bluuebunny/crossref_metadata_2025_split huggingface dataset:
High Performance DEH-PiP: Qualification Status
Authors: Lozinguez William , Roland Paul , Hallot Raymond , Anres Stéphane , D'Huart Pierre Emmanuel 
Published: April 2022

AbstractThis paper presents Saipem's qualification activities on its High-Performance version of DEH PiP technology. A reminder of the technology is given as well as an insight into the modifications and improvements performed. Qualification status of the sub-systems specific to the technology is also detailed.DEH PiP technology has now been around since its development and installation by Shell in the early 2000's. Saipem considers that this technology, provided some improvements, is a very competitive option for subsea flowline heating. As a result, qualification activities on an enhanced version of the DEH PiP were started in 2019 to verify and provide evidence that the system will properly perform the function it is designed for, while bringing risks to a minimum level. Several studies and tests have been performed with this intention and are in part presented in this paper.An overview of the technology qualification process is given and is followed by a description of the qualification activities performed on the various sub-systems of the technology. From an electrical point of view for instance, studies and tests were performed for the qualification of an electrical insulation layer, of the global system electrical modelling, and of the system upgrade for performance enhancement. Other qualification activities, like mechanical tests on the "shear stops", are also part of the qualification to validate new conceptual designs and are presented. The activities already performed in the qualification program allowed to improve the technology readiness level of the system and increase confidence in its potential. The next steps and the associated targets for development are also presented.This paper presents Saipem's qualification activities on its High Performance DEH PiP for the first time and hence gives an interesting overview of this technology and its qualification status.
Angola Block 17 – In-Depth Assessment for a 10 Year-Long Extension of Ageing FPSOs
Authors: Gayon Pierre-Henri , Schmitt Florent , Maimaran David 
Published: April 2022

Abstract
The paper presents the technical study performed for the 10 years Life Extension of Girassol FPSO, Block 17 Angola. A specific methodology has been developed, splitting the asset into packages and performing a comprehensive assessment based on equipment condition and obsolescence aspects.
Starting from the scope definition, development of obsolescence plan, execution of the sites surveys up to the consolidation of the work program for the upcoming years, the paper explores how the study has been executed, in close coordination with the affiliate operational entities, engineering companies and vendors.
It explains how a fit for purpose approach has been promoted to optimize the amount of work and expenditures with a constant focus on safety & production critical items. Some examples are detailed like the selection of refurbishment approach versus newbuilt equipment, as well as the definition of partial upgrades and the use of existing warehouse stock when possible.
The paper addresses the various digital tools which were implemented during the technical evaluation and the project scope of work consolidation. An innovative database was created to record the technical scope for easier handover to project phase and smooth execution monitoring. It covers as well the use of an innovative technique to be able to inspect the inside of the FPSO tanks within the short study schedule.
A New Approach to Assuring Well Integrity and Performance
Authors: Cully Richard , Franklin C. Mark , Lewis Kimberly , Mesa Carlos 
Published: April 2022

Abstract
Well barrier integrity testing is key to protecting people, environment, and a company's reputation and bottom line. However, critical well integrity testing is impacted by criteria and analysis selection in a way not typically considered which introduces significant risk to well integrity assurance.
Accepting testing of key components used to validate well integrity must be consistent for all components in a test system. A simple example is testing a BOP system to a criteria that is less stringent than a test conducted on a packer, where components of the BOP are part of the overall pressure containment system. More concerning is using varying test methodologies or methodologies lacking specific criteria assurance.
20,000-Psi API 16C Choke and Kill Flexible Line Development
Authors: Kovacs Zsolt , Gonzales Gerardo , David Attila , Grepaly Istvan , Mezo Tamas 
Published: April 2022

Abstract
This paper is to give a brief overview of the development process on the industrie's very first 20,000psi API 16C Temp U (-20 to 121°C) hose design. Although the design input and product requirements were clear, some aspects held a significant technical challenge in the early stages of the development. Selecting the proper materials and fine tuning the reinforcement layers to create a qualified and safe product with reasonable performance parameters were just the beginning, validating the product according toAPI 16C requirements with third party inspection marked the end of the process.
This paper is providing an example of a well defined, but challenging development, detailing the design, prototype testing and verification through dynamic analysis of the product.
Pathways to Achieve Rapid Decarbonization of ASEAN
Authors: Lau Hon Chung , Lin Xianlong 
Published: April 2022

AbstractAs a region, the ten countries of ASEAN emitted 1.65 Gt of CO2 in 2020 which was 4.75% of worldwide emission. The biggest CO2 emitting nations were Indonesia, Malaysia, Thailand, Vietnam and Philippines. This paper conducts a detailed analysis of total primary energy consumption (TPEC) and CO2 emission profiles from these five countries as well as Singapore and Brunei (ASEAN-7). Analyses show that in 2018, TPEC of ASEAN-7 consisted of 35% oil, 29% coal, 19% gas and 17% renewables, whereas CO2 emission came 44% from coal, 39% from oil, and 17% from gas. Seven pathways for rapid decarbonization of ASEAN are proposed. They include: (1) increasing the share of renewable energies in power generation, (2) replacing coal by gas in power generation, (3) electrification of road transport, (4) hydrogen for marine transport, (5) biofuels for aviation, (6) blue hydrogen for hard-to-decarbonize industries, and (7) establishing regional carbon capture and storage (CCS) corridors to accelerate implementation of large-scale CCS projects.
Key Technology Qualification of a Full Scale Subsea Chemical Storage and Injection System
Authors: Schroeder Art J. , Chitwood James E. , Gay Tom A. , Gillespie John , Lee Yung 
Published: April 2022

Abstract
This paper provides an overview and summary of development, testing, and qualification of a full-scale prototype subsea chemical storage and injection unit. Successful deployment of this new technology in brownfield applications will provide a very attractive alternative to an umbilical replacement that might be required late in field life when production rates and percent oil tend to be much lower, and where economics may all together preclude installing a new umbilical, resulting in pre-mature field abandonment. Additionally, transferring chemical storage and injection equipment from a host facility deck to subsea frees up space and weight and eliminates interaction of on-deck personnel with hazardous chemicals and can help achieve de-manning industry objectives. In greenfield applications, subsea chemical storage and injection can facilitate the development of hundreds of smaller deepwater resources and billions of barrels of oil equivalent (BOE) by enabling safe, cost-effective long-distance tie-backs to existing infrastructure out of traditional reach of umbilicals.
ISO Standardization as an Enabler for Production Efficiency in the Operating Phase
Authors: Hamran Harald , Østebø Runar , Smith Andrew , Alhanati Francisco 
Published: April 2022

Abstract
Consistent feedback on factors affecting production loss is key to monitoring production performance and drive improvements in production efficiency of upstream (E&P) installations. However, operators have used different frameworks for calculating and reporting production efficiency, and this has hampered communication among stakeholders and improvement efforts. The new ISO/TS 3250 "Calculation and reporting of production efficiency in the operating phase" has been developed to provide requirements and guidance for calculation and reporting production performance data, and production loss data, during the operating phase. This paper describes the background and how this new ISO/TS can assist in achieving consistency in determining the production potential and classifying production loss.
Calculation of the achieved production efficiency is in principle a simple exercise of calculating the ratio of actual production and production potential. However, changes in reservoir conditions, equipment failure and maintenance events, and external factors (such as weather), as well as economics, affect actual production or production potential to various degrees, and it is not always obvious how these events should be considered when calculating and reporting production efficiency. While ISO 20815:2018 already includes production loss categories for reporting production loss, the new technical specification extends these categories and provides requirements and additional guidance. For the allocation of production loss to different systems and equipment classes, the technical specification provides the important relationship to the classification provided by ISO 14224:2016, which is being used by operators in their computerized maintenance management information systems.
In an industry where continuous improvement is essential, keeping track of performance measures is key. Improving production performance or optimizing production efficiency in a life cycle perspective within HSE and sustainability frameworks, requires knowledge of such performance and identification of the most important contributors to production loss. The technical specification also provides a framework that enables consistency for benchmarking between an operator's own production facilities or across the industry.
This paper introduces all participants in the process – operators, contractors and other stakeholders, to this new international standard approach as described in this new technical specification.
XPak De Double Expansion Liner Hanger Replaces Wellhead Sub Mudline Adapter and Hanger - Qualification and Field Trial Results
Authors: Rice James Kevin 
Published: April 2022

Objectives/Scope
This paper discusses the qualification testing and field trials of a large-bore expandable liner hanger, which can serve as an alternative to wellhead sub-mudline supplemental casing hanger systems. Development of the first double expansion liner hanger, the Dril-Quip® XPak De™, allows for the elimination of contingency sub-mudline equipment, improves well integrity, simplifies liner installation, and reduces well costs. Detailed results from two field trial well installations are provided.
Integrated Operation Performance and Optimization Analysis Based on Technical Limit and Invisible Lost Time
Authors: Márquez Freddy José , Sandrea Ranses Guillermo 
Published: April 2022

Abstract
Technical Limit (TL) and invisible lost time (ILT) are concepts that have contributed to the success of several oil and gas projects around the world since late 90s, many of them documented and presented in international conferences. The TL represents the optimum time for a given operation, based on statistical analysis or operation team commitment. Defining TL could be challenging when unique activities are programmed or there is a lack of offset data, on these situations the TL estimated may be biased. The objective of this paper is to describe a methodology that allows to define a TL based on specific conditions of the well, to identify not only the ILT from operational performance, but also identify imprecisions on the daily operation reports (DOR), the program and well design.
ILT is the difference between the productive time and TL, this value allows to estimate efficiency. Identified invisible lost time (IILT) is the ILT portion that can be measured with real time data and/or DOR. The other portion is defined as unidentified ILT (UILT). IILT and UILT were estimated to productive and non- productive time (NPT). Geological correlation was used to estimate ILT derived from drilling performance.
Novelties in the Design of Low-Voltage Subsea Wet-Mate Connectors, Demonstrating Enhanced Electrical Performance and Cost Reduction
Authors: Wyatt Rob 
Published: April 2022

Abstract
A new subsea wet-mate low-voltage connector is presented, showing product strategies and designs to enhance electrical performance and reliability, while reducing cost and lead-time. Also reducing the environmental impact of such a product is discussed. Connectors with reduced environmental impact, reduced cost and enhanced reliability are needed to contribute to the economic and environmental viability of new applications such as ‘all electric’ subsea production systems, as well as new offshore markets such as wind, tidal energy, CO2 storage and fish farming.
Key methods to achieve this are redesign of the electrical insulation system, solderless cable terminations, and physical layout of the pin pattern. The effect of rationalising and standardising the product range on part count reduction for increased economies of scale is discussed, both for the connectors and for flying leads.
Conclusions of the Life Cycle Assessment conducted (embodied CO2) within the product are presented and how this is reduced with new product design.
New design features are shown which allow for components to have reduced dimensions and a reduction in overall quantity of component parts can be observed. Both contributing to reduced raw material content, lowering costs and environmental impact.
Finally, electrical test results performed in accordance with API-17F are shown.
Advancing Geothermal Energy Exploration
Authors: Pinnoo Seth Michael , Hart-Wagoner Nicole Rita , Pollett Buford , Pilko Robert , Chen Jingyi 
Published: April 2022

Abstract
Geothermal energy is a renewable energy source that is coming into more widespread use. Given the recent advancements in geothermal energy, it is an energy source that should be given serious consideration as new policies and regulations are set in place to reduce greenhouse gas emissions. While there are long-standing projects around the world utilizing geothermal resources, many places are still investigating geothermal resource potential, including several states within the United States. One state that has had limited geothermal exploration in recent years is Oklahoma. This paper compounds research efforts for Oklahoma geothermal resource evaluation and potential use and additionally provides information and background for potential sedimentary reservoirs that can be further evaluated for carbon sequestration pore space use. Three regions of Oklahoma were analyzed for geothermal resource potential: the Anadarko Basin, Arkoma Basin, and Osage County. Well logs from 105 wells were identified to analyze geothermal potential and subsurface temperature variations based on bottom hole temperatures (BHT). Results indicate that the Anadarko Basin has low potential for geothermal energy production, as temperatures &gt;100°C (212°F) are not reached until a depth of ~4,000 m (~13,000 ft). The Arkoma Basin wells reached temperatures of 100°C (212°F) at a depth of ~2,000 m (~6,500 ft), indicating potentially higher temperature resources at relatively shallower depths. The areas of higher temperatures appear to be dispersed, so more localized studies should be conducted in this region. The Osage County wells were only drilled to depths of &lt;~1,000 m (~3,300 ft), but some had BHT of &gt;40°C (~100°F) at these depths, indicating possible higher potential at depth. These results indicate that direct use of low-to-medium geothermal resources in Oklahoma can be exploitable further and that this preliminary investigation of geothermal resources in Oklahomashould be used as a basis for further exploration to target geothermal energy sources in the state.
A Novel Approach Using a Resin-Blended Cement System for Remedial Tieback Operations in a Highly Corrosive Environment: Case History from Iraq
Authors: Campana Barbosa Lucio Felipe , Iqbal Javaid , Bhaisora Devesh 
Published: April 2022

Abstract
Multiple heritage wells in Iraq have experienced sulfur water corrosion impacting the intermediate and production casing strings; if left untreated, the wells could be lost. Typically, costly workover operations to address this issue requires running a tieback casing and cementing it to the surface to isolate the production path from the corrosive formation fluids. Thus, well integrity is regained, and corrosion to the well casing is prevented.
To achieve long-term zonal isolation in corrosive environments, various slurry systems were studied, and a resin-blended cement system was selected to isolate the annulus between the tieback pipe and the outer intermediate casing. Reduced permeability of the set cement, resistance to fluid channeling, and increased shear bond strength, which protects the casing from H2S environments, are some of the salient features of this system. A premium grade external sleeve stage tool has been used for some of the strings to provide improved isolation.
Details of the design methodology, laboratory testing, job execution, and results from various wells wherein this cement system was applied are discussed. Some of the cementing operations have differences in terms of execution, such as the use of single or multiple plug systems or use of a perforated joint or stage tool as a means of circulation. However, all operations used the resin cement system. All tieback casings were cemented with zero non-productive time (NPT) and passed a pressure integrity test. This resin-blend cement system's reliability has proven effective for isolating zones where corrosive fluids have created severe and recurring issues in the past. Therefore, this new approach has become the primary choice for the operator.
A resin-blend cement system exhibits multiple desirable properties for isolation of the well's lifecycle and, if used as a primary option, can greatly reduce workover interventions in the future, leading to significant savings for the operator and increased well life, particularly in such corrosive environments.
Maximizing Value from Mature Assets in Deepwater Gulf of Mexico
Authors: Thompson Clay , Jegannathan Manoj , Jeansonne Natasha 
Published: April 2022

Abstract
This paper describes the challenges and opportunities facing operators with mature assets in the deepwater Gulf of Mexico. Oxy has a large deepwater asset base that, although mature, continues to provide the company value through robustness coupled with enhanced recovery techniques.
The deepwater Gulf of Mexico has transitioned from a reasonably steady pace of greenfield developments with standalone facilities into large brownfield projects with subsea tiebacks. As our mature deepwater fields have depleted, Oxy has leveraged the most up-to-date analytical methods and inspection techniques to extend the productive life of our floating and subsea infrastructure. Additionally, Oxy continues to apply a multitude of enhanced recovery technologies to maximize the recoverable reserves.
One of the key challenges for mature deepwater infrastructure is to institute an aggressive and robust integrity management program to achieve approval for continued service in hurricane-prone waters. The second key challenge is to boost the declining production of the aging reservoirs using a variety of enhanced recovery technologies rather than decommissioning the facilities because they are no longer economic to keep in operation.
Enabling All-Electric Subsea Control Systems without Compromising Safety - A Case Study Comparing Functional Safety Systems Using Springs or Batteries
Authors: Orth Alexandre , Placido Neto Amadeu , Hendrix Gottfried 
Published: April 2022

Abstract
The electrification of subsea control and production systems is essential to achieve the low carbon emission and high productivity targets that the offshore industry is facing now. But how to electrify these controls without compromising safety?
This paper provides a comparison of the design strategies using mechanical springs or electric batteries to implement safety functions in control systems, considering as a case study the development of the new subsea electric actuator for small-bore valves SVA R2 from Bosch Rexroth.
Traditionally, to control process valves with safety functions, hydraulic actuators have been applied with field-proven springs to bring the valve to a specific position (open or closed, depending on the application) in case of a safety-related failure such as a loss of power supply. However, the first electric subsea actuators developed with fail-safe springs turned out to be too large, heavy, inefficient, and costly due to their complex electro-mechanic system for broad adoption by the subsea industry. Thus, new electric subsea actuators [2] were developed using electric batteries to reduce overall size, but this added new risks: now the safety control has to detect a dangerous situation by itself and actively drive the system to the safe position. But, at the OTC 2021, a new electric subsea actuator for small bore valves was presented which achieves Safety Integrity Level SIL 3 using field-proven springs as compact as a hydraulic actuator (OTC-31083-MS) [17].
Following the functional safety methodology acc. to the IEC 61508, IEC 61511 and ISO 13849, this work provides a comparison between a control architecture with mechanical springs and another with electric batteries, considering the whole product life cycle (design, manufacture, installation, commissioning, and operation). An evaluation of the failure modes and failure mechanisms of existing subsea equipment, from field data available in the OREDA@Cloud, gives a proper assessment of the risks associated with implementing the new functional safety architecture. Costs of engineering, production and operation are taken into account to find out the most technical and economically feasible solution.
This case study is a reference for the design and qualification of new subsea electric actuators with functional safety requirements using mechanical springs or electric batteries. It provides technical guidelines and risk assessment for designers and users of subsea control systems such as machine builders, EPCI companies, operators, service providers or certification bodies.
If electrification is a prerequisite for a low carbon future, safety is a prerequisite for the adoption of all-electric control systems. This paper shows how to electrify subsea production and process systems by using mechanical springs or electric batteries without compromising safety.
Using Asset Performance Management APM to Deliver a Reliability Centered Maintenance RCM Approach in an Offshore Production Environment
Authors: Koutsoyiannis Loukas 
Published: April 2022

Abstract
In recent years, Asset Performance Management (APM) solutions have garnered increased attention from oil and gas process facility operators employing digitalization strategies. However, despite the growing interest, there is still confusion among industry professionals about what APM is and how it can be leveraged to reduce operating costs (OPEX), improve asset reliability, and contribute to de-manning objectives.
This paper aims to answer these questions by defining the framework for an effective APM program and outlining considerations for implementation. Multipleoffshore production facility uses cases are presented which demonstrate how an APM approach can be applied to enable a reliability centered maintenance (RCM) approach, whilst ensuring that equipment and systems perform their expected function within a specificoperating and business context.