bluuebunny/crossref_metadata_2025_split huggingface dataset:
Hydro-Test Risk Minimization Through Design and Processing for Subsea HP/HT Well Equipment
Authors: Lindley Roy , Fraser Dan , Aiken Bill , Bailey Greg , Patrick David 
Published: April 2015

Abstract
In the realm of high pressure (15,000 psia or greater), high temperature (350 F or greater), or a combination of both, today's manufacturing hydro-testing practices may be detrimental to components intended for deepwater use such as in the Gulf of Mexico. The purpose of this paper is to revisit this practice in terms of designing and developing high pressure/high temperature (HP/HT) equipment while continuing to assure "fitness for service" with adequate safety margins.
The process considers hydro-testing history including recent trends and current requirements in key standards. Risks surrounding environmental cracking processes under stress are also considered. These can lead to rapid component failure and warrant special consideration because of the H2S environment often found in HP/HT wells in the Gulf of Mexico. Finally, practical materials limits and the underlying basis for key codes and standards are examined relative to applicability to HP/HT service in such an environment. This includes recognition for how criteria were established, related limitations, and how this information is used in the design, development, and manufacturing process. At one time, the hydro-test at the end of component manufacturing was a key indicator of safety margin (or even a proof test) and, depending on the era and circumstances, test pressure was several times the rated working pressure (RWP) of a component or vessel. Today a typical hydro-test pressure factor recommended by API is 1.5*RWP. However in the (HP/HT) application a 1.5 pressure test factor can cause plastic deformation of metallic components and may compromise "fitness for service."
For anticipated HP/HT conditions (H2S presence) in the Gulf of Mexico, this paper proposes a reasoned approach concerning the basis for a hydrostatic test. This proposed approach is coupled with an integrated methodology for manufacturing HP/HT equipment that includes design, design verification, materials evaluation and quality systems.
The approach attempts to preserve a traditional hydro-testing comfort level while minimizing pre-service stress and risks of H2S susceptibility on NACE MR0175/ISO 15156 Part 2 materials (carbon and low alloy steels). While more detailed studies and physical tests are certainly needed for these material types, the proposed approach offers a roadmap to reduce hydro-testing induced strain related consequences and risks in HP/HT equipment.
This paper is intended as a fundamental re-examination of the role and value of hydro-testing apart from merely accepting or slightly modifying historical practices.
Distillation of Seismic Attributes to Geologic Significance
Authors: Roden Rocky 
Published: April 2015

Abstract
The generation of seismic attributes has enabled geoscientists to better understand certain geologic features in their seismic data. Seismic attributes are a measureable property of seismic data, such as amplitude, dip, frequency, phase and polarity. Attributes can be measured at one instant in time/depth or over a time/depth window, and may be measured on a single trace, on a set of traces, or on a surface interpreted from the seismic data. Commonly employed categories of seismic attributes include instantaneous, AVO, spectral decomposition, inversion, geometric and amplitude accentuating. However, the industry abounds with dozens, if not hundreds, of seismic attributes that at times are difficult to understand and not all have interpretive significance. Over the last few years there have been efforts to distill these numerous seismic attributes into volumes that can be easily evaluated to determine their geologic significance and improve seismic interpretations. With increased computer power and research that has determined appropriate parameters, self-organizing maps (SOM), a form of unsupervised neural networks, has proven to be an excellent method to take many of these seismic attributes and produce meaningful and easily interpretable results. SOM analysis reveals the natural clustering and patterns in the data and has been beneficial in defining stratigraphy, seismic facies (pressure), DHI features, and sweet spots for shale plays. Recent work utilizing SOM, along with principal component analysis (PCA), has revealed geologic features not identified or easily interpreted previously from the data. The ultimate goal in this multi-attribute analysis is to enable the geoscientist to produce a more accurate interpretation and reduce exploration and development risk.
Offshore Gas Program Acceleration (Karan Gas Program)
Authors: Alotaibi Abdulwahed Z. , Alyahya Abdullah M. 
Published: April 2015

Abstract
The Karan Gas Program successfully completed Saudi Aramco's first offshore nonassociated gas development with a capital budget of US$ multibillion, and achieved record early gas in 2 years and 3 months with full production in 3 years and 4 months. The Karan gas field is located approximately 110 km offshore in Saudi Arabian Gulf territorial waters. It was discovered in 2007 and has a production capacity of 1,800 million standard cubic feet per day (MMscfd) of natural gas.
The Karan field development schedule was accelerated to meet the increased demand from the energy sector for Saudi Arabian gas. The proposed OTC 2015 paper will focus on the project management aspects of the program and include a full field development case study of the field expansion to increase capacity and sustain production. The paper and presentation will elaborate on accelerated offshore gas program development methodologies that resulted in gas production from wells to the domestic consumers in a record timeframe.
The program was executed under four subprojects that were developed concurrently as follows: Karan Gas Facilities: Responsible for providing the primary gas processing facilities.Karan Offshore Facilities: Responsible for fabricating and installing production and tie-in platforms.Karan Gas Pipelines: Responsible for linking the offshore and onshore elements. The project fabricated and installed flowlines from each production well to the tie-in well and 110 kilometers of 38 in. pipe to the onshore producing facility.Manifa Gas Facilities: Responsible for installing processing facilities for associated sour gas and hydrocarbon condensate from the Manifa offshore oil field.
Guidance for the Development and Implementation of an Effective Well Integrity Management System
Authors: Wilson Valerie 
Published: April 2015

The NORSOK D-010 standard established a definition of Well Integrity: “The application of technical, operational and organizational solutions to reduce the risk of uncontrolled release of formation fluids and well fluids throughout the life cycle of a well.” If that is the ultimate goal, how do we get there?
This document was created with the goal to provide references, a basis of information, and guidance for best practices to operators for developing and implementing a Well Integrity Management System (WIMS).
This paper will review the industry documents that address Well Integrity and outline their requirements or recommendations of a Well Integrity Management System (WIMS). This paper will address what elements should be covered in a WIMS. It will also expand on each of these elements in order to provide information and guidance for an operator to build a WIMS. This paper will cover the topic of best practices for successful implementation of a WIMS, from training, personnel buy-in, and auditing/tracking to verify the effectiveness of the program.
All Subsea: A Vision for the Future of Subsea Processing
Authors: Ruud T. , Idrac A. , McKenzie L. J. , Høy S. H. 
Published: April 2015

Over the past 10 to 15 years subsea processing has been globally established as a market segment within the subsea development arena. Subsea processing is expected to be a growth platform for operators and for the service companies that are developing equipment and solutions for well processing and treatment at or below the seabed. The ultimate result of the All Subsea vision is the production of hydrocarbons from reservoir directly to market. Operators and service companies have high expectations for the profitability this business offers and share the All Subsea vision of future topside-less developments.
This paper examines the realism of this All Subsea vision and discusses how the vision can be implemented, based on an analysis of the current state-of-the-art technology and the gaps and barriers that may jeopardize the realization of true subsea- to-market solutions.
Developing products and systems with high development costs for a limited market requires a close cooperation between the suppliers and oil companies.
The paper also reflects on the history of subsea processing, the market trends, and the way subsea processing technologies are adopted by the industry, seen from the authors' perspective and with their extensive experience in developing and delivering subsea processing solutions worldwide.
Prospect of Production Optimization Challenges of Gas Wells with Liquid Loading Problem Using New Surfactant and Nanotechnology
Authors: Wu Junwen , Lei Qun , Xiong Chunming , Zhang Jianjun , Li Jun , Cao Guangqiang , Wang Yun , Jia Min , Li Nan , Liu Yan , He Chunyan 
Published: April 2015

AbstractDecrease of gas production is an indicator that liquid column is probably building up in the well and an additional energy is required to lift the liquid out should be applied to control this situation.Foaming agents provide a means to reduce the density of the liquid so that it can be removed from the well with the gas flow, unloading the accumulated liquid in gas and gas condensate wells. The main constituents of foaming agents are surface active agents. Foam stabilizers are added to increase foam stability. Foaming agent should be selected to form a stable foam under given condition, which means in the presence of salt or sweet water, hydrocarbon phase, at given temperature and pressure.Currently, there are lots of different types of foaming agents. Previous studies mainly focused on the complex between anionic surfactant and anionic surfactant, anionic surfactant and amphoteric ion surfactant, however, the stability of the foam formed by such foaming agents is poor. Therefore, it is necessary to develop a robust foaming agent to cope with the harsh conditions. Traditional research neglect the study of complex between anionic surfactant and cationic surfactant, nevertheless the synergies between them through appropriate method can greatly improve the foam stability compared to one-component system. The strong electrostatic interaction between the opposite charge ionic head groups and the hydrophobic interaction between the hydrocarbon groups made the solution exhibit a complex phase behavior and microstructure which has a high surface activity and foam stability. Gemini surfactant contains a spacer and thus made the packing of molecules tighter and increased the cohesion of surfactant within the monolayer and enhanced the foam stability. Single molecule film formed by surfactant has certain dynamic characteristics, the gas can easily diffuse through the liquid film, so that the bubble burst. However, particles can be adsorbed in the gas/water interface to form a solid film which will reduce the drainage speed of the bubble to enhance the foam stability.In summary, we proposed to develop a robust foaming agent using anionic-nonionic surfactant mixed with gemini cationic surfactant, stabilized by nanoparticles with certain hydrophilicity and size.
The CLOV Hybrid Riser Towers
Authors: Proust Julien , Lynch Mattias , Seguin Blaise 
Published: April 2015

Abstract
The CLOV development is located offshore Angola in a water depth of 1,300m and includes two Hybrid Riser Towers. The first oil was successfully achieved on June, 12 2014 as initially scheduled at project award in July 2010. This paper provides an overview of the engineering scope through all phases of the Hybrid Riser Towers delivery and how such input was used to determine some key aspects of the execution plan.
The paper starts with a description of the design of the Hybrid Riser Towers developed for the CLOV project. Moving through the various phases of the package (from design engineering to procurement, fabrication and offshore installation), the paper details the associated fabrication and installation methods and focuses on the engineering analyses developed to drive the design and the associated installation methodologies. A number of examples are also highlighted in which the input from the engineering analyses was used to introduce key changes to the fabrication and installation philosophies developed for past similar projects (Girassol and Greater Plutonio).
The example of the Hybrid Riser Towers development on the CLOV project provides a perfect field to investigate the extent of the engineering scope of similar riser packages and how to optimize the benefit from such analyses. The Riser Tower design selected for CLOV project benefits from past experience gained on Girassol and Greater Plutonio Riser Towers (Ref. [1], [2], [5] and [7]) and consequent improvements. Significant updates to the Hybrid Riser Towers design and installation methodologies driven by the analyses from CLOV project are presented with details on the way they helped reduce technical risks and secure the delivery schedule. Based on this experience, recommendations are provided on how to best approach the engineering scope covering all phases of large and technically complex projects with tight schedule constraints.
This paper provides the latest updates on state of the art engineering analyses covering design, fabrication and installation of Hybrid Riser Towers and associated installation methodologies for deepwater developments.
Offshore Development: Unique Technical Solutions for Complex Gas Development Projects
Authors: Al-Tunisi Nabilah , Al-Sharif Safwan , Raja Abid 
Published: April 2015

Abstract
In order to meet the growing domestic and global demand for natural gas and its diversified targets, Saudi Aramco elected to increase production in undeveloped offshore natural gas fields. Since 2008, Saudi Aramco has planned and developed three offshore non-associated gas fields at Arabiyah, Hasbah and Karan.
Saudi Aramco's offshore gas fields are unique. The presence of elemental sulfur, risk of hydrate formation, large slug volume and the reservoir's excessive pressure and temperature are key factors that made Arabiyah-Hasbah fields different from other gas fields around the world. Few gas processing facilities in the world have experienced such extreme parameters, including impurities and corrosiveness, all at the same time.
The distinctive nature of the fields has introduced complex and sensitive systems and new technologies to Saudi Aramco. In order to ensure safe and reliable operation of the fields and the offshore gas processing facilities, all newly introduced technologies and complex systems were mandated to be manufactured, tested and accepted according to Saudi Aramco's specifications and requirements.
This paper will detail the challenges, faced by the project team, involved in the development of the offshore gas fields, specifically Arabiyah and Hasbah, and the solutions implemented to achieve the gas production targets.
Fiber Optic Sensor Based Monitoring System for Blowout Preventer
Authors: Turner Alan , Loustau Philippe 
Published: April 2015

Abstract
Ultra-deep water BOP (Blowout Preventer) operation poses numerous challenges in obtaining accurate knowledge of current system integrity and component condition- a salient example is the difficulty of verifying closure of the pipe and shearing rams during and after well control events. Ascertaining the integrity of these functions is currently based on a manual volume measurement performed with a stop watch. Advances in sensor technology now permit more accurate methods of BOP condition monitoring. Fiber optic sensing technology and particularly fiber optic strain gauges have evolved to a point where we can derive a good representation of what is happening inside a BOP by installing sensors on the outside shell. Function signatures can be baselined to establish thresholds that indicate successful function activation. Based on this knowledge base, signal variation over time can then be utilized to assess degradation of these functions and subsequent failure to function. Monitoring the BOP from the outside has the advantage of gathering data through a system that can be interfaced with risk based integrity management software and/or a smart monitoring system that analyzes BOP control redundancies without the requirement of interfacing with OEM control systems. The paper will present the results of ongoing work on a fully instrumented 13-½" 10,000 psi pipe ram. Instrumentation includes commonly used pressure transducers, accelerometers, flow meters, and optical strain gauges. Correlation will be presented between flow, pressure, acceleration signatures and the fiber optic strain gauge's response as it relates to functional verification and component level degradation trending.
Novel Deliverability Test Method for HPHT Sour Gas Wells
Authors: Wei Pang , Tongyi Zhang , Juan Du , Chunfei Fang 
Published: April 2015

Abstract
Sour gas reservoirs with H2S and/or CO2are widely spread in the whole world, especially in France, Canada, America and China. Most of sour gas reservoirs in China are HPHT tight gas reservoirs which require long testing duration to reach steady state when conducting deliverability test while long testing time leads to huge operation risk because testing tools are used close to critical temperature and pressure condition.
In order to resolve the contradiction among testing duration, operation risk and interpretation results' accuracy, a new deliverability test method is proposed by using pressure buildup transient data. The deliverability calculation model is built by integrating wellbore fluid flow and formation seepage considering fluid flow from formation to wellbore after well shut-in. The formation parameters are interpreted by one pressure buildup transient data, based on which, four daily production rates are designed to simulate the wellbore flow pressure until the well reaches steady state flow, and then the deliverability equation can be derived from the pressure & daily rate points under steady state flow.
Filed case comparison is made between interpretation of actual test data and data from the new method. Results show that the new deliverability test method can get more accurate deliverability equation and AOF by only 1 time pressure buildup and greatly reduces the duration for testing, so it is very practicable because it can greatly decrease the operation risk and increase interpretation accuracy for HPHT sour gas reserviors.
This new deliverability test method has wide application prospect in HPHT sour gas reservoirs and can be extended to other oil/gas reservoirs' application for quick AOF determination, rate allocation, and economic evaluation.
Development of a New Synthetic Hurricane Model for Deriving MetOcean Design Criteria for the Gulf of Mexico
Authors: Mudd L. , Vickery P. , Sarathi P. 
Published: April 2015

Abstract
The objective of this work was to develop a robust methodology for deriving hurricane wind, wave, and storm surge design criteria for offshore structures in the Gulf of Mexico. The hurricane simulation model takes advantage of detailed historical database of Gulf of Mexico hurricanes, which includes detailed information on the characteristics of the wind field model not found in the HURDAT database. Using this new database, new statistical models were developed to describe the temporal changes in the storm size, the pressure–wind relationship and the correlation between storm size and intensity. The model includes features that enable the modeling of storm weakening and expansion of the wind field as a storm approaches the Gulf of Mexico coastline. A 1–dimensional ocean mixing model is coupled with an eddy model to enable the modeling of the interation between the simulated hurricanes and the warm eddies that break off from the loop current. A 100,000 year hurricane simulation was performed, the results of which can be used to form the basis for the development of the wind–wave–surge design criteria.
The synthetic hurricane model reproduces the Gulf of Mexico hurricane climate to a good degree, in terms of the distributions of storm size, intensity, and translation speed observed over the previous 50–100 years. In addition, the model provides more plausible values of rare (1,000 – year to 10,000 – year return period) winds as compared to extrapolations from the limited database of hindcast historical storms. This effort presents a step–change in the way hurricane criteria have traditionally been developed by industry. In moving to an extended hurricane database, derived from a synthetic model founded on the best modern hurricane data available, industry will benefit from more stable design criteria, and better estimates of rare return period site conditons.
Deep Offshore Gas Fields: A New Challenge for the Industry
Authors: Gyllenhammar E. , Boireau C. , Riviere L. , Ulvestad A. 
Published: April 2015

A large number of gas fields have recently been discovered offshore in depths of up to 3000 m, far away from the nearest coast and in countries with little or no oil and gas infrastructure. In addition to the field development strategies including large surface facilities for processing and export to shore, or floating LNG plants, the industry may in the future be seeing more subsea-to-shore developments for these fields.
Total and Aker Solutions have completed a study for a challenging notional gas field development located at 2500m water depth, 300 km from shore, that is to be developed using only subsea technology. The vision is a fully autonomous subsea production system with tie-back to shore.
This paper describes the flow assurance challenges with long-distance subsea tie-backs to shore, from deep offshore fields, and the work done to identify the wide range of subsea processing schemes that may improve the gas transport. Two of these schemes were selected and studied in detail: one consisting of pushing the envelope of multiphase transport to shore with the aid of a subsea compression system, and the other of developing a system for subsea gas dehydration to avoid the use of Mono Ethylene Glycol (MEG) for hydrate inhibition. The main challenges of using these technologies are presented and discussed.