bluuebunny/crossref_metadata_2025_split huggingface dataset:
Start-up of a Giant
Authors: Constant Arnaud , Ramat Lionel 
Published: April 2012

Abstract
The start-up of the Pazflor field required a response to three simultaneouschallenges:Start-up of a large complex facility, which involved the use of innovative 3Dvirtual reality training tools used to increase operator confidence and theavailability of Total Group previous experience.Flow assurance for two different reservoirs and oil qualities. First, theOligocene Field had light oil with high temperature, wax/corrosion issues, verylong subsea production loops. Second, the Miocene Fields had unconsolidatedsand, heavy viscous oil, emulsion and gas carry-over and Subsea SeparationUnits.Operating innovative Miocene subsea facilities, with gas/liquid separation onthe sea bed.

Introduction
The Pazflor development includes four reservoirs in Block 17 deep offshoreAngola, which produce to a Floating Production Storage Offloading unit throughone Oligocene subsea loop and three Miocene lines connected to subseaseparation units (SSU) and subsea pumps, with associated gas and waterinjection facilities (Fig. 1).
Classical challenges were faced by Field Operations teams for this type ofproject: performing various engineering studies and delivering spare parts, training production and maintenance personnel, and taking over an installationin safe condition with an adequate operational organization integrated into thepermanent organization.
Particular flow assurance challenges regarding high viscosity and " heavy" fluidissues together with unconsolidated reservoir formation had to be addressed, such as foaming, emulsion, deposit and sand management.
Finally, one of the major stakes was to be ready to face the new technicalchallenge of the Subsea Separation Unit, with a completely new operatingstrategy.
This paper reviews these various challenges, presenting Field Operationspreparation and organization used to meet them. It details main flow assuranceconcerns and innovative subsea facilities operations, and presents the mainachievements of the Pazflor field start-up.
Qualification of Composite Armor Materials for Unbonded Flexible Pipe
Authors: Kalman Mark Douglas , Yu Liang , Seymour Mike , Erni Juan 
Published: April 2012

Abstract
This paper presents the plan and execution of a comprehensive test program toqualify composite tensile and pressure armor materials for application inunbonded flexible pipe for deep and ultradeep water, high temperature andpressure production and high pressure injection service. Due to lighter weightand resistance to corrosion and fatigue, composite materials are beingimplemented for the pressure and tensile armor in unbonded flexible pipe. Amaterial qualification program is necessary to define material properties thatare used in design and to assure that the materials will meet performancerequirements over the service life. The material qualification testing programpresented in this paper can also be used as a model for other compositematerial qualification programs for offshore applications.
The qualification test program was developed based on the design of thepressure and tensile armor layers, and a comprehensive evaluation of thepotential failure modes and associated failure mechanisms associated with theapplication of composite armor materials for the layers. The materialqualification program was developed based on the guidelines presented inDNV-OS-C501 Offshore Standard for Composite Components. Since compositematerials are anisotropic, material properties in the principal directionsneeded for analysis, and how these properties vary with time as a result of theloads and environments experienced over the service life are evaluated. Thematerial qualification requirements have been agreed by members of the flexiblepipe technical community and are being published in Draft InternationalStandard API 17J/ISO 13628-11 as Annex H. This paper summarizes therequirements and presents one manufacturer's initial work to qualify bothfiberglass and carbon fiber based composite armor materials for the pressureand tensile armor layers in unbonded flexible pipe.

Introduction
The advantages of replacing the metallic pressure and tensile armor of unbondedflexible pipe, with fiber reinforced polymer (FRP) materials, or compositearmor, have been known for many years. References [1], [2], [3] and [4]summarize efforts over more than 20 years to use FRP materials for tensilearmor in unbonded flexible pipe. In summary, with proper material selection, design and manufacture, the advantages of composite armor include:Higher strength to weight ratio, resulting in a lighter weight pipestructure for equivalent structural capacityImproved fatigue resistanceResistance to corrosion and degradation by most oilfield chemicals andseawater
In particular, the higher strength to weight ratio enables lower top tensionriser configurations without adding substantial buoyancy, enabling installationand operation from smaller vessels, resulting in lower installed cost risersystems. The advantages increase substantially for ultradeep water risersystems [5].
Field Implementation of New Electrostatic Treating Technology
Authors: Walsh John Michael , Sams Gary Wayne , Lee Joseph M. 
Published: April 2012

Abstract
Mars is an offshore drilling and production platform operating in the deepwaterregion of the Mississippi Canyon area in the Gulf of Mexico. It startedproduction in 1996 with a design basis of 140,000 BOPD. In 2003 at the start ofthe work reported here, Mars was producing an average of 200,000 barrels of oilper day. While the platform had undergone a number of expansions, many processunits, including the Bulk Oil Treater were operating above the design capacity. Due to the high throughput and therefore short residence times, the platformwas experiencing oil dehydration problems, and a high rate of demulsifier wasrequired to meet the oil discharge dehydration target of 1.0 % BS&W.
The original Mars electrostatic treater was a conventional design involving aserpentine perforated pipe distributor, steel electrostatic rods, conventionalAC electrostatic treating technology and a perforated pipe collection header. During the hurricane Katrina shutdown (late 2005/early 2006), the Mars Bulk OilTreater was upgraded to composite grids, Dual Frequency® AC/DC electrostatictreating technology and a Hi-FloTM pipe / deflector spreader. After theupgrade, a significant savings in demulsifier cost was realized. This paperdiscusses how the new electrostatic treating technology was used to reducetreating chemical cost and improve throughput. Additionally, comparison ofdifferent crude dehydration technologies is discussed.

Introduction
When a field reaches its maximum production rates, mechanical separationcapacity is often exceeded. For deepwater platforms, separation residence timeis typically short due to the high cost of space and weight. Topsidesseparation problems can be costly, particularly when production must bedeferred to meet oil or water quality specifications (BS&W and oil in waterconcentration).
The work reported here was carried out in 2003 through early 2006. It wascarried out in two phases. In 2003 and early 2004, the platform was operatingat historically high production rates. Oil production averaged 200,000 BPD. Dehydration problems were addressed by adding more heat, improving the chemicalapplication, and improving the operating procedures. In addition, the option toupgrade the Bulk Oil Treater vessel internals was evaluated during this timeperiod. This was the first phase of the work during which the platform wasoperating at high production rates.
High-Pressure/High-Temperature Sensor Development and Qualification
Authors: Hall James E. 
Published: April 2012

Abstract
This paper describes work required to achieve the goal of identifying anddeveloping the sensors that will be required for accurate flow measurement forextreme (high-pressure, high temperature, or HP/HT) subsea productionapplications. Ideally, these sensors should be available for use by metermanufacturers from normal commercial channels. However, due to small numbers ofthese specialized sensors required for the offshore subsea market, the neededtechnology has not been pursued for development through commercial-onlychannels.
The key element needed is a combination pressure-differential pressure (P-DP)sensor that can be used at pressures and temperatures that are far higher thanmost standard conditions. The primary benefit from this work is the ability toreliably measure flow in these crucially important HP/HT fields, thuspermitting accurate accounting of revenue streams from production and royaltyallocation, improved recovery resulting from more accurate reservoir modeling, and (in the future) better measurement during drilling as well as productionoperations.
Since an HP/HT P-DP subsea sensor was not available at the start of theproject, the team, with the support of and guidance from several majoroperators, concentrated on overcoming numerous technical challenges encounteredin the development of this unique sensor. How these challenges were resolvedwill be discussed, and the performance data for the resulting device, will bepresented.

Introduction
Subsea multiphase flowmeters are increasingly being used as production hasincreased in the Gulf of Mexico as well as other locations around the world. Most of the currently installed subsea multiphase and wet-gas flow meters arelimited to measurement of production fluids at a maximum temperature of 125°Cand operating pressures of 10,000 psig. Improvements are required in the designof the mechanical components of the meters to allow qualification foroperational pressures up to 15,000 psig. For operation at that pressure, theflow meter must be tested at 22,500 psig. The temperature limitation is relatedto the sensors that measure the produced fluids.
Ultra deep and long tie-back systems may require subsea HP/HT multiphasemetering system for well test and allocation measurement instead of using atest flow line. Three types of measurement are needed in this environment:temperature, pressure, and differential pressure. These HPHT sensors, alongwith accurate flow measurement, could provide the basis for accurate revenueand royal allocation, as well as improved reservoir management.
This project was launched as part of the RPSEA Project 07121-1301: Improvementsto Deepwater Subsea Measurement with the realization that this sensor market issmall and the needed HP/HT sensors might not be developed through acommercial-only approach. Thus, this project focused on qualifying and/ordeveloping sensors for the HP/HT environment:Temperature (production fluids) = 250°CPressure (production fluids) &gt; 15K psigWater depth &gt;3K meters (4.3K psig)
SME Special Session: Subsea Slurry Lift Pump Technology - SMS Development
Authors: Leach Stuart , Smith Glen , Berndt Roland 
Published: April 2012

Abstract
Nautilus Minerals', the world's leader in exploration and development of deepocean seafloor resources, has located a number of Seafloor Massive Sulphide(SMS) deposits in the Bismarck Sea, within the Territorial Waters of Papua NewGuinea. Nautilus' business model is based on the notion of ongoing resourceaccumulation and aggregating numerous high grade SMS systems and tosequentially develop them using a floating production system.
Nautilus' project development plans are based on utilizing and / or adaptingexisting technologies from a number of different industries. The offshore oiland gas industry in particular has been a primary source of equipment andtechnology and it is from this industry that Nautilus is procuring a SubseaSlurry Lift Pump (SSLP) to pump slurry from the seafloor to its surfaceproduction vessel.
The SSLP under procurement is a 10 chamber positive displacement lift pump. Thepump technology was originally developed to pump drill fluids and cuttings indual gradient drilling of deepwater offshore oil and gas reservoirs. Byallowing the pump's discharge pressure to adjust to changes in the slurry(Viscosity, Density & Solids Concentration), the positive displacement pumpaccommodates variations in flow conditions to remain within its operatingenvelope. The SSLP has a number of direct technical and operational synergiesthat make it ideally suited for application in the SMS productionindustry.
This paper provides an overview of the SSLP design and its suitability for theseafloor mineral production industry and also explores alternate slurry pump orlift technologies suited to this new and developing industry.
Feasibility of TLP with Tender Assisted Drilling for Northwest Australian Waters - A Case Study
Authors: Xia Jinzhu , Taghipour Reza 
Published: April 2012

Abstract
The objective of the work is to assess the feasibility of a tension legplatform (TLP) dry tree unit (DTU) with tender-assisted drilling (TAD) for theharsh metocean conditions offshore North West Australia, characterized by theoccurrence of tropical cyclones and persistent swells. Making use of thedrilling tender vessel's accommodation, power generation, mud pumping, cleaningand storage facilities etc. can reduce the production platform topsides weightby up to 3,000 tonnes. Such weight and associated cost savings could becomeenablers for some of the deepwater gas field developments offshore WesternAustralia.
A TLP configuration is evaluated as the DTU in a water depth of 500 m. The TLPis sized for a specific payload for gas production. A typical 6-columnsemisubmersible is configured as the drilling tender vessel (DTV), for which apreliminary TAD mooring system is defined. Hydrodynamic models for the combinedDTU/DTV systems are developed and used to perform extreme response andoperability analyses.
The coupled TLP/DTV TAD system is analyzed in 1, 10 and 100-year return periodenvironments. It is shown that the DTU and DTV vessel can be safely mooredtogether by hawsers without collision in up to 10-year return cyclonic stormevents. This means that the mooring system operability of up to 99.97% isachievable.
In environmental conditions harsher than 10-year return cyclonic storms, theDTV will be disconnected from the DTU and a full 8-point mooring pattern willbe required to moor the DTV to survive up to 100-year return periodcyclones.

Introduction
For deepwater gas field development offshore Western Australia, dry treefloating production combined with land-based liquefaction will be one of theviable field development solutions. Subject to reservoir geometry, dry treecompletion offers several advantages comparing to a wet tree solutionincluding:–Reduced drilling cost relative to a MODU,–Easy and economical well intervention,–Increased recoverable reserves,–Simple flow assurance, and–Simple well control systems.
One of the significant challenges for this field development concept is theincreased payload and functional requirements for facilitating drilling on theproduction platform. For deep water development this challenge is even morepronounced since the increased topside capacity will significantly increaseplatform capital cost. Therefore, many of today's deep water hydrocarbonreservoirs have been developed with subsea solutions. A solution to thechallenge is tender assisted drilling, which reduces the payload and functionalrequirements on the production platform and therefore makes the dry completionmore competitive (Botker et al, 2001).
Flow Assurance for Deep Ocean Mining: Large-Scale Experiment for Flow Correlation Validation and Abrasion Testing
Authors: Parenteau Thomas 
Published: April 2012

Abstract
The flow assurance aspects of all subsea projects have a major contribution tothe pipe design, field layout, choice of lifting equipment (subsea-pump or airlift), power requirement and system operability. The context of deepwatermining pushes the design theories beyond the existing application cases due tothe significantly larger particle size combined with small diameter riser andjumper including wave shape to accommodate vessel motions and excursionrequirements. In order to correctly assess pressure drop and erosion rate closeto real flow conditions, TECHNIP and GIW have built a large scale experimentalbench operated at the same flow condition as forecasted for the deepseaproject. This large scale test is using an innovative method to allow thereproduction of realistic erosion rate in the pipe by preventing the solidparticle to be eroded when looping through the pump.
The current paper summarizes the findings and results from this large scaleexperimental set-up, testing concentration from 10% to 45%, velocities from2.5m/s to 5.5m/s in an 8" flexible pipe with equivalent rocks particles.

INTRODUCTION
As described in (Espinasse, 2010), Technip is supporting an internal R&Dprogram that should allow the understanding of critical parameters essential tothe design and operability of a subsea mining system. Within this R&Dprogram, an extensive study of the abrasion and erosion mechanism inside theflowline is needed to:Understand the inner pipe wear mechanism function of flow conditionsDefine the proper flowline pipe material providing the best compromisebetween wear resistance and pipe cost.Define a procedure to evaluate the lifetime duration of the flowline pipeduring operations to schedule inspection and maintenance.
To capture and understand the abrasion during subsea mining operations, Techniphas setted-up a full scale test with the help of GIW. In addition of tacklingflowline wear issues, this test is used to validate at large scale thehydraulic modeling exposed in (Parenteau, 2010) and (Parenteau, 2011).

STATE OF THE ART
The particularity of subsea mining is to transport large and dense particle inrather small diameter pipe compared to what the industry of slurry transport isused to. Subsea Mining Partcicle size disctribution can range from 1 mm to60mm. Crushing experience conducted in (B. Waquet, 2011) indicated that atleast 50% will exceed 25mm and more than 25% of the solid will exceed 50mm[Figure 1]. The particle densities range from 2500 kg/m3 up to 4000 kg/m3. Pipediameter will range between 8" to 10", and evolving into wavy shapes.
Design Issues and Trends for the New Generation of Offshore Support Vessels
Authors: Sano Mike , Huang Wei , Penfold Mark , Ozaki Yoshi , He Charles , Leszczynski Mariusz 
Published: April 2012

Abstract
The new generation of offshore support vessels (OSVs) has become increasinglysophisticated and technically advanced in response to demands from deepwaterdrilling and production operations. This paper reviews design issues and trendsfor the development of the next generation of OSVs, highlighting recentlyenhanced classification technical requirements. The new requirements addresssafety criteria and environmental protection for the design, construction andoperation of OSVs.
The paper also includes applicable criteria and new notations for eachspecialized service of the OSV including transportation of supplies andequipment, towing and anchoring of offshore structures, well stimulation andtesting, fire fighting, heavy lift, oil spill containment, pipelineinstallation, diving activities and safety stand-by as well as provisions forthe integration of multifunctional services.
Additionally, the paper addresses the use of LNG as a fuel for propulsionprimarily to reduce emissions.

Introduction
Over the years, Offshore Support Vessels (OSVs) have evolved dramatically asshown in Table 1 in terms of diversification, worldwide operation and waterdepth capabilities. This evolution of technology advancement has been driven bythe need to meet the ever-increasing support demands of deepwater drilling, production and subsea operations.
Long-Term Applications In the New ISO for the Site-Specific Assessment of Mobile Jack-Up Units and the Use of Skirted Spudcans
Authors: Kudsk Gregers , Stadsgaard Henrik 
Published: April 2012

Abstract
The requirements for the use of jack-up units in long term operations have beenincluded in the ISO 19905-1 International Standard for the Site SpecificAssessment of Mobile Jack-Up Units.
The paper will provide an overview of the verification, fatigue evaluation andthe definition of the inspection programs associated with long-term operationsof jack-ups as combined drilling and production units.
The paper will also address the interaction between the various stakeholdersinvolved in defining conditions for acceptance of such operations in additionto the site specific assessment.
Two actual cases will be used to illustrate the level of analysis applied andwhat it took to obtain the necessary approvals. The cases are both pre-date theISO but contain most of the same requirements in their assessment.
The cases will also provide details of the structural modifications and otheroperational requirements including underwater inspections that were deemednecessary to be able to operate the jack-ups for a period exceeding the fiveyear Class inspection requirement.
The paper will further address the use of skirted spudcans on harsh environmentjack-ups to enhance their operational capability and to permit operations withincreased deck loads thereby facilitating the installation of the productionmodules on the jack-up.
The use of jack-ups in combined drilling and production mode is gainingincreased interest in the offshore industry. In particular as they offer costbenefits solutions for development of marginal fields or second phase enhancedrecovery.Agenda• Long-term use of jack-ups: Background and key issuesLong-term operational casesSkirted Spudcans: Justification, design and operational considerations

Long-term use of jack-ups:

Background
The OTC jack-up session 2012 is intended to provide an overview of the aims andresults of the efforts to develop a comprehensive ISO standard for jack-upassessment.
Long before the decision to create an ISO standard the major stakeholders inthe jack-up industry had moved to create a joint industry effort with thepurpose of creating a uniformly accepted basis for jack-up assessment. Theearly phase of the work started in 1989 with a joint industry project thateventually developed into the recommended Practice of Jack-Up Assessment laterto be known as the SNAME 5-5A document.
When it was decided to move into establishing a workgroup on jack-up assessmentunder the ISO TC67/SC7 Committee the group of participants were to a greatextent formed with people from the SNAME 5-5A work group and the starting pointfor the ISO standard was chosen to be with the SNAME 5-5A as the technologicalreference document.