6507/7-12
Export: PDF
-
General information
-
Wellbore history
GeneralExploration well 6507/7-12 is located in the northern part of the Haltenbanken area, approximately 190 nautical miles west of the Norwegian coast. The block lies on the western flank of a series of NNE-SSW faults, which separate the Dønna Terrace from the Nordland Ridge/Trøndelag Platform to the east. The prospect is in the northern part of block 6507/7 and lies in an Early Cretaceous mini-basin developed in the hanging wall of the Revfallet Fault complex. The well was drilled to test a stratigraphic closure in an anticipated sand prone wedge of Albian age (Lower Cretaceous). The well was drilled in a location planned to test the minimum economic field size in terms of a tie-back to the Heidrun TLP. If hydrocarbons were present, the well would be tested through wire line logging and possible DST to determine hydrocarbon phase and deliverability. Secondary targets were in the Aptian, "Lange B" sands and in the Lysing Formation, also to be evaluated by drilling and wire line logging. Planned total depth for the well was ca. 20 meters into the Upper Jurassic Spekk Formation, prognosed at 3908 m RKB.Operations and resultsExploration well 6507/7-12 was spudded on 17 July 1999 with the semi-submersible installation, "Mærsk Jutlander" and drilled to TD at 3976 m in the Late Jurassic Spekk Formation. The well was drilled with seawater and high viscosity sweeps down to 1316 m, with "BARASILC" water based silicate KCl mud from 1316 m to 2508 m, and with Baroid "Environmul& oil based mud from 2508 m to TD. Porous sands were encountered at all prospective intervals, at depths 70-80 m deeper than prognosed. The wedges previously believed to be of Albian and Aptian were found to be of Aptian and Barremian age, respectively, and sand thickness within the wedges were thinner than anticipated. Oil (3.88 m "net pay" based on wire line data) was found in the Aptian sandstones. However, it was not a commercial success due to lack of permeability, identified from MDT pressure tests. Thin-section analysis from sidewall cores confirmed lack of permeability. Log data showed that shales in this section have totally different acoustic properties than shales above and could be confused with sand. Oil shows in the Early Cretaceous porous zones were mainly faint and weak based on fluorescence cut using acetone as solvent. The secondary objective in Lysing Formation was a 40 m sand with both porosity and permeability, but was drilled outside closure and was clearly water wet. A MDT water sample from Lysing sandstone was taken with a one-gallon chamber at a depth of 2869.8 m MD. The filling was aborted after 2,5 litres due to slow flow of water. Later analysis showed the sample to be contaminated by mud filtrate and with no oil content. Some CO2 and methane-gas were reported from the sample. No conventional cores were cut. The well was permanently plugged and abandoned as a dry well with oil shows on 12 August 1999.TestingNo drill stem test was performed. -
Cuttings at the Norwegian Offshore Directorate
Cuttings at the Norwegian Offshore Directorate Cuttings available for sampling?YESCuttings at the Norwegian Offshore Directorate Cutting sample, top depth [m]Cutting samples, bottom depth [m]1330.003975.00 -
Palynological slides at the Norwegian Offshore Directorate
Palynological slides at the Norwegian Offshore Directorate Sample depthDepth unitSample typeLaboratory1330.0[m]DCRRI1360.0[m]DCRRI1390.0[m]DCRRI1420.0[m]DCRRI1450.0[m]DCRRI1480.0[m]DCRRI1510.0[m]DCRRI1540.0[m]DCRRI1570.0[m]DCRRI1610.0[m]DCRRI1630.0[m]DCRRI1660.0[m]DCRRI1690.0[m]DCRRI1720.0[m]DCRRI1750.0[m]DCRRI1780.0[m]DCRRI1810.0[m]DCRRI1840.0[m]DCRRI1870.0[m]DCRRI1890.0[m]DCRRI1930.0[m]DCRRI1960.0[m]DCRRI1990.0[m]DCRRI2020.0[m]DCRRI2050.0[m]DCRRI2080.0[m]DCRRI2110.0[m]DCRRI2120.0[m]DCRRI2130.0[m]DCRRI2140.0[m]DCRRI2150.0[m]DCRRI2160.0[m]DCRRI2170.0[m]DCRRI2180.0[m]DCRRI2190.0[m]DCRRI2200.0[m]DCRRI2210.0[m]DCRRI2220.0[m]DCRRI2230.0[m]DCRRI2240.0[m]DCRRI2250.0[m]DCRRI2260.0[m]DCRRI2270.0[m]DCRRI2280.0[m]DCRRI2290.0[m]DCRRI2300.0[m]DCRRI2310.0[m]DCRRI2320.0[m]DCRRI2330.0[m]DCRRI2360.0[m]DCRRI2370.0[m]DCRRI2400.0[m]DCRRI2410.0[m]DCRRI2420.0[m]DCRRI2430.0[m]DCRRI2440.0[m]DCRRI2460.0[m]DCRRI2480.0[m]DCRRI2490.0[m]DCRRI2500.0[m]DCRRI2508.0[m]DCRRI2520.0[m]DCRRI2530.0[m]DCRRI2540.0[m]DCRRI2550.0[m]DCRRI2560.0[m]DCRRI2570.0[m]DCRRI2580.0[m]DCRRI2590.0[m]DCRRI2600.0[m]DCRRI2610.0[m]DCRRI2620.0[m]DCRRI2624.0[m]DCRRI2630.0[m]DCRRI2650.0[m]DCRRI2660.0[m]DCRRI2670.0[m]DCRRI2680.0[m]DCRRI2690.0[m]DCRRI2700.0[m]DCRRI2710.0[m]DCRRI2720.0[m]DCRRI2730.0[m]DCRRI2740.0[m]DCRRI2750.0[m]DCRRI2760.0[m]DCRRI2770.0[m]DCRRI2780.0[m]DCRRI2790.0[m]DCRRI2800.0[m]DCRRI2810.0[m]DCRRI2820.0[m]DCRRI2825.0[m]DCRRI2840.0[m]DCRRI2850.0[m]DCRRI2860.0[m]DCRRI2870.0[m]DCRRI2890.0[m]DCRRI2900.0[m]DCRRI2910.0[m]DCRRI2920.0[m]DCRRI2930.0[m]DCRRI2940.0[m]DCRRI2950.0[m]DCRRI2960.0[m]DCRRI2970.0[m]DCRRI2980.0[m]DCRRI2990.0[m]DCRRI3000.0[m]DCRRI3010.0[m]DCRRI3020.0[m]DCRRI3030.0[m]DCRRI3040.0[m]DCRRI3055.0[m]DCRRI3060.0[m]DCRRI3070.0[m]DCRRI3080.0[m]DCRRI3090.0[m]DCRRI3100.0[m]DCRRI3110.0[m]DCRRI3120.0[m]DCRRI3130.0[m]DCRRI3140.0[m]DCRRI3150.0[m]DCRRI3160.0[m]DCRRI3170.0[m]DCRRI3180.0[m]DCRRI3190.0[m]DCRRI3200.0[m]DCRRI3210.0[m]DCRRI3220.0[m]DCRRI3230.0[m]DCRRI3240.0[m]DCRRI3250.0[m]DCRRI3260.0[m]DCRRI3270.0[m]DCRRI3280.0[m]DCRRI3290.0[m]DCRRI3300.0[m]DCRRI3310.0[m]DCRRI3320.0[m]DCRRI3330.0[m]DCRRI3340.0[m]DCRRI3345.0[m]DCRRI3360.0[m]DCRRI3370.0[m]DCRRI3380.0[m]DCRRI3390.0[m]DCRRI3400.0[m]DCRRI3410.0[m]DCRRI3420.0[m]DCRRI3430.0[m]DCRRI3440.0[m]DCRRI3450.0[m]DCRRI3460.0[m]DCRRI3470.0[m]DCRRI3480.0[m]DCRRI3490.0[m]DCRRI3500.0[m]DCRRI3510.0[m]DCRRI3518.0[m]SWCRRI3530.0[m]DCRRI3540.0[m]DCRRI3549.0[m]SWCRRI3560.0[m]DCRRI3570.0[m]DCRRI3580.0[m]DCRRI3590.0[m]DCRRI3600.0[m]DCRRI3610.0[m]DCRRI3620.0[m]DCRRI3640.0[m]DCRRI3650.0[m]DCRRI3664.0[m]SWCRRI3670.0[m]DCRRI3680.0[m]SWCRRI3686.5[m]SWCRRI3693.5[m]SWCRRI3700.0[m]DCRRI3710.0[m]DCRRI3720.0[m]DCRRI3730.0[m]DCRRI3744.5[m]SWCRRI3750.0[m]DCRRI3759.0[m]SWCRRI3770.0[m]DCRRI3780.0[m]DCRRI3790.0[m]DCRRI3799.5[m]SWCRRI3810.0[m]DCRRI3820.0[m]DCRRI3826.0[m]SWCRRI3840.0[m]DCRRI3853.5[m]SWCRRI3865.0[m]SWCRRI3880.0[m]DCRRI3890.0[m]DCRRI3900.0[m]DCRRI3910.0[m]DCRRI3925.0[m]DCRRI3932.0[m]SWCRRI3940.0[m]DCRRI3950.0[m]DCRRI3960.0[m]DCRRI3970.0[m]DCRRI3975.0[m]DCRRI -
Lithostratigraphy
Lithostratigraphy Top depth [mMD RKB]Lithostrat. unit35614921877187720992099215221962196237725952858285828973670374539113911 -
Composite logs
Composite logs Document nameDocument formatDocument size [MB]pdf0.49 -
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 nameDocument formatDocument size [MB].pdf2.71.pdf45.65 -
Logs
Logs Log typeLog top depth [m]Log bottom depth [m]AIT IPLT DSI ACTS24413948CST GR27883967MDT GR28703950MWD - CDR GR DIR4093976MWD - CDR GR DIR25002508VSP11003830 -
Casing and leak–off tests
Casing and leak–off tests Casing typeCasing diam.
[inch]Casing depth
[m]Hole diam.
[inch]Hole depth
[m]LOT/FIT mud eqv.
[g/cm3]Formation test typeCONDUCTOR30415.036516.00.00LOTSURF.COND.13 3/81308.017 1/21308.01.71LOTINTERM.9 5/82500.012 1/42500.01.92LOTOPEN HOLE3976.08 1/23976.00.00LOT -
Drilling mud
Drilling mud Depth MD [m]Mud weight [g/cm3]Visc. [mPa.s]Yield point [Pa]Mud typeDate measured4091.03SEAWATER13161.201.0SEAWATER13251.5326.0KCL/POLYMER17401.5423.0BARASIL-S20751.5424.0BARASIL-S25081.5427.0BARASIL-S28451.5436.0OIL (ENVIRON)31921.5445.0OIL (ENVIRON)35101.5445.0OIL (ENVIRON)37261.5744.0OIL (ENVIRON)38131.5740.0OIL (ENVIRON)38751.5740.0OIL (ENVIRON)39761.5713.0KCL/POLYMER -
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 nameDocument formatDocument size [MB]pdf0.28