Page 11 - EurOil Week 25

EurOil
NEWS IN BRIEF
EurOil
Aker BP given drill permit offshore Norway
e Norwegian Petroleum Directorate (NPD) has granted Aker BP ASA a drilling permit for well 6608/6-1.
Well 6608/6-1 will be drilled from the Deepsea Stavanger drilling facility in position 66 30`2.69 N and 08 56`19.27 E.
e drilling programme for well 6608/6- 1 relates to the drilling of a wildcat well in production licence 762. Aker BP ASA is the operator with an ownership interest of 20 per cent.
e other licensees are Equinor Energy AS with 60 per cent and Petoro AS with 20 per cent. e area in this licence consists of parts of blocks 6608/6, 6608/9, 6609/4 and 6609/7. e well will be drilled about 60 kilometres northeast of the Norne eld.
Production licence 762 was awarded on 7 February 2014 in APA 2013. is is the rst exploration well to be drilled in the licence.
e permit is contingent on the operator securing all other permits and consents required by other authorities prior to commencing the drilling activity.
June 20 2019
NPD publishes Norwegian output figures for May
Preliminary production gures for May 2019 show that Norway produced 1.6 million bpd of oil, NGL and condensate, some120,000 bpd lower than in April.
Total gas sales were 9.9bn cubic metres, marking a 0.1bcm decline m/m. Average
daily liquids production in May was 1.25mn bpd, 319,00bpd of NGL and 29,000bpd of condensate. Oil production in May was 5.4% lower than the NPD’s forecast, and 2.5% below the forecast so far this year.
e main reasons that production in May was below forecast is technical problems and maintenance work on some elds.
June 20 2019
Lundin completes wells at
North Sea’s Edvard Grieg
field
Lundin Norway AS, operator of production licence 338, has completed the drilling of exploration wells 16/1-31 S and 16/1-31 A.
e wells were classi ed as wildcat wells,
but are now being reclassi ed as appraisal wells.
e wells were drilled about 4km northeast of the Edvard Grieg platform in the central part of the North Sea, 190km west of Stavanger.
e Edvard Grieg eld was proven in reservoir rocks from the Cretaceous, Jurassic and Triassic Ages in 2007, and started production in 2015. Prior to drilling these appraisal wells, the operator had estimated reserves at between 34 and 54mn cubic metres of recoverable oil equivalents.
e objective of the wells was to prove oil in conglomerates from the Triassic Age in an extension of the Edvard Grieg basin (16/1-31 S) toward the east and in fractured and porous granitic basement rocks northeast of the eld (16/1-31 A).
16/1-31 S encountered an oil column
of about 29 metres in conglomerates and conglomeratic sandstone, presumably from the Triassic Age and with generally poor reservoir quality. ere is around one metre of sandstone of good quality in the upper part of the reservoir. e oil/water contact was not proven. Pressure measurements show that the reservoir is in communication with the Edvard Grieg eld.
Preliminary estimates of the size of the additional resources are between 0.5 and 3.5mcm of recoverable oil and up to 0,35bn cubic metres of gas. e licensees will assess a development to the Edvard Grieg platform.
Several formation tests have been carried out. e production rate from formation test (DST) was 20 cubic metres of oil per ow day through a 26/64-inch nozzle opening. e oil is undersaturated with an estimated gas/oil ratio of 125 Sm3/Sm3.
e formation tests show mainly poor ow properties in the conglomeratic part of the reservoir. e injection test yielded stable rates of 2000 cubic metres per
day, which is probably due to fracturing and communication with the overlying sandstone. A small-scale formation test in the overlying sandstone reveals good ow properties.
Well 16/1-31 A encountered an oil column of about 62 metres in fractured and weathered basement rock of generally poor reservoir quality. e oil/water contact is estimated at between 1910 and 1912 metres below the sea surface. Small-scale formation tests (mini-DST) show poor to moderate ow properties.
Preliminary estimates of the size of the additional resources are between 0.1 and 2 mcm recoverable oil and up to 0.2 bcm of gas. e licensees will assess a development to the Edvard Grieg platform.
Signi cant data has been collected and samples have been taken in the two wells. ese are exploration wells number 13 and 14 in production licence 338. e licence was awarded in APA 2004.
Wells 16/1-31 S and 16/1-31 A were drilled to respective vertical depths of 2123 and 1977 metres below the sea surface, equivalent to 2195 and 2625 metres measured depth, and were terminated in conglomerate and granitic basement. e wells will be permanently plugged and abandoned. Water depth at the site is 111 metres.
e wells were drilled by the Leiv Eiriksson drilling facility, which will now drill shallow gas pilot wells in production licence 359 in the North Sea, where Lundin Norway AS is the operator.
June 20 2019
Croatia, Hungary eyes gas market co-operation
Croatia and Hungary have set up a working group to explore the scope for their cooperation in the natural gas market, the Zagreb government has announced.
e working group, which will involve Croatian and Hungarian experts, will weigh up the value of this cooperation in the coming months, Croatian Energy Minister Tomislav Coric was quoted as saying in a statement. He spoke a er a meeting with Hungarian Foreign Minister Peter Szijjarto. e working group will also comprise representatives of the two countries’ national market regulators and gas transmission system operators (TSOs).
Hungary is eyeing a 25% stake in an LNG import terminal that is under development on the Croatian island of Krk.
“Such cooperation could create market conditions, in which the purchase of LNG via this terminal would be economically feasible and competitive for us,” Szijjarto said.
In October, the ministry revealed that Hungary was interested in buying 1.7 billion cubic metres of gas per year from
the terminal, slated to start up in December 2019. e project is supported by a 101.4mn euro ($114.6mn) grant issued by the EU
in December 2017. Under its rst phase,
the facility will serve as an o shore oating storage and regasi cation unit capable of taking the equivalent of 2 bcm of LNG per year. Its total cost is 383.6mn euros ($436mn).
June 21 2019
Week 25 27•June•2019
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