25/5-2
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General information
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Wellbore history
GeneralWell 25/5-2 was designed to drill the Frøy structure, which is a NNE-SSW tilted Jurassic fault block located in the northeastern corner of block 25/5. The main objectives of the well were to prove the Southward continuity and extension of the Middle Jurassic reservoir, to determine the OWC in the Frøy Field, to test the productivity in the oil zone, and to test the injectivity in the water zone. The northern extension of the Frøy structure was drilled in 1977 by well 25/2-6 in a down dip position and proved limited oil shows in the Statfjord Formation. Wells 25/5-1 and 25/5-1 A were drilled in 1987 in the central part of the structure, and found oil in the Vestland Group sandstones.Operations and resultsWildcat well 25/5-2 was spudded with the semi-submersible rig West Vanguard on 18 April 1989 and completed 4 July 1989 at a depth of 3304 m in the Early Jurassic Drake Formation. Drilling went without problems to 2300 m where the bit became stuck after a wiper trip, and the string was backed of at 2231 m. A technical sidetrack was started from 2103 m. The string entered into the old hole, and a second sidetrack was started from 2070 m. Below the 9 5/8" casing at 3066 m BSX mud, based on seawater with added NACl and polymers, was used. The MWD measurements showed no indication of shallow gas. The Vestland Group, Hugin Formation, came in at 3186 m, 67 m deeper than expected. Hydrocarbons were encountered at the top reservoir with the oil water contact at 3198 m (3176 m TVD MSL), which is 50 m deeper than the estimated OWC in well 25/5-1 A. Still, RFT Pressure measurements in the oil column indicate pressure communication with the oil column in well 25/5-1. A total of 4 cores were cut down to 3226 m. The well was plugged and abandoned as an oil appraisal well.TestingTwo drill stem tests where performed. Test 1 was a production and injection test in the Middle Vestland Group water zone from 3222 m to 3228 m. In the first attempt, DST 1A, scaling precipitated and blocked the jet pump when seawater came in contact with formation water. In the second attempt, DST 1B, injection was achieved using treated seawater. Test 2 was a production test at the oil/water contact in the interval 3196 m to 3201 m. This interval produced water and oil at maximum rates 56 m3/day and 202 Sm3/day, respectively. The oil was produced with a GOR of 168 Sm3/Sm3. -
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]220.003304.00 -
Cores at the Norwegian Offshore Directorate
Cores at the Norwegian Offshore Directorate Core sample numberCore sample - top depthCore sample - bottom depthCore sample depth - uom13176.03194.0[m ]23194.03196.7[m ]33197.03215.2[m ]43215.23226.5[m ]Cores at the Norwegian Offshore Directorate Total core sample length [m]50.2Cores at the Norwegian Offshore Directorate Cores available for sampling?YES -
Core photos
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Palynological slides at the Norwegian Offshore Directorate
Palynological slides at the Norwegian Offshore Directorate Sample depthDepth unitSample typeLaboratory2160.0[m]DCPETROSTR2170.0[m]DCPETROS2180.0[m]DCPETROS2190.0[m]DCPETROS2200.0[m]DCPETROS2210.0[m]DCPETROS2220.0[m]DCPETROS2230.0[m]DCPETROS2240.0[m]DCPETROS2250.0[m]DCPETROS2260.0[m]DCPETROS2270.0[m]DCPETROS2280.0[m]DCPETROS2290.0[m]DCPETROS2300.0[m]DCPETROS2310.0[m]DCPETROS2320.0[m]DCPETROS2330.0[m]DCPETROS2340.0[m]DCPETROS2350.0[m]DCPETROS2360.0[m]DCPETROS2370.0[m]DCPETROS2380.0[m]DCPETROS2390.0[m]DCPETROS2400.0[m]DCPETROS2410.0[m]DCPETROS2420.0[m]DCPETROS2430.0[m]DCPETROS2440.0[m]DCPETROS2450.0[m]DCPETROS2460.0[m]DCPETROS2470.0[m]DCPETROS2480.0[m]DCPETROS2490.0[m]DCPETROS2500.0[m]DCPETROS2510.0[m]DCPETROS2520.0[m]DCPETROS2530.0[m]DCPETROS2540.0[m]DCPETROS2550.0[m]DCPETROS2560.0[m]DCPETROS2570.0[m]DCPETROS2580.0[m]DCPETROS2590.0[m]DCPETROS2600.0[m]DCPETROS2610.0[m]DCPETROS2620.0[m]DCPETROS3179.7[m]CAPT3179.8[m]COD3180.0[m]CAPT3180.1[m]CAPT3180.5[m]COD3180.5[m]CAPT3180.6[m]CAPT3180.9[m]CAPT3181.5[m]CAPT3181.8[m]CAPT3185.4[m]CAPT3186.6[m]COD3187.8[m]CAPT3188.9[m]CAPT3189.1[m]CAPT3189.9[m]CAPT3190.2[m]CAPT3190.5[m]COD3192.4[m]CAPT3195.3[m]CAPT3195.5[m]COD3195.5[m]CAPT3196.0[m]CAPT3196.4[m]CAPT3196.5[m]CAPT3197.4[m]COD3197.5[m]CAPT3197.9[m]CAPT3198.8[m]CAPT3201.6[m]CAPT3201.9[m]COD3202.2[m]CAPT3202.9[m]COD3203.0[m]CAPT3203.5[m]CAPT3205.6[m]CAPT3205.6[m]COD3206.9[m]CAPT3207.3[m]COD3208.9[m]CAPT3209.7[m]CAPT3210.4[m]CAPT3210.8[m]CAPT3210.9[m]COD3211.0[m]CAPT3211.9[m]CAPT3212.4[m]CAPT3212.8[m]COD3213.4[m]CAPT3213.9[m]COD3216.0[m]CAPT3216.4[m]COD3216.5[m]CAPT3217.9[m]CAPT3219.9[m]COD3221.6[m]CAPT3221.6[m]CAPT3221.8[m]CAPT3222.2[m]CAPT3222.7[m]COD3223.4[m]CAPT3224.3[m]CAPT3224.9[m]CAPT3224.9[m]COD3225.2[m]CAPT3225.6[m]CAPT3225.7[m]CAPT3226.0[m]CAPT3226.2[m]CAPT3226.5[m]CAPT3226.5[m]COD -
Oil samples at the Norwegian Offshore Directorate
Oil samples at the Norwegian Offshore Directorate Test typeBottle numberTop depth
MD [m]Bottom depth
MD [m]Fluid typeTest timeSamples availableDSTDST23196.003201.0027.06.1989 - 00:00YES -
Lithostratigraphy
Lithostratigraphy Top depth [mMD RKB]Lithostrat. unit13947055570070010921388144821602160222222922502260726302630285529802980299030083008313131863186319432313231 -
Composite logs
Composite logs Document nameDocument formatDocument size [MB]pdf0.43 -
Geochemical information
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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]pdf16.35 -
Drill stem tests (DST)
Drill stem tests (DST) Test numberFrom depth MD
[m]To depth MD
[m]Choke size
[mm]2.0319632019.5Drill stem tests (DST) Test numberFinal shut-in pressure
[MPa]Final flow pressure
[MPa]Bottom hole pressure
[MPa]Downhole temperature
[°C]2.0Drill stem tests (DST) Test numberOil
[Sm3/day]Gas
[Sm3/day]Oil density
[g/cm3]Gas grav. rel.airGOR
[m3/m3]2.0200350000.821170 -
Logs
Logs Log typeLog top depth [m]Log bottom depth [m]AMS30663306CBL VDL GR16903262DIL GR SLS11863057DIS GR SLS30663306DLL MSFL GR SP30663302EVA30653307FMS GR30663306HP RFT GR31883226LDL CNL NGS30663306LDL GR11863047MWD1393304SHDT GR11863058VSP12203240 -
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 typeCONDUCTOR30212.036212.00.00LOTINTERM.13 3/81185.017 1/21200.01.85LOTINTERM.9 5/83062.012 1/43077.01.81LOTLINER73304.08 1/23304.00.00LOT -
Drilling mud
Drilling mud Depth MD [m]Mud weight [g/cm3]Visc. [mPa.s]Yield point [Pa]Mud typeDate measured2121.08WATER BASED21.04.19898881.08WATER BASED24.04.198914671.0916.010.2WATER BASED26.04.198917411.1315.011.2WATER BASED27.04.198920161.2544.017.6WATER BASED08.05.198920441.1318.013.7WATER BASED28.04.198921091.1317.012.7WATER BASED02.05.198921201.2531.015.6WATER BASED05.05.198921901.26363.010.7WATER BASED08.05.198922321.2534.014.7WATER BASED05.05.198922481.2735.012.2WATER BASED09.05.198923291.1521.013.7WATER BASED02.05.198924141.2735.015.1WATER BASED11.05.198925081.2733.016.1WATER BASED12.05.198927671.2632.014.7WATER BASED18.05.198927811.2635.015.6WATER BASED19.05.198929011.2729.013.7WATER BASED22.05.198929521.2631.012.7WATER BASED22.05.198930141.2632.014.7WATER BASED23.05.198930771.2633.015.1WATER BASED24.05.198930781.1120.015.1WATER BASED30.05.198931151.1117.016.6WATER BASED30.05.198931771.1218.017.6WATER BASED31.05.198931971.1320.017.6WATER BASED01.06.198932151.1321.017.6WATER BASED02.06.198932411.13181.016.6WATER BASED05.06.198933041.1321.018.6WATER BASED05.06.1989 -
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]pdf0.22