TAMBAR
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General information
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Picture
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Discoveries included
Discoveries included Discovery name -
Activity status — history
Activity status — history StatusStatus fromStatus toProducing15.07.2001Approved for production03.04.200014.07.2001 -
Located in
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PDO – Plan for Development and Operations
PDO – Plan for Development and Operations Date PDO approvedDescriptionType03.04.2000Kongen i StatsrådPDO -
Ownership — full history
Ownership — full history Owner kindOwner nameOwnership from dateOwnership to datePRODUCTION LICENSE03.04.2000 -
Operatorship — full history
Operatorship — full history Company nameOperatorship fromOperatorship to30.11.201612.03.200229.11.201603.04.200011.03.2002 -
Licensees — full history
Licensees — full history Company nameNation codeCompany share [%]Date licensee fromDate licensee toNO55.00000019.12.2019NO45.00000019.12.2019NO55.00000021.05.201918.12.2019NO45.00000021.05.201918.12.2019NO55.00000030.11.201620.05.2019NO45.00000030.11.201620.05.2019NO55.00000006.09.200629.11.2016NO45.00000006.09.200629.11.2016NO55.00000017.04.200205.09.2006NO45.00000017.04.200205.09.2006NO55.00000019.03.200216.04.2002NO45.00000019.03.200216.04.2002NO55.00000012.03.200218.03.2002NO30.00000012.03.200218.03.2002NO15.00000012.03.200218.03.2002NO55.00000017.06.200111.03.2002NO30.00000017.06.200111.03.2002NO15.00000017.06.200111.03.2002NO55.00000010.05.200116.06.2001NO30.00000010.05.200116.06.2001NO15.00000010.05.200116.06.2001NO55.00000003.04.200009.05.2001NO30.00000003.04.200009.05.2001NO15.00000003.04.200009.05.2001 -
Description
Description TypeTextDate updatedDevelopmentTambar is a field in the southern part of the Norwegian sector in the North Sea, 16 kilometres southeast of the Ula field. The water depth is 70 metres. Tambar was discovered in 1983, and the plan for development and operation (PDO) was approved in 2000. The field has been developed with a remotely controlled wellhead platform tied-back to the Ula field. The production started in 2001.13.12.2023ReservoirTambar produces oil from Upper Jurassic shallow marine sandstone in the Ula Formation. The reservoir is at a depth of 4100-4200 metres and has generally very good quality.09.12.2023Recovery strategyThe field is produced by pressure depletion, with natural gas expansion combined with aquifer support. Gas lift is used to improve production performance.28.02.2023TransportThe oil is transported by pipeline to Ula. After processing at Ula, the oil is exported in the pipeline system via the Ekofisk field to Teesside in the UK, while the gas is injected into the Ula reservoir to improve oil recovery.28.02.2023StatusThe production is declining due to decreased reservoir pressure and increasing water cut.09.12.2023 -
Investments (expected)
Investments (expected) The operator's future investments related to the reserves from 2023 [mill NOK 2023-kroner]. The stated investment estimate has not been corrected for possible investment sharing.79 -
Investments (historical)
Investments (historical) Investments
[mill NOK nominal values]Sum4903202243202160820201612019152201868820178132016142015522014117201332012402011112010020090200891200739220062432005722004382003152002420019902000356 -
Production , saleable
Production , saleable MonthNet - oil
[mill Sm3]Net - gas
[bill Sm3]Net - condensate
[mill Sm3]Net - NGL
[mill Sm3]Net - oil equivalents
[mill Sm3]Sum11.7257940.0000000.0000000.59595212.3217460.0655880.0000000.0000000.0034720.0690600.1572670.0000000.0000000.0062880.1635550.0968930.0000000.0000000.0060680.1029610.1984770.0000000.0000000.0078610.2063380.2528320.0000000.0000000.0134980.2663300.2171720.0000000.0000000.0087430.2259150.3316010.0000000.0000000.0160800.3476810.1908730.0000000.0000000.0090850.1999580.2221500.0000000.0000000.0102470.2323970.2526810.0000000.0000000.0113370.2640180.3335640.0000000.0000000.0138110.3473750.2396120.0000000.0000000.0098060.2494180.2255510.0000000.0000000.0095770.2351280.2903960.0000000.0000000.0114550.3018510.2848500.0000000.0000000.0127340.2975840.3409020.0000000.0000000.0161770.3570790.5913330.0000000.0000000.0374980.6288310.6498650.0000000.0000000.0365860.6864510.9355200.0000000.0000000.0556730.9911931.2403040.0000000.0000000.0696711.3099750.8835630.0000000.0000000.0460270.9295901.4633330.0000000.0000000.0718581.5351911.7264890.0000000.0000000.0872381.8137270.5349780.0000000.0000000.0251620.560140 -
Production , sum wellbores
Production , sum wellbores MonthGross - oil
[mill Sm3]Gross - gas
[bill Sm3]Gross - condensate
[mill Sm3]Gross - oil equivalents
[mill Sm3]Sum12.1504292.5379730.00000014.6884020.0700450.0124710.0000000.0825160.1658480.0255830.0000000.1914310.1140560.0228500.0000000.1369060.2099890.0379680.0000000.2479570.2740340.0476860.0000000.3217200.2323420.0381650.0000000.2705070.3674050.0601220.0000000.4275270.2108540.0336030.0000000.2444570.2437720.0402220.0000000.2839940.2755980.0507810.0000000.3263790.3619550.0604760.0000000.4224310.2595160.0416310.0000000.3011470.2430450.0364960.0000000.2795410.3059840.0477450.0000000.3537290.3020940.0541860.0000000.3562800.3670670.0863360.0000000.4534030.6378930.1240420.0000000.7619350.6955090.1311410.0000000.8266500.9626920.2181720.0000001.1808641.2392260.2983830.0000001.5376090.8834040.2064910.0000001.0898951.4629990.3405710.0000001.8035701.7298970.3988240.0000002.1287210.5352050.1240280.0000000.659233 -
Production – charts
Production – charts Production – charts Production – charts Production – charts Production – charts Production – charts Any produced water is only included after 1.1.2000 -
Wellbores – exploration
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Wellbores – development
Wellbores – development Wellbore nameEntered dateCompleted datePurposeContent08.05.199831.07.1998PRODUCTIONOIL02.01.201819.01.2018OBSERVATIONNOT APPLICABLE20.01.201826.01.2018PRODUCTIONOIL03.03.202130.03.2021PRODUCTIONOIL08.09.200124.10.2001PRODUCTIONOIL06.11.201715.12.2017PRODUCTIONOIL06.06.200118.08.2001PRODUCTIONOIL -
Wellbores – other
Wellbores – other Wellbore nameEntered dateCompleted datePurposeStatus