31/2-3
Export: PDF
-
General information
-
Wellbore history
GeneralWell 31/2-3 was drilled in the Troll West area, approximately 8 km NNE of the Troll Discovery well 31/2-1. The well was drilled to appraise the Troll Discovery. It should evaluate reservoir parameters along the axis of maximum gross hydrocarbon column; prove maximum hydrocarbon reserves in the major northern fault block; confirm the significance of the seismic flatspot as a direct hydrocarbon indicator; further assess the significance of the oil shows found in 31/2-1; and evaluate the influence of earlier Kimmerian fault movements on reservoir characteristics.Operations and resultsAppraisal well 31/2-3 was spudded with the semi-submersible installation Borgny Dolphin on 28 March and drilled to TD at 2601 m in Late Triassic sediments in the Statfjord Formation. Drilling took 115 days. The reason for the long drilling period was safety inspection of the rig as a result of the "Alexander Kielland" accident and a strike amongst the Norwegian rig crew. The well was drilled with bentonite and seawater down to 816 m and with a gypsum/lignosulphonate mud from 816 m to TD.No potential reservoir zones were encountered above top Jurassic. The well confirmed that the Late Jurassic sandstone reservoir encountered in wells 31/2-1 and 2 was well developed also in this more northerly part of the structure. A gross gas column of 189 m was penetrated with top at 1384 m. The uppermost 120 m was in a good clean sand (Sognefjord Formation) while the lower part of the gas column was in a micaceous and poor reservoir sand (Heather and Fensfjord Formations). Below the gas a 12 m thick oil zone was encountered, the same thickness and at the same level as in well 31/2-2. In this well however, the oil was in a very micaceous and poorly developed reservoir. The reservoir was uncomformably overlain by Palaeocene claystones, which thus act as an effective seal for the reservoir. Below the OWC at 1585 no moveable hydrocarbons were seen in the well, but shows continued down to 1612 m and isolated shows were seen at 1630 m and at 1638 m.The seismic Flatspot did coincide with the base of the gas column in well 31/2-3, supporting that the Flatspot indeed is a direct hydrocarbon indicator over the entire prospect.Coring was performed in the Middle to Late Jurassic interval from 1412 m to 1645.5 m. Twenty-one cores with a total recovery of 194.4 m (84%) were cut. Coring started approximately 28 m below the top reservoir and continued well below the hydrocarbon/water contact. Prior to the full scale production test programme, a series of runs were made with the Schlumberger Repeat Formation Tester (RFT). A total of 10 RFT runs were made. The first run indicated pressure gradients very similar to those obtained in Wells 31/2-1 and 31/2-2. It was, however, impossible to confirm the 12-meter oil gradient indicated by RFT's in well 31/2-2. Sampling attempts in the water zone failed as only mud filtrate was recovered. In the suspected oil zone, no samples were obtained in spite of numerous attempts as the tool probe always plugged in the relatively tight and poorly consolidated formation. Only two gas samples were obtained, at 1458 m and 1568.5 m.The well was permanently abandoned on 20 July 1980 as a gas and oil appraisal well.TestingFour Production Tests were conducted in the Middle to Late Jurassic. PT1 tested the interval 1600.5 m to 1605.5 m in the water zone, PT2 tested the interval 1577.5 m to 1582.5 m in the oil zone, PT3 tested the interval 1520 m to 1535 m in the micaceous part of the gas bearing section, and PT4 tested 1435 m to 1460 m in the top clean sand of the gas section.After the bottom hole test valve was opened for the test in the water zone, the well flowed for 17 minutes until it died. Some 87.5 litres of formation water (70.000 ppm NaCl equivalent) were recovered.In the oil zone test (PT2) the well came in at a low rate and flowed at about 4.5 - 6.6 Sm3/day for four days. The oil was about 24 deg API and the GOR around 36 Sm3/Sm3. The micaceous gas zone test (PT3) stabilized at a rate of about 142000 Sm3/day on 28/64" choke during the clean up period. The produced fluids were gas of gravity 0.617 (air = 1) and condensate of 50.3 API, with some water (mostly brine) and traces of sediment. The gas contained no detectable H2S and approximately 0.4% C02. Sequential rate tests followed where the rates continuously improved up to 923000 Sm3/day. The test was terminated while production rates were still increasing. The reason for the increasing rates was assumed to be development of a channel behind the casing creating communication with the better sand some 10 meters above the top of the perforations. The clean sand gas test was performed with a gravel pack completion. Severe turbulence effects dominated it. After the initial clean up at 368000 - 481000 Sm3/day flow rate, the well produced at maximum rate of about 1133000 Sm3/day. The fluids had similar composition as in PT3.Temperatures measured during the test gave a formation temperature of 60 - 62 deg C in the gas-bearing section of the reservoir. This corresponds to a linear temperature gradient from seafloor to top reservoir of ca 50 deg C, which is very high for the area. -
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]460.002599.00 -
Cores at the Norwegian Offshore Directorate
Cores at the Norwegian Offshore Directorate Core sample numberCore sample - top depthCore sample - bottom depthCore sample depth - uom11412.01415.5[m ]21421.01425.0[m ]31425.01441.0[m ]41443.01449.3[m ]51450.01461.2[m ]61462.41467.8[m ]81469.21473.0[m ]91473.01475.0[m ]101484.51496.4[m ]111496.41514.5[m ]121514.51529.6[m ]131533.01540.9[m ]141551.01564.5[m ]151564.51566.5[m ]161566.61584.3[m ]171584.01599.7[m ]181601.01619.3[m ]191619.01623.9[m ]201624.01627.7[m ]211628.01645.4[m ]222116.02133.9[m ]Cores at the Norwegian Offshore Directorate Total core sample length [m]216.4Cores at the Norwegian Offshore Directorate Cores available for sampling?YES -
Core photos
-
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 availableDSTDST11577.001582.00WATER06.06.1980 - 20:00YES -
Lithostratigraphy
Lithostratigraphy Top depth [mMD RKB]Lithostrat. unit35964311451145120012421374138413841508156116771755181219021902201020552097217622362358 -
Composite logs
Composite logs Document nameDocument formatDocument size [MB]pdf0.45 -
Geochemical information
-
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]pdf35.06pdf1.29pdf2.43pdf0.44pdf10.79pdf10.10pdf0.36pdf0.06pdf0.44pdf0.12pdf139.86pdf17.61pdf20.73pdf6.05pdf1.25pdf0.77pdf1.51pdf1.22pdf1.66pdf1.43pdf0.60pdf0.84pdf0.54pdf1.97pdf2.69pdf0.50pdf1.12pdf0.32pdf0.71pdf0.35pdf0.34pdf0.33pdf0.34pdf0.56pdf0.28pdf0.20pdf0.23pdf0.38pdf0.14pdf0.69pdf2.60pdf0.75pdf2.06pdf2.29pdf11.20pdf6.07pdf5.32pdf9.81pdf3.63pdf6.10pdf1.31 -
Drill stem tests (DST)
Drill stem tests (DST) Test numberFrom depth MD
[m]To depth MD
[m]Choke size
[mm]1.0157515800.02.0155215576.43.01495151050.84.01410143538.1Drill stem tests (DST) Test numberFinal shut-in pressure
[MPa]Final flow pressure
[MPa]Bottom hole pressure
[MPa]Downhole temperature
[°C]1.02.03.04.0Drill stem tests (DST) Test numberOil
[Sm3/day]Gas
[Sm3/day]Oil density
[g/cm3]Gas grav. rel.airGOR
[m3/m3]1.02.0145600.910403.09140004.01133000 -
Logs
Logs Log typeLog top depth [m]Log bottom depth [m]CBL3501816CBL6301352CST10CST20CST30DLL MSFL GR13521824FDC CNL GR CAL445818FDC CNL GR CAL8031367FDC CNL GR CAL13521824FDC CNL GR CAL18172590HDT13521819HDT18172596ISF BHC GR SP445814ISF BHC GR SP8031368ISF BHC GR SP13521821ISF BHC GR SP18172593LSS GR445816LSS GR8031364LSS GR13521819LSS GR18172594RFT13871750 -
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 typeCONDUCTOR30420.036425.00.00LOTSURF.COND.20779.026789.01.43LOTINTERM.13 3/81328.017 1/21339.01.55LOTINTERM.9 5/81791.012 1/41798.01.74LOTLINER72576.08 1/22576.00.00LOT -
Drilling mud
Drilling mud Depth MD [m]Mud weight [g/cm3]Visc. [mPa.s]Yield point [Pa]Mud typeDate measured7891.3154.0seawater13381.3260.0seawater14331.2852.0seawater19411.1852.0seawater22671.1948.0seawater -
Thin sections at the Norwegian Offshore Directorate
Thin sections at the Norwegian Offshore Directorate DepthUnit1414.40[m ]1432.80[m ]1443.45[m ]1450.20[m ]1471.25[m ]1486.90[m ]1492.80[m ]1505.10[m ]1534.35[m ]1540.40[m ]1553.70[m ]1558.45[m ]1563.90[m ]1565.65[m ]1568.65[m ]7574.45[m ]1574.45[m ]1579.86[m ]1585.79[m ]7586.92[m ]1586.92[m ]1590.54[m ]1599.08[m ]1609.86[m ]1615.50[m ]1623.24[m ]1628.12[m ]1414.00[m ]1433.00[m ]1443.00[m ]1450.00[m ]1471.00[m ]1487.00[m ]1493.00[m ]1505.00[m ]1513.00[m ]1523.00[m ]1534.00[m ]1540.00[m ]1554.00[m ]1558.00[m ]1564.00[m ]1566.00[m ]1569.00[m ]1575.00[m ]1580.00[m ]1586.00[m ]1587.00[m ]1628.00[m ] -
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