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Vortex Induced Vibration Study for Deep Draft Column Stabilized Floaters

Subcontractor: Houston Offshore Engineering

Principal Investigator: Arun Antony
Project Number Project Status
11121-5404-03
RPSEA Project Manager: Rick Baker
Participants
MARIN; Los Alamos National Laboratory; John Halkyard & Associates; Red Wing Engineering
Period of Performance
Start Date End Date
December 4, 2013 September 30, 2016
Total Project Cost RPSEA Share Cost Share
$2,673,692.00 $2,136,100.00 $535,592.00
Project Objectives

A vortex induced motion (VIM) study to determine the sensitivity of the VIM response to the geometric parameters of deep draft semisubersibles, computational fluid dynamics (CFD) analysis to understand semi-submersibles' VIM and sensitivity to various parameters by studying the fluid flow (i.e. vortex shedding and wake interface) and VIM response to be used in the development of guidelines, and a model test to validate the VIM performance of one benchmark semi hull configuration and several variations in VIM mitigation options in a towing tank, with and without suppression devices.

Report

File Name File Type Date
CFD For VIM Estimation Of Semisubmersibles Articles 07/15
VIM model testing Image
Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters Phase 1 Final Report 06/15
Phase 2-FR-Low Cost Flexible Production System for Remote Ultra Deepwater Gulf of Mexico (GOM) Filed Development Phase 2 Final Report 09/16
Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters VIM Model Test Report Vol. 2 04/16
Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters VIM Model Test Report Vol. 2, App G1 04/16
Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters VIM Model Test Report Vol. 2, App G2 04/16
Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters VIM Model Test Report Vol. 2, App G3 04/16
Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters VIM Model Test Report Vol. 2, App G4 04/16
Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters VIM Model Test Report Vol. 2, App G5 04/16
Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters VIM Model Test Report Vol. 2, App G6 04/16
Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters VIM Model Test Report Vol. 2, App G7 04/16
Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters VIM Model Test Report Vol. 2, App G8 04/16
Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters VIM Model Test Report Vol. 2, App G9 04/16
Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters VIM Model Test Report Vol. 2, App G10 04/16
Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters VIM Model Test Report Vol. 2, App H Part 1 04/16
Vortex Induced Motion Study for Deep Draft Column Stabilized Floaters VIM Model Test Report Vol. 2, App H Part 2 04/16

Analysis of Best Practices for Deepwater Cementing in Oil Based Mud (OBM) and Synthetic Based Mud (SBM)

Subcontractor: CSI Technologies, LLC

Principal Investigator: Jeff Watters
Project Number Project Status
12121-6503-01
RPSEA Project Manager: Rob Vagnetti
Participants
ConocoPhillips; Princeton University
Period of Performance
Start Date End Date
June 25, 2014 September 30, 2016
Total Project Cost RPSEA Share Cost Share
$2,903,470.00 $1,789,768.00 $1,084,687.00
Project Objectives

The objectives of this project are to develop fundamental knowledge of mud-cement compatibility issues related specifically to deepwater cementing, to quantify risks associated with cementing in OBM/SBM and to develop best practices and derive recommendation in order to reduce the recognized risks. This study will analyze the relationship between temperature, pressure, cement bond, degree of mud removal and its effect on zonal isolation in complex well architecture.

Report

File Name File Type Date
Final Presentation Final Report 09/16
Phase 1 Interim Report 06/15
Tech. Status Assessment Members Only File
Analysis of Best Practices Members Only File

Reliability of Annular Pressure Buildup (APB) Mitigation Technologies

Subcontractor: Blade Energy Partners, Ltd

Principal Investigator: Robert M. Pilko
Project Number Project Status
12121-6502-01
RPSEA Project Manager: Rob Vagnetti
Participants
Period of Performance
Start Date End Date
July 28, 2014 December 15, 2015
Total Project Cost RPSEA Share Cost Share
$828,074.00 $654,178.00 $165,615.00
Project Objectives

Annular Pressure Buildup (APB) occurs in all wells with high bottom hole temperature, multiple casing strings and annuli that cannot be vented--which includes most deepwater Gulf of Mexico wells. APB can result in casing string and premature well failure, unless a well is properly designed. APB risks are fully assessed for all load cases, and any necesary APB mitigation methods are evaluated, fully analyzed for effectiveness, and properly implemented.

Report

File Name File Type Date
Reliability of Annular Pressure Buildup APB Mitigation Technologies Final Report 03/16
Tech. Status Assessment Members only file

Development of Advanced CFD Tools for the Enhanced Prediction of Explosion Pressure Development and Deflagration Risk on Drilling and Production Facilities

Subcontractor: GexCon US, Inc.

Principal Investigator: Scott Davis
Project Number Project Status
12121-6403-01
RPSEA Project Manager: Gary Covatch
Participants
Period of Performance
Start Date End Date
August 23, 2014 September 30,2016
Total Project Cost RPSEA Share Cost Share
$4,640,000.00 $3,680,000.00 $960,000.00
Project Objectives

The objectives of the project was to provide oil and gas companies operating in the GOM with the tools necessary to design "inherently safer" offshore facilities that can survive gas explosion incidents and prevent escalation. This project enhanced and validated the capabilities of the industry-standard explosion modeling CFD software, FLACS, to aid in reducing the HS&E-related incidents in the GOM.

Report

File Name File Type Date
Development of CFD Tools for the Enhanced Prediction of Explosion Pressure Develoment and Deflagration Risk on Drilling and Production Facilities Final Report 12/16
Task 5 Concept Report 09/15
Roadmap to Close Technology Gaps Report 08/15
Large Scale Testing - Development of Advanced CFD Tools for the Enhanced Prediction of Explosion Pressure Development and Deflagration Risk on Drilling and Production Facilities Presentation
Large Scale Testing - Development of Advanced CFD Tools for the Enhanced Prediction of Explosion Pressure Development and Deflagration Risk on Drilling and Production Facilities Report

Methodology and Algorithm Development for the Evaluation of Ultra-Deepwater or Arctic Floating Platform Performance under Hazardous Sea Conditions

Subcontractor: Offshore Dynamics, Inc.

Principal Investigator: Shan Shi
Project Number Project Status
12121-6402-01
RPSEA Project Manager: Gary Covatch
Participants
Period of Performance
Start Date End Date
July 2, 2014 July 1, 2016
Total Project Cost RPSEA Share Cost Share
$253,000.00 $200,000.00 $53,000.00
Project Objectives

The objective of this project was to improve the overall safety of ultra-deepwater or arctic floating platforms by implementing nonlinear effects in a state of the art software code that could be used by the industry. Better understanding of the effects in a state of the art software code that could be used by the industry. Better understanding of the effects of nonlinearity on floating platforms through research and development would inherently decrease the risks associated with implementing ultra-deepwater or arctic design projects.

Report

File Name File Type Date
Phase 1 Study Final Report
Phase 1 Research Methodology Summary Report Report

Subsea High Voltage Direct Current Connectors for Environmentally Safe and Reliable Powering of UDW Subsea Processing

Subcontractor: GE Global Research

Principal Investigator: Qin Chen
Project Number Project Status
12121-6302-01
RPSEA Project Manager: Gary Covatch
Participants
Period of Performance
Start Date End Date
June 20, 2014 September 30, 2016
Total Project Cost RPSEA Share Cost Share
$3,254,344.00 $2,577,766.00 $676,578.00
Project Objectives

The objective of this project was to assess the risks and close the technology gaps of subsea DC connectors, a critical component to ensure the safe and reliable operation of subsea high voltage direct current (HVDC) transmission and distribution (T&D) systems, which is the emerging technology for environmentally safe and reliable powering of long step-out, ultra-deepwater  (UDW) subsea oil and gas processing.

Report

File Name File Type Date
Mock-up Subsea HVDC Connectors Bench-Scale Test Procedures Report 03/16
Technical Requirements Report 02/15
Subsea HVDC Connectors Tech. Analysis Gap Report 04/15
Effect of moisture and ionic contaminations on DC insulation for subsea applications Paper
Characterization of Solid-Liquid Interface for Wet-Mate Subsea HVDC Connectors Paper
Modeling a Liquid-Solid Insulation System Used in a DC Wet-Mate Connect Paper

Hi-Res Environmental Data for Enhanced UDW Operations Safety

Subcontractor: Fugro Global Environmental and Ocean Sciences, Inc.

Principal Investigator: Grant Stuart
Project Number Project Status
11121-5801-01
RPSEA Project Manager: David Cercone
Participants
Areté Associates; Fugro Geospatial Inc.; Florida State University CO-APS; WeatherPredict Consulting Inc.
Period of Performance
Start Date End Date
February 18, 2014 September 30, 2016
Total Project Cost RPSEA Share Cost Share
$1,690,734.00 $1,042,489.00 $631,338.00
Project Objectives

Ocean currents can pose significant challenges to safe oil and gas operations in the Gulf of Mexico (GoM). One primary objective of this research program was to better understand the physical mechanisms that cause periods of elevated current velocities. Specifically, the passage of Tropical Revolving Stroms (TRS) over areas of relatively higher sea surface temperature (e.g., loop current (LC) or associated eddy (LCE) may cause elevated currents in the boundary layers of the water column.

Report

File Name File Type Date
Tech. Status Assesment Members only file
Images part 1
Images part 2
Validation and Test Report – A Report 02/16

Intelligent BOP RAM Actuation Sensor Systems

Subcontractor: GE Global Research

Principal Investigator: Emad Andarawis
Project Number Project Status
11121-5503-01
RPSEA Project Manager: Bill Fincham
Participants
Period of Performance
Start Date End Date
October 4, 2013 July 4, 2016
Total Project Cost RPSEA Share Cost Share
$1,392,380.00 $1,099,980.00 $278,476.00
Project Objectives

Design and development of an instrument BOP ram prototype and laboratory testing. The technology development will be conducted in five stage gates within two phases:

  • A system feasibility determination, gaps analysis, and a risk assessment will be conducted, followed by technology selection (TRL0).

Instrumentation was conceptualized and reviewed (TRL1), designed (TRL2), a prototype was constructed and bench scale tested (TRL3-4), followed by review with BSEE and API, and development of a commercialization plan.

Report

File Name File Type Date
Tech. Status Assessment D Members Only File 07/14
BOP Ram Sensing and Interface Concept Rationale Technical Report 11/14
Sensing Integration Concept Rationale Technical Report 11/14
Intelligent BOP RAM Actuation Sensor System Final Technical Report 09/16
Phase 1 Final Report 09/14
Phase 1 Technical Report 06/14
Detailed Sensor System Design Final Technical Report Intelligent BOP RAM Actuation Sensor System Final Report 09/16

Integrity Management of Risers to Support Deepwater Drilling and Production Operations

Subcontractor: GE Global Research

Principal Investigator: Judith Guzzo
Project Number Project Status
11121-5402-01
RPSEA Project Manager: Rick Baker
Participants
GE Oil & Gas; Dr. Michael Volk
Period of Performance
Start Date End Date
November 22, 2013 September 30, 2016
Total Project Cost RPSEA Share Cost Share
$2,924,294.00 $2,339,435.00 $584,859.00
Project Objectives

Development of a reliable, cost-effective real-time, riser integrity, management system by closing technology gaps that include: availability of historical riser data for assessment of long-term integrity management of deepwater riser systems; on-board subsea equipment controls to detect anomalous behavioral modes and implement mitigation strategies; essential safety management system/software for riser system integrity data storage, riser performance and user interface for management solutions encompassing hardware, software, processes and people.

Report

File Name File Type Date
Phase 1 Generic Riser Life-cycle Reliability Model Final Report 02/15
Phase 1 Preliminary Design Report Final Report 11/14
Phase 1 Basis of Design Report Final Report 02/15
Riser Lifecycle Monitoring System Integrity Management Tech. Status Assessment

Deepwater Permanent Subsea Pressure Compensated Chemical Reservoir

Subcontractor: Safe Marine Transfer LLC

Principal Investigator: James Chitwood
Project Number Project Status
11121-5302-01
RPSEA Project Manager: Bill Fincham
Participants
Alan . McClure Assoc. Inc,; Canyon Offshore, Inc; Stress Engineering Services Inc; OceanWorks International, Inc.
Period of Performance
Start Date End Date
May 9, 2014 September 18, 2016
Total Project Cost RPSEA Share Cost Share
$6,371,467.00 $4,667,040.00 $1,704,427.00
Project Objectives

The objective of the project was to develop a functional and qualified subsea chemical storage and injection system design with an effective 3,000 - barrel chemical storage volume. The size of the chemical storage dominates the operational constraints for this system. There are several viable approaches to replenishing the chemistry and installation of the facility. Proven technology with economic factors is expected to dominate the selection of these installation and maintenance approaches as the technology for this objective is matured.

Report

File Name File Type Date
Tech. Status Assessment Report
Deepwater Permanent Subsea Pressure Compensated Chemical Reservoir Constructions and Testing Video
Deepwater Subsea Pressure Chompensated Chemical Reservoir Stage 1 Final Report 08/15
Image Image
Development and Qualification of a Subsea 3000 Barrel Pressure Compensated Chemical Storage and Injection System Paper 06/16
Delivery of production chemical storage (3000+ bbls) and injection at point of need to 10000 fsw as a service Presentation 06/16