bluuebunny/crossref_metadata_2025_split huggingface dataset:
Compact Electrostatic Treaters for Floating Offshore Production Facilities
Authors: Sams Gary , Sellman Erik L , Mandewalkar S Pavan Kumar 
Published: June 2014

Abstract
Floating production facilities are very sensitive to equipment weight and footprint. New electrostatic technologies have enhanced the dehydration and desalting process for crude oils by improving treater hydraulics and increasing the electrostatic field strength of the treaters.
Efficient vessel hydraulics is essential for achieving maximum dehydration performance and efficient utilization of the treater vessel volume. Not only is the oil distribution critical but oil collection is equally important to maintaining treater dehydration and desalting performance. A new distributor can increase the treater utilization from low 50% to 95% allowing for the use of smaller and light weigt treaters for crude oil dehydration and desalting.
The crude oil dehydration and desalting performance also decreases as the crude oil conductivity increases, whether this is caused by an increase of heavy solids, asphaltenes or polar organic components, the electrostatic field strength can be reduced significantly. One method for maintaining the electrostatic field strength is to utilize high frequency electrostatic field to quickly replenish the effective voltage and reduce its decay. Modulating the voltage amplitude has also proven to be effective for increased dehydration performance.
Another treater improvement is the use of composite electrodes, which increases the water tolerance of the treater and also improves the treater dehydration performance.
This paper describes compact (light weight and reduced foot print) electrostatic treaters and how these technologies can provide lower CAPEX as well as lower OPEX for offshore crude oil treating facilities. The role of vessel hydraulics, electrode materials and electrostatic field strength to maintaining efficient dehydration and desalting performance will also be discussed.

Introduction
Floating production platforms are used for production facilities installed in deep waters. The Cameron Dual Polarity® and Dual Frequency® technologies have been around for more than one decade and have rapidly developed a solid installed base for crude oil dehydration and desalting on floating production facilities such as FPSOs, SPARs, semi submersibles and other floating production facilities. The higher electrostatic field strength of the Dual Polarity and Dual Frequency type electrostatic treaters allows the use of smaller treaters which provides both weight and space savings. The ElectroDynamic Desalters® also provide an opportunity for use of a single desalter in lieu of two stage desalter arrangement. The Dual Frequency technology combines higher electrostatic field strength with a higher coalescing power and thus allow for the use of drastically smaller treaters.
Smart Reamer Calliper - Real Time Wellbore Diameter and Underreaming Verification
Authors: Alcure Marcos , Placido Joao Carlos Ribeiro , Rasheed Wajid , Lage Antonio Carlos V.M. 
Published: June 2014

Abstract
This paper outlines the R&D methodology of an innovative Smart Reamer Calliper for measurement while drilling. The concept was progressed from design to prototype with long hours downhole drilling qualification completed in 3 years. Existing calliper measurement technology is limited for numerous reasons not least BHA placement and erroneous readings due to changes in fluid density. The prototype tool overcame these limitations by building on-board proper calibration and multiple sensors that allow 360 degree mapping of the wellbore shape. Further optional Measurement While Drilling (MWD), magnetic, vibration and underreamer position sensors can be added.
A R&D project was established with incremental tests identifying root-cause failures/design issues before moving to the next stage. This iterative process ensured proper prototype manufacturing and minimised risk at critical test points. At the same time parallel activities enabled the project to reduce overall time associated with common project tasks. The whole R&D consisted of 4 stages: design and FEA, small scale testing, full scale testing and long hours field test drilling.
The prototype tool was first tested in sliding, rotating and underreaming BHAs for actually drilling a total of 900 m in chalk, clay and sands. Small scale lab tests including high pressure and temperature at 13,053 psi and 150°C for 100 hours were conducted in England. Full scale under-reaming testing occurred in Norway with a wireline calliper for cross-check of the wellbore diameter measurement, and finally another qualification test in England comprising 59 hours on bottom drilling. Lastly, MWD integration was performed using standard MWD pulsers. The new Smart Calliper tool is being developed to accurately measure and provide both memory and real-time data of the 3-D wellbore allowing the drilling team at rig-site to:Pinpoint narrow or under-gauge wellbore sections, verifying underreamer performance and measuring wellbore diameter above the reamer allowing for corrective reaming trip to be performed while drilling BHA is still in hole.Offer better cement volume estimate to minimise excess.Eliminate wireline calliper deployment.Eliminate a wiper trip typically carried out prior to running long casing string.Offer monitoring of downhole tool vibration and separate directional survey if required.
Advanced Forging Process (AFPTM), Super Duplex Stainless Steel for Increased Low Temperature Impact Toughness and Resistance to Hydrogen Induced Stress Corrosion Cracking (HISCC) Due to Cathodic Protection of API Forgings for Subsea Applications
Authors: Francis R , Byrne Dr. Glenn , Warburton Geoff , Schulz Zach John 
Published: June 2014

Abstract
As oil wells become deeper and run at higher temperatures and pressures, there becomes a need for high strength, corrosion resistant material that will withstand the more severe service conditions of these projects. Over the years many projects in various locations around the world have successfully used duplex and super duplex stainless steels for subsea pipe lines, flow loops, flow lines and manifolds to contain the high temperatures and pressures and more demanding corrosive service required with the High Temperature High Pressure (HTHP) wells.
Additionally, operators have realized that they need to qualify the manufacturers of these materials following a number of problems experienced in the field. They see that the more severe conditions require a higher level of quality and security to go with the more demanding performance required. As such, the NORSOK M650 specification is seen as way to qualify the manufacturer and ensure a higher level of quality in the product. This has not solved all problems and a few operators are placing even greater demands on manufacturers to ensure they have the required metallurgical understanding and production facilities to produce parts in these more complicated alloys.
There is also a recent development for super duplex stainless steels to meet service conditions beyond usual requirements. A number of operators have projects where minimum design temperatures are calculated to be as low as −70°C, which is near the lower shelf toughness level for duplex stainless steels. This paper discusses the properties that can be achieved by optimizing the forging route and therefore minimizing nitride precipitation in these alloys. The resultant properties are sufficient to meet the impact properties typically required at temperatures down to −70°C. In addition, the improved ductility and toughness also increase the resistance to HISCC due to cathodic protection. Several end users and OEM's have already used ZERON® 100 AFPTM to benefit from the improved toughness at design temperatures as low as −70°C.
This paper will cover the metallurgy of duplex alloys and how improved understanding and processing can lead to less nitride precipitation, better morphology and austenite spacing that will have a beneficial effect on both toughness and HISCC resistance. The improved toughness values can also be seen across the full temperature range of most Oil & Gas projects with excellent properties at −50°C as well as at −70°C. Discussion of a few case histories also confirms the need for application of this Advanced Forging Process (AFP) of super duplex stainless steel.
Original View on Brazilian Local Content Regulatory Enviroment
Authors: Souza Robson 
Published: June 2014

Abstract
Since Law No. 9.478/97 was enacted, the ANP (National Agency of Petroleum, Natural Gas and Biofuels) has been looking forward to enhance local content for the areas offered in its rounds.
After several tender processes, local content requirements had become decisive for the concession contract winners. Consequently, all the concessionaire supply chain had to evidence the local content of its products and services in accordance to the existing rules. As result, the local content that could be achieved by each E&P (Exploration & Production) supplier becomes a great competitive differential in Brazilian oil market. In this context, foreign companies interested in taking advantage of the growing opportunities in the E&P segment in Brazil, started to look for alternatives and structures capable of adding local content to their products and services.
The concession contracts for offshore blocks have the highest local content commitments during the development phase. This is because there are huge investments in goods and services acquirement, particularly in the acquisition of a production unit like FPSOs (Floating production, storage and offloading) which are particularly efficient due to its mobility in different areas.
The construction and installation for a FPSO, for instance, generates significant demand for such goods and services that may impact the entire local supply chain. The lack of availability these acquisitions in the Brazilian market may adversely affect the attractiveness of projects. Thus, we highlight the importance of a more appropriate method that considers both the profit margin as local content committed by the concessionaires with ANP.
Considering the relevance of the scenario presented above, this paper aims to suggest a method that supports the decision-making that complies with the required local content index and the operator preference. The original view on Brazilian regulatory environment, contributes to improve local content strategy in petroleum industry. The work is developed briefly presenting: method of decision support; oil industry in Brazil; regulatory market and local content policies.
Application of Mesophase Technology for Reservoir Damage Remediation and Improve Hydrocarbon Producibility - A Successful Case History from Kuwait Field
Authors: Veluri Vijay Saradhi , Al-Ajmi abdullah , Al Barazi Naser K , Rasheed Al Enezi Dakhil , Sharma Sidhartha Shankar , Takate Yogesh , Clark David , Al-Mutairi Moute'a , Al-Ajmi Hadi Saad , Al-Rushoud Abdulazziz Saud , Suryavanshi Vijay , Yadav Prahlad , Jadhav Prakash Balkrishna , Sotomayor Ghery , Khan Yousuf , Al-ajmi Khaled , Al-Khaledi Ali , Awad Mohamed Omar 
Published: June 2014

Abstract
An operators renewed focus on horizontal well drilling and open hole completions, using Inflow Control Device (ICD) screens, necessitated the use of oil-based drill-in fluids (DIF) to drill and complete their reservoir. The challenges were increased by low reservoir pressure conditions, increasing the risk of drilling fluid invasion and possible reservoir damage. Comprehensive laboratory studies were carried out to evaluate DIF performance and ensure understanding of the possible damage mechanisms produced while drilling, considering the reservoir characteristics and drilling conditions.
The customized near-wellbore damage remediation system, with a delay-reaction, was designed based on Mesophase technology. This paper discusses detailed laboratory analysis for the clean-up system and its field applications in Kuwait horizontal wells. The applications included drilling carbonate and sandstone reservoirs, open hole ICD completion, and performing effective cleanup required for maximum production.
The effectiveness of the Mesophase clean-up system to remediate reservoir damage and improve producibility was evaluated immediately after well kick off and again after steady production levels were reached. This paper shows the results obtained after the application of the near-wellbore remediation technology.
The lessons learnt during the Mesophase application were incorporated on upcoming wells to standardize the operating procedures and improve field performance.

Background
To meet production targets from Raudhatain field, the operator initiated a horizontal well drilling campaign with open hole ICD completions in Mauddud (Carbonate) and Burgan (Sandstone) reservoirs. The ICD screens control flow rates across the completion for the entire length of the interval. This approach dramatically reduces the effect of water and gas breakthrough, while optimizing production rates across the full completion interval.
Challenges encountered during drilling these horizontal wells included increased non-productive time resulting from interbedded formations with varying formation pressures, wellbore instability in the reactive and stressed shale sections and hole cleaning issues. An oil-based drill-In fluid system was designed with a high oil water ratio (OWR) to overcome these challenges and protect the reservoir from drilling fluid damage.
The formation damage mechanisms analyzed included:Foreign particle invasionFormation clay swellingChemical incompatibilityOil wetting of the reservoir rockEmulsion blockingFluid invasion (Water Blocking)
Development of a Novel Kinetic Hydrate Inhibitor and Corrosion Inhibitor Package for Wet Gas Application
Authors: Jones Regan , Morales Noah , Anthony Jacob , Webber Peter Andrew , Harrington Ryan 
Published: June 2014

Abstract
A dual functional kinetic hydrate inhibitor (KHI) and compatible corrosion inhibitor (CI) package was developed to simplify production chemistry demands for operation in wet gas mode. As these two classes of chemistries are both water soluble and contain surface active components, they have a tendency for interference reducing the efficacy of each inhibitor. Their pairing in a production scenario requires both comprehensive performance testing as well as extensive secondary properties evaluation.
The KHI is to serve as a traditional KHI during steady-state operations while performing as a thermodynamic hydrate inhibitor (THI) during extended shut-ins and cold well restarts. This challenge required the development of a KHI which would retain performance upon significant dilution in a thermodynamic hydrate inhibitor solvent carrier (methanol, ethanol, monoethylene glycol, etc). Performance of this new KHI would be confirmed in blind rocking cell experiments, in the presence of the matched corrosion inhibitor, targeting a hold time of more than eight days at a subcooling of 8 ºC.
The CI is targeted to reduce the general corrosion rate to less than 0.1 mmpy and prevent localized attack. Due to the surfactancy of this class of chemistry, the tendency to induce and stabilize emulsions is of high concern. A robust formulation amenable to modification and potential dilution is required to address the application of chemical over a vast subsea network containing wells of varying age, existing infrastructure, production profiles, and operating conditions.
This paper describes the development, qualification process, related lessons learned, and field applications of this new KHI/CI package.

Introduction
The oil and gas industry often relies on chemical solutions to address challenges related to flow assurance and corrosion inhibition. The transport of produced fluids containing water and acid gases such as carbon dioxide and/or hydrogen sulfide in metal pipelines afford conditions susceptible both to gas hydrate formation and corrosion. Accordingly, production chemical strategies typically must consider a compatible corrosion inhibitor and low dosage hydrate inhibitor as a unified package.
Standard chemical compatibility often includes the mixing of two neat production chemicals with exposure at various temperatures to examine for hazing, phase separation, precipitation, etc. This exercise provides operators insight in the event that chemicals are accidently mixed in storage tanks or may come into contact in delivery lines. Though, the performance compatibility of a KHI and a CI presents a more challenging case.
Subsea Geo-Hazard Risk Assessment and Pipeline Integrity Management - A GIS-Based Data Integration Approach
Authors: Li Ming , McQueen Mark , Bik Marc , Zhai Dong 
Published: June 2014

Abstract
Geo-Hazard assessment is a critical part of threat identification, risk assessment, fitness for services assessment, and overall subsea asset integrity management. Successfully addressing the data management challenges will yield huge benefit to future achievement in quantitatively evaluating and managing geotechnical hazards. In addition, further data visualization and integration analysis is playing an increasingly important role in decision making of pipeline integrity management in today's subsea industry.
This paper proposes a GIS-based data integration approach to managing, analyzing, and visualizing the geo-hazard data, which will help facilitate the early asset integrity management planning.
A case study was presented.

Introduction
For subsea systems, Integrity Management (IM) should provide a solution throughout the whole life cycle of the key associated assets. From project execution perspective, this means the solution should be implemented throughout multi-phase stages which typically involve Pre-FEED, FEED, Design, Construction, Commissioning, Operations, and Decommissioning. This life-cycle driven concept adds a new perspective to the traditional operation-stage focused IM services. Following this philosophy, an effective Integrity Management Plan (IMP) needs to capture multi-phase project data and incorporate the subsequent risk and integrity assessment analysis throughout the life cycle of subsea assets. As a result, the life-cycle based IM approach, particularly through early stage implementation, can help verify key design and response uncertainties early in field life and demonstrate continued fitness for purpose throughout the life of field. However, despite major benefits, this new approach also poses some key challenges summarized as follow:

1) Data Management:
Life-cycle based IMP needs to include a compressive data management system component to effectively manage vast quantity and range of data acquired at multiple phases throughout project execution. Typical information that needs managing and analyzing includes:Historical process and production data, such as pressure, temperature, flow rate, pH, composition, etc.;Erosion and corrosion probe data, corrosion management strategies, etc.;Chemical injection data;
Integrated Modeling for 3D Geomechanics and Coupled Simulation of Fractured Carbonate Reservoir
Authors: Correa Antonio Claudio Franca , Newman Robert Bourne , Naveira Vanessa Palma , de Souza Antonio Luiz Serra , Araujo Tales , da Silva Alexandre Augusto Cardoso , Soares Antonio Claudio , Herwanger Jorg Volker , Meurer Gustavo Bechara 
Published: June 2014

Abstract
Geomechanical models have multiple uses in reservoir management and field development planning. In this case study from a producing deepwater fractured carbonate reservoir (water depth approx. 1500m) we use the same geomechanical model to understand (i) why hydraulic stimulation failed to open a hydraulic fracture due to high minimum principal stress, (ii) what the limits of mud weights for drilling horizontal wells into the pressure depleted reservoir are, and (iii) investigate what the effect of pressure depletion and associated stress changes are on fault permeability, thereby providing an explanation for an observed early water-breakthrough. Multiple data sources, including structural seismic interpretation and Amplitude-versus-Offset (AVO) inversion, well-log measurements and rock-mechanics laboratory tests were combined in building a mechanical property model, and the computed stress state was calibrated with wellbore observations of breakouts directions, induced fractures and leak-off tests.

Introduction
Reservoir geomechanics has become an accepted technology for the petroleum industry during last decades. There are many benefits on improving geomechanical understanding, including:A better characterization of reservoir volume deformation and impact on rock permeability (compaction and dilation);Prediction of surface subsidence;Reducing of risks of fault reactivation and out-of-zone hydraulic fracture propagation during waterflooding or other improved oil recovery process.
In Petrobras, Reservoir Geomechanics is a fundamental tool for development of fields with large number of faults/fractures, which is the case of several offshore sandstone reservoirs in Campos Basin, as well as some carbonates fields. Here we discuss the development of a comprehensive reservoir geomechanics study in an actual field of the Campos Basin. The presented technology has been developed as part of the Technology Cooperation Agreement on Reservoir Geomechanics between Petrobras and Schlumberger. A similar study has been carried out for a sandstone field and presented at a SPE Conference (Souza et al, 2012).
Case Study: Utilizing of Inflow Control Device To Control Oil Wells from Water Production and Regulate Waterfront Encroachment
Authors: Bajunaid Hani Ahmed , Moawad Taha Mousrafa , Al-dhafeeri Abdullah M , Abd Elfattah Mahmoud Mohamed , Mohammed Tawakol I. 
Published: June 2014

Abstract
Khafji offshore field, located in the Arabian Gulf, contains an unconsolidated sand reservoir subdivided into two, upper and lower reservoirs. Upper sandstone reservoir has relatively low reservoir pressure utilizing gas lift to help wells achieve production target rate. The main obstacle in upper reservoir is water encroachment due to unfavorably high-water mobility compared to oil; which presents a reservoir management challenge in the form of curbing water production linked to relatively high-permeability sandstone reservoir. In upper reservoir, water encroachment is dominated by active edge-water drive and it has irregular water-front movement because of the presence of high permeability streaks.
Excessive water production from the high permeability upper sandstone reservoirs causes major economic, operational, and environmental problems during oilfield operations. Water production can also cause secondary problems such as sand production, corrosion, emulsion, and scale formation. Although the reservoir has been on production more than 50 years, water sources are still considered to be a mystery. Many different concepts and scenarios have been considered such as channeling behind the casing, highly conductive faults, channeling through the high-permeability zones and high-permeability streaks, which accelerated water production. As a result of this issue, water breakthrough at crested wells in an edge-water driven upper reservoir and water production has increased.
Inflow Control Devices (ICD) completion has been installed in upper reservoir wells to overcome water production challenges. Low reservoir pressure is a major challenge for upper reservoir wells ICD completion design. During the course of this paper, Khafji field water encroachment study results have been discussed to show the latest water front movement expected scenario. In addition, ICD-completed wells performance was analyzed and compared to cemented perforated liner completion wells (Non-ICD completion) offset wells in upper reservoir. The parameters that were used during the ICD-completion design to overcome the main field challenges were highlighted. ICD completed wells showed positive performance results in water production control and higher oil production rate.