REGISTRERT. 1 < F ft TOTAL - CF.P. DIRECTION FONCTIONNELLE EXPLORATION Departement Laboratoires Exploration GEOCHEMICAL STUDY OF 24/6-1

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1 TOTAL - CF.P. DIRECTION FONCTIONNELLE EXPLORATION Departement Laboratoires Exploration GEOCHEMICAL STUDY OF 24/6-1 J.L. PITTION 3T62125 RL 3741 TEP/DE/LAB 1 < F ft REGISTRERT ADDRESSEES TOTAL GROUP LABORATORIES T.M..M. TEP/DE/LAB CADEX 8 ex, 5 ex, 1 ex, Coordinator : J.L. PITTION Pessac, January 1986

2 C O N T E N T S RESUME CONCLUSION I - INTRODUCTION II - SOURCE ROCK EVALUATION 1I.I QUANTITY OF ORGANIC MATTER. TOTAL ORGANIC CARBON 1I.2 QUALITY OF ORGANIC MATTER Rock-Eval pyrolysis Visual type of kerogen Elemental analysis 1I.3 MATURITY Vitrinite reflectance, TAI Pyrolysis temperature (Tmax) III - HEAD SPACE GAS ANALYSIS, METHANE 5 C13 IV - CONDENSATE ANALYSIS

3 TABLES (in pocket) 1 - Geochemistry analytical results 2 - Reflectometry analytical results 3 - Head-space gas analytical results 4 to 6 Condensate analysis C Condensate analysis thermovaporization FIGURES (in pocket) 1 - Location map (14614) 2 - Geochemical log (14372) 3 - HI vs TOC (14394) 4 - S2 vs TOC (14392) 5 - HI vs Tmax (14393) 6 - S2 vs Tmax (1439) 7 - Tmax vs depth (14391) 8 - Palynofacies log (14399) 9 - Elemental analysis diagram (14412) 1 - Vitrinite reflectance log (14398) 11 - Reflectance histogram log (14397) 12 - Head space gas log (144) 13 - Cl/total gas vs depth (14389) 14-6 C13 vs depth (1441) 15-6 C13 vs wet gas ratio (1383) 16 - a Pristane/C17 vs Phytane/C18 (14415) 16 - b Saturates/Aromatics vs Pristane/Phytane (14415) 17 - Thermovaporization Ip vs Ih (14414)

4 18 - Snowdon diagram (14413) 19 - Synthesis of geochemical results log (1447) 2,21 C15+ saturates chromatograms condensate 22,23 Thermovaporization chromatograms condensate

5 RESUME - CONCLUSION (Fig. 19) Although the Upper Jurassic shales are the best source rocks, the Brent and the Dunlin can be considered as possible source rocks. In the immature Tertiary Cretaceous section some intervals show relatively high organic content (7-1 m, m). At the present time, the beginning of oil window would be at around m and the end (Ro=1.2%) near 4 8 m. The adsorbed gas study shows that high amounts of wet gas have migrated from mature zones into the Heimdal sands. The condensate tested in the Jurassic sands show humic features and thus would have been generated by the Brent shales and coals. Unfortunately due to the use of oil based mud, no extracts can be performed in view of direct correlation between the supposed source rocks and the condensate.

6 I - INTRODUCTION The geochemical study of 24/6-1 (Fig. 1) was performed mainly on the cuttings samples from tin cans sealed at the well site. These cans were taken from 3 m to m about every 25 m. The gas from the head-space of these cans was analyzed. Visual kerogen analysis and maturity study were focused mainly on the Jurassic section. Two samples of condensate (DST 1) from the Middle Jurassic sandstones were also analyzed.

7 II - SOURCE ROCK EVALUATION II.I QUANTITY OF ORGANIC MATTER TOTAL ORGANIC CARBON (TOC) (Tab. 1, Fig. 2, 3, 4) Total Organic Carbon were analyzed by OSA Rock-Eval techniques. Below 2 8 m due to the use of oil based mud, the cuttings and SWC were chloroform washed before analyzing. In the Tertiary section, high TOC (1 to 2%) are present in the 7-1 m interval. They correspond to lignitic debris. Another relatively organic rich level (TOC around 1%) is noted between 1 7 and 2 m. The rest of Tertiary is poorer in organic matter with TOC around.5%. In the Cretaceous section ( m), the organic amount remains relatively low : most of the TOC values are between.3 and.7%. Nevertheless, an organic rich (coaly) SWC (TOC = 1%) is to be noted at 4 69 m. The Upper Jurassic shaly formations (Draupne and Heather) show high organic content : most of the TOC are between 2 and 3.5%. In the Middle Jurassic sandy formation, very thin coal lenses (=^.5 cm) were seen in cores at 4 5 and 4 52 m. At m (core 3) a little thicker coal bed (5 cm) is present : it is embedded in a dark shaly level ( m) showing a high organic content (TOC = 4.35%). Nevertheless, above 4 7 m, coal is a very minor component.

8 The relatively high organic content measured in the sandy samples of the cores are related to hydrocarbons staining. Between 4 71 m and 4 78 m, thicker coals levels are present and were analyzed from SWC at 4 769, and 4 77 m. In the Dunlin shaly formation, the presence of relatively high organic amount (TOC = 1 to 2%) is to be noted. II.2 QUALITY OF ORGANIC MATTER Rock-Eval pyrolysis (Tab. 1, Fig. 2 to 6) Due to the use of oil based mud, below 2 8 m the cuttings and SWC were chloroform washed when still wet. Thus, below 2 8 m, SI values are unusable but TOC, S2, HI and Tmax are considered as representative. In the Tertiary, the hydrogen indices (HI) are low to fair ranging from nearly nil to 3 mg/g. The best HI values correspond to the organic rich interval near 1 85 m. In the Cretaceous, the HI are low between 2 8 and 3 6 m : below this depth, they become higher i.e. mostly between 15 and 3 mg/g. In both the Tertiary and Cretaceous, the S2 are always lower than 4 kg/t. In the Upper Jurassic (Draupne, Heather) the HI are fair but not much higher than at the basis of Cretaceous,

9 i.e. between 15 and 3 rag/g. These relatively low HI (for Upper Jurassic) are due to the relatively high maturity of the formations. Nevertheless, the S2 are between 2 and 1 kg/t and are the highest values in the well. In the sandy Middle Jurassic (Brent), the small coal lenses show HI between 1 and 3 mg/g which is in the normal range at this stage of maturity. One of the two samples taken in the organic shaly level at the bottom of the core 3 ( m) shows a fair HI (344 mg/g). The other samples analyzed in the Brent are sandstones from the cores : they show very high SI amount which correspond to the hydrocarbons staining the reservoir : for these samples the S2 and the HI have no significance in terms of source rock since they are related to secondary products. In the shales from Dunlin the HI are relatively low i.e. between 5 and 13 mg/g. Visual type of kerogen (Fig. 8) Three kerogens from the Tertiary The kerogen at 1 6 m is mixed. show a humic type. In the Cretaceous, the kerogen at 3 25 m is humic. In the lower part of the upper Cretaceous (3 725 and 4 m) the type is mixed and it corresponds to the better hydrogen indices found below 3 6 m. In the Draupne and Heather shales, the kerogens are mostly composed of amorphous matter under its pulverulent

10 and black aspect. Under reflected light, this amorphous organic matter is reflectant. The optical features of the amorphous matter are probably in relation to the relatively high degree of maturity. Small coaly particles (2 to 3%) are also present. In the lower part of the Brent the siltstones show a clearly humic organic matter. In the Dunlin, the bad quality of the kerogen prepa- : ration (high amount of remaining mineral) precludes the identification of the organic type. i Elemental analysis (Fig. 9) j analyzed. Coal samples (from cores and SWC) and kerogens were I The sample at 2 m shows chemical characteristics indicating an immature stage. In the Upper Jurassic ( m) kerogens due to the relatively high maturity stage, (end of the oil winj dow) it is difficult to determine precisely the type of or- ganic matter. " ) ] i The coals at 4 52, 4 512, 4 769, 4 77 m are even more mature. i The two shaly samples at the basis of Brent with H/C! around.65 and /C around 4 show very mature features.

11 II.3 MATURITY Vitrinite reflectance/ TAI (Tab. 2, Fig. 1,11) Vitrinite reflectance analysis were performed on kerogens, and on chips of coal either taken in the cores and the SWC or hand-picked in the cuttings. It is to be reminded that in the cores a small bed (5cm thick) of coal was seen at m and very thin ones at 4 5 and 4 52 m. Moreover, the SWC taken near 4 77 m are coaly and correspond to thicker coal beds as indicated by log data. In the Tertiary, the reflectance values vary between.2% and.4% indicating immaturity. At the basis of the Cretaceous, at 4 69 m a SWC, rich in coaly particles shows a reflectance of.53%. In view of the depth and of other parameters such as Tmax, this value seems a little too low. Near 4 5 m, the reflectance in coal chips from the core is around %. In the coal side wall cores around m, it is around %. These results obtained from coal are reliable and can be considered as reference points. The last two sets of results indicate a very high maturity gradient i.e. around 1% Ro per 1 m. Nevertheless, such a high increase in maturity is not uncommon when reaching a high maturity level, even in a normal thermal regime because of the exponential increase in the kinetic rate. From these data, the beginning of the oil window is uncertain but probably between 3 5 and 3 8 m and the end of the oil window would be reached near 4 8 m. Since an

12 important chronostratigraphical gap occurs at the limit Cretaceous -Jurassic, the abnormal low reflectance value of the SWC at 4 69 m could be explained by a maturity break related to a discordance after erosion. Nevertheless, such an hypothesis would sediments which is unrealistic. involve an erosion of at least 4 m of Pyrolysis temperature (Tmax) (Tab. 1, Fig. 2,5,6,7) Above 2 8 m, the Tmax are always lower than 43 C. Between 2 8 and 3 5 m most of the significant values i.e. corresponding to samples with a sufficiently high TOC and a low amount of secondary products, are around 435 C. At 3 5 m there is a clear increase in Tmax and in the lower parts of the Cretaceous ( m) most of the values are between 44 and 45 C. This increase in Tmax could partly be due to the change of the type of organic matter in relation to the higher hydrogen indices in this zone. and 46 C. In the Upper Jurassic shales, Tmax are between 445 In the coal lenses of the Brent, Tmax values are between 46 and 49 C. The increase from 46 C at m to 488 C at 4 77 m corresponds to the increase in vitrinite reflectance from.9 to 1.3%. The shales of the Dunlin show Tmax in the same range as the Upper Jurassic ones. These data would indicate that the Upper Jurassic shales are in the second part of the oil window and the lower part of the Brent at the beginning of the gas window.

13 Ill - HEAD SPACE GAS ANALYSIS, METHANE s C13 (Tab. 3, Fig. 12 to 15) Tin cans containing cuttings with mud were taken at the well site every 25 m. The composition of the gas (Cl to C4) in the head space was analyzed. Moreover methane <5 C13 was analyzed about every 15 m. In the upper part of the well (i.e. down to 1 5 m), the wet gas ratio (C2 to C4/C1 to C4) is almost nil :the gas is composed only of biogenic methane. From 1 5 m to 2 15 m, the wet gas ratio increases quickly and reaches 7-75% in the interval m. Between 1 5 m and 2 1 m the quantities of gas (compared to the TOC) are relatively high. They correspond to accumulations in the sand interval (Heimdal formation m). Thus, these high wet gas ratios can't be related to autochtonous gases since the host rocks are immature : they are to be related to gases migrated from a more mature zone and accumulated in the Heimdal sandy interval. At 2 84 m, the wet gas ratios show a break and decrease strongly to 5.6%. They remain relatively low down to 4 2 m. Between 4 2 m and the TD, they increase again and the highest values reach about 3%. In the shaly marly Cretaceous section ( m), the gas could have partly an autochtonous origin as indicated by the relatively little negative s C13 values in the still immature section above 3 5 in. Below 4 m, the relatively low wet gas ratio in view of the quick increase in maturity can be explained by the leakage of relatively dry gas from the Jurassic gas condensate bearing reservoir.

14 1 Methane -6 C13 (Fig. 14, 15) In the upper part above 1 4 m, the 5- C13 is very negative (-6 to - 8%o) which is typical of biogenic gas. Between 2 18 m and 2 5 m (Heimdal sand) the 5C13 corresponds to mature gas (-3 to -35%c ) which has migrated from deep zones and accumulated in the Heimdal sand. Between 1 4 and 2 m the decrease in the 5 C13 is due to the mixing of gas leaked from Heimdal sand and the autochtonous one. Between 2 8 and 4 5 m the 6 C13 around -4 to - 45% o probably corresponds partly to autochtonous gas and partly to gas migrated from the Jurassic reservoir. Between 4 5 m and the TD (4 937 m), the analyzed methane corresponds to gas present in the Jurassic reservoir : the <5 C13 values around -3 to - 35% O would indicate a thermogenic origin. The sample at 4 85 m (5 C13 = 43%o) is somewhat anomalous.

15 11 IV - CONDENSATE ANALYSIS (Tab. 4 to 7, Fig. 16 to 18 and 2 to 23) Two condensate samples from DST-1 were analyzed. (C5-C15) fractions were studied. Both the C15+ and light In the C15+ fraction, saturates are abundant i.e. around 86% and the heavy products around 1 to 3%. Although they are the most abundant in the C13-C15 range, n-alkanes are present until C33. The values of Pristane/C17 (~.45) and Phytane/C18 (^.23) indicate a rather mature stage. Pristane/Phytane around would indicate a humic origin (terrestrial organic matter). The indices (Ip and Ih) obtained from the light thermovaporizable fraction indicate a humic origin in a moderate stage of maturity. Since the Ip, Ih, Pristane/Phytane values indicate a land-plant origin, the most probable source for the condensate is the coals and shales of the Middle Jurassic formation which are in a favourable stage of maturity. Unfortunately due to the use of oil based mud, no extracts can be performed in view of direct correlation between the supposed source rocks and the condensate.

16 T a b l e 1 «N O R W A Y 2 4 / 6 - P E T R O L E U M P O T E N T I A L O S A L E G EE N D PAGE s 1 ########################»» #-a T.» C ,,....»,. S I P R O D U C T I V I T Y.... S 2 P O T E N T I A L P R O D U C T I V I T Y,, P I P R O D U C T I O N I N D E X...» TMAX PYROLYSIS TEMPERATURE» # HC HYDROCARBONS INDEX.... HI HYDROGEN INDEX,..... TOTAL ORGANIC CARBON ( WEIGHT 7, OF ROCK ) «KG OF HYDROCARBONS(FREE & THERMOVAPORIZABLE)PER- TON OF ROCK > OIL «KG OF HYDROCARBONS(CRACKING OF KEROGEN) PER TON RATIO (PRODUCTIVITY / PRODUCTIVITY + POTENTIAL PRODUCTIVITY) S3./SI+82 # TEMPERATURE! "OOF THE MAXIMUM FORMATION OF HY DROCARSONS BY CRACKING OF KEROGEN - S2 MG OF HYDROCARBONS(FREE & THERMOVAPORIZABLE)IN «THE ROCK PER G OF TOC SI/TOC MG OF HYDROCARBONS (COMING FROM CRACKING OF «KEROGEN) PER G OF TOC 32/TOC ############################################### No GR DEPTH TOC SI S2 I p! MAX HC HI rt t \ ' "i -1 C\ "'i V.i.!. C.~ = ,, » , 45, 5» 525, 55» 575,, ,, 675» 7, 725» » 8» 825,, 85, 9,, » 2, ,, , 34 2,,69 1» , = 53, = =. 1.,..,,2. 3, 5, K ,, 94., 36 I! It 2... I ,. ^- <-j i ') 2,,. 12, ,,.., ṫ.j., ": J ~\ "'j'.'.t:.,...' / % '.".' o S3

17 \ =... '. ' ' -» " PAGE # NORWAY 24/6--1 ## No 6R O f:<23- c -l S /i. "'. ^"i :""; C"i ;- \/ J::. "; ' DEPTH 925= 95=, 975= 1» 125 =, , 1125, 1175» 12= 125= 13,, 1325, 135» 1375= 1425,, 145, n 1525, 1575,, 16,, 1625,, 165, 17,, 1725= 175,, 18-, 1825= 19,, 2» O /.'..) O-.'."> 21= 2125,, 215» 22,, 2225» 225,, 2275, , 24».,:. t.eu :J = ''J-.J 2475, 25,, = 2575,, 2625, 265,, 2675,= 27» , TOC i, 4 1» = 54, 9 1,26., 68,59, = ,,48 6,,72. 68,,69 69 = 95,,87 :> ",.1., =a.,: ,,67 i,9, 7., 68 71,, ai.. - J , /3 38 =, 13,58 56,49 = 63 = 38» 46,,21, = 6 = 6 8 =, 4 6 4,, 4,= 3 r =,2,1, 1 1 3» » 1 = 6, 8 =, 6 1 = 8 = 9,,25, , 13,9, OS 12 1 i 4 r. I J, 1 4» 4, 1 = 6 :, =, 3.9 «4 =, 3, 3, 2 =, '"?.- i = 8 1= 16. = 25, 81» 7 1r ,,5 = 67,53. 41,= 89 = » 42 5,,5 = 67 :, 83 = 94, 85 = 94 = 11 i.1 = 86 = 8 1= y,,,87 = 93 1= 71 1= 68 1= « , _ Q3 1 1 n ;:.',. '"?' 1 T O 71, 43 1, 6 H 7 1, = 53 =,83 = 72 = ,,41 IP i TMAX A'"."«/!, HC.., A 4 /I r ' " i i HI i V.:' , '., O "? A... :.' i R

18 PAGE! NORWAY 24/6-1» No UK /!.- ;.- "", ' ";?:".,..s.., -.j. ^ C D E P T H , = » , 5 2 9,, » ,, , 5 3» ,, 5 3 5,, ,, » , ,, ,, , , ,, = 5 3 4, , , , , , 5 3 6, , ,, ,, 5 3 7, , , ,, 5 3 8, = ,, , , 1 3 9, » , , ,, , , 1 4, 5.,.,.. i w'w- 3,69,. 36» 49,, «26 33, 38, 3,38. 43,49,,58,59 A A «-\-'r» 3 34,, » , 52,5 47, ,68,2,5, 5, 53,55 52,62,64 41,56, 45,68 = 79,,74-21,54 39, 77 S1 «4 i 3,. 7,. 8. O S ,,8,9 13,, 13,,6,, 7, 17 :: I / 12,,, 1 r. 7,, 14 11, 19 9, 1, 1 i o , 7 '~' -i 24 12, , 2.6., , 6,, 1 3, , 4, 12,,8 52..>.">. i 1, '? 1 = 28,,38?,.. 42 = 2, 2 7, 2, 24 = 31.: -?.if..,5 -JD « "7" 46,,36. 46, 51.71, , 7,, ,58.1., 16,8 1, ,48, , El i, 29,66 1,65 " ^"/ 1 ->, » o.,:;.-.; '7-"?; i TMAX HC HI t " si < -!,,;;..! /.» '."' = '-,9 2.1.,..-.,. "> -i.:c i ,., ,-.^ :;; ;j r-} 21 1 h f O" f'. ' A-i 28

19 I :."j P A8E ; NORWAY i n - X.. No GR DEPTH TOC IP TMAX hic HI ' /'. /Å. (\ "' " "' , = 429, 1 4, Ob 469 = = : 415 = 4174 = 4182, = ,, 421 = 1 426=, 11 4'?1 =; 1 T.,:.,.=. -...< = A V.,:...-/..ti :: 4234, 1 425=, 4267 = ,, 4298, 4322=, , 4375 = 4378=, = 4425» 445, 4475,, 4492 = =, 5 45 = 35 45,, 8 452,, = 9 458,, = ,, 4512» » 4575 = 46== 4625 = 4631,, 5 465,, 4675,, 47, 4725,, 4769,, ,,, /I -/ -7 r,;:, 1 o 64 19, 78 36,67 ii AT 2,= 85 1 = ti = 5 = 68 2 = n = ' '= , i 6 24 = = u25 51 = = 27 = 3 = 25 = 3 =, 19 = 69. '?'? O~-t;, 15 =, 2, 13 3, 43 = 4,, 43, 39, "' " O,,8.42 r=?., Q ,38,, = ,, = , =, , = 8 A "T 37 = 24 '?3 16,78, 3 = 23 = ,47 1 = 31 9,84. i 9 8 i = 72 =, 14., 47 39» 82. 7, = 6.' 9 3, 43 4,,6 6, 15 7, 35 6, 11 9 =, 9 4 = 1 a. -i-,..«..i 3.74 ':'' r"= -1 : = o j. / "j<:.r » , T =:::.il. = -M! - J 3,= t ii.:«, K^!,,6, ,, = 2 1, 22 = 29 2= = ,= 98 1 = 34.,;-, j, / 5 '? r 27 34=46 fl /I 1.31 = 58 1 = 52 7 = » 65 3= i!nr "r /f n - = '"! '! i : ~r o it -" J..=: !" -..: «~, r ^ i p : > _> & 18 2 r~i -:; /i ; - ': i X ' _? -r i::r '"> 'TO A...."...' Pi ".- o "7 2O2 " ! A C!

20 P A G E» 5 # # N O R W A Y 2 4 / A - 1. S R D E P T H T O G S i 3 2 I P T M A X H C H I O3O = 51 48= ,, » » :, , , = , V. 27 1,, K «4' i» = 9, , 13 =, 11 Æ ~ = 54 1= 81 j.» 6 X, 1 i A. i.1 :. 89 i j 14 = 36-34,76 = 77,, '? 'P ";!.,-., :..'.' \S J.. '~l O

21 REFLECTOMETRY Table 2 NORWAY 24/6-1 + : + # + + # + # VI TR INITE EXINITE I N E R T I N I TE GEOCH, NUN, DEPTH, MEAN S-D, NB. MEAN S-D. NB. M E A N S-D. NB. «EAS MEAS MEAS GK4Q22. :! : GK4255. >i> GK4 2É1. A- GK4O29C. i- GK :! GK4 777, i' GR GK4 782, GK47S4. GK GK GK :+: GK42579, GR GK GR43789, GR A'- GR '! GR '! GR4378, GK GR43781, GR43782, GR GR GR GK4351S. GR :! : GK GK433, , , ,26. 3,42,.53.73, , t t t , 6 1, kerogen-cut.o 9 " " 9 " " 22 " " Q " " ll " 28 coaly shale-swc 16 kerogen-cut " " "» " 1 14 " "1 26 "» 3 Silt, coal-core" 3 coal-core 14 Silt. coal-co$e coal core 1 " " 6 Picked coal ^ut. 5» " " 39 k erogen cut.o 44 Picked coal 8ut. 46 " " " 28 Coal SWC 1 7 " " 3 " " 28 kerogen-cut. 9 Picked coal But. kerogen-cut.^ «" , , CAVINGS MEAN 8-D. NB, MEAS o 1 1 o o.13, REWORKED + MEAN S-D. NB, MEAS TOTAL NB. MEAS,

22 Table 3 FICHIER GA2 85/1/23. PAGE ANALYSIS OF HEAD SPACE GAS NORWAY 24/6-1 He NO. GEOCHIM. t t «t»te GR4193. GR4194. GR4195. GR4199. GR42. GR421. GR422. GR424. GR42. GR4G26. GR427. GR428. GR429. GR4211. GR4212. GR4213. GR4214, GR4O215. GR4216. GR4217. GR4218. GR422. GR4221. GR4222. GR4223. GR4224. GR4225. GR4227. GR4O228. GR4 229, GR4231. GR4232. GR4234. III Hi lie «I It DEPTH < HETERS > a. -- it..1..ft» , ft- ^t4l L«lt «b4k «fe«a s she H» W W 11 18H 4: 4l 4t 4= 4< METHANE C1 PPM S t t W 4«4: 41 4< 4t 4i 4t 4! 4e ETHANE C2 PPM J r «U kfe^ «fe «cw «fe ,, 16, 16, 12, VI ,,9 6,,4 7,,4 4= 4= Etttl 4< 4t 4t m % PROPANE I-BUTANE N-BUTANE TOTAL GAS T.O.C. C3 PPM IC4 PPM NC4 PPM C1-C4 / i % 4< 4<,, 4C 4<. 4. 4= ,2 7, , , TG/TOC WET GAS IC4/NC4 4<L/KG CAR4C / 4= 4: 6 1 4i 4! + 4i 4<.71624= = , , , e 4< 4! 4<

23 FICHIER GAZ 85/1/23. PAGE ANALYSIS OF HEAD SPACE GAS NORWAY 24/6-1 4=4: Jft m H W He H i K Ht V )< ift -VHt Vf Hk4( $c ne mmt mm nt»tc4= He»K tffiifi ties xytm n X: NO. GEOCHIM. GR4235. GR4236. GR4237. GR4O238. GR424. GR4241. GR4242. GR4243. GR4244. GR4246. GR4247. GR4248. GR4249. GR4251. GR4O252. GR4253. GR4255. GR4256. GR4O258. GR426. GR4261. GR4O262. GR4264. GR4265. GR4266. GR4267. GR4269. GR427. GR4271. GR4272. GR4274. GR4275. GR DEPTH < METERS > , , = 4< # 4i METHANE C1 PPM = 4= 4i 4= ETHANE C2 PPM , , , : 4i 4< PROPANE C3 PPM 1 «Aal«såa «La «feftft» if.! 2.6 7, , , : 4: 4! 4: 1-BUTANE IC4 PPM.. «I» Am 1 \tm 1 1M fcl « , C N-BUTANE NC4 PPM h_ kfe ma«ta tl- - ^^ mi , , e VV H H V H H H i «lp He V w H f{ 1 F n 4C 4= TOTAL GAS T. C1-C4 la & -~ > <- «1.!. at. al mt , fen M 4: 4: cifeif; O.C. / TG/TOC 4-L/KG CAR4: WET GAS / ^ , ,57 1I , = 4, , = = ; ' = = " ', = 1.22 t.7914= 38, ', = I = ,92 ' C ' = ; = , ; , , 19 4! , ,7.4, IC4/NC , = , = 4=

24 FICHIER GAZ 85/1X23. PAGE ANALYSIS OF HEAD SPACE GAS NORWAY 24/6-1 tys> 41 NO. GEOCHIM. GR4277. GR4O278. GR4O28O. GR4281. GR4O282. GR4O233. GR4284. GR4O236. GR4287. GR4O288. GR4O289. GR4O29O. GR4291. GR4292. GR GR4O729. GR4O73O. GR4O731. GR4732. GR4733. GR4O734. GR4O735, GR4736. GR4737. GR4738. GR4O739. GR4O74O. GR4O741. GR4742. GR4743. GR4744. GR4O745, GR4O c4i^ 4. DEPTH <METERS> s m m sfe jc»; m # ^ m» , 33. METHANE C1 PPM «1» ti<sfe tl4fe «L»'b 4fexU Ht»te»H sf! I»- H! c , ETHANE C2 PPM tl4ia Hr^fc- å4ka.«- I»H "Is H=»p HI « «i 4. PROPANE 4«I-BUTANE C3 PPM < IC4 PPM 1»! H! W P Hi P u «la 4&» tl» tl L» L> lift tl»4b fcl rbft >fsi c >fc} sfe sfe ife i^ 9f<: v« i 83, « , i» i i < » K f « K > i H > f > f > > fc > > ,4 4. 4i N-BUTANE NC4 PPM r» l»li> ilatl» -^Ar tlrn! Sft if! Hi W HJ H«H TOTAL GAS T C1-C4» TA» tl il «1» el» tl t&» tl ti , ,4 1849, , ,». tfehthl -& ft] c i«jt Ht ifajfi H Wt»1 O.C. / , , , , ,49.58,51 TG/TOC L/KG CAR - - «I. t.. tl» «&» «1 tl! ul t&> ii , , WET GAS / fcci»fcft., _. _.a.,a.fc iscjchiiflhshtht , , IC4/NC4 IK 4l» 4 tl> A ^» 4j iff JfC 1» H!» , ,

25 FICHIER GAZ 85/1/23. PAGE ANALYSIS OF HEAD SPACE GAS NORWAY 24/6-1 c 4 if lit it! NO. GEOCHIM. J.«. ml m «^ kl» ^^ - -- ^ GR4748. GR4749. GR475. GR4751. GR4752. GR4753. GR4754. GR4755. GR4756. GR4757. GR475S. GR4759. GR476. GR4761. GR4762. GR4763. GR4764. GR4765. GR4766. GR4767. GR4768. GR4769. GR477. GR4771. GR4772. GR4773. GR4774, GR GR GR4777, GR4778. GR4779. GR478, DEPTH <METERS> ^U«& tl«l «1#«1 hidkfta ll i qt >ft tfi»#c m sfc s#t m n 3325, ! 4: METHANE C1 PPM - -a. ^U^U W< t &åå - -! & ^L.4 ll4l«- - j - &». -AdtdL - - «a,«. - HWWIpV th WW W»ff fttt %«m m Ift 9K Wift aft H » , ETHANE C2 PPM C + PROPANE C3 PPM , te44 41 I-BUTANE IC4 PPM 1 W S , C 4C N-BUTANE TOTAL GAS NC4 PPM C1-C «c 41 UtbUalkkldtLbL LA «l»tl P H 1» «ft K»H»H»l «l , , = 4: 4! T.O.C. / ,38, ,5.53,52.62, ,77, , TG/TOC L/KG CAR4. M «1 ^ «& t& tf <k «1 «1 ~ % f Ht f! W t t? l» K»fs 1 Hilt»! Ic4 4< = , , ,57583, WET GAS / , , , C IC4/NC , C 4C 4C»c

26 FICHIER GA2 85/1/23. PAGE ANALYSIS OF HEAD SPACE GAS NORUAY 24/ < NO, GEOCHIM. it 9ft jf: ^t ift Jfe m Jft if; >fcj Ji GR4781. GR4O782. GR4783, GR4784. GR4785. GR4786. GR4787. GR4788. GR GR GR GR4258. GR42581, GR GR GR GR GR GR GR425S8. GR4326. GR4327. GR4328. GR4329. GR433. GR4331. DEPTH < METERS > S "JBX»(B1.K1. 1# "Jo 1 «A 4] «fsfsitsf Wl , k «c METHANE C1 PPM!. 1- t&m kl tlu-t %%! VfSWf mm HSI , ETHANE C2 PPM - # «X-aL >1>1, 1»1BJ Ifl 9fC 5»!-t ifctfc fcsft , PROPANE C3 PPM AM tl# tå» %ld tlwtl» >l»cil , , «tft w ifc jy; Hi H f I H<l I-BUTANE IC4 PPM» tl»tl> tlb4l» «1» ftl» «Is» «å J , N-BUTANE NC4 PPM L>4lu> -- J.- 'Cjlulfci! I , it.»a..am- --» u - j -.< c1k m Jf. Jfltf V «ft»fs W H TOTAL GAS C1-C T.O.C. / l~ «t «At -t--^-.-. «i <1» d < ^ 1-!... < r- v U WV m if ,53 TG/TOC L/KG CAR , WET GAS IC4/NC4 / 4: t-.m-.ci.» %»! 1»ft fe «te if. HSJf. M\t -ft He L»JL» Aid ^Itftl J >K if! if. SfcJ (ft H rf!

27 CRUDE OIL WELL FIELD FLUIDS : CONDENSAT GRAVITY (gr7cm3) 24/6-1 COMPOSITION DISTILLATE (<21 deg.c) SATURATED HYDROCARBONS AROMATIC HYDROCARBONS RESINS ASPHALTENES SATURATES / AROMATICS NORWAY TEST DEPTH (m) Table 5 G B : 4423 DST-1 7H PERIOD : MIDDLE JURASSIC 452. TO FORMATION : BRENT TEST RESULTS G..R(ra3/m3) : TEMP. (deg.c) : RESULTS OF THE GEOCHEMICAL ANALYSIS.791 ( % WEIGHT ) N-ALKANES COMPOSITION C ( % WEIGHT ) 13 : 14 : : : : : : : : : : : : : : : : : : : : 34 : CHROMATOGRAPHIC PRIST./C 17 PHYT./C 18 PRIST./PHYT. CPI (C24-C32) GRAVITY ( 9r n /cm3: la.p.i : ANALYSIS COMPOSITION OF ALKANES WITH ISOPRENOID STRUCTURE ( % WEIGHT / OF N-ALKANES ) (PRIST.): 4.2 2(PHYT.) : 1.87

28 Table 6 CRUDE OIL NORWAY G B : WELL : 24/6-1 FIELD : FLUIDS : CQNDENSAT GRAVITY (gr/cm3) : COMPOSITION DISTILLATE (<21 deg.c) SATURATED HYDROCARBONS AROMATIC HYDROCARBONS RESINS ASPHALTENES SATURATES / AROMATICS RESULTS.792 ( % WEIGHT ) TEST : DST-l 9H PERIOD : MIDDLE JURASSIC DEPTH (m) : 452. TO FORMATION : BRENT TEST RESULTS G..R(m3/m3) : TEMP. (deg.c) : GRAVITY fgr/cm3 [a.p.i THE GEOCHEMICAL ANALYSIS CHROMATOGRAPHIC ANALYSIS 4-ALKANES COMPOSITION ( % WEIGHT C " : 3.43 ' 25 : 2.21 : : 1.16 ) PRIST./C 17 PHYT./C 18 PRIST./PHYT. CPI (C24-C32) COMPOSITION OF ALKANES WITH ISOPRENOID STRUCTURE ( % WEIGHT / OF N-ALKANES ) (PRIST.): (PHYT.) : 1.71

29 NORWAY 24/6-1 Table 7 THERMOVAPORISATION RESULTS OF CRUDE OIL DEPTH METRES PERIOD OIL DENSITY API FORMATION PRESSURE GRADIENT FORMATION TEMPERATURE II Ih 12 BENZENE n HEXANE RATIO BENZENE + TOLUENE NAPHTENES PARAFFINS n ALKANES % in nc4-ncl5range MIDDLE JURASSIC BRENT DST 1 7h DST 1 9h [2.2 f Me C6 + 3 Me 3 isomeres of DiMe Cyclo C,. Ih = n C7 x 1 Cyclo C, peaks ^ Me Cyclo C, II = n C6 Me Cyclo 12 = n C7 1 trans 2 DiMe Cyclo C : % in n C, - Toluene range