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

RFT - MDT•

67686970717273747576777879808182838485868788899091929395969798991003456789101 112141516202122232425

89191020

«ii3264.33268.753277.53294.53308.053334.053347.83356.753357.53363.63368.43378.553375.53392.353397.3

3410.853424.453433.73456.853499.53536.353578.33626

3651.653579.853812.63830.84113 .84127.13525.13526.553531.853530.84582.64582.94583.554594.44600.14594.34594.3

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

fe;;» .:'m^f^:mi!Mmiimm

•11

RFT-B

MDT

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

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

-2"oQ

dzo.d)a.v>Q

4 rM

ud T

ype

rm H!,/U-

Q.CM

"a£ti0)0 M

ud T

emp

C

4MPniAI

o.£2

Cu_

>CL.

CL>

IVH

o0)«/)

O

"0)CD

JM 1

cEo1)CD

' IV|

_i

<Jol<

\J1PI

^

CLX

11*?*

a

•2a,X

» 9\Å

<DJ*ooCL<

Ull

0)J*OU

a.X

HUI

s«mTJ"ov>

y

»8T5

Ov> Li

quid

s %

n-1cdS

XDL a_ M—

CLM— 6 o

O

0}

?'u>LLJ

21/05/9322/05/9323/05/9324/05/9325/05/9326/05/9327/05/9328/05/9329/05/9330/05/9331/05/9301/06/9302/06/9303/06/9304/06/9305/06/9306/06/9307/06/9308/06/9309/06/9310/06/9311/06/9312/06/9313/06/9314/06/9315/06/9316/06/9317/06/9318/06/9319/06/9320/06/9321/06/93

123456789101 1121314151617181920212223242526272829303132

RIG MOVERIG MOVESPUD MUDSPUD MUDSPUD MUDSPUD MUDKILL MUDKILL MUDKILL MUDKILL MUDKILL MUDKILL MUDKCLGELGELKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLY

000

195530530815465465223465520520520685

10371254160916092104226522652265226522652265236925412644274229763130

0000000000000000000000000000000

58

0.000.001.031.051.051.401.401.401.401.401.401.301.301.301.30.30.30.44.50.55.65.65.65.65

1.651.651.651.631.631.631.631.63

00

998989999999999999908080716047556468646674746268595659525656

00

1099

2522212122222035209

1820204052424348445452524342374949

00

20202023322424252619141416986

1410101 199

10109

10109

1 110

00

27272731373232323221121 2611122222222143422

00

6363638098787877802615158213555654454

107

1 199

00

20181614151 71 71617151515213

4.75.83.63.63.32.92.92.9

33

3.22.8

33.4

33

00000000000000000000000000000000

00000000000000000000000000000000

00000333333333310111111111111111

00000000000000000000000000000000

00333

1414141414141010101 11414192122252525252525252524242424

00

0.50.50.50.50.50,50.50.50.50.50,50.50.50.50.50.50.30,30.30.30.30.30.30.30.30.30.10.10,10.1

00

979797868686868686909090898686817978757575757575757576767676

000000000000000

3036505357575753505353565660575757

00

10101010101010101010101010999

8.38.18.18.18.18.38.28.18.48.48.18.28.38.2

000000000000

0.100.250.10

00000000000000000

0000

0.200.250.250.200.200.200.25

00.150.200.10

00000000000000000

0000

0.400.400.400.400,400.300.35

00.400.400.25

00000000

0.500000000

00

0.40.4

0000000000000000000

570000000

59

00000000000000000000000

6000000000

480

ANDY MAIN

ANDY MAIN

ANDY MAINANDY MAIN

MAIN/LAURFTZENMAIN/LAURITZEN

MAIN/LAUR1TZENMAIN/LAURITZEN

MAIN/LAURITZEN

MAIN/LAURITZENMAIN/LAURITZENNORDBY/LAURITZENNORDBY/LAURITZENNORDBY/LAURITZEN

NORDBY/LAURITZENNORDBY/LAURITZEN

NORDBY/LAURITZENNORDBY/LAURITZENNORDBY/BLSENNORDBY/ELSEN

NORDBY/ELSENNORDBY/ELSEN

NORDBY/ELSENNORDBY/ELSEN

MAIN/ELSENMAIN/ELSENMAIN/ELSEN

MAIN/ELSENMAIN/ELSENMAIN/ELSENMAIN/ELSENMAIN/LAURITZEN

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

IJ3>Q

3334353637383940414243444546474849505152535455565758596061626364

Mud

Typ

e

KCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLY

Dep

th a

t 1 2

pm

32053 2 1 1325233083362347134713494350235023502350235023502350235023586365236803726383739303957396839874035407740984 1 1 1414242004227

Mud

Tem

p

Mud

Wt

5900

58590

5758584838292626262454584453566048586467706727666727

.63

.63

.63

.63,63

1.631.631.611.611.611.611.611.611.631.621,611.611.611.611.611.611.611.611.611.611.611.611.611.611.661.661.66

Fun

Vise

59605859656360685964808289919389575760555353|66565556565360676258

>CL

4251514648494466624942484948494842404644414242424544444751505139

a.">

1 11 19

1 11 21 21 21 2131 1999

10101 199

1088

10101 11014131315131312

o0)vtO

"0)CD

23222223222222222222211222323333

c£o

"0)CD

99777787665556663354434466867978

_i£

CL<

33.63.63.72.53,53.62.92.42.62.42.42,62.42.52.52.62.52.62.72.42.52.52.82.82.82.82.82.73.52.72.8

_jB:

a.X

00000000000

12121 11 11 1121 21 21 1101414141414131 21 2121212

HPH

TTem

p

00000000000

250250250250250250250250250250275275275275275275275275275275275

(b-soCL<

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

HPHT

Cak

e

00000000000000000000000000000000

Solid

s %

2424242424242023232323232323232323232323232323232323232323252525

Sand

%

0.10.10.10.10.10.0.0.0.0.0.0.0.0.10.10.10.10.10.10.10.10.10.10.10.10.10.10,10.10.10,10.1

Liqu

ids

%

7676767676768077777777777777777777777777777777787877777777757575

(~:cd5

5050535754545443434339393939393639393936363236363332323232323238

±CL.

88888

8.38.48.58.58.3

88.28.28.18.28.18.18,48.28.28.38.2

88

8.18.68.48.3

8888

a_

0.100

0.10.1

00.10.1

000000000000000000000000

«t—Q.

000000

0.10.1

0000000000000

0.10.10.1

00000000

0.400

0.30.3

00.20.20.30.30.30.30.30,20.20.20.30,30.50.50.50,60.60.50.60.60.70.70.70.70.70.6

O

5900

5252000

525050525149494850505050494543444240404139383438

+oO

60000

560560

000

560560600600560640640600800520720720560480560600480400480440320440400480

S0)

'a>LLJ

MAIN/LAURITZENMAIN/LAURITZENMAIN/LAURITZEN

MAIN/LAURITZEN

MAIN/LAURITZENMAIN/LAURITZENBLSEN/LAURITZENEL9EN/LAURITZEN

ELSEN/LAURITZENELSEN/LAURITZENELSEN/LAURITZENELSEN/LAURITZEN

ELSEN/LAURITZEN

ELSEN/LAURITZENELSEN/LAURITZENELSEN/LAURITZEN

MAIN/ELSEN

MAIN/ELSENMAIN/ELSEN

MAIN/ELSEN

MAIN/ELSENMAIN/ELSENMAIN/ELSENMAIN/ELSEN

MAIN/ELSEN

MAIN/ELSENMAIN/ELSENMAIN/ELSENMAIN/LAURITZEN

MAIN/LAURITZEN

MAIN/LAURITZENMAIN/LAURITZEN

Will: 2/5-10 Mud Properties summary

3oa

24/07/9325/07/9326/07/9327/07/9328/07/9329/07/9330/07/9331/07/9301/08/9302/08/9303/08/9304/08/9305/08/9306/08/9307/08/9308/08/9309/08/9310/08/9311/08/9312/08/9313/08/9314/08/9315/08/9316/08/9317/08/9318/08/9319/08/9320/08/9321/08/9322/08/9323/08/9324/08/93

d

Iat.v>Q M

ud T

ype

6566676869707172737475767778798081828384858687888990919293949596

KCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYKCL/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLY

Dep

th a

t 12p

m

42274227422742274227422742274227423542354275429843404395442945004547454745564575458445914649470147014701470147014701470145204520

Mud

Tem

p

181616191860415958585658535661606000

56374553533336363056303933

Mud

Wt

1.661.661.661.661.661.661.681,671.671.981.981.991.981.982.032.032.032.032.032,082.082.082.082,082.082.082.082,082.082.082.082.08

Fun

Vise

6564676464575763525857575864646053535148494944403941454452445952

>CL

5343444444404137354444454342393935373431334027262327292830304347

CL>

12101090

81 19

13945689

101 11 11 110788875667665

1 1

o0)v>O

®O

33333334712238875644344333333324

c"Eoli)CD

88876678

20457

101516191 2131 199

1 11 1108688884

1 7

_j£CL<

2.42.22.32.22.32.82.73.6

42,22.6

22.42.73.83.32.92.82.9

222

3.3333

2.22.62.6

22.83.8

_i

£

D.X

1212121 21 213131400

12141 11314151513151515151414151 21 21 213121220

HPHT

Tem

p

275275275275275275275275275275300320320320320320320320320320320320320320320320320320320320320320

(D.seD0ol<

11111111222

2.522222222222222222222

HPHT

Cak

e

00000000000000000000000000000000

Solid

s %

2525252525252525253333333434353535353536363636363636363636363636

San

d%

0.10.10.10.10.10.10,10.10.10.30.30.30.30.30.30.30.30.30.30.30.30.30.30.30.30.30.30.30.30.30.30.3

Liqu

ids

%

7575757575757575756767676767656565656565656565656565656565656565

H^cd2

3232323232323237352221182025222117242222222224212121212323232522

XOL

8.28.18.18.1

89.3

995

1 18.58.59.39.39.29.49.38.58.38,38.98.58.88.58.58.2

99.28.98.78.8

1 112

Ea.

00000000000000000000000000000000

H-CL

0.20,10.10.10.10.30.3

00.30.30.30.20.30.30.20.20.10.10.50.10.10,10.10.10.10.10.10.20.20.20.70.8

S

1 . 10.70.80.80.70,80,70.80.80.80.81.21 . 11.41.2

10.71.30.5

10.8

10.80.8

11.21.21,31.21.21.41.8

6

3739404040403939402120202120191612131 1101 11 11010101010101 110101 1

oO

440460460440440520480440800160160320480480520480280400280320440440360400440520440400400440600680

<Da>'a>uu

MADMLAURITZENMAIN/LAURITZENMAIN/LAURITZEN

MAIN/LAUHITZEN

MAIN/LAURITZEN

MAIN/LAURITZENLAURITZEN/EL9ENLAUMTZEN/ELSEN

LAURITZEN/ELSENELSEN/NORDBY

ELSEN/NOHDBY

ELSEN/NORDBYELSEN/NORDBYELSEN/NORDBY

ELSBN/NORDBYELSEN/NORDBYELSEN/NORDBY

MAIN/NORDBY

MAIN/NORDBYMAIN/NORDBYMAIN/NORDBY

MAIN/NORDBYMAIN/NORDBYMAIN/MILNEMAIN/MILNEMAIN/MILNE

MAIN/MILNE

MILNE/ELSENMILNE/ELSENMILNE/ELSEN

MILNE/ELSEN

MILNE/ELSEN

WELL: 2/5-10 Mud Properties summary

5oa

dza&o>a M

ud T

ype

Q.CM

"a£a& M

ud T

emp

Mud

Wt

Fun

Vise

>ol

a!>

0

"®CD

cEoo

CD

_j£ol<

_j<J

a.T. H

PHTT

emp

d)J*oO51< H

PHTC

ake

Solid

s %

Sand

%

Liqu

ids

%

i-cd5

XCL CL

s—a_ 6DO

i1LU

25/08/9326/08/9320/09/9321/09/9322/09/9323/09/9324/09/9325/09/93

979899100101102103104

HPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYRIG MOVERIG MOVE

452045924 1 1 521022082

1 1 08888

274144000

2.082.032.061.681.671.66

604752444844

483739222324

637998

412222

86

1 2667

3.42.7

222

48

1815181800

320320320320

00

222222

000000

363436232222

0.30.20.30.10.10.1

656765777878

221 121181 818

1 1

9.5109

9.810

0

0000

0.8

0.90.90.425

0.40.4

22

2.62.12.42.6

1 17

1 1998

720400880800960960

MILNE/ELSEN

MILNE/ELSEN

MAIN

MAIN

MAINMAIN

MAIN

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

"oQ

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

6

IJ?O

1

23456789101 112131415161718192021222324

Mud

Typ

e

HPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLYHPHT/POLY

Dep

th a

t 12p

m

435143064310431843184394442544604497450045414596461246214631464046684715471547154715471547154210

Mud

Tem

p

565052383850605962535456574545404938293265313144

Mud

Wt

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

Fun

Vise

534651494954555559625448566554504651705756565652

>CL

353736363635373739393540393835363535254033323939

a.'>

64544768

1 11 199

1 11 110101 110144

1 11 197

u<DmO

150

222225457755665444914442

c"Eo"o0

127999

16141923241316171514n121 1187

1012191 2

_j$CL<

2.62.52.52.52.52.82.62.52.62.62.72.62.62.5

2222222

1.91.9

2

£

a.X

151313121214141313141413131313121313131314121216

HPHT

Tem

p

325320320320320320320320320320320320320320320320320320320320320320320320

API C

ake

222222222222222222222222

HPHT

Cake

000000000000000000000000

Solid

s %

353636363636363636363535363636363636373535363636

8«-a0<n

0.30.20.10.10.10.10.10.10.30.30.30.30.30.30.30.30.30.30.30.30.30.30.30.3

Liqu

ids

%

656564646464646464646565656564656464636565656565

H^CD

S

181616161621182024242024242121212124211818212121

Xa."

9.39.39.39.39.39.29.38.99.39.39.18.99.39.2

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

Appendix 1 A

Tables

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