bluuebunny/crossref_metadata_2025_split huggingface dataset:
HPHT Formation Evaluation : Planning For Success via a Structured Approach
Authors: Owens J. 
Published: June 2014

Abstract
Successfully delivering HPHT well information objectives can be achieved through a robustly planned formation evaluation programme by applying the principles of a project maturation process. The following discussion outlines a pragmatic approach that compliments many existing corporate project planning systems which adopt a front end loaded philosophy. The goal is to deliver maximum value in a safe manner through a structured planning, execution, application and learning cycle (PEAL).
Wax Deposit Surface Characteristic under Single-phase and Water-in-Crude-Oil Flow Conditions
Authors: Panacharoensawad Ekarit 
Published: June 2014

Abstract
The deposit surface roughness has a direct impact on the pressure drop of turbulent flow in flow lines. Currently, an arbitrary roughness value for the deposit roughness, typically the pipe roughness value, or reference measured pressure gradient is used in deposit thickness calculation models. During the process of wax deposition the topology of the deposit surface is expected to change. Therefore, the assumption of a constant pipe roughness for the deposit interface can result in inaccurate deposit thickness estimation. This paper presents the results of an experimental study on the surface characteristic of the single-phase and two-phase dispersed water-in-oil flow wax deposits. South Pelto crude oil was used for the deposition test. The tests with water cuts of 0, 16, and 35% were conducted. The general observation from the turbulent flow tests is that the deposit near the test fluid inlet side exhibited a patchwork pattern and the deposit sloughing occurred due to undeveloped flow. However, under the fully-developed flow conditions the deposit surface was found to be visually smooth in most cases. Specifically, the deposit surface of (1) the single-phase fully-developed flow cases where 3300 = Reini = 4300 and (2) the fully-developed flow region in all 16% water cut cases was found to be visually smooth. The deposit surface for laminar emulsion flow with 35% water cut displayed many stream-like grooves.
Deepwater Construction Vessel ‘Aegir’ Shifting the Frontiers of Reeling
Authors: van der Graaf Jan , van Zandwijk Kees 
Published: June 2014

Abstract

Description of the material
In the coming decades a significant rise in ultra-deepwater developments is expected. In 2013, Heerema Marine Contractors brought its multi-purpose Deepwater Construction Vessel ‘Aegir’ in operation with the aim to maintain and extend its position in this rapidly expanding market. The paper will focus on the novel concept of the vessel with a fully revised view on pipe reeling logistics.

Application
The vessel is equipped with exchangeable reels, a concept enabling to keep the pipelay vessel in the field during its pipeline reeling operations. This efficiency gain will induce a step change in the economics of reeling. The presentation will illustrate how the functional requirements were translated into the specific lay-out of the vessel and how the requirements of the reeling system played a dominant role in this.
Many of the future deepwater oil and gas fields will be in open ocean waters. A number of novel features have been included in the design to ensure a good workability of the conventional hull-shaped Aegir in long ocean swells, in particular where it concerns the lifting of reels on board the vessel, in order to ensure continuous reeling operations.
Introducing the new pipelay concept with exchangeable reels required the design of new industrial processes for filling the reels at a spoolbase and transporting them to the Aegir. The separation of the reel spooling and transport from the pipelay vessel offers new opportunities for tuning the logistics process to specific project needs.

Results, Observations and Conclusions
The paper will discuss the properties of the vessel and the pipe lay system, the test results, performance of the off-line spooling process and performance in the field.
The market shows appetite for the new reeling concept: meanwhile, two major subsea construction projects have been landed for the Aegir, both making use of exchangeable reels. It will be illustrated how the different settings of these projects lead to different logistic concepts.
The paper will also touch upon the first in field experience with Aegir.

Significance of Subject matter
Subsea Field development, in particular the ultra-deep, HP/HT fields require Game changing Vessel concepts like Aegir to be able to serve the operators. Also when they decide to move to water depths beyond 10,000' with flow lines requiring top tension lay-capacity of 2000tn in remote areas of the world.
Study of the Effect of Condensate Tie-back on Wax Deposition in an Indonesian Offshore Crude Oil Pipeline
Authors: Singh A. , Lee H. , Singh P. , Sarica C. 
Published: June 2014

Abstract
A gas condensate field was tie-backed to an existing subsea pipeline transporting paraffinic crude oil from an Indonesian offshore production system where wax deposition was a primary flow assurance challenge. As expected, condensate addition did alleviate the challenge of both wax deposition and waxy oil gel restart of the commingled pipeline. Pipeline operating data including pigging frequency, transient flow rate and pressure drop were analyzed to estimate average wax deposit growth rates for the condensate line and the commingled line for various blends of oil and condensate liquids.
Flow rate, pressure drop, inlet and arrival temperatures, and seabed temperature data were used to validate thermo-hydraulics of the system. A numerical scheme was developed to eliminate noise in the data and calculate deposition rates between two consecutive pig runs for condensate and commingled pipelines for various blends of the condensate and oil. Detailed laboratory analysis of fluids was performed for their wax deposition potentials (including high temperature gas chromatographic, wax appearance temperature, wax content, density and viscosity). Wax characteristics have been used in an in-house Wax Deposition simulator to predict the wax deposition rate under various operating conditions.
For the condensate liquid, wax deposit surface roughness was found to significantly contribute to the pressure drop increases, and therefore, increase in the measured pressure drop cannot be solely attributed to deposit thickness increase. For the commingled fluid system, the simulator predictions using the Film Mass Transfer Model (FMTM) with aging reasonably matched the deposit thickness obtained from the field data. For the condensate liquid system, both FMTM and Equilibrium Model (EM) were assessed and it was confirmed that the predictions from the two models bound the wax deposition rate calculated from the field data.
Lessons Learned - Counter-acts Used To Install Pipelines Offshore In Very Soft Clay
Authors: Olsen Christian , Brown Neil , Rosborg Anne , Sørensen Carsten S. 
Published: June 2014

Abstract
As part of the Ormen Lange Northern Field Development, 36 large diameter steel cylinders were used as counter-acts to ensure pipeline stability during pipe-lay along route curves. The Ormen Lange field is situated 120 km off the mid-Norwegian coast of the Norwegian continental shelf at the base of the Storegga landslide. Due to the Storegga landslide, the soil conditions vary significantly with a stratigraphy characterized by very soft Holocene clay overlying very stiff clay till. Locally, the clay till outcrops at seabed level. The water depth is in excess of 800 m and the seabed topography is highly irregular. This makes the development of the Ormen Lange field very challenging. Ormen Lange came on stream in 2007, and the operator is A/S Norske Shell. Ormen Lange is the second biggest offshore gas field and the deepest subsea production facility in Europe. The gas is exported through one of the world's longest pipelines, and the gas-export in peak production equivalents 20% of the UK's gas demand.
The chaotic seabed topography and variable stratigraphy presented several unusual geotechnical design challenges. Stability charts were constructed based on a parametric study considering slope gradient, counter-act inclination and penetration of the skirt plate. With use of these design charts, decisions were made offshore to relocate, install additional counter-acts or increase the pre-load the counter-acts with use of a steel clump weight. The counter-acts were designed with an internal lifting mechanism, which allowed for safe installation in the harsh environment. Furthermore, optimization of counter-act locations removed the requirement for a costly subsea rock installation campaign. The methodology proved to be robust and this paper presents lessons learned for design, installation and retrieval of counter-acts in harsh environments on a soft seabed.
The Single-Lift Vessel "Pieter Schelte": Honoring the Past, Shaping the Future
Authors: Heerema Edward P. 
Published: June 2014

Abstract
This paper describes the building of a ship for single-lifting of very large topsides of offshore platforms.
The ship's layout and functioning was described in an earlier OTC paper (Heerema, E.P. 2012).
The paper covered in detail the significance of a motion compensation system for rough seas, and the benefits of single-lifting by removing the need to build up or remove topsides module by module. The paper also described the installation and removal methods for jackets, as well as the vessel's pipelay system for application in the periods when there is insufficient heavy lifting work.
This paper deals with the next step, the actual building of the vessel and her equipment, taking place largely over the past two and a half years; the commissioning is planned to be completed by the end of 2014.
The concept behind Pieter Schelte is entirely novel, and such is the scale of the ship and her equipment that the building is a major challenge, but one that the shipyard and suppliers are presently coping with well. Proven equipment is used in all elements, but the method of functioning is unprecedented.
Pieter Schelte will have a topsides lifting capacity of 53,000 short tons (48,000 metric tons) and a jacket lifting capacity of 27,500 short tons (25,000 metric tons) (see figures 1 and 2).
Her length will be 1253 feet (382 m) excluding lifting equipment protruding overboard, and her width will be 406 feet (124 m). For moving in around platform substructures, the width of the bow slot will be 193 feet (59 m) (see figure 3).
She will also be a pipelayer with a tensioner capacity of 2200 short tons (2000 metric tons), enabling her to lay heavy pipelines in shallow and deep water (see figure 4).
Mini to Mega LNG: An Independent's Perspective
Authors: Khurana Sandeep , Gallon Steve 
Published: June 2014

Independent Oil Companies have found large gas resources globally, onshore and offshore. With relatively low value attributed to gas resources due to either limited or highly competitive markets within its vicinity, companies are facing a dilemma on how to strategize gas to LNG effectively to improve return on investment. Gas to LNG requires understanding of integration and/or interface across various business segments for value creation. The options are numerous and challenging ranging from partnership with established players to entering into new business streams. The paper will address commercial and technical challenges as well as above ground risks such as Government policies and regulatory authorities.
The paper will analyze various business aspects for gas to LNG such as entering into a large LNG plant ownership and operations, effectively being a part of transportation and marketing, moving to new technology such as Floating LNG, or starting small with mini-LNG plants for onshore gas resources.
The paper will illustrate risks and rewards along with capital exposure in various business segments. The amount of integration and commercial innovation required to secure the value of gas resources will be contemplated for various scenarios with case studies.
Li-Ion Batteries for Energy Storage and Hybrid Power: Safety and Suitability Considerations for Offshore Applications
Authors: Hill Davion M. , Agarwal Arun , Gully Benjamin 
Published: June 2014

Abstract
With new battery technologies available and impending emissions control areas (ECA) in the US continental shelf, and NOx enforcement mechanisms in the North Sea and elsewhere, there is a need to reduce emissions and improve efficiency of oil and gas exploration and production. It has been stated that ECA regulations will require NOx reductions by 80% by 2020. This reduction can be achieved in part with hybrid power systems. In addition, the movement toward subsea systems will introduce new power requirements. Transmission to ultra deepwater assets will be costly, and a need to downsize transmission lines and cables can be met with subsea battery systems which buffer transients and reduce the maximum capacity for cables. The challenge that the oil and gas industry faces is to decide when and where hybrid power systems provide the most value for operations, how they should be implemented, what technologies are acceptable, what safety considerations there may be, and how these technologies can improve the bottom line. There is a wealth of information on lithium ion batteries though it is not all consistent; cost data is unclear, lifetime and energy density considerations vary under different conditions, and ruggedness and application to harsh environments is a large uncertainty.
Gas Hydrate Deposits of Krishna Godavari Basin, India: Issues and Potentiality in Exploration and Commercial Production
Authors: Sahay Vinay K. , Johnson Arthur H. 
Published: June 2014

Abstract
Gas hydrate, is an important energy resource, occurring in sediments on the continental margin of the India Ocean. Quite significant scientific and commercial interest has been generated in India with a 130 m thick gas hydrate discovery in shale in Krishna Godavari Basin. This paper presents the evaluation results of seismic, logging while drilling, and core data in the context of exploring those issues which are relevant in the commercial production of gas hydrate deposits of Krishna Godavari Basin. Apart from this, we discuss the scientific and technological issues and potentialities in commercial exploitation of Krishna Godavari gas hydrate deposits.
Evaluation of logging-while-drilling (LWD) sonic log data of Krishna Godavari Basin shows an increase of relative velocity in the gas hydrate bearing zone. Apart from this, the LWD density log data also shows a relative increase of density in gas hydrate bearing zone in Krishna Godavari Basin. Increase in relative velocity and density of the zone under evaluation may be ascribed due to presence of gas hydrate (as a solid mass, increasing overall cohesiveness of hosting lithology shale, present within the depth boundary of gas hydrate stability zone). The sonic and density log validates their use as an important tool in demarcation of gas hydrate bearing zones and gas hydrate reserve estimations, calibrating and integrating with core-based gas hydrate saturation data. Evaluation of seismic sections, however, does not show the BSR (Bottom Simulating Reflector) as a full proof and conclusive proxy for the presence/absence of gas hydrates as has been observed from the data of KG Basin. Precaution should have to be exercised while utilizing BSR, in seismic data evaluation and interpretation, in the identification of gas hydrate.
Investigation and evaluation of the data of the Krishna Godavari Basin gas hydrate deposits indicate the potential for commercial production utilizing presently available knowledge of science and technology for finding viable accumulations of gas hydrates. Apart from the above discussed aspects, the paper also provides some suggestions which can be utilized and integrated with the National Gas Hydrate Program, India to resolve many issues.
Wave Energy Research, Development and Testing Including Testing of Materials and Technologies for Bio-Fouling and Corrosion Prevention
Authors: von Jouanne Annette , Baker Josh , Yim Solomon , Amon Ean , Moran Sean , Lettenmaier Terry , Bunn Malachi , Yokochi Alex 
Published: June 2014

Abstract
This paper illustrates opportunities for ocean wave power to become a new, reliable and clean source of renewable energy. Presented are the activities of the Northwest National Marine Renewable Energy Center (NNMREC), a Department of Energy sponsored partnership between Oregon State University and the University of Washington (UW). NNMREC performs fundamental technological, social, and environmental research on marine renewables, in addition to providing unique testing facilities including a wave energy linear test bed, 2D and 3D wave tanks, and an Ocean Sentinel mobile ocean test berth instrumentation buoy to facilitate ocean testing. This paper includes the ongoing research and testing with the Ocean Sentinel instrumentation buoy, in addition to the developing cable-to-shore testing facility, which would be the first utility scale, grid-connected wave energy test site in the US. Finally, this paper presents the ongoing research and testing of materials and technologies for bio-fouling and corrosion prevention in the marine environment.
In Depth Cost of Energy Analysis of East Coast Offshore Wind Farms
Authors: Drenick Chelsea , Prowell Ian , Dolan Dan 
Published: June 2014

Abstract
As the United States moves closer to constructing its first offshore wind farms, data-based decisions about how to select the most viable project site are crucial. This in-depth study examined both the revenue and costs of three potential wind farms off the East Coast. Multi-year energy time history analyses were performed to determine the energy generation and revenue potential of each site based on local winds and energy pricing. The costs were determined for each site based on characteristics including water depth, distance to shore, and distance from a port. These characteristics formed the basis to estimate the foundation costs, cabling costs, equipment mobilization fees, and other expenses associated with the project. Overall, this study shows that seemingly similar sites can have a very different levelized cost of energy (LCOE) estimates when an in depth analysis is performed.
Estimation of Temporal Probability in Offshore Geohazards Assessment
Authors: Nadim Farrokh , Lacasse Suzanne , Choi Young Jae , Hadley Christopher 
Published: June 2014

Abstract
Risk assessment for sea floor installations exposed to offshore geohazards requires an estimation of the occurrence probability of a hazardous event during a reference time period, for example the annual probability of the installation being impacted by a submarine mass gravity flow. The paper describes the procedures developed in recent offshore geohazards studies for the estimation of the temporal probability in two situations:When there is a clear trigger for initiating the slide that would develop into a mass gravity flow andWhen there is evidence of slide activity, but no obvious trigger for slide initiation.
In the first situation, the assessment of temporal probability requires a probabilistic description of the frequency and intensity of the trigger(s) releasing the submarine slide, a probabilistic model for calculating the response of the slope to the trigger, and a probabilistic model for evaluating the runout of the released mass gravity flow. Using these models, the probability of a mass gravity flow impacting the seafloor installation(s) should then be computed for all relevant scenarios and return periods in order to derive the annual or lifetime probability. However, analyzing all possible scenarios and return periods could be time-consuming and impractical. The paper presents a simplified procedure and demonstrates its application through a case study for earthquake-triggered slides. In the second situation, where it is difficult to identify the trigger(s) initiating the slide, one must rely on the identification and dating of recent (in the geological sense) slide events in the area. The dating results and other relevant geological evidence are then integrated into a Bayesian framework to establish the annual probability of slope instability. The paper also presents the theoretical framework and example calculations for this situation.
Intelligent Casing-Intelligent Formation (ICIF) Design
Authors: Stalford Harold , Ahmed Ramadan 
Published: June 2014

AbstractIntelligent Casing-Intelligent Formation (ICIF) design is evaluated for ultra deepwater (UDW) applications and for maximizing investments therein. ICIF design is a composite of Intelligent Casing (IC) design and Intelligent Formation (IF) design. The impact of ICIF design on drilling, completion and production technologies is assessed. The benefits and implementation challenges of ICIF design are evaluated in identifying optimal UDW applications. Early detection and early forecasting benefits are identified in evaluating the cost effectiveness of using ICIF design. Early detection and forecasting scenarios are utilized in evaluating ICIF design for its impact on Health, Safety, and Environment (HSE), well control, risk management activities and cost control strategies.Intelligent Casing (IC) designs are considered that utilize fiber optic based distributive sensing of temperature, pressure, strain, acoustic, and chemical. Fiber optical cable deployment outside the casing is considered in the IC designs for permanent and continuous monitoring of reservoir-performance and wellbore integrity to enhance production and return on investment; multilayered reservoirs and multiphase flows are addressed. ICIF designs are cost-effective as compared to conventional designs. Various issues associated with the installation and operation of IC designs and IF designs are addressed (e.g., perforations for completions). The operation and control of downhole equipment (e.g., submersible pump) and the communication of such operational information to the surface are addressed. The benefits of early detection of wellbore barrier failure and/or water breakthrough issues are highlighted. ICIF designs are compatibility with conventional casing and cementing design and procedures.
Impact on Risers and Flowlines Design of the FPSO Mooring in Deepwater and Ultra Deepwater
Authors: Saint-Marcoux J. , Legras J. 
Published: June 2014

Abstract
Ten years back the choice between turret-moored FPSO and spread-moored FPSOs was primarily dictated by local met ocean conditions: spread moored FPSO in West Africa, soft-(DICAS) mooring FPSO in Brazil, and turret-moored FPSO elsewhere. Over the recent years West Africa is turning to turret-moored FPSOs (internal and external), and Brazil has installed spread-moored FPSOs. Whereas spread moored FPSOs prevail in larger sizes (about 2MB), new built, turret-moored, FPSOs are usually smaller in size (1MB) with external-turret offering cost and schedule benefits to the operators over internal-turrets. This paper presents the impact of this new trend in FPSO mooring on the design of the flow lines and risers and related impact to field layout. The orientation of a spread-mooring is governed by the local met ocean conditions and may not be optimal for the routing of the flowlines; also compromises may have to be done with regards to flow assurance constraints. Turret-moored FPSO allow possibly a better use of the seafloor space especially in deeper water where the seafloor slope is gentler, and result in shorter flowlines. Risers for spread-moored FPSOs are decoupled unless they can be a small number and limited to the central part of the hull. For turret-moored FPSO, decoupled risers allow larger FPSO offset movements and are compatible with both internal and external turret. In the case of SHR or HRT, safety rules impose a significantly longer jumper lines to protect the FPSO from accidental buoyancy tank release. SCRs may also be feasible but highly insulated risers are very light and prone to fatigue in-service. Examples are being provided to evaluate the impact of the various FPSO mooring options.