MARTIN LINGE

hide details Export:  PDF

• General information

  General information

  Attribute	Value
  Field name Official field name	MARTIN LINGE
  Factmaps in new window	link to map
  Current activity status Current activity status of the field. Example of legal values: SHUT DOWN, PRODUCING, PDO APPROVED	Producing
  Discovery wellbore Name of the wellbore which proved the field.	30/7-6 R
  Discovery year. The year the field was discovered	1978
  Main area Main NCS area. Example of legal values: NORTH SEA, NORWEGIAN SEA, BARENTS SEA	North sea
  Main supply base Main supply base	Tananger/Dusavik
  NPDID field Norwegian Offshore Directorate's unique id for fields	21675447

• Picture

  Picture

• Discoveries included

  Discoveries included

  Discovery name
  30/4-3 S
  30/7-2
  30/7-6 Martin Linge
  29/6-1

• Activity status — history

  Activity status — history

  Status	Status from	Status to
  Producing	30.06.2021
  Approved for production	11.06.2012	29.06.2021

• Located in

  Located in

  Block name	Prod. licence
  29/6	043
  30/4	043
  30/7	040
  29/6	043 BS
  29/9	040
  30/4	043 BS

• PDO – Plan for Development and Operations

  PDO – Plan for Development and Operations

  Date PDO approved	Description	Type
  03.07.2017	PUD fritak Herja/Herv	PDO
  11.06.2012	Behandlet i Stortinget	PDO

• Ownership — full history

  Ownership — full history

  Owner kind	Owner name	Ownership from date	Ownership to date
  BUSINESS ARRANGEMENT AREA	MARTIN LINGE UNIT	11.06.2012

• Operatorship — full history

  Operatorship — full history

  Company name	Operatorship from	Operatorship to
  Equinor Energy AS	16.05.2018
  Statoil Petroleum AS	19.03.2018	15.05.2018
  Total E&P Norge AS	11.06.2012	18.03.2018

• Licensees — full history

  Licensees — full history

  Company name	Nation code	Company share [%]	Date licensee from	Date licensee to
  Equinor Energy AS	NO	51.000000	30.09.2022
  Petoro AS	NO	30.000000	30.09.2022
  Sval Energi AS	NO	19.000000	30.09.2022
  Equinor Energy AS	NO	70.000000	16.05.2018	29.09.2022
  Petoro AS	NO	30.000000	16.05.2018	29.09.2022
  Statoil Petroleum AS	NO	70.000000	19.03.2018	15.05.2018
  Petoro AS	NO	30.000000	19.03.2018	15.05.2018
  Total E&P Norge AS	NO	51.000000	11.06.2012	18.03.2018
  Petoro AS	NO	30.000000	11.06.2012	18.03.2018
  Statoil Petroleum AS	NO	19.000000	11.06.2012	18.03.2018

• Norwegian Offshore Directorate – estimate for reserves (Norwegian share)

  Norwegian Offshore Directorate – estimate for reserves (Norwegian share)

  Valid date:	31.12.2023

  Norwegian Offshore Directorate – estimate for reserves (Norwegian share)

  Orig. recoverable oil [mill Sm3]	Orig. recoverable gas [bill Sm3]	Orig. recoverable NGL [mill tonn]	Orig. recoverable cond. [mill Sm3]	Orig. recoverable oil eq. [mill Sm3 o.e]
  7.70	16.40	1.09	0.00	26.17

  Norwegian Offshore Directorate – estimate for reserves (Norwegian share)

  Orig. inplace oil [mill Sm3]	Orig. inplace ass. liquid [mill Sm3]	Orig. inplace ass. gas [bill Sm3]	Orig. inplace free gas [bill Sm3]
  27.00	9.00	1.00	29.00

  Norwegian Offshore Directorate – estimate for reserves (Norwegian share)

  Remaining oil [mill Sm3]	Remaining gas [bill Sm3]	Remaining NGL [mill tonn]	Remaining cond. [mill Sm3]	Remaining oil eq. [mill Sm3 o.e]
  3.62	11.00	0.70	0.00	15.95

• Description

  Description

  Type	Text	Date updated
  Development	Martin Linge is a field located near the border to the UK sector in the northern part of the North Sea, 42 kilometres west of the Oseberg field. The water depth is 115 metres. Martin Linge was discovered in 1978, and the plan for development and operation (PDO) was approved in 2012. The development concept is a fully integrated fixed production platform and a floating storage and offloading unit (FSO) for oil storage. The installation is supplied with power from shore. A PDO exemption for the Herja discovery and the Hervor prospect was granted in 2017. The production started in 2021.	13.12.2023
  Reservoir	Martin Linge produces mainly gas and condensate from sandstone of Middle Jurassic age in the Brent Group. The reservoirs are structurally complex with high pressure and high temperature (HPHT) at depths of 3700-4400 metres. In addition, oil is produced from the Frigg Formation of Eocene age. The Frigg reservoir is at a depth of 1750 metres and has good quality.	13.12.2023
  Recovery strategy	The gas is produced by pressure depletion. Oil from the Frigg reservoir is produced by natural aquifer drive and gas lift. Some produced water is reinjected.	28.02.2023
  Transport	Rich gas is transported to the Frigg UK pipeline (FUKA), and on to the Shell-Esso Gas and Liquid (SEGAL) terminal at St Fergus in the UK. Oil and condensate are exported via tankers from the FSO.	28.02.2023
  Status	New 4D seismic data gathered in July 2023 will provide additional information for updating reservoir models and estimates of in-place volumes and reserves. Work is ongoing to prepare for the second drilling campaign on Martin Linge which is planned to start in early 2024.	13.12.2023

• 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.	3461

• Investments (historical)

  Investments (historical)

  	Investments [mill NOK nominal values]
  Sum	57515
  2022	1077
  2021	6124
  2020	7368
  2019	6966
  2018	6469
  2017	5322
  2016	6452
  2015	7639
  2014	5594
  2013	2740
  2012	1362
  2011	187
  2010	0
  2009	23
  2008	117
  2007	0
  2006	75

• Production , saleable

  Production , saleable

  	Month	Net - oil [mill Sm3]	Net - gas [bill Sm3]	Net - condensate [mill Sm3]	Net - NGL [mill Sm3]	Net - oil equivalents [mill Sm3]
  Sum		4.830492	6.607608	0.000000	0.712414	12.150514
  2024		0.700015	1.247831	0.000000	0.143879	2.091725
  1	0.093515	0.163149	0.000000	0.019860	0.276524
  2	0.075172	0.128159	0.000000	0.016431	0.219762
  3	0.103032	0.165681	0.000000	0.016835	0.285548
  4	0.085165	0.153275	0.000000	0.018377	0.256817
  5	0.083561	0.171266	0.000000	0.019156	0.273983
  6	0.089748	0.168033	0.000000	0.017896	0.275677
  7	0.091568	0.165939	0.000000	0.019174	0.276681
  8	0.078254	0.132329	0.000000	0.016150	0.226733
  2023		1.214638	1.818519	0.000000	0.210590	3.243747
  1	0.126866	0.187855	0.000000	0.018434	0.333155
  2	0.083548	0.110934	0.000000	0.012204	0.206686
  3	0.124230	0.158323	0.000000	0.015377	0.297930
  4	0.103716	0.142765	0.000000	0.018331	0.264812
  5	0.094719	0.134443	0.000000	0.015093	0.244255
  6	0.099971	0.151730	0.000000	0.017973	0.269674
  7	0.102404	0.163232	0.000000	0.020056	0.285692
  8	0.101848	0.154789	0.000000	0.019014	0.275651
  9	0.092038	0.156629	0.000000	0.019714	0.268381
  10	0.094884	0.132168	0.000000	0.015944	0.242996
  11	0.095959	0.164543	0.000000	0.018802	0.279304
  12	0.094455	0.161108	0.000000	0.019648	0.275211
  2022		2.029928	2.628125	0.000000	0.275953	4.934006
  1	0.168381	0.204268	0.000000	0.025427	0.398076
  2	0.170909	0.179585	0.000000	0.023345	0.373839
  3	0.199395	0.180508	0.000000	0.022743	0.402646
  4	0.183008	0.196370	0.000000	0.022705	0.402083
  5	0.185771	0.257033	0.000000	0.026561	0.469365
  6	0.181257	0.252481	0.000000	0.025559	0.459297
  7	0.167286	0.250036	0.000000	0.024967	0.442289
  8	0.177702	0.248131	0.000000	0.026214	0.452047
  9	0.162839	0.228651	0.000000	0.021855	0.413345
  10	0.153270	0.227849	0.000000	0.020910	0.402029
  11	0.143286	0.209858	0.000000	0.018480	0.371624
  12	0.136824	0.193355	0.000000	0.017187	0.347366
  2021		0.885911	0.913133	0.000000	0.081992	1.881036
  6	0.001904	0.000000	0.000000	0.000000	0.001904
  7	0.020786	0.031335	0.000000	0.000000	0.052121
  8	0.126808	0.107152	0.000000	0.000000	0.233960
  9	0.145245	0.131016	0.000000	0.013676	0.289937
  10	0.174491	0.194738	0.000000	0.019917	0.389146
  11	0.204773	0.223847	0.000000	0.023221	0.451841
  12	0.211904	0.225045	0.000000	0.025178	0.462127

• Production , sum wellbores

  Production , sum wellbores

  	Month	Gross - oil [mill Sm3]	Gross - gas [bill Sm3]	Gross - condensate [mill Sm3]	Gross - oil equivalents [mill Sm3]
  Sum		4.827952	7.017415	0.000000	11.845367
  2024		0.697500	1.331742	0.000000	2.029242
  1	0.091000	0.172954	0.000000	0.263954
  2	0.075172	0.140352	0.000000	0.215524
  3	0.103032	0.177093	0.000000	0.280125
  4	0.085165	0.164479	0.000000	0.249644
  5	0.083561	0.181311	0.000000	0.264872
  6	0.089748	0.177491	0.000000	0.267239
  7	0.091568	0.179728	0.000000	0.271296
  8	0.078254	0.138334	0.000000	0.216588
  2023		1.214638	1.946139	0.000000	3.160777
  1	0.126866	0.200161	0.000000	0.327027
  2	0.083548	0.121259	0.000000	0.204807
  3	0.124230	0.171452	0.000000	0.295682
  4	0.103716	0.157670	0.000000	0.261386
  5	0.094719	0.144615	0.000000	0.239334
  6	0.099971	0.161029	0.000000	0.261000
  7	0.102404	0.174435	0.000000	0.276839
  8	0.101848	0.163202	0.000000	0.265050
  9	0.092038	0.160321	0.000000	0.252359
  10	0.094884	0.143962	0.000000	0.238846
  11	0.095959	0.176746	0.000000	0.272705
  12	0.094455	0.171287	0.000000	0.265742
  2022		2.029928	2.776131	0.000000	4.806059
  1	0.168381	0.215481	0.000000	0.383862
  2	0.170909	0.186526	0.000000	0.357435
  3	0.199395	0.197019	0.000000	0.396414
  4	0.183008	0.211209	0.000000	0.394217
  5	0.185771	0.269015	0.000000	0.454786
  6	0.181257	0.264469	0.000000	0.445726
  7	0.167286	0.264337	0.000000	0.431623
  8	0.177702	0.264678	0.000000	0.442380
  9	0.162839	0.241529	0.000000	0.404368
  10	0.153270	0.236842	0.000000	0.390112
  11	0.143286	0.220035	0.000000	0.363321
  12	0.136824	0.204991	0.000000	0.341815
  2021		0.885886	0.963403	0.000000	1.849289
  6	0.001904	0.001733	0.000000	0.003637
  7	0.020786	0.035368	0.000000	0.056154
  8	0.126808	0.112165	0.000000	0.238973
  9	0.145245	0.136821	0.000000	0.282066
  10	0.174491	0.202986	0.000000	0.377477
  11	0.204748	0.233092	0.000000	0.437840
  12	0.211904	0.241238	0.000000	0.453142

• 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

  Wellbores – exploration

  Wellbore name	Entered date	Completed date	Purpose	Status	Content
  29/6-1	12.10.1981	09.05.1982	WILDCAT	P&A	GAS/CONDENSATE
  29/9-1	23.09.1983	24.02.1984	APPRAISAL	P&A	OIL/GAS
  30/4-2	16.11.1979	16.05.1980	APPRAISAL	P&A	GAS/CONDENSATE
  30/4-3 S	16.06.2016	09.10.2016	WILDCAT	RE-CLASS TO DEV	GAS/CONDENSATE
  30/7-2	06.08.1975	09.11.1975	WILDCAT	P&A	OIL/GAS
  30/7-6 R	18.04.1978	03.06.1978	WILDCAT	P&A	GAS/CONDENSATE
  30/7-8	19.11.1980	04.04.1981	APPRAISAL	SUSPENDED	GAS/CONDENSATE
  30/7-8 R	23.09.1981	29.01.1982	APPRAISAL	P&A	GAS/CONDENSATE

• Wellbores – development

  Wellbores – development

  Wellbore name	Entered date	Completed date	Purpose	Content
  30/4-A-1	11.11.2014	04.11.2015	INJECTION	WATER
  30/4-A-3	23.09.2014	09.02.2015	OBSERVATION	OIL
  30/4-A-3 A	11.02.2015	04.08.2015	PRODUCTION	NOT APPLICABLE
  30/4-A-3 B	05.08.2015	13.08.2015	PRODUCTION	OIL
  30/4-A-5 Y1			PRODUCTION
  30/4-A-5 Y2			PRODUCTION
  30/4-A-5 Y3			PRODUCTION
  30/4-A-6	05.11.2014	16.09.2015	PRODUCTION	OIL
  30/4-A-6 A			PRODUCTION	NOT APPLICABLE
  30/4-A-7	18.11.2014	19.03.2015	OBSERVATION	OIL
  30/4-A-7 A	21.03.2015	20.04.2015	PRODUCTION	OIL
  30/4-A-8	06.10.2014	10.04.2016	PRODUCTION	GAS
  30/4-A-9	16.06.2016	09.10.2016	PRODUCTION	GAS
  30/4-A-10	15.10.2014	01.12.2015	PRODUCTION	GAS
  30/4-A-11	12.08.2021	04.01.2022	PRODUCTION	GAS/CONDENSATE
  30/4-A-12	30.03.2017	26.06.2017	PRODUCTION	GAS
  30/4-A-13	10.05.2018	01.02.2021	PRODUCTION	GAS/CONDENSATE
  30/4-A-13 A			PRODUCTION
  30/4-A-16	07.10.2021	11.02.2022	PRODUCTION	GAS/CONDENSATE
  30/4-A-17	30.03.2021	29.07.2021	PRODUCTION	GAS/CONDENSATE
  30/4-A-19	19.05.2018	05.11.2020	PRODUCTION	GAS
  30/4-D-1 H	19.09.2009	22.02.2010	OBSERVATION	GAS/CONDENSATE
  30/4-D-1 AH	23.02.2010	31.03.2010	PRODUCTION	GAS/CONDENSATE

• Wellbores – other

  Wellbores – other

  Wellbore name	Entered date	Completed date	Purpose	Status
  30/4-U-1	23.11.2013	25.11.2013	SHALLOW GAS	PLUGGED