Harkand named Alan White as head of engineering services in Europe, where he will oversee a 40-person team as the company expands its capabilities in the region. White has more than 20 years of experience in subsea construction and project management, having worked for other major contractors on subsea pipeline scopes of work from design to fabrication and delivery in the North Sea. He will be based in Aberdeen at the company's European headquarters.
In 2016, Malaysia Petroleum Management (MPM), the regulatory body of PETRONAS launched a 3 year dedicated strategy to intensify the idle wells restoration and production enhancement activities in order to maximize profitability through efficiency and success rate improvement. The basis of this strategy is the risk-sharing integrated operations in which the industry embraced it in all major well intervention activities. As the drilling activities dropped drastically over the past few years, it was crucial that the well intervention activities are carried out with high efficiency and success rate to restore the production.
The strategy went through various development changes throughout the 3 year journey. As the well intervention scope covers a wide range of activities, the framework of this integrated risk sharing mechanism provided the flexibility that is required for the execution of the various scopes and meet specific value targets either profitability from production gain or cost saving from decommissioning and infill drilling. Each of the project carried unique Key Performance Indicators (KPIs) as the guiding principles to drive the efficiency improvement that was required. A unique process called Total Wells Management (TWM) was implemented as the overlaying guide to further improve the uncertainty of subsurface challenges, operation optimization and commercial risk exposure.
This paper outlines the overall post mortem analysis of the 22 projects that were executed under this integrated operations strategy between MPM, ten operators and five main service companies. This strategy, known to the industry as the Integrated Idle Wells Restoration (IIWR) program, has become the new norm on how well intervention and subsurface assessments are executed to yield the best results especially in late life fields. The risk sharing integrated framework have proven to be a win-win scenario for all involved parties. The scope was also extended to cover non production adding activities such as wells decommissioning, well startups and pre drilling zonal isolation. IIWR have also opened up the opportunities for many ‘first in Malaysia’ projects such as the first subsea hydraulic intervention, first subsea decommissioning and also the reinstatement of technologies such as coiled tubing catenary. The biggest impact from this 3 years strategy implementation can be seen from the Unit Enhancement Cost (UEC) improvement where the average UEC was reduced from 14 to 17 USD per barrel of oil to about 4 to 7 USD barrel of oil.
Although there were major challenges, the overall results have been very encouraging. This framework is also being replicated for drilling and completion activities as well. Specific to well intervention, this IIWR framework is currently being put through an enhancement process to further expand the landscape of well intervention activities without compromising safety, operational efficiency and business profitability.
ABB is running a joint project with Equinor, Total and Chevron to develop technologies for subsea power transmission, distribution and conversion. The output will form a critical part of future advanced subsea field developments. As such an undertaking has never been achieved before, it is a journey with considerable learnings to be shared not only upon completion (anticipated by the end of 2019) but also en route.
The paper will describe steps taken to build confidence along the way that the proposed solution will be fit for purpose when fully launched. Readers will gain insights into the key steps of this cutting-edge project. These include modifying prototypes of the equipment based on rounds of simulations, laboratory assessments (eg accelerated aging, vibration and shock testing) and water testing. Insight will be provided on tedious testing and qualification effort required to achieve the technology readiness level (TRL) required.
Readers will learn from the challenges experienced in this ground-breaking project and how they were overcome. Insight will be given into the overall challenge of both research/development and qualification of the novel technology developed in the JIP. Findings from testing, including extensive lab testing against industry standards, and the impact on subsequent development will be presented. The paper will eventually share results from extensive joint research work between the partners and ABB. The results are ground breaking and will by the end of the day introduce completely new opportunities for development of subsea fields.
As a first-of-kind-project, the results gained, and the subsequent technology developed will be of considerable interest to the industry. By the end of the day, the results from this project will be a key enabler for the subsea factory vision envisioned by the industry.
Shell in the UK has a vast network of more than 200 pipelines & umbilicals covering some 3000 kilometres. Historically, Shell has executed Side Scan Sonar Surveys along these pipelines using a Remotely Operated Towed Vehicle and subsequently followed up with ROV based surveys & inspections. However, in 2018, the respective Geomatics & Subsea Maintenance / Pipelines Departments decided to take advantage of new & emerging innovative technologies and compiled a minimal technical scope & tender document to tap into the latest that the market could offer. Consequently, Shell UK awarded DeepOcean (Norway) with a contract for their "Fast Digital Imaging Service" and embarked on a 45 day survey campaign. In 2019, the same subsea inspection project will be executed once again and the lessons learned ought to inspire and excite many different disciplines and communities, both internally within Shell and externally e.g OGA - Oil & Gas Authority & other valued stakeholders. The paper highlights the key technologies that were deployed and how the new deliverables & business insights take us down the road to Digitalisation including scope for future Machine Learning & Automation processes. Challenges arising from the acquisition and managing the associated data sets shall also be discussed. The speaker will spark dialogue at the end by asking the respective communities how robotics and artificial intelligence will change the industry landscape?
Subsea pipeline decommissioning for either abandonment or retrieval is hazardous for both divers and the marine environment. This presentation reports on the development of a Fast Intervention Tool (FIT) for pipeline decommissioning by Webtool with input from Chevron Energy Technology Company. The FIT reduces the risks to divers and enables a quicker operation while avoiding the need for a containment dome during pipeline cutting and retrieval.
Sophisticated measures are taken to reduce the hazards to divers and the impact on the marine environment during pipeline decommissioning. Yet, traditional cutting technologies can undermine these best intentions. Diamond wire or other types of saw are time consuming and prone to jamming as the pipe moves during the cut. The containment dome used to catch contaminants that leach out during cutting and retrieval cannot "follow" the pipe as it is retrieved via a crane, therefore additional measures are needed to plug or seal to the pipe end before retrieval. The Fast Intervention Tool presented here addresses these shortcomings.
The FIT combines lifting, crimping, injection and cutting in a single deployment frame which also contains the hydraulic control system. Deployed using a barge crane, the FIT assembly is lowered over a pipeline on the seabed, with either a diver or ROV to position it. The FIT cycle time to lift, crimp, inject sealant and cut is under 1 hour (excluding vessel or set up time) after which the pipe can now be safely recovered topside without leakage. The spike injector and blades will perform a number of cycles, therefore running costs are low; the only major consumable cost is the sealant itself. Webtool has completed FIT conceptual design and in-house development and testing and is now preparing a working prototype for hyperbaric and sea trials.
Safer and more environmentally friendly method of pipeline decommissioning.
Digital technologies serve as a primary theme of this year’s group, with a few environmentally conscious firms included in the mix. The well will immediately be brought on production and is expected to flow at more than 100 MMscf/D of gas and 3,000 B/D of associated condensate, the company said. The main goal of production logging is to evaluate the well or reservoir performance. The shale sector is studying the results of a 23-well experiment in the southeastern corner of New Mexico to learn what the wider implications might be. The shale sector is making moves to consolidate amid investor pressure to increase cash flow.
Autonomous underwater vehicles (AUVs) have demonstrated their capabilities during the search for Malaysian Airlines flight 370 in the Indian Ocean. Robotic submarines, capable of operating by themselves thousands of feet underwater for months or perhaps years at a time, are under development as the vanguard of tomorrow’s subsea oil and gas fields.
The Health and Safety Executive, a UK safety authority, has served BP with an improvement notice regarding its training for lifeboat evacuation on the Glen Lyon floating production vessel, west of Shetland. Cutting-edge computing and subsea wireless camera technology deployed on a pipeline construction project enhanced diver safety and generated significant cost savings by avoiding the need for additional subsea vessels. The oil and gas industry is marking 10 years since a Bond Super Puma helicopter came down 12 miles off the coast of Peterhead, Scotland, killing all 14 passengers and two crew members. In 2015 and 2016, the Health and Safety Working Group of the North Sea Offshore Authorities Forum discussed common challenges for the oil and gas industry. The challenges related to maintaining and operating aging installations in a low-oil-price environment was selected as a topic for further work.
The complete paper presents and discusses the authors’ technology-development program regarding very-long oil-tieback architectures (50–100 km) and enabling technologies. When two engineers lost their jobs during the industry downturn, they used the misfortune as an opportunity to develop an innovative concept that aims to make it a lot easier to move subsea gas long distances.
Obstacles remain to keeping offshore development competitive with its onshore counterpart. Can the industry advance technology at a pace where the subsea segment will see a resurgence? Reducing the complexity and controlling the cost of major offshore projects are together one of the biggest challenges facing the oil and gas industry. There is no shortage of ideas for reducing the cost and risk of offshore oil and gas developments. The hard part is implementing them in an industry where they require changes in long-standing habits, corporate cultures, and some new technology.