PNEC

2022 CONFERENCE SESSIONS

Tuesday, March 1, 2022
9:00 AM - 4:30 PM
To come
5:00 PM - 7:00 PM
Network with exhibitors and colleagues.
Wednesday, March 2, 2022
7:00 AM - 8:00 AM
Don't skip the most important meal of the day.
8:00 AM - 9:20 AM
 
9:20 AM - 10:10 AM
Grab a cup of coffee and network.
10:10 AM - 10:40 AM

Petrobras has developed and patented a new technology, called HISEP. It is a high-pressure, dense-phase separation system that can enhance production by promptly enabling the separation and reinjection of CO2 on the seabed as a dense fluid using centrifugal pumps. The technology also reduces the need for large gas processing plants on the topside, which in turn reduces capex, opex, and accelerates the cycle time to first production. The technology is undergoing definition and testing. 

10:40 AM - 11:10 AM

The focus of this presentation will be on SCR Design in respect to HP/HT requirements for deepwater developments and field layout considerations to ensure the most efficient riser design. Specifically, emphasis will be placed on wall thickness selection, unique welding qualification testing & procedures development, and the regulatory review process required prior to final approval as well as a discussion of some of the challenges encountered in the early design phase regarding the subsea infrastructure.

11:10 AM - 11:40 AM

Shell views long subsea oil tiebacks greater than 25 mi. as important to deliver on our strategy of keeping existing Deepwater hubs full. Key challenges to long tiebacks include CAPEX, hydraulics, and flow assurance. Our long tieback program is intended to assess and improve deployment readiness of a suite of selectable technologies. In addition to commercially available solutions, we have identified high voltage mineral insulated (HVMI) heater cable from Salamander Solutions as an alternative technology to address flow assurance challenges. We are executing a qualification program to mature HVMI technology components to enable additional technology options for future long tiebacks.

11:40 AM - 12:55 PM
Catch up with colleagues over lunch.
12:55 PM - 1:25 PM

Barracuda project is located NCMA Trinidad and Tobago and comprises a subsea tie-in to the existing Dolphin Deep subsea infrastructure and back to the Dolphin Area platform. The new Barracuda wells (SITP 6100PSI) are gas producers and flow back through the existing Dolphin Deep flowline (MAWP 4500PSI). The derated section of flowline between the platform and the new infrastructure is protected by the first Subsea HIPPS package to be delivered to Shell Deepwater organization. This is also the first TFMC / Shell HIPPS solution. The presentation will take a look at the key highlights / low points & lessons learned of the project as its moved from Concept to delivery & commissioning. Focus will be on key decision drivers to move forward with a HIPPS solution, Key inputs to the SURF design, Key design challenges, functional safety considerations for subsea & certification, delivery challenges, How we dealt with COVID and remote testing, Installation & commissioning learnings and key take always for future Shell HIPPS projects.

1:25 PM - 1:55 PM

After a subsea failure in the Umbilical Termination Assembly (UTA), there is a leak in the HP line to function the SCSSVs. This immediately shut in production on the 2 producers in the Cascade field because of the inability to hold open the SCSSV. After investigation into the root cause, the failure was found to be at the socket weld in the UTA. The option to repair the umbilical included pulling the umbilical up to a boat and re-terminating on the back of a boat. Knowing how costly and risky this could be to the umbilical integrity, Murphy began searching for alternatives. A Subsea Accumulator Module (SAM) was developed and installed address this shortcoming. The SAM is a bank of accumulators that have been integrated into the subsea system to allow HP pressure supply into the lines downstream of the weld failure. This allows control of the SCSSVs and allows production of the two Cascade wells. The new system has been in place and functioning per design for 8 months. These details will be presented along with other available solutions and options considered and either discarded or progressed as a parallel option.

1:55 PM - 2:25 PM

This presentation will focus on various challenges that we were faced with during the Praline development that caused us to consider alternatives for the pipeline installation and how we navigated through pivotal milestones to validate contingency plans that put us in a position to execute a truly unique installation sequence to salvage first oil and fulfill our commitments with the host operator.

2:25 PM - 3:15 PM
Grab a cup of coffee and network.
3:15 PM - 3:45 PM

The PowerNap project is a new tie-back in the GoM and is one of the first applications of the residual curvature method in deepwater.

3:45 PM - 4:15 PM

Mid-way through 2019, when Murphy acquired a number of LLOG assets, two of the discoveries were fast-paced field developments. Murphy is known for working quickly and efficiently and saw this as a great fit for us. Just as execution plans were implemented and major contracts signed, the world came to a screeching halt - COVID hit! Plants were shut down. Countries were shut down. Supply chains for raw material and equipment were severely disrupted. Yet, in spite of this global pandemic, the Oil & Gas Industry went on. Murphy and our contractors forged ahead. We optimized plans and schedules, increased communication, focused on mitigations to maintain our forward trajectory towards installation and first oil. Our contractors and suppliers were instrumental in this effort and were dedicated to our combined success. We will discuss specific steps taken to structure the project, and to ensure safe and timely delivery, including regulatory approvals, to enable advancement to installation of these three major projects while nearly all of the work occurred during a worldwide pandemic.

4:15 PM - 4:45 PM

Thermoplastic Composite Pipe (TCP) is a potentially disruptive technology that combines light weight, high strength and excellent corrosion resistance in a material that can be spooled. Allied to a business case that can offer robust economics, TCP may offer the potential to reduce the carbon footprint of subsea pipelines with respect to conventional steel alternatives. This presentation will review Chevrons approach to TCP adoption including a summary of lessons learned from recent Chevron TCP deployments as well as a discussion of drivers for future deployments and a perspective on future qualification activities.

4:45 PM - 5:00 PM
To be announced
5:00 PM - 6:30 PM
Network with exhibitors and colleagues.
Thursday, March 3, 2022
7:00 AM - 8:00 AM
Don't skip the most important meal of the day.
8:00 AM - 8:30 AM

A new 2.2 MW subsea multiphase pump was installed and commissioned in LLOG’s Who Dat “E” field in January 2020. Within 30 days of startup the pump exhibited a failure which rendered it inoperable for continued service. The pump was subsequently retrieved, disassembled, and analyzed to identify the root cause of failure. The remediation plan currently in progress is the manufacture of a new pump cartridge that will be re-installed in 3Q2022. The presentation will touch on the original project execution and design basis, operating conditions, and diagnostics at time of failure, root cause analysis of pump failure, and the corrective actions and remediation plan going forward.

8:30 AM - 9:00 AM

While the development of subsea compression technology in deep-water advances a more efficient means of gas production, performing future intervention introduces new challenges to overcome. This gap has been recognized and a solution developed by configuring the Jansz-Io Subsea Compression Station layout to achieve any future intervention & interchangeability with no or minimal impact on production. The Greater Gorgon Development, including the Jansz-Io field, is located off the northwest coast of Western Australia. The primary objective of Jansz-Io Compression (J-IC) is to enhance the recoverability of the field and maintain long-term natural gas supply to the Gorgon liquefied natural gas (LNG) facility on Barrow Island through development of a Subsea Compression Station (SSCt), which utilizes three parallel subsea dry gas compressors. The SCSt has been developed based on a modular design philosophy where key elements are individually retrievable within modules for maintenance and repair. This approach allowed to meet challenges associated with: · Fabrication optimization (constructability and quality) · Testing · Installation · IMR and operation of process modules and control modules, as well as the total system availability Aker Solutions has developed the Horizontal Connection System (HCS) as their primary method for tie-ins systems & connection mechanisms. To facilitate the SCSt Modularization & Interchangeability objective, a unique version of the Horizontal Connection System has been designed so that the interconnecting spools between each module can slide horizontally, allowing the subject module to be retrieved without impacting the compression station’s operation continuity. The outcome of such design provides flexibility in operation and in future subsea intervention; allows the main process components to be independently retrievable; and takes into consideration the limited availability of intervention vessels in Western Australia. The lessons learned from the Åsgard Subsea Compression project were leveraged to define a suitable design for JIC-SCSt development, and to ensure that high reliability design requirements were safely achieved. This paper demonstrates how the challenges presented by the J-IC SCSt were met through a range of innovative engineering strategies which ensure safe execution and achieves the 50-year design life and high reliability requirements of the LNG development.

9:00 AM - 9:30 AM

Production at Julia was previously limited due to constraints on the Subsea Pump. In the event of a trip, the suction pressure would rapidly increase and potentially overcome the barrier fluid pressure resulting in a pump failure. A multi-disciplinary team collaborated to explore varying options to maximize production in the most efficient and cost effective way. The team ultimately decided to progress ‘Idle Flowline Accumulator (IFA)’ which included modeling the subsea system and performing multiple field trials to verify effectiveness. Julia has been successfully operating in IFA since April of 2021.

9:30 AM - 10:30 AM
Grab a cup of coffee and network.
10:30 AM - 12:00 PM

Panel on low carbon solutions, electrification, energy transformation. Roy Robinson of Excipio will present on energy transition as it relates to subsea; Rick Kopps of Chevron -will present on Janz Subsea Compression and/or subsea electrification; Herbert Prince Koelln of Petrobras will discuss low carbon subsea processing and how it will reduce carbon footprint; Julie Ingram of McDermott will present on McDermott’s R&D efforts related to ET from a subsea perspective.

12:00 PM - 1:00 PM
Lunch, Speaker Awards and Prize Drawing