3.7.4 RFT/MDT interpretation
The two samples collected at 4594.3 m and 4583.1 m during the MDT run contained weakhydrocarbon shows, a discontinues film of oil in the sample #1 and gas traces in the sample#2. Because of the failure of the MDT tool's equalization valve, a leakage between the twochambers was considered likely and therefore the location of these hydrocarbon shows isdoubtful. However they should more likely be attributed to the top part of the Upper JurassicSST as confirmed by the sample #3 collected in the following RFT run which contained at4594.3 m (same depth as sample #1) formation water. Only mud filtrate was finally recoveredin the sample #4 taken at 4614 m.
EXP/001832
3.1.5 Wireline formation testingIn the 12 1/4" hole section an RFT tool was run to take pressure measurements while in the 83/8" section both an MDT and an RFT tools were utilized in order to obtain pressure data andfluid samples (see TAB 3.5). Pressure test results and interpretation and samples descriptioncan be found in the Formation evaluation section.This is a summary of wireline formation testing opeartions in the well 2/5-10 from an operationpoint of view:
RFT in 12 1 /4" hole: 33 tests attempted23 tests successful (8 dry)12 tests lost seal
M DT in 8 3/8" hole: 19 tests attempted12 tests successful (2 dry)7 tests lost seal3 samples attempted2 samples recovered
RFT in 8 3/8" hole: 5 tests attempted5 tests successful4 samples attempted2 samples recovered
EXP/001832
Nr3
4
4
m Ml
A - 6
A - 5
B-6
26/7/93
20/8/93
21/8/93
HlSiliWPS
12 1/4' OH
83/8'OH
8 3/8* OH
mmfUrS;* liNi
23456789101 112131415161718192021222324252627282930313233
123456789101 11213141516171819
12345
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67686970717273747576777879808182838485868788899091929395969798991003456789101 112141516202122232425
89191020
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3410.853424.453433.73456.853499.53536.353578.33626
3651.653579.853812.63830.84113 .84127.13525.13526.553531.853530.84582.64582.94583.554594.44600.14594.34594.3
4583.154583.154583,34582.94583.14593.654583.254583.454583.74586.054582.64594.54594.34583.14590.554590.054614.054594.454586.14594.34614
3264.33268.753277.53294.53308.053334.053347.83356.753357.53363.63368.43378.553375.5
3392.353397.3
3410.853424.453433.73456.853499.53536.353578.33626
3651,653579.853812,63830.84113.84127.13525.13526.553531.853530.84582.64582.94583.554594.44600.14594.34594.34583.154583.154583.34582.94583.14593.654583.254583.454583.74586.054582.64594.54594.34583.14590.554590.054614.054594.454586.14594.34614
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RFT-B
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RFT-B
conventional
conventiona
conventiona
HP/Strain
HP/Strain
Strain
1
drydrydry
lost seallost seal
drylimeted drawdown
lost seallost seal
limited drawdownlimited drawdownlimited drawdownlimited drawdownlimited drawdownlimited drawdownlimited drawdownlimited drawdown
lost seallost seallost seal
limited drawdowndry
normaldry
unrecognizablelost seallost seallost seallost seal
drylost seal
drylimited drawdown
normalnormal
volumetricvolumetricvolumetricvolumetric
normalnormal
drydry
volumetricvolumetric
lost seallost seallost seallost seallost seallost seallost seal
sample #1sample #2
normalnormalnormalnormalnormal
sample #3sample #4
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WELL: 2/5-10 Mud Properties summary
•
22/06/9323/06/9324/06/9325/06/9326/06/9327/06/9328/06/9329/06/9330/06/9301/07/9302/07/9303/07/9304/07/9305/07/9306/07/9307/07/9308/07/9309/07/9310/07/9311/07/9312/07/9313/07/9314/07/9315/07/9316/07/9317/07/9318/07/9319/07/9320/07/9321/07/9322/07/9323/07/93
d
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3334353637383940414243444546474849505152535455565758596061626364
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5900
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Will: 2/5-10 Mud Properties summary
3oa
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WELL: 2/5-10 Mud Properties summary
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3.1.5 Wireline formation testing
An MDT run was carried out in the 8 3/8" section in order to obtain pressure data and fluidsamples (see TAB 3.5). Pressure test results and interpretation and samples description canbe found in the Formation evaluation section.
This is a summary of wireiine formation testing opeartions in the well 2/5-1OA from anoperation point of view:
M DT in 8 3/8" hole: 15 tests attempted12 tests successful (1 dry)3 tests lost seal6 samples attempted4 samples recovered
EXP/001877
RR - MDT
A - 4 15/9/93 8 3/8" OH 4620,14625.95
_4595.3_4600.4
MDT conventional HP/Strain abandoneddrawdown
47 4619,05 4594.3 drawdown48 4624.1 4598.6 drawdown49 4624.65 4599 abandoned5051
4627,554630.1
4602 lost seal4603.6
52 4634.05 4607drawdowndrawdown
4639.05 4611.2 lost seal10 54 4639.05 4611.2 lost sealn 55 4657,05 4625.712 56 4663.3 4631.2
drawdownnormal
13 57 4688,05 4651.7 drawdown14 59 4616 4591.9 abandoned15 60 4617 4592.7 dry
4619 4594.25 sample #14624.1 4598.6 sample #24630 46035 sample #34657 4625,65 sample #4
3.7.4 RFT/MDT interpretation
The pressure measurements achieved in the Jurassic section (see TAB 3.16, FIG 3.9 and3.10) did not allow to draw any reliable gradient through the points, there were noindications of hydrocarbon was detectable. The pore pressure gradient calculated from theRFT turned out to be around 2.03 g/cc very close to the actual mudweight utilized duringthis phase. The four samples collected at 4619 m, 4624.1 m, 4630 m and 4657 m containedformation water and mud filtrate with only traces of oil.
EXP/001877
WELL: 2/5 -10A Mud Properties summary
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27/08/9328/08/9329/08/9330/08/9331/08/9301/09/9302/09/9303/09/9304/09/9305/09/9306/09/9307/09/9308/09/9309/09/9310/09/9311/09/9312/09/9313/09/9314/09/9315/09/9316/09/9317/09/9318/09/9319/09/93
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435143064310431843184394442544604497450045414596461246214631464046684715471547154715471547154210
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565052383850605962535456574545404938293265313144
Mud
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2.042.032.042.042.042.032.032.032.032.032.042.032.042.042.032.032.062.062.072.062.062.062.062.06
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222222222222222222222222
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353636363636363636363535363636363636373535363636
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99.59.39.89.18.99.18.58.510
a.
0.40.80.50.40.50.40.40.30.50.50.40.30.40.20.20.30.40.50.20.30.30.30.60.6
H—Q-
0.20.30.30.30.30.20.20.10.30.30.20.10.20.20.20.20.20.40.10.20.30.20.40.4
5
1.31.42.21.81.81.51.41.21.61.51.4
11.41.61.72.11.82.51.31.52.42.32.72.6
U
88888888997668899995999
1 1
oO
1040760
1040920920
104012001280128012801000880880880800720600440520280560560560880
1"a>Ul
MILNE/ELSEN
MILNE/ELSEN
MILNE/ELSEN
MILNE/ELSEN
MILNE/ELSEN
ELSEN/WARDE
ELSEN/WAHDE
ELSEN/WARDE
ELSEN/WARDE
ELSEN/WARDE
WARDE/MAIN
WARDE/MAIN
WARDE
WARDE/MILNE
WARDE/MILNE
WARDE/MILNE
WARDE/MILNE
MILNE/ELSEN
MILNE/ELSEN
MILNE/ELSEN
MILNE/ELSEN
MILNE
MILNE
MILNE
NORSK AGIP.2/5-10-A
DETAILED DISCUSSION
8 3/8" HOLE INTERVAL
DRILLING
The previous hole, 2/5-10, was drilled vertically to 4701metres, it was then plugged back and the cement dressed off to4292 metres. At this point the mud was diluted with 60 % newmud to control the severe increase in rheology caused bycement contamination and high temperature. This dilution wascharged off to the original well and 509 cubic metres of mudrecorded as transferred to the new well.
The cement was tagged at 4292 metres and drillingproceeded with a kick off assembly and mud motor. This wasrun for 36 hours with little sign of it drilling out into theformation. The bit was pulled at 4306 metres.
Another higher angle assembly ( 2 . 2 5 degree bent sub) wasrun and the hole oriented to 4318 metres. Having kicked offand an angle built of 7.2 degrees, the assembly was thenpulled.
A new 1.25 degree bent sub was then run and the anglebuilt to 11.9 degrees at 4394 metres where a wiper trip wasmade to the shoe by backreaming. Drilling and orienting thencontinued to 4500 metres with the angle increasing to 24.7degrees. The bit was then pulled after backreaming to thecasing shoe. Penetration rate over this bit run variedbetween 1.5 and 3 metres per hour.
A new assembly was run without a mud motor and the holereamed from the kick off point before drilling continued to4612 metres where there was a drilling break. Bottoms up wascirculated and then, after a wiper trip to the shoe, the bitwas pulled to run a core barrel. The deviation at this pointwas 32.4degrees,and TVD 4588 m.
A 10 metre core barrel was run in the hole and bottomsup circulated before the core was cut at 4 - 8 metres/hour to4621 metres. Bottoms up was again circulated and then thebarrel pulled. Core recovery was 92%.
A second core barrel was then run and, after circulatingbottoms up, during which the trip gas reached 35% a core wascut to 4631 metres. Bottoms up was circulated and the corepulled out of the hole with 100% being recovered.
A wiper trip was made with a bit and bottoms up gasreached 34.5%; the hole was then logged with a gamma ray andthe bit pulled.
4.5.2.2
NORSK AGIP.
2/5-10-A
DETAILED DISCUSSION
8 3/8" HOLE SECTION (cont.)
DRILLING (cont.)A third core barrel was run in, and, after circulating
bottoms up with trip gas reaching 9%, cut a core to 4640metres. After circulating bottoms up the core was pulled tosurface with 9 2 . 6 % recoverey..
A new bit was run with DPR MWD tool and the hole loggedfrom 4206 metres to the bottom before drilling resumed.Thehole was drilled without problems to 4715m. (4674m TVD ) .After a short trip and circulating bottom's up with only 0.77%gas,the assembly was pulled for logging.
The mud, on bottom's up showed slightly increasedrheology, but remained stable. This confirmed the hot rollpilot tests on the rig, although these tests showed areduction in the lower end rheology which was not seen in thebottom's up samples. This difference may be due to the mudpicking up solids or filter cake off the wellbore whiletripping.Logging was completed in two sessions, with a wiper tripbetween sessions. Bottom's up mud showed increased rheologyand with the HTHP fluid loss of 17 ml/30 minutes.Maximum gaswas recorded at 9 . 9 % .
MUD TREATMENTS.
509 cubic metres of mud was transferred from the previouswell having already been diluted by 60% to combat cementcontamination. The initial concentration of chemicals in themud was as follows :-
IDF Polytemp 7.7 kg/m3IDF Hi Temp II 18.3 kg/m3Idthin 500 5 . 9 8 kg/m3Borrewe11 1.83 kg/m3
At the end of drillingthe mud was as follows:-
IDF PolytempIDF Hitemp IIIdthin 500Borrewe11
the concentration of chemicals in8 . 6 3 kg/m31 8 . 6 kg/m311.1 kg/m30 . 9 1 kg/m3
NORSK AGIP.
2/S-10-A
DETAILED DISCUSSION
8 3/8" HOLE SECTION (cont.)
MUD TREATMENT (cont.)
The concentration of IDF Hitemp II remained quiteconstant, but the IDF Polytemp and Idthin were increased. ThePolytemp gave improved rheological stability at temperature,and the Idthin 500 gave greater stability and fluid losscontrol after ageing. This was demonstrated in the laboratoryby treating field muds with alternative doses of chemicals,the results of which were sent out to the rig.
Premixes were made with 10-20% old mud as a base to whichwas added new mud with the following formulation:-
IDF Polytemp 10 kg/m3IDF Hi Temp II 15 kg/m3Gluteraldehyde 0.5 kg/m3Defoamer 0.5 kg/m3Barite for 2.03 sg.
Idthin 500 was added directly to the active system whenrequired to reduce rheology,in particular, Gel strengths. IDFPolytemp and IDF Hi Temp II were also added directly to theactive to control the Filtrate.
As drilling progressed no further Borrewell was added tothe mud and the concentration of IDF Polytemp increased. Thishad the result of improving the firmness of the filter cakeand high temperature stability. In particular, the filtrateremained stable and the gel strengths were reduced in hot rolltests at 325 degrees F.
Few cuttings were observed at the shakers whiledrilling and small dilutions with unweighted mud were madeperiodically in order to stop the mud weight from increasingdue to solids build up.
When bottoms up mud was checked after trips, all therheology parameters showed a slight increase due to increasedcuttings which were observed at the shakers, although hot rolltests indicated that the Yield Point of the mud would remainstable, Plastic Viscosity would increase, and the gelstrengths would be reduced. The bottoms up checks showed verylittle increase in Filtrate and a reduction in pH whichcorresponded well with the hot roll test results.
NORSK AGIP.2/5-10-A
DETAILED DISCUSSION
8 3/8" HOLE SECTION (cont.)MUD TREATMENT (CONT.)
Whole mud dilutions were made at the following depthswhile tripping.:-
DEPTH(m) VOLUME(m3) DILUTION(%)4394 40 174500 75 314612 33 134631 33 134640 33 12
SOLIDS CONTROL EQUIPMENT
The five shakers were installed with 60 mesh on the topand 150 mesh on bottom back and 180 mesh on bottom front.This configuration was kept throughout the section. Thecentrifuges were not run during this section for 3 reasons :-a) in order to maintain accurate volume measurements in theHTHP section.b) due to the high density of the mud the operation of thecentrifuges would process only a very small volume of mud;attempts to run the centrifuges had resulted in them becomingloaded up and stalling.c) a large amount of barite would be taken out as the cutpoint was not ideal; (the centrifuges were designed andinstalled originally for a cuttings wash system).
VOLUMES.
After completing the initial well 2/5-10, 509 m of Hitemppolymer mud were transferred to the sidetrack 2/5-10-A.At theend of drilling on day 18, prior to running logs and the P&Aproceedures,the volume analysis was as follows:
Start v o l u m e . . . . . . . . . . . . . . . . . 509 m3Total built . . . . . . . . . . . . . . . . . 3 9 2 m 3Total used . . . . . . . . . . . . . . . . . . 3 8 9 m 3Volume lost s u r f a c e . . . . . . . . . . 370 m3Volume lost sub/surface...... 19 m3Total volume l o s t . . . . . . . . . . . . 389 m3Final v o l u m e . . . . . . . . . . . . . . . . . 512 m3
NORSK AGIP.2/5-10-A
DETAILED DISCUSSION
SECTION COSTS
For this sidetrack, no estimate was prepared.The initial509 m3 of mud was charged off the last well 2/5-10.Taken as atthe end of the drilling on day 18 and before logging and theP&A proceedures, the costs were as follows:
Section c o s t . . . . . . . . . . . . . . . . . 966987.08 NOK.Section lenth . . . . . . . . . . . . . . . 4 2 3 M .Volume u s e d . . . . . . . . . . . . . . . . . . 3 8 9 M 3Cost / M 3 . . . . . . . . . . . . . . . . . . . 2485.82 NOK.Cost / M . . . . . . . . . . . . . . . . . . . . . 2286.02 NOK.
When compared with the original well 2/5-10, the cost per m3is greater at 2485.82NOK vs 2178.3 NOK. However, the costper meter of this sidetrack was less at 2286.02 NOK vs 3717.81NOK for the straight hole.The higher cost/m3 can be explained by the greaterconcentrations of chemicals in the mud at the end of thesidetrack compared with the original well. These are shownbelow:FINAL MUD CONCENTRATIONS: 2/5-10 2/5-10-A
IDF Polttemp 7. 6 7 kg/m3 8 . 6 3 kg/m3IDF HitempII 18.3 kg/m3 18.6 kg/m3IDTHIN 5 . 9 8 kg/m3 11.1 kg/m3Borewell 0.00 kg/m3 0 . 9 1 kg/m3
PLUG AND ABANDON.
After running the electric logs the decision was made to plugand abandon the well. Following the last logging run, opentubing was run in and two plugs were set. Plug #1 was setfrom 4715 m MD. to 4565 m, with plug #2 set from 4310 m.After cementing, mud was circulated b/up and 5 to 12 m3 ofhigh pH mud dumped. Borewell was added at 1.4kg/m3 in orderto control any increase in rheology due to cementinfluence.Plug #2 was tagged 2 meters inside the shoe, at 4125m.and athird plug was set.This plug was set from 4210 and was tagged at 4115m. Thecasing was successfully tested to 130 bar.Reserve mud was prepared at 1. 6 7 sg to displace the hole at2100 m.by diluting back with drill water and using IDVIS togive the required viscosity.At this stage the abandonment phase was reassigned to theinitial well (2/5-10) along with all associated costs.
4.5.2.3
NORSK AGIP
WELL; 2/s-io-A
VOLUME ANALYSIS 8.375*' HOLE SECTION
INITIAL VOLUME OF FLUID ON RIG:NET VOLUME RECEIVED ON RIG:VOLUME BUILT ON RIG.SUB TOTAL:SURFACE LOSSES:SUB SURFACE LOSSES:OTHER LOSSES:TOTAL LOSSES:VOLUME BACKLOADED TO TOWNVOLUME LEFT AT END OF INTERVAL:
5090
407916437280
465
0451
M3M3M3M3M3M3M3
M3
M3M3
IRRECOVERABLE VOLUME (TOTAL LOSSES):
COST SUMMARY 8.375" HOLE SECTION
465
ACTUAL
DEPTH DRILLED: (M)COST PER M:DAYS ON INTERVAL:COST PER DAY:ENGINEERING COST:IRRECOVERABLE VOLUME: (M3)COST PER M3:CEMENTING COST:NET INTERVAL COSTTOTAL INTERVAL COST
NOK
NOKNOKNOKNOKNOKNOK
4232370.31
2441776.66158400.00
4652463.49
0.001002639.721002639.72
M3
Schlumberger GECO-PRAKLA GEOLABJBNOR
2 2 APR. 1994REGISTRERTOLJEDIREKTORATET
Geochemical Report forWells NOCS 2/5-10 and 2/5-1 OA
Authors: Kjell Arne Bakkenlan L Ferriday
Geolab Nor A/SPostboks 5740 Fossegrenda7002 TrondheimNorway
Date : 14.02.94
Schlumberger GECO-PRAKLA ! GEOLABJfiNOR
Chapter 1
INTRODUCTION
The wells NOCS 2/5-10 and 2/5-1OA were analyzed on behalf of Norsk Agip byauthorization of Knut Schjerverud. At the request of Norsk Agip, the data arepresented in two separate reports, one for each of the wells, while the interpretationis in a separate report (this report) which includes interpretation for both wells.
The wells are located in the Norwegian sector of the North Sea and is situated in theCentral Graben. All depths given are relative to KB unless otherwise specified. Thelocation of the well is shown in Figure 1.
Samples (cuttings, side-wall cores and conventional cores) were supplied by NorskAgip and delivered to Geolab Nor's laboratory in Trondheim. A preliminary stratigraphywas provided by Norsk Agip and is used in this report. Note that this stratigraphy maydiffer slightly from the final stratigraphy.
Both screening and follow-up analyses were performed. Samples for analyses wereselected in agreement with Knut Schjerverud on a continuous basis. Well 2/5-10 wasanalyzed from 1000 m to 4350 m and 2/5-1 OA from 4350 m to 4750 m. The exceptionwas some samples from 2/5-10 which were analyzed from below 4350 m (see thedata report for 2/5-10). Conventional core samples were preferred for analyses whereavailable and side-wall cores were preferred to cuttings samples. The results arepresented in the relevant stratigraphic sections of this report.
The report is divided into chapters according to the various analytical methods used.Within the chapters the results are discussed mainly in a (descending) stratigraphiccontext.
Schlumberger GECO-PRAKLA GEOLAB^NOR
1.1 General Comments
The cuttings samples were supplied unwashed in bags. The samples were washed,described and picked before analyses commenced. The conventional core sampleswere supplied as core-chips which were used after removal of any superficialcontamination. The side-wall cores were cleansed of drill-mud before analyses.
The quality of the rock samples was good, except for cuttings samples from below4350 m in well NOCS 2/5-10. Some of these samples contained up to 100 % mudadditives, mainly barite. No analytical problems were encountered.
1.2 Analytical Program
In accordance with the contract, sample availability and the screening analysis results,the following analytical program was executed for the wells NOCS 2/5-10 (1000 m to4577.55 m) and 2/5-1OA (4348 m to 4712 m).
Well NOCS 2/5-10 (Tables in Data Report for Well NOCS 2/5-10)
Analysis type No of samples Figures Tables
Headspace and occluded Gas 19 3a-d 1 a-cLithology description 53 2a 2Rock-Eval pyrolysis 22 4-11 3
Thermal extraction and pyrolysis GC (GHM) 7 12 -14 4Soxhlet extraction of organic matter 2MPLC/HPLC separation 2 15 5a-dWhole oil GC 1
I ^ H Schlumberger gcUAlJs ai? M MIIll ÉM ^ ^ ^ ^ B33S!l
Table la: Cl to C7 hydrocarbons in(/jl gas/kg rock)
Project: 2/5-10Well: 2/5-10A
Depth unit of measure:
Depth
4352.4361.4370.4379.4388.4397.4406.4415.4424.4433.4442.4451.4460.4 4 6 9 .4478.4487.4496.4505.4514.4523.4532.4541.4550.
0000000000000000000000000000000000000000000000
Cl
34676265163322977710442041312412584483736064534646826074
326711300916580253549885077444927763277
C2
599510705297331125447598953062568398175867862532342978417
226041480016700360683747382509942994707
n
C3
126752456688719619
119397612790136326529
1276610615110657024
159754625539874593344 6 6 990528336551050215472
1-HEADSPACE gas
* Indicated
iC4
23755021198919822962954
1375662
14452575192224921358382286099487
20694724
10681051754684744
nC4
821315470689073509295295650272158404578955915752839269720327343290152686219635483418232422882304
values
C5+
831313501734076967990209362363233371979137312710840489278
362834275952366158832513087208021641411
in ml
sumC1-C4
3272562027224062436037353219312374011432218443919532378317542128744008142873110071165994137302703025264181361506816504
gas/kg
sumC2-C4
292585576220723220632964317511196099020
160003082226314264081660537934110*
97062149*
111952204220187136871229213227
rock
%wetness
8 9 . 48 9 . 99 2 . 59 0 . 67 9 . 47 9 . 98 2 . 67 8 . 973.37 8 . 681.383.278.08 6 . 277.188.29 0 . 081.58 1 . 67 9 . 975.58 1 . 680.1
iC4——nC4
0 . 2 90.320 . 2 90.270.320.320.270.310 . 3 60.330.320.330.350 . 3 90 . 2 60 . 2 90 . 3 90 . 3 30.300.310.320.300.32
I
- 2-Table la: Cl to C7 hydrocarbons in HEADSPACE gas
(jjl gas/kg rock)Project: 2/5-10
Well: 2/5-10ADepth unit of measure: n * Indicated values in ml gas/kg
sum sumDepth
45594568457745894601461046224631464046494658466746764685469447034712
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
Cl
115328674216
611886072870151695158619522275398199
56163628285
55123347
C2
10533831428110347720273855546452765022668661273171315234333959114512
C3
10225134502868278292873075455034773638536213123479665724375964395010
iC4
145788803
11131287145411837031116• 5 9 48661971033842479846679
nC4
370231921663178387139604019223834272059270265233702641166725392055
C5+
318212721092432414838584737146028432304157377830301924160423821968
C1-C4
3743149391649482653267243023023462176602497611401217913013
251161806995292124715603
C2-C4
259012072122782146520652215291829312502187819174
163932814
195001444192441573512256
rock
%wetness
6 9 . 280.874.426.077.371.278.070.875.280.575.29 3 . 477.67 9 . 99 7 . 074.17 8 . 6
<JtUL
iC4nC4
0 . 3 90.340.370.350.330.370 . 2 90.310.330.290.320.300.310.320 . 2 90.330.33
i «Hiimiti.M«.r« GECO-PRAKLA GEOL
- 1-Table lb: Cl to C7 hydrocarbons in CUTTINGS gas
( / ; ! gas/kg rock)Project: 2/5-10
Well: 2/5-10ADepth unit of measure: n * Indicated values
Depth
43524361437043794388439744064415442444334442445144604469447844874496450545144523453245414550
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
Cl
6218011268151114228407326397231276299276309500312373460495445439458
C2
3287302301542846253383895256316 6 9297607508141201138
219332992808245925232609
C3
30377261319818922658295423851526253330123348201632382316833917
11788972128541049181891055410425
iC4
12893444205210661725894
1107656
12751536139811041366817585630982302739533471251835263515
nC4
55161357885874583708934424785276751566101542646675398370125102649368512338146091264491021343213695
C5+
12270303372941812870206846468
178491113820423193931305514958138281019811373130191484340110264423885169063848134358
in ml gas/kg
sum sumC1-C4
1023225193141797763
119078029884357459815
11677110728360
109087618437848976295
269033517529909227133047430702
C2-C4
1017025013140677695
117567915861553389489
11280108418084
106097342406943975983
265303471529414222683003530244
source
%wetness
9 9 . 49 9 . 39 9 . 29 9 . 19 8 . 79 8 . 69 7 . 49 2 . 99 6 . 79 6 . 69 7 . 99 6 . 79 7 . 39 6 . 49 2 . 98 9 . 89 5 . 09 8 . 69 8 . 79 8 . 39 8 . 09 8 . 69 8 . 5
rockiC4nC4
0.230.250.240.230.240 . 2 60.230.240.250.250 . 2 60.240.250.220.230.240.270.250.270.270.280 . 2 60 . 2 6
i•JJHI H Schlumberger •naSjSgjI-ErTi M BBB ÉÉHM
- 2-Table lb: Cl to C7 hydrocarbons in CUTTINGS gas
(fjl gas/kg rock)Project: 2/5-10
Well: 2/5-10ADepth unit of measure: n * Indicated values
Depth
45594568457745894601461046224631464046494658466746764685469447034712
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
Cl
744209295185218243281368368186372226325210183263196
C2
35507871430601659726401
130014224782307105016011254844
12881294
C3
1068435356 3 6 628642981328926525649605629019044464668635111352952295267
iC4
32351174253911181070120312632078219311272564145121661504104816151531
nC4
117194433887541664261459148257728785344849867562884745875424862076186
C5+
23979445
2029310779128731222414633165911990112191194881307121589955195641017314681
1
in ml gas/kg
sum sumC1-C4
29932101381950589349189100529422
17123178929176241541300119429139549852
1460214474
C2-C4
291889929
192108749897198099141
16755175248990237821277519104137449 6 6 9
1433914278
source
%wetness
9 7 . 59 7 . 99 8 . 59 7 . 99 7 . 69 7 . 69 7 . 09 7 . 99 7 . 99 8 . 09 8 . 59 8 . 39 8 . 39 8 . 59 8 . 19 8 . 29 8 . 7
GEOL
rockiC4nC4
0.280 . 2 60 . 2 90.270.250 . 2 60 . 2 60.270.280.250 . 2 60 . 2 60 . 2 60 . 2 60.250 . 2 60.25
1 —— • i
— 1 —
Table lc: Cl to C7 hydrocarbons in HEADSPACE and CUTTINGS gas(/; ! gas/kg rock)
Project: 2/5-10Well: 2/5-10ADepth unit of measure: n * Indicated values in ml gas/kg source
sum sum %wetDepth
4352436143704379438843974406441544244433444244514460446944784487449645054514452345324541
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
Cl
3529644517952365786145344359281961708770629556224981635032980135091689229085448557248943215
C2
6323114353203326657316614564429574506821785315620490489252274515001168385799
116731019075586822
C3
157123182712069115111459710566102865158906215778139631308110262182914708840791605121364121906188271369915575
iC4
366484654041304846871848248213182720411133203596272446399194
101172167637515021452232724210
nC4
13729290481547711933163846398981249259201
1399611341121959324
134213524435550563711453418157160621142615720
C5+
205834383836758205662867485612408514371241422730620367220661787619476476565577867209416985895
269721898640645
C1-C4
42957872203658532123492602996032583171773165950872434504011432195516261472511149681722894063362205551734084945542
C2-C4
3942880775347902975841399254262822414358254894210237155344922721445276114*101*155*
3772556757496013595542327
ness
9 1 . 89 2 . 69 5 . 19 2 . 684.08 4 . 98 6 . 68 3 . 680.582.885.58 6 . 084.587.777. 688.39 0 . 29 2 . 89 1 . 28 9 . 988.09 2 . 9
vacui.
rockiC4nC4
0.270. 2 90 . 2 60 . 2 60.290.290.250.270.300.290.290 . 2 90.290.350.260.280.380 . 2 60.280.280.290.27
^-mmiiiimsuMU^ UtUU-HHAKLA j GEOL
- 2-
Table le: Cl to C7 hydrocarbons in HEADSPACE and CUTTINGS gas(fjl gas/kg rock)
Project: 2/5-10Well: 2/5-10ADepth unit of measure: n * Indicated values in ml gas/kg
sum sumDepth
4550.4559.4568.4577.4589.4601.4610.4622.4631.4640.4649.4658.4667.4676.4685.4694.4703.4712.
000000000000000000000000000000000000
Cl
3735189730764511
613736290894454505526656324135770425
5941383846857753543
C2
7316460346185711
109487861811159475827792431468919178187326488418371995806
C3
158971170686 6 9
113949 6 9 1
11273120191019710683137926754152575880
14829108357288
1166810277
iC4
425933801962334222312357265724462781330917213430164831992346152724612210
nC4
15999120896752
1104173448132855188449 9 6 6
112806543
125696280
118448516591587468241
C5+
357692715
11572224021321117021160821937018051227441449521061138492461911475111681255516649
C1-C4
472063367525077359999158735913402823288434783428682057745945160144454532023193813584930077
C2-C4
434713177822001314883021429623313382743429257363051816440175155893860428185189133007426534
source
%wetness
9 2 . 19 4 . 487.787.533.082.577.883.484.184.788.387.49 7 . 48 6 . 788.09 7 . 68 3 . 988.2
rockiC4nC4
0.270.280 . 2 90.300.300 . 2 90.310.280.280 . 2 90 . 2 60.270 . 2 60.270.280 . 2 60.280.27
Schtumberger GECO-PRAKLA GEOLAB5BNOR
- 1-
Table 2 i Lithology description for well NOCS 2/5-10ADepth unit of measure: mDepth Type Grp Frm AgeInt Cvd TOC% % Lithology description
Trb Sample
4348.00 swc4.02 100 Sh/Clst: dsk y brn to brn blk
4352.00
4361.00
100 Sh/Clst: brn blk
100 Sh/Clst: brn blk
4365.00 swc3 . 9 0 100 Sh/Clst: dsk y brn to brn blk
4370.00
4379.00
4388.00
100 Sh/Clst: brn blktr Sh/Clst: gy redtr Ca : w to lt gy, chk
100 Sh/Clst: brn blktr Sh/Clst: gy redtr Ca : w to lt gy, chk
100 Sh/Clst: brn blktr Sh/Clst: gy redtr Cont : prp
00010001-1L
00260026-1L
00270027-1L
00020002-1L
00280028-1L0028-2L0028-3L
00290029-1L0029-2L0029-3L
00300030-1L0030-2L0030-3L
Schlumberger GECO-PRAKLA GEOLABJfiNOR
Table 2 : Lithology description for well NOCS 2/5-10ADepth unit of measure: mDepth Type Grp Frm AgeInt Cvd TOC% % Lithology description
4395.00 swc4 . 3 6 100 Sh/Clst: dsk y brn to brn blk
4397.00100 Sh/Clst: brn blktr Sh/Clst: gy redtr Cont : prp
4405.00 swc1.54 100 Sh/Clst: dsk y brn to brn blk
4406.00
4415.00
4424.002.18
100 Sh/Clst: gy blk to brn blktr Sh/Clst: gy redtr Ca : w to lt gy, chk
80 Sh/Clst: gy blk, dol10 Ca : lt gy10 Sh/Clst: dsk y brn, dol
95 Sh/Clst: gy blk to brn blk5 Sh/Clst: dsk y brn, dol
tr Ca : lt gy
Trb Sample
00040004-1L
00310031-1L0031-2L0031-3L
00030003-1L
00320032-1L0032-2L0032-3L
00330033-1L0033-2L0033-3L
00340034-1L0034-3L0034-2L
Schlumberger GECO-PRAKLA GEOLABJfiNOR
Table 2 : Lithology description for well NOCS 2/5-10ADepth unit of measure: mDepth Type Grp Frm AgeInt Cvd TOC% % Lithology description
Trb Sample
4433.0095 Sh/Clst: gy blk to brn blk5 Cont : prp
tr Ca : lt gytr Sh/Clst: dsk y brn, dol
00350035-1L0035-4L0035-2L0035-3L
4442.0095 Sh/Clst: gy blk to brn blk5 Cont : prp
tr Ca : lt gytr Sh/Clst: dsk y brn, dol
00360036-1L0036-4L0036-2L0036-3L
4451.00 swc2. 3 6 100 Sh/Clst: dsk y brn to brn blk
00050005-1L
4451.0095 Sh/Clst: gy blk to brn blk5 Cont : prp
tr Sh/Clst: dsk y brn, dol
00370037-1L0037-3L0037-2L
4460.0090 Sh/Clst: gy blk to brn blk10 Ca : lt gy, prptr Sh/Clst: dsk y brn, dol
00380038-1L0038-3L0038-2L
4469.002.41 100 Sh/Clst: gy blk
tr Sh/Clst: dsk y brn, doltr Ca : lt gy, prp
00390039-1L0039-2L0039-3L