DRILL STEM TESTING SUMMARY - Forsiden - … I - 21 - DRILL STEM TESTING SUMMARY WELL 6507/7-6 The Drill Stem Test (DST) program commenced with the setting of a full string of 9 5/8"

I

I

- 21 -

DRILL STEM TESTING SUMMARY

WELL 6507/7-6

The Drill Stem Test (DST) program commenced with the setting ofa full string of 9 5/8" casing at 2510m. After setting the sealassembly and testing the BOPE, a gyro survey was run to totaldepth. A spaceout run was made with the sub surface test tree(SSTT) to the wellhead, followed by a bit and scraper run to2481m while picking up 6 1/2" drill collars and 3 1/2" tubing.With the bit on bottom, the mud was circulated and conditioned,and the mud weight was reduced from 10.6 to 10.0 ppg. The bitand scraper were then pulled and a cement bond log was run. TheCBL indicated adequate cement bonding across the proposed testinterval. The CBL was followed by a velocity survey (VSP) from2475m to 1800m and a gauge ring / junk basket run to 2475m. TheDST No 1 interval was then perforated from 2411.5 to 2415.5m andfrom 2421-2424m in two runs with 5" casing guns. The downholetest tools were picked up and pressure tested with water beforerunning in on tubing. Another pressure test was performed onthe string after picking up the SSTT (tubing filled withdiesel). The landing string was run with a lubricator valvepositioned one stand below the surface test tree. The surfacelines were then connected, the packer set, and all finalpressure tests were performed.

A safety meeting was held with all crew members before beginningthe test. The well was opened for a 40 minute initial flowperiod at 2036 hours on 23 August, and then shut in for 7 hours.During the 21 hour second flow period, 6 downhole fluid sampleswere taken on 3 wireline runs. A 6 hour second shut-in precededa 19 hour final flow period which yielded 4911 BOPD of 23 APIoil and 1.628 MMCFPD of gas through a 90.5/64" choke. The finalflowing wellhead pressure was 531 psig. The well was shut in fora final build up period of 8 hours after which the well waskilled, circulated out, and the test string pulled.

Following DST No 1, a CCL was run on wireline to check for sandbuildup in the rathole. No buildup was detected and a cementretainer was set with the wireline at 2402m. The perforationsbelow the retainer were then squeezed with cement, and the BOPequipment was tested before commencing with DST No 2.

The DST No 2 interval from 2348 to 2365m was perforated using 5"casing guns on 3 separate wireline runs. The test tools werethen run, and the surface equipment was hooked up and tested.The well was opened at 2014 hours on 27 August for a 12 minuteinitial flow and then shut-in for 93 minutes. The well wasopened and allowed to "clean up" for 10 1/2 hours through a12/64" choke before wireline sampling on the second flow period.Four wireline sample runs were made with inconclusive results.

FWR/FWR-255

- 22 -

After completing the recombination sampling at the separator,the choke size was increased to 16/64" to clean up the well foradditional wireline samples. The sample chamber and gauge wouldnot go to bottom at the higher flow rate, so the choke wasreduced back to 12/64". Once the downhole pressure was verifiedfrom the gauge run, the choke was reduced to 8/64" and threeadditional wireline sample runs were made. The choke was slowlyopened to 132/64" upon completion of the downhole sampling. Thewell produced 3950 BOPD of 27° API oil and 2.170 MMCFPD of gasat a FFWHP of 331 psig. The well was also producing largeamounts of sand at this rate which eventually brought the flowperiod to a premature end. The second flow period lasted 55hours, of which 3 1/2 hours were at the maximum choke size whilebypassing the heater. The final shut in period was 9 hours. Thewell was then killed and the test tools recovered. A CCL/gaugering run tagged the sand fill at 2361m, which was 41m above thetop of the plugged back depth.

A cement retainer was set on wireline above the test zone at2340m. The test tubing and drill collars were then laid downbefore final plugging and abandoning the well. Total testingtime was 14 days.

I

FWR/FWR-255

- 47 -

I3.5 MUD DATA

3.5.1 Discussions, Conclusions,

and Recommendations by Intervals.

3.5.2 Material Consumption and Cost.

3.5.3 Mud Properties Recap.

3.5.4 Graphs.

FWR/FWR-264

48 -

I

I

CONOCO NORWAY INCNortrym6507/7-6

NORSK A PETROLEUM

SERVICES I

INTERVAL DISCUSSION

36" Hole 375 to 473 meters30" Casing at 473 meters

The Nortrym was moved to its new location, 65O7/7—6. This wellwas spudded on the 23rd July 1986. The seabed was tagged at 375meters RKB(Rotary Kelly Bushing).

The 36" hole was drilled with seawater and high viscosity pills.Returns were to the sea bed. 450 barrels of 9.5ppg (poundsper gallon) kill mud was built in accordance with CONOCONORWAY INC's contigency plan for shallow gas. While drilling informations containing boulders, the drill pipe backed off at a TD(Total Depth) of approximately 42O meters. Because of the ensuingproblems of fishing out the drill string, it was decided to respudthe well 1O meters from the first location. No significantproblems were encountered drilling the hole at its new location.TD was reached at 472 meters.

Approximately 25 barrels of 1OO seconds/quart viscosity mud wascirculated at each connection. At TD, the hole was circulatedwith 1OO barrels of high viscosity mtul and 400 barrels of seawaterprior to a wiper trip to 4OO meters. After running back tobottom, 4O0 barrels of 9.5 ppg l:ill mud wa?> spotted in the hole.The drill string was pulled out of the hole. The 3O" casing wasrun and cemented with no problems.

2450 barrels of mud were built in this interval, of which, 1345barrels were transferred to the next interval. The 11O5 barrelsused on this interval was 25X lower than the programmed 1475barrels. The mud program displacements were calculated todisplace the open hole twice at 1507. of the calculated holevolume. In actual practice the hole was swept with a 1OO barrelhigh viscosity pill and displaced with 1OO7. calculated holevolume. The unprogrammed barite was *0.G0 per barrel. When thisis taken into consideration, the actual per barrel mud cost was*O.O9 lower than programmer!.

- 49 -


I

I

INTERVAL- DISCUSSION

26" Hole 473 to 1O3O meters2OM Casing at 1024 meters

This section was drillnd without a rir.nr using seawater and highviscosity pills. 630 barrels of 1O ppg kill mud was built inaccordance with CONUCU NORWAY INL's tontigency plan -for shallowgas.

A 17 1/2" pilot hole was drilled to 1030 meters without anyproblems. At TD, 100 barrels of high viscosity mud were pumpedand was followed by 400 barrels of seawater. 500 barrels of 10ppg kill mud were spotted in the open hole prior to tripping forthe 26" bit.

The hole was opened to 26" without any significant problems.Reaming was necessary on only the last few joints. 1000barrels of 1O ppg kill mud was built in accordance with CONOCONORWAY INC's contigency plan for shallow gas.

When the hole had been opened to 26", lnO barrels of highviscosity mud were pumped and was followed by 4OO barrels ofseawater. After a wiper trip to the ?(.»" casing shoe, another 1OObarrel high viscosity sweep was done. The hole was displaced to1O ppg kill mud in preparation to run the 2O" casing. The 2O"casing was run and cemented.

The programmed per barrel cost of *2.14 was based on a closedsystem for the pilot hole. The increased bentonite consentration,required for the high viscosity cost *1.76 per barrel and theincreased barits concentration for the kill muds cost *0.93 perbarrel. This resulted in a mud cost of *322.7O over theprogrammed cost.

- 50 -

I

I

CONOCO NORWAY INCN o r t r y w

65O7/7-6

NORSK • PETROLEUM

INTERVAL DISCUSSION

17 1/2" Hole 1O3O to 2087 meters13 3/8" Casing at 2OBO meters

The pits were cleaned out after cementing the 20" casing. AKC1/Polymer system was mixed up for the 17 1/2" hole interval.Displaced to the KC1/Polymer system after running theleak— of i— test to 12 .7 ppg equi val ent mutl weight.

The mud weight was raised in increments from 9.5 to 12.0 ppgduring the course of this interval. Throughout this intervalKC1/Polymer premixes were added to the system to maintain volumeand the required mud properties. Prior to drilling the soft clayat approximately 15OO meters, the KC1 content was increased to 37ppb (pounds per barrel) and the polymer concentration was doubledto maintain hole stability and encapsulate the drill cuttings.

While coming out of the hole at 1778 meters for a bit change, agreat deal of overpul1 was experienced and several joints had tobe pumped out. Only three slightly tight spots were encounteredon the trip back in the hole. This would indicate stress reliefof the well bore in the soft clay section.

Drilling continued to TD. Prior to reaching TD, gas shows of upto 11% were recorded. Ihe mud weight was raised from 11.5 to 11.8ppg. While making a wiper trip at TD, swabbing occurred and thewell flowed at approximately 6 barrels per hour. The mud weightwas raised to 12.0 ppg. The well was static, and the drill stringwas pulled with no further problems.

The 13 3/8" casing was run and landed with no problems. 30barrels of mud were lost to the formation while circulating thecasing prior to cementing. A further 102 barrels were lost whiledisplacing the cement.

The KC1/Polymer system was maintained to meet CONOCO NORWAY INC'sspecf ications. At one point the MBT w*s 16 ppb which was slightlyhigher than +/- 15 pph called for in the* program. No problemsoccurred, and the mud was returned to the required specification.The calcium content did rise above the» recommended maximumlevel of 200 mg/1 level and was treated with soda ash.

Dilution rates were not as high as estimated and the per barrelcost was $0.80 lower resulting in a cost savings of *8,549.53 or13% on the estimated cost of the interval.

- 51 -

t

I


INTERVAL- DISCUSSION

12 1/4" Hole 2087 to 2087 meters9 5/8" Casing at 251O meters

The mud from the previous interval was diluted to 1O.5 ppg and theKC1 content was allowed to deplete while drilling this interval.Seawater was used for dilution for the PAC/DEXTRID mud systemrecommended for this interval.

10 cores <213 meters) were cut in the interval from 2129 meters.The average core recovery was 90.2%.

No difficulties were experienced with drilling or hole stability.The cal iper log showed the hole was close to guage throughout theinterval. There was some overpul1 nn the wiper trip at TD, butthe hole cleaned up hole after the wiper trip. The wirelinelogging, final wiper trip and 9 5/8" casing operations all wentsmoothly.

The increased barite concentration over the estimated bariteconcentration and higher than estimated dilution requirements in ahigher than estimated miuJ rost for the intnr val of •11,397.05.

- 52 -

CONOCO NORWAYNortrym6507/7-6

INC

INTERVAL DISCUSSION

Testing9 5/8" Casing at 251O meters

ITesting was done using the PAC/DEXTRIO mud from the 12 1/4" holeinterval. SURFLO B-21 was added to the mini system to prevent anyboidgradation of the pol ymers while I hr> imii.1 was static in thehols.

Two drill stem tests were run. The perforations were cemented offafter the testing program was completed. A cement plug was set inthe casing at 600 to 400 meters. The casing was cut and the wellwas abandoned.

I

- 53 -

I

I

CONOCO NORWAY INCNortry»6507/7-6

CONCLUSIONS AND RECOMMENDATIONS

I fjL,

The CONOCO NORWAY INC well 6507/7-6 was drilled to TD at 2525meters in 2B days. 1h«? total rotating hours was 202.3, of which52.5 hours were spent coring in the 12 1/4" hole interval. Thewell went extremely smoothly and no major problems wereencountered. The mud material cost was 8V. higher than estimated.This was due to the kill mud requirements in the first two holeintervals, which was not included in the estimate, and a higherdilution requirement than estimated in the final drillinginterval.

In the Heidrun field in Haltenbanken, reactive gumbo clays can beexpected in the 17 1/2" hole interval at approximately 1500meters. Prior to drilling these clays, it is of paramountimportance to increase the potassium content to 35 to 40 ppb KC1for inhibition of these clays and to pnsiirp that there issufficient polymer in the mud system for encapsulation of thedrill cuttings to prevent solids build-up in the mud system.This was done in this well and the dilution requirements wasapproximately 350 barrels less than estimated.

The mud weight should be increased, in increments, to a maximum of12.O ppg, as hole conditions dictate, in these reactive gumboclays in the 17 1/2" section. 11.8 ppg was sufficient to drillthis interval, but 12.O ppg was required at TD in order to tripout of the hole to run casing.

Control of the calcium content to as low as possible, but lessthan 200 mg/1, is recommended for the 17 1/2" interval forefficient use of the pnlyacrylamide (Alcomer 110L in this well)which is calcium sensitive. The use of potassium carbonate isrecommended instead of soda ash. The potassium carbonate willreduce the calcium level and will add potassium ions to the mudsystem to increase inhibition. The soda ash, sodium carbonate,will reduce the calcium content, but the sodium ions will competewith the potassium ion* in the mud system and does not provide theinhibition that the potassium ion does.

i Baroid

OPERATING AREA

CONOCO NORWAY INC.

- 54 -

6507/7-6

INTERVAL SUMMARY

I

I

SECTION

Hole Size:

Casing Size:

Casing Set At:

Interval Length:

Mud Type:

Spud Depth:

Spud Date:

TD Depth:

TD Date:

Maximum Hole Deviation:

Drilling Days:

Total Days on Interval:

Interval Mud Cost:

Volume Built:

Volume Transferred to Interval:

Volume Salvaged:

Volume Left Behind Casing:

Volume Lost To Formation:

Volume Dumped:

Volume Lost Over Solids Equip.

Total Volume To Sea:

Volume Cuttings Drilled:

Cost per Barrel

Cost per ft m ....'?...:

Cost per Day:

Cost Of Mud Used On Interval:

36"

30"

4 72 m

97 m

Spud

375 m

23 . 07 .86

4 72 m

2 6 . 0 7 . 8 6

0

2 .3

4

$ 7 ,614 .00

2450 b b l

0

1345 bbl

0

0

1105 bbl

0

1105 bb l

63 .3 m3

$ 3 .11

$ 78 .49

$ 1,903 .50

$ 3,436 .55

SpaslafuyMi. Stvgr

i Baroid

OPERATING AREA

CONOCO NORWAY I N C .

- 55 -

6507/7-6

INTERVAL SUMMARY

I

I

SECTION

Hole Size:

Casing Size:

Casing Set At:

Interval Length:

Mud Type:

Spud Depth:

Spud Date:

TD Depth:

TD Date:


Drilling Days:


Interval Mud Cost:

Volume Built:


Volume Salvaged:



Volume Dumped:

Volume Lost Over Solids Equip.



Cost per Barrel

Cost per ft m ...*....:

Cost per Day:Cost Of Mud Used On Interval:

26"

20"

1024 m

558 m

Spud

4 72 m

27.07.86

1030 m

29.07.86

0

1 .2

3

$ 8,356.20

1529 bbl

134 5 bbl

0

0

02874 bbl

0

2874 bbl

183 .5 mJ

$ 5,47

$ 14 .98

$ 2,785.40

$ 12,533 .65

SpMUJtiykk. Stvgr.

- 56 -

I

I

lim Baroid

OPERATING AREA


SECTION

Hole Size:

Casing Size:

Casing Set At:

Interval Length:

Mud Type:

Spud Depth:

Spud Date:

TD Depth:

TD Date:


Drilling Days:


Interval Mud Cost:

Volume Built:


Volume Salvaged:



Volume Dumped:

Volume Lost Over Solids Equip.:



Cost per Barrel

Cost per ft m ...&...:

Cost per Day:


6507/7-6

INTERVAL SUMMARY

17 1/2"

13 3 / 8 "

2080 m

1057 m

KC1/Polymer

1030 m

01 .08.86

2087 m

05 .08 .86

0 . 4 °

3

8

$ 5 9 , 2 3 6 . 9 7

4054 bbl

0

2 7 70 bb l

118 bbl

2 30 bb l

715 bb l

221 b b l

936 bb l

165 m1

$ 14 .61

$ 56 .04

$ 7,404 .62

$ 18,759 .24

SceslimykH. Slvgr

mi Baroid

OPERATING AREA


- 57 -

6507/7-6

INTERVAL SUMMARY

I

I

SECTION

Hole Size:

Casing Size:

Casing Set At:

Interval Length:

Mud Type:

Spud Depth:

Spud Date:

TD Depth:

TD Date:


Drilling Days:


Interval Mud Cost:

Volume Built:


Volume Salvaged:



Volume Dumped:



Volume Cuttings Drilled: .

Cost per Barrel

Cost per ft m .. . .£..:

Cost per Day:


12 1/4"

9 5/8"

2510 m

438 m

PAC/DEXTRID

2087 m

08.08.86

2525 m

16.08.86

2.9

13

$ 21 ,788 .40

2178 bbl

2770 bb l

1862 bbl

180 bbl

188 bbl

2456 bbl

262 bbl

2 718 bbl

33.3 m1

$ 10.00

$ 49.75

$ 1 ,676 .03

$ 43 ,629 .70

ScwslaNtyWi. Srvgr

- 58 -

I

I

Inn BaroidOPERATING AREA


SECTION

Hole Size:

Casing Size:

Casing Set At:

Interval Length:

Mud Type:

Spud Depth:

Spud Date:

TD Depth:

TD Date:


Drilling Days:


Interval Mud Cost:

Volume Built:


Volume Salvaged:



Volume Dumped:




Cost per Barrel

Cost Der ft m . ^ •

Cost per Day:Cost Of Mud Used On Interval:

6507/7-6

INTERVAL SUMMARY

TESTING

9 5 / 8 "

2510 m

0

PAC/DEXTRID

1 6

$ 7 ,481 .25

380 bb l

1862 bb l

0

213 bb l

488 bb l

153 3 bb l

8 bbl

1541 bb l

0

$ 19 .69

$ 467 .58

$ 2 6 , 1 1 7 . 6 8

Sposiiltryfck. Stvgt.

- 59 -

CONOCO NORWAYNortrym6507/7-6

INC

C O N S U M P T I O N

MATERIAL PACKAGING QUANTITY

I

I

Al comer 11OLBari teBentoni teCaustic SodaDextridDrlspacLimePAC-LPAC-RPotassium ChloridePotassium HydroxideSoda AshSodium BicarbonateSurflo B-21Mai nut

XCD Polymer

Included in above totals

BROKEN SACKS

DextridPAC-L

USED ON CEMENT JOBB

Bar!teCaustic Soda

COSTS

INTERVAL

36"26"

17 1/2"12 1/4"Testi ng

Totals

Cost per barrelCost per meter

25kgMTMT

25 kg25kg501b20kg25 kg25kg50 kg50 kg50kg50kg25 kg25 kg25kg

25 kg25 kg

MT25 kg

METERS BARRELS

543985434

518401

9573

1116121316141267

54

2O7

COST*

975581057438

2150

Dri11 ing

*9.50*45.11

2450152940542178380

10591

•7$8

•59*21• 7

• 104

,614.00,356.20,236.97,788.40,481.25

,476.82

Total

•9.86•48.59

WELL NAME: CONOCO 6507/7-6

MUD PROPERTY RECAP

OATE

1986

22.07.

22.07.

23.07.

2*.. 07.

25.07.

26.07.

27.07.

28.07.

29.07-

30.07.

31.07.

01.08.

02.08.

03.08.

0<i.06.

05.08.

06.08.

07.08.

08.08.

DEPTH

T>»lres

PIT

PIT

1308

1769

1839

2C9

2087

2087

2081

2129

DENSITY

PPG/

8.6

8.6

8.6

8.6

8.6

8.6

8.6

8.6

8.6

9.5

9.5

9-7

11.5

11.6

11.8

12.0

12.0

10.5

10.5

VISC-OSITY

»•<•»

100*

100*

100+

100*

100*

100*

100*

100*

100*

62

62

52

55

63

53

5<i

56

53

50

FILTRATE

CCS

5.1

A.O

3.5

t.6

5.2

5.2

5.9

5.9

3.6

3.5

32/4rr

1

1

1

1

1

1

1

1

1

1

H^P till

°500p«i

C C I

S P

S P

S P

S P

S P

S P

S P

S P

S P

-

3fyrVT

D

D

D

D

D

D

I D

I 0

I 0

_

_

-

pH

M U 0

M U D

M U 0

M U D

M U 0

M U 0

M U D

M U D

M U D

10.2

10.1

9.6

9.1

9.2

8.8

9.0

9.1

9.5

10.2

RHEOLOGY

PV

cp

20

19

17

2*.

30

27

28

28

19

15

YP 10* | 10'

bt/iOOft'-gmi/cm^

27

27

18

19

20

17

18

19

13

20

k

3

i*

5

i.

5

5

3

3

3

9

1*

18

20

19

6

5

FILTRATE ANALYSIS

Cl

mo/htc»

28 K

28 K

31 K

37 K

35 K

37 K

37 K

37 K

27 K

19 K

Ca

ppm

160

160

120

200

220

220

230

210

280

200

Pf

.15

.15

.15

.25

.18

.09

.18

.2

.3

.2

Ml

.35

.35

.5

.57

.7

.4

M

.45

.7

.5

Pm

0

0

.1

.19

.19

.15

.16

.n

.5

1.0

RETORT ANALYSIS

Oil

0//o

0

0

0

0

0

0

0

0

0

0

Water

'0

96

96

92

83

83

82

81

81

68

89

;orr.Solids

0/

/o

h

8

12.

12.

I?-1"

1V.3

T..3

9.0

8.5

CEC

PPB

Btnt.Eq

5

5

3

11

12

16

15

15

12.5

12.5

OTHER

PPB

Kcl

31

31

30

37

36

V37

37

25

20

ASG

3.6

WELL N A M E : CONOCO 6507/7-6

MUD PROPERTY RECAP

OATE

1986

08.08.

09.08.

09-08.

10.08.

10.08

11.08.

11.08.

12.08.

12.08.

13.08.

13.08.

14.08.

14.08.

15.08.

16.08.

16.08.

17.08.

18.08.

18.08.

DEPTH

2142

PII

2185

2237

2305

PIT

2344

2365

2385

PII

PII

2424

2440

2<t62

2525

PII

PII

2525

PII

DENSITY

P P G /

10.5

10.5*

10.5*

10.6

10.6

10.5

10.5

10.6

10.6

10.6

10.5*

10.6*

10.5

10.7

10.5+

10.6

10.7

10.5-

10.6*

VISC-OSITY

stc.t

53

<t8

53

57

55

50

55

58

57

51

53

59

54

57

53

57

55

55

FILTRATE

cct

2.8

2.6

2.8

2.6

2.8

2.4

Z.<t

2.1

2.6

2.2

2.4

3.0

2.4

2.4

3.2

2.7

3.0

2.8

2.4

C*k«

&An

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

HJ^P (ill

°500psi

cc»

_

-

_

_

-

-

Jtynnr

-

_

_

-

-

pH

10.2

10.2

10.2

10.3

10.0

10.1

10.1

10.0

9.9

10.0

9.9

10.0

9.8

9.5

9.1

9.1

9.0

8.9

9.0

RHEOLOGY

PV

cp

20

21

21

23

22

22

22

23

22

22

20

24

22

24

22

23

24

20

23

YP 10* 10'

bs/iOOft'-BirVcm?

20

16

20

19

23

17

22

18

21

17

18

22

23

22

22

22

22

19

20

3

3

3

3

4

2

<t

2

3

3

3

k

5

3

3

4

4

4

3

6

V

5

5

6

3

5

<r

1,

<l

4

5

6

4

6

5

6

5

4

FILTRATE ANALYSIS

Cl

mg/litr*

19 K

17 K

16 K

16 K

15 K

14 K

15 K

14 K

14 K

13 K

13 K

12 K

15 K

12 K

11 K

11 K

11 K

11 K

11 K

C«

ppm

200

160

160

140

240

160

160

160

180

200

180

120

140

200

160

200

200

200

240

P»

.3

.25

.35

.2

.15

.1

.2

.15

.2

.1

.2

.25

.2

.1

.2

.1

.1

.1

.1

Mf

.65

.7

.65

.65

.4

.45

.5

.45

.5

.3

.5

.65

.5

,35

.5

.5

.5

.5

.45

Pm

1.1

1.1

1.0

1.0

0.8

0.8

0 . 7 5

0 . 7 5

0 . 6 5

0.4

.6

.6

.5

.5

.5

.5

.5

.5

.5

RETORT ANALYSIS

Oil

0//o

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

Walar

y89

89

89

88

89

90

90

89

89

89

89.5

89

89

89

89

89

88

89

89

Dorr.Solids

/o

8.5

9.16

9.16

10.5

9.5

9

9

10.2

10.2

11.0

10.5

11

11

11

11

11

12

11

11

CEC

PPB

Bent.Eq-

12.5

12.5

12.5

12.5

12.5

12.5

12.5

12-5

12.5

11.5

11.5

11.5

11.5

11.8

11.0

11

11

11

11

OTHER

KC1

PPB

20

15

15

12

12

8

8

6

6

IR

IR

IR

IR

IR

ASG

3.6

3.6

3.6

3.4

3.6

3.75

3.75

3.6

3.6

3.5

3.55

3.5

3.5

3.6

3.4

3.5

3.5

3.44

3.49

WELL NAME: CONOCO 6507 /7 -6

MUD PROPERTY RECAP

OATE

19.08.

20.08.

21.08.

22.08.

23.08.

2*1.08.

25.08.

26.08.

27.08.

28.08.

29.08.

30.08.

51.08.

01.09.

02.09.

OEPTH

metres

PIT

PIT

PIT

PIT

PII

PII

2360

PII

PII

PII

PII

PII

PII

PIT

PIT

DENSITY

PPG/

10.0

10.0

10.0

10.0

10.0

10.0

10.0

10.0

10.0

10.0*

10.0

10.0

10.0

10.0

10.0

VISC-OSITY

s«r.t

45

55

53

54

52

53

«.8

47

44

<i8

49

46

48

48

<i8

FILTRATE

cc*

2.6

2.6

4.3

4.6

4.4

4.6

4.2

4 . 4

4.8

5.2

5.0

5.*

5.2

5.2

5.2

Cik«

3?/4rr

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

H^IP «ill

SOOp»i

CCS

_

_

_

yjfmn

-

_

_

_

pH

8.3

9.3

10.0

9.9

9.9

9.8

9.6

9.3

10.0

10.2

10.1

10.0

10.2

10.2

10.2

RHEOLOGY

P V

cp

15

24

20

22

20

20

22

21

17

18

17

19

18

18

18

YP I 10* 10'

/ i /1OOIbøoOfl -gmi/cm>

13

19

20

20

18

18

22

21

17

17

17

17

17

17

17

3

8

5

I.

4

4

5

5

3

3

3

3

3

3

<>

1*.

7

8

6

5

8

7

6

5

5

5

5

5

5

FILTRATE ANALYSIS

Cl

mg/lilt»

10.500

10.500

8.000

8.000

8.000

8.000

8.000

8.000

8.000

8.000

8.000

8.000

8.000

8.000

8.000

C»

ppm

2<i0

240

100

100

100

100

160

180

120

160

160

140

160

160

160

Pf

.05

.15

.1

.1

.1

.1

.1

.1

.2

.1

.15

.2

.2

.2

.2

Mr

.35

.5

•25

.3

.3

.3

.6

.5

.6

.8

.6

.6

.65

•65

.65

Pm

0.1

0.5

0.8

0.8

0.8

0.8

0.8

0.7

0.4

0.8

.75

.6

.75

• 75.

.75

RETORT ANALYSIS

Oil

/o

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

Wafer

i92

92

92

92

92

92

92

92

92

92

92

92

92

92

92

:orr.Solid*

0//o

8

8

8

8

8

8

8

8

8

8

8

8

8

8

8

CEC

PPB

B«nt.Eq-

8.5

10.0

11.5

12

12

12

12

12

12

12

12

12

12

12

12

OTHER

ASG

3.53

3.53

3.52

3.5

3.5

3.5

3.5

3.5

3.5

3.5

3.5

3.5

3.5

3.5

3.5

- 119 -

Table 5.4

RFT Pressure Results

I

I

Depth(m RKB)(log depth)

21492169

2192220422212 23 52263.52277.52302.52320.52332.52337.52346

2351.5

2356

23602370.52380238524052414.5242424362447

245224572472.524 872504

MudHydrostatic

(psia)

39113960

4002402340554080.14132.641574202.84235.14556.94266.54282.2

4292

4300.1

4308.243264343.84352.44389.84406.34424.34445.84466. 1

4475.34484.445124539.64571.6

Formation(psia)

35183540

3530.73533.73538.83542.53550.6

—3560.23565.33567.53569.33604.2

3585.6

3604.7

-36013615.436213638.13649.13660.33674.73689.7

3696.63703.83726.23746.93771.5

Permeability

V. Good

V. GoodV. GoodV. GoodV. GoodV. Good

V. GoodV. GoodV. GoodV. GoodFair

Good

Fair

V. GoodV. GoodV. GoodGoodGoodFairGoodGood

GoodGoodGoodGoodV. Good

Remarks

gas in flowLine or poorpermeability

Tight formation

Possibly partialprobe pluggingPossible partialprobe pluggingPossible partialprobe pluggingTight formation

2446.5 tried, notstabilised

The RFT pressure results are also presented on figure 5.4

Documents

DRILL STEM TESTING SUMMARY - Forsiden - … I - 21 - DRILL STEM TESTING SUMMARY WELL 6507/7-6 The Drill Stem Test (DST) program commenced with the setting of a full string of 9 5/8"