The SPE has split the former "Management & Information" technical discipline into two new technical discplines:
- Data Science & Engineering Analytics
The SPE has split the former "Management & Information" technical discipline into two new technical discplines:
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Abstract The objective of the R&D project and subsequent field testing was to develop, test and commercialize a new technology with an emphasis on scanning speed for use in subsea flowlines to detect hydrate plugs through thick subsea coatings without the need for 360-degree access of the pipe. Acoustic Resonance Technology has proven to be an extremely reliable and accurate way to measure wall thickness of coated flowlines and risers with insulations thicknesses of 90+ mm. While advancing the use of Acoustic Resonance Technology for pipe-in-pipe applications, it was theorized that the resonant frequencies would be able to detect the unique acoustic signature of hydrate formation within a pipe. The client initiated an R&D project to test the use of Acoustic Resonance Technology on hydrate formations in a lab setting. The testing showed a clear indication of hydrate acoustic signatures while only needing access to the top half of the pipe. The client moved to a field test on a 12 km flowline off the coast of Angola. The offshore field test was completed on an 8-inch 3-Layer polypropylene (3LPP) coated water injection line at a water depth of 1,300 m off the west coast of Angola. The tool scanned 12 km of pipe within 33 hours and identified the length of the hydrate plug. A second tool was launched to complete a 360 degree scan to define exact start and end points of the hydrate plug. Client achieved a significant cost savings compared to comparable methods due to inspection speed and a reduction in pre-inspection dredging time. This paper will show how field proven technologies, in particular Acoustic Resonance Technology, can be adapted for new uses within the subsea industry. The testing and field work shown in this paper will provide evidence of a faster and more efficient way to detect and measure hydrate formations compared to existing technologies on the market.
TechnipFMC has been awarded a significant contract to supply flexible pipe and associated hardware for the first subsea life extension project by TotalEnergies EP Angola and its Block 17 Partners in West Africa. The contractor defines "significant" as a contract valued between 75 million and 250 million. The contract covers the engineering, procurement, and supply of flowlines and connectors for the Girassol Life Extension project offshore Angola. The flexible pipes will extend the life of the Girassol field by bypassing the rigid pipe bundles installed before production began in 2001. The Girassol project is located within Block 17, about 210 km north-northwest of Luanda, Angola.
Russo, Massimiliano (Kongsberg) | Nagalingam, Krishna Kumar (Kongsberg) | Haakonsen, Rune (Kongsberg) | Loftager, Rune | Puskarskij, Konstantin (Noble Drilling)
Abstract This paper details the successful validation process of advanced DP (Dynamic Positioning) and power management tools and solutions through processing big data from offshore drilling operations. Along with outlining the technical details behind the validation process, the paper also describes how these advanced tools can be applied to pursuing industry sustainability goals by reducing the environmental footprint of offshore drilling operations. Implementation of such a validation process will aid drilling operators to select and prioritize among different emission-reducing technologies and by that ensure that the installed solutions are suitable for the operation. The validation mechanism is based on retrieving cloud-stored rig sensor data from the 7th generation drillship operating offshore Angola. The data processing section of the study included data normalization by removing abnormalities in order to establish clean baseline operational parameters to be reproduced by the use of the marine, drilling, and power plant simulators. The combined wind, wave, and climate (metocean) conditions for the entire period were also established and mapped. After validation of the analytical model accuracy, the model was advanced with several layers of advanced DP and power management functionalities in addition to energy storage tools and solutions to evaluate efficiency gains from deploying them individually and combined. Finally, the paper provides a comparison of efficiency gains (versus the clean baseline analytical model), deploying the said tools and solutions where the efficiencies are detailed as an amount of saved fuel, reduced GHG (Greenhouse Gas) emissions, and also reduction of maintenance burden on propulsion and power plant machinery.
Azule Energy recently checked several big-ticket items off its shopping list for its Agogo Integrated West Hub project as the BP-Eni joint venture partnership awarded 7.8 billion in contracts. Multiple contractors secured work on the development project that is set to expand the footprint and increase the production of the Agogo oilfield in the West Hub production area in Block 15/06 located about 110 miles offshore Angola. The project is comprised of 36 new wells: 21 production wells and 15 injection wells. The work package includes 23 subsea trees, 11 manifolds, hundreds of miles of flowlines and umbilicals, and a converted floating production storage and offloading vessel (FPSO) with a production capacity of 120,000 BPD of oil production, 230 MMFSCFD of gas injection, and 120,000 BPD of water injection. The Agogo Integrated West Hub will produce hydrocarbons from the Agogo and Ndungu fields via both the existing FPSO Ngoma and the new FPSO Agogo that will be operational in 2026, reaching a peak of production of 175,000 BPD.
Abstract The objective of this study is to understand the configuration of different deformation styles in post-salt sedimentary succession of Lower Congo Basin. Emphasis is placed on structural characteristics with respect to the thickness of salt and the geometry of the base of salt detachment. Owing to its weak visco-plastic properties, salt is very effective at decoupling deformation in pre- and post-salt sequences. Gravity and density driven deformation in the post-salt sediments is predominately controlled by salt thickness and changes in dip at the base of salt. Variations in these elements change across the basin which control the nature and timing of trap development. Using regional 2D and 3D seismic depth cubes, interpretation focused on the Aptian Salt and post-salt Cretaceous-Tertiary sedimentary succession. Here we map and identify various deformation styles in salt tectonics across the basin within which we observe consistent trap geometries which are containing hydrocarbons and resulting one of the prolific basins in the world for oil production. The post-salt sediments, present a classic example of gravity driven deformation associated with salt tectonics at a passive margin. Gravity driven structuration of (i) Extension, (ii) Translation and (iii) Compression can be observed along regional dip-sections. Through detailed mapping, various sub-domains provide an insight into the regional structural trends and tectonic evolution in the post-salt succession. Overall, ten structural domains have been identified from Shelf to distal basin along the regional dip section. Well defined structural domains can play a major role in classifying the trapping styles for hydrocarbon accumulations in post-salt successions. Identification of these domains provides a framework to de-risk different trap styles or highlights those traps which carry a higher trap risk. Timing of trap formation due to salt movement also plays a major role to further de-risk these traps. The main source rock for Post-salt section is located in Senonian interval, the charge modelling suggests the peak expulsion of hydrocarbon in Early Miocene time, therefore those traps formed in Oligocene to Early Miocene intervals have higher chance of trapping hydrocarbons, however traps formed from Mid – Miocene to younger levels have higher risk of trapping smaller or no hydrocarbons due to lack of charge availability.
ExxonMobil has made a new oil discovery with the Bavuca South-1 exploration well in Block 15 offshore Angola. The well is part of the Angola Block 15 redevelopment project targeting to deliver around 40,000 B/D of new oil production. According to ExxonMobil, the well encountered 30 m of hydrocarbon-bearing sandstone. The probe is located approximately 365 km northwest of Luanda and was drilled in 1100 m of water by the Valaris DS-9 rig. As the block's operator, ExxonMobil is leading the installation of new technology and a multiyear drilling program aimed at adding new production volumes to help offset natural production declines.
The transformation of an oil platform into an artificial reef is underway in Angola. The platform is the first in Africa to be decommissioned in a project led by environmental quality services company EQS with a Saab Seaeye Falcon underwater robot deployed for the task. "By operating the Seaeye Falcon and all its related capabilities, EQS is supporting its aim to fulfil specific works in a safe and cost-effective manner, delivering accurate and relevant information," said Carlos Rodrigues, chief technical officer at EQS. The Falcon is assisting in the survey and mapping of all underwater components, including checking the wellhead, pipelines, and surrounding maritime environment. Baseline environmental conditions are determined by taking water and sediment samples at several stations and at different depths, focusing on biological matter, namely zooplankton, phytoplankton, and benthos.
A step change is noticeable in the quality of papers from the previous 2 years. First, the papers have better technical content; second, they are pushing the boundaries of currently accepted technologies and mores. Perhaps this is because of a desire to produce from ever-more-difficult and -challenging wells. The current energy crisis and higher prices as a result have encouraged the application of new technology, which, in a low-energy-price environment, generally takes a back seat. This is a good thing for the technology junkies of this world. A few technology areas are worth mentioning. Although ceramic sand screens have been around for a few years, this year there were more than the usual number of papers on this technology. For those interested in probing the operating limits and life span of these screens, paper OTC 31896 is worth reading. Sand consolidation continues to be a subject of interest, perhaps because of its noninvasive nature. Besides, it is potentially low-cost and has been used widely with success. This year, there were 10 papers on the subject. An interesting paper worthy of mention is SPE 208808, which introduces a novel temperature-activated, “green” consolidation fluid. In paper SPE 207193, the authors propose a fast and accurate machine-learning algorithm to predict the onset of sanding in sandstone formations. The algorithm uses 11 geological and reservoir parameters that directly affect sand production. The answer is binary (i.e., sand production will or will not occur). This could be a great tool for completion engineers. Finally, there was extensive coverage of sand management in the topsides, an area often overlooked. This trend is encouraging. Paper OTC 31554 is thought-provoking. It discusses the first field installation of a patented device that modifies the flow profile to alleviate the impact of solids at critical points. I hope you enjoy the papers. Recommended additional reading at OnePetro: www.onepetro.org. OTC 31872 Improving Erosion Wear Life of Completion Equipment in High-Flow-Rate Conditions by Numerical Design Optimization for Influx Equalization by Gocha G. Chochua, Schlumberger, et al. SPE 208839 Completion Standardization Using Conformable Sand-Screen Technology in Multilayered Ultrafine Sand Reservoir by Ricardo Gomez Simancas, Cabinda Gulf Oil, et al. SPE 208845 A Comprehensive Review of Sand-Retention Test Methods and Data Analysis With a Focus on Application by Tanner Linden, Constien and Associates, et al.
French major TotalEnergies has tapped McDermott International for engineering, procurement, supply, construction, installation (EPSCI), precommissioning, and assistance to commissioning and startup on its Begonia Project in Angola Block 17/06. The Begonia field is in water depths between 400 and 750 m and will produce hydrocarbons via a subsea-to-subsea tieback to an existing floating production, storage, and offloading (FPSO) unit, Pazflor. McDermott will provide all EPSCI services for subsea umbilicals and water-injection and production flowlines. There are three production wells in total which are gathered through a multiphase production flowline, approximately 12 miles (20 km) in length. The two water-injection wells are connected back to an existing riser.
Italy's Eni and its partners in the New Gas Consortium (NGC), together with Angolan concessionaire and regulator, the National Agency for Oil, Gas and Biofuels, have reached a final investment decision (FID) on Angola's first nonassociated gas project, Quiluma and Maboqueiro (Q&M). Eni has held a 25.6% operator interest in NGC but will now be joined by BP (11.8%) as co-operator as the two companies' merge their Angolan businesses to create the 50/50 Azule Energy joint venture (JV), Angola's newest and largest independent oil and gas producer. The Q&M project aims to produce 4 Bcm per year of gas (330 MMscf/D at plateau) from two offshore wellhead platforms. The project also includes an onshore gas processing plant and a connection to the Angola LNG (ALNG) facility to enable marketing of condensate and gas as LNG cargos. Construction will start this year, with first gas expected in 2026.