The ‘Pseudo’ Dry Gas (PDG) subsea concept is being developed to dramatically improve the efficiency of subsea gas transportation by removing fluids at the earliest point of accumulation. The technology will increase the geographical reach from receiving gas terminals, allowing asset owners to prolong production life without the need for more expensive design solutions. This paper will provide an overview of the innovative technology, demonstrating that a 200 km plus tie back can be achieved, without compression.
Increasing the distance of subsea tie-backs increases the liquid inventory, with constraints on pipeline diameter for slug free flow. The PDG concept is based on a main gas line integrated with piggable gravity powered drain liquid removal unit and pumps (a smaller fluid line transports separated liquid). Multiple units are specified to drain liquids as they condense in the line, maintaining near dry service. Liquid free operation removes the constraint on pipeline diameter. Specification of a large diameter pipe (within installation limits) reduces backpressure on the wells, enhancing recovery. Minimum stable flow limits are removed, improving tail end recovery.
Current stranded gas development options (subsea compression, floating facilities, FLNG) generate a step change in costs which can make a project uneconomic. This is even more acute in mature and semi-mature basins where existing gas processing facilities / LNG terminals already exist offshore or onshore along with sunk costs from the exploration. A case study for a 185 km pseudo dry gas subsea tie-back to shore demonstrates the PDG concept feasibility. This result is used to argue that the PDG concept should be included in the suite of subsea processing options considered by Operators in early field development planning.
Petrobras and Shell have brought online the Lula field’s seventh FPSO as the firms continue to ramp up production from the pre-salt Santos Basin. The French major is racking up barrels of deepwater production as part of its large-scale West African push. This paper describes how a technique known as applied-surface-backpressure managed-pressure drilling (ASBP-MPD) can alleviate the limitations of conventional deepwater well control. Majors BP and Chevron have overcome development challenges and delays to launch their respective Clair Ridge and Big Foot projects. The unit is flowing oil and gas from the Lula Extremo Sul area, 290 km off Rio de Janeiro state in 2150 m of water.
The shale revolution is leading the US into a unique position: a bigger exporter of crude and petroleum liquids than the Kingdom of Saudi Arabia. Current production from the phase is 400 MMcf/D and expected to peak at 700 MMcf/D. A third phase also is slated to come on stream this year. Facilities Piping Inspection: Is Direct Assessment Enough? Tons of resources are devoted to assure the integrity of facility piping systems, but are the generally accepted methods of inspecting these systems the best way?
Woodside awarded Subsea 7 three contracts since December 2018, each for engineering studies and incl ... The Abu Dhabi National Oil Company (ADNOC) has awarded South Korea’s SK Engineering and Construction ... BP has contracted with i-Tech Services for subsea construction, inspection, repair, and maintenance ... McDermott International announced a “large” contract award from Saudi Aramco for the engineering, pr ... DCN Diving has received a contract from Dana Petroleum to execute work offshore the Netherlands.
The US majors plan to produce around 1 million BOE/D each from the basin, which has become a primary focus of their upstream operations. Two new centers in Bergen, Norway will lean on emerging digital technology to oversee much of the Norwegian operator’s offshore operations. The objective of this case study is to describe a specific approach to establishing an exploration strategy at the initial stage on the basis of not only uncertainty reduction, but also early business-case development and maximization of future economic value. Creativity and innovation have long characterized production and facilities, and this year is no exception. This paper focuses on compressor systems associated with major production deferments.
BP Trinidad and Tobago began first gas production from its Angelin development on 26 February. Subsea Production Systems—Will 2019 Be a Tipping Point? The past year ended with a surge of subsea tree awards as E&P operators locked in lower supply-chain cost. Will demand continue to grow in 2019 and allow subsea OEMs to build backlogs and take back pricing power? Current production from the phase is 400 MMcf/D and expected to peak at 700 MMcf/D.
A newly launched JIP aims to bridge the BSEE and API frameworks and achieve industry consensus on the analysis and inspection data required to assess the feasibility of an extended service life. Inspection data management system software can help companies bolster their mechanical integrity programs, but choosing the wrong software can have a lasting impact on a company’s operations. So, what goes into finding the right software for your needs? Trendsetter Engineering completed its 2-year design and build work for Noble Energy’s Leviathan project. Saipem is taking the lead in advancing the capabilities of FlatFish, an autonomous underwater vehicle being developed by Shell for commercial application by 2020.
Africa (Sub-Sahara) Vaalco Energy started oil production from the Etame 12-H development well offshore Gabon. The well was drilled to a measured depth of approximately 3450 m and was targeting the recently discovered lower lobe of the Gamba reservoir. It was brought on line at a rate of 2,000 BOPD with no indication of hydrogen sulfide. Vaalco (28.07%) is the operator with partners Addax Petroleum (31.63%), Sasol (27.75%), The well will reach a total depth at 5,462 ft and will test Early Miocene stacked fluvial sandstones on a broad structural high. The well will also appraise the Rossukon-1 reservoir, which produced 850 BOPD during tests. KrisEnergy (30%) is the operator with partners Northern Gulf Petroleum(40%) and Mubadala Petroleum (30%).
Africa (Sub-Sahara) ExxonMobil subsidiary Esso Exploration Angola has started oil production at the Kizomba Satellites Phase 2 project offshore Angola. The project involves the development of subsea infrastructure for the Kakocha, Bavuca, and Mondo South fields. Mondo South is the first field to begin production, and the other two satellite fields will follow later this year. The goal is to increase Block 15's production to 350,000 BOPD. Esso (40%) is the operator with BP Exploration Angola (26.67%), Kosmos Energy discovered gas at the Tortue West prospect in Block C-8 offshore Mauritania.
Africa (Sub-Sahara) Tullow's Cheptuket-1 well in Block 12A of northern Kenya has encountered good oil shows over an almost 2,300‑ft interval, the company reported. The first well to test the Kerio Valley Basin, Cheptuket-1 was drilled to a final depth of 10,114 ft. The results indicate the presence of an active petroleum system with significant oil generation, the company said. Post-well analysis now under way will affect future basin exploration decisions. Delonex Energy (40%) and Africa Oil (20%) are the other participants. Asia Pacific Rosneft has spudded the PLDD‑1X exploration well in Block 06.1 of Vietnam's Nam Con Son Basin, the first Rosneft-operated international offshore drilling project.