Ill 10. DRILLING auid SUMMERY

Transcription

1 Ill 1. DRILLING auid SUMMERY

2 CASING INTERVAL Well: Casing: Bit: 657/31 3" 36" Operator: Statoil 392, m 392, m 453, m 456, m Quantity: Material: Units: Unit Price: Total Cost NOK: 9 Wyoming Benite 1 Caustic Soda 2 Soda Ash 2, 85, 12, 18, 85, 24, VOLUME m3 48, Total Cost for Interval: Cost per meter , 286,33 Days: Cost per m3: 381,77 Page 1

3 CASING INTERVAL Well: Casing: Bit: 657/31 2" 26" Operator: Statoil 392, m 456, m 881, m 9, m Quantity: Material: Units: Unit Price: Total Cost NOK: Barite CMCHV 7, 29, 6 9, , VOLUME m3 1 1, TotafCost for Interval: Cost per meter , 389,93 Days: 4 Cost per m3: 171,42 Page 1

4 CASING INTERVAL Well: Casing: Bit: 657/ /8" 171/2" Operator: Statoil 392, m 9, m 1846, m 186, m Quantity: Material: Units: Unit Price: Total Cost NOK: 199 Barite 224 Propol SL 84 Propol Reg 148 Gypsum 19 Caustic Soda 14 Probioll 4 kg 25 I 7, 56, 56, 55, 85, 485, 139 3, , 42 54, 8 14, 1 615, 6 79, VOLUME m3 725, Total Cost for Interval: Cost per meter , 324,68 Days: Cost per m3: 429,92 Page 1

5 CASING INTERVAL Well: Casing: Bit: 657/31 9 5/8" 12 1/4" Operator: Statoil 392, m 186, m 3168, 3183, m m Quantity: Material: Units: Unit Price: Total Cost NOK: Barite Propol SL Gypsum Caustic Soda Probio II Sodium Bicarbonate Lime Propol reg. Wyoming Benite 4 kg 25 I 25kg 7, 56, 55, , 8, 43, 75 56, 76, 82 2, , 14 25, 4 335, 11 64, 4 56, 1 443, , 3 496, VOLUME m , Total Cost for Interval: Cost per meter ,75 848,86 Days: 19 Cost per m3: 965,64 Page 1

6 CASING INTERVAL Well: Casing: Bit: 657/31 7" Liner 81/2" Operator : Statoil 392, m 3183, m 3953, m 3974, m Quantity: Material: Units: Unit Price: Total Cost NOK: Barite Lignite Caustic Prothin Caustic Soda Proseal Miltemp Benite Wyom. Prodefoam Proplug F Soda Ash Gypsum Prothin C Imcospot Pipelax Propol SL Propol reg Probio II Kemseal Sodium Bicarbonate Lime Diaseal M Benite 5 Ib 25 I 4 kg 5 Ib 2 I 25 I 5 Ib 4 Ib 7, 1, 9, 85, 415, 2 36, 2, 768, 12, 12, 55, 9, 58, 8 25, 56, 56, 485, 2 4, 8, 43,75 448,64 6, 795 2, 28 9, 25 74, 18 53, , 52 68, 86, , 6, 12, 11, 2 7, , 66, , 4 48, 16 49, 621 6, 1 32, 218, ,84 1 2, VOLUME m3 Total Cost for Interval: 1 646, ,59 Cost per meter 3 443,69 Days: 52 Cost per m3: 1 654,9 Page 1

7 CASING INTERVAL Well: Casing: Bit: 657/31 6" Operator: Statoil 3974, m 4757, m Quantity: Material: Units: Unit Price: Total Cost NOK: Barite Propol SL Kemseal Caustic Soda Proseal Miltemp Benite Wyom. Prodefoam Sodium Bicarbonate Probio II 51b 51b , 56, 2 4, 85, 415, 2 36, 2, 768, 8, 485, 187 6, , 41 4, 2 89, 61 5, , 18, , 3 68, 14 65, VOLUME m3 536, Total Cost for Interval: , Cost per meter 1 495,5 Days: 34 Cost per m3: 2 184, Page 1

8 CASING INTERVAL Well: Casing: Bit: 657/31 Testing Operator: Statoil Quantity: Material: Units: Unit Price: Total Cost NOK: Barite Propol reg Kemseal Prothin Benite Miltemp Benite Wyom. Prodefoam Sodium Bicarbonate Probio II Caustic Sodsi Nutplug C/F Zinc Carbonate 5 1b 51b , 56, 2 4, 9, 76, 2 36, 2, 768, 8, 485, 85, 12, 425, 262 5, 4 554, 12, 2 16, 2 58, 51 92, 58, 4 68, 7 6, 4 85, 1 36, 4 2, 1 275, VOLUME m3 149, i Total Cost for Interval: , Cost per meter Days: 47 Cost per m3: 2 82,25 Page 1

9 Volume summary MUD VOLUME SUMMARY WELL: RIG: 657/31 Ross Rig OPERATOR: Statoil Section: 36" 26" 17 1/2" 121/4" 8 1/2" 6" Testing Hole from [m] Hole to [m] Hole length [m] Mud Type Vol buildt Vol transfered from external Vol transfered to external Vol behind casing [m3] Vol dumped Vol lost to formation Vol lost on solids equipment Vol transferred to next interval Vol cuttings drilled [cub. m] Benite , 42, CMC , 152, Gyp/polymer , Gyp/polymer , Gel/Ligno. Kemseal/Pac/Miltemp , 14, Squeezed/left in hole TOTALS mud buildt mud dumped mud lost to formation mud lost on solids cont. mud behind csg mud left in hole total mud left in hole total vol cuttings drilled 5277, 3789, 122, 935, 13, , 487,3 total buildt total dumped total left In hole Page 1

10 4.2 Repeat Formation Testing A total of 3 RFT run were performed in the well. All RFT runs were done before the well was sidetracked. A total of 42 pressure measurements were attempted during the RFT logging. 7 pressure points indicated good/very good permeability, 2 points demonstrated fair/low permeability and 2 points poor permeability. Seal failure/supercharge occurred in 8 attempts while 3 measurements showed a tight formation. In as many as 19 attempts the tool was not able to get any seal to the formation. The only sampling obtained was in RFT run 3c in the Gam formation at 361 m RKB. The 2 3/4 gallon chamber was emptied offshore, containing gas and some condensate. The 1 gallon chamber was sent onshore for laboratory analysis, but was lost during transfer in the laboratory.

11 Data from 2 3/4 gallon chamber: Fill up time Opening pressure Recovery Density mudfiltrate Density condensate Amount CO2 Amount H2S : 18 minutes : 145 bar. : 2.5 m3 gas and 1.69 litres of condensate/ mudfiltrate. : 1. g/cm3 :.79 g/cm3 :.5 % : none Approximately gas composition: Cl : 84.7 % C2 : 9.3 % C3 : 4.3 % IC4:.7 % NC4: 1. % Opening pressure 1 gallon chamber 145 bar. Fill up time: Recovery: 32 min Lost in laboratory.

12 4.3.4 DST NO. 2 Objectives: Confirm movable hydrocarbons. Receive good reservoir samples for analyses. Pressure and temperature measurements. Determine permeability and productivity of the perforated interval. Perforation interval: m RKB. The test was performed by using of the following test string: 3.5" tubing in a 7" liner Downhole tester valve 4 pressure gauges in gauge carriers Tubing conveyed perforation, 12 shot/foot Test performance The well was perforated underbalance using drillwater as cushion with a differential pressure of approximately 1 kpa. The well was perforated with the choke manifold open on a 25.4 mm choke to surge tank. There was little response of flow. After 7 hours and 21 minutes the well was shutin. The cumulative production was measured to approximately 55 litres. One buildup period was performed before the well was opened to run bottom hole samplers. Three bottom hole samplers were run.

13 The bottom hole sampling was done with three PSTE sampler types at three different depths. The depths were , and m RKB. The bottom hole pressure and temperature during sampling were kpa and 131. Deg.C. Some oil and gas was trapped between the LPRN and the APRM valves.

14 Analysis of the gas samples from Statoil: ompcment N2 C2 Cl C2 C3 IC4 NC4 IC5 NC5 SUM SUM SUM SUM SUM TOTAL C6/NC6 C7/NC7 C8/NC8 C9/NC9 C1+ PSTE TS / / / PSTE TS / /.12.54/.3.5/ TS212: MW = g/mol and a density of.731 (Air=1.). Analyses of the oil and the gas trapped between the LPRN and the APRM valves from Schlumberger: Component N2 C2 Cl C2 C3 IC4 NC4 IC5 NC5 C6 C7+ Total Oil Gas The oil was heated to 5 Deg. C. Density Viscosity Avg. molar mass oil.858 g/cc at 3 Deg.C 795 cp at 4 Deg.C g/mol gås.74 (air=l.) 21.4 g/mol

15 4.3.5 DST NO. 3 Objectives: Receive good reservoir samples for analyses. Pressure and temperature measurements. Determine permeability and productivity of the perforated interval. Perforation interval: m RKB. The test was performed by using of the following test string: 3.5" tubing in a 7" liner Downhole tester valve 4 pressure gauges in gauge carriers Tubing conveyed perforation, 12 shot/foot Test performance The well was perforated underbalance using drillwater as cushion with a differential pressure of approximately 1 kpa. The following flow and shutin periods were performed: Cleanup flow Cleanup buildup Main flow Main buildup Multirate flow Multirate buildup 378 min. 575 min. 816 min min. 364 min. 722 min. Figure shows the test performance. Three out of four gauges performed well during the test.

16 TIME hh:mm WELL PRESS Bar Clean uo f] Low W' Lth 12 7 mm 14: : 16: 17: 18: End clean UT? flo^j :3 Main jflow period 7:3 9: 11: 14: 16: 17: HEAD TEMP DegC CONDENSATE RATE Sm GRAV. g/cc with ] L9.5 Ipm (48/64") End main flow period 18: 23: : Multi] rate f] Low period with 12.7 mip 'f32/64") Choke 15: 15:45 Multi] rate f] Low period with 19.5 ipm (48i'64"Y 17:15 17:45 Multiiate f] Low period with 25.4 miti (64/64") choke 19: 19:3 2: Close 9 8: 349. End Dih? NO chole manii r old. I RATE Sm3* 1 GAS 12/6; I") fixed clloke JPRN GRAV. air=l GOR Sm3/ Sm choke not c] Losed H2S ppm choke CO 2 %

17 Test analysis Data from the Hallibur gauge no is used in the test analyses. The test analyses are performed on the build up periods from the Cleanup flow, Main flow and the Multirate flow periods. The test is evaluated as a gas test. The semilog data is reached. Gauge 1119 sensing depth: m RKB Analyses Pressure P (kpa) Perm, k (md) Skin S Buildup Period Gauge P* Reservoir P Homer Homer Homer * 474 * * Cleanup Main Multirate * Reservoir pressure P is calculated to mid perforations with a fluid density of.8 g/cc. Figure shows the rate history used in the analyses. Figure 4.3.3, and shows the LogLog Buildup, Homer Buildup and the Hor ner Analysis plot. The results from the Cleanup shut in period give the best results because the LPRN tester valve failed during the Main and the Multirate shut in periods.