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C O M P I L A T I O N T A B L E S 545

T a b l e 1. Triassic~Permian (and older) oil and gasfields

Amethys t Auk Barque

Trap

Type Dep th to crest ft ss Lowest closing con tou r ft ss

G O C or G W C ft ss O W C ft ss Gas co lumn (ft)

Oil co lumn (ft)

Structural Structural Strat igraphic Structural 8800 7337 7500 9050 7900 8800

9049 - - - - - - 7606, 7704, 7750 - - - - - - < 1200 - - < 4 0 0 - -

Pay zone

Lithology Sandstone Sandstone Dolomi te Sandstone Forma t ion Leman Rotl iegend Zechstein Leman Age Permian Permian Permian Permian

Gross thickness (ft) 40-120 985 28 700-800

Net /gross rat io (average) 0 .40-0.98 0.85 1.00 0.76 Poros i ty (average, range) (%) 11-25 14-16 12 (2-26) 11

H y d r o c a r b o n sa tura t ion (average %) 50 40 60 51 Permeabil i ty (average, range) (md) 1-1000 5 (0.2-125) 53 (0.1-10 000) 0.02-100

Product iv i ty index (BOPD/ps i ) - - 1 50-150 - -

Hydrocarbons

Oil density ~ API - - 38 - -

Oil type - - - - - - Gas gravity - - - - 0.59

Bubble point (psig) - - 700 - -

Dew point (psig) - - - - - - Gas -o i l ratio - - 190 - - Fo rma t ion volume fac tor 235 1.15 229

Formation water

Salinity (NaC1 eq.) (ppm) Resistivity (ohm m)

145 000 105 000 200 000 - - 0.025 0..020

Reservoir conditions

Tempera tu re (~ 190 215 175 Pressure (psig) 4100 4067 3850

Pressure gradient (psi/ft) 0.1 0.33 0.08

Field size

Area (acres) 24 000 16 055

Gross rock volume (acre ft) - - 1 400 000

Recovery factor % 77 18 Drive mechanism Pressure Depl. Water Drive

Recoverable oil ( M M B B L ) - - 93 Recoverable gas ( B C F ) 844 - - Recoverable N G L / c o n d e n s a t e ( M M B B L ) - -

85OO

47 Pressure Depl.

316

Production

Star t -up date 1990 1975

Produc t ion rate, plateau: oil BOPD - - 9500

gas M M C F D 180 - - Number / type o f well 20 producers - -

1990

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546 COMPILATION TABLES

Table 1 cont&ued

Camelot

Buchan N C/S NE Cleeton Clipper

Trap

Type Depth to crest ft ss Lowest closing contour ft ss GOC or GWC ft ss OWC ft ss Gas column (ft) Oil column (ft)

Structural 9464

10 384

1919

6225

6346

Structural 6050 6418 6232

200

6300

6418

Structural 9088

9344

Structural 7500 8900

<900

Pay zone

Lithology Formation Age Gross thickness (ft) Net/gross ratio (average) Porosity (average, range) (%) Hydrocarbon saturation (average %) Permeability (average, range) (md) Productivity index (BOPD/psi)

Sandstone Upper O.R.S. Dev.-Carb >2182 0.82 9 (7-10) 10-68 38 2-20

Sandstone Leman Permian 120-200 1.0 18 (15-21) <80 200 (5-5000)

Sandstone Leman Permian 200-400 0.95 18 (15-20) 83 95 (40-100)

Sandstone Leman Permian 650-775 0.81 11 49 0.02-100

Hydrocarbons

Oil density ~ API Oil type Gas gravity Bubble point (psig) Dew point (psig) Gas-oil ratio Formation volume factor

33.6 Undersat

1271

285 1.21

0.62

192

m

0.59

229

Formation water


116 528 0.067

180000 0.025

214000 0.020

200 000 0.020


Temperature (~ Pressure (psig) Pressure gradient (psi/ft)

222 7506 0.35

150 2850 0.07

175 4148

175 3850 0.08

FieM size

Area (acres) Gross rock volume (acre ft) Recovery factor % Drive mechanism

Recoverable oil (MMBBL) Recoverable gas (BCF) Recoverable NGL/condensate (MMBBL)

3527 m

15-18 Pressure Depl. and gas lift 81

500 32 000

1500 191 000 70 Water Drive

215

740 41 600

1830

79 Pressure Depl.

E

280

12 000

42 Pressure Depl.

558

Production

Start-up date Production rate, plateau:

oil BOPD gas MMCFD

Number/type of well

1981

28 000

9 producers

1989

70 (DCQ)

1988

80 5 producers

1990

m

m

m



COMPILATION TABLES 547

T a b l e 1 continued

Indefatigable Leman Morecambe S Ravenspurn S

Sean

N S


1360


800


1350

Structural 9055

10 206

Structural 8324 8427 8700 8600 8543 8543

Sandstone Leman Permian 150 (115-423) 1.00 15 (5-22) 75-80 30 (0.9-1000)

Sandstone Leman Permian 800 1.00 12.9 51 0.5-15

Sandstone Sherwood Triassic 4800 0.96 12.5 (9-15) 79 (65-89) 200 (5-10 000)

Sandstone Leman Permian 200-330 0.39-0.77 12-14 51-61 <90

Sandstone Leman Permian

~< 268 1.00 17.5 (15-18)

79 130-400

4249 1.00 17.1 (16-18)

190-400

m

m

228

m

m

0.59

229

w

m

0.64

1650

145

m

m

m

m

m

m

240

m

m

0.62

218

m

m

0.61

225

196 200 0.019

240 000 0.026 0.036

E 225 000 0.017

195 4122 0.07

125 3022 0.08

90 1860 0.05

200 4490

202 3945

0.07

192 3977

m

Pressure Depl.

4418 8

69 456

83 Pressure Depl.

11523

20 700

Pressure Depl.

4570

9000

58 Pressure Depl.

700

3379 198 056 82

192 0.4

2207 326 600 87

Pressure Depl.

233 0.5

1971

678

1968

m

m

m

1985

m

1200

1989

m

23 producers

1986-7

< 6OO




Table 1 cont&ued

Trap


Pay zone


Hydrocarbons


Formation water



Temperature (~ Pressure (psig) Pressure gradient (psi/It)

FieM size

Area (acres) Gross rock volume (acre ft) Recovery factor % Drive mechanism Recoverable oil (MMBBL) Recoverable gas (BCF) Recoverable NGL/condensate (MMBBL)

Production


oil BOPD gas MMCFD

Number/type of well

Rough Thames

Thames et al.

Yare Bure


550

8045

295

Structural

7911

i61

8050

200

Sandstone Leman Permian 95 (78-115) 0.98 12.5 (10.5-16.1) 64 (56-68) 75 (2-184)

270-316 1.0 19 63 135-487

Sandstone Leman Permian 43O 1.0 19 55 38-106

400 1.0 20 66 78

n

m

0.64

4360

256

0.60

m

0.018

m

0.048

197 4533 0.09

172 3715

170 3665

177 3713

5O5O

75 Pressure Depl.

366

m

m

i

m

m

i

i

m

m

m

1975

104 6 producers

1986

m

m

m

1987

n

m

1987

m

m




Table 1 continued

V. Gas Victor Viking West Sole

Structural 7200-7900

7650-8450

450-583


480

Structural Variable (8000-9600) Variable (9000-10 200) Variable (9000-10 200)

< 700

Structural 8858

9679

820

Sandstone Leman Permian 890 (790-990) 0.8 (0.6-1.0) 13.5 (3-23) 60 5 (0.1-1950)

Sandstone Leman Permian 300-450 O.99 16 73 52

Sandstone Leman Permian 400-700 0.50-I.00 7-25 50-60 0.1-100+

Sandstone Leman Permian 423 0.75 12 60

m

0.60

220

m

m

0.61 0.62

m

0.60

1403

239

190000-290000 0.017-0.022

220000 0.017

220000 0.017

m

0.020

142-177 3472-3835 0.07

192 4047 0.08

170-200 4050-4670 0.08

185 4265 0.08

70-77

1654 3

55OO 907 739 87

920

89

2830 12.7

17 000

74 Pressure Depl.

!873

1988

324.5

1984

5 producers

1972

m

1967

160 20 producers




T a b l e 2. Jurassic oil and gasfields

Alwyn N. Beatrice

Trap


Structural 9875-10 958 10 367-12 401 11 745 10 315-10 630 787 397-440

Structural 5900

6784

Pay zone

Lithology Formation

Age Gross thickness (ft) Net/gross ratio (average) Porosity (average, range) (%) Hydrocarbon saturation (average %) Permeability (average, range) (md) Productivity index (BOPD/psi)

Sandstone Statfjord

JL 869 0.65 13.5 80 330

Sandstone Brent

JU 335-361 0.85-0.90 17 77-81 500,800

Sandstone Brora, Pentland, Beatrice

JL-JM 1100 0.41 13-22 78.5 1-4000

Hydrocarbons


46-48

0.34

37-42 Undersat 0.574).68

38 High Paraffin

635

126 1.09

Formation water


17 000-82 000 0.064).20

20 000-27 000 0.07-0.10

35 000 0.062



225-235 248 176 2897 0.33

Field size

Area (acres) Gross rock volume (acre ft) Recovery factor %

Drive mechanism


420-1877

35 (oil) 70 (gas) Depletion

176

2643

45-56

Water injection

58O0

30

Depletion and Water injection 146

Production


oil BOPD gas MMCFD

Number/type of well

1987

90000

1981

30 000

27 producers 12 iMectors





Beryl

Brae N. Brae C Brae S

Structural/Stratigraphic 9600

11 300 to

1950

10 400

10 900 11 550 500

Structural/Stratigraphic 11 830 12 100 12 475

645

Structural/Stratigraphic 11 750 12 100

13 426

1676

Structural/Stratigraphic 11 821 12 I00

13488

1670

Sandstone (Lewis, Nansen, Linnhe) Bery!, (Katrine) (TR, JL) JM (JU) 500 (200-800) 0.85 (0.4-0.99) 17 (10-23)

88 350 (30-4400) 10-100

Sandstone Brae

JU 120 (0-645) 0.64 14.5 86 360 (1-4000)

Sandstone Brae

JU 800 (0-1676) 0.60 11.5 80 100 (1-1000)

Sandstone Brae

JU 800 (0-1670) 0.75 11.5 80 131 (2-500) 10-40

37

0.71 3200-4900

900-1500 1.7

41-49 Gas Condensate 0.78

5500-6500 2500-6500

33

4112

1415 1.77

33-37

3702

1343 1.73

77 000 0.120

79 000 0.098

75 000 0.120

207 4900 0.28

240 6900 0.19

246 7057 0.33

253 7128 0.30

12 000

Sol gas/Gas cap drive

800 (Beryl Fm 687) 1600

4700 1 571 160 66 (Cond) 72 (Gas)

Gas Recycle

798 178

1800 675 000 40

Water i~ect ion

64

6

6000 2 750 300 33

Water and gasinjection

274

38

1976

27 producers 11 injectors

1988

81 500

16

1989

15 500

1983

115 000

33




T a b l e 2 c o n t i n u e d

Brent

Chanter

Galley Piper

Trap

Type Depth to crest ft ss Lowest closing contour ft ss GOC or GWC ft ss OWC ft ss Gas column (It) Oil column (ft)

8240 9300 8560 9040 320 480

Structural 9000 10 700 9100 9690 100 590

12 240 13080

Pay zone


Brent JM 810

21 (16-28)

650 (10-6000)

Sandstone Stat~ord JL/TR 850

23 (16-29)

500 (20-10 000)

Sandstone Galley Volg

11.6 87 250

Sandstone Piper Kimm

13.5 82 80

Hydrocarbons


0.74

1.80

m

0.76

2.04

38

3305

914 1.54

52

5371

Formation water


25 000 0.236

24000 0.270

44000 0.045 m



204 5785 0.27

218 6020 0.26

252 6196

252 5860

Field size


Recoverable 0il (MMBBL) Recoverable gas (BCF) Recoverable NGL/condensate (MMBBL)

D

m

Water and gas injection 1815 3705

n

m

i

R

h

m

m

m

m

m

Production


oil BOPD gas MMCFD

Number/type of well

1976

334 000 500




Table 2 continued

Claymore

JU

8655

Structural

n

JU

0.50-0.90 18-21

0.2-1300

Sandstone

29

680

120 1.10

49 630 0.045

170 3785

3505

33

511

b

KL Clyde Cormorant Crawford

9400

Structural/ Stratigraphic 12 050

12 570

520

Structural/ Stratigraphic 8200 10 000

I0 000

< 1500

Structural

h

n

Valhall KL

0.40-0.95 20-24

20--4000

Sandstone Fulmar Kimm-Volg 650 0.60 20 (5-30) 75 1-1000

Sandstone Brent Baj 300 (250-550) 0.75 13 70 50-1300 9-60

Brent JM

Sandstone

34

1550

408 1.23

37-38 Undersat.

1722, 2370

340, 490 1.24, 1.34

34-36 Undersat. 0.838 1040-2970

224-770 1.15-1.42

31

529 1.32

53 400 0.039

110 000 0.016 0.12-0.17

70000 0.043

190 4080

297 6458 0.9

195-225 4825-5265 0.32

190 3235

3729

45

2773

38 Depletion and water injection 154

h

39 Water injection

572 55 21

m

9

1987

50000

12 producers 11 i~ectors

1979

122 000

1989

n

Skagerrak TR

25

794 1.41

190 3690




T a b l e 2 con t inued

Cyrus Deveron Don Dunlin

Trap

Type Structural Structural Structural Structural Depth to crest ft ss 8238 8650 10 900 8500 Lowest closing contour ft ss 8369 - - - - 9205 GOC or GWC ft ss . . . . OWC ft ss 8369 8910 11 409 9205 Gas column (ft) . . . . Oil column (ft) 131 260 500 705

Pay zone

Lithology Sandstone Sandstone Sandstone Sandstone Formation Andrew Brent Brent Brent Age Palaeocene Bath Bath Baj-Bath Gross thickness (ft) 820 450 420 450 (170-650) Net/gross ratio (average) 0.90 0.12-1.00 0.41-0.55 < 1.00 Porosity (average, range) (%) 20 24 (16-30) 16.5 16-30 Hydrocarbon saturation (average %) 65 70 70 35-85 Permeability (average, range) (rod) 200 100-3000 2-50 < 10 000 Productivity index (BOPD/psi) 20-50 - - 4-15 12-110

Hydrocarbons


35 38 39-42 35 Undersat. - - - - Undersat.

1300 650 1228-2940 960

239 150 335-870 220 1.19 1.12 1.25-1.47 1.13

Formation water


90 000 23 500 17 000 24000 0.028 0.264 0.303 0.I10


Temperature (~ 232 220 265 210 Pressure (psig) 3425 5000 7220 6020 Pressure gradient (psi/ft) 0.32 - - 0.36 0.35

Field size



3286 512 1390 4446 - - 49 723 236 000 878 000 16 48 22 44 Aquifer support Depletion Depletion and Depletion and

waterinjection water injection 12 20 24 363

- - - - - - 6

Production


oil BOPD gas M M C F D

Number/type of well

1990 1984

15 000 4800

2 horizontal 3 producers producers

1989

m

m

1978

126 000



C O M P I L A T I O N T A B L E S 555


Eider Emerald Fu lmar Glamis Highlander

Structural Structural Structural Structural Structural /Stra t igraphic

8450 5100 9900 10 000 8500

9033 5580 - - 10 300 9546

- - 5378 - - - - - -

9033 5580 10 830 10 306 9546

- - - - 930 <81 < 9 8 6

Sandstone Sandstone Sandstone Sandstone Sandstone

Brent Emerald Fu lmar - - Piper, un-named

JM Bath-Cal l O x f - K i m m Volgian JU K L

259 42-64 < 1200 20-140 141 109

0.81 1.00 0.94 0.91 1.00 0.55

23 28 (27-33) 23 15 15 24

75 84 79 88 86 78

375 600 (100-1300) 50-800 40-1500 1350 180

40 3-11 80 - - 100 12

34 24 40 41.5 36 35

Undersat . - - Undersat . - - - - - -

- - O.653 . . . .

1050 2425 1800 3210 800 650

205 300 614 1037 85 70

1.15 1.14 1.43 1.64 1.2 1.1

19 000 52 028 138 000 84 500 87 000 50 000

0.I1 0.14 0.018 0.028 0.08 0.13

225 140 285 246 200 200

5020 2425 5700 4562 4250 4250

- - 0.38 0.29 - - 0.33 0.33

865 3650 2825 790 600 500

- - 170 000 877 500 - - - - - -

42 20 57 50 56 25

Depletion and Deplet ion and Deplet ion and Deplet ion and Gas l i f i /Water in jec t ion

water injection water injection water injection water injection

85 43 462 17.5 68 7

- - - - 264 - - - - - -

1988 1990 1982 1989 1985 1987

57 000 40 000 165 000 10 200 27 000 3000

- - - - 8 8 - - - - - -

- - 7 producers - - 2 producers - - - -

4 i~ec tors 1 injector





Heather Hutton NW Hutton

Trap

Type Structural Structural Structural Depth to crest ft ss 9450 9180 11 000 Lowest closing contour ft ss - - - - - - GOC or GWC ft ss - - - - OWC ft ss - - 10 090 12 932 Gas column (ft) - - - - - - Oil column (ft) > 2350 ~< 910 1932

Pay zone

Lithology Sandstone Sandstone Sandstone Formation Brent Brent Brent Age JM JM JM Gross thickness (ft) 210 (125-369) 275 (I 50-400) 320-550 Net/gross ratio (average) 0.54 0.60 0.45 Porosity (average, range) (%) 10 (0-27) 22 (17-26) 16 (8-24) Hydrocarbon saturation (average %) 65 67 45 Permeability (average, range) (md) 20 (0.1-2000) 100-4500 0.1-2000 Productivity index (BOPD/psi) 0.2-15 15

Hydrocarbons

Oil density ~ API 32-37 34.5 37 Oil type - - - - - - Gas gravity 0.91 - - - - Bubble point (psig) 1930-3890 715-800 - - Dew point (psig) - - - - - - Gas-oil ratio 450-1280 140-160 600-800 Formation volume factor 1.3-1.8 1.12-1.125 1.38-1.42

Formation water


22 000 - - 23 000 0.33 0.36 0.28



227-242 225 245 4950 6300 7315-7563 0.29-0.31 0.34 0.64-0.66

Field size

Area (acres) 10 500 6600 13 440 Gross rock volume (acre ft) 2 200 000 848 000 5 376 000 Recovery factor % 23 34 - - Drive mechanism Water flood Water injection Water injection Recoverable oil (MMBBL) 100 190 145 Recoverable gas (BCF) 61 - - - - Recoverable NGL/condensate (MMBBL) 10 - - - -

Production



Number/type of well

1978 1984 1983

38 000 107 000 86 680

29 producers - - 25 producers 12 i~ectors - - 9 i~ectors





Ivanhoe/Rob Roy Kittiwake

Structural 7670/7730

8052

<382

Structural Structural 7560/7725 9773 - - 1 0 000

7937/7994

< 377 657

Stratigraphic

Sandstone Piper

Supra JU Main Supra 60 165 81 0.69 1.00 0.81 25 24 24 91 87 94 928 1759 508 I2 74 48

Sandstone Piper

JU Main 193 0.93 23 92 2408 189

Sandstone Fulmar Skaggerak JU TR 120 (60-213) <367 0.54 0.2 16-30 6-20 30-90 28 0.1-3200 0.05-10 80

31 29 41

1800 1800 3460

360 360 1391 1.22 1.22 1.80

39

1900

613 1.37

38 Undersat.

1150-1480

300-380 1.2

90 990 0.102

130000 0.02

175 3510

0.35 0.35 0.26 0.31

244 6520-6540 0.30

693 461 707

30 54 41 Nat. water drive/waterinjection

11.2 31.2 14.2 4.0 11.2 19.8

537

62

43.3 26.5

m

m

40 Water injection

70 25

1989

60 000


1991

29 000




558 C O M P I L A T I O N TABLES


trap

Type

Depth to crest ft ss Lowest closing contour ft ss GOC or GWC ft ss OWC ft ss Gas column (ft) Oil column (ft)

Magnus Miller Murchison Ninian

Structural/ Structural/ Structural Structural Stratigraphic Stratigraphic 9186 13 058 9500 8946 10 387 - - 10 450 - -

10 387 13 418 10 106 10 430

1201 361 <600 167 (average)

Pay zone

Lithology Sandstone Sandstone Sandstone Sandstone Formation Kimm_Clay Brae Brent Brent Age JU JU JM JM Gross thickness (ft) 0-820 410-820 425 (250-720) 215 (150-370) Net/gross ratio (average) 0.76 0.80 0.70 0.70 Porosity (average, range) (%) 21 (18-24) 16 (12-23) 22 (16.5-26.5) 20 (16-25) Hydrocarbon saturation (average %) 83 85 70 60-65 Permeability (average, range) (md) 82 (0-950) 11-1200 500-1000 700 (20-2850)

Productivity index (BOPD/psi) <~200 - - - - - -

Hydrocarbons


Formation water




Field size

39 38.5 37 36 Undersat. Undersat. Undersat. - -

- - 4900 1850 1330

750 1813 524 301 1.43 1.97 1.31 1.20

- - 70000 - - - - 0.12 0.03 0.31 0.11

240 250 230 215 6653 7250 6300 - - 0.67 0.27 0.31 0.34

Area (acres) 8154 11 115 4200 22 000 Gross rock volume (acre ft) - - - - - - 4 760 000 Recovery factor % 40 - - 43 35-40 Drive mechanism Water injection Water injection Water injection Water injection Recoverable oil (MMBBL) 665 300 340 1045 Recoverable gas (BCF) - - 570 138 150 Recoverable NGL/condensate (MMBBL) - - - - - - 30

Production



Number / type of well

1983 1992

139 000 113 000

- - 21 producers 9 injectors

1980

127 000

15 producers 11 injectors 1 dual

1978

3 150 000



C O M P I L A T I O N TABLES 559


Osprey Petronella Piper Scapa

Structural Structural/ Structural Structural/

Stratigraphic Stratigraphic 8389 7200 7300 - - 9300 7800 - - - -

- - 7316 - - - -

8918 7648 8510 8812 - - 1 1 6 - - - -

<375 332 < 1210 <761

Sandstone Sandstone Sandstone

Brent Piper Sgiath Piper JM JU JU JU

375 - - < 140 < 320

0.70 1.00 0-0.7 0.7-0.9 25 (22-28) 21 (16-25) 24 (20-28) 24 (18-30) 83 81 88 90

300-2100 212 (10-629) 1200 (200-4000) 4000 (500-10000) 12-65 140 150-450

Sandstone Valhall

KL

SD SA

18 23 77 78 111 390

1 1 - 2 5

31 39 37 32

- - - - Naphtheno-paraffinic - - - - 1 . 0 0 - - - -

605 3350 1600 1104

89-109 1250 430 208

1.09 1.70 1.26 1.16

22 000 76 000 44 000 - -

0.28 0.04 0.045 0.127

214 160 175 185 6000 3450 3700 3384 0.37 0.28 - - - -

1112 240

38 51 Waterinject ion Nat. Water drive

60 17 7

7350

70

Water injection

952

m

SD SA 26 32

Water injection

63

1991 1986

25 000 13 000

- - 1 producer

1976

250 000

1986

28 000

4 producers

4 injectors




Table 2 continued

Tartan

Upthrown Downthrown Tern Thistle

Trap


Structural 9700

10 328

628

Stratigraphic 11 600

12 169

569


8064 (N), 8260 (S)

Structural 85O0

9322

822

Pay zone

Lithology Formation Age Gross thickness (ft) Net/gross ratio (average) Porosity (average, range) (%) Hydrocarbon saturation (average %) Permeability (average, range) (rod) Productivity index (BOPD/psi)

Sandstone Piper JU

15 (12-19) 88 150 (10-1000) 50

12 (9-14) 61 17 (0.1-300) 7

Sandstone Brent JM 284 0.62 22 (20-24) 71 35O 6O

Sandstone Brent JM 200-550 0.20-1.00 24 (16-30) 78 40 -4000

Hydrocarbons


38

3650

1450 1.85

38

2850

1100 1.39-1.65

33 Undersat.

895

177 1.13

38

960

290 1.18

Formation water

Salinity (NaCI eq.) (ppm) Resistivity (ohm m)

95 000 0.027

95 000 0.027

21 000 0.267

23 000 0.253



215 4650 0.26

240 5800 0.30

199 3580 0.34

220 6060

Field size



985

68

Water flood

1996

48

2470

39 Gas lift & Water injection 175

3970 910 000 50 Gas lift& Water injection 396

Production


oil BOPD gas MMCFD

Number/type of well

1981

30000

1989

52 000

1978

124 000




C O M P I L A T I O N TABLES 561

T a b l e 3, Ter t iary /Cre taceous oil and gasfields

Arbroath Balmoral Forties

Trap

Type Structural Structural Structural Depth to crest ft ss 8030 6905 6660 Lowest closing contour ft ss 8250 7110 7274 GOC or GWC ft ss - - - - - - OWC ft ss 8250 7150 7274

Gas column (ft) - - - - - - Oil column (It) 220 145 614

Pay zone

Lithology Sandstone Sandstone Sandstone Formation Forties Andrew Forties & Andrew Age Palaeocene Thanetian Palaeocene Gross thickness (ft) 330 (260-440) 550-850 653-1161 Net/gross ratio (average) 0.50 0.87 0.65 Porosity (average, range) (%) 24 (3-30) 25 27 (10-36) Hydrocarbon saturation (average %) 55 81 85 Permeability (average, range) (md) 80 (1-2000) 20-3300 30-4000 Productivity index (BOPD/psi) - - - - 25

Hydrocarbons

Oil density ~ API 38-42 39.9 37 Oil type - - - - Undersat. Gas gravity - - - - - - Bubble point (psig) 1991 1453 1142-1390 Dew point (psig) - - - - - - Gas-oil ratio 490 366 303 Formation volume factor 1.33 1.26 1.24-1.32

Formation water

Salinity (NaCI eq.) (ppm) Resistivity (ohm m)

135 000 72 000 55 500 0.023 0.039 0.034


Temperature (~ 245 207 141 Pressure (psig) 3700 3145 3215 Pressure gradient (psi/ft) - - - -

Field size



7712 555 000

Water drive

102

3240

45 Depletion and water injection 68

23 000

57 Water injection/ Gas lift 2470

Production



Number/ type of well

1990


1986

35 000


1975

500 000

103 producers



562 C O M P I L A T I O N T A B L E S

T a b l e 3 con t inued

Frigg Maureen Mont rose

Trap

Type Strat igraphic Structural Structural

Dep th to crest ft ss 5856 - - 8040

Lowest closing con tou r ft ss 6414 - - 8250

G O C or G W C ft ss - - - - - - O W C ft ss - - 8702 8250

Gas co lumn (ft) 525 - - - - Oil co lumn (ft) 30 < 650 210

Pay zone

Lithology Sandstone Sandstone Sandstone F o r m a t i o n Frigg Maureen Fort ies Age Lower Eocene Palaeocene Palaeocene

Gross thickness (ft) average 180 140-400 330 (260-440) Net /gross rat io (average) 0.95 - - 0.50

Poros i ty (average, range) (%) 29 (27-32) 18-25 24 (3-30)

H y d r o c a r b o n sa tura t ion (average %) 91 - - 55 Permeabil i ty (average, range) (md) 1500 (900-4000) 30-3000 80 (1-2000)

Product iv i ty index (BOPD/ps i ) - - - - - -

Hydrocarbons

Oil density ~ API 23 36 40

Oil type - - - - - - Gas gravity 0.58 0.78 - - Bubble point (psig) - - - - 2348-2737

Dew point (psig) - - - - - - Gas -o i l rat io - - 393 600-800 Fo rma t ion volume factor 197 - - 1.47-1.56

Formation water

Salinity (NaCI eq.) (ppm)

Resistivity (ohm m)


63 000 - - 111 000 - - - - 0.027

Tempera tu re (~ 142 243 257

Pressure (psig) - - 3792 3744 Pressure gradient (psi/ft) - - - - - -

Field size

Area (acres)

Gross rock volume (acre ft) Recovery factor % Drive mechanism

Recoverable oil ( M M B B L ) Recoverable gas (BCF)

Recoverable N G L / c o n d e n s a t e ( M M B B L )

Production

Star t -up date Produc t ion rate, plateau:

oil B O P D gas M M C F D

N u m b e r / t y p e o f well

24 700 4650

75 54 Deple t ion /Nat . Water drive and water drive water injection

- - 210

9910 748 000

Water drive

98

1977

m

m

1983

12 producers

7 injectors

1976

35 000

15 producers

6 injectors



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