Wellbore: 315-L - 34/4-4 - Factpages - Norwegian Offshore Directorate

General information

General information
Attribute	Value
Wellbore name Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	34/4-4
Type Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)	EXPLORATION
Purpose Final classification of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS. Legal values for other wellbores: SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities), SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location), PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore), SCIENTIFIC (drilling according to Law of Scientific research and exploration), STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).	APPRAISAL
Status Status for the wellbore. Legal values are: BLOWOUT: A blowout has occurred in the well. CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported. DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging, JUNKED: The drilling operation has been terminated due to technical problems. P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations. PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage. PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate. INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate. PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores. RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore. RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production. SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.	P&A
Factmaps in new window	link to map
Main area Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.	NORTH SEA
Field Name of the field the wellbore is related to.	SNORRE
Discovery Name of the discovery the wellbore is related to.	34/4-1 Snorre
Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	34/4-4
Seismic location Position of spud location on seismic survey lines. SP: shotpoint.	SG 8020 - 201 SP 2295
Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	057
Drilling operator Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.	Saga Petroleum ASA
Drill permit The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.	315-L
Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	DYVI ALPHA
Drilling days Number of days from wellbore entry to wellbore completion.	146
Entered date The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,	11.09.1982
Completed date Exploration wellbores from moveable facilities: For floating facilities - date when anchor handling is started. For jackups - date the jacking-down started. Exploration wellbores from fixed facilities and all development wellbores: Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore. Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.	03.02.1983
Release date Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.	03.02.1985
Publication date Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.	21.12.2012
Purpose - planned Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.	WILDCAT
Reentry Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.	NO
Content For exploration wellbores, status of discovery. Legal values: DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS. SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment. Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER For development wellbores, type of produced/injected fluid. Legal values: WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.	OIL
Discovery wellbore Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.	NO
1st level with HC, age Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.	LATE TRIASSIC
1st level with HC, formation Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.	LUNDE FM
Kelly bushing elevation [m] Elevation of the rotary kelly bushing (RKB) above mean sea level.	25.0
Water depth [m] Depth in metres betweem mean sea level and sea floor.	345.0
Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	3800.0
Final vertical depth (TVD) [m RKB] Vertical elevation from total depth to kelly bushing. Shown only for released wells. Referred to as true vertical depth (TVD).	3800.0
Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	122
Oldest penetrated age Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.	MIDDLE TRIASSIC
Oldest penetrated formation Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.	TEIST FM (INFORMAL)
Geodetic datum Reference system for coordinates. Example of legal values: ED50.	ED50
NS degrees Geographic coordinate of the wellhead, north-south degrees.	61° 30' 20.85'' N
EW degrees Geographic coordinate of the wellhead, east-west degrees.	2° 14' 9.54'' E
NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	6819527.92
EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	459334.80
UTM zone Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.	31
NPDID wellbore Norwegian Offshore Directorate's unique id for the wellbore.	41

The primary objective of the exploration well 34/4 4 was to drill the untested Triassic sequence in the fault blocks west of well 34/4-1. The well location was chosen to be stratigraphically higher relative to the Triassic sequence in well 34/4-1. The purpose of the well location was also to penetrate and core the maximum oil column above the tentative oil water contact interpreted in well 34/4-1 and to test possible lateral fluid communication with 34/4-1.

Operations and results

Wildcat well 34/4-4 was spudded with the semi-submersible installation Dyvi Alpha on 11 September 1982 and drilled to TD at 3800 in Middle Triassic sediments, Teist Formation. As much as 15 % of total rig time was WOW due to bad weather. While coring, after core number 12 was taken, the mud was replaced with seawater by accident and caused a kick, resulting in a 20 bbls influx. The well was drilled with spud mud down to 493 m, with gel mud from 493 m to 1212 m, with gypsum/polymer mud from 1212 m to 2116 m, with Lignosulphonate mud from 2116 m to 2475 m, and with lignosulphonate/Chem-X mud from 2475 m to TD.

First oil shows were recorded on cuttings from thin sandstone stringers below 2075 m, accompanied by increased gas readings. Sidewall cores from siltstone beds between 2100 and 2414 m also occasionally had oil shows.

The Early Cretaceous Åsgard Formation rested unconformably on the Late Triassic Lunde Formation at 2425 m. The Lunde Formation sandstones were oil bearing down to the oil water contact at 2586 m. The OWC was set mostly on the intersection of the oil and water pressure gradients from RFT data. The oil bearing sand was separated from the water zone by a 22 m thick residual oil zone between 2586 and 2608 m. This interval had an average net sand porosity of 22%. In the water wet sand interval between 2608 and 2794 m, the average net sand porosity was 21%. No shows were recorded below 2612 m.

A total of 180 m core was cut in 15 cores from 2433.7 to 2638.4 m in the Lunde Formation oil reservoir and down across the OWC. The core-log depth shifts were significant with the cored depth for core 1 being + 9.5 m relative to logger's depth. The shifts for the following cores decreased in a relatively regular fashion with increasing core depth to + 4.5 m for core 15. The RFT tool was run and good pressure data was obtained. RFT segregated fluid samples were taken at 2431.5 m (oil and gas), 2489.0 m (mud filtrate), 2573.0 m (oil and mud filtrate), 2605.5 m (mud filtrate), 2643.5 m (mud filtrate), and 2715.0 (water and mud filtrate).

The well was permanently abandoned on 6 February 1985 as an oil appraisal well.

Testing

Four DST's were performed in the Late Triassic Lund Formation sandstones. The test results were considered to be some of the best so far in the North Sea.

DST 1 tested the water zone from the interval 2618.0 - 2626.0 m. At stable conditions in the final flow the well produced 83.5 m3 water/day through a 32/64" flow. Bottom hole temperature was 95.6 deg C.

DST 2 tested the interval 2572.5 - 2577.5 m. At stable conditions in the main flow the well produced 461 Sm3 oil/day through a 24/64" choke. The separator GOR was 94 Sm3/Sm3. Bottom hole temperature was 96.1 deg C. When opening up to a 52/64" choke the production reached 1606 Sm3 oil/day. No water or sand was produced.

DST 3 tested the interval 2512.8 - 2515.8 m. After perforations the test was suspended for a week due to bad weather. The interval was re-perforated before the test was resumed. The production in this test never stabilized, possibly due to formation damage caused by the interruption period. An average oil rate of 54 Sm3/day was estimated. The oil density was 0.83 g/cm3. No water or sand was produced. Bottom hole temperature was 94.4 deg C.

DST 4 tested the interval 2429.0 - 2437.0 m. During 8 hours main flow through a 44/64" choke the rated declined slowly from 1844 Sm3 to 1717 Sm3 /day. The separator GOR was 70 Sm3/Sm3. The dead oil density was 0.82 - 0.83 g/cm3. No water or sand was produced. Bottom hole temperature was 93.3 deg C.

Cuttings at the Norwegian Offshore Directorate

Cuttings at the Norwegian Offshore Directorate
Cuttings available for sampling?	YES

Cuttings at the Norwegian Offshore Directorate
Cutting sample, top depth [m]	Cutting samples, bottom depth [m]
500.00	3794.00

Cores at the Norwegian Offshore Directorate

Cores at the Norwegian Offshore Directorate
Core sample number	Core sample - top depth	Core sample - bottom depth	Core sample depth - uom
1	2433.7	2444.1	[m ]
2	2444.8	2457.0	[m ]
3	2457.9	2471.3	[m ]
4	2472.2	2482.5	[m ]
5	2482.6	2486.0	[m ]
6	2489.3	2501.9	[m ]
7	2501.9	2519.5	[m ]
8	2519.5	2535.0	[m ]
9	2535.0	2548.6	[m ]
10	2548.6	2566.8	[m ]
11	2566.8	2576.1	[m ]
12	2578.3	2595.4	[m ]
13	2596.2	2607.5	[m ]
14	2614.4	2621.3	[m ]
15	2624.0	2634.6	[m ]

Cores at the Norwegian Offshore Directorate
Total core sample length [m]	182.4

Cores at the Norwegian Offshore Directorate
Cores available for sampling?	YES

Core photos

Core photos

2433-2437m	2437-2439m	2440-2442m	2443-2444m	2444-2447m

2448-2450m	2451-2454m	2455-2456m	2457-2460m	2461-2463m

2464-2467m	2468-2471m	2472-2475m	2475-2479m	2479-2482m

2482-2486m	2486-2488m	2489-2492m	2492-2496m	2496-2499m

2499-2501m	2501-2505m	2505-2507m	2508-2511m	2511-2514m

2514-2517m	2518-2519m	2519-2522m	2522-2525m	2525-2528m

2528-2532m	2532-2535m	2535-2537m	2537-2539m	2540-2547m

2547-2548m	2548-2551m	2551-2554m	2555-2558m	2558-2562m

2562-2565m	2565-2566m	2566-2570m	2570-2573m	2573-2576m

2578-2581m	2581-2585m	2585-2588m	2592-2594m	2594-2595m

2596-2598m	2599-2603m	2603-2606m	2606-2607m	2614-2617m

2617-2621m	2624-2627m	2627-2631m	2631-2634m	2603-2606m

2606-2607m	2614-2617m	2617-2621m	2624-2627m	2627-2631m

2631-2634m

Palynological slides at the Norwegian Offshore Directorate

Palynological slides at the Norwegian Offshore Directorate
Sample depth	Depth unit	Sample type	Laboratory
2444.9	[m]	C	RRI
2833.7	[m]	SWC	RRI
2851.5	[m]	SWC	RRI
2925.6	[m]	SWC	RRI
2930.4	[m]	SWC	RRI
2938.2	[m]	SWC	RRI
3359.2	[m]	SWC	RRI

Oil samples at the Norwegian Offshore Directorate

Oil samples at the Norwegian Offshore Directorate
Test type	Bottle number	Top depth MD [m]	Bottom depth MD [m]	Fluid type	Test time	Samples available
DST	DST2	2572.00	2578.00		31.12.1982 - 08:30	YES
DST	DST4	2429.00	2437.00	OIL	22.01.1983 - 22:00	YES

Lithostratigraphy

Lithostratigraphy
Top depth [mMD RKB]	Lithostrat. unit
370	NORDLAND GP
1157	UTSIRA FM
1180	HORDALAND GP
1634	ROGALAND GP
1634	BALDER FM
1670	LISTA FM
1787	SHETLAND GP
1787	JORSALFARE FM
1943	KYRRE FM
2414	CROMER KNOLL GP
2414	ÅSGARD FM
2425	HEGRE GP
2425	LUNDE FM
3143	LOMVI FM
3228	TEIST FM

Geochemical information

Geochemical information
Document name	Document format	Document size [MB]
41_GCH_1	pdf	1.01
41_GCH_2	pdf	8.32
41_GCH_3	pdf	1.83

Documents – older Norwegian Offshore Directorate WDSS reports and other related documents

Documents – older Norwegian Offshore Directorate WDSS reports and other related documents
Document name	Document format	Document size [MB]
41_01_WDSS_General_Information	pdf	0.19
41_02_WDSS_completion_log	pdf	0.36

Documents – reported by the production licence (period for duty of secrecy expired)

Documents – reported by the production licence (period for duty of secrecy expired)
Document name	Document format	Document size [MB]
41_34_04_04_Completion_Report_and_log	pdf	23.91

Drill stem tests (DST)

Drill stem tests (DST)
Test number	From depth MD [m]	To depth MD [m]	Choke size [mm]
1.0	2618	2626	12.7
2.0	2572	2578	10.3
3.0	2512	2516	6.3
4.0	2429	2437	17.5

Drill stem tests (DST)
Test number	Final shut-in pressure [MPa]	Final flow pressure [MPa]	Bottom hole pressure [MPa]	Downhole temperature [°C]
1.0
2.0
3.0
4.0

Drill stem tests (DST)
Test number	Oil [Sm3/day]	Gas [Sm3/day]	Oil density [g/cm3]	GOR [m3/m3]
1.0
2.0	461			94
3.0	54
4.0	1749	200000	0.830	70

Logs

Logs
Log type	Log top depth [m]	Log bottom depth [m]
CBL VDL GR	1850	2083
CBL VDL GR CCL	1750	2785
CST	2105	2428
CST	2639	2794
CST	2810	3359
CST	3363	3776
DIP	2097	2793
DIP	2788	3797
DLL MSFL NGS	2097	2793
ISF DDBHC GR	2098	2796
ISF DDBHC MSFL NGL	2788	3798
ISF LSS SP GR	494	1213
ISF LSS SP GR	1213	1713
ISF LSS SP GR	1213	2115
LDL CNL CAL GR	494	1213
LDL CNL GR	1213	2115
LDL CNL GR	2098	2797
LDL CNL GR	2788	3797
RFT	2432	2762
RFT	2893	3491
VSP	500	3798

Casing and leak–off tests

Casing and leak–off tests
Casing type	Casing diam. [inch]	Casing depth [m]	Hole diam. [inch]	Hole depth [m]	LOT/FIT mud eqv. [g/cm3]	Formation test type
CONDUCTOR	30	493.0	36	493.0	0.00	LOT
SURF.COND.	20	1200.0	26	1212.0	1.26	LOT
INTERM.	13 3/8	2098.0	17 1/2	2115.0	1.59	LOT
INTERM.	9 5/8	2792.0	12 1/4	2800.0	1.87	LOT
OPEN HOLE		3800.0	8 1/2	3800.0	0.00	LOT

Drilling mud

Drilling mud
Depth MD [m]	Mud weight [g/cm3]	Visc. [mPa.s]	Mud type
530	1.03	15.0	waterbased
900	1.11	7.0	waterbased
1070	1.14	7.0	waterbased
1610	1.13	9.0	waterbased
1910	1.28	18.0	waterbased
2140	1.42	27.0	waterbased
2350	1.50	25.0	waterbased
2810	1.60	23.0	waterbased
3360	1.62	16.0	waterbased
3620	1.60	20.0	waterbased

Pressure plots

Pressure plots
The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.

Pressure plots
Document name	Document format	Document size [MB]
41_Formation_pressure_(Formasjonstrykk)	pdf	0.23

34/4-4