4.7 Formation Temperature
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1 4.7 Formation Temperature The maximum recorded temperatures (BHT) obtained during logging have been converted to static formation temperatures (T f ) using a Homer plot technique. The recorded BHTs and the estimated static formation temperatures are listed in table 4. The data used for the calculations are listed in table 4.6. The data have been plotted in fig. 4, and include a maximum BHT measurement of 91 C at 2454 mrkb MD, recorded during the well test. J:\EU\WP\U480\FWR\34717.RAP 38
2 Table 4.6: Temperature Data, wells and 17A* Log Date Run No. Temp, meas. point mrkb MD TVD Average recorded temp. C Time since circ. At, hrs Total circ. time at meas. point t, hrs DIL-LSS-LDL-GR-SP A RFT-GR A DITE-MSFL-LDL-CNL-GR B DSI-GR A SHDT-GR (DIPMETER) A RFT-GR B DITE-MSFL-SDT-GR-SP* A LDL-CNL-GR* A SHDT-GR* (DIPMETER) A RFT-GR* A *347-17A J:\EU\WP\U480\FWR\34717.RAP 40
3 Formation Pressures DEPTH mrkb TVDmMSL HYDROSTATIC MUD PRESSURES (before)(after) psia psia FORMATION PRESSURES (HP-gauge) psia bara COMMENTS RUN IA TIGHT FORM. DRY TEST DRY TEST DRY TEST Segregated sample attempted at Flowline plugged. Cable stuck. RUN2B DOUBTFUL SUPERCHARGED SUPERCHARGED REMARKS: The pressures> are temperature corrected RKB: 26 m Table 5 Formation pressures, well BAaToRERF 78
4 Formation Pressures A W \ DEPTH mrkb TVDmMSL HYDROSTATIC MUD PRESSURES (before)(after) psia psia FORMATION PRESSURES (HP-gauge) psia bara COMMENTS RUN IA DRY TEST SEAL FAILURE Segregated sample attempted at 2495, and m. Lost seal. RUN IB Segregated sample attempted at , 2498, , 2498, , and 2499 m. Probe and flowline to 2 34 gal (;hamber plugging , 2496, REMARKS: The pressures are temperature corrected RKB: 26 m Table 5.6 Formation pressures, well A 6.91 BAaToRERF 79
5 Formation Fluid Samples RUN NO. DEPTH mrkb 2 34 gal chamber 1 gal chamber 1A 1881 Opening pressure : 0 Gas : 0 cuft Oil : 0 cc MudWater : 9500 cc Remarks: Cable got stuck during sampling at 1881 m gal chamber opened at rig floor. RKB: 26 m Table 5.7 Results from 1 and 2 34 gallon chambers, well BAaToRERF 80
6 Formation Fluid Samples A RUN NO. DEPTH mrkb 2 34 gal chamber 1 gal chamber IA 2495 Opening pressure Gas Oil MudWater 50 psia Film cc 0 Film 1750 cc IB Opening pressure Gas Oil MudWater 150 Film 1800 psia cc Remarks: RKB: 26 m RUN 1A: Lost seal on the 2 34 gal chamber RUN IB: Probe and flowline to 2 34 gal chamber plugging Table 5.8 Results from 1 and 2 34 gallon chambers, well A 6.91 BAaToRERF 81
7 Well test A Formation Fluid Perforation interval (mrkb MD) Last flowing rate (Sm3D) Last flowing water-cut (fraction) Last flowing wellhead pressure (bar) Last flowing bottom-hole pressure at mrkb (bar) Choke size (mm) Dead oil density (kgm3) Gas gravity (air= 1) GOR (Sm3Sm3) - at separator pressure (bar) - at separator temperature (DegC) Tarbert oilwater Table 5.9 Test results, A.7.91 HaSERF 82
8 Saga Petroleum a.s. 6.2 MUD PROPERTIES, DAILY REPORT Well: Date Hole size Hole depth Mud weight PV YP Gel strength ph Alkalinity Pf Mf Ca++ mg1 Clmg1 Sand % Solids % Mudtype " 36" 36" 36" 26" 9 78" 26" 26" 26" 26" 17 12" 17 12" 17 12" 17 12" 17 12" 17 12" 17 12" 17 12" 17 12" A.l A WATER BASED WATER BASED WATER BASED
9 Saga Petroleum a.s. 6.2 MUD PROPERTIES, DAILY REPORT Well: Date Hole size Hole depth Mud weight PV YP Gel strength ph Alkalinity Pf Mf Ca++ mg Cling Sand % Solids % 38.0 Mudtype to
10 Saga Petroleum a.s. 6.2 MOD PROPERTIES, DAILY REPORT Well: A Date Hole size Hole depth Mud weight PV YP Gel strength ph Alkalinity Pf Mf Ca++ mg Clmg Sand %.2.2 Solids % Mudtype to (Jl
11 SAGA PETROLEUM a.s MUD MATERIALS USED WELL NO.: Materials Unit 36" hole 26" hole 1712" hole hole Total AGIPACK LV AGIPACK REG. ALCOMER 75L BACBAN 3 BARITE BENTONITE CAUSTIC SODA CITRIC ACID KCL (BRINE) KCL (POWDER) LAMPAC LV LIME MAGCO POLYSAL POLYDRILL POLYPLUS POT. BICARB SIL. DEFOAM SODA ASH SOD. BICARB XANTHAN GUM MT MT BBL ,000 4, ,659 2, , , , ,775 1, , , , ,564 2,500 3, ,775 1,225 1,975 1, , to en J:\SL\WP\U80921\MUD.TRK
12 SAGA PETROLEUM a.s MUD MATERIALS USED WELL NO.: A MATERIALS mi HOLE TESTING TOTAL AGIPACK LV AGIPACK REG. BACBAN 3 BARITE CITRIC ACID D.D. 208 DESCO HEC GYPSUM KCL (BRINE) KCL (POWDER) MAGCO POLYSAL POLYPLUS POT. BICARB SIL. DEFOAMER SOD. BICARB XANTHAN GUM XANVIS MT LIT BBL 7, , ,000 2,575 1,075 2, , , 50 1, , , ,000 2,575 1,075 3, , J:\SL\WFttJ80921VMUD.TRK -J
SAGA PETROLEUM A.S RFT WELLSITE WORKSHEET. RKB-MSL: 18m RIG: WEST ALPHAk FORMATION PRESSURE SO<PSIA) SOXPSIA) HP(PSIA) NORMAL TEST ,1 5776,3
Well 7-9 Formation Pressures (RFT) r i WELL NO: 7-9 PRESSURE UNITS: PSIA SAGA PETROLEUM A.S RFT WELLSITE WORKSHEET RKB-MSL: 8m RIG: WEST ALPHAk PAGE OF: WITNESSED BY: BAa & TOR DATE: -9 RUN* A TEST* DEPTH
Pressure data were read from the FMT raw data log. They were then coded for test results, test and permeability qualities. A
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Perforated interval: m RKB, Aldra Formation. First ) Last recorded flowing/buildup pressure at 4192 m RKB
Flow Data Summary,, DST No. 1 Perforated interval: 4302-4336 m RKB, Aldra Formation Description First Flow Production time 438 Total influx 4.5 sm Fluid water Well head pressure 177 B.H. flowing pressure
All pressure points were taken in the Jurassic formation.
FORMATION MULTI TESTER (FMT) After drilling to m RKB, one FMT run was completed to check the formation pressure. Then drilling to TD at 6 m RKB, 6 FMT runs were conducted. Three runs were performed with
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