Wellbore: 02.01.2024 - 34/10-30 - 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.	34/10-30
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.	GULLFAKS SØR
Discovery Name of the discovery the wellbore is related to.	34/10-2 Gullfaks Sør
Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	34/10-30
Seismic location Position of spud location on seismic survey lines. SP: shotpoint.	LINJE 170 SP 405 (3D-SURVEY)
Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	050
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.	Den norske stats oljeselskap a.s
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.	501-L
Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	DYVI STENA
Drilling days Number of days from wellbore entry to wellbore completion.	115
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,	16.01.1986
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.	12.05.1986
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.	12.05.1988
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.	28.05.2003
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.	APPRAISAL
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/GAS
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.	MIDDLE JURASSIC
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.	BRENT GP
2nd level with HC, age Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.	EARLY JURASSIC
2nd level with HC, formation Name of lithostartigraphic unit, 2nd 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.	STATFJORD GP
3rd level with HC, age Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.	LATE TRIASSIC
3rd level with HC, formation Name of lithostartigraphic unit, 3rd 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.	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.	133.0
Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	3785.0
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).	3773.0
Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	11.5
Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	143
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.	LATE 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.	LUNDE FM
Geodetic datum Reference system for coordinates. Example of legal values: ED50.	ED50
NS degrees Geographic coordinate of the wellhead, north-south degrees.	61° 6' 31.07'' N
EW degrees Geographic coordinate of the wellhead, east-west degrees.	2° 15' 23.92'' E
NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	6775275.64
EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	459930.95
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.	877

Well 34/10-30 was the fifth well drilled on Gullfaks Sør. The well was the "continuation" of the junked well 34/10-28, which was plugged and abandoned at 528 m. Well 34/10-30 was drilled on the Alpha structure, and designed to test for hydrocarbon accumulations in the North East part of the structure. The main objectives were the Brent and Statfjord sandstones. The Lower Jurassic Cook sandstone, which had been water bearing in the other Gullfaks Sør wells, was considered a secondary objective, as was the penetration of the oil/water contact. Prognosed depth was 3435 m.

Operations

Appraisal well 34/10-30 was spudded with the semi-submersible installation Dyvi Stena on 16 January 1986 and drilled to TD at 3785 m in the Triassic Lunde Formation. Drilling proceeded without significant problems, but 20" casing was set early due to shallow gas in the interval 332-340 m. The well was drilled with spud mud down to 232 m, with PAC/polymer mud from 232 m to 325 m, with gypsum / PAC mud from 325 m to 1898 m, with gypsum/PAC/"Borewell" mud from 1898 m to 2845 m, and with Lignite/"Borewell" mud from 2845 m to TD.

A four-meter thick Brent sandstone was encountered at 2941 m. The sandstone showed a milky white to pale yellow fluorescence with a slow white streaming cut and a C1/C2 mud gas ratio that indicate a gas bearing formation. The Cook Formation was dry. The top of the Statfjord Formation was at 3120 m, approximately 100 m higher than prognosed. The formation was all filled with oil and gas and had a gas-oil contact at 3251.6 m. The Lunde Formation was reached at 3375 m. The formation was oil bearing with no defined oil-water contact. The oil/water contact was expected at 3395 m. This was not the case and drilling of a 6" section thus commenced past the prognosed depth. The oil water contact was difficult to define, but there is reason to believe it to be at approximately 3712 m. Twenty-two cores were cut in the well, 9 in the Lunde Formation, 12 in the Statfjord Formation, and one in the Dunlin Group. One segregated RFT sample was collected in the Lunde Formation at 3554.0 m. The bottom part of the well was plugged back into the 7" liner without permission from NPD. The well was tested and subsequently plugged and abandoned on 12 may 1986 as an oil and gas appraisal well.

Testing

Three drill stem tests were performed. DST No 1 (3460 m to 3473 m) in the Lunde Formation flowed 418 Sm3 oil /d with a GOR of 146 Sm3/Sm3 through a 12.7 mm choke, DST No 2 (3296 m to 3317 m) in the oil zone in the Statfjord Formation flowed 1161 Sm3 oil /d with a GOR of 102 Sm3/Sm3 through a 17.5 mm choke, while DST No 3 (3125 m to 3155 m) in the gas zone in the Statfjord Formation flowed 352 Sm3 oil/d and 1151000 Sm3 gas/d (GOR = 3270 Sm3/Sm3) through a 17.5 mm choke.

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]
230.00	3782.00

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	2942.4	2945.8	[m ]
2	3125.0	3146.0	[m ]
3	3146.0	3171.7	[m ]
4	3173.0	3179.5	[m ]
5	3179.5	3186.5	[m ]
6	3186.5	3199.5	[m ]
7	3199.5	3217.6	[m ]
8	3217.5	3235.6	[m ]
9	3235.5	3252.8	[m ]
10	3252.5	3270.2	[m ]
11	3270.5	3288.8	[m ]
12	3288.8	3305.2	[m ]
13	3306.0	3326.6	[m ]
14	3411.0	3429.4	[m ]
15	3429.0	3446.0	[m ]
16	3446.5	3465.0	[m ]
17	3465.0	3478.5	[m ]
18	3543.0	3561.3	[m ]
19	3561.5	3579.8	[m ]
20	3548.0	3597.5	[m ]
21	3597.5	3615.0	[m ]
22	3615.5	3633.7	[m ]

Cores at the Norwegian Offshore Directorate
Total core sample length [m]	392.2

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

Core photos

Core photos

2942-2946m	3125-3131m	3131-3137m	3137-3143m	3143-3146m

3146-3152m	3152-3158m	3158-3164m	3164-3170m	3170-3172m

3173-3179m	3179-3180m	3180-3185m	3185-3187m	3187-3192m

3192-3198m	3198-3200m	3199-3205m	3205-3211m	3211-3217m

3217-3218m	3218-3222m	3223-3229m	3229-3235m	3235-3236m

3235-3240m	3241-3247m	3247-3253m	3252-3258m	3264-3270m

3270-3271m	3270-3276m	3276-3282m	3288-3289m	3282-3288m

3288-3294m	3294-3300m	3300-3306m	3306-3312m	3312-3318m

3318-3324m	3411-3417m	3417-3423m	3423-3429m	3429-3430m

3429-3435m	3435-3441m	3441-3446m	3446-3452m	3452-3458m

3458-3464m	3464-3465m	3465-3471m	3471-3477m	3477-3479m

3543-3549m	3549-3555m	3555-3581m	3561-3562m	3561-3567m

3567-3573m	3573-3579m	3579-3580m	3579-3585m	3585-3591m

3591-3597m	3597-3598m	3597-3603m	3603-3609m	3609-3615m

3615-3621m	3621-3627m	3627-3633m	3633-3634m

Palynological slides at the Norwegian Offshore Directorate

Palynological slides at the Norwegian Offshore Directorate
Sample depth	Depth unit	Sample type	Laboratory
2910.0	[m]	DC	GEOCH
2922.0	[m]	DC	GEOCH
2934.0	[m]	DC	GEOCH
2942.3	[m]	DC	GEOCH
2952.0	[m]	DC	GEOCH
3125.9	[m]	C	HYDRO
3133.7	[m]	C	HYDRO
3140.4	[m]	C	HYDRO
3146.8	[m]	C	HYDRO
3153.5	[m]	C	HYDRO
3158.9	[m]	C	HYDRO
3162.4	[m]	C	HYDRO
3167.9	[m]	C	HYDRO
3179.6	[m]	C	HYDRO
3185.9	[m]	C	HYDRO
3192.5	[m]	C	HYDRO
3196.9	[m]	C	HYDRO
3201.7	[m]	C	HYDRO
3204.1	[m]	C	HYDRO
3211.6	[m]	C	HYDRO
3214.4	[m]	C	HYDRO
3217.5	[m]	C	HYDRO
3228.9	[m]	C	HYDRO
3233.3	[m]	C	HYDRO
3240.7	[m]	C	HYDRO
3251.6	[m]	C	HYDRO
3255.6	[m]	C	HYDRO
3261.0	[m]	C	HYDRO
3262.5	[m]	C	HYDRO
3273.3	[m]	C	HYDRO
3283.6	[m]	C	HYDRO
3288.2	[m]	C	HYDRO
3292.1	[m]	C	HYDRO
3294.4	[m]	C	HYDRO
3297.1	[m]	C	HYDRO
3309.4	[m]	C	HYDRO
3316.7	[m]	C	HYDRO
3318.3	[m]	C	HYDRO
3320.6	[m]	C	HYDRO
3323.5	[m]	C	HYDRO
3411.4	[m]	C	HYDRO
3417.7	[m]	C	HYDRO
3420.9	[m]	C	HYDRO
3426.9	[m]	C	HYDRO
3431.7	[m]	C	HYDRO
3440.6	[m]	C	HYDRO
3448.3	[m]	C	HYDRO
3453.8	[m]	C	HYDRO
3459.7	[m]	C	HYDRO
3469.8	[m]	C	HYDRO
3472.9	[m]	C	HYDRO
3474.7	[m]	C	HYDRO

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]	Test time	Samples available
DST	TEST1	3460.00	3473.00	15.04.1986 - 03:42	YES
DST	TEST2	3297.00	3318.00	21.04.1986 - 20:50	YES
DST	TEST3	3125.00	3155.00	30.04.1986 - 00:00	YES

Lithostratigraphy

Lithostratigraphy
Top depth [mMD RKB]	Lithostrat. unit
158	NORDLAND GP
920	UTSIRA FM
951	HORDALAND GP
1785	ROGALAND GP
1785	BALDER FM
1856	LISTA FM
2006	SHETLAND GP
2918	CROMER KNOLL GP
2941	BRENT GP
2945	DUNLIN GP
2945	DRAKE FM
2950	COOK FM
2983	AMUNDSEN FM
3120	STATFJORD GP
3375	HEGRE GP
3375	LUNDE FM

Composite logs

Composite logs
Document name	Document format	Document size [MB]
877	pdf	0.81

Geochemical information

Geochemical information
Document name	Document format	Document size [MB]
877_1	pdf	1.87
877_2	pdf	0.27

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]
877_01_WDSS_General_Information	pdf	0.28
877_02_WDSS_completion_log	pdf	0.34

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]
877_34_10_30_COMPLETION_REPORT_AND_LOG	pdf	36.37

Drill stem tests (DST)

Drill stem tests (DST)
Test number	From depth MD [m]	To depth MD [m]	Choke size [mm]
1.0	3460	3473	12.7
2.0	3297	3318	17.5
3.0	3125	3155	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	7.600		25.900	129
2.0		9.000	29.200	126
3.0			43.100	118

Drill stem tests (DST)
Test number	Oil [Sm3/day]	Gas [Sm3/day]	Oil density [g/cm3]	Gas grav. rel.air	GOR [m3/m3]
1.0	418	61000	0.863	0.694	146
2.0	1150	118000	0.859	0.662	102
3.0	352	1151000	0.790	0.658	3271

Logs

Logs
Log type	Log top depth [m]	Log bottom depth [m]
CBL VDL GR	155	2832
CBL VDL GR	300	1885
CBL VDL GR	2671	3500
CBL VDL GR	3046	3163
CST GR	1887	2845
DLL MSFL GR	2832	3497
DLL MSFL GR	3500	3783
DLWD - GR RES DIR	236	3500
DLWD - NMR P-K	3125	3319
DLWD - NMR P-K	3411	3479
ISF LSS MSFL GR	319	1405
ISF LSS MSFL GR	1322	1896
ISF LSS MSFL GR	1887	2845
ISF LSS MSFL GR	2832	3365
ISF LSS MSFL GR	2832	3499
ISF LSS MSFL GR	3500	3787
ISF LSS MSFL GR	3500	3677
LDL CNL GR	319	1898
LDL CNL GR	1887	2846
LDL CNL GR	3500	3787
LDL CNL NGS	2832	3500
RFT GR	2919	3146
RFT GR	3133	3302
RFT GR	3542	3766
SHDT GR	2832	3483
SHDT GR	3500	3787
VSP	319	3787

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	231.0	36	235.0	0.00	LOT
SURF.COND.	20	320.0	26	329.0	1.33	LOT
INTERM.	13 3/8	1886.0	17 1/2	1898.0	1.80	LOT
INTERM.	9 5/8	2831.0	12 1/2	2845.0	0.00	LOT
LINER	7	3785.0	8 1/2	3785.0	1.99	LOT

Drilling mud

Drilling mud
Depth MD [m]	Mud weight [g/cm3]	Visc. [mPa.s]	Yield point [Pa]	Mud type	Date measured
634	1.12	17.0	11.0	WATER BASED	23.01.1986
898	1.15	20.0	12.5	WATER BASED	23.01.1986
1718	1.17	56.0	25.0	WATER BASED	31.01.1986
1776	1.20	58.0	16.0	WATER BASED	03.02.1986
1887	1.27	62.0	15.5	WATER BASED	03.02.1986
1898	1.30	61.0	13.5	WATER BASED	04.02.1986
1905	1.35	52.0	9.8	WATER BASED	11.02.1986
1928	1.40	52.0	9.8	WATER BASED	11.02.1986
2043	1.45	52.0	9.8	WATER BASED	11.02.1986
2100	1.56	56.0	8.4	WATER BASED	11.02.1986
2151	1.55	56.0	8.4	WATER BASED	11.02.1986
2204	1.60	56.0	8.4	WATER BASED	11.02.1986
2476	1.62	51.0	7.4	WATER BASED	12.02.1986
2750	1.62	57.0	10.0	WATER BASED	16.02.1986
2770	1.67	50.0	7.0	WATER BASED	16.02.1986
2777	1.67	55.0	8.0	WATER BASED	16.02.1986
2944	1.65	21.0	4.5	WATER BASED	11.03.1986
3133	1.65	21.0	4.5	WATER BASED	11.03.1986
3146	1.65	21.0	4.5	WATER BASED	11.03.1986
3365	1.60	20.0	4.5	WATER BASED	11.03.1986
3500	1.50	20.0	6.0	WATER BASED	25.03.1986
3675	1.50	23.0	5.7	WATER BASED	01.04.1986
3693	1.50	24.0	5.2	WATER BASED	03.04.1986

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]
877_Formation_pressure_(Formasjonstrykk)	pdf	0.22

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