Synchronized 28.01.2021 - 01:51

MARTIN LINGE

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General information

General information
Attribute	Value
Field name	MARTIN LINGE
Factmaps in new window	link
Current activity status	Approved for production
Discovery wellbore	30/7-6 R
Discovery year.	1978
Main area	North Sea
Main supply base	Tananger/Dusavik
NPDID field	21675447

Picture

Picture

Discoveries included

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

Activity status – history

Activity status – history
Status	Status from	Status to
Approved for production	11.06.2012

Located in

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

Owner – current

Owner – current
Owner kind	Owner name
BUSINESS ARRANGEMENT AREA	MARTIN LINGE UNIT

Operatorship – current

Operatorship – current
Company name
Equinor Energy AS

Licensees – current

Licensees – current
Company name	Nation code	Company share [%]
Equinor Energy AS	NO	70.000000
Petoro AS	NO	30.000000

The NPD estimate for reserves (Norwegian share)

The NPD estimate for reserves (Norwegian share)
Valid date:		31.12.2019

The NPD 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]
11.14	26.42	2.17	0.00	41.68

The NPD 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]
22.00	10.00	1.00	37.96

The NPD 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]
11.14	26.42	2.17	0.00	41.68

Description

Description
Type	Text	Date updated
Development	Martin Linge is a field 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 operations (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. A mobile jack-up rig is utilised for the drilling of production wells. The installation will be supplied with power from shore. A PDO exemption for the Herja discovery and the Hervor prospect was granted in 2017.	18.02.2020
Reservoir	The main reservoir contains gas and condensate at high pressure and high temperature (HPHT), and is structurally complex. Three reservoirs are in sandstone of Middle Jurassic age in the Brent Group, at depths of 3,700-4,400 metres. Oil also occurs in the Frigg Formation of Eocene age; the reservoir is at a depth of 1,750 metres and has good quality.	25.04.2019
Recovery	The gas reservoir will be produced by pressure depletion. Oil production from the Eocene reservoir will be supported by natural aquifer drive and gas lift. Produced water will be reinjected.	16.03.2018
Transport	Rich gas will be 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 will be exported via tankers from the FSO.	16.03.2018
Status	The field is under development. The platform jacket was installed on the field in 2014 and the topside modules in 2018. Production is planned to start in mid-2020.	18.02.2020

Investments (expected)

Investments (expected)
Future investments from 2020 [mill NOK 2020-kroner] : 12971

Investments (historical)

Investments (historical)
	Investments [mill NOK nominal values]
Sum	42946
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]

Production , sum wellbores

Production , sum wellbores
Month	Gross - oil [mill Sm3]	Gross - gas [bill Sm3]	Gross - condensate [mill Sm3]	Gross - oil equivalents [mill Sm3]

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-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-12	30.03.2017	26.06.2017	PRODUCTION	GAS
30/4-A-13	10.05.2018		PRODUCTION	GAS/CONDENSATE
30/4-A-17			PRODUCTION
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	01.11.2013	01.11.2013	PILOT