarily conducted at the level of the component where a functional failure can be defined and accelerated conditions applied. Further, we perform sub-assembly testing mainly geared toward confirming the overall function, design margins, and the thermal and high-current performance. Formal qualification of key components and sub-assemblies is planned for 2017. Based on qualified components, final prototypes will be assembled in 2018 for a 3000 hour shallow-water endurance test and system demonstration. The project passed a decision gate milestone in April 2015, having verified technology concepts as well as TRL2 for key components. Prototypes under development include full-scale subsea drives and switchgear with supporting controls and LV auxiliaries and functional verifications in key ABB factories. During 2016 key prototype designs have been tested and functionally demonstrated over a limited operating range. This paper provides a summary of the current status of the project highlighting the most critical areas for success, such as designing for modularity and the demanding reliability and availability targets, and utilizing the best experts and experience across ABB as well as the participating oil companies.

Additive manufacturing (AM) is estimated to grow significantly in the next few years, the potential for AM is significant, however, AM is not the plug and play technology that it appears to be, AM works for specific applications, the first question that should always be asked is ‘does it make sense to make the product using AM compared to more traditional methods of manufacture’. The hype around AM has led many traditional manufacturers to assume that the manufacturing controls and material properties for a given material produced by AM processes are similar (if not the same) as those required and resultant from a conventional manufacturing process (such as a forging). There are many individual steps involved in the process of manufacturing a part by AM. In order to have confidence in the integrity of the part each of these individual steps must be carried out correctly and can greatly reduce production cost and time, yet there is no standardized way of proving to manufacturers and regulators that printed products are safe. LR is working with a number of partners, to consolidate research and development efforts, alongside real-world AM practices, to create new product certification guidelines - paving the way for widespread adoption of the technology. The purpose of the guidance document is to provide industry with goal-based certification guidelines for the manufacture of metallic parts/components using additive manufacturing (AM).

Abstract Although more than 1,000 exploration and development wells have been drilled through the zone of hydrate stability in the deepwater Gulf of Mexico, gas hydrate has not been documented as a serious drilling hazard. Acquisition parameters and survey design of 3D exploration seismic are not optimized for shallow sediments and do not allow accurate characterization of naturally occurring hydrate. Deep stratigraphic test wells drilled through hydrate deposits in spring 2005 will allow calibration of geophysical data and provide information of the impact of hydrate drilling and production on seafloor stability. Introduction There has been considerable debate in recent years about drilling safety, long-term wellbore integrity, and foundation stability for subsea facilities during deepwater petroleum operations in gas-hydrate areas. With more than 1,000 Gulf of Mexico exploration and development wells drilled through the zone of hydrate stability, however, there are still no documented reports of significant drilling problems associated with gas hydrates. In most of these wells the shallow hydrate-bearing section to at least 2,000 feet below the seafloor is drilled riserless, and Logging While Drilling curves for the large-diameter shallow hole are the only available information. Geohazard assessment of the entire lease block and hazards evaluation of the drillsite and associated anchor and chain positions must be completed, reviewed, and approved before drilling. In a few cases, anomalous amplitudes, seismic blanking, shingling, or a bottom-simulating reflector (BSR) indicate hydrated sediment on conventional or high-resolution seismic data, but to date shallow water flow (SWF) is the only deepwater geohazard with an important economic impact in this province. While SWF sands generally occur at drilling depths similar to gas hydrates, any association of these occurrences remains unproven. Four pairs of 1,000- to 2,000-foot dedicated gas-hydrate wells with additional coring on an active gas-hydrate mound are planned by the Department of Energy Gulf of Mexico Gas Hydrate Joint Industry Project (JIP) at two locations this spring. Four wells in Keathley Canyon Block 151 will be drilled through gas hydrate above a BSR with a complete log suite and up to 30 percent core recovery. A similar drilling program in Atwater Blocks 13 and 14 will provide samples and information on the flanks of an active seafloor hydrate mound. Results of JIP hydrate drilling and other preliminary studies will yield critical ground truth data on the distribution and hazard potential of Gulf of Mexico hydrates. Drilling Experience in Hydrate Areas To date, drilling through gas hydrates has not been considered a high-risk situation. The shallow section in the zone of hydrate stability in deep water, however, is drilled riserless as a large diameter hole with returns deposited on the seafloor. Fracture gradients in these sediments are low and there is a narrow margin between minimum and maximum mud weights that can be used. The deepwater conductor hole section is typically drilled using seawater and gel sweeps until wellbore instability or shallow water flow is encountered. Weighted waterbase drilling mud is then used to kill any flow or overcome hole stability problems.

Abstract The methods and the technology for deepwater geotechnical investigations in the Gulf of Mexico (GOM) have evolved over a number of years, and this evolution has been punctuated by several technological advancements. Deepwater geotechnical investigations are now pushing the limits of present capabilities, both in terms of drilling and in situ testing tools. More efficient and advanced tools are being developed to keep pace with the ever increasing water depth requirements and the related technological challenges. This paper describes some of the recently developed tools. Where existing tools have been modified, both the shortcomings and improvements are discussed, The tools described in the paper include the small-diameter piezoprobe, wireline hydraulic fracture tool, Halibut II remote vane shear system, and the long-stroke cone penetrometer system, whichis still in the initial stages of development. Also described in the paper are the ongoing joint industry projects that are part of this tool development effort. Investment and continuoustool development will make it possible for the geotechnical community to meet the future challenges in 2000-m to 3000-m water depth. Introduction The oil and gas industry continues moving into ever deeper waters of the Gulf of Mexico. The enthusiasm demonstrated in recent rounds of deepwater lease sales suggest that the industry is now prepared to invest in deepwater exploration and production. The march into the deep waters of the Gulf of Mexico began in the mid to late 1970s, and the journey into deeper waters continued through the 1980s (Pelletier et al., 19%). Geotechnical investigations were targeted at developingdesign information for both fixed platforms and compliant tower foundations. Beginning in the late 1980s, the scene changed from exploring prospects in less than 600m of waterto those in water depths exceeding 850 to 900m. The deepest water depth for a geotechnical investigation to date has been at Shell's "Mensa" prospect (1616m). The foundation scenarios for these deeper waters have changed to subseatemplates and tension leg platforms (TLP). Deepwater geotechnical investigations in the Gulf of Mexico are now beginning to exceed operational limits of existing site investigation systems. The status of the current technology, and the direction the industry has taken to develop systems and tools to meet the deepwater challenges, are described in subsequent sections of this paper. Evolution of the Deepwater Geotechnical Investigation Practice Geological and geotechnical investigations performed to date in the deepwater Gulf of Mexico have identified an overall very complex environment. The complexity is primarily the result of the upward movement of salt diapirs which have produced extensive zones of steep slopes, faults, fluid expulsion areas, rocky seafloor, eroded seafloor, chemosynthetic communities and other features which make development of oil and gas production facilities challenging, if not impossible.

ABSTRACT A number of studies have been conducted to provide a data base on a variety of deep water development concepts. The purpose of these studies were to identify those concepts which were technically feasible and to determine their costs and schedules. The results from the studies were adjusted to arrive at complete development costs and to place the contractor's cost estimates on a comparable basis. The base cases were then adjusted to investigate a range of field sizes and corresponding production rates. Economic evaluations have been performed on these concepts to arrive at economic characteristics for a range of oil prices. From the results of these analyses, general conclusions regarding the use of various types of deep water concepts, the minimum economic field size and oil price were drawn. THE DEEP WATER PRODUCTION CHALLENGE Deep water oil field development has presented the offshore oil industry with a challenge to provide technically feasible concepts for production, which must also be economic. Many concepts have been designed and evaluated, each with its own distinct advantages and disadvantages. The optimum concept selection process should include consideration of development cost, operating costs and schedule. Some deep water concepts such as fixed steel platforms offer higher initial capital costs, but lower operating and drilling cost with a long fabrication and drilling schedule. Other concepts such as floating semisubmersible systems offer lower capital costs but higher drilling and operating costs, with a shorter fabrication and drilling schedule. Because of the difference in schedule, economic comparison of various deep water concepts is not meaningful without performing a complete economic analysis over the life of the field. The majority of the data base on deep water production systems has recently been focused in the Gulf of Mexico. Because of this the engineering feasibility studies and the economic evaluations in this paper have been conducted for Gulf of Mexico applications. The methodology could be applied worldwide, but the platform designs and economic analyses would have to be modified for the specific operational, environmental and economic conditions. DEEP WATER CONCEPTS DESIGNED AND THEIR ECONOMICS EVALUATED A number of studies were conducted to provide a data base on a variety of deep water development concepts. The purpose of these studies was to identify those concepts which were technically feasible and to determine their costs and schedules. The more technically promising concepts were identified and investigated. These projects resulted in feasibility studies which demonstrated each concept's technical capability to operate safely and supplied a first iteration design and cost estimate for specific environmental and operating conditions. The concepts which were selected for detailed study were: Conventional fixed steel jackets Guyed tower platforms Roseau tower platforms Semisubmersible floating production facilities Tension leg platforms Tanker based production and storage units Water depths for these concepts ranged from 935 to 3,000 ft. Based on the six deep water development concepts identified, the following engineering feasibility studies were performed for the specific cases identified in Table 1. These studies were conducted as Joint Industry Projects or actual deep water platform designs were used where possible.

ABSTRACT The Gulf Deepwater Fixed Platform Joint Industry Project design concept for severe environmental conditions is presented after five years of research. The participants include: Britoil, Norske Shell, Statoil and the project managers, Gulf Oil. The base case Deepwater Fixed Platform (DWFP) shown on Figure 1, is a four legged, self-floating steel tower in a water death of 365m, with a deck load of 22,700 tonnes. Two alternative deck load and water depth variations investigated are: a light deck load of 12,500 tonnes in 457m, and a heavy deck load of 60,000 tonnes in 365m. The investigations produced feasible structures and confirmed simplified design methods. The structure weights determined in the project agreed with projections based on existing structures in severe environments. INTRODUCTION The four-legged advanced self-floating steel tower for deepwater and harsh environmental conditions uses temporary auxiliary flotation for floatout and sea transportation. The structure is upended by controlled flooding of legs and flotation tanks. The temporary flotation raft is removed with the tower in the vertical orientation prior to docking with a subsea template and/or setting on bottom. After ballasting the structure, one piece pile installation begins using a semi submersible crane vessel (SSCV) equipped with underwater hammers. The exterior piles of the group at each leg are stabbed into guide cones atop the pile sleeves, laid back into an open guide, and lowered to the seabed. The underwater hammer is stabbed into the pile, laid back and lowered to rest on an internal driving shoe. The interior piles of the group are installed using a lengthened hammer and a pair of fixed guides located outboard of the structure. Although many engineering aspects of the self-floating deepwater steel structure were investigated in the Joint Industry Project, this paper will focus on the in-place storm and fatigue conditions; and the comparison of member strength using API RP 2A and the Norwegian Petroleum Directorate Rules Proposal for steel member design, foundation configuration and construction methods. Results in terms of structural steel weight requirements are contained in the CONCLUSION. DEVELOPMENT OF CONFIGURATION The underlying principle behind the configuration of the DWFP is that of wave transparency. In order to achieve a feasible structure the storm wave load on the tower must be substantially reduced compared with a traditional North Sea design extended to deep water. Concurrently, the structure configuration required o achieve this fundamental aim must be capable of performing other operational requirements adequately. The use of the advanced self-floater concept eliminates the need for large diameter flotation legs penetrating the waterline. Adequate structure buoyancy for floatout from the graving dock and transportation to the field is provided at the top of the structure by a removable temporary auxiliary flotation tank or raft. Without the large flotation legs, wave loads under storm and fatigue conditions are significantly reduced. The use of large plan bay spacings reduces the number of members. As a result, the number of nodes in the tower is reduced, further reducing the inspection and maintenance costs of the structure during operation.