EnQuest CEO Amjad Bseisu said:
"EnQuest is on track to achieve first oil from Kraken before the end of June and to deliver on its production, unit opex and capex targets for 2017. Our strategic priorities continue to be increasing production by delivering on operational and development execution, whilst also continuing to reduce the operating cost base. First production from the Kraken development will give EnQuest its seventh operated hub and will mark a turning point in EnQuest's progress from a period of heavy investment to one focused on cash generation and deleveraging the balance sheet.
EnQuest's proposed acquisition and operation of interests in the Magnus oil field and the Sullom Voe Terminal is on schedule for completion around the end of the year. This transaction recognises EnQuest's differential operational capability in managing mature assets and infrastructure, essential in the North Sea basin at this point in its evolution. Magnus will be EnQuest's eighth operated hub and provides the potential for significant future growth."
Production on a working interest basis
Net daily average
1 Jan' 2017 to
Net daily average
1 Jan' 2016 to
Performance update by individual production and development asset
All drilling is now complete on DC1 and DC2 and the rig has moved to DC3, where further excellent progress has been made on the drilling programme. Drilling performance to date has significantly de-risked delivery of the project to and beyond first oil.
DC1 and DC2 subsea commissioning is complete and ready for operation. The turret pipework and emergency shut down valves have been installed. Nitrogen/helium leak testing has been successfully conducted and the final rotation testing is complete. The boiler systems are running well and the water injection and HSP power pumps have been commissioned. Testing and other topsides and subsea infrastructure final commissioning work is ongoing. Handover of FPSO systems from commissioning to operations continues. Longstanding discussions with Bumi continue in relation to the remedies of Kraken partners for contractual infringements by Bumi.
At start up, 13 wells will be available comprising 7 producers and 6 injectors. As with all developments of this scale, wells will be brought onstream in a phased manner in line with good reservoir management practices aiming to maximise long term productivity and value.
The project continues to be under budget and on schedule.
Northern North Sea production
A programme improving the reliability of water injection is being implemented and is already having a positive impact.
The Don fields
Well performance has been particularly good at Don Southwest, with high levels of production efficiency across the Don fields.
The 2017 Heather/Broom production is progressing broadly according to plan.
Central North Sea production
Greater Kittiwake Area ('GKA') & Scolty/Crathes
The work programme in GKA for 2017 is focused on optimising production from the existing well stock including the Scolty and Crathes fields. Good production has been delivered from the GKA fields, with very high levels of plant uptime. Initial rates on Scolty and Crathes for H1 have been constrained due to operational issues. Work is currently ongoing to restore the rates.
As expected at the time of EnQuest's results announcement in March, 2017 production from Alma/Galia has been lower than 2016, given two wells are shut in, production outages in Q1 due to storm damage and natural decline. Discussions are ongoing with the ESP supplier on rectification plans to address pump reliability issues.
Production from Alba benefitted from the A49 well coming back online in March.
EnQuest is continuing to enhance production by investing in low cost well interventions and facility projects to improve production efficiency, including gas compression and power generation control system upgrades. In addition, robust maintenance and integrity inspection campaigns of platform structures, topsides, and subsea pipelines are continuing to ensure safe operations.
Longer term, EnQuest will extend field life through further investment in idle well restoration, facility improvements and upgrades and technical studies supporting development drilling, secondary recovery and capacity enhancement projects to increase ultimate recovery.
Focus remains on steady, safe and low cost operations in 2017. Tanjong Baram field has produced since December 2016 without an unplanned shutdown.
As at 30 April 2017, net debt was approximately $1,912m, including $28m additional 'payment in kind' interest since 31 December 2016. Cash and undrawn facilities totalled $244m.