bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Method for Improved Cathodic Protection Monitoring on a Rock Dumped Offshore Pipeline Corridor - A Case History
Authors: Britton J. N. , Vittonato J. , Sulentic I. 
Published: April 2018

Abstract
Objectives/Scope: This paper describes a project to facilitate cost effective and reliable surveillance of cathodic protection performance on two parallel rock dumped pipelines. The lines are located in Total's Edradour Glenlivet field one 12″ production flow line and one 6″ MEG line with a 2″ piggyback service line. The objective was to be able to verify that cathodic protection levels on all the lines met requirements. This method was selected based on shortcomings of other available survey techniques which are also discussed and compared.
The broader implications of changing offshore pipeline survey methodology to reduce cost and improve accuracy are also covered.
Methods, Procedures, Process: The basic approach is to place test stations at intervals along the route of the lines on the edge of the rock dump. These test points are electro-mechanically connected to the pipes prior to the rocks being installed. The ROV installable attachment clamp design is reviewed along with the key points of the installation procedure. The selection of test location spacing will be discussed along with the options for life cycle survey on the system.
Results, Observations, Conclusions: Installation will be discussed along with the initial commissioning results. We will also look at the first verification survey on the system after the rock dump. The simplicity of the pipeline survey and the broader implications for integrity management cost reduction will be reviewed.
Novel/Additive Information: The practice of installing test points on offshore pipelines is quite new but is gaining more momentum as the obvious cost and data value improvements become apparent. The currently used systems will soon evolve into smart systems that will allow autonomous underwater vehicles (AUV's) do the work. The method used on this particular project was the first time that the mattress based test stations have been applied to a newly installed pipeline, the first time under a rock dump and the first time on parallel pipelines.
Combining Floating and Grounded LNG Plant, LNG Storage and Power Units Offshore for Gas Field Developments
Authors: Takata N. , Knox J. , Sharma P. , Winkler D. 
Published: April 2018

Abstract

Objectives/Scope
With recent discoveries of large gas fields offshore around the world, there is a need to bring the gas near shore for liquefaction, storage and transportation to local and international markets especially in regions where security is required. The objective of this paper is a development of low cost overall facilities for monetization of large gas fields.

Methods, Procedures, Process
Current fixed platforms offshore cannot accommodate large plants such as power, LNG storage or liquefaction due to weight limitations. The same applies to floating units. Both structures become cost prohibitive after a certain size. Fixed platforms are also costly to decommission. The design and cost of floating systems are also limited by extreme environmental conditions at the operating site mainly because of the limitations of their turret/anchor/offloading systems. Floating systems also provide limited protection to LNG carriers at the time of loading. The combination of grounded and floating facilities is expected to solve the above limitations.

Results, Observations, Conclusions
This paper focuses on a new floating and grounded LNG offshore gas field liquefaction, storage and power concept that provides the following advantages. The concept: Is easily expandable to accommodate a growing productionIncorporates floating units that are capable to be grounded on a Steel Base for ease of installation and decommissioningIncorporates grounded units that can be installed head to toe for protection against extreme environmental conditions during loading to the LNG carrier and for the other floating units (such as FLNG or FSO)Provides the flexibility to add a power unit that will not only provide ample supply of electricity to the gas facilities but also the capability to sell the extra electrical capacity to local markets where electricity is a premiumProvides extra security to the facilities, export systems and staff by being near shore rather than onshoreIncorporates top units such as LNG storage, power plant and LNG liquefaction plant barges that can be separated from their respective Steel Base and function again as floating unitsIncludes units (top and base) that can be re-used at other sitesProvides the optimum operating scenario at the most effective cost

Novel/Additive Information
This paper presents examples of different floating and grounded units near shore gas facilities demonstrating the advantages of this concept around the world. The combination of grounded and floating units provides a novel solution.
Cyber Security - Understanding Your Threat Landscape
Authors: Jorgensen John M. , McSweeney Kevin P. 
Published: April 2018

Automation provides many new and improved abilities for ships and offshore assets. Automation is more than the mere replacement of the functions of older (less optimal) systems; it requires system interoperability and integration. Interconnectivity of multiple systems adds new risk factors to the system as a whole. Two key risk factors are cyber security and system complexity.
At a high-level, cybersecurity means understanding your systems and processes, your personnel's capabilities and limitations, as well as thoroughly evaluating your threat landscape. In other words, system owners must have a keen understanding that there will always be new threats to counter, and new technologies to harness.
With improvements in cyber security systems, employees are now the preeminent target, thus making them a substantial vulnerability. Through negligence (human error) and malicious acts — including being the victim of phishing/whaling attacks, lost laptops, accidental disclosure of information, and actions of rogue employees account for up to two-thirds of all cyber-related breaches. Industry must be cognizant that added complexity (e.g., system design/arrangement, rules, policies, procedures, etc.,) can decrease an individual's situational awareness and increase the likelihood of human error.
A key to effective systems-risk assessment and complexity management lay in understanding cyber safety system designs, and how people interact with those systems. This paper will discuss methods to engineer systems, control system complexity, and how to help mitigate human error, with the goal of creating an efficient and effective cyber security environment.
Modeling Hydrate Formation Management with Anti-Agglomerant Injection in a Subsea Tieback
Authors: Wang Yan , Koh Carolyn A. , Zerpa Luis E. 
Published: April 2018

Abstract
Gas hydrates forming in deep water subsea tiebacks can stop production of offshore wells by blocking the pipeline. This is considered one of the most challenging problems in flow assurance. In this work, we present a transient hydrate simulation tool with the ability of predicting hydrate formation in oil-dominated systems and the purpose of capturing the complicated multiphase flow scenarios that occur in oil and gas flowlines. This modeling tool can be applied to estimate hydrate formation in flowlines with different water cuts, which is especially useful in modeling transient shut-in/restart operations. A field case is used as a benchmark to verify the prediction performance of the proposed hydrate simulation model. The geometry, fluid properties and production data from an offshore well is reproduced using the hydrate formation model, quantifying hydrate formation and estimating plugging risk at different liquid holdup, water cuts and produced gas-oil ratios. Hydrate anti-agglomerant chemicals were used in this field case, and are considered in the simulations of steady state and shut-in restart operations. The proposed transient hydrate prediction model successfully predicted the formation of hydrate plugs as observed in the real field. This hydrate formation simulation tool can be applied for the design and optimization of prevention, management and remediation procedures of hydrates in flowlines.
Field Operational Results of Precision Slot Cutting Using Novel Electromechanical Slot-Cutting Technology
Authors: Fanini Otto N. , Garcia Alejandro , Ransonet Gerald 
Published: April 2018

AbstractThe downturn in the market has affected the majority of oil and gas producers and made their ability to maximize the production of current wells a crucial goal. Completion installations are becoming increasingly complex with many incorporating sliding sleeves to gain access to multiple zones in the wellbore. These completions are often concentric in design and engineered with packers, outer gravel pack screens, and an inner tubing string to isolate zones. The production rate often decreases before its expectancy due to fines migration, asphaltine and scale. These factors are coupled with the inability to acidize and stimulate behind the inner tubular through the sliding sleeve or without damaging the integrity of the gravel pack screens. Advances in electromechanical slot-cutting technology address the need to cut multiple slots in a single trip. As a result, costly field production can be quickly restored to meet daily production flow targets, considerably minimizing downtime, risk, collateral intervention damage and overall intervention complexity and cost.Reliable, precise slot cutting of the tubing is imperative for maintaining the screen integrity. The use of shaped charges to penetrate the inner tubing without damaging the outer screen has proven to be an un-reliable solution due to a varied depth of penetration. Field results demonstrate the ability of electromechanical slot-cutting technology to produce surface-monitored slots per design that are precisely controlled for penetration and maximum flow area. Slot locations and dimensions are designed to optimize overall flow rate while preserving the durability of the cutting elements and the supporting hardware assembly. As a result, multiple slots can be made in a variety of difficult operating conditions, pipe materials and environments without damaging adjacent completion components, and with minimal debris.The ability of electromechanical slot-cutting technology to pass through inner-diameter restrictions and complete slot cuts for zonal stimulation further improves the capital efficiency and investment return to the operator. Logistical and environmental constraints are also greatly reduced by providing precise slot cuts without the use of hydraulic jet systems, ballistics or hazardous chemicals that pose safety and environmental hazards.This paper shows the novel electromechanical technology's ability to perform slot cuts in a variety of conditions and environments. The paper includes a deepwater case history to illustrate the advanced operating capabilities and to show how operators can incorporate this advanced technology into the engineering of future completions.
The Control Room is Anywhere and Everywhere: Putting the Industrial Internet of Things to Work Offshore and Beyond
Authors: Zornio Peter 
Published: April 2018

Abstract
The oil and gas industry has long faced obstacles surrounding 4-D characteristics that make staffing offshore and other remote locations a challenge: dangerous, dirty, distant and dull. And the industry is producing more real-time data—about asset health, operations, production—than ever before. Companies are discovering a powerful one-two punch to effectively manage these challenges: Industrial Internet of Things (IoT) solutions to manage and monitor operations, and remote integrated operations centers to consolidate expertise, increasingly including support from third parties.
With this combination, data and analysis now accessible anywhere in the world, not just on site, and not just accessible to company personnel. This tech combo makes it possible for companies to anticipate and address issues remotely, before they become problems. The industry has at its fingertips priceless information that can help it achieve top quartile performance.
Methods, Procedures, Process: Companies are leveraging the Industrial IoT to connect the right people, with the right data, to prescribe the right improvement actions, anywhere in the world. This approach is being successfully implemented from small projects to one of the world's largest offshore processing vessels operating from an integrated operations center 2,000 kilometers away. To achieve this takes more than data; without the correct software or personnel with domain expertise to identify trends and prevent issues, these assets are producing an endless stream of numbers that provide little business value. This is too often the case: A recent IndustryWeek survey found that while 60 percent of manufacturers are testing Industrial IoT, fewer than 1 in 20 are investing with a clear business case.
Through remote monitoring software and analytics, coupled with either in-house or external experts, the unending stream of numbers become actionable instructions that can be accessed and acted upon from anywhere in the world. Once data is generated, experts can analyze and make adjustments to prevent unplanned downtime, improve asset health and enhance safety. And because remote monitoring solutions are customized, companies can turn to scalable options to pilot the technology.
Results, Observations, Conclusion: Remote monitoring technologies can have a significant impact on operations, and it doesn't take long to see the impact. Companies see a return on investment on either internal remote monitoring deployments, or use of external experts quickly.
In addition, remote monitoring can significantly reduce unscheduled downtime—a scourge for companies already running at capacity. In today's world, best in class facilities operate at upwards of 97 percent availability, and any shutdown can translate into millions of dollars lost in downtime.
Novel / Additive Information: In this presentation, attendees will hear about proven Industrial IoT strategies and how the oil and gas industry has leveraged them to their advantage.
Development of Next Level Drilling Simulator Using Multiple User Interaction Concepts
Authors: Srivastava Saket , Ichim Adonis , Teodoriu Catalin 
Published: April 2018

Abstract
The process of making drill pipe connections is not only crucial in drill string integrity but also in assessing rigfloor safety. Almost 15% of recorded incidents in US onshore rigs occur due to improper make-up/tripping process as reported by IADC in 2015. Even with advances in pipe handling systems, human factors greatly influence the likelihood of errors which can lead to accidents. Training on simulators is a proven solution for innovation. The crew can better understand the rig equipment and prepare for potential risks. While drilling simulators exist for all aspects of drilling operations, a simulator for making drill pipe connections through human factor assessment is critically needed. This paper presents three unique approaches in building and using this much needed tool.
One approach works like a visual interactive interface where the user can click and drag the rig components over to the rig floor and make a connection in a step-by-step manner. This enables a thorough understanding of the process and highlights errors if tasks are not performed sequentially. Another approach looks at the driller's screen where the user can control all the rig floor operations. This is a more realistic approach for a user who is well versed in the make-up process. The system works in real time and features a risk-meter that evaluates the process safety. The third approach is an automated interface for making connections. Before initiating the process, the user can choose among the different pipe handling systems, dope to be applied and rig crew assignments for the job. Different rig crews have combinations of experience, operational awareness and physical strength as attributes. The process begins with an animation of the make up process alongside a log of the process and description. Riskmeter and the option to pause-start are also features of this interface.
These novel drilling simulators can play a crucial role in understanding and assessing the make up process on a rig floor. The simulators developed can be used for training new, and more experienced crews. The crew can be trained on the correct operational procedures, and create a profile evaluating the competency of the user. Since it features a safety meter that rates the ongoing process based on the handling system and crew selected, a comparative study was done and WAR (Weighted Assessment of Risk) was defined. The rig crew competency was analysed using these parameters. The tool could also be used for rig crew profiling and job assignments to improve safety and efficiency of tripping operations.
Local Heating of Subsea Flowlines, A Way to Increase Step Out Distance with Conventional Thermal Insulation
Authors: Anres S. J. , Hallot R. , Macauley L. , Valdenaire T. 
Published: April 2018

Abstract
Innovative flow assurance solutions are required to make new field developments both technically and economically feasible. Indeed in the case of long distance tie-backs, very deepwater applications or when the fluid temperature at the wellhead is too low, conventional flow assurance solutions might not be applicable. In this case, heating the flowlines is a way to overcome the thermal constraints, mitigate hydrate and wax risks and provide operational flexibility.
Existing heating solutions are based on distributed heating technologies (DEH and Heat tracing) and are mainly considered for hydrate management under transient operations (start-up, shutdown, preservation). Local heating is a different solution, intending to be used continuously during production. Local heating allows for the integration of the system into a compact subsea station, installed in parallel of the main flowline, which can be retrieved for maintenance or relocated to another location. The technology can be implemented either on new fields or for the extension of existing lines.
The purpose of this paper is to present an overview of the local heating technology under qualification by Saipem. The heat is provided using induction. This solution is thus able to provide a very high power density leading to a very compact solution. The internal diameter of the line in the heating station remains unchanged from the main production line, which makes the solution fully compatible with preservation by flushing and allows to pig the system in case of deposits. The temperature is monitored throughout the heating module by means of a network of optical fibers.
The paper will introduce the main features of the technology, the main scenarios for which this solution is particularly suitable as well as the impact on the field operations. Information will be based on the results of flow assurance studies performed for various types of oils and field configurations. Some preliminary designs of the subsea station will be given, going up to 3MW of thermal power delivered to the fluid.
Finally the paper will present the qualification testing recently conducted on a reduced scale prototype, with a description of the prototype and the main results obtained.
Novel Adsorption-Based Gas Treating Technology Platform for Upstream Gas Separations
Authors: Barnes William , Chen Chien-Chiang , Fowler Tracy , McMahon Patrick , Nagavarapu Ananda Krishna , Shatto Donald 
Published: April 2018

The oil and gas industry has become increasingly focused on cost reducing technologies. Processing and treating systems used to monetize resources can often be heavy and require a large footprint. When operating in challenging locations, such as deep water or the arctic, these systems can be very expensive. To address these challenges, a novel adsorption-based gas separation technology platform has been under development for process intensification. This technology uses rapid pressure- and/or temperature-swing cycles to dramatically reduce equipment size and weight, and overall gas treating footprint by ~50%, relative to conventional technologies. In addition to CAPEX savings, the weight and footprint savings are beneficial in locations where space is at a premium. Furthermore, the technology is well suited for skid-based deployment, which provides execution efficiencies.
While the technology platform is broadly applicable for a variety of Upstream gas separations, the current focus of development has been on deep dehydration and CO2 removal before cryogenic gas processes, such as LNG or NGL recovery. Extensive fundamental research, including laboratory and pilot testing, has been completed to demonstrate technical feasibility. Construction of a field research and demonstration facility is underway to demonstrate scaled-up operation over a wide range of operating conditions. This paper will provide background on the technology platform, the key enablers, the scale-up approach, and integration in an LNG process.
A Novel Survey of Bulk Gel Treatment Designs in Injection Wells-Part I: Gel Strength
Authors: Aldhaheri Munqith , Wei Mingzhen , Zhang Na , Bai Baojun 
Published: April 2018

Polymer bulk gels are increasingly applied to alleviate the costly burden of excessive water production in mature oil fields. This paper presents a comprehensive review of the designs of injection well gel treatments conducted between 1985 and 2014. The survey includes 61 field projects compiled from SPE papers and U.S. DOE reports. Seven design parameters related to the gel strength were evaluated per the reservoir type and the recovery process using the univariate descriptive analysis and stacked histograms.
We identified that there is a great concern about losing the informative content of the three levelsdata of gel treatment designs unless a specialized data reporting approach is used to obtain sufficiently representative and discriminating field-wide estimations. The traditional practice to plan a gel treatment is to adopt the designs from gel case histories in similar formations or empirically estimated the designs by reservoir engineers. The gel strength parameters are appreciably affected by the formation type and reservoir types can be ordered in term of increasing polymer concentration as matrix-rock, unconsolidated, and naturally-fractured. Gel treatments typically start with polymer concentration of 3000 ppm, end with 7600 ppm, and a constant polymer-crosslinker ratio of 40:1 is maintained during the treatments. Often, gel treatments are applied using polymers of 10-11 MM Dalton molecular weights that are injected in three to five treatment stages.
The gel strength is designed based on the problem channeling strength and the required gel volume. However, in the cases of void-space problems, gel extrusion, gel breakthrough, and gel breakdown become important designing criteria. To address these issues, more advanced tapering schemes than the normal gradual increase of polymer concentrations are used to optimize the gel plugging efficiency. In addition, small volumes of cement or low molecular weight, fast-maturing, rigid gels are injected in front (only gels) or behind the MARCITSM gels as capping materials. The unsuccessful gel pilots had significantly higher polymer concentrations than the successful gel projects applied in the same formation type. Increasing trends were identified of polymer concentrations against the treatment timing indicators. The present review prominently maintains the variability of the design data and provides conformance engineers with the typical treatment designs for different application environments.