bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integrated Project Management Applied to Ocean Bottom Seismic
Authors: Hartland Martin John , Platz Michael Scott 
Published: April 2016

Abstract

Objectives
This paper lays out key elements of an Integrated Project Management Approach for Ocean Bottom Seismic Projects involving multiple vessels and combined data acquisition services.

Methods
The methodology is based around a generic data acquisition project life cycle and a group of main activities. The guidelines for several of the activity groups will be explained using diagrams and narrative. The context in which this methodology is applied is set around seafloor seismic acquisition which typically will involve a fleet of three to six offshore service vessels (OSVs) working together on a survey, very often significant SIMPOS activity will be experienced. The vessels utilized will often be considered as critical path resources and therefore system redundancy is important to maintain. Services of multiple data providers need to be integrated and combined to support operational efficiency and acquisition deliverables.

Conclusions
The methodology employed has proven to be successful on several complex OBS projects, and where the project objectives have been achieved to the satisfaction of the client and the contracted company. Being able to successfully execute complex data acquisition projects requiring the integration of multiple data acquisition service providers has become extremely important as oil reserves are increasingly scarce and oil companies seek to maximize the recovery from these fields, Seafloor seismic is considered the highest quality of Marine Seismic data available and keeping the cost to controlled and predicted levels is essential for both contractor and client. It is through an Integrated Project Management approach that this can successfully be achieved. The methodology can be applied in other areas of offshore project management with some adaption for the specific business sector requirements.

Additive Information
Existing methodologies and techniques are considered to be highly generic and therefore fail to approach the real challenges faced by organizations who attempt to deploy these methods. This paper is intended to provide insight into integrated project management specifically intended for ocean bottom seismic data acquisition projects. The Case study based around a real project executed from June 2014 – to November 2015 in the Bay of Campeche Mexico will demonstrate the effectiveness of the Integrated Project Management approach.
An Improved Method for Model Test Based Identification of Drift Coefficients and Damping for Floating Platforms
Authors: Rogne Øyvind Ygre , Haug Nora , Løken Rolf 
Published: April 2016

Abstract
A new method for identification of wave drift coefficients and low-frequency damping from model tests is presented. The method is motivated by the lack of robust numerical methods for the calculation of the viscous contribution to the mean and slowly varying wave drift forces – often the largest contribution for semisubmersibles in storm sea states. The drift coefficients represent the diagonal of the difference frequency quadratic transfer function, and because Newman’s approximation is implied by the method, these drift coefficients will give rise to both mean and slowly varying forces.
The new method is based on a weighted least squares solution of the equation of motion, and uses a combination of linear and non-linear least squares methods. The parameters are identified such as to minimize the error in the slowly varying horizontal motion over the entire measurement record.
The method will be demonstrated using data from physical model tests of three different semisubmersibles in a large number of different sea states, including wave only, wave+current and wave+current+wind tests. The accuracy of the obtained results is investigated by the ability of the identified model to back-calculate the measured motions. In addition, a "standard error" on the drift coefficient curves is provided that shows the frequency interval where the identified drift coefficients can be trusted.
The case studies show that the identified models are able to back-calculate the measured motions with good accuracy. Both viscous effects and wave-current interaction is seen to have an impact on the drift coefficients and damping. The quadratic damping is seen to be of much less importance than the linear damping in most cases. Still, it is argued that a significant portion of the linear damping comes from viscous effects, and that the linear viscous damping represents a low-frequency best-fit to the actual all-frequency quadratic damping.
Auto-ID Tracking System Monitors the Location and Compliance Status of Offshore Assets
Authors: Coaton N. 
Published: April 2016

Abstract
The objective of this paper is to demonstrate the value of utilising automatic identification (auto-ID) technology to monitor the location and compliance status of offshore transportable Cargo Carrying Units (CCUs) and other oilfield equipment in the oil and gas sector.
It is very common to see logistical inefficiencies in the oil and gas supply chain. As a result, there is an increasing demand for solutions that will minimise those inefficiencies, improve productivity and reduce operational costs. The most requested solutions are those focused on achieving improved and automated capture of data related to asset and material movements using globally accessible web-based applications and auto-ID hardware components, such as GPS and RFID, which are certified to critical hazardous area standards such as ATEX and IEC-Ex. Any solution deployed must also be internationally applicable and based on open standards to ensure global use and cost-effective interoperability.
A key concern for Operators' Logistics functions and Service Companies is ensuring that asset turnaround time and on site asset handling costs are kept to a minimum. Therefore, removing manual processes and improving data fidelity and accuracy is key.
By applying auto-ID technology to assets and deploying RFID reader infrastructure, many manual processes related to asset tracking, logistics coordination, reporting and administration are greatly reduced or removed (Gaukler, Hemmige and Merchan 2009). Bottlenecks and inefficiencies are also highlighted when the data set is accurate and current.
An Operator was internally reporting 88 days and 58 days respective turnaround times for Offshore Chemical Tanks and CCUs which far exceeded their global KPI targets (56 days and 28 days respectively). However, by applying GPS the reported turnaround for the tagged units was actually averaging 33 days for tanks and 18 days for CCUs – a variance of 78%. The increased visibility and accurate data that auto-ID technology produced, identified where the inefficiencies in the supply chain were and focused efforts on specific bottlenecks.
A major Service Company also achieved a combined 40% reduction in their rental asset sourcing and handling costs within one of their major facilities by introducing active RFID tags and associated reader infrastructure on site.
Additional benefits that can be realised from auto-ID tracking of offshore assets include: Up to 20% reduction in transport costsReduction in operational costs and duplicate ordersUp to 25% increase of asset utilisationReduction in billing disputes and back office administrationReduced headcount to manually track asset location
An Integrated Geomechanical Modeling and Completion Selection for Production Enhancement from Lower Tertiary Wells in GOM
Authors: Bagci S. , Tjengdrawira M. , Park N. , Hustedt J. 
Published: April 2016

AbstractAn integrated study involving geological, geomechanical, reservoir and completion analyses were conducted to design a new completion system for optimizing production in Lower Tertiary play in deep-water Gulf of Mexico (GOM). Lower Tertiary reservoirs are generally characterized by lower productivity potential due to low permeability and poor reservoir energy in some areas due to low GOR, little/no gas cap and very limited water drive. Multiple reservoir sand layers need to be hydraulically fractured for production under a potentially high geo-pressure and stress environment. The design of a lower completion system focused on stimulation, sand control systems and their impact on production. The proposed lower completion system has a large ID to maximize production rates and supports stimulating reservoirs with high proppant volumes and pump rates to increase the number of treatment zones.Petrophysical and geological analyses were conducted to determine the distribution of sand bodies in thirty study wells drilled across from Alaminos Canyon through Keathley Canyon to Walker Ridge (W-E). A geomechanical analysis was conducted to determine the variation of rock mechanical properties and stresses across these regions. Sanding analysis was conducted to assess the risk of rock failure and the effect of production in open-hole completion under the high draw-down scenarios.Frac-Pack fracture modeling was conducted with an optimized stress profile for a candidate well for three lower completion systems to select the optimal fracturing intervals and treatment schedules that will maximize well performance. Possible oil production rates were estimated for various scenarios involving natural flow, ESP and subsea boosting.This study focusing on understanding the reservoir characteristics for lower completion systems design ensures optimal technology selection to ultimately enhance well productivity and ROI with better production rates and ultimate recovery.
Cessão Onerosa FPSOs - Challenges and Achievements Conducting Four Simultaneous Hull Conversion Designs
Authors: Portella R. B. , de Souza Lima H. A. 
Published: April 2016

Abstract
Under the development of the Brazilian pre-salt onerous concession areas Petrobras contracted Enseada Industria Naval for the conversion of 4 (four) VLCC ships into the hulls of FPSOs P74, P75. P76 and P77, for which PROJEMAR have awarded a contract for the complete hull conversion engineering design.
Even with the accumulated experience on the design of 12 (twelve) FPSOs conversions, nothing could be compared with 4 (four) ships being simultaneously converted in two shipyards, being one in Brazil and one in China, to receive 4 (four) Process Plants weighting about 35.000 t designed by 3 (three) different Topsides engineering designers.
This paper intends to describe the main challenges and achievements of the engineering design work for the conversion design of the 4 (four) FPSOs, where the need to maximize standardization conflicted with the different hull configuration of the VLCCs that were being converted, with the different production characteristics of the two shipyards involved on the conversion work and with the different design philosophies of the Topsides engineering designers. These can be exemplified by: The need to face single hull and double side VLCCs that were built in different shipyards in Korea and Japan, what led to different main deck reinforcement and different strategies for steel renew;The different Topsides engineering led to different main deck reinforcements for the Topsides equipment and structures;The main equipment was standardized, but the different ship´s hull structure led to different structural solutions, and smaller equipment were acquired from local suppliers close to shipyards;Different arrangements and tanks configuration led to different piping designs;A new standard accommodation block needed to be fitted in different main deck structure configurations;Individual motions analyses were carried out for each FPSO, but needed to be validated by a unique model tests program;etc
In summary, maximize the design standardization is a key path to improve construction productivity, but as an FPSO conversion design is essentially a tailor made activity, this duality was highly pronounced when dealing with the multiple simultaneous activities of the Cessão Onerosa FPSOs design.
Deepwater Hydraulic Well Intervention at Tahiti: A Creative Hybrid Solution
Authors: Beard J. , Boiteau J. , Chauvin R. , Conner B. , Courtois C. , Theall T. 
Published: April 2016

Acid stimulation and scale squeezing are generally well-established hydraulic well intervention practices, although methods for delivering such treatments specifically to deepwater, subsea wells are a less mature area of application. A rig-less intervention alternative provides a more economic option for intervening on subsea wells, in comparison to traditional rig-based methods. This technical paper describes the planning and execution of a multi-service vessel (MSV)-based hydraulic intervention campaign at Chevron's Tahiti field in the U.S. Gulf of Mexico.
Challenged with early-life well productivity decline and imminent injected seawater breakthrough, the Tahiti asset formed a multi-disciplinary team to develop a fit-for-purpose solution to remediate and mitigate these concerns. Acid stimulation was selected to arrest and recover well productivity, while scale squeezing was required for protection against barium sulfate scaling from the mixing of formation water and injected seawater. These treatments were to be delivered to subsea production wells in water depths of ~4,200 ft.
The design basis of this hydraulic intervention system involved dual, open-water coiled tubing strings deployed from the MSV to a subsea stimulation module. This module is landed and secured subsea on a modified suction pile, allowing structural isolation from the horizontal subsea production trees. In turn, a flexible jumper from this module to a valve package and modified choke insert on the tree enabled access to the wellbore for delivery of the treatments. De-coupling the stimulation module from the tree interface alleviated the risk and complexity of removing crown plugs and imparting load forces on the tree, and denotes the ‘hybrid’ nature of the system.
Design and operational phases required overcoming challenges such as coiled tubing fatigue management, unexpected loop current conditions, and deployment sequence optimization. Given the first-time deployment of this hybrid system, detailed front-end engineering and design was required for validation of an enhanced well control and emergency disconnect system, to accommodate safe execution. The 5-well campaign was executed incident-free during 2015, delivering a total treatment volume of almost 30,000 bbls, resulting in 8,500 BOPD gross initial production uplift, and cost savings of 85% in comparison to traditional rig-based methods.
Key Development Technologies of Deep Water Oilfields in Angola
Authors: Bingyu Ji , Zhihai Chen , Huaiyin Li , Jingwei Wang , Xuebo Dang , Zhang Shiyang 
Published: April 2016

Abstract
Sinopec has acquired six deep water blocks in Angola. According to their geological features, a series of key technologies have been developed and applied by all partners under the leadship of operaters, covering reservoir description, reservoir engineering, production engineering, flow assurance, etc. On the Basis of a sedimentary faces study, seismic waveform and amplitude, prediction method was developed to identify turbidity sands with thicknesses of 3-5 m; fault imperviousness and connectivity were determined by using static value potential of shale smear, dynamic interference testing, and dynamic correlation of production data on both sides of the faults; individual well production capacity was evaluated by DST testing results, and residual oil was described by 4D seismic data; six development strategies were made for Angola deep water oil fields development, including fast recovery, high production rate with minimum wells, carefully feasibility study in advance, full utilization of main offshore facilities, optimization of the entire production system, and efficient operation of production facilities. Additionally, certain technical measures were successfully applied to determine development layer series, well pattern and spacing, development sequences, injection strategy, and production rate. Slug flow was minimized by riser base gas lift. Insulation and chemical injection were introduced for flow assurance. Most wells were completed with open hole gravel pack and expanding screen for sand control. Above mentioned technologies were effectively applied and proved to be successes in Block 18, Block 15/06, and Block 32, which have technical significances for the development of oilfields with similar conditions.
Top-Hole Formation Pore Pressure Assessment at Deepwater Well Sites Using a Geotechnical Approach
Authors: Trandafir Aurelian C. , Haneberg William C. 
Published: April 2016

Abstract
Geotechnical investigations are routinely performed in site characterization studies for offshore infrastructure development. Until present, little consideration has been given to the application of geotechnical methods to pore pressure assessment in the top-hole section of deepwater sediments. Laboratory geotechnical tests including one-dimensional consolidation tests and index property measurements on intact cores collected from pilot holes drilled at prospective well sites have the ability to provide a rigorous characterization of the normal compaction trend and in-situ porosity, which are critical in evaluations of overpressure associated with a compaction disequilibrium mechanism. This paper presents key considerations pertaining to interpretation of results from geotechnical tests in the context of top-hole formation pore pressure assessment at deepwater settings. Examples of top-hole pore pressure regime evaluation at two hypothetical deepwater wellsites are used to depict particularities related to development and interpretation of normal compaction trend describing stratigraphic sequences associated with various depositional mechanisms, likely to be encountered within the top-hole section of deepwater sediments.
Case Study on the Design of HPHT Components Using ASME Section VIII Division 2 and 3
Authors: Peters D. T. , Biagiotti S. F. 
Published: April 2016

Design margins in high pressure / high temperature (HPHT) equipment vary throughout the various Codes and Standards. This paper is an overview of the design standards which can be applied to HPHT service or are currently under development.
This paper will provide a case study of the design philosophies referred to in API 17TR8 which refers heavily on ASME Section VIII Division 2 and Division 3. This will demonstrate the difference in design margins, and how the life of the components may be affected.
Design approaches such as "Design-by-Rule" or "Design-by-Analysis" are included in the standards used today. Implementation of the "Design by Analysis" methods can be very complex and require a significant amount of analytical rigor, compared to traditional "Design-by-Rule" analyses. However, the benefits of the additional rigor can be significant to allow the use of lower design margins which will minimize material while providing equal or increased theoretical design lives.
HPHT equipment is entering into operating pressure ranges that have rarely been experienced before by similar equipment. API 17TR8 does not have approved industry guidance that would support a traditional "Design-by-Rule" process. The lower design margins used by some codes can have the unintended consequence of leading to significant areas of potentially high stresses due to thinner sections and stress concentrations, which can lead to fatigue issues. A combined approach which includes lower design margins and rigorous analytical methods for the determination of the cyclic life of components can lead to robust designs which both minimize cost while improving manufacturability and reliability.
VIM Model Test of Deep Draft Semisubmersibles Including Effects of Damping
Authors: Antony A. , Vinayan V. , Madhavan S. , Parambath A. , Halkyard J. , Sterenborg J. , Holmes S. , Spernjak D. , Kim S. J. , Head W. 
Published: April 2016

Abstract
Semisubmersible platforms are good candidates for hydrocarbon exploration and production in the Gulf of Mexico (GoM) and elsewhere. These platforms are a preferred choice for deep-water applications involving higher design throughput. A dry tree application of semisubmersible provides the benefit of having improved well control, direct vertical well access, easy access to production equipment, reduced capital expenditures and other dry tree benefits. These are in addition to the benefits that a semisubmersible platform has over spars and tension leg platforms (TLPs). A public-private partnership has sponsored multiple projects since 2009 with the aim of maturing a dry tree semisubmersible design that is cost-effective and safe like spars and TLPs. Due to the deeper draft of the semisubmersibles proposed for the dry tree applications, vortex induced motion (VIM) is an area of concern that needs to be addressed during the design stage. The research work presented here is a part of the "Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters."
The effect of additional damping due to mooring lines and risers on the VIM response of a deep draft semisubmersible is an area of focus of the ongoing project. CFD-based predictions show a significant reduction in the VIM response when additional damping is considered. With the intent of validating the CFD models and to further understand the effect of additional damping on the VIM response, a model test campaign was conducted with different levels of applied additional damping. The paired column semisubmersible and conventional semisubmersible platforms were tested, with and without damping and the results are discussed here. In addition, during model testing, the conventional semisubmersible hull was equipped with a column force measurement system to measure the hydrodynamic forces on the individual columns.
The results of the study show that damping plays a significant role in reducing the platform VIM which directly impacts the estimated fatigue damage of mooring lines and risers, and which in turn can reduce the overall cost of the system.
A Novel Approach to Replacing a Gravel Pack Completion Using Hydraulic Screens to Remove the Annular Gap
Authors: Oddie K. , Clark M. , Arnestad E. S. , Davidian T. , Ravndal M. , Evans J. 
Published: April 2016

Abstract
Achieving flow performance in openhole sand control completions often requires removal of the annular gap between the screen section and wellbore. For the first time in the industry, patented hydraulic screen technology has been used to provide wellbore support and overcome the challenges associated with gravel packing in depleted reservoirs with low operational margins.
This paper demonstrates how new technology has been adopted by an operator in Norway to provide effective downhole sand control in an offshore environment faced with continuous reservoir pressure depletion. Detailed job planning and evaluation of risks when adopting new technology is described.
The case study describes a producer well drilled to 2580 m, at a maximum deviation of 30º, and temperature approximately 90ºC. With the sand control equipment run to depth closed ended, the liner hanger and hydraulic screens are set by surface applied pressure. When set, the screens extend radially to close the annular gap and provide wellbore support; production ports in each screen provide the flow path from the reservoir to production tubing. The liner hanger packer was set and reservoir isolation barrier valve closed in the same trip providing testable barriers, prior to displacing the well for upper completion operations.
The paper outlines how adopting new technology challenges openhole gravel packing and delivers effective downhole sand control in a depleted reservoir. The operator has demonstrated savings associated to operational planning, logistics, HSE risks and rig time. Production rates meet expectations with all screens contributing to flow.