bluuebunny/crossref_metadata_2025_split huggingface dataset:
Soft Rope Traction Winch (SRTW)
Authors: Schols Martijn , Carey Dean , De Jager Martijn , Mahar John 
Published: June 2014

Abstract
This paper presents an overview of the benefits of the use of synthetic rope winches as a direct replacement to wire-rope winches in ultra-deepwater applications. The Perdido was the first SPAR to use Direct Vertical Access (DVA) to access 22 planned well slots. The planning process invoked many new ideas on technologies required to operate in this ultra-deepwater environment. One of the many innovations that came out of this development was the need to develop a winch that could set Tubing Hangers and X-trees from the actual structure. Prior to the development of the Soft Rope Traction Winch, a wire rope winch was used to perform these tasks. Because of the weight of the wire rope in deeper applications, the actual winch pulling capacity was significantly reduced. The only other method available required utilizing a Multi-Service Vessel (MSV) that could accommodate the size of the winch to perform this two-step process. This approach was expensive and relied on Mother Nature's cooperation which was unpredictable at best. The development of the SRTW provided a viable option to using a MSV. By replacing wire-rope with synthetic rope the winch weight and size would be significantly reduced. The SRTW's small footprint and weight allowed it to be positioned on a cantilevered platform that did not use any of the deck space which is typically at a premium on these structures. The challenge was how to spool soft rope at these depths and not have the weight of the payload work its way between the spooled layers of rope when in tension. Additionally, the characteristic of synthetic rope when placed in various tensions causes deformation and stretching resulting in slippage of the rope during spooling operations. This slippage results in heat being generated due to friction which will ultimately damage the rope. All these challenges were over-come and the winch has proven to be a safe, reliable and economic substitute for wire-rope winches.

Introduction
This paper presents an overview of the benefits that can be achieved by replacing wire-rope winches for synthetic rope winches in deep and ultra-deepwater applications.
As demand for energy continues to increase, the search for vital energy resources is expanding further offshore into harsher and deeper waters. Globally, there are more than 150 major deep and ultra-deep water developments that have the potential to come on-stream over the next 5 to 10 years (figure 1). This growth is centering upon the ‘Deepwater Triangle’ of Brazil, West Africa and the North American Gulf of Mexico.
Dry Tree Solutions for Ultra-Deepwater in Offshore Brazil
Authors: Yan Lu Jenny , Davis Heather , Raposo Celso , Hansen Vigleik L 
Published: June 2014

Abstract
With Pre-salt area being a massive new offshore oil frontier, there is a high demand for deepwater floaters for both drilling and production. There are some unique challenges related to the ultra-deepwater (water depth beyond 1500m) and the Brazilian environment for the pre-salt area. Various floater concepts have been evaluated with specific focus for Offshore Brazil applications.
This paper provides an overview of the current technology related to dry tree solutions as well as discussion of the pros and cons of various concepts. The paper also discusses some new concepts emerging in the industry attractive for Offshore Brazil.
A dry tree solution has the advantage of direct access into reservoirs from the floaters. This allows the operators to drill, complete and workover the well directly from the same hosting unit. The result could be increased reserves and productions in Offshore Brazil as well as significant cost reduction. Proper validation of the concepts and technology qualification of all the systems/components associated with novel technology, establish the basis for a safe and successful project implementation while reducing potential risk to personnel, environment and property.
DNV has established processes to systematically evaluate new concepts and new technologies, e.g. Approval in Principle (AiP) and Technology Qualification (TQ). A brief introduction to these processes is included in the paper and how they support the development of these new concepts.
Regulatory Challenges of Local Content Rules in Brazil
Authors: Mirilli Miguel Oliveira 
Published: June 2014

Abstract
This paper addresses some issues that E&P companies in Brazil have been struggling in relation to Local Content Rules, whether to understand the regulation enforced by clause twenty of the concession agreement and regulatory provisions or to meet the targets set in the tenders' bids. Several public data was gathered to support a better analysis of some regulatory challenges of Local Content Rules.

Introduction to Local Content in Brazil
The oil companies interested in E&P activities in Brazil must previously win a bidding round for the chosen block, which activities will be regulated by a concession agreement and several regulatory provisions issued by the federal agency responsible to the industry, ANP, which name stands for Agency of National Petroleum, Natural Gas and Biofuels. Another possibility is entering into a farm-in agreement with an oil company that already has a concession agreement.
In this context, Local Content presents a twofold nature:Local Content target weighting 20% in the tender bids;a contractual obligation based on the tender bids, once the oil company wins the block bidding.
Nowadays, the legal provision of Local Content is Law #9478/97 article 2, item X, included by Law#12351 issued on 2010. The sole logical deduction arising from the aforementioned rule is that Local Content can be used as a national policy instrument, although there is no definition of how it should be calculated and what it is the exactly definition thereof.
Even prior to 2010, Local Content was enforced by regulatory provisions issued by ANP and the clause twenty of the concession agreement.
Several authors from many countries defines Local Content as a political orientation designed to improve the participation of local/domestic companies in providing services and goods for a specific economic sector, generating revenue, jobs and technological development. A secondary goal of Local/Domestic Content policies is to increase the likelihood of local companies to export to other countries, as it will be increased in scale production and technological competitiveness along the years of this policy protection.
Accordingly, Local Content can be defined in its political aspect as a policy to enhance local goods and services industry capacities, helping forward the country's development and increasing employment offers.
In light of this, Local Content aims to increase the participation of local inputs in the product's added value either by employing goods manufactured locally or services provided by local workforce.
Movable Chain Jacks and Winches, Case Study of Petrobras' P58/P62 and Eni's Goliat FPSOs
Authors: Grindheim Reidar 
Published: June 2014

Abstract
Recently, Aker Solutions delivered a movable chain jack system to Petrobras's P58/P62 FPSOs and a movable windlass system to ENI's Goliat FPSO. This paper highlights the main differences between the two systems and when it is beneficial to employ movable systems. There are many parameters to consider in determining which system to use - also a traditional system involving a single winch or chain jack per mooring line may in many cases be preferred. The movable chain jack concept is designed to operate multiple mooring lines within the same cluster. A single chain jack is lifted by a skidding gantry and moved to the next mooring line and so forth. Installation and messenger chains are moved using a large sliding chain locker allowing for later offloading of the surplus chain. The movable windlass system is also designed to operate multiple mooring lines within the same cluster. However, in this case the winch is rotary and can operate via electric or hydraulic power. One of the main considerations is to move the windlass and keep the mooring lines intact without cutting them.

Introduction
The primary purpose of an offshore mooring system is to maintain a floating unit on station within specified tolerances. These tolerances are often based on offset limits determined from the configuration of the riser system. The mooring system provides restoring forces that act against environmental forces (wind, waves and currents) that are trying to move the unit off station. Most mooring systems for offshore application are spread moored or single point moored (including turret systems). Spread mooring is the conventional mooring approach and is widely used for both drilling and production units. Spread mooring keeps the unit in position at an optimal heading but does not allow weathervaning. Single point mooring (internal/external turrets) is used primarily for ship-shaped vessels allowing the vessel to weathervane. However, a spread moored system can also be applied to ship-shaped vessels and we see many of this type off the coast of West Africa and Brazil.
Traditionally, on-vessel mooring equipment has consisted of individual winches, fairleads and chain stoppers located at each mooring line. The mooring lines can be chain, wire rope, fiber rope or a combination. This paper discusses movable chain jacks and winches recently supplied for spread mooring systems on both ship-shaped and cylindrical- shaped FPSOs.

1. Traditional Spread-Moored Platform Designs
Position moored production and drilling units come in various shapes and sizes. Traditionally, we have seen semisubmersible, spar and ship-shaped units. All these units have applied winch or chain jack systems. Figure 1 shows typical designs that have been in use for several decades.
Analysis of Jump-out of Casing Connectors
Authors: Placido Joao Carlos Ribeiro , Fonseca Carlos Eduardo , Anjos Jorel Lopes Rodrigues dos , Roveri Francisco Edward 
Published: June 2014

Abstract
Failures related to casing connectors jump-out have occurred, causing flat time of deep water drilling rigs, which generates great losses due to very high daily rate of these rigs. The objective of this paper is to show a methodology for performing post analysis of this type of failure. In order to do the analysis, it is mandatory to obtain the mechanical properties and dimensions of the casing connector. It is important to raise the stress-strain curve of samples extracted from the connector. In case of proprietary connectors, the dimensions should be obtained with the manufacturer, once it is necessary detailed dimensions.
Aiming to verify the structural integrity of the casing connector, a proper definition of the load scenario prior to failure must be done. Provided the meteocean condition during the analyzed operation, a dynamic finite element analysis of the whole casing string is performed. The string is treated as beam elements and bending moments and axial stresses are tracked. Varying wave parameters it is possible to define a load envelope. Due to the geometric and material complexity of casing connectors, axisymmetric and 3D finite element models were developed to reproduce the problem domain and load scenarios. Based on an excessive displacement and plasticity criteria, a strength envelope was evaluated. Combining load and strength conditions, it was possible to access some issues that may have caused the connector failure.

Introduction
In deep water drilling operation with floating rigs, while running in offshore surface casing, sometimes jump-out of connectors has been observed. This problem usually causes big losses and, therefore, it is very important to find out the reasons in order to avoid them.

Objective
The main objective of this study is to determine the possible causes of jump-out of casing connectors while running these pipes into a well in offshore floating rigs.

History
Since 2002 Petrobras has been using connectors welded to the surface casing X-56, 20?? × 5/8??, 131.5 ppf. This connector has tension strength approximately 40% lower than the pipe body. The length of the joint is 12m (40ft). The connection makeup is done with ¾ of turn and a key seat must be used to guarantee the connection will be safe.
In August 4th, 2011, it was initiated the operation of running a 20?? surface casing into the well. After 7 (seven) joints have been assembled using an auxiliary table, the casing string was moved to the main table with a trolley (Figure 1). The casing was lifted up to the main table and the trolley stayed below the rotary table functioning as a guide.
A Diagnostic and Prognostic Framework for Integrated Reservoir-Completion Management Using Intelligent Well Data
Authors: da Silva Jr Manoel Feliciano , Radespiel Eduardo dos Santos , Jacinto Carlos Magno Couto 
Published: June 2014

Abstract
Well construction and maintenance represent most of the costs of a deepwater offshore field exploitation. Planning and execution times in this scenario are normally impacted by geological and operational uncertainties leading to deviation on the actual times and consequently costs. Intelligent wells have been used to face the geological uncertainties for heterogeneous reservoirs with multiple pay zones in Brazil's Pre-Salt reservoirs. Robust diagnostic and prognostic of abnormal operational situations have not been addressed completely up to now even with real-time data available from the Intelligent Wells.
The completion design, cost and reliability are the basis for the identification of all sensors needed to provide a rich data set for a fit for purpose application using a system view. Even though these are permanent sensors, the idea is suitable for coiled tubing and e-line operations where additional sensing options are available, but without the capability to capture the dynamic behavior.
Data quality methods as well as integrated modeling simulation are all at a very early stage. This challenge is aggravated by the huge amounts of data coming from an Intelligent Well which is far greater than the data flow that the petroleum industry normally has to deal with. Additionally, the increased complexity of the completion affects the coupled well-reservoir modeling used in today's analysis.
The evaluation of the well equipment degradation is also vital to prevent future complications that will lead to unexpected well shut-ins. Flow control, well integrity, artificial lift, and their related equipment are all targets for tuning the maintenance practices.
In this paper, we propose a framework which includes:real-time data quality control;non-isothermal coupled well-reservoir modeling taking into account completion equipment;appropriate analysis tools.
The aim is to simultaneously optimize well completion operations and maintenance practices. We focus our strategy on: initial well completion design; formation evaluation; stimulation, and equipment reliability, discussing applications that support our proposition.

Introduction
One of the most representative recent oil discoveries worldwide is the Santos Basin Pre-Salt Cluster (Moczydlower et al, 2012), offshore Brazil. Considering the importance of the reserves and intending to accelerate cash flow, Petrobras and its associates decided to fast track its development. Several subsurface uncertainties resulted from this choice which leaded to a mix of classical strategies (information, flexibility and robustness) for the development plan. IW (Intelligent Well), in this context, was identified as an extra flexibility that was worth investing in. Fast response to unexpected events and better production system behavior prediction were the main issues to address.
Regaining Wellbore Access and Enhancing Safety Devices Operation by Removing Obstructions Using E-line Conveyed Technology
Authors: Torres Rafael , Carrillo J.G. Rego , Higa Rogelio M , Martinez Arturo , Huerta Juan Martin , Soto Alan , Ramos Jaime A 
Published: June 2014

Abstract
The Marine regions represent a significant portion of the total oil production in México. Sustaining oil production at current levels is a constant challenge; thus a large local operator is exploring unconventional methods in their quest to optimize rig utilization by implementing novel rigless work-over interventions.
One of the Marine Region most common interventions is production tubing clean-out. The objective of these interventions is the removal of deposits layers, asphaltenes and scale bridges in order to regain access to the producing intervals, and in some cases to eliminate the detrimental effect in production caused by reduced flow in scaled areas. Traditional clean-out methodology includes tubing conveyance, pumping of cleaning fluids and the operation of hydraulic or mechanical downhole tools.
E-line conveyed technology enables rigless clean-outs by mechanical removal of debris from production tubing, safety devices like SSSV and plug seats, saving deferred production and allowing the operator to optimize rig utilization. The cleaning tool run on a well tractor and e-line has proved to be a reliable and effective solution for clean-out applications.
E-line tractor assisted clean-out technology induces zero damage to the produced zone. The ability of removing debris from the wellbore without pumping a single drop of fluid into the well represents a major turnover into traditional workover approach. E-line conveyed clean-out enables operators to perform environmental friendly interventions, with reduced personnel and carbon footprint, enabling logistics optimization.
This paper examines these recent applications of through-tubing e-line conveyed well intervention solutions in Mexico's marine regions and presents the relevant well conditions and criteria used for selection. It provides case histories with operational challenges as well as the results of several successful, rig-less cleaning operations on an important producing wells.

Introduction
A large operator located in the Mexican marine region (Fig. 1), which is located in the the Gulf of Mexico, is responsible for maintaining nearly 75% of the overall oil production of Mexico
One of the major challenges that the marine regions face's is to minimize deferred production, therefore, they are continuously looking for workover alternatives that allows them to keep production at maximum levels.
Most of the wells in the fields of the marine region have carbonate scale building issues due to water production. Scale bridges across the production tubing restrict the access to the producing zones, creates downhole chokes with detrimental effects to production and may obstruct or even prevent correct functioning of subsurfarce safety valves.
Technological Innovations on FPSO P-63 for Operation at Papa Terra Field - Offshore Brazil
Authors: Rocha Anderson Cicero , Araujo Paulo Fonseca , Nicodemos J. Fernando 
Published: June 2014

Abstract
The Papa Terra oil field is operated by Petrobras in partnership with Chevron, located 110 kilometers from the coast in deep water at Campos Basin, offshore Brazil, has an extra heavy oil formation with several challenges for its production development. The purpose of this paper is to present the innovative strategy to exploit the field, as well as the technological innovations on the FPSO (Floating Production Storage and Offloading) P-63, designed and built to process, store and export the extra heavy oil of Papa Terra field. During the lifetime of the field, each new technology applied to the project will be closely monitored by the company in order to provide useful information to be considered when designing the next offshore production units.
The strategy of developing the heavy oil field production in deep waters, using three floating units, such as the TLWP (Tension Leg Wellhead Platform) P-61, in combination with a TAD (Tender Assisted Drilling), along with the innovative technologies onboard the FPSO P-63, can be considered an innovative and very attractive concept in Brazilian oil industry.

INTRODUCTION
The Papa Terra oilfield is located in the South portion of the Campos Basin, 111 Km off Cabo Frio city, in the state of Rio de Janeiro (figure 1). The field was discovered in June 2003 and extends over an area of 183 square kilometers, in water depths varying from 400 to 1,400 meters and is estimated to contain 700 million to a billion barrels of oil equivalent. The total volume of recoverable oil is approximately 400 million barrels.
The presence of extra heavy oil with high viscosity, low gas-oil ratio (GOR) and a large amount of produced water brings extra challenges, demanding a differentiated strategy for the field development.
Examining Progressive Collapse of Framed Structures in Response to Fire and Explosion Consequence Events
Authors: Reed Morgan , Peterson Eric 
Published: June 2014

Abstract
Inherent safety is well accepted in the oil and gas industry, with codes and standards' providing guidance and requirements to ensure its successful adoption. In the last decade, the offshore industry has made major shifts in ensuring the safety of personnel and asset preservation (e.g., platforms). Advances in computational power permit specialized software to evaluate safety concerns. Major safety concerns associated with offshore installations can be examined with particular attention paid to structural integrity, deformation and any impact on personnel safety (evacuation routes, temporary refuge, etc.).
Specialized software tools, Fire and Heat Transfer Simulator (FAHTS) and Ultimate Strength of Framed Offshore Structures (USFOS), enhance the capabilities to evaluate the survivability of offshore drilling structures from fire and explosion loading. When structures are subject to extreme loads due to fire and/or explosion, progressive collapse analyses are frequently used to predict both the resistance of structures subject to accidental loads and the residual strength of damaged structures after such loads. Coupling 3D Computerized Fluid Dynamics (CFD) software packages with those containing Finite Element Analysis (FEA) permits the progressive collapse of offshore platforms to be assessed.
Results presented evaluate structural member deformation and any subsequent collapse in and around Safety Critical Elements (SCEs) such as: escape routes, temporary refuge, and fire water pumps. When evaluating SCEs, particular attention is paid to which structural members collapse and if their failure is acceptable for the overall integrity of the structure to remain intact and specifically any effect upon the SCEs. Structural members supporting critical substructures, vessels, equipment which can lead to escalation need to be protected. Optimization of passive fire protection will be discussed for areas showing gross deformation or failure.
This paper focus is on simulated heat loads from fires and blast loads from explosions. The attendant structural responses are due to thermal radiation fluxes, blast overpressures and the associated applied mechanical loads. Early identification and appropriate mitigation responses to potential fire and blast scenarios that may threaten personnel or the survivability of an offshore installation can lead to additional safety and cost benefits for operators and engineering, procurement and construction companies.