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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

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3.1.5 Wireline formation testingIn the 12 1/4" hole section an RFT tool was run to take pressure measurements w hile in the 83/8" section both an MDT and an RFT tools were utilized in order to obtain pressure da ta 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)1 2 tests lost sealM DT in 8 3/8" hole: 19 tests attempted1 2 tests successful (2 dry)7 tests lost seal3 samples attempted2 samples recoveredRF T in 83/8" hole: 5 tests attempted5 tests successful4 samples attempted2 samples recovered

EXP/001832

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Nr3

4

4

m MlA-6

A- 5

B- 6

26/7/93

20/8/93

21 /8 /93

HSlWPS1 2 1/4' O H

83/8'OH

8 3/8* OH

mmf U r S ; * liNi2

34567891 01 11 21 31 41 51 61 71 81 9202 12223242526272829303 132331234567891 01 11 21 31 41 51 61 71 81 9

12345

RFT - MDT676869707 17273747576777879808 18283848586878889909 19293959697989910034567891 01 11 21 41 51 6202 122232425

891 91 020

i3264.33268.753277.53294.53308.053334.053347.83356.753357.53363.63368.43378.553375.53392.353397.33410.853424.453433.73456.853499.53536.353578.3

36263651.653579.853812.63830.84 1 1 3 . 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

3264.33268.753277.53294.53308.053334.053347.83356.753357.53363.63368.43378.553375.53392.353397.33410.853424.453433.73456.853499.53536.353578.3

36263651,653579.853812 ,63830.84 1 1 3 . 84127.13525.13526.553531.853530.84582.64582.94583.554594.44600.14594.34594.3

4583.154583.154583.34582.94583.14593.654583.254583.454583.74586.054582.64594.54594.34583.14590.554590.054614.054594.454586.14594.34614fe;; .:'m^f^:mi!Mmiimm

11RFT-B

MDT

RFT-B

conventional

conventiona

conventiona

HP/Strain

HP/Strain

Strain

1

drydrydrylost seallost sealdrylimeted drawdown

lost seallost seallimited drawdownlimited drawdownlimited drawdownlimited drawdownlimited drawdownlimited drawdownlimited drawdownlimited drawdown

lost seallost seallost seallimited drawdowndrynormaldryunrecognizablelost seal

lost seallost seallost seal

drylost seal

drylimited drawdownnormalnormal

volumetricvolumetricvolumetricvolumetricnormal

normaldrydryvolumetricvolumetric

lost seallost seallost seallost seallost seallost seallost sealsample #1

sample #2normalnormalnormalnormalnormal

sample #3sample #4

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XA/CI 1 O /C Irt K /li i 4 B * v*A!,>%*> iwfci tj*!***

-2"oQ

dzo.d)a.v >Q

4 r

MT

rm H,/U

Q.CM"ati0)0 M

Tm

C

4MPA

o.2C

u_ >C L. CL>

IVH

o0))O"0)C D

JM 1

cEo1)CD

' IV

_i

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WELL: 2/5 -10 Mud Properties summ ary

^22/06/9323/06/9324/06/9325/06/9326/06/9327/06/9328/06/9329/06/9330/06/930 1 / 0 7 /9302/07/9303/07/9304/07/9305/07/9306/07/9307/07/9308/07/9309/07/9310/07/931 1 / 07 /9 312/07 /9313 / 0 7 / 9314/07/9315/07 /9316 /07 /9317 /07 /9318 / 0 7 / 9319 / 0 7 / 9320/07/932 1 / 0 7 / 9322/07/9323/07/93

dIJ3 >Q33343536373839404 14243444546474849505 15253545556575859606 1626364

MT

KCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL / P O LYKCL/POLYKCL / P O LYKCL / P O LYKCL / P O LYKCL / P O LYKCL/POLYKCL / P O LYKCL/POLYKCL/POLYKCL / P O LYKCL / P O LYKCL/POLYKCL/POLYKCL/POLYKCL / P O LYKCL / P O LYKCL/POLYKCL / P O LY

Dha12pm

32053 2 1 1325233083362347134713494350235023502350235023502350235023586365236803726383739303957396839874035407740984 1 1 14 1 4 242004227

MTm

MW

59005859057585848382926

26262454584453566048586467706727666727

.63

.63

.63.63,631.631.631 . 6 11 . 6 11 . 6 11 . 6 11 . 6 11 . 6 11.631.621 , 6 11 . 6 11 . 6 11 . 6 11 . 6 11 . 6 11 . 6 11 . 6 11 . 6 11 . 6 11 . 6 11 . 6 11 . 6 11 . 6 11.661.661.66

FVs

596058596563606859648082899 19389575760555353|66565556565360676258

>CL

425 15 146484944666249424849484948424046444 1424242454444475 1505 139

a.">1 11 19

1 11 21 21 21 21 31 1999

1 01 01 199

1 088

1 01 01 11 01 41 31 31 51 31 31 2

o0)vtO"0)CD

23222223222222222222211222323333

co"0)CD

99777787665556663354434466867978

_iCLuu

MADMLAURITZENMAIN/LAURITZENMAIN/LAURITZENMANLAUHTZENMAIN/LAURITZENMAIN/LAURITZENLAURITZEN/EL9ENLAUMTZEN/ELSENLAURITZEN/ELSENELSEN/NORDBYELSEN/NOHDBYELSEN/NORDBYELSEN/NORDBYELSEN/NORDBYELSBN/NORDBYELSEN/NORDBYELSEN/NORDBYMAIN/NORDBYMAIN/NORDBYMAIN/NORDBYMAIN/NORDBYMAIN/NORDBYMAIN/NORDBYMAIN/MILNEMANMILNEMANMILNEMANMILNEMILNE/ELSENMILNE/ELSENMILNEELSENMILNE/ELSENMILNE/ELSEN

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WE LL : 2/5 -10 Mud Properties summary

5oadza&o>a M

TQ.

CM"aa& M

TmMW

FVs >ol a!>

0"CD

cEooCD

_ joCL353736363635373739393540393835363535254033323939

a.>64544768

1 11 199

1 11 11 01 01 11 01 44

1 11 197

uU

MILNE/ELSENMILNE/ELSENMILNEELSENMILNE/ELSENMILNE/ELSENELSENWARDEELSENWAHDEELSENWARDEELSENWARDEELSENWARDEWARDE/MAINWARDE/MAINWARDEWARDE/MILNEWARDE/MILNEWARDE/MILNEWARDE/MILNEMILNEELSENMILNEELSENMILNE/ELSENMILNEELSENMILNEMILNEMILNE

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NORSK AGIP.2/5-10-A

DETAILED DISCUSSION

8 3 / 8 " HOLE INTERVALDRILLING

The previous h o l e , 2 / 5 - 1 0 , 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 . 2 5 degree bent sub was then run and the anglebuilt to 1 1 . 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 2 4 . 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 9 2 % .A second core barrel was then run a n d , 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 3 4 . 5 % ; the hole was then logged with a gamma ray andthe bit pulled.

4 . 5 . 2 . 2

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NORSK AGIP.2/5-10-A

DETAILED DISCUSSION

8 3 / 8 " HOLE SECTION ( c o n t . )DRILLING ( c o n t . )

A third core barrel was run in, a n d , after circulatingbottoms 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 4715 m. ( 4674m TVD ) .After a short trip and circulating bottom's up with only 0.77%gas,the assembly was pulled for logging.The m u d , on bottom's up showed slightly increasedrheology, but remained stable. This confirmed the hot rollpilot tests on the r i g , 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 1 8.3 kg/m3Idthin 5 0 0 5 . 9 8 kg/m3Borrewe11 1 . 8 3 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/m31 1 . 1 kg/m30 . 9 1 kg/m3

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NORSK AGIP.2/S-10-A

DETAILED DISCUSSION

8 3/8" HOLE SECTION ( c o n t . )MUD TREATMENT ( c o n t . )

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 . 0 3 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.

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NORSK AGIP.2/5-10-A

DETAILED DISCUSSION

8 3/8" HOLE SECTION ( c o n t . )MUD TREATMENT ( C O N T . )

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 EQUIPMENTThe 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 s y s t e m ) .

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 . . . . . . . . . . . . . . . . . 5 0 9 m 3Total built . . . . . . . . . . . . . . . . . 3 9 2 m 3Total used . . . . . . . . . . . . . . . . . . 3 8 9 m 3Volume lost s u r f a c e . . . . . . . . . . 370 m 3Volume lost s u b / s u r f a c e . . . . . . 19 m3Total volume l o s t . . . . . . . . . . . . 38 9 m 3Final v o l u m e . . . . . . . . . . . . . . . . . 5 1 2 m 3

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NORSK AGIP.2/5-10-A

DETAILED DISCUSSION

SECTION COSTSFor 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 . . . . . . . . . . . . . . . . . 9 6 6 9 8 7 . 0 8 N O K.Section lenth . . . . . . . . . . . . . . . 4 2 3 M .Volume u s e d . . . . . . . . . . . . . . . . . . 3 8 9 M 3Cost / M 3 . . . . . . . . . . . . . . . . . . . 2485.82 N OK .Cost / M . . . . . . . . . . . . . . . . . . . . . 2 2 8 6 . 0 2 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 2 2 8 6 . 0 2 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 1 8 . 3 kg/m3 1 8 . 6 kg/m3IDTHIN 5 . 9 8 kg/m3 1 1 . 1 kg/m3Borewell 0 . 0 0 kg/m3 0 . 9 1 kg/m3PLUG 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/upand 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 . b y 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 - 1 0 ) along with all associated costs.

4 . 5 . 2 . 3

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NORSK AGIPW E L L ; 2/s-io-A

VOLUME ANALYSIS 8.375*' HOLE SECTIONINITIAL VOLUME OF FLUID ON R I G :NE T VOLUME RECEIVED ON R I G :VOLUME BUILT ON R I G .SUB TOTAL:SURFACE LOSSES:SUB SURFACE LOSSES:OTHER LOSSES:TOTAL LOSSES:VOLUME BACKLOADED TO TOWNVOLUME LEFT AT END OF INTERVAL:

5 0 904079 1 643728046 50451

M3M3M3M3M3M3M3M3M3M3

IRRECOVERABLE VOLUME (TOTAL LOSSES):COST SUMMARY 8 . 3 7 5 " HOLE SECTION

465

ACTUALDEPTH DRILLED: ( M)COST PER M:DAYS ON INTERVAL:COST PER D A Y :ENGINEERING COST:IRRECOVERABLE VOLUME: ( M 3 )COST PER M3:CEMENTING COST:NET INTERVAL COSTTOTAL INTERVAL COST

NOKNOKNOKNOKNOKNOKNOK

4232370.31244 1 7 7 6 . 6 6158400.004652 4 6 3 . 4 90 . 0 0

1 0 0 2 6 3 9 . 7 21 0 0 2 6 3 9 . 7 2

M3

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Schlumberger GECO-PRAKLA GEOLABJBNOR

2 2 A P R . 1994

REGISTRERTOLJEDIREKTORATET

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

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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 we lls, w hile 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 an d 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 an d 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 O A 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 an d 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.Wthin the chapters the results are discussed mainly in a (descending) stratigraphiccontext.

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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 con tract, sample availability and the screening analysis results,the following analytical program was executed for the w ells NOC S 2/5-10 ( 1 0 0 0 m to4577.55 m) and 2/5-1OA (4348 m to 4 7 1 2 m).Well NOCS 2/5-10 (Tables in D ata Report for W ell NOCS 2 /5 -10)

Analysis type No of samples Figures Tables

Headspace and occluded Gas 19 3a-d1 a-cLithology description 53 2a 2Rock-Eval pyrolysis 22 4-113Thermal extraction and pyrolysis GC ( G H M ) 7 12-14 4Soxhlet extraction of organic matter 2MPLC/ H PLC separation 2 1 5 5adW hole oil GC 1

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Appendix 1 ATables

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I^ H Schlumberger gcUAlJsai? M MIIllM ^ ^ ^ ^B33S!l

Table l a : Cl to C7 hydrocarbons in( / j l gas/kg r o c k )P r o j e c t : 2/5-10Well: 2/5-10ADepth unit of measure:

Depth4 3 5 2 .4 3 6 1 .4 3 7 0 .4 3 7 9 .4388.4 3 9 7 .4 4 0 6 .4415.4424.4 4 3 3 .4442.4 4 5 1 .4 4 6 0 .4 4 6 9 .4478.4487.4 4 9 6 .450 5.4 5 1 4 .4 5 2 3 .4 5 3 2 .4 5 4 1 .4 5 5 0 .

0000000000000000000000000000000000000000000000

Cl

34676 2 6 516332 2 9 77710442041312412584483736 0 6 4534646826074

326711 3 0 0 916580253549885077444927763277

C25 9 9 5

107052 973311254475 9 8 95 3 0 62 5 6 8398175867862532342978417

2 2 6 0 414800167003 6 0 6837473825 0 9 942 9 94707

n

C3

126752 4 5 6 688719 6 1 9

1 1 9 3 9761279 0 136326 5 2 9

1276610615110657024

1597546255398745 93344 6 6 99 0 5 28336551050215472

1-HEADSPACE gas

* Indicated

iC4

237550211 9 8 919822 9 6 29 5 4

13756 6 2

144525751 9 2 2249 21358382286 0 99487

2 0 6 9 472 4

1068105175 4684744

nC4

8213154706 8 9 073509 2 9 52 9 5 6502721584045789559 1575283 9 2 69720

327343 2 9 0 15 2 6 862 1 9 635483418232422882304

values

C5+

83131350173407 6 9 679 9 02 0 9 36 2 3 63233371979137312710840489278

36283427595 2 3 6 615883251308720802 1641411

in mlsumC1-C4327256 2 0 272 2 4 0 624360373532 1 9 3 12374011432218443 9 1 9 532378317542128744008

1428731100711 6 5 9 9 413730270302 5 2 64181361 5 0 6 816504

gas/kgsumC2-C4

2 9 2 5 85 5762207232 2 0 6 32 9 6 43175111 9 6 0 99 0 2 0

1 6 0 0 0308222 63 14264081 6 6 0 537934

110*9 7 0 6 2

149*1 1 1 9 52204220187136871 2 2 9 213227

rock%wetness8 9 . 48 9 . 99 2 . 59 0 . 67 9 . 47 9 . 98 2 . 67 8 . 97 3 . 37 8 . 68 1 . 38 3 . 278. 08 6 . 277.188. 29 0 . 08 1 . 58 1 . 67 9 . 97 5 . 58 1 . 68 0 . 1

iC4nC4

0 . 2 90 . 3 20 . 2 90 . 2 70 . 3 20 . 3 20 . 2 70 . 3 10 . 3 60 . 3 30 . 3 20 . 3 30 . 3 50 . 3 90 . 2 60 . 2 90 . 3 90 . 3 30 . 3 00 . 3 10 . 3 20 . 3 00 . 3 2

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I

- 2-Table la: Cl to C7 hydrocarbons in HEADSPACE gas( j j l gas/kg r o c k )Project: 2/5-10W e l l : 2/5-10ADepth unit of measure: n * Indicated values in ml gas/kg

sum sumDepth455945684577458946014610462246314640464946584667467646854 6 9 447034712

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

Cl

115328674216

61188607287015 1 6 951586 1 9 5222753981 9 9

5 6 1 63628285

55123347

C2

10533831428110347720273855 54645276 5 0 2266866 1 2731

71315234333959 114512

C31022513450286827829287307545503477363853621312347 9 6 6572437596 4 3 95010

iC4

145788803

1113128714541183703

1 1 16 5 9 48 6 61 97

10338424798466 7 9

nC4

3702 3 1 92 1 6 631783871396 04019223834272 0 5 9270265 2

33702641166725392055

C5 +318

2127210924324148385847371460284323041573778

30301 9 2 41 6 0423821 9 68

C1-C4

37431 4 9 3 91 6 4 9 482653267243023023462176602497611401217913013

2 5 1 1 6180699 5 2 9

212471 56 03

C2-C42 5 9 0

1207212278214652 0 6 5 22 1 5 2 91829312502187819174

163932814

1 9 5 0 0144419244

157351 2 2 56

rock

%wetness6 9 . 28 0 .87 4 . 42 6 . 077.37 1 . 278. 070 .87 5 . 280. 575 . 29 3 . 47 7 . 67 9 . 99 7 . 074.17 8 . 6

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i Hiimiti.M.r GECO-PRAKLA GEOL

- 1-Table lb: Cl to C7 hydrocarbons in CUTTINGS gas( / ; ! gas/kg r o c k )P r o j e c t : 2/5-10

Well: 2/5-10ADepth unit of measure: n * Indicated values

Depth43524361437043794388439744064415442444334442445144604 4 6 9447844874496450545144523453245414550

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

Cl

6 218011268

15111422840732 63972312 762 9 92 7630 950031 237346049 5445439458

C2

32873023015428462 53383895256316 6 92 9 760 7508141201138

21933 2 9 928082 4 5 92 5 232 6 0 9

C3

30377261319818922 6 5 82 9 5 4238515262533301233482016323823168339 1 7

11788972128541049181891055410425

iC4

1289344420521 0 6 61725894

11076 5 6

127515361398110413668175856309 82

302739 533471251835263515

nC4

5516135788587458370893442478527675 1 5661015426466753983701251026493685

123381 46 0 91 26449102

134321 3 6 9 5

C5+12270303372941812870206846468

1784911138204231 9 3 9 313055149581382810198113731301914843401102644

238851 6 9 0 63848134358

in ml gas/kgsum sumC1-C4102322 5 1 9 3141797763

119078029884357459815

11677110728360

1 0 9 087618437848976 2 9 5

2 6 9 0 3351752 9 9 0 9227133047430702

C2-C4

1017025013140677695

117567915861553389489

11280108418084

1 0 6 0 973424 0 6 943975983

26530347152 94 1 42 2 2 683003530244

source%wetness9 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 . 2 30 . 2 50 . 2 40 . 2 30 . 2 40 . 2 60 . 2 30 . 2 40 . 2 50 . 2 50 . 2 60 . 2 40 . 2 50 . 2 20 . 2 30 . 2 40 . 2 70 . 2 50 . 2 70 . 2 70 . 2 80 . 2 60 . 2 6

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JJHI H Schlumberger naSjSgjI-ErTi M BBB HM

- 2-Table lb: Cl to C7 hydrocarbons in CUTTINGS gas( f j l gas/kg r o c k )P r o j e c t : 2/5-10Well: 2/5-10ADepth unit of measure: n * Indicated values

Depth4559456845774589460146104622463146404649465846674676468546 9 447034712

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

Cl

7442 0 92 9 51852182432813683681 863722 263252101832 631 9 6

C23550787

143060 16 5 972 6401

130014224782307105016011254844

12881294

C3

1068435356 3 6 62864298132892 6 5 256496 0 5 62901904446466863511135295 2 2 95 267

iC4323511742 5391118107012031 263207821931127256414512 1 6 61504104816151531

nC4

117194433887541664261459148257728785344849867562884745875424862076186

C5+

23979445

2 0 2 9 3107791287312224146331 6 5 9 11 9 9 0 11219119488130712158995519 5 6 4

1017314681

1

in ml gas/kgsum sumC1-C42 9 9 3 2101381 9 5 0 589349 1 8 9100529422

17123178929 1 7 624154130011 9 4 2 91 3 9 5 49852

1460 214474

C2-C4291889 9 2 9

19210874989719 8 0 99141

16755175248 9 9 023782127751 9 1 0413744

9 6 6 91433914278

source%wetness9 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 . 2 80 . 2 60 . 2 90 . 2 70 . 2 50 . 2 60 . 2 60 . 2 70 . 2 80 . 2 50 . 2 60 . 2 60 . 2 60 . 2 60 . 2 50 . 2 60 . 2 5

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1 i

1

Table lc: Cl to C7 hydrocarbons in HEADSPACE and CUTTINGS gas( / ; ! gas/kg r o c k )P r o j e c t : 2/5-10Well: 2/5-10ADepth unit of m e a s u r e : n * Indicated values in ml gas/kg source

sum sum %wetDepth43524 3 6 143704379438843974406441544244433444244514460446944784487449645054514452345324541

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

.0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

. 0 0

Cl

35 2 96445179523657861453443592819617087706 2 9 55 6 2 249816350

3298013 5091689 22 9 0 85448557248943215

C2

63231143532033 26657316 6 1 456442 9 5 7450682178531562 0490489252274515001168385 7 9 9

116731 0 1 9 075586822

C3

15712318271 2 0 6 911511145971 0 5 6 61028651589 0 6 2157781 3 9 6 3130811 0 26 21829147088407916051 2136412 1 9 0 6188271 3 6 9 915575

iC4366484654041304846871848248213182720411133203 5 9 627244 6 3 99 1 9 4

101172 167637515021452232724210

nC41372929 048154771 1933163846 3 9 8981249259 2 0 1

1 3 9 9 6113411 2 1 9 59324

1342135244355505637114534181571 6 0 6 21142615720

C5 +2058343838367582 0 5 6 6286748 5 6 124085143712414227306203672 2 0 6 6178761 9476476565577867209416 985895

269721898640645

C1-C4

429578722036585321234926 02 9 9 6 0325831717731659508724345040114321955 1 6 2 61472511 14968172289406336 2 2 0 5551734084945542

C2-C43942880775347902975841399254262822414358254894210237155344922721445276

114*101*155*

3772556757496 013595 542327

ness9 1 . 89 2 . 69 5 . 19 2 . 68 4 . 08 4 . 98 6 . 68 3 . 68 0 . 58 2 . 88 5 . 58 6 . 08 4 . 58 7 . 77 7 . 68 8 . 39 0 . 29 2 . 89 1 . 28 9 . 98 8 . 09 2 . 9

vacui.

rockiC4nC4

0 . 2 70 . 2 90 . 2 60 . 2 60 . 2 90 . 2 90 . 2 50 . 2 70 . 3 00 . 2 90 . 2 90 . 2 90 . 2 90 . 3 50 . 2 60 . 2 80 . 3 80 . 2 60 . 2 80 . 2 80 . 2 90 . 2 7

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^-mmiiiimsuMU^ UtUU-HHAKLA j GEOL

- 2-

Table le: Cl to C7 hydrocarbons in HEADSPACE and CUTTINGS gas( f j l gas/kg r o c k )P r o j e c t : 2/5-10Well: 2/5-10ADepth unit of m e a s u r e : n * Indicated values in ml gas/kg

sum sumDepth4550.4 5 5 9 .4 5 6 8 .4577.4 5 8 9 .4 6 0 1 .4 6 1 0 .4 6 2 2 .4 6 3 1 .4 6 4 0 .4 6 4 9 .4 6 5 8 .4 6 6 7 .4 6 7 6 .4 6 8 5 .4 6 9 4 .4703.4 7 1 2 .

000000000000000000000000000000000000

Cl

37351 8 9 730764 5 1 1

613736 2 9 0894454505 5 2 66 5 6 32 4 1 35770425

5 9 4 1383846857753543

C27 3 1 646034 6 1 85 7 1 1

1 0 9 487 8 6 181115947582779243 1 4 68 9 1 91 7 8 1873264884 1 8 37 1 9 95806

C3

1 58971 1 7 0 68 6 6 9

1 1 3 9 49 6 9 1

1 1 2 7 31 2 0 1 91 0 1 9 710683137926754

152575880

14829108357288

1 1 6 6 810277

iC4

425933801 9 6 233422 2 3 1235726 5724462 7 8 1330917 2134301 6 4 83 1 9 923461 5 2 72 4 6 12 2 1 0

nC 4

1 5 9 9 9120896752

1104173448 1 3 28 5 5 188449 9 6 6

1 1 2 8 06543

1 2 5 6 96280

1 1 8 4 48 5 1 65 9 1 587468 2 4 1

C5+

357692 7 1 5

1 1 5 7 2224021 3 2 1 11 7 0 2 116082193701 8 0 5 122744144952 1 0 6 1138492 4 6 1 9114751 1 1 6 8125551 6 6 4 9

C 1 - C 4

4720633675250773 5 9 9 9915873 5 9 1 34028232884347834286820577459451 6 0 1 444545320231 9 3 8 13584930077

C2-C443471317782200131488302142 9 6 2 331338274342 9 2 5 7363051 8 1 6 4401751 5 58 938604281851 8 9 1 3300742 6 5 34

source

% w e tness9 2 . 19 4 . 48 7 . 78 7 . 53 3 . 08 2 . 57 7 . 88 3 . 48 4 . 18 4 . 78 8 . 38 7 . 49 7 . 48 6 . 78 8 . 09 7 . 68 3 . 98 8 . 2

rockiC4nC4

0 . 2 70 . 2 80 . 2 90 . 3 00 . 3 00 . 2 90 . 3 10 . 2 80 . 2 80 . 2 90 . 2 60 . 2 70 . 2 60 . 2 70 . 2 80 . 2 60 . 2 80 . 2 7

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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 . 0 2 10 0 Sh/Clst: dsk y brn to brn blk

43 5 2 . 0 0

4 3 6 1 . 0 0

1 00 Sh/Clst: brn blk

1 0 0 Sh/Clst: brn blk

4 3 6 5 . 0 0 swc3 . 9 0 1 0 0 Sh/Clst: dsk y brn to brn blk

4370.00

4 3 7 9 . 0 0

4388.00

1 00 Sh/Clst: brn blktr Sh/Clst: gy redtr Ca : w to lt gy, chk

1 00 Sh/Clst: brn blktr Sh/Clst: gy redtr Ca : w to lt gy, chk

10 0 Sh/Clst: brn blktr Sh/Clst: gy redt r Cont : p r p

0 0 0 10001-1L0 0 2 60 0 2 6 - 1 L00270027-1L00020 0 0 2 - 1L00280028-1L0028-2L0028-3L0 0 2 90 0 2 9 - 1L0 0 2 9 - 2L0 0 2 9 - 3L

00300030-1L0030-2L0030-3L

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Schlumberger GECO-PRAKLA GEOLABJfiNOR

Table 2 : Lithology description for well NOCS 2/5-10ADepth unit of measure: mDepth Type Grp Frm AgeInt Cvd T O C % % Lithology description4 3 9 5 . 0 0 swc

4 . 3 6 100 Sh/Clst: dsk y brn to brn blk

4 3 9 7 . 0 01 00 Sh/Clst: brn blktr Sh/Clst: gy redt r Cont : p r p

440 5. 0 0 swc1 . 5 4 1 0 0 Sh/Clst: dsk y brn to brn blk

44 0 6 . 0 0

44 1 5 . 0 0

4424.002 . 1 8

100 Sh/Clst: gy blk to brn blktr Sh/Clst: gy redt r C a : w t o l t g y , c h k

80 Sh/Clst: gy b l k , dol10 Ca : lt gy10 Sh/Clst: dsk y b r n , dol

95 Sh/Clst: gy blk to brn blk5 Sh/Clst: dsk y b r n , dolt r C a : l t g y

Trb Sample

00040004-1L0 0 3 10031-1L0031-2L0031-3L

00030003-1L00320032-1L0032-2L0032-3L00330033-1L0033-2L0033-3L00340034-1L0034-3L0034-2L

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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

4433.009 5 Sh/Clst: gy blk to brn blk5 Cont : p r pt r C a : l t g yt r Sh/Clst: dsk y b r n , dol

00350035-1L0035-4L0035-2L0035-3L

4442.009 5 Sh/Clst: gy blk to brn blk5 Cont : p r pt r C a : l t g ytr Sh/Clst: dsk y b r n , dol

0 0360036-1L0036-4L0036-2L0036-3L

44 5 1 . 0 0 swc2 . 3 6 1 0 0 Sh/Clst: dsk y brn to brn blk

00050005-1L

44 5 1 . 0 09 5 Sh/Clst: gy blk to brn blk5 Cont : p r ptr Sh/Clst: dsk y b r n , dol

00370037-1L0037-3L0037-2L

446 0. 0 09 0 Sh/Clst: gy blk to brn blk1 0 C a : l t g y , p r ptr Sh/Clst: dsk y b r n , dol

00380038-1L0038-3L0038-2L

4 4 6 9 . 0 02 . 4 1 10 0 Sh/Clst: gy blktr Sh/Clst: dsk y b r n , dolt r C a : l t g y , p r p

00390 039-1L0039-2L0039-3L