bluuebunny/crossref_metadata_2025_split huggingface dataset:
Adapting the OPTI-EX Topsides to Suit the Who Dat Reservoir
Authors: Tucker Bob , Meyers Patrick , Sakers Michael , Mullett Craig , Krekel Marcus Hendrik , Mahase Deodath 
Published: April 2012

Abstract
The OPTI-EX Floating Production System (FPS) was commissioned on speculation. Its foreseen areas of deployment were the Gulf of Mexico, Brazil or WestAfrica. Before the project was sanctioned, a marketing study was undertaken onpotential prospects to support the formulation of a basis of design (Phase I). The marketing study summarized all known marginal fields and early-developmentfields for which an FPS could be suitable. The study helped to confirmviability of a speculative FPS and helped the design team to focus on the rightsize of production facility.
A production system (Phase II) was designed that was highly modular, whichallowed for a maximum of flexibility in production. The capacity of thetopsides comprised 40 Mbop/d plus 50 MMscf/d. For equipment that was toofield-specific, only space, payload and utilities were provided. The FPS wasbuilt and subsequently laid-up, awaiting a deployment contract.
When the current owner procured the FPS, they completed the facility by addingthe field-specific equipment and modules to it (Phase III). Also, the capacitywas increased to 60 Mbop/d plus 150 MMscf/d. The paper describes how theseupgrades were achieved, where the original design philosophy worked well, andwhere it was deficient.
The paper addresses the possibilities and limitations of generic productionfacilities design, using the " Who Dat" deployment of the OPTI-EX FPS as a casestudy.
Most of the modifications of the facilities in effect, comprised the additionof the field-specific equipment and modules originally anticipated. Only alimited number of existing systems were converted. By adopting a modular designwith sufficient flexibility and capacity, a wide range of field conditions canbe accommodated.
There is an industry tendency to " prototype" a standard facility time and timeagain. In a field development, significant schedule and cost gains can be madeby using an existing FPS, provided its facilities have sufficient capacity /flexibility and the FPS has adequate spare payload, space and utilities.

The Project
The Exmar OPTI-EX™/ LLOG Who Dat project was unique from start to finish. Theunique deep-draft semisubmersible OPTI-EX floating production system (FPS), conceived by Exmar Offshore Company (EOC), was designed and constructed to bere-deployable for use in early production and marginal field developmentopportunities, for medium to large reservoirs, and in waters ranging up to10,000 feet. It was the first independently-owned facility with this capabilityand the first speculative FPS constructed in the industry. One of the mostunique features of the structure was its generic single-level topsides, whichmade it capable of being modularized for customization to be used multipletimes in global fields. Fully outfitted, the OPTI-EX is capable of producing60,000 barrels of oil per day (bop/d) plus 150 million standard cubic feet ofgas per day (MMscf/d).
Pazflor - The Challenges of the Offshore Phase
Authors: Rouyer Sebastien 
Published: April 2012

Abstract

HSE
The Pazflor SURF installation campaigns kicked-off on 05th September 2010 withthe mobilisation of the first construction vessel and ended in September 2011. With over 800 people present offshore at peak of activity and 1.5 millionmanhours upon completion, it has unfolded without any major incident.
During the preparation phase, particular attention was paid to the bridging ofthe HSE management system of the 3 main contractors with the system of Total, and especially the emergency response procedures.
During the execution phase, the project installation team focused on theanticipation of co-activities between construction vessels, other vessels suchas drilling rigs and surface or subsea assets and was successful in eliminatingmost of these situations, or properly preparing the one that couldn't beavoided.

Campaign size and integrated schedule
Pazflor subsea installation campaigns involved the installation of 180 km ofpipelines, 84 km of umbilicals, 17 risers (including 2 IPBs) and 7 dynamicumbilicals as well as over 120 subsea structures totalling about 10,000 tonnes. Over 350 ROV tools and accessories were necessary to perform more than 200subsea tie-ins.
The campaign has involved up to 6 main construction vessels at peak of activity(the complete construction spread reaching nearly 40 vessels and barges)working in conjunction with 3 drilling rigs and seismic acquisitionspreads.
Potential interferences between the construction spread and other vessels wereanticipated using an integrated location-based planning and were all butcompletely avoided in spite of a very intense period of activity in the firstsemester of 2011.

Campaign complexity
Both Pazflor Oligocene and Miocene production systems consist in complexassemblies of components with very different design principles and installationconstraints (flexible risers, rigid lines, flextails, subsea connectors, rigidspools, subsea structures…), which require specific installation means anddictate the installation and test sequence. As a consequence, the plannings ofall the main construction vessels are heavily inter-dependant.
Such interdependence raised the stakes of respecting vessels' respectiveschedules a step higher than is usual in offshore operations. Preparation andprior full scale testing allowed to ensure no unexpected event affected thegood development of the more complex installation phases.
Pazflor: Performing Fabrication and Construction in Angola
Authors: Croguennec Steven 
Published: April 2012

Abstract
Between 2001 and 2008, the production of the Angolan oil industry trebled from700,000 to more than 1.8 million barrels of oil per day. For Angola, it is acrucial challenge to spread the benefits of this windfall throughout theAngolan economy as a whole and to stimulate the creation of value on a localscale. In collaboration with all the contractors, Pazflor encouraged localmanufacture of project facilities and equipment whenever possible. Identifyingthe production capacity available at existing yards, scoping out local skillsand reviewing the workload of local companies were all preliminaries to thecontract awards.
During the Project execution phase, Angolan yards made a significantcontribution to the construction of project equipments. Around 3.8 millionsmanhours, 10% of the overall project workload, were spread over 4 fabricationyards, with a strict respect of HSE project requirements. In line with projectschedule, local companies achieved the fabrication of various equipements:suction piles, FPSO structures, offloading buoy, subsea manifold modules, XTfunctional testing and almost all umbilicals of the project lay-out.
These 3.8 millions manhours performed for Pazflor represent in average around500 persons working on a full time basis during the 3 years of the fabricationphase on the Angolan ground
Pazflor SSPS Project; Testing and Qualification of Novel Technology: A Key to Success
Authors: Eriksen Steinar , McLernon Hildegunn , Mohr Camilla 
Published: April 2012

Abstract
The paper will address the development, qualification, engineering and testingphases for the Total's Pazflor Subsea Separation and Production System (SSPS). Items to be discussed will be qualification challenges associated with thespecific component test, factory acceptance test, extended factory acceptancetest, system integration test, shallow water test and cool down test. Pazfloris the first full-scale green field development with subsea separation andboosting as a prerequisite to producing two different grades of hydrocarbonsfrom four independent reservoirs. Other challenges which are discussed are thedynamic simulation and full-scale function.
Total is the operator of the Pazflor development, located in Block 17 Angola, wich consists of 2 different fields: the Oligocene field has light oil atmedium pressure and medium temperature while the Miocene field has heavy(viscous) oil with low pressure and temperature. One of the challenges for thisdevelopment was to produce common equipment and systems capable of meeting thetechnical requirements for both fields, e.g. hydrate formation challenge vs.high temperatures. For the Miocene field the low reservoir pressure and deepwater in combination with high viscosity and stable emulsion creates the largepressure drop in the flowline and risers which therefore requires boosting ofthe production fluid from start-up of the field.
This paper provides details of the extensive test program required tosuccessfully deliver a major Subsea Separation and Production System. It showsthe systematic and integrated process required from qualifying products atcomponent level to further verification in an overall system testprogram.
New technology such as integrated insulation on pipe termination heads andsubsea separation systems together with a new system philosophy regardinginstallation of equipment and thermal performance has been verified.
A successful offshore installation campaign took place during 2010 and 2011, confirming that potential issues were identified and rectified through the testprogram.
The Pazflor subsea field development consists of two parts; the subseaproduction system (SPS) and the subsea separation system (SSS). The latter isexpected to be applied on several more subsea developments for both brown fieldand green field applications in the future.
This Paper provides details on how these two parts were integrated into onesuccessful overall project with a focused engineering, execution and testprogram.
Applying a Real-Time Engineering Methodology To Drill Ahead of Potential Undesirable Events
Authors: Perez Tellez Carlos , Rodriguez Rosas Reginaldo , Ramirez Ignacio , Bermudez Martinez Rafael Angel , Palavicini Cham Carlos Alberto 
Published: April 2012

Abstract
Current methodologies for drill planning, widely implemented by Oil Companiesto optimize the definition of technical and economic options for the drillingprocess, are based on a scrupulous analysis of the production requirements, thetechnical risks, and the geological uncertainties. Planning and designingdrilling projects begin by considering the problems observed in correlationwells drilled in the same field, in order to obtain a successful mechanicalmodel.
Once the drilling process begins, an evaluation of the continuing operationsallows drilling engineers to control and adjust the differences that may arisebetween the drilling plan and the actual conditions observed while drilling. These identified variations are related to uncertainties in the criticaloperational parameters, such as pore pressure and fracture pressure gradients, salt intrusions, and changes in the planned lithology column, such as, shaledomes, and gas shows. Dealing with these variations is imperative, as they candetermine either the success or the failure of the well.
This Paper proposes a Real-Time Drilling Engineering Methodology that allowsoperations staff to drill ahead in depth and time by anticipating geological, mechanical and operational conditions, thus allowing preemptive actions. ThisMethodology allows forecasting the adequate drilling parameters by visualizingthe current conditions of the well. These include the analysis of theinteraction between the drill string and the fluid with the formation, thenormalization of mud densities in the areas of interest, and the analysis ofgeopressures from logging-while-drilling data. Other parameters that need to beconsidered might include the variation of casing and hydraulics designs, andthe optimization of the well path from Real-Time Trajectory and Log Data.
This Real-Time analysis leads to immediate engineering recommendations that caneliminate and avoid ongoing and potentially undesirable situations whiledrilling, such as stuck pipes, gasifications, and runoffs, thereby allowing apreemptive response to the variations that may occur between the proposeddrilling plan and the actual drilling conditions. By applying this Methodologyin several oilfields in Southern Mexico, an observed 20% increase of thetechnical efficiency of the drilling process has been reported, resulting inover 80% of the wells operating under normal conditions, with a reduction inthe average cost of the well for the operator.
Improvements to Deepwater Subsea Measurements RPSEA Program: Meter Alteration Effects From Fouling and Erosion
Authors: Zanker Klaus , Stobie G. J. 
Published: April 2012

Abstract
Multiphase/wet gas flow meters used in deepwater subsea conditions are known tohave problems with scale from produced water and erosion from sand production. The objective of this RPSEA project is to evaluate the flow meter performancechanges produced by these meter altering mechanisms
Multiphase/wet gas meter elements: Venturi, cone and wedge meters, werephysically tested and subjected to Computational Fluid Dynamics (CFD)simulations.
The erosion testing was done with water-sand and air-sand on one size and onebeta ratio of each meter type. CFD simulations were used to extend the sizerange, the beta range and the fluid densities to cover the multiphase densityrange between air and water.
Erosion results are presented that allows the user to estimate the possibilityor likelihood of wall penetration, the measurement error on a flow meter andthe effect of a flow meter on the erosion of a downstream bend.
The scale deposition testing was done with brine of mostly sodium and calciumon one size and one beta ratio of each meter type. No attempt was made to useeither multiphase flow or realistic subsea conditions.
Scale deposition is a highly complex and variable process that is difficult tomodel. For CFD to be able to estimate meter error it would have to predict thedistribution and thickness of scale in the meter. At present this is beyond thecapability of CFD. However, CFD simulations were run to assess how meters areaffected by scales that are sensitive to fluid scouring, pressure distribution, particle accretion and thermal effects.
These CFD-based methods are sufficiently realistic to provide an insight intothe effects of scale. They are used to compare different meter designs andhence identify design features that may be desirable if scale formation is aconcern.

1. Introduction
This RPSEA 07121–1301 [Ref. 1] project addresses gaps in the deployment and useof multiphase and wet gas meter technology in deepwater production systems. Inparticular the objective of this task is to understand the ways in whichproduction fluids affect subsea meters and thereby affect their meterresponses.
It is known from field operations that meters can become fouled internally bydeposits of scale, or altered by erosion. At present these effects are not wellunderstood and the objective is to estimate their magnitude.
Flow tests and computational fluid dynamic (CFD) analyses have been performedto evaluate the effects of alteration on Venturi, cone and wedge meters, byscale deposition and by sand erosion. The results are interpreted to give aclearer understanding of these meter alternation effects on subsea multi-phasemeter response.
Qualification of a DP-Based FPSO Offloading Vessel
Authors: Diederichsen Kim , Olsen Frode 
Published: April 2012

Abstract
As the oil and gas industry moves into deeper and deeper waters, the need foran efficient system to offload crude oil from FPSOs to tankers is steadilyincreasing. Furthermore, oil transportation and trading has becoming moreinternational, where oil companies tend to seek solutions that allow forconventional oil tankers to offload directly from FPSOs and transport the crudeoil directly to the market.
Traditionally, offloading of crude oil from FPSOs to the tankers is carried outeither in tandem configuration or via a remote Single Point Mooring (SPM) buoysolution. Tandem operations are normally carried out by use of specially builtDynamically Positioned (DP) tankers or with conventional tankers along with theuse of several tugs in order to keep the tanker at a safe distance from theFPSO. The new DP based offloading vessel is designed to dock onto and keep anyof the existing 2000 conventional tankers, from Aframax to VLCC size, safe onposition during the typical 24 hours of offloading operations.
First applications of new innovative technologies are often perceived asinvolving potentially increased risks, with possible significant adverseconsequences and high levels of uncertainties. Hence, the development anddeployment of an innovative technology is often hindered by the view of suchrisks and uncertainties.
This paper is prepared and presented by Remora and it addresses the steps andresults of a 10-year development and qualification process for new DP basedFPSO offloading vessel particularly suited for the new deepwater fields in WestAfrica, Brazil, GOM, etc.
The paper explains the methodology applied for the qualification and describesthe entire qualification process. It outlines the main challenges anduncertainties identified during the process and the mitigations implemented anddescribe the results obtained. As part of the qualification process for the DPbased offloading vessel, extensive Sea Trial's with simulator validations andfollowing real life operations have been executed off of the west coast ofNorway throughout Q1 and Q2 2011.
Improved Pile Driving Predictions in Carbonate Soils and Rock
Authors: Brunning Paul , Ishak Baidrul 
Published: April 2012

Abstract
Driving piles into carbonate strata, particularly weak rock (calcarenite) andcemented sands is traditionally thought to carry high risk in terms ofpremature refusal, exceedance of fatigue criteria or pile tip buckling. Although soil resistance to driving (SRD) algorithms have been developed forcarbonate deposits they are based on limited experience (primarily ArabianGulf) and there is a need to expand this database to include installationexperience elsewhere in carbonate conditions such as the Australian north westshelf where significant oil and gas developments are planned.
Much of the uncertainty surrounding the prediction of pile driving in carbonatestrata can be attributed to the difficulty in establishing a reliable andcontinuous soil resistance profile which is primarily due to i) the difficultyobtaining suitable samples of rocks such as calcarenite for compressivestrength testing, and ii) the equipment limitations for pushing conepenetrometers into weak rock.
It is standard industry practice to base hammer selection, fatigue damageanalyses and driveability assessments on upper bound plugged conditions which, for weak rocks such as calcarenite, gives significantly higher resistances thanfor the unplugged case and this can lead to the conclusion that driving iseither completely unfeasible or not possible beyond a certain depth.
This study presents data from a pile installation in the Timor Sea to supportmodifications that may be made to existing SRD algorithms to improvereliability of the predictions, at least for this particular site. Back-analyses of the installation data show that unplugged conditions are farmore likely to prevail when driving a large diameter pile which suggests thatautomatically assuming plugged conditions is over-conservative. Possiblecorrelations between cone tip resistance and unconfined compressive strength(UCS) of calcarenite are made by fitting SRD algorithms that require UCS as aninput to those that are based on cone tip data.

Introduction
Offshore pile fabrication and installation is expensive and anyover-conservatism in the design or in driveability predictions can result inproject costs being significantly higher than they might otherwise be. On theother hand, unplanned problems such as premature refusal or pile tip bucklingduring installation are potentially even more costly which is why a cautiousapproach is normally adopted. Where an over-conservative approach leads to piledriving appearing to be marginal, or indeed unfeasible, an alternative andpotentially very expensive solution such as grouted piles or contingencydrilling equipment may have to be adopted. A more balanced approach based onthe most likely driving behaviour would result in optimised project costs.
Pore Pressure Monitoring of Active Fault-Fluid-Hydrate System in Deep Water, Nigeria
Authors: Sultan Nabil , Riboulot Vincent , Ker Stephan , Marsset Bruno , géli Louis , Tary Jean-Baptiste , Klingelhoefer Frauke , Voisset Michel , Lanfumey Valentine , Colliat Jean-Louis , Adamy Jerome , Grimaud Sylvie 
Published: April 2012

Abstract
To characterize the link between faults and fluid release and to identify therole of fluid flow in gas hydrate occurrences, four piezometers were deployedat the border of a shale-cored anticline in the eastern Niger delta. Two ofthose piezometers were deployed along a major fault linked to a shallowhydrocarbon reservoir while the two others were deployed within two pockmarkfields. Pore pressures were measured for periods ranging from 370 and 435 days. The two piezometers deployed along the fault simultaneously registered aprolonged fluid flow event lasting 90 days.
By combining and analyzing acquired data, we show that the fluid-fault systemoperates according to the following three stages:upward pore fluid migration through existing conduits and free gascirculation within several shallow sandy layers intersecting the majorfault,gas accumulation and pore pressure increase within sandy-silty layersandhydro-fracturing and fluid pressure dissipation through sporadic degassingevents, causing pore fluid circulation through shallow sandy layers andattracting seawater into the sediment.
The present work clearly demonstrates how an integrated approach based onseafloor observations, in situ measurements, and monitoring is essential forunderstanding fault-fluid-hydrate systems.

Introduction
Published research papers concerning gas hydrates have exponentially increasedthose last three decades and mainly since natural gas hydrates have beenrecovered worldwide from polar regions to deep-water shelves (Kvenvolden,1994). Generally, most of those research papers focus on one of the followingthree main topics: role of gas hydrates in global climate change (see forinstance Kvenvolden, 1994);gas hydrates as a potential cause of sedimentdeformations and submarine slope instabilities (see for instance Kayen and Lee,1991);gas hydrates as a an unconventional energy resource (see forinstance Collett, 2002).
Detecting gas hydrates and understanding the dynamic of any gas hydrates systemassociated to climate changes, geohazards, and/or energy resources leads toinvolve integrated approaches combining geophysical data, geochemical analysis, geotechnical testing and in situ monitoring. The present work aims to highlightthe importance of pore pressure monitoring in such integrated studies and todemonstrate the importance of such measurements in the comprehension of acomplex active fault-fluid hydrate system in deepwater Nigeria.