Improved Acoustic Quick-Disconnect Technology for Mooring Operations

2021 ◽  
Author(s):  
Jonathan Kent Longridge ◽  
Johnny Shield ◽  
Sarah Finn ◽  
Tom Fulton
Keyword(s):  
Shallow Water ◽  
Oil And Gas ◽  
Signal Transmission ◽  
Cost Savings ◽  
Oil And Gas Industry ◽  
Lessons Learned ◽  
Battery Life ◽  
User Friendliness ◽  
Mooring Lines ◽  
Reduced Risk

Objectives/Scope As the offshore oil and gas industry has changed, deep water Mobile Offshore Drilling Units (MODU) are commonly outfitted with dynamic positioning (DP) systems and on-vessel mooring equipment to facilitate drilling operations at ultra-deep and shallow water well locations. However, since many shallow water locations can experience harsh conditions and may require moorings for station-keeping performance, it is beneficial to enable a DP rig to quickly disconnect from its mooring system and avoid hazardous conditions without support vessel assistance. Providing this capability, acoustically releasable subsea mooring connectors allow a rig's mooring lines to be released remotely and almost immediately. Additionally, the ability to disconnect without Anchor Handler Vessel (AHV) assistance for mooring operations and rig transit support offers reduced risk and cost savings. Methods, Procedures, Process A brief review of existing quick-disconnect mooring devices will be presented. It will highlight how the technology has evolved and is being used, particularly in recent years. Successes, problems, and lessons learned from past InterMoor and SRP product development will be summarized and focused attention will be given to a significant number of more recent improvements to increase the product's reliability, availability, serviceability, and robustness. Improvements to ensure reliable long-term battery life and power supply, enhance on-vessel accessibility and user-friendliness for rig personnel, and employ advanced acoustic signal transmission, reception, and device status analytics will be discussed. External modifications to reinforce its robustness during deployment and internal electromechanical changes to facilitate its serviceability will also be described. Results, Observations, Conclusions A substantially lighter and smaller acoustically releasable mooring connector was developed two years ago, tested thereafter, recently deployed on several offshore mooring campaigns, and has now been upgraded to incorporate high-fidelity electronics with the ability to release under tension loads as high as 900 tonnes. As such, this second-generation device's reliability, accessibility, and serviceability are significantly enhanced. Results from offshore deployments from recent MODU and barge mooring operations will be summarized. This technology provides a safer way to quickly disconnect mooring lines and offers cost efficiency by allowing faster rig moves from one location to the next with reduced risk. Novel/Additive Information The paper will cover the work, challenges, trials, and tribulations required to bring a new product to market with cutting edge capabilities. Novel highlights will include the integration of a networked data transmission and communication system, the system's fundamental change from pneumatic to electromechanical actuation, and additional enhancements and improvements that are unique to mooring quick-disconnect devices and at the forefront of subsea technology.

Hybrid Bit Technology Deployment Yields Breakthrough Drilling Performance & Cost Savings for Operator

2021 ◽  
Author(s):  
Fawaz Al-Salah ◽  
Saad Al-Mejmed ◽  
Atef Abdelhamid ◽  
Ali Alnemer ◽  
Tahir Gada ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Impact Damage ◽  
Cost Savings ◽  
Polycrystalline Diamond ◽  
Oil And Gas Industry ◽  
Lessons Learned ◽  
Drill Bit ◽  
Drilling Performance ◽  
Carbonate Formation ◽  
Percent Improvement

Abstract Optimized drilling performance and minimized cost per well are key objectives for operators in the current challenging oil and gas industry. The process of collecting lessons learned and designing new drill bit technologies based on these learnings is critical for optimizing drilling performance and reducing non-productive time (NPT). Southeast Kuwait onshore wells are drilled with conventional drill bit technology such as tungsten carbide insert (TCI) and polycrystalline diamond compact (PDC) bits on rotary or directional-motor bottom hole assemblies (BHA). This paper discusses the analysis that enabled breakthrough-drilling performance of 16-in. hybrid drill bit technology, delivering outstanding results and cost savings for an operator. The non-homogeneous carbonate formation in these onshore wells cause impact damage, limit the drilling efficiency of PDC and TCI bits, and result in a low rate of penetration (ROP) and poor dull conditions. A collaborative technical analysis identified key performance objectives to ensure a step change in section drilling performance. The analysis involved reviewing: Post-run dull conditions Operating parameters Formation compressive strengths Bit design Previous deployments results On Multiple wells, advanced hybrid bit technology and optimized drilling methods achieved outstanding 73-percent improvement in ROP over conventional technologies, saving operator's 3.8 drilling days and more than 27% of drilling costs. The hybrid design completed two consecutive best in class (BIC) wells in southeast Kuwait compared with the typical TCI performance of a single well per bit.

New Automated MPD Riser System Allowed an Operator to Reduce Manual Working Hours in the Moonpool by 85% and Installation Time by 60%

2021 ◽  
Author(s):  
Mohamed Hammad ◽  
Julian Hernandez ◽  
Angel Hernandez ◽  
Karim Mammadli ◽  
Rustam Soltanov
Keyword(s):  
Oil And Gas ◽  
Service Providers ◽  
Cost Optimization ◽  
Cost Savings ◽  
Working Hours ◽  
Oil And Gas Industry ◽  
Lessons Learned ◽  
The Caspian Sea ◽  
Automated Technology ◽  
Installation Time

Abstract In pursuit of efficiency and well construction cost optimization, the oil and gas industry demand continuous improvements and constant evolution of the service providers’ hardware and software, including Managed Pressure Drilling (MPD) technologies. Recently deployed in the Caspian Sea, the new automated riser system enabled an operator to reduce manual working hours in the moonpool by 85% and installation time by 59%. The improved efficiencies represent an additional saving of 19.5 hours rig time compared to the previous generation MPD below tension ring (BTR) systems, which are currently used on more than 19 floaters around the world. Lessons learned over the past 10 years led to the design and release of the new automated technology that resulted in this time and cost savings. The operator currently targets deep reservoirs that cannot be drilled using conventional drilling techniques because of very narrow operating windows. This paper discusses the service delivery process, engineering, and operational challenges that culminated in the flawlessly executed first deployment of the automated MPD riser system.

Tubarão Martelo Field Riser System: Shallow Water Challenging

2015 ◽  
Author(s):  
Elton J. B. Ribeiro ◽  
Zhimin Tan ◽  
Yucheng Hou ◽  
Yanqiu Zhang ◽  
Andre Iwane
Keyword(s):  
Shallow Water ◽  
Deep Water ◽  
Oil And Gas ◽  
Vertical Motion ◽  
Oil And Gas Industry ◽  
System Configuration ◽  
Wave Load ◽  
Gas Industry ◽  
Campos Basin ◽  
Water Problem

Currently the oil and gas industry is focusing on challenging deep water projects, particularly in Campos Basin located coast off Brazil. However, there are a lot of prolific reservoirs located in shallow water, which need to be developed and they are located in area very far from the coast, where there aren’t pipelines facilities to export oil production, in this case is necessary to use a floating production unit able to storage produced oil, such as a FPSO. So, the riser system configuration should be able to absorb FPSO’s dynamic response due to wave load and avoid damage at touch down zone, in this case is recommended to use compliant riser configuration, such as Lazy Wave, Tethered Wave or Lazy S. In addition to, the proposed FPSO for Tubarão Martelo development is a type VLCC (Very Large Crude Carrier) using external turret moored system, which cause large vertical motion at riser connection and it presents large static offset. Also are expected to install 26 risers and umbilicals hanging off on the turret, this large number of risers and umbilicals has driven the main concerns to clashing and clearance requirement since Lazy-S configuration was adopted. In this paper, some numerical model details and recommendations will be presented, which became a feasible challenging risers system in shallow water. For instance, to solve clashing problem it is strictly recommended for modeling MWA (Mid Water Arch) gutter and bend stiffener at top I-tube interface, this recommendation doesn’t matter in deep water, but for shallow water problem is very important. Also is important to use ballast modules in order to solve clashing problems.

Lessons Learned in Developing Human Capital for the Oil and Gas Industry in Kazakhstan

2021 ◽  
Vol 73 (08) ◽  
pp. 60-61
Author(s):  
Chris Carpenter
Keyword(s):  
Human Capital ◽  
Human Resource Development ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Technical Conference ◽  
Program Improvement ◽  
Lessons Learned ◽  
Colorado School ◽  
Gas Industry ◽  
Successful Model

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 201272, “Lessons Learned in Developing Human Capital for the Oil and Gas Industry in Kazakhstan,” by Zhassulan Dairov, SPE, KIMEP University and Satbayev University; Murat Syzdykov, SPE, Satbayev University; and Jennifer Miskimins, SPE, Colorado School of Mines, prepared for the 2020 SPE Annual Technical Conference and Exhibition, originally scheduled to be held in Denver, Colorado, 5–7 October. The paper has not been peer reviewed. The World Economic Forum’s (WEF) Human Capital initiative has been implemented at Satbayev University (SU), Almaty, Kazakhstan, during the last 2 years. Participating in this effort are Chevron, Eni, Shell, and the Colorado School of Mines (Mines). The complete paper assesses the effectiveness of project components, such as industry guest lectures, summer internships, and program improvement, and provides lessons learned for human-resource-development initiatives. Introduction In most cases, the industry/ university alliance is intermittent, short-term, and underdeveloped. The engagement of three stakeholders, such as government, industry, and the university, is the most-successful model of joint performance. This approach allows all participants to create competitive advantages in the achievement of common objectives. Moreover, the role of governmental agencies is critical alongside professional organizations in facilitating such cooperation.

Digital Oil Field; The NPDC Experience

2021 ◽  
Author(s):  
Henry Ijomanta ◽  
Lukman Lawal ◽  
Onyekachi Ike ◽  
Raymond Olugbade ◽  
Fanen Gbuku ◽  
...  
Keyword(s):  
Real Time ◽  
Oil And Gas ◽  
Data Gathering ◽  
Oil And Gas Industry ◽  
Oil Field ◽  
Battery Life ◽  
Gas Industry ◽  
Field Management ◽  
Digital Oilfield ◽  
Data Analytic

Abstract This paper presents an overview of the implementation of a Digital Oilfield (DOF) system for the real-time management of the Oredo field in OML 111. The Oredo field is predominantly a retrograde condensate field with a few relatively small oil reservoirs. The field operating philosophy involves the dual objective of maximizing condensate production and meeting the daily contractual gas quantities which requires wells to be controlled and routed such that the dual objectives are met. An Integrated Asset Model (IAM) (or an Integrated Production System Model) was built with the objective of providing a mathematical basis for meeting the field's objective. The IAM, combined with a Model Management and version control tool, a workflow orchestration and automation engine, A robust data-management module, an advanced visualization and collaboration environment and an analytics library and engine created the Oredo Digital Oil Field (DOF). The Digital Oilfield is a real-time digital representation of a field on a computer which replicates the behavior of the field. This virtual field gives the engineer all the information required to make quick, sound and rational field management decisions with models, workflows, and intelligently filtered data within a multi-disciplinary organization of diverse capabilities and engineering skill sets. The creation of the DOF involved 4 major steps; DATA GATHERING considered as the most critical in such engineering projects as it helps to set the limits of what the model can achieve and cut expectations. ENGINEERING MODEL REVIEW, UPDATE AND BENCHMARKING; Majorly involved engineering models review and update, real-time data historian deployment etc. SYSTEM PRECONFIGURATION AND DEPLOYMENT; Developed the DOF system architecture and the engineering workflow setup. POST DEPLOYMENT REVIEW AND UPDATE; Currently ongoing till date, this involves after action reviews, updates and resolution of challenges of the DOF, capability development by the operator and optimizing the system for improved performance. The DOF system in the Oredo field has made it possible to integrate, automate and streamline the execution of field management tasks and has significantly reduced the decision-making turnaround time. Operational and field management decisions can now be made within minutes rather than weeks or months. The gains and benefits cuts across the entire production value chain from improved operational safety to operational efficiency and cost savings, real-time production surveillance, optimized production, early problem detection, improved Safety, Organizational/Cross-discipline collaboration, data Centralization and Efficiency. The DOF system did not come without its peculiar challenges observed both at the planning, execution and post evaluation stages which includes selection of an appropriate Data Gathering & acquisition system, Parts interchangeability and device integration with existing field devices, high data latency due to bandwidth, signal strength etc., damage of sensors and transmitters on wellheads during operations such as slickline & WHM activities, short battery life, maintenance, and replacement frequency etc. The challenges impacted on the project schedule and cost but created great lessons learnt and improved the DOF learning curve for the company. The Oredo Digital Oil Field represents a future of the oil and gas industry in tandem with the industry 4.0 attributes of using digital technology to drive efficiency, reduce operating expenses and apply surveillance best practices which is required for the survival of the Oil and Gas industry. The advent of the 5G technology with its attendant influence on data transmission, latency and bandwidth has the potential to drive down the cost of automated data transmission and improve the performance of data gathering further increasing the efficiency of the DOF system. Improvements in digital integration technologies, computing power, cloud computing and sensing technologies will further strengthen the future of the DOF. There is need for synergy between the engineering team, IT, and instrumentation engineers to fully manage the system to avoid failures that may arise from interface management issues. Battery life status should always be monitored to ensure continuous streaming of real field data. New set of competencies which revolves around a marriage of traditional Petro-technical skills with data analytic skills is required to further maximize benefit from the DOF system. NPDC needs to groom and encourage staff to venture into these data analytic skill pools to develop knowledge-intelligence required to maximize benefit for the Oredo Digital Oil Field and transfer this knowledge to other NPDC Asset.

Case Histories of the Resolution of Bolted Joint Leakage in the Oil and Gas Industry

2016 ◽  
Author(s):  
Warren Brown ◽  
Geoff Evans ◽  
Lorna Carpenter
Keyword(s):  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Lessons Learned ◽  
Bolted Joint ◽  
Case Histories ◽  
Gas Industry ◽  
Root Cause ◽  
The Past ◽  
Cause Of Failure ◽  
Assessment Techniques

Over the course of the past 20 years, methods have been developed for assessing the probability and root cause of bolted joint leakage based on sound engineering assessment techniques. Those methods were incorporated, in part, into ASME PCC-1-2010 Appendix O [7] and provide the only published standard method for establishing bolted joint assembly bolt load. As detailed in previous papers, the method can also be used for troubleshooting joint leakage. This paper addresses a series of actual joint leakage cases, outlines the analysis performed to determine root cause of failure and the actions taken to successfully eliminate future incidents of failure (lessons learned).

How to avoid aches and pains in your joint ventures

2016 ◽  
Vol 56 (2) ◽  
pp. 559
Author(s):  
Brent Steedman
Keyword(s):  
Joint Ventures ◽  
Joint Venture ◽  
Oil And Gas ◽  
Cost Savings ◽  
Oil And Gas Industry ◽  
Capital Allocation ◽  
Operating Efficiency ◽  
Global Business ◽  
Gas Industry ◽  
The Right

The Australian oil and gas industry is in a period of substantial challenges, including a significant decline in oil prices, fluctuating spot gas prices, a relentless drive for operating efficiency, and tight capital allocation, together with increased regulatory scrutiny and a reputation for below-standards productivity. On the upside, these market challenges provide significant opportunities for companies to bring in new investors, implement new operating models, apply innovation to update processes and practices, and restructure activities. Making material step-changes, requires companies to review, amend, and update joint venture operating agreements (JVOAs). KPMG has worked with many of Australia’s leading oil and gas companies on a range of joint venture engagements. This extended abstract outlines why JVOAs need to be reviewed with respect to the following key opportunities and challenges: Fast-changing global business operating models. Available cost savings by eliminating inconsistent management and operating models between joint ventures. Planning for potential restructuring, including separation of infrastructure (e.g. plants, pipelines, support) from reserve ownership. Sharing of services (e.g. maintenance and logistics) between unrelated joint ventures. Transparency of costs and asset performance. Improved joint venture governance (not more or over-governance) between participants to attract investment. Effective resourcing, noting the right transition of capabilities between deal-makers and joint venture operators. With this extended abstract the authors aim to provide ideas for consideration. Each of these ideas will impact JVOAs. The authors’ proposition is that now is the right time to complete a comprehensive review of JVOAs to enable organisations to move fast as new and innovative opportunities arise.

Additive Manufacturing in the Oil and Gas Industry Overview

2020 ◽  
Author(s):  
Carlo De Bernardi
Keyword(s):  
Additive Manufacturing ◽  
Inventory Management ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Lessons Learned ◽  
Current Status ◽  
Gas Industry ◽  
Standardization Process ◽  
Process Feedback ◽  
Different Levels

Abstract The API 20S Standard is designed to play a crucial role in leveraging Additive Manufacturing (AM) to foster innovation in the oil and gas industry. The paper, in association with the standard, will facilitate the understanding of how AM will enable equipment design improvements, faster prototyping, and better inventory management. By way of discussing the progress, challenges, and lessons learned from the standardization process, the paper aims to encourage a safer, broader, and faster adoption of AM technologies in the mainstream oil and gas applications. The paper will summarize the streamlining process, feedback from the API 20S task group, and current status of the standardization efforts. Additionally, upcoming challenges and the potential for the oil and gas industry industries to contribute to the standard will be summarized. The paper will also showcase a novel tiered approach (Additive Manufacturing Specification Levels) to allow the users of the document to match different levels of criticality.

Experience in the Application of the Goal Setting Regime and Risk-Based Design of Safety Critical Elements in the Oil and Gas Industry

2013 ◽  
Author(s):  
Robert W. Brewerton ◽  
Paul Geddes ◽  
Sava Medonos ◽  
Raghu Raman ◽  
Christopher C. E. Wilkins
Keyword(s):  
Goal Setting ◽  
Oil And Gas ◽  
Cost Savings ◽  
Oil And Gas Industry ◽  
Quantitative Risk Assessment ◽  
Operational Experience ◽  
Facility Design ◽  
Worst Case ◽  
Fire And Explosion ◽  
Technical Safety

The research and development activities following the Piper Alpha disaster have resulted in significantly improved technical safety of oil & gas facilities offshore and onshore. This improved technical safety resulted from the development of goal-setting, risk-based approach, the objective of which was to open the routes for design optimization and remove previous constraints that addressed the worst case and was prescriptive. Despite this initiative, a Quantitative Risk Assessment (QRA), while still being carried out, often remains “disconnected” from the practical design and prescriptive methods still take precedence. Resorting solely to a prescriptive approach can result in adequate protection missing in places where it should be, and applied in areas where there is a low likelihood of the hazard. This Paper addresses the application in the facility design, risk based methods and known behavior of structures and equipment in accidents. It stresses the importance of practical experience in the application of fire and explosion protection, and adequate design and operational experience. The Paper focuses on fire and explosion hazards and is based on more than 30 years of the authors’ experience in supporting facility design and assessment. Such approach has resulted in solutions with improved technical safety and significant cost-savings. It addresses both new installations and modifications of existing facilities.

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