Subsea

Theoretical and experimental research on the ultimate strength of rigid pipelines for deepwater applications conducted at the Laboratory for Submarine Technology-COPPE has been reviewed. Small scale laboratory tests included intact pipes under external pressure combined with longitudinal bending as well as damaged pipes under external pressure. Results obtained from specialist computer programmes and analytical formulations have been correlated with experimental results in order to propose ultimate strength equations to be used in the design procedures. Aspects related to the pipeline installation by reeling method are considered.

Norway's subsea history is a tale of pioneering spirit and drive, innovation and boldness, and world class technology solutions and engineering skills. It's about staking out an unexplored route, and about the way Norway - despite harsh weather conditions, deep waters and strict government regulations - has moved from importing subsea equipment for its Ekofisk field in 1971 to become a leading exporter of underwater technology worldwide in 2019.
Subsea wells currently account for about half of Norway's offshore oil and gas production. But Norwegian offshore technology also has a substantial transfer value to related activities such as offshore wind power, aquaculture and seabed mining. The sector provides the basic for new industrial development.  Knowing were it has come from will be valuable for understanding ts present position - and where it is heading.

ABSTRACT The computational problems existing today in naval, offshore and subsea industry presents a complexity degree which centralized sequential solutions can not solve, once it is demanded a high level of storage and processing. This paper presents a study about multiagent systems insertion in this domain, where the goal is to map the state of the art about these applications and to explore new contexts where resources distribution, logical or geographical, are not a problem, but it can be seen as part of the solution.

Modern terrestrial planet formation models are highly successful at consistently generating planets with masses and orbits analogous to those of Earth and Venus. In stark contrast to classic theoretical predictions and inferred demographics of multi-planet systems of rocky exoplanets, the mass (10) and orbital period (2) ratios between Venus and Earth and the neighboring Mercury and Mars are not common outcomes in numerically generated systems. While viable solutions to the small-Mars problem are abundant in the literature, Mercury's peculiar origin remains rather mysterious. In this paper, we investigate the possibility that Mercury formed in a mass-depleted, inner region of the terrestrial disk (a < 0.5 au). This regime is often neglected in terrestrial planet formation models because of the high computational cost of resolving hundreds of short-period objects over ∼100 Myr timescales. By testing multiple disk profiles and mass distributions, we identify several promising sets of initial conditions that lead to remarkably successful analog systems. In particular, our most successful simulations consider moderate total masses of Mercury-forming material (0.1-0.25 Earth masses). While larger initial masses tend to yield disproportionate Mercury analogs, smaller values often inhibit the planets' formation as the entire region of material is easily accreted by Venus. Additionally, we find that shallow surface density profiles and larger inventories of small planetesimals moderately improve the likelihood of adequately reproducing Mercury.

The key issue to develop the Roncador field, located in ultra deep water offshore Campos Basin, in Brazil, is the maximization of production rate keeping the completion reliability, avoiding premature high workover costs involved in that scenario. Roncador reservoir has a succession of thick turbidite sandstones containing 31° API oil, requiring sand control and water injection to maintain reservoir pressures above saturation&amp;amp;amp;amp;amp;amp;amp;amp;amp;#39;s. The distance between the pay zones are as short as 12 meters, becoming the first problem to fit the gravel assembly in such a short space. Flexibility in the completion is provided by an internal string with sliding sleeves. When water coning occurs in any zone, the sleeves shall be closed using slick line in a light workover. The paper will describe the main challenges to carry out three stacked frac-packs in a subsea well drilled in water depths above 1800 m, considering the experience acquired from the first three deviated subsea wells, working in dynamic positioned rigs. Special procedures were adopted to prevent failures during the completion, such as: rigid control of fluid cleanness and gel properties, selection and operation of service tools suitable to that environment (heaving, risk of rig drive-off) and careful design for frac-pack based on minifrac data. The drives for equipment selection will be reviewed, including the choice of perforation charges, gravel equipment and sliding sleeves. The good results obtained in those frac-packs, using the Tip Screen Out technique, reducing the skin effect compared to conventional gravel pack, will be presented too. Introduction Roncador field was discovered in October 1996 by the wildcat RJS-436. The 132 square kilometers field lies 125 kilometers off the coast of Rio de Janeiro, at water depths ranging from 1,500 to 2,000 meters (Fig. 1). The field size, the good quality of crude and the concurrent benefits for the downstream, allied to economic results of the project, led the Company to adopt a fast track development plan. In January 1998 another wildcat, RJS-513, confirmed the extension of the reservoir and the existence of oil in the southwestern portion of the reservoir. Immediately afterwards, Petrobras began the appraisal of the reservoir, drilling four other wells. In this same year the Early Production System (EPS) was designed to allow a long duration test in the wildcat RJS-436. Three major developments made this EPS viable: the Drill Pipe Riser2, the Guidelineless Christmas Tree with vertical production2 and the upgrade in FPSO Seillean3 to 2000 m water depth. The stacked frac-pack was deemed the solution required to obtain the desired flow rate in this vertical well, allowing long term appraisal with good economical results. In January 1999 the first oil came on stream in Roncador, when the Early Production System began producing through RJS-436 at a rate of 20,000 barrels of a light oil per day. This System is installed at 1,853 meters of water depth, being the current world record for a subsea completion. Background The wildcat well (RJS-436) was tested, indicating that sand control would be required. to develop the field. The sand control method planed was the frac-pack, defined here as the combination of fracturing the formation followed by an annulus packing. This choice was based upon two mean reasons:the excellent background of this method in Campos Basin andthe excellent results obtained in wildcat well by using frac-pack system. (i) Generally, Campos Basin sandstones are highly unconsolidated and have permeabilities ranging from medium to ultra-high values. In high permeabilities, damaging the well by sand controlling, no matter the method, is very common.