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193-027
Pages NOT Scanned in this Well History File · XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. it ~'~' 02/~ File Number of Well History File PAGES TO DELETE RESCAN Complete Color items - Pages: n Grayscale, halftones, pictures, graphs, charts- Pages: n Poor Quality Original - Pages: n Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs 'of various kinds Other COMMENTS: Scanned by: na Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: is~ STATE OF ALASKA ALASKA-åIL AND GAS CONSERVATION COM1vrtSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Commission 1 b. Well Class: Anchorage o Development 0 Exploratory o Stratigraphic ~ Service 12. Permit to Drill Number 193-027 306-089 13. API Number 50- 029-22343-00-00 14. Well Name and Number: RECEIVED' JUN 2 2 2006 No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged ~ Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2292'FSL,2516'FEL,SEC.36,T12N,R14E,U~~ Top of Productive Horizon: /S IfF . 4070' FSL, 3127' FWL, SEC. 31, T12N, RyŒ, UM Total Depth: IS-~ 4222' FSL, 3592' FWL, SEC. 31, T12N, RJA'Ë, ÙM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 688758 y- 5979929 Zone- ASP4 TPI: x- 694354 y- 5981851 Zone- ASP4 Total Depth: x- 694815 y- 5982015 Zone- ASP4 18. Directional Survey 0 Yes ~ No 21. Logs Run: MWD, Gyro Zero Other 5. Date Comp., Susp., or Aband. 4/212006 6. Date Spudded 02115/1993 7. Date T.D. Reached 04/28/1993 8. KB Elevation (ft): 49' PBU AGI-07 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 9. Plug Back Depth (MD+ TVD) 10992 + 8459 10. Total Depth (MD+TVD) 11015 + 8474 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL Ft Ft 16. Property Designation: ADL 034628 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CASING SIZE 20" 13-3/8" 9-518" 7" WT. PER FT. 91.5# 68# 47# 29# GRADE H-40 K-55 I L-80 NT -80-S L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE Top BOTTOM Top BOTTOM SIZE 30' 106' 30' 106' 30" 34' 3937' 34' 3502' 16" 4020' 10306' 35' 8017' 12-114" 10130' 11013' 7903' 8472' 8-1/2" CEMENTING RECORD 11 yds Arcticset 2604 cu ft PF 'E', 460 cu ft Class 'G' 460 cu ft Class 'G' Uncemented Slotted Liner AMOUNT PULLED 22. 23. Perforations 0Ren to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD ~D JUL 0 { 2006 26. Date First Production: Not on Injection Date of Test Hours Tested TVD 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) . . 7",26#, NT-80-S 9590' - 10051' 5-1/2",17#, L-80 10051' - 10135' 10055' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVÃL (MD) AMOUNT & KIND OF MATERIAL USED 9917' P&A Perfs wi 51 Bbls Class 'G' Cement 4200' Set EZSV 3935' Set Kick Off Plug: 59 Bbls Class 'G' Cement PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA OIL-BBL PRODUCTION FOR TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED .......... OIL-BBL Press. 24-HoUR RATE""'" GAs-McF CHOKE SIZE GAS-OIL RATIO W A TER-BBL GAs-McF OIL GRAVITY-API (CORR) W A TER-BBL 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 1212003 RBDMS BFL JUN 2 8 2006 n R I h I f\ 1°ZllrED ON REVERSE SIDE /' b 28. GEOLOGIC MARKER~ 29. --- FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top Sadlerochit 10375' 8061' None Base Sadlerochit 10970' 8445' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHUbble~~. ~ Title Technical Assistant Date ()(P(zz/CKp PBU AGI-07 193-027 306-089 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Shane Gagliardi, 564-5251 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only -- c.~ Well: Field: API: Perm it: AGI-07A Prudhoe Bay Unit 50-029-22343-01-00 206-052 Accept: Spud: Release: 04/26/06 05/13/06 05/31/06 Nabors 27E -..-~~-~--- PRE-RIG WORK 03/26/06 BEGIN TO RIH WI 4.52" CENT WI EQ PRONG TO EQ PLUG. 03/27/06 ATTEMPT TO EQ PLUG. RECOVERED -1 CUP OF FINE SAND IN BAILER. RAN 4.5" LIB SHOWS CLEAN FN. PULLED 51/2" XXN PLUG AT 10099' SLM. TAGGED BTM AT 10926' SLM (10965' CORRECTED). PERFORMED SBHP AS PER PROGRAM. 04/01/06 MU 2.3" BDN. PT SURFACE EQUIPMENT. DEPRESSURE S-RISER. 04/02/06 SERVICE WING VALVE. KILL WELL WI 840 BBLS OF 1% KCL AT 6.5 BPM. LAY IN THE FOLLOWING FROM FLAGGED DEPTH OF 10965', 5 BBLS 15.8# NEAT CLASS G CEMENT, 25 BBLS 15.8# CLASS G WITH 12 LBIBBL AGGREGATE, 21 BBLS 15# NEAT CLASS G (51 BBLS TOTAL CEMENT PUMPED). PARK ABOVE PERFS, UNABLE TO BUILD ANY SQUEEZE PRESSURE WITH 10 BBLS CEMENT BEHIND PIPE. LAY IN REMAINING CEMENT. WAIT AT SAFETY (9200'), HESITATE, BUILT PRESSURE OF 450 PSI, HELD GOOD. CLEAN OUT TO 9940' WITH BIO AND XS-1% KCL. CHASE OUT AT 80%. LOST COIL PUMP AT 7483'. SWAP PUMPS. RE-TAG AT 9938'. CHASE OUT AT 80%. 04/03/06 CHASE OUT FROM TOC AT 9938', AT 80% WI XS KCL TO SURFACE. WASH BOP'S. RIH TO 2000'. FREEZE PROTECT WELLBORE TO 2000' WI WATERlMETH. TRAP 230 PSI WHP. RDMO. 04/04/06 DRIFT WI 5.75" CENT AND S-BAILER TO 9748' SLM. DRIFT WI 3.5" CENT AND S-BAILER TO 9772' SLM. DRIFT WI 2.5" CENT AND 10' X 2.25" P. BAILER TO TOC AT 9917' SLM. (SAMPLE OF CEMENT RECOVERED) MIT-T TO 3500PSI (PASSED). LEFT WELL S/I. 04/05/06 T/I/O= 120/770/50. TEMP= SI. BLEED lAP <100 PSI (PRE E-LlNE CHEM CUT). TBG AND IA FL'S ARE AT SURFACE. BLED lAP FROM 770 PSI TO 0 PSI IN 45 MINUTES (6.28 BBLS). TBG PRESSURE DECREASED 20 PSI DURING BLEED. BLED 20 PSI FROM OA. MONITORED PRESSURES FOR 30 MINUTES. lAP INCREASED 30 PSI. FINAL WHP'S= 100/30/30. 04/06/06 MEDIUM TUBING PUNCH FROM 9568' - 9570' 15'X4 STRAND STRING SHOT FROM 9576' - 9591' CHEM CUT 7" TUBING AT 9590' WITH 5.75" CHEMICAL CUTTER AND 5.75" TANDEM ANCHORS, 14" X 0.75" GGG AND 132" X 2" BRF3 CHEM CUTTER HEAD SHOW INDICATIONS OF VERY EVEN BURN, SLIGHT WASHOUT ON 20 PERCENT OF HEAD. 04/07/06 T/I/O= 01010 -CIRC OUT. PUMPED 7 BBLS NEAT, 970 BBLS 1% KCL DOWN IA UP TUBING TAKING RETURNS TO TIGER TANKS. PUMPED 150 BBLS DIESEL TO FREEZE PROTECT TBG AND IA. FINAL WHP'S= 01010. 04/10/06 SET BPV. 04/27/06 T/I/O=0/40010, TEMP=SI. BLEED lAP FOR RIG. IA FL AT SURFACE. BLED lAP TO SLOP OIL TRAILER, FROM 400 PSI TO 0 PSI IN 10 MIN. RETURNED 1.6 BBLS DIESEL. FWHP=O/O+/O. BPEXPLORATION Operations ·SummaryReport Page 1 .... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: AGI-07 AGI-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 4/26/2006 Rig Release: 5/16/2006 Rig Number: 27E Spud Date: 5/13/2006 End: 5/31/2006 Date From - To Hours Task Code NPT Phase Description of Operations 4/26/2006 15:00 - 00:00 9.00 RIGU P DECOMP Accepted Rif at 1500 hrs, 4/26/06. Clean and Organize Rig and Conduct House Keeping Prior to Commencing Operations 4/27/2006 00:00 - 03:00 3.00 RIGU P DECOMP Clean and Organize Rig, Perform House Keeping Prior to Commencing Rig Operations 03:00 - 05:00 2.00 WHSUR P DECOMP PJSM; 7" x 9-5/8" Annulus Pressure 400 psi, Tubing Pressure 400 psi. RlU DSM Lubricator and Pull BPV. RID Lubricator. 05:00 - 09:00 4.00 WHSUR P DECOMP RlU High Pressure Lines to Circulating Manifold and Tree. 09:00 - 09:30 0.50 WHSUR P DECOMP Bled Down Annulus to 0 psi. Volume Back 1.6 bbl. 09:30 - 13:30 4.00 WHSUR P DECOMP Circulate Seawater Through Manifold to Gas Buster. Leak in Gas Buster Line-Repaired. Pressure Test Lines to 3,500 psi. Union Leaking on Mudline Jumper Hose Union. Attempt to tighten - retest, no success. Break out and inspect need to replace. 13:30 - 14:00 0.50 WHSUR P DECOMP Held Discussion with Anchorage Team on Annulus Pressure. Removed Mudline Hose. Decision was Made to Change Out Seawater for 9.3 ppg KCL Brine 14:00 - 18:00 4.00 WHSUR N WAIT DECOMP Wait on 9.3 ppg KCL Brine 18:00 - 20:00 2.00 WHSUR P DECOMP RlU Injection Line for Well Kill Operations 20:00 - 21 :00 1.00 WHSUR P DECOMP Pump 20 bbls Seawater to Fill Lines and Gas Buster. Test Lines to 250 psi low I 3,500 psi high. 21 :00 - 22:00 1.00 WHSUR P DECOMP Pump 100 bbls Down Annulus at 3 bpm Holding 400 psi Back Pressure on Choke. Taking Diesel Returns from Tubing to Cuttings Tank 22:00 - 00:00 2.00 WHSUR P DECOMP Circulate 9.3 ppg KCL Brine Down Tubing at 5 bpm Holding Constant Bottom Hole Pressure of 400 psi. 4/28/2006 00:00 - 01 :30 1.50 WHSUR P DECOMP Circulated Surface to Surface 9.3 ppg KCL Brine Down Tubing at 5 bpm Holding Constant Bottom Hole Pressure of 400 psi. to Kill Well. At Completion of Kill Operations Well Bore Pressure o psi. 01 :30 - 02:00 0.50 WHSUR P DECOMP Monitor Well-Static 02:00 - 03:00 1.00 WHSUR P DECOMP Blow Down Circulating Lines. RID Lines from Tree 03:00 - 05:00 2.00 WHSUR P DECOMP Remove Tree Cap and Install TWC. Install Tree Cap and Pressure Test TWC from Below to 250 psi. Bled Down Pressure. Blow Down All Lines 05:00 - 09:00 4.00 WHSUR P DECOMP Held PJSM; N/D Tree and Adapter Flange. Inspec Hanger Threads. Threads in Bad Shape, Will Use Spear to Pull Tubing. Take Well Head Measurements, RT-TS = 28.00', RT-CS = 30.30', RT-GL = 33.50' 09:00 - 12:00 3.00 BOPSUF P DECOMP Held PJSM; Inspect Bridge Crane. P/U BOPE Stack from Cellar Pedestal and Position On Tubing Head. Install Flange Bolts and BOPE Securing Cables 12:00 - 16:30 4.50 BOPSUF P DECOMP Open Lower Ram and Blind Ram Cavities. Inspect 3-1/2" x 6" Variable and Blind Shear Rams. Both Sets in Good Condition. C/O Upper Rams to 4-1/2" x 7" Variables 16:30 - 21 :30 5.00 BOPSUF P DECOMP Held PJSM; Remove Top of GL Hydril Annular, C/O Element, Replace Top of Annular. Tighten All Ram Doors 21 :30 - 23:00 1.50 BOPSUF P DECOMP Held PJSM; Remove BOPE Securing Cables, Attach Bridge .Crane to BOPE's, Remove Lower Flange Bolts, Set BOPE's Back on Cellar Pedestal. 23:00 - 00:00 1.00 BOPSUF P DECOMP Install 13-5/8N Drilling Spacer Spool on Tubing Head 4/29/2006 00:00 - 06:00 6.00 BOPSUF P DECOMP Held PJSM; Pick BOPE Stack from Cellar Pedestal and Set on Drilling Spool. Install Flange Bolts. Torque Bolts on Upper and Lower Drilling Spool Flanges. Connect Kill and Choke Lines Printed: 6/512006 11 :44:05 AM Page 2_ BP EXPLORATION Operations Summary Report .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date AGI-07 AGI-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E 4/29/2006 4/30/2006 Charge Accumulator System, Close Blind Rams, Installed Drilling Riser and Flowline. Air Boot Leaked Between Annular and Riser. NID Flowline and Drilling Riser, C/O Air Boot, N/U Riser and Flowline Rebuild High Pressure Mudline Between Substructure and Pit Complex Rebuild High Pressure Mudline Between Substructure and Pit Complex. Test to 4,500 psi Open Lower Ram Door and Check Ram Activation for Interference with DP Test Joint Tool Joint. No Interference. Close Ram Door and Secure RIU BOPE Test Equipment Perform Full Body Test on Stack and Choke Manifold, 250 psi low / 4,000 psi high. Door Seal on Blind Rams Failed. Bled Down All Pressure to Opsi. Replaced Driller Side Blind Ram Door Seal Perform Full Body Test on Stack and Choke Manifold to 250 psi / 4,000 psi. RIU Test Joint, Connect Testing Manifold and Equipment Test 13-5/8" 5,000 psi BOPE, Choke Manifold, Floor Safety Valves and TOP Drive IBOP's to 250 psi low /4,000 psi high. Annular Tested to 250 psi low /3,500 psi high. All Tests Held 5 min Each. Test Witnessed by Lou Gramaldi - AOGCC Rep. Bill Decker, Rodney - WSL. and Allen Lunda, Charles Richards Nabors Toolpusher. Test #1. Upper Pipe Rams, Kill HCR, Choke Vlaves #1 & #2 Test #2. Manual Kill, Choke Valves #4, #5 & #6 Test #3. Choke Valves # 8 & #9 Test #4. Choke Vlave #3-Failed Test #5. Choke Valve #7-Failed Test #6. Choke Valves #11 & #12- Off Drillers Side Top Pipe Rams Door Seal Failed SFAL DECOMP Replaced Off Drillers Side Top Pipe Ram Door Seal DECOMP Continue with BOPE Test Test #6. Choke Valves #11 & #12 Test #7. Choke Valves #13, #14 & #15 Test #8. Manual Choke Test #9. Annular Test #10 P/U 7" Test Joint, Upper Pipe Rams. Test #11 7" Test Joint, Annular Test #12 Blind Rams, Retest Choke Valve #3 Test #13 Restest Choke Valve #7 Test #14 Floor Dart Valve Test #15 Floor Safety Valve Test #16 Lower IBOP-Failed-Replaced-Retested Test #17 Upper IBOP Accumulator Test Initial Pressure 3,200 psi After Closure 1,900 psi 200 psi Recovery 27 sec. Full recovery 1 min 45 sec. Nitrogen Btls 8 at 2,425 psi Avg From - To Hours Task Code NPT Phase 06:00 - 10:00 4.00 BOPSUF P DECOMP I 10:00 - 14:00 ¡ 4.00 BOPSUF N SFAL DECOMP 14:00 - 00:00 10.00 BOPSUF N RREP DECOMP 00:00 - 03:30 3.50 BOPSUF N RREP DECOMP 03:30 - 04:30 1.00 BOPSUF P DECOMP 04:30 - 05:00 0.50 BOPSUF P DECOMP 05:00 - 05:30 0.50 BOPSUF P DECOMP 05:30 - 07:00 1.50 BOPSUF N SFAL DECOMP 07:00 - 07:30 0.50 BOPSUF P DECOMP 07:30 - 09:30 2.00 BOPSUF P DECOMP 09:30 - 12:00 2.50 BOPSUF P DECOMP 12:00 - 13:30 13:30 - 00:00 1.50 BOPSUPN 10.50 BOPSUF P Start: 4/26/2006 Rig Release: 5/16/2006 Rig Number: 27E Spud Date: 5/13/2006 End: 5/31/2006 Description of Operations Printed: 6/512006 11 :44:05 AM ~-- BP EXPLORATION Operations Surnmary Report Page·3 ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: AGI-07 AGI-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 4/26/2006 Rig Release: 5/16/2006 Rig Number: 27E Spud Date: 5/13/2006 End: 5/31/2006 Date From - To Hours Task Code NPT Phase Description of Operations 5/1/2006 00:00 - 01 :00 1.00 BOPSUF N SFAL DECOMP Replace Lower Top Drive IBOP 01 :00 - 01 :30 0.50 BOPSUF N SFAL DECOMP Test Lower Top Drive IBOP to 250 psi low I 4,000 psi high 01 :30 - 02:30 1.00 BOPSUF N HMAN DECOMP MIU Choke Line Directioanl Flow Block 02:30 - 03:00 0.50 BOPSUF N HMAN DECOMP Test Choke Line to 250 psi low I 4,000 psi high 03:00 - 04:30 1.50 BOPSUF P DECOMP Install Lubricator Extension. PIU and MIU DSM Lubricator. Check 7" x 9-5/8" Annulus Pressure, 0 psi. Pull TWC. RID Lubricator. 04:30 - 06:00 1.50 PULL P DECOMP PIU and M/U Baker7", 26# Spear dressed with DBL 6.220" Grapples & Circ. Cups. 06:00 - 06:30 0.50 PULL P DECOMP RIH with Baker Spear Assy. and Engage 7" Tubing below Hanger. PIU to 100,00 Up Wt. to Check Grapple Integrity. BOLDS. PIU to 260,000# Up Wt., Hanger Unseated, at 292,000# String Pulled Free. Continous Pull of 240,000# to Pull hanger to Rig Floor. 06:30 - 08:00 I 1.50 PULL P DECOMP Circulate Surface to Surfaqce with 9.3 ppg Brine at 7-1/2 bpm at 1,030 psi. Loss 30 bph While Circulating. RlU Control Line Spooler While Circulating 08:00 - 08:30 0.50 PULL P DECOMP Monitor Well-6 bbl Loss per/hr 08:30 - 09:00 0.50 PULL P DECOMP B/O Spear Assy. UD Spear Assy and 1 Joint DP 09:00 - 11 :00 2.00 PULL P DECOMP PJSM; RlU Casing Tongs, Single Line Compensator, C/O Bails and Install 7" Elevators 11 :00 - 12:30 1.50 PULL P DECOMP PJSM; Held Training Session on Pulling Tubing and Working with Single Joint Compensator. Pull 7 Jts 7" 26# NT-80-S-IPS NSCC Tubing 12:30 - 17:30 5.00 PULL N RREP DECOMP Pipe Skate Hyd. Pipe Ejector Cylinder Failed. Replace Cylinder 17:30 - 22:30 5.00 PULL P DECOMP POH with 7" 26# NT-80-S-IPC NSCC Tubing. B/O and UD SSSV. 54 Full Joints UD. Recovered 29 SS Control Line Bands. RID and UD Camco Spooling Unit. 22:30 - 23:00 0.50 PULL P DECOMP Conducted BOP Drill While Pulling Casing. Held Post-Op Review of Drill with All Personnel Involved. 23:00 - 00:00 1.00 PULL P DECOMP POH with 7" 26# NT-80-S-IPC NSCC Tubing 5/2/2006 00:00 - 00:30 0.50 PULL P DECOMP Pull 7" 26# NT-80-S-IPC NSCC Tubing, UD 66 Joints Total 00:30 - 15:00 14.50 PULL N RREP DECOMP Pipe Skate Broke, Love Joy Coupling between Electrical Drive Motor and Hyd. Drive Pump. Replaced. Functioned Tested Skate before Continuing Operations 15:00 - 17:30 2.50 PULL P DECOMP Pull 7" Tubing, UD 105 Joints Total 17:30 - 18:30 1.00 PULL P DECOMP Service Top Drive, Blocks, Crown, Iron roughneck. 18:30 - 20:30 2.00 PULL N RREP DECOMP Troubleshoot Stabbing Board Winch. Winch Drive Motor Failed. Safe Out Stabbing Board Man Basket in Stationary Postion. 20:30 - 00:00 3.50 PULL P DECOMP Pull 7" Tubing, UD 155 Joints Total 5/3/2006 00:00 - 01 :30 1.50 PULL P DECOMP Pull 7" 26# NT-80-S-IPC NSCC Tubing, UD 172 Joints Total 01 :30 - 03:30 2.00 PULL N RREP DECOMP Repaired Coupler on Pipe Skate. Coupler Shifted on Drive Shaft, Removed Coupler, Redressed and Reinstalled 03:30 - 07:30 4.00 PULL P DECOMP Pull 7" Tubing, Recovered 239 Joints Total, 1 ea. 15' Cut Off Joint and SSSV Assy. 07:30 - 08:30 1.00 PULL P DECOMP RID Casing Tongs and Single Joint Compensator, Remove Casing Equipment from Rig Floor 08:30 - 09:30 1.00 WHSUR P DECOMP Install 5" Elevators, P/U Test Joint, M/U Wear Ring Running Tool. Installed Wear Ring, RILDS. B/O Running Tool and UD Test Joint 09:30 - 11 :00 1.50 CLEAN P DECOMP RlU Schlumberger Unit. Hang Sheaves and String E-Line. 11 :00 - 13:00 2.00 CLEAN P DECOMP M/U 8.5 Gauge Ring I Junk Basket, RIH on E-Line to 4,400'. Printed: 6/512006 11 :44:05 AM --- -- Page 4'- BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date S/3/2006 S/4/2006 POH and Recovered 1 SS SSSV Contol Line Band M/U Halliburton 9-S/81\ EZSV Bridge Plug and Set at 4,200'. POH with E-line. RlU Test Chart and Test 9-S/8" Casing and Bridge Plug to 3,SOO psi. Held 30 min. RID Schlumberger E-Line Tools and Equipment Remove Elevators, C/O Bails, Install Elevators Service Top Drive, Blocks and Crown Held PJSM; M/U Baker 9-S/8" Casing Cutter. M/U Top Drive and Circulated at 2 bpm to Function Test Cutter Blades. RIH with 9-S/8" Casing Cutter on S" DP to 2,340'. P/U DP 1 x 1 from Pipeshed RIH with 9-S/8" Casing Cutter on S" DP and Tag EZSV at 4,200'. P/U DP 1 x 1 from Pipeshed Established Parameters; UP WT 122,000#, DN WT 120,000#, RT WT 120,000#, Pump 1,340 psi at 6 bpm. P/U to 4,010'. Engage Pumps at 47 spm, 813 psi. S/O to 4,03S', Did Not Find Collar, P/U to 4,OOS', Increase Pump to 900 psi, SO spm, S/O and Found Collar at 4,020'. Shut Down Pumps, S/O to 4,040'. Engage Rotary, Slowly Increasing RPM to 60, Bring Pumps up to 60 spm at 1,4S0 psi. Torque 6,000/7,000 ft/lbs. When Cutters Penetrated 9-5/8" Casing Torque Dropped Down to 4,000 ft/lbs. RPM's Increased to 6S. Shut Down Pumps and Rotary. WEXIT Monitored 9-S/8" x 13-3/8" Annulus for Pressure, 0 psi. Closed Annular and Try to Establish Circulation. Slowly Pressure Up to 7S0 psi. No Returns. Bled Down Pressure to 0 psi. Open Annular. WEXIT POH to 3,880'. Repeat Casing Cutting Process. WEXIT Montiored OA for Pressure, 0 psi. Close Annular and Try to Establish Circulation W/O Success. RlU to Reverse Circulate Down OA Taking Returns Up IA. Pressure Up to 6S0 psi on OA. Held S min. No Bleed Down. Pressure Up to 1,SOO psi. Held S min. No Bleed Down. Bled Down All Pressures to 0 psi. Monitor Well 16 bph Losses. Blow Dn All Lines. POH with S" DP Monitor Well, Fill Trip Tank, Function Tested BOPE's B/O and UD 9-S/8" Casing Cutter Change Out Top Pipe Rams to 9-S/8". Monitoring Losses with Blind Rams Closed Circulating Across the Top of the Hole with Rig Pump P/U S" Test Joint and Pull Wear Ring. UD Test Joint P/U 9-5/81\ Test Joint and Test Plug. Install Plug and Joint RlU BOPE Testing Equipment. Tested 9-S/81\ Rams to 2S0 psi low / 3,500 psi high. Held Tests for S min Each. RID Test Equipment. Test Witnessed by WSL Chris Clemens. UD Test Joint and Test plug P/U 2 Joints S" DP and M/U Baker Spear Assy Addressed with a Single Grapple for 9-S/8" 47# Casing. Torqued All Connections on Assy as per Baker Rep. 12.74' BHA Length Spear 9-S/8" Casing, BOLDS. P/U to 140,000# to Ensure Spear Engaged. S/O to 40,000#, P/U to 2S0,ooO#, Functioned Lock-Down Screws, All Moved Freely. S/O to 40,000#, P/U to AGI-07 AG 1-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E From - To Hours Task Code NPT Phase 11 :00 - 13:00 2.00 CLEAN P DECOMP 13:00 - 14:30 1.50 DHB P DECaMP 14:30 - 1S:30 1.00 CASE P DECaMP 15:30 - 16:30 1.00 DHB P DECaMP 16:30 - 17:30 1.00 PULL P DECaMP 17:30 - 18:30 1.00 DEMOB P DECaMP 18:30 - 19:00 0.50 STCTPL P WEXIT 19:00 - 00:00 S.OO STCTPL P WEXIT 00:00 - 03:00 I 3.00 STCTPL P WEXIT 03:00 - 04:00 1.00 STCTPL P WEXIT 04:00 - OS:OO I 1.00 STCTPL P OS:OO - OS:30 OS:30 - 07:30 0.50 STCTPL P 2.00 STCTPL P 07:30 - 10:00 2.50 STCTPL P WEXIT 10:00 - 10:30 0.50 STCTPL P WEXIT 10:30 - 11 :00 0.50 STCTPL P WEXIT 11 :00 - 13:00 2.00 STCTPL P WEXIT 13:00 - 13:30 0.50 STCTPL P WEXIT 13:30 - 14:30 1.00 STCTPL P WEXIT 14:30 - 15:30 1.00 STCTPL P WEXIT 1S:30 - 16:00 0.50 STCTPL P WEXIT 16:00 - 18:00 2.00 STCTPL P WEXIT 18:00 - 20:00 2.00 STCTPL P WEXIT Start: 4/26/2006 Rig Release: 5/16/2006 Rig Number: 27E Spud Date: 5/13/2006 End: 5/31/2006 Description of Operations Printed: 6/512006 11 :44:05 AM - BP EXPLORATION Operations Summary Report PageS'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: AGI-07 AGI-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 4/26/2006 Rig Release: 5/16/2006 Rig Number: 27E Spud Date: 5/13/2006 End: 5/31/2006 Date From - To Hours Task Code NPT Phase Description of Operations 5/4/2006 18:00 - 20:00 2.00 STCTPL P WEXIT 300,000#, No Pipe Movement, Increased Up Wt to 350,000#. Pipe Moved 6". S/O to 40,000#. Work Pipe from 40,000# to 400,000#. With 400,000# Up Wt Measured 19" Pipe Stretch. Baker Calculations Susgests Pipe Stuck Around 3,500'. Work Pipe from 40,000# to 450,000# While Waiting on Schlumberger E-Line Unit. 20:00 - 21 :00 1.00 STCTPL P WEXIT Set 9-5/8" Pack-Off Back into Wellhead and RILDS. Released Spear, POH and UD Spear Assy and DP 21 :00 - 22:30 1 .50 STCTPL P WEXIT Held PJSM with Schlumberger E-Line Crew. Load Rig Floor I with E-Line Equipment and Tools. RlU and Hang Sheaves. I String E-Line and Raise Blocks. I 22:30 - 00:00 i 1.50 I STCTPL P WEXIT M/U E-Line CCUGRlUSIT Logging Tools and RIH, Monitoring Well with Trip Tank 5/5/2006 00:00 - 04:30 4.50 STCTPL P WEXIT Run Schlumberger CCUGRlUSIT Log 04:30 - 05:30 1.00 STCTPL P WEXIT Send Logs to Town. Discuss Options with Anchorage Team 05:30 - 06:00 0.50 STCTPL P WEXIT RID E-Line. UD Sheaves and Tools 06:00 - 06:30 0.50 STCTPL P WEXIT P/U 1 Joint 5" DP . M/U Wear Ring Running Tool. Install Wear Ring. RILDS, Remove Running Tool and UD DP 06:30 - 07:30 1.00 STCTPL P WEXIT Held PJSM; P/U 1 Stand 5" DP and M/U 9-5/8" Casing Cutter. Replaced Cutter Blades. Pump at 2 bpm to Confirm Blades Extended. Shut Down Pumps. Retract Blades and Secure with Duct Tape. 07:30 - 08:00 0.50 STCTPL P WEXIT Blow Down Top Drive and Lines 08:00 - 10:00 2.00 STCTPL P WEXIT RIH with 5" DP to 3,880' 10:00 - 11 :00 1.00 STCTPL P WEXIT Break Circulation at 2 bpm and Locate Old Cut at 3,900'. Shut Down Pumps and Reposition Cutter at 3,910'. Proceed to Cut 9-5/8" Casing with 50 Rotary rpm, 4 bpm Pump at 1,000 psi. Torque While Cutting 5,000/8,000 ft Ibs. Torqued Dropped to 2,000 ft/lbs and Pressure Dropped to 200 psi When Blades Penetrated Casing. Slowly Reduce Pump and Rotary to O. 11 :00 - 13:30 2.50 STCTPL P WEXIT Close Annular and Circulate 9.3 ppg Brine Down DP at 5-1/2 bpm at 300 psi. Taking Retruns Off OA to Cuttings Tank Until Clean Returns at Surface. Total Displaced Volume 288 bbls 13:30 - 14:00 0.50 STCTPL P WEXIT Monitor Well, 7 bph Fluid Loss 14:00 - 16:30 2.50 STCTPL P WEXIT POH with 5" DP 16:30 - 17:00 0.50 STCTPL P WEXIT B/O and UD Casing Cutter 17:00 - 18:00 1 .00 STCTPL P WEXIT P/U 2 Joints DP, M/U Baker Spear Dressed with 9-5/8" 47# Casing Grapple. RIH and Engaged Spear. BOLDS, Pull on Spear and Casing, String Free at 195,000# Up Wt. Pull 9-5/8" Hanger and Packoff to Rig Floor 18:00 - 19:00 1.00 STCTPL P WEXIT Circulate 233 bbls Annulus Volume to Surface. Final Circulating Rate 10 bpm at 200 psi. Installed False Bowl on Rotary Table for 9-5/8" Casing 19:00 - 19:30 0.50 STCTPL P WEXIT Held PJSM; Breaking and UD Down 9-5/8" Spear. Pulling 9-5/8" Casing 19:30 - 21 :30 2.00 STCTPL P WEXIT B/O Spear, Make All Service Breaks and UD Same. UD 2 Joints DP 21 :30 - 22:00 0.50 STCTPL P WEXIT RlU Casing Tongs, C/O Elevators to 9-5/8" Side Doors 22:00 - 00:00 2.00 STCTPL P WEXIT POH with 9-5/8" 47# NT-80-S Casing. UD 9-5/8" Hgr and Joints #1 - #12 5/6/2006 00:00 - 05:00 5.00 STCTPL P WEXIT POH with 9-5/8" 47# NT-80-S Casing. Joints #13 - #98. Cut Off Joint 10.31' 05:00 - 05:30 0.50 STCTPL P WEXIT RID Casing Tools and Equipment Printed: 6/512006 11 :44:05 AM - BP EXPLORATION Operations Summary Report Page 6 _ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: AG 1-07 AGI-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 4/26/2006 Rig Release: 5/16/2006 Rig Number: 27E Spud Date: 5/13/2006 End: 5/31/2006 Date From - To Hours Task Code NPT Phase Description of Operations 5/612006 05:30 - 06:00 0.50 STCTPL P WEXIT Clear and Clean Rig Floor 06:00 - 08:30 2.50 STCTPL P WEXIT PJSM; C/O Top Rams to 2-7/8" to 5" Variables 08:30 - 10:00 1 .50 STCTPL P WEXIT P/U Test Joint and Install Test Plug. RIU Testing Equipment 10:00 - 12:30 2.50 STCTPL P WEXIT Tested 2-7/8" x 5" Variables Rams to 250 psi low 14,000 psi high, Rams Leaked By, Bled Down Pressure, Functioned Rams, Retested-Failed Again 12:30 - 14:30 2.00 STCTPL N SFAL WEXIT Replaced 2-7/8" x 5" Rams with 4-1/2" x 7" Rams 14:30 - 15:00 0.50 STCTPL N SFAL WEXIT Tested 4-1/2" Variables to 250 psi low 14,000 psi high. Both Tests Held 5 min Each. Test Witnessed by WSL, Chris Clemens 15:00 - 15:30 0.50 STCTPL P WEXIT Pull Test Plug and Install Wear Ring 15:30 - 19:00 3.50 STCTPL P WEXIT Held PJSM; P/U and M/U 9-5/8" Casing Milling BHA; Lockomatic Mill wi 8.565" Nose - Jet Sub - Bumper Sub - Oil Ja - XO - 9 X 6-3/8" DC's - XO. 307.25' Total Length 19:00 - 20:00 1.00 STCTPL P WEXIT Service Top Drive, lronroughneck, Blocks and Crown 20:00 - 22:00 2.00 STCTPL P WEXIT RIH with 5" Dp to 3,900' 122:00 - 00:00 2.00 STCTPL P WEXIT Held PJSM; Pump 65 bbls 9.4 ppg Brine. Chased by 585 bbls I 9.0 ppg Milling Fluid at 9 bpm, 675 psi. 5n 12006 00:00 - 06:30 6.50 STCTPL P WEXIT Established Parameters; Up Wt 130,000#, On Wt 124,000#, Rt Wt 125,000#, WOM 4,000#, Pump 105 spm at 850 psi, Rotary 85/100 rpm, On Btm Torque 5,500 Nibs, Off Btm. Torque 3,000 Nibs. Pumping Sweeps Every 5' to 7'. Mill from 3,910' to 3,927'. Sweep Formula 25 bbls 9 ppg Fluid, .2 ppb Soda Ash, 3-4 ppb Duo-Vis, .05 ppb Caustic Soda, 10 ppb Gel, .1 gpb Greenside 25 G, 3.75 Ibs Super Sweep. 06:30 - 09:00 2.50 STCTPL P WEXIT Circulated and Reciprocated Pipe. Pump 150 spm at 1250 psi, Rotary 100 rpm. Pump Weighted 11.0 ppg Super Sweep (recovered 400 Ibs metal), Pump Hi-Vis Super Sweep (recovered 200 Ibs metal), Pump Weighted Super Sweep (recovered 50 Ibs metal) 09:00 - 00:00 15.00 STCTPL P WEXIT Mill from 3,927 to 3,971'. WOM 10-15K. RPM 75/100, Pump 150 spm at 1525 psi. Torque Off Btm 3,000 NIbs, Torque On Btm 6,500 - 10,000 ftllbs. Alternating 1 Weighted Sweep to 2 Non-Weighted Sweeps. 5/8/2006 00:00 - 04:30 4.50 STCTPL P WEXIT Mill from 3,970' to 3,990'. WOM 10-15K. Altemating 1 Weighted Sweep to 2 Non-Weighted Sweeps. 04:30 - 06:00 1.50 STCTPL P WEXIT P/U to Circulate and Clear Cutter Blades of Shavings. Work Pipe Back Down to 3,990'. WOM 10-20K, Roatary 50-100 rpm, Pump 10-15 bpm. Pump Weighted Sweep and Super sweep to Clean Well Bore 06:00 - 11 :00 5.00 STCTPL P WEXIT Mill from 3,990' to 4,020'. Pump Sweep Every Hour. Altemating 1 Weighted Sweep to 1 Non-Weighted Sweep 11 :00 - 13:30 2.50 STCTPL P WEXIT P/U to Circulate and Clear Cutter Blades. Pumped Weighted Sweep Followed by Super Sweep. Reciprocated and Rotated Pipe While Circulating, 130 rpm, 180 spm at 1,850 psi I 2,00 psi. Unable to Work Past 3.993' 13:30 - 17:30 4.00 STCTPL P WEXIT POH, Back Ream from 3,993' to 2,137'. R9tary 60 rpm, Pump 180 spm at 2,000 psi. Tight at 2,894' 17:30 - 18:00 0.50 STCTPL P WEXIT Pump Dry Job 18:00 - 19:30 1.50 STCTPL P WEXIT POH with 5N DP 19:30 - 21 :30 2.00 STCTPL P WEXIT POH with Milling BHA; UD DC', Jars, Bumper Sub, Jet Sub, Casing Mill. Printed: 6/512006 11 :44:05 AM -....... .~--" BP EXPLORATION Operations Summary Report PageT'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: AG 1-07 AGI-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 4/26/2006 Rig Release: 5/16/2006 Rig Number: 27E Spud Date: 5/13/2006 End: 5/31/2006 Date From - To Hours Task Code NPT Phase Description of Operations 5/8/2006 21 :30 - 22:00 0.50 STCTPL P WEXIT Clear and Clean Rig Floor 22:00 - 23:30 1.50 STCTPL P WEXIT P/U and M/U BOPE Flushing Tool, Flush BOPE's, Choke Line and Kill Line, Function All Rams and Annular, Reflush BOPE's. STCTPL I P and Flowline. UD Flushing Tool 23:30 - 00:00 0.50 WEXIT P/U Test Joint and Remove Wear Ring 5/9/2006 00:00 - 00:30 0.50 STCTPL P WEXIT P/U Flushing Tool, Flush WellheadfTest Plug Setting Area. UD Flushing Tool 00:30 - 01 :30 1.00 STCTPL P WEXIT P/U Test Joint, M/U Test Plug and Install, R/U Testing ISFAL Equippment 01 :30 - 03:30 2.00 STCTPL N WEXIT BOP test witness waived by Jeff Jones(AOGCC) Witnessed by wellsite leader Rod Klepzig and Nabors tour pusher Rick Brumley. Fill BOPE Stack with Water, Leaking By Test Plug, ¡ Pull Test Plug and Inspect Seal, Seal in Good Condition, I Reinstall Test Plug, Fill with Water, Still Leaking, RILDS, Still Leaking, Removed Test Plug. Installed Upper Test Plug, Filled BOPE's with Water, Full Body Pressure Test to 250 psi / 4,000 psi. 03:30 - 09:00 5.50 STCTPL P WEXIT Test BOPE as per BP and AOGCC regulations, to 250 psi low I and 4000 psi high - Test Hydril to 250 psi low and 3500 psi I I high. Pulled upper test plug, installed a new lower test plug and tested bottom flange ok. Test witnessed by BP wellsite leader Chris Clemens and Nabors tool pusher AI Lunda. 09:00 - 10:00 1.00 I STCTPL P WEXIT Clear floor, install wear bushing. 10:00 - 12:30 2.50 STCTPL P WEXIT Pick up 3-1/2" mule shoe and 20 jts 3-1/2" tubing, totaling 628.80' and xo back to 5" dp. 12:30 - 14:30 2.00 STCTPL P WEXIT RIH with 3-1/2" tbg on 5" drill pipe to 13-3/8" shoe at 3936'. 14:30 - 15:30 1.00 STCTPL P WEXIT RIH while pumping 2.5 bbls/min at 200 psi. Held up at 3992'. Attempt to wash and work past with no success. 15:30 - 17:30 2.00 STCTPL P WEXIT Circulate b/u at at 700 gpm - 650 psi. Rig up cement equipment, hold safety meeting. Up wt=115k - On wt =11 Ok 17:30 - 18:30 1.00 STCTPL P WEXIT Pump 5 bbl water spacer, pressure test surtace lines to 3500 psi, pump 5 bbls water spacer, pump 59 bbls of 17 ppg cement at 4.5 bbls per minute, pump 1 bbl water spacer, displace cement with rig pump, 56 bbls at 6 bbls/minute 18:30 - 19:30 1.00 STCTPL P WEXIT Lay down pup jt and 1 jt of 5" drill pipe. Pull out of cement 8 stands slowly to 3190' 19:30 - 21 :00 1.50 STCTPL P WEXIT Circulate 510 bbls to clear annulus of contaminated cement. Approximately 150 bbls came back with a ph of 11 .2, dropping to a ph of 10.0 in the next 50 bbls of mud pumped. Dropped wiper plug, pumped 51 bbls at 336 gpm at 350 psi. 21 :00 - 23:30 2.50 STCTPL P WEXIT Trip out of the hole to the 3-1/2" tubing. Mud wt in and out 9.1 ppg. 23:30 - 00:00 0.50 STCTPL P WEXIT Rig up casing tongs to lay down 3-1/2" tubing 5/10/2006 00:00 - 01 :00 1.00 STCTPL P WEXIT POH LD XO, 20 Jts 3 1/2" NSCT & Mule shoe 01 :00 - 02:00 1 .00 STCTPL P WEXIT RD 31/2" handling equipment. Clean and clear rig floor 02:00 - 04:30 2.50 BOPSUF P WEXIT MU Flushing tool and flush BOP stack. Function test rams. Pull wear bushing. Repeat Flushing procedure. Service wear bushing and install same. 04:30 - 09:00 4.50 STCTPL P WEXIT RU 5" handling equipment and RIH PU 5" DP 1 x1 bulding stands to TD intermediate hole section. 09:00 - 10:30 1.50 STCTPL P WEXIT Trip out 33 stands and rack back in derrick to TO intermediate hole section. Printed: 6/512006 11 :44:05 AM ---" Page 8 ... BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date AGI-07 AGI-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E 5/10/2006 5/11/2006 From - To Hours Task Code NPT Phase I STCTPL P WEXIT 10:30 - 14:30 ! 4.00 14:30 - 17:00 2.50 STCTPL P WEXIT 17:00 - 19:30 : 2.50 I STCTPL i P WEXIT 19:30 - 20:00 ¡ 0.50 STCTPL i P WEXIT 20:00 - 22:00 ! 2.00 STCTPL P WEXIT 22:00 - 23:30 : 1 .50 STCTPL P WEXIT 23:30 - 00:00 . 0.50 STCTPL P WEXIT 00:00 - 01 :00 1.00 STCTPL ¡ P WEXIT I 01 :00 - 03:30 ¡ 2.50 STCTPL ¡ P WEXIT 03:30 - 04:00 ' 0.50 STCTPL P WEXIT 04:00 - 05:00 : 1 .00 STCTPL P WEXIT 05:00 - 05:30 0.50 STCTPL N HMAN WEXIT 05:30 - 08:00 ; 2.50 STCTPL P WEXIT 08:00 - 10:30 ; 2.50 STCTPL N HMAN WEXIT 10:30 - 12:00 1 .50 STCTPL N HMAN WEXIT 12:00 - 13:30 1.50 STCTPL N HMAN WEXIT 13:30 - 14:30 1.00 STCTPL P WEXIT 14:30 - 17:00 2.50 STCTPL P WEXIT 17:00 - 18:00 1.00 STCTPL P WEXIT 18:00 - 19:30 1.50 STCTPL P WEXIT 19:30 - 20:30 1.00 STCTPL P WEXIT 20:30 - 21 :30 1.00 STCTPL P WEXIT 21 :30 - 22:30 1 .00 STCTPL N WAIT WEXIT 22:30 - 23:00 0.50 STCTPL P WEXIT 23:00 - 00:00 1 .00 STCTPL P WEXIT Start: 4/26/2006 Rig Release: 5/16/2006 Rig Number: 27E Spud Date: 5/13/2006 End: 5/31/2006 Description of Operations RIH PU 5" OP 1x1 bulding stands to TD intermediate hole section. Trip out 31 stands and rack back in derrick to TO intermediate ,hole section. Make up 12-1/4" bha. P/U milltooth bit, mud motor set at 1.83 degrees, stab, and mwd tools. Load mwd tools. Pick up 3 - 8" flex dc'c, xo, 12 jts 5" hwt, 6.25" jar, 5 jts 5" hwt RIH w/5" dp to 3200', strap in hole. Cement compression at 2300 hrs is 1800 psi. I Circulate and condition mud. 420 gpm - 875 psi. Up wt=125k - IOn wt=115k, 9.2 ppg in and out ¡ Circulate and condition mud. 420 gpm - 875 psi. Up wt=125k - IOn wt=115k, 9.2 ppg in and out. !Test 13-3/8" casing to 2750 psi for 30 minutes, record on chart. 160 strokes total at 1 bbl/min. Lost 125 psi in 30 minutes. ! Blow down choke line with air. RIH, tag top set 4-1/2" x 7" variable rams that were left closed after testing casing. Mix and pump dry job to POOH. Mobilize 133/8" storm packer I from Halliburton. At 0530 the compression on the kick off plug I is 4000 psi. ! Wash down from 3180' to 3554' looking for cement while I mobilizing Halliburton. I PU storm packer, set at 45', pull wear ring,set test plug, visually inspect top set of 4-1/2" x 7" variable rams, test same to 4000 psi. Rig down test equipment. Release storm packer and lay down same. M/U top drive, establish slow pump rate, perform D2 and 05 wel kill I drill. Simulate well kill through choke manifold, alternate crew members operating super choke testing well control equipment for operational performance. Wash and ream from 3554' to 3655', tag cement at 3655'. Up wt=125k - On wt =120k, 500 gpm at 1300 psi, 30 rpm rotary, 9.2 ppg in & out, torq=6500. Calibrate depth tracking for Epoch and Sperry Sun. Drill cement from 3655' to 3830'. Up wt=125k - Dn wt =120k, 500 gpm at 1300 psi, 30 rpm rotary, 9.2 ppg in & out, torq=6500. Run water 30 bbls/hr. Change shaker screens to 180's, 140's, 11 O's,84's Orill cement from 3830' to 3927'. Up wt=125k - Dn wt =120k, 500 gpm at 1300 psi, 30 rpm rotary, 9.2 ppg in & out, torq=6500. Circulate while waiitng on supersuckers. Up wt=125k - On wt =120k, 500 gpm at 1300 psi, 30 rpm rotary, 9.1 ppg in & out, torq=6500. Drill cement from 3830' to 3927'. Up wt=125k - Dn wt =120k, 500 gpm at 1300 psi, 30 rpm rotary, 9.0 ppg in & out, torq=6500. Circulate and condition mud, turn up pumps to 600 gppm, hole unloaded. Up wt=150k - On wt =123k, 600 gpm at 1750 psi, 30 rpm rotary, 9.0 ppg in & out, torq=6500. Printed: 6/512006 11 :44:05 AM -"-_ 3tJI' BP EXPLORATION Operations Summary Report Page 9 .., Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: AG 1-07 AG 1-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 4/26/2006 Rig Release: 5/16/2006 Rig Number: 27E Spud Date: 5/13/2006 End: 5/31/2006 Date From - To Hours Task Code NPT Phase Description of Operations 5/12/2006 00:00 - 00:30 0.50 STCTPL P WEXIT Circulate hole clean at 700 gpm at 2100 psi. Up wt=150k, dn wt= 123k, 30 rpm's, 6.5k torq, 8.9 ppg in and out. 00:30 - 03:00 2.50 STCTPL N DFAL WEXIT I Trouble shoot Spery Sun MWD. Tool would not turn on. 03:00 - 06:00 3.00 STCTPL N DFAL ,WEXIT ¡Trip out of hole for MWD tool. 06:00 - 07:30 1.50 STCTPL N DFAL iWEXIT Stand back bha - drain mud motor 07:30 - 08:30 1 .00 STCTPL N DFAL WEXIT Download mwd data 08:30 - 09:30 1.00 I STCTPL N DFAL WEXIT Lay down mwd tool, pick up new mwd tools. 09:30 - 10:30 1.00 STCTPL N DFAL WEXIT Change out bits to a Hycalog PDC 12-1/4" DSX 103H, change I motor bend to 1.50. 10:30 - 11 :30 1.00 STCTPL N DFAL WEXIT Orient mwd to motor, initialize mwd tool. 11 :30 - 13:00 1.50 STCTPL N DFAL WEXIT Trip in hole to 1800'. 13:00 - 13:30 0.50 STCTPL N DFAL WEXIT Make up ghost reamer into drill string 1800' behind the bit. 13:30 - 14:00 0.50 STCTPL ' N DFAL WEXIT Shallow pulse test mwd tool. 14:00 - 15:00 1.00 STCTPL N DFAL WEXIT RIH to 3720'. 15:00 - 19:00 4.00 STCTPL N RREP WEXIT Repair hydraulic leak on top drive. 19:00 - 19:30 0.50 STCTPL N DFAL WEXIT RIH to 3935'. 19:30 - 20:30 1.00 STCTPL P iWEXIT Circulate hole clean. 270 gpm at 500 psi. 8.9 ppg in and out, up 20:30 - 00:00 I i wt= 150k, dn wt=123k. I 3.50 STCTPL N RREP I WEXIT Hydraulic brake on top drive failed, repair same. 5/13/2006 00:00 - 01 :30 1.50 STCTPL N RREP WEXIT Hydraulic brake on top drive failed, replace selinoid. 01 :30 - 02:00 0.50 STCTPL P .WEXIT Make connection, orient pipe to a 150R TF. 02:00 - 06:30 4.50 DRILL P INT1 Time drill 5'/hr to kick off cement plug. 700 gpm @ 1300 psi, I uw=150k,dw=123k, 8.9 ppg in/out, 2k wt on bit. Drilled from I I 3935' to 3957'. AST =4hrs. -~ 1.50! DRILL ~,.96:30 - 08:00 !P INT1 Circulate 10594 stks @ 700 gpm, 1300 psi, uw=150 , '"'- I dw=123k, 9 ppg in/out. '- 08:~~0 1.00 DRILL P INT1 Perform L.O.T., broke down at 673 psi, 12. pg. 09.00 - 10. ~ 1.50 DRILL P INT1 Slide F/3957'-T/3990', 700 gpm @ 130 si, uw=150k, '- dw=123k. 9 ppg in/out. AST =1.5hr . '-, 10:30 - 12:00 '~~O DRILL P INT1 Rot F/3990'-T/4027', 60 rpms =130k, uw=150k, dw=123k, 10~ tq=7k, 9 ppg in/out. 12:00 - 13:00 INT1 Circulate hole clean, . ppg in/out 13:00 - 13:30 0.50 DRILL P INT1 Trip out 3 stand the shoe. 13:30 - 14:30 1.00 DRILL INT1 Establish b ine for clean hole ECD of 9.1 ppg. 14:30 - 15:00 0.50 DRILL P 15:00 - 00:00 9.00 DRILL P 5/14/2006 00:00 - 00:30 0.50 DRILL P 00:30 - 12:00 INT1 12:00 - 00:00 P INT1 Drill F/4027'- T/5066', AST =.5hrs, ART =4.15hrs, TDT =1 0.15hrs, 85 rpm, 5k-12k wt on bit, uw=160k, dw=130k, rw=150k, tq =8k, tq off=7k, mw=9.2ppg in/out, 700 gpm @ 1830 psi. Sli /5066'-T/5096', 750 GPM @ 1900 psi, 5k-12k wt on bit, uw=160 ,dw=130k, rw=150k, tq on=8k, tq off=7k, mw=9.2ppg in/out. Drill F/5096'-T/5 ',850 GPM @ 2300 psi, 5k-12k wt on bit, uw=191 k, dw=135k, in/out. Drill F/5096'-T/'6095', 850 GP 2300 psi off, 2400 psi on, 80 rpm, 5k-20k wt on bit, uw=200k, d 140k, rw=160k, tq on=10k, tq off=8k, mw=9.2ppg in/out. AST =.5, 5/15/2006 2.50 DRILL P INT1 Drill F/6095'-Tf6204', 850 GPM, 2300 psi off, 2 psi on, 80 rpm, 5k-20k wt on bit, uw=200k, dw=140k, rw=160k, tq off=8k, mw=9.2ppg in/out. Printed: 6/512006 11 :44:05 AM Well Job# Loa DescriDtion Date BL Color CD D-23A 10942207 MCNL It::¡ Cc - ¡~'R. 04/22/05 1 lV " A.rp,l..·d"j,.. fo>_ L3..Q8 11136738 RST ¡/<'?! - 1'-/-;;(, 11/04/05 1 1 L3..Q8 11212839 RST Î"x' ~ - 1t.../3 03/29/06 1 1 03-14A 11212846 USIT ;}CG'" /"':,) ~ 04/24/06 1 D.S. 3..Q9 11212840 USIT 17£1 ~ ò ~p 03/31/06 1 D.S.15-17 11221562 SCMT I ~4 - ö.>S4 04/10/06 1 NGI..Q8 11225958 USIT '--"Ie.. lr (;., -b()~ 04/11/06 1 D.S.01..Q4A N/A USIT ';:)Î'J 1_ /5':J 05/06/06 1 12..Q8C 11221571 US IT riö;} -I 3 L., 05/06/06 1 AGI..Q7 11221569 USIT U'!:c. \'13 -69":1- 05/05/06 1 E-15B 11212857 US IT OIC, -04 ::J 05/18/06 1 L-50PB1 40012467 OH LDWG EDIT OF MWD/LWD ~'/~ ,J) - I ~ c... 10/18/05 1 1 RECE!VED Schlumberger MAY 2 4 2006 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,~Oit & Gas CGns. Comæ~C;¡ And1ora<;-e Petrotechnical Data Center LR2-1 900 E, Benson Blvd, Anchorage, Alaska 99508 ."'\ t'-_~ l') C" 1) 1~ \ J (- ':"'-') (]~JÁ- ~/9 siðÇo 05/19/06 NO. 3812 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 1 Anchorage, AK 99501 I} ~"Ö Field: Prudhoe Bay \ 0\. ;.; e e Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage. AK 99503-2836 A TIN: Beth e e ~UL 'uŒ lID FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 l~~~1>~1 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU AGI-07 Sundry Number: 306-089 Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unle s rehearing has been requested. DATED this1!2 day of March, 2006 Encl. AGI-07 A Sundry #305-273 Cancellation e lq~ ;Dz..7 e Subject: AGI-07 A Sundry #305-273 Cancellation From: "Gagliardi, Shane T" <Shane.Gagliardi@bp.com> Date: Mon, 20 Mar 2006 11 :48:35 -0900 To: winton_aubert@admin.state.ak.us Winton, Just a follow up for AGI-07A. The RWO wI scab liner sundry (#305-273) should be cancelled. We have decided to side track the well and request that the sundry application for P&A of the original well bore be approved. If you need more information, let me know. Thanks, Shane Shane Gagliardi Operations Drilling Engineer 907-564-5251 (Office) 907-632-6789 (Cell) i.of 1 3/20/2006 12:49 PM ()Ì'"S "3 )'?9/ (. rAly~,gfo-Yftßf. ((/J¿ ~4A- ~/2..0 Iz.ot'4> I STATE OF ALASKA31/&(OV .~~ RECEIVED ALASKA AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL MAR 172006 20 AAC 25.280 Alaska Oil & Gas Cons. Commission 1. Type of Request: B Abandon / o Suspend o Operation Shutdown o Perforate o Other --------------------------- o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. o Development o Explorato~/ /'f 93-027 (305-273, Prevo 10-403) 3. Address: o Stratigraphic 1m Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22343-00-00 ,/ 7. KB Elevation (ft): 49' 9. Well Name and Number: / PBU AGI-07 8. Property Designation: 10. Field I Pool(s): ADL 034628 Prudhoe Bay Field I Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11015 8474 10992 8459 10123 11010 Casing Length Size MD / TVD Burst Collapse ~trlJcllJr;:¡1 76' 20" 106' 106' 1490 470 ~lJrf;:¡Cp. 3903' 13-3/8" 3937' 3502' 3450 1950 10271' 9-5/8" 10306' 8017' 6870 4760 Pr Liner 883' 7" 10130' -11013' 7903' - 8472' 8160 7020 Perforation Depth MD ~): I Perforation Depth TVD (ft): I Tubing Size: 17#/ Tubing Grade: I Tubing MD (ft): 10630' - 1 0958' 8226' - 8437' 7",26# x 5-1/2", NT80 I L -80 10135' / Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'SB-3A' packer Packers and SSSV MD (ft): 10055' / 12. Attachments: 13. Well Class after proposed work: 1m Description Summary of Proposal o BOP Sketch o Exploratory o Development 1m Service o Detailed Operations Program -'~ 14. Estimated Date for I 15. Well Status after proposed work: / Commencing Operations: Marc~! 27,12006 DOil o Gas o Plugged 1m Abandoned 16. Verbal Approval: Dðte; o WAG DGINJ DWINJ o WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Gagliardi, 564-5251 Printed N~ave Wesley ............... Title Senior Drilling Engineer Signature,' .{r4f'¿ -/~'~1/' >i.. Date ;q//S-;Æ7J, Prepared By NamelNumber: Phone 564-5153 Terrie Hubble, 564-4628 / c/ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ( ?JJl 0 .-rf3q o Plug Integrity ~OP Test o Mechanical Integrity Test o Location Clearance Other: "\ -e. c; t go PE- Subsequent Form Required: ID -7íJ Date Ó,1-IJ- of; ~J~ APPROVED BY Approved By: COMMISSIONER THE COMMISSION Form 10-403 Revised 07/2005 L/ L/ '---- o~ Submit In Duplicate I ~\ R8DMS BFL MAR 2 9 ¡ , I G¡ ¡\lAL Z006 ~ e e GeR ......- tifFJltT l!rlIII1íOtJ.Jl3.J7 """ To: Winton Aubert - AOGCC Date: March 10, 2006 From: Shane Gagliardi - BPXA GPB Rotary Drilling Subject: Reference: AGI-07A Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-22343-00 Approval is requested for the proposed P&A of PBU well AGI-07. AGI-07 was drilled and completed in May, 1993. The completion was 7", 26#, NT-80 IPC NSCC tubing. The well was put on continuous injection at rates as high as 255 MMSCFD at 3550 psi. Operation had been problem free to date. AGI-07 was scheduled for mechanical integrity test - inner annulus (MIT-IA) for regulatory compliance on August 23,2005. The MIT-IA failed at .75 bpm at 1380 psi. On August 28,2005 the MIT- IA was repeated and again failed. A liquid leak rate (LLR) was established down the IA of 2.0 bpm at .,-/ 2200 psi. AGI-07 was SI and safed out with a tubing tail plug (TTP). The tubing was pressure tested against the TTP and passed to 3000 psi. A leak detect log (LDL) was run August 31, 2005 and confirmed a cretaceous leak in the 9-%" casing at 7650' md (6088' tvdss). The purpose of the sidetrack is to correct a Cretaceous intermediate casing leak and replace the existing solid, cemented and perforated liner with a slotted liner. The sidetrack is currently scheduled for Nabors 27E, beginning around April 15th 2006, after 27E is commissioned from storage. The pre-rig work for this sidetrack will begin at the Well's Group earliest convenience after sundry approval. ./ Current Condition: ./ Currently well is SI. ./ 9-%': 47#, NT-80-S intermediate set at 10,306' ./ 7': 29#, NT-80-S liner landed at 11,013'. ./ 9-%" x 5-];2" Baker SB-3A packer at 10,055'. ./ 5-1/2': 17#, L-80 IPC x 7': 26#, NT-80-S IPC Tubing with WLEG at 10,135'. ./ 6-%" CIW tree FMC Big Bore./ ./ MIT T to 3000 psi (PASSED). MY IA to 3000 psi (FAILED) at a LLR of 2.0 bpm @ 2200 psi. MIT OA to 2000 psi (PASSED) 8/25/05 ./ Set 51/2 XXN @ 10,095 SLM 8/28/05 ./ Leak detection log showed 9-%" casing leak at 7665' md 8/31/05 ./ PPPOT- T&IC Passed 9/14/05 Scope * Notify the field AOGCC representative with intent to plug and abandon * Pre-Rig Work: 1. Pull Tailpipe plug at 10,123'. 2. Run static pressure survey to determine BHP. 3. Bullhead fluid-pack.. the well to seawater or kill-weight fluid. R/U coiled tubing. RIH a~. lug and abandon the open perforations (328' from 10,630' - 10,958') with a minimum of 500' >2 bbls) of 15.8ppg class~·è7me.nt from PBTD. @ 10,992~ to approximately 1.5~' above top perfo '. tion. TOC expected @ 1 ,4 achieved by pumping approximately 20 bbls at minimum. 4. Pressure teste cement plug to 3,500 psi for 30 minutes. 5. Drift the 7" 26# L-80 tubing to -10,051' md, below the planned tubing cut depth of 10,000' md. 6. R/U SWS E-line. RIH with the appropriate chemical cutter and cut the 7" tubing at ± 10,000' md, in the middle of the full length tubing joint. 7. Circulate the well to seawater through the tubing cut, until returns are clean. AGI-07A Application for Sundry e e 8. Bleed casing and annulus pressures to zero. Freeze protect to -2,200' md with diesel. / 9. Function all tubing and casing Lock Down Screws. Set a BPV. Remove well house and flow line. r Level the pad as necessary. Rig Operations: 1. MIRU Nabors 27E. 2. Pull BPV. Circulate out diesel freeze protection an ad . ce the well to 8.~g brine. Install TWC. 3. Nipple down the tree. Nipple up and test BOPE to ,000 si. Pull TWC. 4. R/U. Pull the 7" tubing from the tubing cut at -10, md. 5. RU wireline and drift the 9-%" casing to 4,200' md. Set 9-%" bridge plug at 4200'. 6. RIH with multi-string cutter and cut the 9-%" casing 80' below the 13-%" casing shoe. Attempt to circulate through first cut. If unsuccessful, cut again at 40' above the casing shoe. Lay down cutter. 7. Spear the 9-%" casing at surface and recover top 3,900' of 9-%" casing. 8. MU spear and jars and recover bottom 120' cut stub. 9. MU 12- W' bit and 13-%" casing scraper. Clean out to top of 9-%" casing stub 10. RIH with mule shoe on drill pipe and lay balanced cement kickoff plug from 9-%" bridge plug to 200' ----' inside the 13-%" casing with 17 ppg cement. .....I ~ A"'t~· 12-%" drilling assembly and dress cement top to 3,950' md. MC;. 1° --v '2. Swap to 8.8 LSND drilling fluid. o..vyy(}l/""l. 13. Kick off and drill to top of Sag River drilling target, weighting up to 10.8 ppg by top of HRZ. CBU, POH 14. RIH with 9-%" long string and perform 2-stage cement job through shoe and a Halliburton EZSV stage tool @ 200' md below the top CM3. Top of second stage designed to reach 13-%" casing shoe. Bullhead freeze protect to 2,200' with diesel. 15. MU 8-W' drilling assembly. Test the casing to 4,000 psi. Drill out shoe tract and swap over to 8.5 ppg Flo-Pro SF. 16. Drill 20' of formation and perform FIT to 10.0 ppg. 17. Drill ahead, per directional proposal, through the reservoir section. 18. CBU, POH. Spot liner running pill. 19. Run 7" slotted production liner. RU wireline and run USIT in 9-%" casing from the shoe to 4,000' md. 20. Run 7-%" x 7" completion, stinging into the 7" liner tie back sleeve. 21. Space and land the completion. RILDS. 22. Install and test TWC. Nipple down the BOPE. 23. Nipple up the adapter and tree and test to 5,000 psi. Pull the TWC. 24. Circulate the annulus to seawater with Corrosion Inhibitor, followed by 134 bbls diesel. 25. RU U-tube line. Allow diesel to U-tube to the tubing side to provide 2,200' freeze protection. 26. Drop the ball/ rod. Set the packer and individually test the tubing to 4,000 psi and annulus to 3,800 psi for 30 minutes. Record each test. 27. Install a BPV. Secure the well. 28. Rig down and move off. Post-Ria ODerations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Re-install the well house, instrumentation, and flow line. 3. Perforate selected intervals. 4. Set SSSV. Timina: This sidetrack is scheduled for spud in mid April 2006. Estimated Pre-rig operations start date: Estimated Rig operations / spud date: Shane Gagliardi Operations Drilling Engineer 564-5251 03/27/06 04/20/06 AGI-07 A Application for Sundry JREE ~. " V'1ELLHEA~ = ACTUATOR = KB. ELEV = BF, ELEV = KOP = ~ax _~r~gle = Datum MO = Datum lVO = CIW BAKERC 49' e AGI-07 AFETY NOTES: LINER NOT CEMENTED. L TBG IS IPC WITH NSCC THREAD. 1600' ~9 @~~q15' 11506' 8800' SS 13-3/8" CSG, 68#, K-55, (TOP TWO JOINTS) 13-3/8" CSG, 68#, L-80, 10 = 12.415" I . 2186' -i 7" CAMCO BAL-O SSSV NIP, 10 = 5.937" I ??? 3936' Minimum ID = 4.455" @ 10123' 5-1/2" OTIS XN NIPPLE 17" TBG, 26#, NT-80-S-IPG, NSCC, .0383 bpf, 10 = 6.276"1 ITOP OF 5-1/2" 1BG 1 10051' -i 7" X 5-1/2" XO, 10 = 4.875" I TOP OF 7" LNR 1 10129' -iANCHOR, 10 = 4.875" 1 -i 9-5/8" X 5-1/2" BAKER SB-3A PKR, 10 = 4.874" 10102' -i 5-1/2" PARKER SWS NIP, 10 = 4.562" I 15-1/2" TBG, 17#, L-80-IPG, NSCC. .0232 bpf, 10 = 4.892" 1 19-5/8" CSG, 47#, NT-80-S, 10 = 8.681" 1 ÆRFORA TION SUMMARY REF LOG: MWO OPR ON 04/28/93 ANGLEATTOPÆRF: 49 @ 10630' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 3-3/8" 6 10630 - 10650 C 06/17/93 3-3/8" 6 10668 - 10678 C 06/17/93 3-3/8" 6 10764 - 10784 C 06/17/93 3-3/8" 6 10824 - 10844 C 06/17/93 3-3/8" 6 10858 - 10868 C 06/17/93 3-3/8" 6 10938 - 10958 C 06/17/93 10306' 1 7" LNR, 29#, NT-80-S, .0371 bpf , 10 = 6.184" H 11013' 11010' -i (2) SHEAROUT BALLS W/ROOS, 05/01/93 I 10992' 1 OA TE REV BY COMMENTS 05/03/93 ORIGINAL COM PLETION OS/22/01 RN/KAK CORRECTIONS 03/09/03 AS/TP ADD IPC/THREAO FOR TBG 05/12/03 JRClKK ADD 13-3/8", K-55 CSG 09/22/05 MOR/TL XN TIP SET (08/28/05) OA TE REV BY COMMENTS PRUDHOE BAY UNrr WELL: AG~07 ÆRMrr No: "1930270 API No: 50-029-22343-00 SEC36, T12N, R14E, 1271,69' FEL & 1056.95' FNL BP Exploration (Alaska) CIW BAKERC 49' AGi4b7 A Proposed ItAFETVNOTES' lREE!! " ELLHEAO - AClUA TOR - KB. ELEV = BF. ELEV - KOP = 1600' Max Angle - 50 @ 11015' Datum MD = 11506' Datum lVD - 8800' SS 13-3/8" CSG, 68#, K-55. (TOP mo JOINTS) 113-3/8" CSG, 68#, L-80, ID = 12.415" H ??1 3936' Minimum ID = 5.770" @ 9760' 7" HES RN NIPPLE I TOP OF 9 5/8" H 4025' 9 5/8" EZSV H 4200' / I Top of 7" H 10000' I ITOP OF 7" LNR I 10129' 19-5/8" CSG. 47#. NT-80-S, ID = 8.681" H 10306' I ÆRFORA TION SUMMARY REF LOG: MWD DPR ON 04/28/93 ANGLEATTOPÆRF: 49 @ 10630' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10630 - 10958 S 06/17/93 7" LNR, 29#, NT-80-S H 11013' DATE 05/03/93 11/01/05 REV BY COMMENTS ORIGINAL COM PLETION PGS Proposed Sidetrack DATE REV BY 2060' 2100' 2140' H 7 5/8" x 7" XO 1--17" CAMCO DB SSSV NIP. ID = 6,0" H 7" x 7 5/8" XO I 75/8" TBG, 29.7#, L-80-IPC, V AM Top HC, ID = 6.875" 6000' H 9 5/8" 47# L-80 TC-II 8175' l-i 95/8" TAM port collar 9730' H 7518" x 7" 26# TC-II XO 9770' H 7" R Nipple, ID - 5.963" 9 5/8" x 7" Baker SAB-L Pkr I 7" RN Nipple, ID = 5.770" 1 7" Liner hanger/Packer 7" WLEG 95/8" 47# L-80 BTC-M , \ \ \ \ \ \ \ ~-i I 10530' H 7" 29# L-80 Slotted PBTD 7" 29# TD COMMENTS PRUDHOE BA Y UNrr WELL: AGI-07A ÆRMrr No: 1930270 API No: 50-029-22343-01 SEC36. T12N. R14E, 1271.69' FEL & 1056.95' FNL BP Exploration (Alaska) STATUS: AGI-07 e . p;t> iL(q3_ 02-7 Subject: ST ArUS: AGI-07 From: "NSLJ, ADW Well Integrity Engineer" <I\SUADWWclllntcgrityEnginccr@BP.com> Date: Sat, 19 Nov 2005 21 :03:21 -0900 _ To: .lames Regg <jim _.rcgg@admin.statc.ak.us> Ke21l'~ Zz./~ CC: Winton G Aubert <winton aubert@admin.statc.ak.us>, "NSlJ, ADW Well Integrity Engineer" <:NSlJADWWclIrntegrityEngincer@BP.com>, "Luckett, Ely Z. (VECO)" <luckez@BP.com>, "H.o1t, Ryan P (VECO)" <Ryan.Holt@'BP.com>, "Mielke, Robert L." <roberl.mie1kc@BP.com>, "Dubc, Anna T" <Anna.Dubc@BP.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com>, "~SU, ADW Well Operations Supervisor" <NSLJADWWellOpcrationsSupcrvisor@RP.com>, "Rossbcrg, R Stevcn" <RossbeRS@BP.com>, "Engel, Harry R" <EngelHR@BP.com>, "Schmoyer, AI" <SchmoyAL@BP.com> Hi Jim. AGI-07 is currently SI due to a production casing leak at 7665', leak rate = 2 BPM @ 2200 psi. Current plans are to conduct a rig workover to either fix the PC leak or sidetrack the well above the leak point. Anna and I include wells on the monthly UIC report that either have Sundries/AA's or are in the process of being evaluated for an AA. We have not been including injectors shut-in for mechanical problems that are not being evaluated for an AA. We prefer to keep the monthly report focused on sundred/AA'ed wells. We'd be glad to work with you to prepare a separate report listing the status of long-term shut-in injectors, if desired. Please call with any questions. Joe 1-907-659-5102 -----Original Message----- ':'CANNED DEC 1 ® 2005 From: James Regg [~~;h~c::>_:j_~~ regg~admi~ßtate ~~:~§.] ~ Sent: Monday, October 24, 2005 11:02 AM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: Status of Injectors w/Failed MITs Need an updated status on the following wells. Also, these wells should be added to the monthly report you provide for injectors unless integrity concerns have been eliminated. PBU 9-25: according to last info we have (email 7/18/05), SI¡ plan was to take water sample for analysis¡ any change PBU 13-25: email dated 8/1/05 said this would be added to not showing up in last rpt we received¡ status? PBU 13-32A: email dated 8/4/05 said would do diagnostics¡ results? PBU AGI-07: reported failed MIT 8/25¡ well is not listed in montly rpt¡ status? PBU AGI-10: status? DIU 1-05/020: well was SI 9/18 after failing MIT¡ suspect packer leak¡ well is not listed in montly rpt¡ status? the well is in status? monthly rpt¡ reported failed MIT 8/25¡ well is not listed in montly rpt¡ Jim Regg AOGCC 1 of! 11/22/2005 8:52 AM ~.( (¡ . \ ~ .fi.T\ ~ !~.' \~_ \. ii, l)'ï \~ i Ii!) ,'\ I: .:! I, \\ !' I ~ " \ :" ~ ,r i I 1,,1 "ilF;\\:1 Ir~ ~..' tU ,J~lIU W l~ l-:;:;:-""~ ¡--E ! I . I) ì I . I , l ! ! : , I ' i) , ;:J.'.' ii í: iÛ' \:::!) 1: ) ¡ \ í-: 'r:\~ .,--¡, /fi \. 'I. .I¡ ~. I, Ii 0.JJ (~\\'\ I i II ill! '. ~,,\'\ ,i ..µ \~. !! . / iJ '~" ,"'<')'." :/iÎ1, il: Jiïl'~ inJ I iU \)... ~W 'W ",-" ) AIASIiA OIL AlVD GAS CONSERVATION COltDlISSION ¡ I FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 tt- f." f~ lr\'iA 1He: ~ " ~.\. CD') -¡ ') n [P:.ir ",.) ~,,~' 1/ "u ,R ~3 0...;.. L.., .J L I' t" .iL L ~" '. Re: PBv AGI-07 Sundry Number: 305-273 lq3 --- O~ Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, /Î I·, //1 /. Á"/ e¥1 /~-jØä:jf£Yl ; y .. John K. Norman Chairman l/ft- DATED this-LJQ. day of September, 2005 Encl. v:..¡ (,i\- ~ ¡t(¡ /2..-C'oç ( STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAt- 20 MC 25.280 "'"""'.,' ;\. ,j' SEP 1 4 2005 1'''''''''',.- 1. Type of Request: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Other o Alter Casing / II Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: o Development 0 Exploratory o Stratigraphic IBI Service / 5. Permit To Drill Number 193-027 .....r 6. API Number: ,,/ 50- 029-22343-00-00 99519-6612 49' 9. Well Name and Number: AGI-07 / 8. Property Designation: ADL 034628 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITIÖN $UMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10992 8459 None :Surst, Junk (measured): 10992 ,Collapse 11. Total Depth MD (ft): 11015 Casing Structural Conductor Surface Intermedia~e Production Liner Total Depth TVD (ft): 8474' Length 76' 20" 106' 106' 1490 470 3903' 13-3/8" 3937' 3502' 3450 1950 10271' 9-5/8" 10306' 8017' 6870 4760 883' 7" 10130' - 11013' 7903' - 8472' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 10630' - 109581 8226' - 8437' 7",26# x 5-1/2", 17# Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'SB-3A' packer; 7" Cameo 'BAl-O' SSSV Nipple Tubing Grade: Tubing MD (ft): NT80/ L-80 10135' Packers and SSSV MD (ft): 10055'; 2186' 12. Attachments: IBI Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: ,/ o Exploratory 0 Development IBI Service 16. Verbal Approval: Commission Representative: 17. I hereby certif that the foregoing is true and correct to the best of my knowledge. Printed Na David Reem Title Drilling Engineer (1~~ September 29,2005 ./ Date: 15. Well Status after proposed work: o Oil 0 Gas / 0 Plugged o WAG IBI GINJ 0 WINJ o Abandoned o WDSPl Contact David Reem, 564-5743 Signature Phone 564-5743 Commission Use Only Date ,r w/ "I-()S I Sundry Number~~5"" /l7L 1 Prepared By Name/Number: Terrie Hubble, 564-4628 , Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ü!I"Bop Test 61Mechanicallntegrity Test 0 location Clearance Other: Ie <..+ E,o P E- +ò 4000 p! ¡ , /lll L-T r<¡tM.t-lJ. RBDMS 8Fl SEP 162005 Subsequent Form Required: lO -- 4-.0 4- . Approved BY:~~ - ~~ COMMISSIONER Fonn 10-403 ReviS~ ~~þ04 0 RIG \ N A L APPROVED BY THE COMMISSION Date~ -/6 - t2.s-' Submit In Duplicate ~ ( ..----\ Well Status: Shut-in gas injector. Well has a confirme~'ín the 9-5/8" intermediate casing at -7650'md. Well is secured with a tubing tail prog. / Project: Retrieve existing 7", 26#, NT -80 IPC NSCC completion, mill & recover packer and tail-pipe. Fully cement in place a 7", 26#/ft, L-80 BTC-M scab liner with liner top at /' -7100'md. Re-complete with 7.625", 29.7#/ft, L-80 IPC Yam Top HC tubing with WLEG stung into scab liner-top tie-back receptacle. Provide AOGCC field inspectors 24-hr notices as required to witness BOP tests and MITIA post packer setting. /~ 1. MIRU 4ES or Doyon 16. Pull BPVs, set and test TWC in 7" tubing hanger. ND tree and adapter flange. NU BOPE. Test annular to 250 psi (low)/3500 psi (high), remaining BOPE to 250 psi (low)/4000 psi (high) per BP and AOGCC regulations. /' 2. Fully circulate thru the pre-RWO jet cut with heated seawater. /' 3. Pull 7", 26#/ft, NT-80 NSCC down to the jet cut just above the packer. 4. Mill and recover the 7" x 9-5/8" SB-3A packer. ,.<"" 5. Run 8-1/8" bit and 9-5/8" casing scraper and clean wellbore to top of 7" liner at / 10129'. 6. RU e-line and log 9-5/8" with USIT from 10129' in both cement evaluation mode and corrosion mode. Log up to -3900'md. 7. Run 7", 26#/ft, L-80 BTC-M scab liner from top of 7" x 9.625" liner top . packer/hanger at 10129'md up to -7000'md**. Fully cement liner in place. /' 8. PT liner/casing to 4000 psi for 30-min (charted). Drill out shoe-track. CBU with hi- vis sweeps to clean up weUbore. 9. Run new 7.625", 29.7#/ft, L-80 IPC Yam Top HC completion with WLEG stung /' into liner top packer's tie-back receptacle. Set and test packer to 4000 psi (tubing and inner annulus). 10. RDMO 4ES. 11. Tie well in and place on gas injection. MITIA with AOGCC witness once well is on ,./ injection and stabilized. ** The results of the USIT log will dictate the depth of the scab liner's top. The liner top could go as high as -3900'md. -7000'md is the deepest the 7" scab liner top is planned for. / (' 1REE = WELLHEAD = ACTUATOR = 'KB. ELEV = BF. ELEV = KOP = Max Angle = Datum MD = Datum lVD = CW BAKERC 49' 1600' 50 @ 11015" 11 506' 8800' SS 13-3/8" CSG, 68#, K-55, -1 (TOP TWO JOINTS) 113-3/8" CSG, 68#. L-80, ID = 12.415" H ??? 3936' Minimum ID = 4.455" @ 10123' 5-1/2" OTIS XN NIPPLE AGI-07 / ^..........,..:... ~ ~ 17" lBG, 26#, NT-80-S-IPC, NSCC, ,0383 bpf, ID = 6,276"H 1 0051' t- \ / TOP OF 5-1/2" lBG 1-1 10051' ITOP OF 7" LNR l-i 10129' I z ~ ( SAFETY NOTES: LINER NOTCEMENTB:>. ALL TBG IS IPC W rrH NSCC THREAD. 2186' H 7" CAMCO BAL-Q SSSV NP, ID = 5.937" I ~ I 10051' H 7" X 5-1/2" XO, ID = 4,875" 1 10054' I-iANCHOR, ID=4.875" 1 10055' 1--i9-5/8" x 5-1/2" BAKER SB-3A PKR, ID= 4.874" . . 1 10102' 1-15-1/2" PARKER SWS NIP, ID = 4,562" 1 . . 1 10123' 1-15-1/2" OllS XN NO-GO NIP, ID = 4.455" 1 . . 15-1/2" lBG, 17#, L-80-IPC, NSCC, .0232 bpf, ID = 4.892" 1-1 10135' ~----I 19-5/8" CSG, 47#, NT-80-S, ID = 8.681" 1-1 10306' PERFORAllON SUMMARY REF LOG: MWD DPR ON 04/28/93 ANGLE AT TOP PERF: 49 @ 10630' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10630 - 10650 0 6/17/93 3-318" 6 10668 - 10678 0 6/17/93 3-3/8" 6 10764 - 10784 0 6/17/93 3-3/8" 6 10824 - 10844 0 6/17/93 3-3/8" 6 10858 - 10868 0 6/17/93 3-3/8" 6 10938 - 10958 0 6/17/93 17" LNR, 29#, NT-80-S, .0371 bpf , ID = 6.184" 1-1 11013' I DATE 05/03/93 01/29/01 OS/22/01 03/09/03 05/12/03 REV BY COMMENTS ORIGINAL OOMA..EllON SIS-MD FNAL RN/KAK OORRECTIONS AS/TP ADD IPCfTHREAD FOR TBG JRC/KK ADD 13-3/8", K-55 CSG DATE .. ~ J I 10135' 1-15-1/2"WLEG. ID= 4,892" I 10138' l-t ELMD IT LOGGED 06/08/93 ,- 11010' H(2) SHEA ROUT BALLS W/RODS, 05/01/93 1 ~ 10992' I ~ REV BY COMMENTS PRUDHOE BAY UNIT WELL: AGI-07 PERMIT f\b: 1930270 AR f\b: 50-029-22343-00 SEC 36, T12N, R14E, 1271,69' F8.. & 1056.95' FNL BP Exploration (Alas ka) ,TREE.= . WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP = Max Angle = Datum MD = Datum lVD = CIW BAKERC 49' AGI-07 Proposed ~ 1600' 50 @ 11015' 11506' 8800' SS 13-3/8" CSG. 68#, K-55, -i (TOP TWO JOINTS) \13-3/8" CSG, 68#, L-80, ID = 12.415" l-i ??? 3936' / L7.625" TBG, 29.7#, L-80 IPC VamTop HC j l-i -6900' 1- 17" x 9.625" ZXP Liner Top Packer/Hanger 1-1 -7000' 1 7", 26#/ft, L-BO BTC-M scab liner Fully cemented with liner top .....500' above PC leak depth. Bottom of scab liner stung into existing 7" liner's tie-back receptacle. ITOP OF 7" LNR 1-1 10129' I 19-5/8" CSG, 47#, NT-80-S, ID = 8.681" 1--1 10306' PERFORATION SUMMARY REF LOG: MWD DPR ON 04/28/93 ANGLE AT TOP PERF: 49 @ 10630' Note: Refer to Production DB for historical perf data SIZE SPF IN1ERVAL Opn/Sqz DA1E 3-3/8" 6 10630 - 10650 0 6/17/93 3-3/8" 6 10668 - 10678 0 6/17/93 3-3/8" 6 10764 - 10784 0 6/17/93 3-3/8" 6 10824 - 10844 0 6/17/93 3-3/8" 6 10858 - 10868 0 6/17/93 3-3/8" 6 10938 - 10958 0 6/17/93 I 7" LNR, 29#, NT-80-S, ,0371 bpf , ID = 6.184" l-i 11013' I DATE 05/03/93 01/29/01 OS/22/01 03/09/03 05/12/03 REV BY COMMENTS ORIGINAL COMPLETION SIS-MD FINAL RN/KAK CORRECTIONS A S/TP ADD IPC/THREA D FOR TBG JRC/KK ADD 13-3/8", K-55 CSG DATE I . 1--17" CAMCO DB-6 NIP, ID = 6.00" 2100' ~ ~ (-I ~ REV BY -6950' 1-19.625" x 7" Baker "S-3" Perm Packer PC leak logged at -7650'md ,,/ ~ I I 1 -,- I 11010' 1--1(2)SHEAROUTBALLSW/RODS, 05/01/93 1 ~- 10992' I COMMENTS PRUDHOE BA Y UNrT WELL: AGI-07 PERMrr No: 1930270 API No: 50-029-22343-00 SEC 36, T12N, R14E, 1271.69' FEL & 1056.95' FNL BP Exploration (Alaska) MEMORANDUM ':( ( ~, State of Alaska Alaska Oil and Gas Conservation Commission TO: DA TE: Tuesday, August 30, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLOR,\ nON (ALASKA) rNC AGI-07 PRUDHOE BAY UNIT AGI-07 Jim Regg -0 C(.,I P.I. Supervisor . f-.¡l1c¡ (I 3¡O<; FROM: John Crisp Petroleum Inspector Src: Inspector NON-CONFIDENTIAL " \~~ o 'd-'\ Reviewed By: P.I. Suprv :Jߣ-- Comm Well Name: PRUDHOE SAY UNIT AGI-07 Insp N um: mitJCr050825 130236 Rei Insp Num API Well Number 50-029-22343-00-00 Permit Number: 193-027-0 Inspector Name: John Crisp Inspection Date: 8/23/2005 Packer Depth G ;1' TVD_,~. 7854 - I IA SPT: Test psi i 1963.5 I O-¡-I L.._, ~ --...--- ---- - .---- T~ï;i;g I 15 Min. 30 Min. 45 Min. 60 Min. 1500 370! -------- 1---- . ._.1. ..----.......- 175 i ¡--."...---- _...--1.___._____ Pretest Initial Well ! AGI-07 IType Inj. __~_:!: _ __rl-93027õ---rTypeTe~___ Interval__~~!.ST .. ____.~(F 370 2140 125 175 3500 3500 Notes Total of 8 bbls pumped for test. Failure of approx, 1 bbl per minute. ~ \' ,.l;. Ntn tee 9(0105 j ') 1 LrvtlL -:~CLU'1?t 01 TTP pØ\/1 deè-l bßP>4\ ",', {. n p¡;:~ ~?: J .))1.1", Tuesday, August 30, 2005 175 3550 3550 6k:?iT (,î/, ~C,.) I Page 1 of 1 AGI-07 Failed MITIA (PTD 1930270) e · / '0¡1 ~!3P¡,s- Sub.icct: ACìI-07 Failcd MITIA (.";."93Ql~, From: "Anders, Joc L" <andcrs22(("l!.BP.com> Date: Thu, 25 Aug 2005 15: 15 :07 -0800 To: j imJcgg@admin.statc.ak.us, winton_aubcI1@admin.statc.ak.us, aogcc__prudhoc_.bay@;admin.state.ak.us, "Rossbcrg, R Steven" <RossbcRS@BP.com>, "NSU, ADW Well Opcrations Supervisor" <NSUADWWcllOpcrationsSupcrvisor@.BP.com>, "NSU, ADW WL & Completion Supervisor" <NSLJADW\VL&ComplctionSupcrvisor@BP.com>, "GPB, FSl DS Ops Lcad" <GPBFS 1 DSOpsLeadCt:i?BP.com>, "GPB, FS 1 /SlP/STP Area Mgr" <GPBFS 1 TL@BP.com>, "Schmoyer, AI" <SehmoyAL@BP.com>, "GPB, Prod Opt TL" <GPBProdOptTL@BP.com>, "GPB, Optimization Engr" <GPBOptimizatiollEngr@BP.com>, "GPB, Wells Opt Eng" <GPBWcllsOptEng@BP.com>, EngeIHR@BP.com, "Bill, Michael L (Natchiq)" <M iehael.Bi II@BP.com> CC: "NSlJ, ADW Well Integrity Engineer" <NSUAD\VWelUntegrityEnginccr@BP.com>, "Luckett, Ely Z. (VECO)" <Iuckcz@mp.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com>. "Reeves, Donald .F" <RcevcsDf@BP.com> All: Well AGI-07 (PTD 1930270) failed an MITIA on 8/23/05. The IA was pressured to 2140 psi when the pressure was observed to suddenly decrease. Subsequently an injection rate of .75 BPM @ 1380 psi was established. The well is currently on injection. Current plans are as follows: 1. FB: Load tubing, freeze protect 2. SL: Set TTP 3. DHD: Bleed WHP's to <300 psi 4. FB: MIT-T to 3000 psi, MIT-IA to 3000 psi, MITOA to 2000 psi. LLR & CMIT any failures. If sufficient rate: 5. EL: LDL 6. WIE/APE: Eval repair vs. AA Attached is a wellbore schematic and TIO Plot. Please call if you have any questions. «AGI-07.pdf» «AGI-07 TIO Plot.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com ~ÇANNED Nmf 0 9 2005 Content-Description: AGI-07.pdf Content-Type: application/octet-stream Content-Encoding: base64 AGI-07 TIO Plot.jpg Content-Description: AGI-07 TIO Plot.jpg lof2 8/30/2005 9:39 AM AGI-07 Failed MITIA (PTD 1930270) 20f2 e Content-Type: Content-Encoding: e image/jpeg base64 8/30/2005 9:39 AM 1REE = WELLHEAD - CrN AcrUATOR - BAKERC KB. ELEV = 49' BF. ELEV- KOP - 1600' Max Angle - 50 @ 11015' Datum MD - 11 506' Datum lVD = 8800' SS 13-3/8" CSG, 68#, K-55, -1 ??? (TOPTVVO JOINTS) 13-3/8" CSG, 68#, L-80, ID = 12.415" 3936' Minimum ID = 4.455" @ 10123' 5-1/2" OTIS XN NIPPLE 17" 1BG, 26#, NT-80-S-IPG, NSCC, .0383 bpf, ID - 6.276"1 TOP OF 5-1/2" lBG 1 TOP OF 7" LNR I 10129' 5-112" lBG, 17#, L-80-IPG, NSCC, .0232 bpf, ID= 4.892" I 9-518" CSG, 47#, NT-80-S, ID - 8.681" 1 0306' PERFORA110N SUMMARY REF LOG: MWD DPR ON 04/28/93 ANGLE AT TOP PERF: 49 @ 10630' Note: Refer to Production DB for historical perfdata SIZE SPF INTERVAL n/S )ð,TE 3-318" 6 10630 - 10650 0 6/17/93 3-318" 6 10668 - 10678 0 6/17/93 3-318" 6 10764 - 10784 0 6/17/93 3-318" 6 10824 - 10644 0 6/17/93 3-318" 6 10858 - 10888 0 6/17/93 3-318" 6 10938 - 10958 0 6/17/93 17" LNR, 29#, NT -80-S, .0371 bpf , ID = 6.184" H 11013' 1 DATE 05/03/93 01/29/01 OS/22/01 03/09/03 05/12/03 REV BY COMJl.fENìS ORIGINAL COMA-ErION SIS-MD FNA L RN/KAK CORREcrlONS ASlTP ADDIPCrrHREAD FORTBG JRClKK ADD 13-3/8", K-55 CSG DATE AGI-07 . REV BY COMJl.fENTS SAFETY N01ES: LINER NOT C8\II ENTED. All. TBG IS IPC W ITH NSCC THREAD. 2186' 7" CAMCO BAL-O SSSV NP, ID = 5.937" 1 0051 ' 7" X 5-112" XO, ID = 4.875" -1 ANCHOR, ID=4.875" 1 9-518" X 5-112" BAKER SB-3A PKR, ID - 4.874" 10102' 5-1/2" PARKER fNVS NIp, ID - 4.562" 10123' 5-1/2" 011S XN NO-GO NIP, ID = 4.455" 5-1/2" WLEG, ID = 4.892" H EUvD TT LOGGED 06108/93 (2) SHE;AROUT BALLS W/RODS, 05101/93 PRUDI-OE BAY UNIT WELL: AGI-07 PERMIf N:>: 1930270 AA N:>: 50-029-22343-00 SEC36, T12N, R14E, 1271.69' FB. & 1056.95' FNL BP Exploration (Alaska) AGI-07 TIO Plot.jpg (JPEG Image, 923x289 pixels) 4.000 1 of 1 +Tbg 8/30/2005 9:42 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~\q/~v- DATE: May 27, 2001 Commissioner SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder BPX P.I. SupervisorL/~ ' AGI Pad AG 1-06, 07, 08, 09, 10 FROM: Jeff Jones PBU Petroleum Inspector PBF NON- CONFIDENTIAL P.T.D. Notes: '. Well P.T.D. Notes: Well , P.T-D.I Notes: Well P:T.D. Packer Depth Pretest Initial 15 Min. 30 Min. AGI'06 J Typelnj. J G' J T.V.D. J 7880 J Tubing J3500 J3500 J3500 J3500 J lntervalJ 4 Type testI P j TestpsiI 1970 ICaSingJ 800 I 2100l 21°° I' 2090 J P/FI P 193-009 AG,.07 J Typ~,,j.J G J T.V.D. J78,0 J T.bingJ3,00 I ~,00 I ~,00 I~,00 J,.~erv.,J 4 193-027 'TypetestJ ' P JTestpsiJ .1960 JCasingJ 85O I 2130J 2130J 2130' J P/F I P AGI,08 J Typeinj. J G I T.V.D. I Tubingl~00 J lntervalJ 4 193-033 JTypetestJ P JTestpsiJ 1965 JCasingJ 89o I 212° J 2120 J' 2110J P/F J P I T,,.,,j.I I T.V.O. I Tu ,n J,nte va,I4 193-035 JTyPetestJ P JTestpsiJ 1972 JCasingJ 1120 1,2100I 2100I 2100I P/F I R Notes: we,Ii AGI,10 J Typelnj. J G J T.V.D. 17824 I Tubing J 3600 J 36'00 J 3600 J3600 J lntervalJ 4 P.T.D.J 193'039 JTypetestJ P JTeStpsiJ'1956 jcasingj 700 I 21001 20801 2080 J 'PIE I P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Sunday, May 27, 2001: I traveled to BPX's AGI Pad to witness 4 year MIT's on gas injection wells AGI-06, 07, 08, 09, and 10. The pre-test pressures were observed to be stable and the standard annulus pressure test was then performed with all five wells passing the MIT's. The test data above indicates these wells are suitable for continued injection. Sumtna~: I witnessed five successful MIT's on BPX's AGI Pad in the Prudhoe Bay Field. M.I.T.'s performed: _5 Number of Failures: _0 Total Time during tests: 3 hrs. Attachments: cc: .... MIT report form 5/12/00 L.G. MIT PBU AGI-06,07,08,09,10 5-27-01 JJ 6/9/01 ON OR BEFORE W PERMIT 93-027 5868 ..93-e-2-7~ --5905 ~ ~._.- 02 ? "~OGCC Individual Well Geological Materials Inventory DATA T DATA_PLUS C'T/8303-11014, OH/MWD LL ~:,. COMP DATE: 06/09/93 DAILY WELL OP &~R 02/15/93-05/01/93 93-027 407 93-027 93-027 SURVEY 93-027 SURVEY 93-027 SURVEY 93-027 SURVEY 93-027 COMP 93-027 DPR/GR 93-027 DPR/GR 93-027 GR/CCL 93-027 PERF 93-027 SBL/GR/CCL ~R~ SS DIRECTIONAL ~ MWD DIRECTIONAL ,'~R MWD DIRECTIONAL ~' MWD DIRECTIONAL ~T~RUN 1, 5" L'L RUNS 6&7,2&5"MD RUNS 6&7,2&5"TVD RUN 1, 5" RUN 1, 5" ~L~- CH, R1,5'' Page' 1 Date: 04/11/95 RUN DATE_RECVD 6&7 6&7 10/29/1993 11/30/-t993 .... 08/26/1993 08/26/1993 08/26/1993 08/31/1993 08/31/1993 09/13/1993 07/30/1993 07/30/1993 07/30/1993 07/30/1993 07/30/1993 05/06/1993 Are dry ditch samples required? Was the well cored? yes ~alysis & description/~eived? r equired?~ yes~___~i~-Received? Are well tests Well is in compliance Initial COMMENTS yes ,_~..., And received~_~'~s no yes no ANNULAR INJECTION DATA ENTRY SCREEN Asset AG[ ............................................ Rig Name ..................................................... Inj Well Name ~G~"7'%"i~ .................................. Permit Sur Csg Dap ........................... Cumulative Data Start ....... 1./..1./.,9.;~ ...... Permit E n d .....1.21.3..1. J..9.3.... Legal Desc PP92.'.E.S.L.,..25.1~:EEL,..S~.c..,3J~,...~'.~.21~...B.:t..4E. ..................... Research ........................................................................................................................ C=r~act. ed..C=~¥..=P,,aL.t~z..AD~CC...3¢..1.7.¢.9.7.. .............. Daily Data AGI 9 287 AGI-8 252 AGI-10 356 1993 Year End Summary I 3ril 25 throu( 1993 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-22-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS 4-17-93 10-7-93 ca 3-31-93 11/18-3o/92 11-23-92 4-15-93 1-29-93 2-13-93 4-28-93 3-6-93 5-8-93 3-28-93 MWD: DPR/GR DI /AC/C /GR MWD: DPR/GR MWD '?Tl~-~tq'~O MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR. MWD: DPR/GR MWD: DPR/GR r MWD: DPR/GR Job#1209 Job#6055 Job# 1202 Job#AEMM921128 Job#1152 Job# 1168-450 Job# 1172-450 Job#1181 Job# 1185-450 Job# 1190 Job# 1195-450 Job# 1205-450 Sperry HHX %b-o~-Itov4 Please sign and return the attached copy as receipt of data. /.~ RECEIVED BY__ . OCF 2 9 1995 Have A Nice Day! /~/ ~k~ 0i/ Sonya Wallace APPROVED_J/~ ATO-1529 Trans# 9312~~- . # PHILLIPS # BOB OCANAS (OH/GCT) # EXXON # BPX # STATE OF ALASKA ., The correct API# for 3-18A is 50-029-20421-01. The correct APl# for 9-28A is 50-029-21292-01. The correct APl# for AGI-1 is 50-029-22307-00. ARCO 2~l--k-; Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 9-10-93 REFERENCE: ARCO DIRECTIONAL DATA c{~_ ~a 3-18A 4-24-93 Electronic Multi-Shot Survey Job~30023 Sperry c{~_ ~-/ 3-20A 4-14-93 Electronic Multi-Shot Survey Job~2 Sperry c~%-t~ 5-3A 5-26-93 MWD Directional Survey Ana ~~ 5-14A 626-93 MWD Directional Survey Aha c/%~q-~ 5-15A 6-26-93 MWD Directional Survey Ana c~-5'~ 6-22A 4-304)3 MWD Directional Survey Aha c/~. q0 18-29A 4-26-93 MWD Directional Survey Ana q~- {~5 AGI-3 4-14-93 MWD Directional Survey Job~1163 BHI c~9.- |~ AGI4 4-14-93 MWD Directional Survey Job~1168 BHI o~-9_7 AGI-7 4-28-93 MWD Directional Survey Job~ 1185 Teleco /AGI-9 3-17-93 MWD Directional Survey Job#1195-450 BHI c{~ ~5 ~,AGI-9 5-8-93 MWD Directional Survey Job~ 1195-450 BHI Please sign and return tl~e attached copy as receipt of data~ RECEIVED BY _~Z~~~ ..... Have A Nice Day! _ \ ~.e,~,~.. '-'/~,~ ' -~/ ATO- 1529 ~/~ CENTRAL FILF~ CHEVRON D&M # CLINT CHAPM,~'q # EXXON M,~A~,ATHON MOBIL # PB WELL FILES R&D #BPX .# ST. OF,~I~- (2 COPIES) TEXACO # LUCKJ,E JOHNSTON ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-10-93 REFERENCE: ARCO DIRECTIONAL DATA 12-20-92 2-25-93 2-27-93 4-19-93 4-9-93 3-19-93 3-23-93 4-18-93 2-23-93 2-26-93 3-7-93 3-13-93 4-6-93 4-15-93 3-7-93 4-1-93 12/6-23/92 1/23-2/6/93 MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MW]) Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MW]) Directional Survey 12/30-1/15/93 MWD Directional Survey 12-9-91 MWD Directional Survey 1-15-92 MWD 1/92 MW~ 2-9-93 MWD 1-16-93 MWD 12-27-92 MWD 1-18-93 MWD 1-17-93 MWD 2-16-93 MWD 2-24-93 MWD 4-28-93 MWD 3-7-93 MWD 3-17-93 MWD 3-30-93 MWD Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Job#AKEI30010 Sperry Job#1209 BHI Ana Ana Job#AKEI30016 Sperry Job#AKMW30020 Sperry Job# 1188 Teleco Job#AKEI30009 Sperry Job# 1192 Teleco Job#AKEI30012 Sperry Job#1202 BHI Ana Ana Ana Job# 1159 Teleco Job#1175 Teleco Job# 1167 Teleco Job#AKMM911128 Sperry Job#AKMM911231 Sperry Sperry Ana Job#AKMW30003 Sperry Job#AKMM921231 Sperry Job#1168 Teleco Job# 1172 Teleco Teleco Job# 1185-450 Teleco Job# 1185 Teleco Job# 1190 Teleco Job # 1195-450 Teleco Job#1205 BHI Please sign and return the attached copy as receipt of data. .ECEIVE, Have A Nice Day! Sonya W~_119ce ATO- 1529 CHEVRON # CLINT CHAPMAN # EXXON MOBIL Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Group ORI tNAL Well Name Date Surveyed Survey Performed By : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : : April 28, 1993 : : Don Lentz This survey is correct to the best of my knowledge and is supported by actual field data. ........................... COMPANY REPRESENTATIVE Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : Date April 28, 1993 Filename : l185ETAK No Interpolation Plane of Vertical Section : 73.2° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE · Magnetic Declination :+30.15°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-7 +0° 0' 0' ' (T) Eastman Teleco Client Well Name : Prudhoe Bay Drilling Group : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : Page 1 of 2 Date April 28, 1993 Filename : l185ETAK No Interpolation MD CkL INC DIR TVD VS LAT DEP ft ft deg deg ft ft ft ft 0 0 0.0 0.0 0 0 0 0 422 422 0.1 124.4 422 0 -0 0 601 179 1.3 76.9 601 2 0 2 782 181 4.5 65.3 782 11 4 11 969 187 6.4 72.0 968 29 10 27 D' LEG °/100 0.0 0.0 0.7 1.8 1.1 BUILD °/lOO 0.0 0.0 0.7 1.8 1.O TURN o / 100 0.0 29.5 -26.5 -6.4 3.6 1156 1343 1532 1719 1907 187 7.7 72.3 1153 187 7.7 69.9 1339 189 9.8 71.6 1526 187 11.4 74.1 1709 188 17.4 72.7 1891 52 77 106 140 187 17 49 0.7 0.7 0.2 25 73 0.2 0.0 -1.3 34 100 1.1 1.1 0.9 45 133 0.9 0.9 1.3 58 178 3 . 2 3 · 2 -0 · 7 2089 2281 2468 2655 2842 182 22.9 70.6 2062 192 25.8 70.2 2237 187 30.2 70.9 2402 187 36.0 72.7 2559 187 38.1 70.2 2708 250 78 237 3.0 3.0 -1.2 329 104 312 1.5 1.5 -0.2 416 134 395 2.4 2.4 0.4 518 165 492 3.1 3.1 1.0 631 201 598 1.4 1.1 -1.3 3029 3214 3402 3588 3777 187 41.5 71.6 2852 185 45.8 75.2 2985 188 45.7 73.4 3117 186 44.7 70.9 3248 189 45.0 69.5 3382 751 240 711 1.9 1.8 0.7 878 277 834 2.7 2.3 1.9 1013 3.13 963 0.7 -0.1 -1.0 1145 354 1089 1.1 -0.5 -1.3 1278 399 1214 0.5 0.2 -0.7 3880 4148 4430 4712 4993 103 45.2 70.9 3454 268 44.4 70.2 3645 282 44.2 70.2 3846 282 43.4 71.6 4050 281 43.8 71.3 4253 1351 423 1283 1.0 0.2 1.4 1539 486 1461 0.4 -0.3 -0.3 1736 553 1646 0.1 -0.1 0.0 1931 617 1831 0.4 -0.3 0.5 2125 679 2015 0.2 0.1 -0.1 5274 5555 5836 6118 6398 281_ 45.3 70.2 4454 281 45.2 71.3 4652 281 44.5 72.7 4851 282 44.6 72.7 5052 280 44.9 74.5 5251 2322 744 2201 0.6 0.5 -0.4 2521 809 2389 0.3 -0.0 0.4 2719 871 2578 0.4 -0.2 0.5 2917 929 2766 0.0 0.0 0.© 3114 985 2955 0.5 0.1 0.6 6679 6964 7240 7521 7803 281 45.5 72.0 5449 285 45.4 73.8 5649 276 46.7 74.1 5840 281 45.6 74.1 6035 282 45.0 72.3 6233 3313 1043 3146 0.7 0.2 -0.9 3517 1102 3340 0 · 5 -0 · 0 0.6 3715 1157 3531 0.5 0.5 0.1 3918 1213 3726 0.4 -0.4 0.0 4118 1271 3918 0.5 -0 · 2 -0.6 8085 8366 8646 8928 9211 282 43.2 70.9 6436 281 40.8 73.8 6644 280 42.2 72.3 6854 282 43.6 73.8 7061 283 45.0 73.8 7263 4314 1333 4104 0.7 -0.6 -0.5 4502 1390 4284 1.1 -0.9 1.0 4688 1444 4461 0.6 0.5 -0.5 4880 1500 4645 0.6 0.5 0.5 5077 1555 4834 0.5 0.5 0.0 Client Well Name Eastman Teleco : Prudhoe Bay Drilling Group : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : MD CkL INC DIR TVD VS ft ft deg deg ft ft 9489 278 46.3 73.8 7458 5276 9768 279 47.5 72.7 7648 5480 10053 285 49.0 73.4 7838 5693 10263 210 49.9 73.1 7975 5852 10459 196 50.1 74.1 8101 6002 10645 186 49.6 72.7 8220 10832 187 50.4 70.2 8341 10980 148 50.4 69.9 8435 6144 6288 6401 Page 2 of 2 Date April 28, 1993 Filename · l1851ETAK No Interpolation LAT DEP D'LEG BUILD ft ft °/100 °/100 1610 5025 0.5 0.5 1669 5220 0.5 0.4 1731 5424 0.6 0.!5 1777 5577 0.4 0.4 1819 5721 0.4 0.1 TURN o/100 0.0 -0.4 0.2 -0.1 0.5 1860 5857 0.6 -0.3 -0.8 1906 5993 1.1 0.4 -1.3 1944 6100 0.2 0.0 -0.2 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 6402 ft 72.3° Baker Hughes INTEQ Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Date Surveyed Survey Performed By : Apex Gas InjeCtion 7 : Apex Gas Injection Pad : North Slope, Alaska : : April 28, 1993 : : Don Lentz This survey is correct to the best of my knowledge and is supported by actual field data. ............................ COMPANY REPRESENTATIVE Baker Hughes INTEQ Client : Prudhoe Bay Drilling Group Well Name : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : Date April 28, 1993 Filename : l185ETAK Interpolated 100 ft of TYD Plane of Vertical Section : 73.2° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep O.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.15°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-7 +0° 0' 0' ' (T) Client Well Name Baker Hughes INTEQ : Prudhoe Bay Drilling Group : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : Page 1 of 3 Date April 28, 1993 Filename : l185ETAK Interpolated 100 ft of TVD MD CkL INC DIR TVD ft ft deg deg ft 0 0 0.0 0.0 0 100 100 0.0 29.5 100 200 100 0.0 59.0 200 300 100 0.1 88.4 300 400 100 0.1 117.9 400 5OO 6OO 700 80O 901 1001 1102 1203 1304 1405 1506 1608 1709 1813 1916 2023 2131 2240 2352 2466 2585 2707 2832 2962 3096 3235 3378 3520 3662 3803 3944 4085 4225 4365 4504 100 0.6 103.7 500 100 1.3 77.2 600 100 3.1 70.5 700 100 4.7 66.0 800 100 5.7 69.6 900 101 6.6 72.1 1000 101 7 . 3 72 . 2 1100 101 7.7 71.7 1200 101 7.7 70.4 1300 101 8.4 70.5 1400 101 9.5 71.4 1500 102 10.4 72.6 1600 102 11.3 74.0 1700 103 14.4 73.4 1800 104 17.7 72.6 1900 107 20.9 71.4 2000 108 23.5 70.5 2100 110 25.2 70.3 2200 112 27.5 70.5 2300 113 30.1 70.9 2400 119 33.8 72.0 2500 122 36.6 72.0 2600 125 38.0 70.3 2700 130 40.3 71.1 2800 134 43.1 72.9 2900 139 45.8 75.0 3000 143 45.7 73.6 3100 142 45.1 71.8 3200 141 44.8 70.4 3300 141 45.1 69.9 3400 141 45.0 70.7 3500 141 44.6 70.4 3600 140 44.3 70.2 3700 140 44.2 70.2 3800 139 44.0 70.6 3900 VS ft 0 0 0 0 0 1 2 7 13 23 33 45 58 72 87 102 120 138 163 190 227 267 312 362 415 LAT ft 0 -0 -0 -0 -0 -0 0 2 4 8 11 15 19 23 28 33 39 44 51 59 71 84 99 116 133 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 0 0.0 0.0 29.5 0 0.0 0.0 29.5 0 0.0 0.0 29.5 0 0.0 0.0 29.5 1 0.5 0.5 -14.2 2 0.8 0.7 -26.5 7 1.8 1.8 -6.6 12 1.7 1.6 -4.6 21 1.1 1.0 3.6 31 1.0 0.9 2.5 43 0.7 0.7 0.2 55 0.4 0.4 -0.5 68 0.2 0.0 -1.3 82 O.7 O.7 0.1 96 1.1 1.1 0.9 113 0.9 0.9 1.2 131 0.9 0.9 1.3 155 3.0 3.0 -0.6 181 3.2 3.2 -0.8 216 3.0 3.0 -1.2 253 2.5 2.4 -0.8 296 1.5 1.5 -0.2 343 2.0 2.0 0.2 393 2.4 2.4 0.4 480 153 455 3.1 3.1 1.0 549 175 521 2.3 2.3 -0.0 625 199 593 1.4 1.1 -1.3 708 226 671 1.8 1.8 0.6 797 254 756 2.3 2.1 1.3 893 996 1097 1197 1296 281 848 2.2 2.0 1.5 309 947 0.7 -0.1 -1.0 339 1043 1.0 -0.5 -1.3 371 1138 0.7 -0.2 -1.0 405 1232 0.3 0.2 -0.4 438 472 5O5 538 570 1396 1495 1593 1691 1787 1326 0.4 -0.0 0.6 1419 0.4 -0.3 -0.3 1512 0.2 -0.2 -0.1 1604 0.1 -0.1 0.0 1695 0.3 -0.2 0.3 Baker Hughes INTEQ Client Well Name · Prudhoe Bay Drilling Group · Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : Page 2 of 3 Date April 28, 1993 Filename : l185ETAK Interpolated 100 ft of TVD MD CkL INC DIR TVD ft ft deg deg ft 4643 139 43.6 71.3 4000 4781 138 43.5 71.5 4100 4919 138 43.7 71.4 4200 5058 139 44.1 71.0 4300 5199 140 44.9 70.5 4400 5340 141 45.3 70.5 4500 5482 142 45.2 71.0 4600 5623 142 45.0 71.6 4700 5764 141 44.7 72.3 4800 5905 141 44.5 72.7 4900 6045 140 44.6 72.7 5000 6186 141 44.7 73.1 5100 6327 141 44.8 74.0 5200 6468 141 45.0 73.9 5300 6610 142 45.4 72.6 5400 6752 142 45.5 72.5 5500 6895 143 45.4 73.4 5600 7038 143 45.7 73.9 5700 7182 144 46.4 74.0 5800 7326 144 46.4 74.1 5900 7471 144 45.8 74.1 6000 7614 143 45.4 73.5 6100 7756 142 45.1 72.6 6200 7896 140 44.4 71.8 6300 8035 139 43.5 71.1 6400 8172 136 42.5 71.8 6500 8306 135 41.3 73.2 6600 8440 134 41.2 73.4 6700 8574 134 41.8 72.7 6800 8709 135 42.5 72.6 6900 8845 137 43.2 73.4 7000 8983 138 43.9 73.8 7100 9123 140 44.6 73.8 7200 9264 141 45.2 73.8 7300 9407 143 45.9 73.8 7400 9551 9697 9846 9996 10148 VS ft 1883 1979 2074 2170 2269 2368 2469 2569 2669 2768 LAT ft 601 632 662 694 726 DEP D ' LEG BUILD TUR}? ft °/100 °/100 °/100 1786 0.4 -0 . 13 0 . 5 1876 0.2 -0. 1 0.2 1966 0.2 0.1 -0.1 2058 0.4 0.3 -0.2 2151 0.6 0.5 -0.G 759 2245 0.3 0.3 -0.0 792 2340 0.3 -0.0 0.G 824 2435 0.3 -0.1 0.G 855 2529 0.4 -0.2 0.5 885 2624 0.2 -0.1 0.3 2866 914 2718 0.0 0.0 0.0 2965 943 2812 0.2 0.1 0.3 3064 971 2907 0.5 0.1 0.6 3164 999 3003 0.2 0.12 -0.! 3265 1028 3100 0.7 0.2 -0.9 3366 1058 3196 0.1 0.1 -0.1 3467 1088 3293 0.5 -0.0 0.6 3570 1117 3392 0.3 0.2 0.4 3674 1146 3491 0.5 0.5 0.i 3778 1174 3591 0.1 -0.0 0.0 3882 12.03 3692 0.4 -0.4 0.0 3984 1232 3789 0.4 -0.13 -0.4 4085 1261 3886 0.5 -0.12 -0.6 4183 1291 3980 0.6 -0.5 -0.5 4280 1322 4072 0.7 -0.6 -0.5 4372 1350 4160 0.8 -0.8 0.5 4462 1377 4245 1.1 -0.9 1.0 4551 1404 4330 0.2 -0.1 0.2 4640 1430 4415 0.6 0.5 -0.5 4730 1456 4502 0.5 0.5 -0.0 4823 1483 4591 0.6 0.5 0.5 4918 1510 4681 0.5 0.5 0.3 5016 1538 4775 0.5 0.5 0.0 5115 1565 4870 0.5 0.5 0.0 5217 1594 4969 0.5 0.5 0.0 144 46.6 73.6 7500 5322 1623 146 47.2 73.0 7600 5428 1654 148 47.9 72.9 7700 5538 1686 150 48.7 73.3 7800 5650 1719 152 49.4 73.3 7900 5765 1752 5069 0.5 0.5 -0.2 5171 0.5 0.4 -0.4 5276 0.5 0.5 -0.1 5383 0.6 0.5 0.2 5493 0.5 0.5 0.0 Client Well Name Baker Hughes INTEQ : Prudhoe Bay Drilling Group : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : Page 3 of 3 Date April 28, 1993 Filename : l185ETAK Interpolated 100 ft of TVD MD CkL INC DIR TVD ft ft deg deg ft 10303 154 49.9 73.3 8000 10458 156 50.1 74.1 8100 10613 155 49.7 72.9 8200 10769 155 50.1 71.0 8300 10925 156 50.4 70.0 8400 10980 55 50.4 69.9 8435 VS LAT DEP D'LEG BUILD TURN ft ft ft °/100 °/100 °/100 5882 1786 5606 0.3 0.3 0.0 6002 1819 5720 0.4 0.1 0.5 6120 1853 5834 0.6 -0.3 -0.7 6239 1890 5947 1.0 0.3 -1.2 6359 1930 6060 0.5 0.2 -0.7 6401 1944 6100 0.6 0.2 -0.7 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 6402 ft 72.3° Baker Hughes INTEQ Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Date Surveyed Survey Performed By : Apex Gas Inje6tion 7 : Apex Gas Injection Pad : North Slope, Alaska : : April 28, 1993 : : Don Lentz This survey is correct to the best of my knowledge and is supported by actual field data. ........................... COMPANY REPRESENTATIVE Baker Hughes INTEQ Client : Prudhoe Bay Drilling Group Well Name : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : Date April 28, 1993 Filename : l185ETAK Interpolated 100 ft of MD Plane of Vertical Section : 73.2° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.15°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-7 +0 ° 0' 0' ' (T) Client Well Name Baker Hughes INTEQ : Prudhoe Bay Drilling Group : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : Page 1 of Date April Filename : Interpolated 3 28 , 11993 l185ETAK 100 ft of MD MD ft 0 100 200 30O 40O 5OO 6OO 700 8OO 90O CkL INC DIR TVD ft deg deg ft 0 0.0 0.0 0 100 0.0 29.5 100 100 0.0 59.0 200 100 0.1 88.4 300 100 0.1 117.9 400 100 0.6 103.7 500 100 1.3 77.2 600 100 3.1 70.6 700 100 4.7 65.9 800 100 5.7 69.5 899 1000 100 6.6 72.0 999 1100 100 7.3 72.2 1098 1200 100 7.7 71.7 1197 1300 100 7.7 70.5 1296 1400 100 8.3 70.4 1395 1500 100 9.4 71.3 1494 1600 100 10.4 72.5 1592 1700 100 11.2 73.8 1691 1800 100 14.0 73.5 1788 1900 100 17.2 72.8 1885 2000 100 20.2 71.6 1979 2100 100 23.1 70.6 2072 2200 100 24.6 70.4 2163 2300 100 26.2 70.3 2254 2400 100 28.6 70.6 2342 2500 100 31.2 71.2 2429 2600 100 34.3 72.2 2513 2700 100 36.5 72.1 2595 2800 100 37.6 70.8 2674 2900 100 39.2 70.6 2753 3000 100 41.0 71.4 2829 3100 100 43.2 73.0 2903 3200 100 45.5 74.9 2975 3300 100 45.8 74.4 3045 3400 100 45.7 73.4 3115 3500 100 45.2 72.1 3186 3600 100 44.7 70.8 3256 3700 100 44.9 70.1 3327 3800 100 45.0 69.8 3398 3900 100 45.1 70.8 3469 VS ft 0 0 0 0 0 1 2 7 13 23 33 45 58 71 86 101 118 137 160 185 219 254 295 338 384 434 488 545 606 668 732 8O0 869 940 1011 LAT ft 0 -0 -0 -0 -0 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 0 0.0 0.(3 29.5 0 0.0 0.0 29.5 0 0.0 0.0 29.5 0 0.0 0.0 29.5 -0 1 0.5 0 2 0.8 2 7 1.8 4 12 1.7 8 21 1.1 11 15 19 23 28 0.5 -14 .2 0. '7 -26.5 1.8 -6.6 1.6 -4.6 1.0 3.6 31 1.0 0.9 2.5 43 0.7 0.7 0.2 55 0 . 4 0 . 4 -0 . 5 68 0.2 0.0 -1.3 81 0.6 0.6 -0.0 33 96 1. 1 1. 1 0.9 38 112 1.0 0.9 1.2 44 130 0.9 0.9 1.3 50 152 2.7 2.7 -0.3 58 176 3 . 2 3 . 2 -0 . 7 68 208 3 · 1 3 · 0 -1. i 79 241 2 · 9 2 · 9 -1.0 93 280 1.5 1.5 -0.2 107 320 1.7 1.7 -0.i 123 364 2 · 4 2 · 4 0.4 139 411 2.6 2.6 0.6 156 463 3.1 3.1 1.0 174 517 2.2 2.2 -0.I 193 574 1.4 1.1 -1.3 213 633 1.5 1.5 -0.1 234 694 1.9 1.8 0.7 254 758 2.4 2.2 1.6 274 825 2.7 2.3 1.9 293 893 0.5 0.3 -0.6 313 962 0.7 -0.1 -1.0 1082 334 1030 1.1 1153 356 1097 1.0 1224 380 1163 0.5 1294 404 1230 0.2 1365 428 1296 0.7 -0.5 -1.3 -0.5 -1. 3 0.2 -0.7 0.2 -0.3 0.1 1.0 Client Well Name Baker Hughes : Prudhoe Bay Drilling Group : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : INTEQ Page 2 of 3 Date April 28, 1993 Filename : l185ETAK Interpolated 100 ft of MD MD ft 4000 4100 4200 4300 4400 45OO 4600 4700 4800 4900 5OOO 5100 5200 5300 5400 55OO 5600 5700 5800 5900 6OO0 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 CkL INC DIR TVD ft deg deg ft 100 44.8 70.6 3540 100 44.5 70.3 3611 100 44.4 70.2 3682 100 44.3 70.2 3753 100 44.2 70.2 3825 100 44.0 70.5 3897 100 43.7 71.0 3969 100 43.4 71.5 4041 100 43.5 71.5 4114 100 43.7 71.4 4186 100 43.8 71.3 4258 100 44.4 70.9 4330 100 44.9 70.5 4401 100 45.3 70.3 4472 100 45.3 70.7 4542 100 45.2 71.1 4613 100 45.1 71.5 4683 100 44.8 72.0 4754 100 44.6 72.5 4825 100 44.5 72.7 4896 100 44.6 72.7 4968 100 44.6 72.7 5039 100 44.7 73.2 5110 100 44.8 73.9 5181 100 44.9 74.5 5252 100 45.1 73.6 5322 100 45.3 72.7 5393 100 45.5 72.1 5463 100 45.5 72.8 5534 100 45.4 73.4 5604 100 45.6 73.8 5674 100 46.0 73.9 5743 100 46.5 74.1 5812 100 46.5 74.1 5882 100 46.1 74.1 5951 100 45.7 74.1 6020 100 45.4 73.6 6090 100 45.2 73.0 6161 100 45.0 72.3 6231 100 44.4 71.8 6303 VS ft 1435 1506 1576 1645 1715 1784 1854 1923 1992 2061 2130 2200 2270 2340 2411 2482 2553 2623 2694 2764 2834 2904 2975 3045 3116 3186 3257 3328 3400 3471 3542 3614 3686 3758 3831 3903 3974 4045 4116 4186 LAT ft 452 475 499 522 546 569 592 614 636 658 680 703 726 750 773 796 8.19 841 863 884 9O5 926 946 966 985 1006 1026 1047 1068 1089 1109 1129 1149 1169 1189 1209 1229 1249 1270 1292 DEP D ' LEG BUILD TURN Q o o ft /100 /100 /100 1363 0.4 -0.3 -0.3 1429 0.4 -0.3 -0.3 1495 0.2 -0.2 -0.1 1561 0.1 -0.1 0.0 1627 0.1 -0.1 0.0 1692 0.3 -0.2 0.3 1758 0.4 -0.3 0.5 1823 0.4 -0.3 0.5 1888 0.1 0.1 -0.0 1954 0.2 0.1 -0.1 2019 0.2 0.2 -0. i 2085 0.6 0.5 -0.4 2152 0.6 0.5 -0.4 2218 0.4 0.4 -0.2 2285 0.3 -0.0 0.4 2352 0.3 -0.0 0.4 2419 0.3 -0.1 0.4 2486 0.4 -0.2 0.5 2553 0.4 -0.2 0.5 2620 0.1 -0.1 0.2 2687 0.0 0.0 0.0 2754 0.0 0.0 0.0 2822 0.4 0.1 0.5 2889 0.5 0.1 0.6 2957 0.4 0.1 0.6 3025 0.7 0.2 -0.9 3093 0.7 0.2 -0.9 3161 0.4 0.2 -0.6 3229 0.5 -0.0 0.6 3297 0.5 -0.0 0.6 3365 0.3 0.1 0.4 3435 0.5 0.5 0.1 3504 0.5 0.5 0. 1 3573 0.1 -0.0 0.0 3642 0.4 -0.4 0.0 3712 0.4 -0.4 0.0 3780 0.4 -0.3 -0.5 3848 0.5 -0.2 -0.6 3916 0.5 -0.2 '-0.6 3982 0.7 -0.6 -0.5 Client Well Name Baker Hughes INTEQ Prudhoe Bay Drilling Group Apex Gas Injection 7 Apex Gas Injection Pad North Slope, Alaska Page 3 of 3 Date April 28, 1993 Filename : l185ETAK Interpolated 100 ft of MD MD CkL INC DIR TVD ft ft deg deg ft 8000 100 43.7 71.3 6375 8100 100 43.1 71.1 6447 8200 100 42.2 72.1 6521 8300 100 41.4 73.1 6595 8400 100 41.0 73.6 6670 8500 2LO0 41.5 73.1 6745 8600 :LO0 42.0 72.5 6820 8700 iL00 42.5 72.6 6894 8800 100 43.0 73.1 6967 8900 100 43.5 73.7 7040 9000 I00 44.0 73.8 7112 9100 t00 44.5 73.8 7184 9200 I00 44.9 73.8 7255 9300 t00 45.4 73.8 7326 9400 100 45.9 73.8 7395 9500 100 46.3 73.8 7465 9600 t00 46.8 73.4 7533 9700 100 47.2 73.0 7602 9800 100 47.7 72.8 7670 9900 100 48.2 73.0 7736 10000 100 48.7 73.3 7803 10100 100 49.2 73.3 7869 10200 100 49.6 73.2 7934 10300 100 49.9 73.3 7998 10400 100 50.0 73.8 8063 10500 100 50.0 73.8 8127 10600 ].00 49.7 73.0 8191 10700 100 49.8 72.0 8256 10800 100 50.3 70.6 8320 10900 100 50.4 70.1 8384 10980 80 50.4 69.9 8435 VS ft 4255 4324 4391 4458 4525 4591 4657 4725 4793 4861 4930 5000 5070 5141 5213 5284 5357 5430 5504 5578 5653 5728 5804 5880 5957 6034 6110 6187 6263 6340 6401 LAT ft 1314 1336 1356 1376 1396 1416 1435 1454 1474 1494 1514 1533 1553 1573 1593 1613 1634 1655 1676 1698 1719 1741 1763 1785 1807 1828 1850 1873 1898 1923 1944 DEP D' LEG BUILD TUR~; o o o ft /100 /100 /100 4048 0.7 -0.6 -0.5 4114 0 . 7 -0.7 -0 . 3 4178 1.1 -0.9 1.0 4241 1.1 -0.9 1.0 4305 0.5 -0.4 0.5 4368 0.6 0.5 -0.5 4432 0.6 0.5 -0.5 4496 0.5 0.5 0.0 4561 0.6 0.5 0.5 4626 0.6 0.5 0.5 4693 0.5 0.5 0.1 4760 0.5 0.5 0.0 4827 0.5 0.5 0.0 4895 0.5 0.5 0.0 4964 0.5 0.5 0.0 5033 0.5 0.5 -0.0 5103 0.5 0.4 -0.4 5173 0.5 0.4 -0.4 5243 0.5 0.5 -0.2 5315 0.6 0.5 0.2 5386 0.6 0.5 0.2 5458 0.5 0.5 0.i 5531 0.4 0.4 -0.i 5604 0.3 0.3 0.I 5677 0.4 0.1 0.5 5751 0.0 -0.1 -0.0 5824 0.6 -0.3 -0.8 5897 0.8 0.1 -1.1 5969 1.1 0.4 -1.3 6042 0.5 0.1 -0.6 6100 0.6 0.1 -0.7 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 6402 ft 72.3° INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 93-027 COMP 93-027 DPR/GR 93-027 DPR/GR 93-027 GR/CCL 93-027 PERF 93-027 SBL/GR/CCL 93-027 407 93-027 DAILY WELL OP 93-027 SURVEY Are well tests required? Yes No Was well cored? Yes No... RUN 1, 5" RUNS 6&7,2&5"MD RUNS 6&7,2&5"TVD RUN 1, 5" RUN 1, 5" CH,R1,5" COMP DATE:06/09/93 02/15/93-05/01/93 SS DIRECTIONAL If yes, was the core analysis & description received? Yes No Are dry ditch samples required? Yes No WELL IS ON COMPLIANCE. INITIAL 08/30/1993 PAGE: 1 COMMENTS: AOGCC GEOLOGICAL MATEi~iALS INYENTOi~¥ LIST PEI~MIT# ~'~ - ,~'~, . WELL NAME .. ~ ~t ~? COMPLETION DATE I X~ CO. CONTACT~ ~~ ~ check off or fist data as it' is received.*lis'i'~receiv~d date for 407. if not required list as NR cored inte~a,!,~ , c°re, ~na,!ysis d~ ~itch intewals digitaI ~a~a :; i i i i i iii I iiiii i i i ii ii L iiiii I iiii I I i I I i I ii I i i I I I I L I I II I I I ii ~ii I i i I j I I i II I I I L . i i i iii i i ii i ii I I I I I I J i LoG TYPE ' ~UN INTEFtYALS SCALE'" " NO. (to the nearest foot] , linch/100'1 54] ~ ~1~ ~ ~ ~ll~ ...... ! ........... .... ii! ............................ ...... ,, ~ m~ u , ................... ~ ,~ ........ . , , ~, ,, ~, ,~. ,.~..~..,,,_,.s , ,~,,.. . . , ~ ...... ~ 1~1 ' ~ iii i i ,ii~, ii, iii i i i i i IJ I I Ii J~ J Ii ~ ii i ~ I I ....... 1 ?] ................... 18! · L I I I I III II I I II II I I I II I I I I I I I I I · ~,r---, STATE OF ALASKA ALASK~ MIL AND GAS CONSERVATION C(. ,,'MISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE El( A~3ex ~a~ Ini~actor 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. (~ 93-27 3. Address'~'~,, 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22343 4. Location of well at surface~~'~-"'""~ ~r 9. unit or Lease Name 2292' NSL, 2516' WEL, SEC. 36, T12N, R14~~ v~,'~, Prudhoe Bay Unit At Top Producing Interval ?..~~ i ,, ~FI~DI 10. Well Number "~~ 11. Field and Pool Al Total Depth 5~E'~~ Prudhoe Bay Field/Prudhoe Bay Pool 4226' NSL, 3591'EWL, SEC. 31, T12N, R1 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 49.5' I ADL 34628 12. Date Spudded 13. Dale T.D. Reached 14. Date Comp.,,/,,.)/c,..,S'usp: or Aband.I~"'11' 5. Water Depth, if otfshore,i0ne116' No. of Completions 2/15/93 4/28/93 6/.,t,7-/ej~ ~/' 7/ Z,( N/A feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey'" -'~ FO. Depth where SSSV set 121. Thickness of Permafrost 11015' MD/8473' TVD 11013' MD/8472' TVD YES [] N3 [] I 2186' feet MD I 1900'(Approx.) 22. Type Electric or Other Logs Run MWD, Gyro 23. CASING, LINER AND CEMENTING RECORD SE'ri'lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 30' 106' 30" 11 yds Arcticset 13-3/8" 68# K-55/L-80 34' 3937' 16" 2604 cu ft "E"/460 cu ft "G" 9-5/8" 47# NTS-80 35' 10306' 12-1/4" 460 cu ft Class "G" 7" 29# L-80 10130' 11013' 8-1/2" Uncemented 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MDI Gun Diameter 3-3/8" 6 spf 7"x 5-1/2" 10135' 10055' MD TVD 10630'-10650' 8226'-8239' NTSO/L-80 10668'- 10678' 8250'-8257' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10764'- 10784' 8313'-8326' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10824'- 10844' 8352'-8364' Freeze protected w/5 bbls diesel 10858'-10868' 8373'-8380' 10938'-10958' 8424'-8437' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 6/9/93 I Gas injectin,t Date of Test Hours Tested PRODUCTION FOR DIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. ,Submit core chips. RECEIVED AUG 2 6 1993 Alaska Oil & Gas Cons. Cornmissior~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. I~i 30. GEOLOGIC MARKERS ~ I'~RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEI:q'H GOR, and time of each phase. Top Sadlerochit 10365' 8055' Base Sadlerochit 109 70' 8445' RECEIVED A(J G 2 6 1993 Alaska 0il & Gas Cons. (;ummJssio~' Anchorage 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge '~ned ~*~~[; TitleDrillinclEnoineerSuoervisor Date ~"~~'~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: AGI 7 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 02/14/93 11:00 SPUD: 02/15/93 12:15 RELEASE: 05/01/93 12:00 OPERATION: DRLG RIG: AUDI 2 WO/C RIG: AUDI 2 02/15/93 (1) TD: 110'( 0) MIX SPUD MUD. MW: 8.5 VIS: 0 SKID RIG. RIG ACCEPTED @ 23:00 HRS, 2/14/93. MIX SPUD MUD. 02/16/93 ( 2) TD: 1233' (1123) DRLG. MW: 8.8 VIS:195 P/U BHA. SPUD WELL @ 12:15 HRS, 2/15/93. DRLG TO 1233' 02/17/93 ( 3) TD: 3467' (2234) 02/18/93 (4) TD: 3945'( 478) 02/19/93 ( 5) TD: 4615' ( 670) 02/20/93 (6) TD: 6975' (2360) 02/21/93 ( 7) TD: 8008' (1033) 02/22/93 (8) TD: 8502' ( 494) 02/23/93 (9) TD: 9684' (1182) DRLG. MW: 9.1 VIS:135 DRLG F/ 940'-2533' CIRC. SHORT TRIP TO 850'. DRLG F/ 2533'-3467' N/D FLOW LINE· MW: 9.3 VIS: 98 DRLG TO 3945'. CBU. SHORT TRIP TO 2349'. CIRC. POOH. L/D BHA. RIH W/ 13-3/8" CSG. CIRC. R/U HOWCO. CMT CSG. DISP W/ MUD. R/D HOWCO. L/D LAND JT. N/D FLOW LINE. DRLG. MW: 9.0 VIS: 37 N/D DIVERTER. TOP JOB W/ 104 SX CMT. N/U BOPE. TEST BOPE. RIH W/ BHA TO 3857'. TEST CSG. OK. DRLG FLOAT EQUIP, CMT F/ 3857'-3945'. DRLG NEW HOLE F/ 3945'-4985' CBU. LOT (12.8 PPG EMW). CIRC. DRLG F/ 3985'-4120' POOH. CAHNGE MWD. RIH. DRLG F/ 4120'-4615' DRLG. MW: 9.4 VIS: 38 DRLG TO 5152'. CBU. SHORT TRIP TO 4120' DRLG F/ 5152'-6183'. CBU. SHORT TRIP TO 4403' DRLG F/ 6183'-6975'. DRLG. MW: 9.7 VIS: 39 DRLG TO 7317'. CBU. POOH. CHANGE BIT. RIH. REAM F/ 6903'-7317' DRLG TO 8008' DRLG. MW: 9.7 VIS: 40 DRLG TO 8382'. CBU. POOH. CHANGE BHA, BIT. RIH. REAM F/ 8252'-8382' DRLG F/ 8382'-8502' · RIH. MW:10.0 VIS: 41 DRLG TO 9373' CBU. SHORT TRIP TO 8382' DRLG TO 9684' LOST 1700 PSI. POOH. FOUND WASHOUT. RIH. AUG 8 Alaska Oil & Gas Cons. Commission Anchorage WELL : AGI 7 OPERATION: RIG : AUDI 2 PAGE: 2 02/24/93 (10) TD:10326' ( 642) 02/25/93 (11) TD: 10326' ( 0) 02/26/93 (12) TD: 10326' ( 0) 04/28/93 (13) TD:10720' ( 394) 04/29/93 (14) TD:ll015' ( 295) 04/30/93 (15) TD:ll015 PB:ll015 05/01/93 (16) TD:ll015 PB:ll015 POOH. MW: 9.9 VIS: 41 DRLG F/ 9684'-10233' POOH TO LOOK FOR WASHOUT. DRLG F/ 10233'-10326' CBU. SHORT TRIP TO 9713' CIRC. POOH. N/D BOPE. MW: 8.5 VIS: 0 POOH. L/D BHA. RIH W/ 9-5/8" CSG. WASH TO 10306'. PUMP 20 BBLS PREFLUSH, 50 BBLS SPACER, 82 BBLS 'G' CMT. DISP W/ SEAWATER. BUMP PLUG W/ 2000 PSI. L/D CSG TOOLS. INSTALL PACKOFF. INJECT 200 BBLS MUD DN ANNULUS. RIH TO 2000' DISP WELL W/ DIESEL. POOH. F/P ANNULUS. N/D BOPE. RIG RELEASED. MW: 8.5 VIS: 0 N/D BOPE. N/U TREE. TEST TREE. RIG RELEASED @ 09:00 HRS, 2/25/93. DRLG. MW: 9.1 VIS: 50 MOVE RIG. RIG ACCEPTED @ 07:00 HRS, 4/27/93. N/D TREE. N/U BOPE. TEST BOPE. RIH W/ BHA, BIT. DISP DIESEL. RIH. CIRC. TEST CSG. OK. DRLG FLOAT EQUIP, CMT TO 10326'. CIRC. DISP TO FLO-PRO. DRLG F/ 10326'-10336' FIT (12.9 PPG EMW). DRLG F/ 10336'-10720' CIRC. MW: 9.2 VIS: 60 DRLG TO 11015' TD WELL @ 11:30 HRS, 4/28/93. CIRC. SHORT TRIP TO ~HOE. CBU. POOH. L/D BHA. RIH W/ 7" LNR ON DP. CIRC. RIH TO 11013'. CIRC. NOTE: DAILY COST INCLUDES CORRECTION OF MISSED COSTS. R/I SLICK LINE. MW: 9.3 NaC1 SET PKR. RELEASE F/ LNR. DISP WELL W/ BRINE. POOH. L/D BHA. RIH W/ TBG. SPACE OUT. M/U HGR. F/P TOP 2000' W/ DIESEL. ATTEMPT TO PRESSURE UP ON TBG. NO GO. R/U CAMCO. RIG RELEASED. MW: 9.3 NaC1 R/U CAMCO. PULL DUMMY F/ SSSV. SET PLUG IN NIPPLE. SET PKR. PRESS UP TO 4000 PSI. SET DUMMY IN SSSV. TEST TBG, ANNULUS. OK. SHEAR OUT. PUMP 20 BBLS DIESEL DN TBG. RELAND TBG. RETEST TBG. R/D CAMCO. SET BPV. N/D BOPE. N/U TREE. TEST TREE. SECURE WELL. RIG RELEASED @ 24:00 HRS, 4/30/93. SIGNATURE: (drilling superintendent) DATE: RECEIV' D UG 2 6 & Gas Cons. L;ommissJon Anchorage SUB - S URFA CE DIRECTIONAL SURVEY ~'J UIDANCE ONTINUOUS r~ OOL RE(~EIVED A U G 2 6 1993 AIaska Cji & Gas Cons. Cornmissjol~' Anchorage Company Well Name Field/Location ARCO ALASKA, INC. AGZ-7 (2291' FSL, 2515' FEL, SEC 36, T12N, R14E) PRUDHOE BAY', NORTH SLOPE, ALASKA Job Reference No. 93264 Loqqed BV: CRYER Date 8-dUN-93 Computed By: KOHRING · SCHLIJMBF_RGER · OCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. AGI-7 METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE: 08-JUN-93 ENGINEER' J, CRYER RECEIVED A U G 2 6 t99~ Alaska Oil & Gas Cons. Commissio,' Anchorage MINIMUM CURVATURE LINEAR HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 73 DEG 10 MIN EAST COMPUTATION DATE' 30-JUN-93 PAGE I ARCO ALASKA, INC. aGI-7 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 08-JUN-93 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' J. CRYER INTERPOLATED VALUES FOR EVEN 100 FEET Of MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600.00 700.00 800.00 900.00 0 O0 100 O0 200 O0 300 O0 40O O0 500 O0 599 99 699 92 799 68 899 32 -49.00 51 O0 151 O0 251 O0 351 O0 451 O0 550 99 650 92 75O 68 850 32 0 0 N 0 0 E 0 6 S 3 12 E 0 7 S 3 52 E 0 8 S 2 10 E 0 I S 0 41W 0 17 N 88 6 E I 2 N 7O 59 E 3 17 N 64 55 E 4 25 N 66 7 E 5 17 N 69 21E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 -0 06 -0 13 -0 ,19 -0 22 -0 10 1 09 A 75 11 51 19 92 0 O0 0 O0 0 O0 0 O0 0 O0 0 63 0 99 1 14 0 63 1 04 0 O0 N 0 14 S 0 36 S 0 57 S 0 68S 075S 040S 0 97 N 3.80 N 6.96 N 0 O0 E 0 02 W 0 03 W 0 03 W 0 02 W 0 13 E 1 26 E 467 E 10 88 E 18 71 E 0 O0 N 0 0 E 0 0 0 0 0 1 4 11 19 14 S 7 29 W 36 S 3 59 W 57 S 2 46 W 68 S 1 41W 76 S 9 30 E 32 S 72 20 E 77 N 78 17 E 52 N 70 44 E 96 N 69 36 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 998 79 O0 1098 11 1049 O0 1197 30 1148 O0 1296 34 1247 O0 1395 22 1346 O0 1493 93 1444 O0 1592 50 1543 O0 1690.85 1641 O0 1788.94 1739 O0 1885.83 1836 949 79 6 22 11 7 3 30 7 37 34 8 16 22 8 52 93 9 28 50 10 0 85 10 47 94 12 0 83 16 58 N 7O 5 E N 71 47 E N 73 21E N 72 58 E N 70 23 E N 70 47 E N 72 28 E N 73 7 E N 73 4O E N 72 37 E 3O 18 41 79 54 51 68 37 83 27 99 27 116 11 134 15 153 63 178 19 0 2O 0 38 0 71 0 73 0 68 0 40 0 70 0 55 2 6O 5 91 10.46 N 14.30 N 39 18 12 N 51 22 05 N 64 26 76 N 78 32 14 N 93 37 45 N 109 42 77 N 127 48 34 N 145 55 28 N 169 28 36 E 30.23 N 69 45 E 33 E 41.85 N 70 1E 46 E 54.56 N 70 36 E 76 E 68.41 N 71 12 E 90 E 83.31 N 71 16 E 99 E 99.33 N 71 7 E 98 E 116.18 N 71 12 E 22 E 134.22 N 71 25 E 88 E 153.68 N 71 40 E 44 E 178.23 N 71 56 E 2000.00 1980 08 1931 08 21 22 2100.00 2072 2200.00 2165 23OO O0 2255 2400 O0 2344 2500 O0 2431 2600 O0 2516 2700 O0 2598 2800 O0 2679 2900 O0 2757 90 2023 16 2116 93 2206 84 2295 88 2382 79 2467 46 2549 07 2630 97 2708 9O 22 11 16 23 31 93 25 59 84 28 38 88 30 13 79 33 58 46 35 56 07 36 49 97 38 41 3000 O0 ~2835.44 2786.44 40 11 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2909.95 2860.95 43 35 O0 2980.80 2931.80 45 37 O0 3050.65 3001 65 45 26 O0 3120.96 3071 96 45 26 O0 3191.17 3142 17 45 6 O0 3262.13 3213 13 44 25 O0 3334.01 3285 O1 43 56 O0 3405.45 3356 45 44 54 O0 3476.08 3427 08 45 12 N 70 7 E N 7O 36 E N 71 16 E N 70 26 E N 69 54 E N 70 39 E N 71 31E N 71 26 E N 71 28 E N 70 35 E 211 49 248 66 287 19 329 O9 374 79 423 95 476 70 534 37 593 52 654 90 N 71 3 E N 71 50 E 784 N 74 19 E 855 N 75 22 E 926 N 74 43 E 997 N 71 26 E 1069 N 70 45 E 1139 N 71 23 E 1208 N 70 11E 1278 N 70 14 E 1349 718 07 71 27 79 85 05 45 92 83 52 1 48 0 61 2 66 2 20 2 57 1 96 4 03 0.49 1.91 0.86 3 25 4 11 1 76 1 lO 1 56 2 73 1 21 0 63 0 7o 0 74 66 20 N 200 93 E 211.56 N 71 46 E 78 70 N 235 91 32 N 272 104 97 N 312 120 58 N 355 09 E 375 137 21N 401 42 E 424 154 22 N 451 38 E 477 172 58 N 506 08 E 534 191 211 232.22 N 679 96 E 718 52 N 71 9 E 253.54 N 743 274.08 N 810 292.67 N 879 310.71N 948 331.14 N 1016 354.32 N 1083 376.80 N 1149 399.87 N 1215 423.86 N 1281 98 E 248 76 N 71 33 E ~ · ~ 42 E 287 32 N 71 28 E ~ · ~ 07 E 329 25 N 71 25 E ~ O0 N 71 15 E =' ~> 22 N 71 8 E _ ~',,---'~ O0 N 71 8 E ~ ~' 70 N 71 10 E o v~ 30 N 562.22 E 593 87 N 71 13 E ~ c 45 N 620.24 E 655 30 N 71 11E 20 N 71 10 E 71 N 71 19 E 14 N 71 36 E 11 N 71 52 E 29 N 71 58 E 73 N 71 53 E 24 N 71 51E 21 N 71 47 E 96 N 71 42 E 14 E 785 63 E 855 74 E 927 52 E 998 72 E 1069 26 E 1139 04 E 1209 10 E 1279 70 E 1349 ARCO ALASKA, INC. AGI-7 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 30-JUN-93 PAGE 2 DATE OF SURVEY: 08-JUN-93 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: J. CRYER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3547 35 3498.35 44 8 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3619 O0 3690 O0 3761 O0 3833 O0 3904 O0 3977 O0 4049 O0 4122 O0 4193 03 3570.03 44 23 45 3641.45 44 30 69 3712.69 44 35 03 3784.03 44 17 88 3855.88 43 52 13 3928.13 43 39 64 4000.64 43 25 06 4073.06 44 2 88 4144.88 43 53 N 7O 29 E 1419 58 N 70 40 E 1489 N 71 2 E 1559 N 71 8 E 1629 N 71 16 E 1699 N 71 33 E 1768 N 71 31E 1837 N 71 22 E 1906 N 71 12 E 1975 N 71 6 E 2045 24 18 31 34 87 97 81 73 27 0 16 0 44 0 46 0 30 0 33 0 69 0 25 0 29 1 01 0 63 447 44 N 1347 76 E 1420 09 N 71 38 E 470 493 516 538 561 582 604 627 649 61N 1413 58 n 1479 32 N 1546 90 N 1612 07 N 1678 96 N 1743 88 N 1809 04 N 1874 53 N 1940 53 E 1489 65 E 1559 04 E 1629 37 E 1700 30 E 1769 88 E 1838 16 E 1907 47 E 1976 31E 2046 81 N 71 35 E 80 N 71 33 E 98 N 71 32 E O5 N 71 31E 61 N 71 31E 74 N 71 31E 61 N 71 31E 56 N 71 30 E 15 N 71 29 E 5000 O0 4266.15 4217 15 43 39 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4338.57 4289 O0 4410.34 4361 O0 4480.63 4431 O0 4550.88 4501 O0 4621.43 4572 O0 4692.12 4643 O0 4762.91 4713 O0 4833.97 4784 O0 4905.52 4856 57 43 32 34 45 3 63 45 18 88 45 20 43 45 0 12 44 58 91 44 53 97 44 30 52 44 2 N 70 56 E 2114 33 N 70 50 E 2183 N 71 S E 2252 N 71 36 E 2323 N 71 46 E 2395 N 72 0 E 2465 N 72 20 E 2536 N 72 39 E 2607 N 72 47 E 2677 N 73 7 E 2747 24 81 90 05 91 62 25 60 47 0.21 0.40 1.88 0.37 0.04 0.19 0.44 0.48 0.29 0.46 671 99 N 2005 68 E 2115 25 N 71 29 E 694 717 740 762 784 806 827 848 868 56 N 2070 41N 2136 12 N 2204 42 N 2271 51N 2338 21N 2406 42 N 2473 30 N 2540 81N 2607 84 E 2184 61E 2253 02 E 2324 61E 2396 95 E 2467 26 E 2537 64 E 2608 82 E 2678 61E 2748 21 N 71 28 E 84 N 71 26 E 96 N 71 26 E 14 N 71 27 E O1 N 71 27 E 73 N 71 29 E 35 N 71 30 E 69 N 71 32 E 53 N 71 34 E 6000 O0 4977 43 4928 43 44 2 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 5049 O0 5120 O0 5191 O0 5262 O0 5333 O0 5404 O0 5474 O0 5544 O0 5615 30 5000 38 5071 29 5142 25 5213 42 5284 38 5355 84 5425 96 5495 29 5566 30 44 18 38 44 55 29 44 48 25 44 43 42 44 37 38 44 57 84 45 29 96 45 25 29 45 20 N 73 24 E 2816 96 N 73 33 E 2886 N 73 58 E 2956 N 74 14 E 3027 N 74 24 E 3O97 N 74 50 E 3168 N 74 59 E 3238 N 73 28 E 3309 N 73 34 E 3380 N 74 5 E 3451 49 83 33 77 O0 43 37 66 74 0 21 1 O1 0 39 0 25 0 65 0 57 0 21 I 41 0 84 0 15 888 82 N 2674 15 E 2817 99 N 71 37 E 908 928 947 966 985 1003 1022 1043 1062 63 N 274O 30 N 2808 62 N 2876 64 N 2943 29 N 3011 64 N 3079 63 N 3148 11N 3216 82 N 3284 81E 2887 34 E 2957 15 E 3028 99 E 3O98 72 E 3168 75 E 3239 12 E 3310 41E 3381 71E 3452 7000 O0 5685 56 5636.56 45 19 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 5755 O0 5823 O0 5892 O0 5961 O0 6031 O0 6101 O0 6172 O0 6242 O0 6314 27 5706.27 46 25 98 5774.98 46 46 75 5843.75 46 27 96 5912.96 45 59 74 5982.74 45 36 87 6052.87 45 19 27 6123.27 45 10 91 6193.91 44 53 02 6265.02 44 34 N 74 10 E 3522 89 N 74 17 E 3594 N 74 3 E 3667 N 74 9 e 3739 N 74 19 E 3811 N 74 37 E 3883 N 74 39 E 3954 N 74 39 E 4025 N 73 22 E 4096 N 72 4 E 4166 57 21 80 97 58 85 84 61 91 0 32 0 45 0 50 0 41 0 53 0 26 0 22 0 36 2 21 0 28 1082 34 N 3353 14 E 3523 49 N 72 7 E 1101 1121 1141 1161 1180 1199 1217 1237 1258 76 N 3422 58 N 3492 46 N 3561 11N 3631 27 N 3700 16 N 3769 94 N 3837 09 N 3905 29 N 3972 15 E 3595 05 E 3667 88 E 3740 32 E 3812 34 E 3884 09 E 3955 58 E 4026 72 E 4096 75 E 4167 5O N 71 40 E 79 N 71 43 E 24 N 71 46 E 62 N 71 49 E >-- 80 N 71 53 E 16 N 71 57 E 05 N 72 0 E c 33 N 72 2 E =: 38 N 72 4 E ~' 13 N 72 9 E o c- 75 N 72 12 E ~ u~ 31 N 72 14 E c~ . 44 N 72 16 E c 02 N 72 19 E 25 N 72 21 E 21 N 72 24 E 95 N 72 26 E 26 N 72 26 E COMPUTATION DATE' 30-JUN-93 PAGE 3 ARCO ALASKA, INC. AGI-7 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 08-JUN-93 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' J. CRYF_R INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMLFFH DEPTH DEPTH DEPTH DEG BIN DEG BIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOLFTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 6385 67 6336 67 43 50 8100 8200 8300 8400 8500 860O 8700 8800 89OO O0 6458 O0 6531 O0 6606 O0 6681 O0 6757 O0 6832 O0 6906 O0 6980 O0 7053 33 6409 93 6482 44 6557 99 6632 47 6708 37 6783 63 6857 35 6931 33 43 93 42 14 44 41 27 99 40 45 47 41 13 37 41 47 63 42 16 35 42 46 44 7004.44 43 18 N 72 16 E 4236 65 N 72 19 E 4305 N 72 44 E 4373 N 72 46 E 4439 N 72 49 E 4505 N 72 44 E 4570 N 72 46 E 4637 N 72 46 E 4704 N 72 44 E 4771 N 72 42 E 4839 35 O4 73 25 84 10 O6 63 87 0 97 0 73 0 91 0 93 0 29 0 34 0 53 0 40 0 44 0 59 1279.65 N 4039 16 E 4237 02 N 72 25 E 1300.53 N 4104 1320.91N 4169 1340.65 N 4232 1360.05 N 4295 1379.47 N 4358 1399.13 N 4421 1418.97 N 4485 1438.99 N 4549 1459.28 N 4615 61E 4305 17 E 4373 87 E 4440 45 e 4505 10 E 4571 38 E 4637 34 E 4704 88 E 4772 O3 E 484O 72 N 72 25 E 42 N 72 25 E 11 N 72 26 E 62 N 72 26 E 21 N 72 26 E 47 N 72 26 E 44 N 72 27 E O1 N 72 27 E 25 N 72 27 E 9000 O0 7125 84 7076 84 43 55 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 7197 O0 7268 O0 7339 O0 7409 O0 7478 O0 7547 O0 7616 O0 7683 O0 7751 57 7148 71 7219 36 7290 44 7360 79 7429 66 7498 05 7567 93 7634 57 44 23 71 44 51 36 45 15 44 45 50 79 46 19 66 46 40 05 47 1 93 47 34 05 7702.05 48 6 N 72 41E 4908 85 N 72 38 E 4978 N 72 35 E 5048 N 72 33 E 5119 N 72 32 E 5190 N 72 33 E 5262 N 72 40 E 5335 N 72 35 E 5408 N 72 33 E 5481 N 72 31E 5555 53 8O 57 9O 94 44 4O 82 94 0 76 0 56 0 51 0 44 0 62 0 16 0 4O 0 19 0 57 0 52 1479 80 N 4680 89 E 4909.23 N 72 27 E 1500 1521 1542 1564 1585 1607 1629 1651 1673 55 N 4747 53 N 4814 75 N 4881 16 N 4950 79 N 5018 44 N 5087 24 N 5157 26 N 5227 48 N 5298 41 E 4978 91 N 72 28 E 48 E 5049 99 E 5119 04 E 5191 76 E 5263 96 E 5335 59 E 5408 64 E 5482 36 E 5556 18 N 72 28 E 96 N 72 28 E 29 N 72 28 E 34 N 72 28 E 84 N 72 28 E 8O N 72 28 E 23 N 72 28 E 36 N 72 28 E 10000 O0 7817 54 7768 54 48 33 10100 10200 10300 10400 10500 10600 10700 10800 10900 O0 7883 O0 7948 O0 8013 O0 8077 O0 8141 O0 8206 O0 8271 O0 8336 O0 8400 38 7834 60 7899 19 7964 30 8028 64 8092 63 8157 57 8222 10 8287 38 49 4 60 49 28 19 50 0 30 50 5 64 49 43 63 49 21 57 49 38 10 50 1 14 8351.14 50 19 N 72 30 E 5630 63 N 72 30 E 5705 N 72 28 E 5781 N 72 33 E 5858 N 73 46 E 5934 N 73 14 E 6011 N 72 37 E 6087 N 71 41E 6163 N 71 5 E 6239 N 7O 15 E 6316 89 7O 03 77 32 33 36 72 44 0 58 1 16 1 27 0 64 0 85 1 O6 0 65 0 74 0 82 3 6O 1695 91N 5369 60 E 5631.05 N 72 28 E 1718 1741 1764 1786 1808 1830 1853 1878 1903 54 N 5441 38 E 5706.32 N 72 28 E 35 N 5513 68 E 5782.12 N 72 28 E 32 N 5586 48 E 5858 46 N 72 28 E 50 N 5659 94 E 5935 20 N 72 29 E 24 N 5733 35 E 6011 74 N 72 30 E 59 N 5805 99 E 6087 74 N 72 30 E 95 N 5878.36 E 6163 78 N 72 30 E 34 N 5950.76 E 6240 17 N 72 29 E 75 N 6023.23 E 6316 92 N 72 28 E 11000.00 8463.91 8414.91 50 23 11015.00 8473.48 8424.48 50 23 N 70 16 E 6393.36 N 70 16 E 6404.90 0. O0 0. O0 1929.76 N 6095.72 E 6393.89 N 72 26 E 1933.66 N 6106.60 E 6405.43 N 72 26 E RECEIVED AU G 2 6 t993 Aiaska Oil & Gas Cons. Commission Anchorage ARCO ALASKA, INC. AGI-7 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 30-JUN-93 PAGE 4 DATE OF SURVEY' 08-JUN-93 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' J. CRYER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASt..~ED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE BEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG ~IN DEG BIN FEET DEG/IO0 FEET FEET FEET DEG BIN 0.00 0.00 -49.00 0 0 N 0 0 E 0 O0 1000.00 998.79 949.79 6 22 N 70 5 E 30 18 2000.00 1980.08 1931.08 21 22 N 70 7 E 211 49 3000.00 2835.44 2786.44 40 11 N 71 3 E 71B 07 4000.00 3547.35 3498.35 44 8 N ?0 29 E 1419 58 5000.00 4266.15 4217.15 43 39 N 70 56 E 2114 33 6000.00 4977.43 4928.43 44 2 N 73 24 E 2816 96 7000.00 5685.56 5636.56 45 19 N 74 10 E 3522 89 8000.00 6385.67 6336.67 43 50 N 72 16 E 4236 65 9000.00 7125.84 7076.84 43 55 N 72 41 E 4908 85 lO000.O0 7817.54 7768.54 48 33 N 72 30 E 5630.63 11000.00 8463.91 8414.91 50 23 N 70 16 E 6393.36 11015.00 8473.48 8424.48 50 23 N 70 16 E 6404.90 0.00 0.20 1.48 3.25 0.16 0.21 0.21 0 O0 N 0 O0 E 0 O0 N 0 0 E 10 46 N 28 36 E 30 23 N 69 45 E 66 20 N 200 93 E 211 56 N 71 46 E 232 22 N 679 96 E 718 52 N 71 9 E 447 44 N 1347 76 E 1420 09 N 71 38 E 671 99 N 2005 68 E 2115 25 N 71 29 E 888 82 N 2674 15 E 2817 99 N 71 37 E 0.32 1082 34 N 3353 14 E 3523 49 N 72 7 E 0.97 1279 65 N 4039 16 E 4237 02 N 72 25 E 0.76 1479 80 N 4680 89 E 4909.23 N 72 27 E 0.58 1695.91 N 5369.60 E 5631.05 N 72 28 E 0.00 1929.76 N 6095.72 E 6393.89 N 72 26 E 0.00 1933.66 N 6106.60 E 6405.43 N 72 26 E RECEIVED AU G 2 6 199 AJaska 0ii & Gas Cons. Commission Anchorage COMPUTATION DATE' 30-JUN-93 PAGE ARCO ALASKA, INC. AGI-7 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 08-JUN-g3 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' J. CRYER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 49 O0 149 O0 249 O0 349 O0 449 O0 549 O0 649 03 749 18 849 48 0 O0 49 O0 149 O0 249 O0 349 O0 449 O0 549 O0 649 O0 749 O0 849 O0 -49 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0 5 S 12 53 W 0 9 S 7 26W 0 7 S 5 8 W 0 3 S 13 9 E 0 5 S 36 19 E 0 43 N 72 42 E 2 I N 69 49 E 3 57 N 65 33 E 4 51 N 68 8 E 0 O0 -0 03 -0 10 -0 16 -0 21 -0 21 0 33 '2 35 7 8O 15.47 0 O0 0 39 0 16 0 O0 0 26 0 23 0 8O 2 23 I 79 0 92 0 O0 N 0 04 S 0 25 S 0 46 S 0 67 S 0 71S 0 65 S 0 O1 N 2 26 N 534 N 0 O0 E 0 O1 W 0 02W 0 03W 0 02 W 0 O1 W 0 54 E 2 46 E 7.46 E 14.55 E 0.00 N 0 0 E 0.04 S 18 15 W O. 25 S 5 28 W 0.46 S 3 12 W 067 S 2 OW 0 71 S 0 42W 0 85 S 39 26 E 2 46 N 89 40 E 7 80 N 73 7 E 15 50 N 69 50 E 949 91 1050 1151 1252 1353 1454 1555 1657 1759 1861 949 O0 53 1049 29 1149 18 1249 24 1349 47 1449 85 1549 42 1649 23 1749 69 1849 900 O0 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 5 57 O0 6 39 O0 7 18 O0 8 0 O0 8 37 O0 9 17 O0 9 42 O0 10 28 O0 11 14 O0 14 40 NTO 15 E N 70 30 E N 72 31 E N 73 43 E N 71 31 E N70 15 E NT1 42 E N 72 56 E N 73 29 E N 73 53 E 24 76 35 88 48 20 61 6O 76 18 91 86 108 57 126 31 145 45 167 68 1.87 0.91 0.36 0.57 0.76 0137 0.47 0.86 1.24 6.31 8 63 N 12 40 N 16 26 N 45 20 13 N 58 24 44 N 72 29 66 N 87 35 14 N 102 40.49 N 119 46.02 N 138 52.24 N 159 33 73 E 35 44 E 48 27 E 61 19 E 76 O0 E 91 8O E 108 72 E 126 03 E 145 38 E 167 23.26 E 24 81 N 69 39 E 94 N 69 49 E 26 N 70 18 E 64 N 70 57 E 22 N 71 18 E 92 N 71 10 E 63 N 71 8 E 38 N 71 19 E 50 N 71 34 E 72 N 71 51E 1966 71 1949 O0 lgO0 O0 20 29 2O74 2182 2292 2404 2519 2639 2762 2888 3017 20 2049 39 2149 28 2249 73 2349 86 2449 15 2549 57 2649 51 2749 82 2849 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 22 3 O0 23 5 O0 25 50 O0 28 45 O0 30 40 O0 35 12 O0 36 19 O0 38 35 O0 40 45 N 70 12 E n 70 30 E NT1 8 E N70 31 E N 69 55 E N 7O 54 E N 71 26 E N71 38 E N 70 32 E N71 9 E 199 59 238 96 280 21 325 71 377 04 434 O0 498 93 571 24 647 72 729 62 4.19 0.46 2.03 2 25 2 47 2 95 2 38 0 9O 0 98 3 3O 62.16 N 189 72 E 199.65 N 71 52 E 75.47 N 226 89..07 n 265 103 84 N 308 121 35 N 357 140 52 N 410 161 29 N 472 184 25 N 541 209 235 82 E 239.05 N 71 36 E 80 E 280.33 N 71 28 E 88 E 325 87 N 71 25 E 20 E 377 25 N 71 14 E 91E 434 27 N 71 7 E 47 E 499 24 N 71 9 E 07 E 571 58 N 71 12 E 06 N 613.47 E 648 11 N 71 11 E 96 N 690.90 E 730 08 N 71 9 E 3154.69 2949 O0 2900.00 45 9 3297.65 3O49 3440.00 3149 3581.60 3249 3720.84 3349 3861.60 3449 4002.30 3549 4141.95 3649 4282.19 3749 4422.29 3849 O0 3000.00 45 28 O0 3100.00 45 31 O0 3200 O0 44 37 O0 3300 O0 44 5 O0 3400 O0 45 5 O0 3500 O0 44 8 O0 3600 O0 44 25 O0. 3700 O0 44 35 O0 3800 O0 44 11 N 73 9 E N 75 20 E 925 N 73 48 E 1026 N 70 37 E 1126 N 71 14 E 1223 N 70 12 E 1322 N 70 29 E 1421 N 70 48 E 1518 N 71 8 E 1616 N 71 20 E 1714 822 99 12 37 57 39 34 18 57 82 88 2 37 1 12 2 O1 1 15 1 32 0 37 0 17 0 40 0 28 0 71 265 06 N 779.64 E 823 47 N 71 13 E 292 318 35O 381 414 447 480 512 543 24 N 878 12 E 925 45 N 975 06 N 1071 45 N 1162 65 N 1256 98 N 1349 30 N 1441 27 N 1534 89 N 1627 97 E 1026 09 E 1126 75 E 1223 O8 E 1322 27 E 1421 24 E 1519 21E 1617 10 E 1715 47 N 71 36 E 61 N 71 56 E 85 N 71 54 E 72 N 71 50 E 75 N 71 44 E 69 N 71 38 E 17 N 71 34 E 48 N 71 32 E 59 N 71 31E COMPUTATION DATE' 30-JUN-93 PAGE 6 ARCO ALASKA, INC. AGI-7 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF surveY. 08-JUN-93 KELLY BUSHING ELEVATION- 49.00 FT ENGINEER' J. CRYER INTERPO~T~ VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPAR-rURE SECTION SEVERITY NORTH/SOl]TH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4561 11 3949 O0 3900 O0 43 42 4699 4837 4976 5114 5254 5397 5539 5680 5821 12 4049 55 4149 29 4249 39 4349 97 4449 33 4549 O0 4649 37 4749 06 4849 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 43 25 O0 44 14 O0 43 40 O0 43 35 O0 45 26 O0 45 20 O0 45 1 O0 44 56 O0 44 28 N 71 32 E 1811 13 N 71 22 E 1906 N 71 8 E 2001 N 70 59 E 2097 N 70 47 E 2193 N 71 26 E 2291 N 71 46 E 2393 N 72 5 E 249~ N 72 36 E 2593 N 72 49 E 2692 20 86 98 14 87 15 48 39 36 0 34 0 28 0 16 0 21 0 63 0 54 0 10 0 16 0 18 0 16 574 45 N 1718 41 E 1811 88 N 71 31 E 604 635 666 697 729 761 793 823 852 69 N 1808 48 N 1899 65 N 1990 82 N 2080 96 N 2173 82 N 2269 O1N 2365 28 N 2460 66 N 2554 59 E 1907 22 E 2002 20 E 2098 20 E 2194 63 E 2292 80 E 2394 18 E 2494 41E 2594 92 E 2693 O0 N 71 31E 71 N 71 30 E 89 N 71 29 E 12 N 71 27 E 92 N 71 26 E 24 N 71 27 E 58 N 71 28 E 50 N 71 30 E 45 N 71 33 E 5960 45 4949 O0 4900.00 44 6099 6240 6381 6521 6663 6805 6947 7090 7236 59 5049 39 5149 34 5249 90 5349 21 5449 76 5549 99 5649 92 5749 46 5849 O0 5000.00 44 17 O0 5100.00 44 50 O0 5200.00 44 48 O0 5300.00 44 40 O0 5400.00 45 17 O0 5500.00 45 25 O0 5600.00 45 23 O0 5700.00 46 20 O0 5800.00 46 33 N 73 18 E 2789 46 N 73 33 E 2886 20 N 74 4 E 2985 32 N 74 23 E 3084 63 N 74 53 E 3183 38 N 74 25 E 3283 18 N 73 38 E 3384.76 N 74 3 E 3485.90 N 74 18 E 3588.00 N 74 6 E 3693.73 0 36 1 O1 0 33 0 15 0 51 1 85 0 87 0 58 1 08 0 73 880.94 N 2647.81E 2790 51 N 71 36 E 908.54 N 2740.53 E 2887 936 15 N 2835.74 E 2986 963 11 N 2931.34 E 3085 989 31 N 3026.58 E 3184 1015 37 N 3122.96 E 3283 1044 27 N 3220.35 E 3385 1072 20 N 3317.56 E 3486 1099 98 N 3415.83 E 3588 1128 86 N 3517.55 E 3694 21 N 71 40 E 27 N 71 44 E 50 N 71 49 E 17 N 71 54 E 88 N 71 59 E 43 N 72 2 E 52 N 72 5 E 57 N 72 9 E 25 N 72 12 E 7381.33 5949 O0 5900.00 46 3 7524 66 6049 O0 6000.00 45 34 7666 98 6149 O0 6100.00 45 15 7808 60 6249 O0 6200.00 44 50 7948 99 6349 O0 6300.00 44 16 8087 23 6449 O0 6400.00 43 6 8223 02 6549 O0 6500.00 42 2 8356 47 6649 O0 6600.00 40 45 8488 75 6749.00 6700.00 41 11 8622 32 6849.00 6800.00 41 54 8757 38 6949 O0 6900 O0 42 33 8893 9032 9172 9313 9456 9601 9748 9896 10047 89 7049 21 7149 22 7249 70 7349 92 7449 95 7549 41 7649 93 7749 66 7849 O0 7000 O0 7100 O0 7200 O0 7300 O0 7400 O0 7500 O0 760O O0 7700 O0 7800 O0 43 16 O0 44 7 O0 44 45 O0 45 18 O0 46 8 O0 46 40 O0 47 12 O0 48 5 O0 48 52 N 74 14 E 3798 54 N 74 39 E 3901 18 N 74 40 E 4002 42 N 73 7 E 4102 68 N 72 11 E 4201 19 N 72 19 E 4296 63 N 72 48 E 4388 49 N 72 46 E 4476 85 N 72 45 E 4563 43 N 72 46 E 4651 97 N 72 46 E 4742 76 N 72 42 E 4835 67 N 72 40 E 4931 23 N 72 39 E 5029 22 N 72 32 E 5129 29 N 72 32 E 5231 82 N 72 40 E 5336 85 N 72 33 E 5443.85 N 72 32 E 5553.67 N 72 29 E 5666.43 0 48 0 19 0 17 2 16 0 89 0 70 0 93 0 47 0 31 0 48 0.50 O. 53 0.43 0.47 0 52 0 91 0 41 0 73 0 5O 0 37 1157.47 N 3618 39 E 3799.01 N 72 16 E 1184.94 N 3717 1211.74 N 3814 1238.81N 3911 1268.83 N 4005 1297.88 N 4096 1325.49 N 4183 1351.65 N 4268 1377.27 N 4351 32 E 3901.61 N 72 19 E 98 E 4002.80 N 72 23 E 54 E 4103 03 N 72 26 E 38 E 4201 55 N 72 25 E 30 E 4297 O0 N 72 25 E 92 E 4388 86 N 72 25 E 32 E 4477 22 N 72 26 E 03 E 4563 80 N 72 26 E 1403.53 N 4435 59 E 4652 35 N 72 26 E 1430 43 N 4522 30 E 4743 13 N 72 27 E 1458 03 N 4611 1486 46 N 4702 1515 68 N 4795 1545 67 N 4891 1576 45 N 4989 1607 86 N 5089 1639 87 N 5191 1672.79 N 5296 1706.68 N 5403 03 E 4836 26 E 4931 79 E 5029 27 E 5129 08 E 5232 31E 5337 41E 5444 18 E 5554 74 E 5666 05 N 72 27 E 61 N 72 27 E 61 N 72 28 E 69 N 72 28 E 22 N 72 28 E 26 N 72 28 E 26 N 72 28 E 08 N 72 28 E 85 N 72 28 E = ]> COMPUTATION DATE: 30-JUN-93 PAGE 7 ARCO ALASKA, INC. AGI-7 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 08-JUN-93 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: J. CRYER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG 10200 62 7949 O0 7900 O0 49 28 10355 84 8049 O0 8000 O0 50 11 10511 37 8149 O0 8100 O0 49 38 10665 18 8249 O0 8200 O0 49 33 10820 11 8349 O0 8300 O0 50 7 10976 fil 8449 O0 8400 O0 50 23 11015 O0 8473 48 8424 48 50 23 N 72 28 E 5782 17 N 73 21E 5900 87 N 73 9 E 6019 99 N 71 55 E 6136 85 N 70 55 E 6255 12 N 70 16 E 6375 37 N 70 16 E 6404 90 .24 67 89 48 83 O0 O0 1741 49 N 5514 13 E 5782 60 N 72 28 E 1776 93 N 5627 42 E 5901 30 N 72 29 E 1810 75 N 5741 65 E 6020 41 N 72 30 E 1845 66 N 5853 17 E 6137 27 N 72 30 E 1883 36 N 5965 33 E 6255 58 N 72 29 E 1923 68 N 6078 76 E 6375 88 N 72 26 E 1933 66 N 6106 60 E 6405 43 N 72 26 E R£CE!VED AUG £ 6 1998 Alaska Oil & Gas COns. Cornmissior; Anchorage ARCO ALASKA, INC. AGI-7 PRUDHOE BaY NORTH SLOPE, ALASKA MARKER GCT LAST READING 'FD COMPUTATION DATE: 30-JUN-g3 PAGE 8 DATE OF SURVEY: 08-JUN-93 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: J. CRYER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 2291' FSL & 2515' FEE, SEC36 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 10910.10 8406.59 8357.59 1906.38 N 6030.54 E 11015.00 8473.48 8424.48 1933.66 N 6106.60 E ARCO ALASKA, INC. aGI-7 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER TD COMPUTATION DATE: 30-JUN-93 PAGE 9 DATE OF SURVEY: 08-JUN-93 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: J. CRYER · ~~~ STRATIGRAPHIC SUMMARY ~~~ SURFACE LOCATION = 229I' FSL & 2515' FEL, SEC36 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11015.00 8473.48 8424.48 1933.66 N 6106.60 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 11015.00 8473.48 8424.48 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 6405.43 N 72 26 E 2 .41.aS~.O#.~ Gas Cons. Con~rnissio~ 21.Chorage DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FIELD PRUDHOE BAY WELL AGI-7 COUNTRY USA RUN ONE DATE LOGGED 08 - JUN - 93 DEPTH UNIT FEET RECE ¥E.D 6 t 199 Alaska Oil & Gas Cons. oommissiOt~ Anchorage REFERENCE 93264 All Interpretations are opinions based on Inferences from elecfl'lcal or other measurements and we cannot, and do not guarantee the accuracy or correctness of any Interpretations. and we shall not, except In the case of gross or wllfull negligence on our part, be liable or responsible for any loss, costa, damages or expenses Incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees. These Interpretations are also subject to our C:~eneral Terms and Conditions as set out In our current price ~chadule. I/ELL: AGZ-7 (2291' FSL, 2515' FEL, SEC 36, T12N, R14E) HORZZONTAL PROdECT~ON NORTH 8000 REF 6000 4OOO 2000 -2000 -4000 __ -6000 SOU~H -8000 -4000 -2000 0 2000 SCALE = 1 / 2000 IN/FT 4000 6000 8000 10000 12000 WEST EAST h'ELL' AG[-7 i (2291' FSL, 2515' FEL, SEC 36, T12N, R14E) VERTICAL PROdECT~ON -4000 -2000 0 0 2000 4000 6000 8000 10000 12000 .~..~ : ....... ~..~..: ..... ~.,,~..,~...~ ...... ~ ...... :...~...:...:...~..~ .... : ...... :...~ ..... ~...~...~...~...~...~...~...~ ~...~...~..~ .... ~...:...:..~ .... ~...~..~...~...~...~...~..~...: .... ~.~.~ ....... :,.:,;, :::: :::: :::: :::: :::: :::: :::: :::: ::;: :;:: :::: :::: :::: :,:: :, : .:: : .... : :: :::. : . :::: ::::. ::.: :::: :::: :::: :::: :::: :::; ii!.! i.~i ..... ?.i...i.i ~i..i...i i.i.i..! i.!i...i..~.ispo,)i..i..i..i i...ii.i i.i...i...i .... i...i...ii ..... ?.i..i..i i?.i..! ..... :.i!.i:i!:! ~i~ ~ ; ~ : : ; i i i i ; ; kid i : ; ; : i ; ; i ; i ~ : : ~ : ; i i ; ; ; ; ; : : ~ ; : : : ~ : · : : . ..... .......... .... 80.OQ : .; ................................ :: :.:: :::: :::: .::. .:,. :::: : : ::.: : .. : :: : :: : ::;: :~:: :::. .:. ;::: : : ::::~ , .::~..!~:--i.:..~ :-: ::.: .... :::.: ::.:-: ...... :-:.::::.:-: ;-: ::..;-.: ...... : ...... ; ~.; i i i ! .... i i ! i !-i ~ ! .... !'"! !"i ~'.~ t'-'! i'f .... !'!'!'-i ! ~ ~ ! ,'iI ' : ' : ' I I : : ' ' ~.~ .......... ~-i ...... i-..i..-i...: !.-.!.-.i..-i ...... !ii..-i-.i-.-i--.!--i--.! i---i.-i--i..i.!.-i.-.i i..i...i..i ....... !...!..-i.i ...... i..i...!..-! ..... i.;..-~...! !:,~ ::., ,!,:. : .... i-ii.i .... i-li! :"~il '~-~'-'~'i .ii"~--~'-~-~'ii .... i'i~'i" ;i'i':" ~i!"i' ii":..: '~'-ii-i ~i:'i : ..... ::,: .:~: .... :--+-i-: .:-:.: ::..~i i!..:.i~!--~ iii.~ ~:'!'i'':!!! :!':' !';"i'";. ::-::'~!::~ -::~: : ::i i .:!l !.'~ .:' ; i i i :'! i .... i"i"Ti" : ~"i'i' T';'i'i ..... i'i i'T' 'i'"i i'i .... i";'T'i' 'i'"i'i i "7['i i' "i"7i ! i"i'i"i ; i'. :, · :':'! ?!'"!'!' i"':"!":'''!''I''!'!'!!':!' !i,': .... ,: i ...... ?""!": :!: i : i : i ~".i .... !"!'"~"i i i'~ i"! i'i -'i'!-'i"'! .... !--'!"!'i "i'"i'-i'i !"~.i ! "i-"i-i i ..... i"i--i'i .... !...: i-i. ! i.-:.! ..: ..... : .. i i ; i ! ; ! i i i .... i-..i.-.h.i.i...i.i-i, i-~ i--.; i.!.i..i F.!-.F.i .... i i i..i i-!.!..i ..... i-~..i-! F.!-i..i ..... i..!..i-.i i.?-i-.~ .i; ; .... .. :=,:. ::: ::: ::: :::: :::: :::: ::: :=:: .::: :::: :.. :: ' i i ' ~ ! i i : ! ' ' : ! i i ............. ~ : ......... ~ ~ ~,!~: V. :~.~ i ;..;.;.; . i~ ::-~i~ ;~:i ~i: ~i~ ~ii~ i;:. ~ ...... : ., ..................... : · ; ..... ~ i i...i..-i...i.. ; .... : ..... i..i...i..i .i i..i..i ..: i.i.i. ~.i.~.i i..i.i.i.i..:..i.i ..... i.i.i. ..i.i.i i ..... .i_~__:_ i iii'~"i'!'i'i i'ili2~_o(~LLL_!~.ii,L_!ii! 'i!ii i:!i ii.i.~_iAiJ~i~199~ 'i: .................... ~ !!!-! .... !"!-'-t"! .... !'-!-!!'~'!!''!--!~! ! !i''!"!"!'!!! ~''' !iii i.!i?:':i::i:::i'i' i:.i:i!: i!!:i iiii i!!'i ;!!i !ii! !!!i ~askaoil&~tas~COns:Conl~iss~°' ~ ! 73.00 Z w.- II PROJECTION ON VERTICAL PLANE 253.00 73.00 SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1 / 2000 IN/FT ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 1-28 ~'~ ~-18-93 3-25A ~?'~3 6-17-93 3-31 ~ V-?z 6-16-93 3-32 ~ ~/~l 7 6-15-93 3-33 t ¥~ ~,o 6-16-93 4-8 ?~-f~ 6-11-93 5-14 ??-~ 6-12-93 6-2~ ~ .r.6-6-93 6-2~ ~ ~ 16-10-93 7-25 ~I-Y ~ 6-6-93 9-44 ~ ~ - ~ z~-6-93 11-18 f/,'~z6-7-93 14-6 ~ l- ~oY6-8-93 14-8 ?~-/,~ 6-10-93 14-13 ~]~']d 16-13-93 14-15 tl'~ 6-8-93 16-4A tz'1¢~6-9-93 16-17 ~" zz~6-14-93 16-31 ~'~{ 6-7-93 17-4 ~~ 6-14-93 AGI-5 5~'~-6-13-93 AGI-6 ~'d~ 6-14-93 AGI-7 ~ _6-8-93 AGI-7 } {~ ~-t6-15-93 AGI-7 6-17-93 Prod Profile Completion Record Plug Setting Record Plug Setting Record Plug Setting Record Perf Record TBG Cutter Record Leak Detect Legit Detect Perf Record Perf Record Production Log PITS /Lesk Detect Leak Detect Inj Profile Completion Record Prod Profile Perf Record Production Log Completion Record Completion Record Completion Record Perf Record Run 1, 5" Sch R~_m 1, 5" Sch R~m 1, 5" Sch R~m 1, 5" Sch R~m 1, 5" Sch R-n 1, 5" Sch R~m 1, 5" Sch Run I 2" Sch Run 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Rim 1, 5" Sch Run 1, 5" Sch R~_m 1, 2"&5" Sch Rim 1, 5" Sch Rim 1, 5" Sch R~m 1, 1"&5" Sch Rim 1, 2"&5" Sch Rim 1, 5" Sch Run 1, 5" Sch R~m 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch R~m 1, 5" Sch R~_m 1, 5" Sch AGI-8 q'~-"3 ~/6-9-93 GR/CCL Run 1, 5" Sch AGI-9~ ~1 6-9-93 GR/(X~ R~_m 1, 5" Sch AGI-9i -~/~{ 6-17-93 Pe~ Record R~ 1, 5" Sch ~e~e sl~ ~d retm~~ch~~ .cetpt ~~ .... - RECEIVED S~~ /// ~~ ~ ATO- 1529 ~~ 93073 : ~ 0 ~ *~e ~~t ~9 ~ ~32 ~ ~21141~. ~e c~ct ~H ~e for ~ l~ ~ ~2~ ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO OPEN HOLE FINAI~ 3-18A~ ~/~4/10-17/93 MWD: DPR/GR R,,n~ 1-3, 2~'&5'~MD 3-18A/ 4/10-17/93 MWD: DPR/GR R~r~S 1-3, 2"&5"TVD * ~-°',-~ r, 6-z3-93 Lw~: CnN mm Z, ~'~' * 5-3A3~ ~'/ 6-13-93 LWD: CDR Rim 1, 2'&5" * 5- 5~ / 6-13-93 LWD: CDN N/F Run 1, 2'&5' * 5-3A ~ -t-- 6-13-93 LWD: CDN N/F OverlayRun 1, 2'&5" 5-3Afl 6-13-93 LWD: CDN Run 1, 2"&5"1'VD 5-3A ~-13-93 LWD: CDR Run 1, 2'&5"TVD ** AGI-5-9 /6 ~ ~4- 22 ~O. 99 33 DLL/GR/SP Run 1, 2'&~' ** AGI-5~ 4-20-93 BH Profile Run 1, ** AGI-6'~ o~ 4-25-93 DLL/GR/SP Run 1, ~'&ff' ** AGI-6/ ~ 4-25-93 BHCA/GR Run 1, 2'&~' ** AGI-6 ~ ~'~ 4-25-93 BH Profile l~m 1, AGI-6] .2/11-13/93 DPR/GR Runs 6&7, ~'&5'~D AGI-6r a./{ 2/11-13/93 DPP,/GR Runs 6&7, 2'&~'rVD AGI-7~¢4~''~ 2/154/28/93 DPR/GR Rtms 6&7, 2'&I~D AGI-7" ' /~ 2/154/28/93 DPR/GR R~_m_s 6&7, 2'&[~'FVD A~i.8~4~' ~ 3/~-6/93 -~/C~ ~un 4. AGI-8' _ ~{ 3/5-6/93 DPR/GR Run 4, 2~'&5"FVD AGI-9~ ~/'~ 3/9-5/7/93 DPR/GR Runs 4&5, AGI-9° 3/9-5/7/93 DPR/GR Runs 4&~, 2'&~'rVD AGI- 10 ~~ 3/24-28/93 DPR/GR AGI-10 3/24-28/93 DPR/C~ Rims 3&4, 2'&5'~/ID Runs 3&4, :~'&~'I'VD sign and re~ched~ as receipt of data~ ATO-1529 Trans# 93070 # CENTRAL FILES # CHEVRON #D&M # BPX # STATE OF ALASKA # MOBIL ,JUL ~ 0 199~ Alaska Oil & (las C,o~l~t'~~ FILES Auch°r~LINT CHAPMAN ~ E~ON t TEMCO BHI BHI Sch Sch Sch Sch Sch Sch Atlas Atlas Atlas Atlas Atlas Atlas Teleco Teleco BHI BHI BHI BHI BHI BHI BHI BHI * The correct n~me for this well is 5-3A, and the logs are finals. ?*::' These logs are revised ~_n~! prints, please replace previous logs. /7 ARCO Alask~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-30-93 REFERENCE: ARCO ~-1-9 4-16-93 1-20~'' ) 0c/p 4-11-93 -- 1-16 4-~3-93 ~3~?'~.--- Z'E. 4-9-93 4-10-93 --- 3-10 4-1-93 3-31 ~q-~Z~ 4-11-93 _.4-19 4-8-93 9-5A~-~-te 4-1-93 '~-28~ _ 44-93 1~1~-~ ~1~93 AGI~ ~93 AGI-7 ~93 Inflatable IBP Set_ting Run 1, Dual Burst TDTP (Borax) Run 1, Production l~_m 1, Static Press/Temp Run 1, Perf Record Run 1, Production Run 1, 2'&5' Static Pressure/Temp Run 1, Perf Record l~m 1, SHt,/GR/C~ R,_m 1, ~" PFC/CCA, (packer Setting) Run 1, fY' D~,_s! Burst TDTP/Temp (Borax) Run 1, Production Run 1, Dual Burst TDTP (Borax) Run 1, Production Run 1, Sm,/GR/CC[, l~m 1, S~L/GR/CC~ lhm L Please sign and return tl~ attached copy a~ receipt of data. ,EC iVE, Have A Nice Day! Sonya Wallace ATO-1529 # CENTRAL FILES # Ct~VRON D&M # CLINT CHAPMAN # EXXON MARATHON # MOBIL RECEIVED . APPROVED "×" l/AY 0 ro 1993 Tra_ns# 9305 - # PI-HL~ PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO Sch Sch Sch Sch Sch Atlas Sch' Sch Sch Atlas Atlas Sch. Sch Sch Sch Sch Atlas Atlas Atlas ' ~ STATE OF ALASKA A~KA OIL AND GAS CONSERVATION COMMIS,.,,..,N · ~.-~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown x Stimulate Plugging Perforate ~ Pull tubing Alter casing Repair well Other /<['~.. 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2291' NSL, 2515'WEL, SEC. 36, T12N, R14E At top of productive interval N/A At effective depth N/A At total depth 1196'SNL, 2170'WEL, SEC. 31, T12N, R15E 5. Type of Well: Development, ,, Exploratory Stratigraphic Service X 6. Datum elevation (DF or KB) KBE -- 51' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number AGI-7 9. Permit number/approval number 93-27 10. APl number 50- 029-22343 11. Field/Pool Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10326 feet 8016 feet N/A feet N/A feet Casing Length Size Structural Conductor 76' 20" Surface 3899' 13-3/8" Intermediate Production 10268' 9-5/8" Liner Perforation depth: measured None Plugs (measured) Junk (measured) Cemented 281 cu fl Arcticset 2604 cu ft "F"/460 cu fl "G" 460 cu ft Class "G" Measured depth 106' 3937' 10306' True vertical depth 106' 3495' 8003' true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure REEE]VED Alaska 0il & Gas Cons. C0m~tss'to~ 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaoe Production or Iniection Data -- OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil __ Gas Suspended Service Apex Gas Injector 17. I hereby certify that the foregoir~ is true and correct to the best of my knowledge. Sicjned /~. ~ (.. TitleDrillin~lEn~linoerSupervisor Form 10-404 Rev 06/15/8~("~'~ ~' SUBMIT IN DUPLICATE~_..> BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: AGI 7 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 02/14/93 11:00 SPUD: 02/15/93 12:15 RELEASE: 02/25/93 09:00 OPERATION: DRLG RIG: AUDI 2 WO/C RIG: 02/15/93 ( 1) TD: 110'( 0) 02/16/93 (2) TD: 1233' (1123) 02/17/93 ( 3) TD: 3467' (2234) 02/18/93 (4) TD: 3945' ( 478) 02/19/93 (5) TD: 4615' ( 670) 02/20/93 ( 6) TD: 6975' (2360) 02/21/93 (7) TD: 8008' (1033) 02/22/93 (8) TD: 8502' ( 494) 02/23/93 (9) TD: 9684' (1182) MIX SPUD MUD. MW: 8.5 VIS: 0 SKID RIG. RIG ACCEPTED @ 23:00 HRS, 2/14/93. MIX SPUD MUD. DRLG. MW: 8.8 VIS:195 P/U BHA. SPUD WELL @ 12:15 HRS, 2/15/93. DRLG TO 1233' DRLG. MW: 9.1 VIS:135 DRLG F/ 940'-2533'. CIRC. SHORT TRIP TO 850'. DRLG F/ 2533'-3467' N/D FLOW LINE. MW: 9.3 VIS: 98 DRLG TO 3945'. CBU. SHORT TRIP TO 2349'. CIRC. POOH. L/D BHA. RIH W/ 13-3/8" CSG. CIRC. R/U HOWCO. CMT CSG. DISP W/ MUD. R/D HOWCO. L/D LAND JT. N/D FLOW LINE. DRLG. MW: 9.0 VIS: 37 N/D DIVERTER. TOP JOB W/ 104 SX CMT. N/U BOPE. TEST BOPE. RIH W/ BHA TO 3857' TEST CSG. OK. DRLG FLOAT EQUIP, CMT F/ 3857'-3945'. DRLG NEW HOLE F/ 3945'-4985'. CBU. LOT (12.8 PPG EMW). CIRC. DRLG F/ 3985'-4120'. POOH. CAHNGE MWD. RIH. DRLG F/ 4120'-4615' DRLG. MW: 9.4 VIS: 38 DRLG TO 5152'. CBU. SHORT TRIP TO 4120'. DRLG F/ 5152'-6183'. CBU. SHORT TRIP TO 4403' DRLG F/ 6183'-6975'. DRLG. MW: 9.7 VIS: 39 DRLG TO 7317' CBU. POOH. CHANGE BIT. RIH. REAM F/ 6903'-7317'. DRLG TO 8008'. DRLG. MW: 9.7 VIS: 40 DRLG TO 8382'. CBU. POOH. CHANGE BHA, BIT. RIH. REAM F/ 8252'-8382' DRLG F/ 8382'-8502' RIH. MW:10.0 VIS: 41 DRLG TO 9373'. CBU. SHORT TRIP TO 8382' DRLG TO 9684' LOST 1700 PSI POOH. FOUND WASHOUT. RIH. RECEIVED IVIAR 1 7' 199; .A~aska Oil & f..~s OOn'~r LUm?~iSSiOi"~ WELL : AGI 7 OPERATION: RIG : AUDI 2 PAGE: 2 02/24/93 (10) TD:10326' ( 642) 02/25/93 (11) TD: 10326' ( 0) 02/26/93 (12) TD: 10326' ( 0) POOH. MW: 9.9 VIS: 41 DRLG F/ 9684'-10233'. POOH TO LOOK FOR WASHOUT. DRLG F/ 10233'-10326'. CBU. SHORT TRIP TO 9713'. CIRC. POOH. N/D BOPE. MW: 8.5 VIS: 0 POOH. L/D BHA. RIH W/ 9-5/8" CSG. WASH TO 10306'. PUMP 20 BBLS PREFLUSH, 50 BBLS SPACER, 82 BBLS 'G' CMT. DISP W/ SEAWATER. BUMP PLUG W/ 2000 PSI. L/D CSG TOOLS. INSTALL PACKOFF. INJECT 200 BBLS MUD DN ANNULUS. RIH TO 2000' DISP WELL W/ DIESEL. POOH. F/P ANNULUS. N/D BOPE. RIG RELEASED. MW: 8.5 VIS: 0 N/D BOPE. N/U TREE. TEST TREE. RIG RELEASED @ 09:00 HRS, 2/25/93. SIGNATURE: (drilling superintendent) DATE: 'F 995 Aiaska Oil & ~as Cons. Commissio~ Anchorage Baker Hughes company 6324/6116 Nielson Way · Anchorage, AK 99518 Phone: (907) 563-3269/Fax: (907) 563-5865 Phone: (907) 562-2646/Fax: (907) 561-1358 EASTMAN TELECO MWD SURVEY APEX GAS INJECTION #7 APEX GAS INJECTION PAD Eastman Teleco appreciates the opportunity to provide our services. Please find attached a copy of the directional surveys in each of the following formats: · No Interpolation · Interpolated 100' MD · Interpolated 100' TVD MAR Alaska Oil & Gas Cons. Commission ~nchorags Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Location Date Surveyed Survey Performed By : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : : Feb. 24, 1993 : : Scott Burkhardt This survey is correct to the best of my knowledge and is supported by actual field data. . .. COMPANY REPRESENTATIVE MEASURED DEPTH NO INTERPOLATION Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Apex Gas.~Injection 7 Location : Apex Gas Injection Pad : North Slope, Alaska : Date Feb. 24, 1993 Filename : 1185-450 No Interpolation Plane of Vertical Section : 73.2° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.16°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-7 +0 ° 0' 0' ' (T) Eastman Teleco Client Well Name Location : Prudhoe Bay Drilling Group : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : Page 1 of 2 Date Feb. 24, 1993 Filename : 1185-450 No Interpolation MD C~L INC DIR TVD VS LAT DEP ft ft deg deg ft ft ft ft 0 0 0.0 0.0 0 0 0 0 422 422 0.1 124 . 4 422 0 -0 0 601 179 1.3 76.9 601 2 0 2 782 181 4.5 65.3 782 11 4 11 969 187 6.4 72.0 968 29 10 27 D'LEG °/100 0.0 0.0 0.7 1.8 1.1 187 7.7 72.3 1153 187 7.7 69.9 1339 189 9.8 71.6 1526 187 11.4 74.1 1709 188 17.4 72.7 1891 1156 1343 1532 1719 1907 BUILD o/loo 0.0 0.0 0.7 1.8 1.0 TURN o/lOO 0.0 29.5 -26.5 -6.4 3.6 52 17 49 0.7 0.7 0.2 77 25 73 0.2 0.0 -1.3 106 34 100 1.1 1.1 0.9 140 45 133 0.9 0.9 1.3 187 '58 178 3.2 3.2 -0.7 2089 2281 2468 2655 2842 182 22.9 70.6 2062 192 25.8 70.2 2237 187 30.2 70.9 2402 187 36.0 72.7 2559 187 38.1 70.2 2708 250 78 237 3 329 104 312 1 416 134 395 2 518 165 492 3 631 201 598 1 .0 .5 .4 .1 .4 3.0 1.5 2.4 3.1 1.1 -1.2 -0.2 0.4 1.0 -1.3 3029 3214 3402 3588 3777 187 41.5 71.6 2852 185 45.8 75.2 2985 188 45.7 73.4 3117 186 44.7 70.9 3248 189 45.0 69.5 3382 751 240 711 1 878 277 834 2 1013 313 963 0 1145 354 1089 1 1278 399 1214 0 .9 .7 .7 .1 .5 1 2 -0 -0 0 .8 .3 .1 .5 .2 0.7 1.9 -1.0 -1.3 -0.7 388O 4148 4430 4712 4993 103 45.2 70.9 3454 268 44.4 70.2 3645 282 44.2 70.2 3846 282 43.4 71.6 4050 281 43.8 71.3 4253 1351 423 1283 1539 486 1461 1736 553 1646 1931 617 1831 2125 679 2015 .0 .4 .1 .4 .2 0 -0 -0 -0 0 .2 .3 .1 .3 .1 1.4 -0.3 0.0 0.5 -0.1 5274 5555 5836 6118 6398 281 45.3 70.2 4454 281 45.2 71.3 4652 281 44.5 72.7 4851 282 44.6 72.7 5052 280 44.9 74.5 5251 2322 744 2201 2521 809 2389 2719 8.71 2578 2917 929 2766 3114 985 2955 .6 .3 .4 .0 .5 0 -0 -0 0 0 .5 .0 .2 .0 .1 -0.4 0.4 0.5 0.0 0.6 6679 6964 7240 7521 7803 281 45.5 72.0 5449 285 45.4 73.8 5649 276 46.7 74.1 5840 281 45.6 74.1 6035 282 45.0 72.3 6233 3313 1043 3146 3517 1102 3340 3715 1157 3531 3918 1213 3726 4118 1271 3918 0.7 0.5 0.5 0.4 0.5 0 -0 0 -0 -0 .2 .0 .5 .4 .2 -0.9 0.6 0.1 0.0 -0.6 8085 8366 8646 8928 9211 282 43.2 70.9 6436 281 40.8 73.8 6644 280 42.2 72.3 6854 282 43.6 73.8 7061 283 45.0 73.8 7263 4314 1333 4104 4502 1390 4284 4688 1444 4461 4880 1500 4645 5077 1555 4834 0.7 1.1 0.6 0.6 0.5 -0 -0 0 0 0 .6 .9 .5 .5 .5 -0.5 1.0 -0.5 0.5 0.0 Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Apex Gas Injection 7 Location : Apex Gas Injection Pad : North Slope, Alaska : Page 2 of 2 Date Feb. 24, 1993 Filename : 1185-450 No Interpolation MD C~L INC DIR TVD ft ft deg deg ft 9489 278 46.3 73.8 7458 9768 279 47.5 72.7 7648 10053 285 49.0 73.4 7838 10263 210 49.9 73.1 7975 VS ft 5276 5480 5693 5852 LAT ft 1610 1669 1731 1777 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 5025 0.5 0.5 0.0 5220 0.5 0.4 -0.4 5424 0.6 0.5 0.2 5577 0.4 0.4 -0.1 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 5853 ft 72.3° MEASURED DEPTH 100' INTERPOLATED Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Apex Gas Injection 7 Location : Apex Gas Injection Pad : North Slope, Alaska : Date Feb. 24, 1993 Filename : 1185-450 Interpolated 100 ft of MD Plane of Vertical Section : 73.2° Latitude & Departure relate to : SLOT CEN.TER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.16°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-7 +0° 0' 0'' (T) Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling Group : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : Page 1 of 3 Date Feb. 24, 1993 Filename : 1185-450 Interpolated 100 ft of MD MD ft 0 100 200 300 400 50O 600 700 8OO 900 C~L INC DIR TVD ft deg deg ft 0 0.0 0.0 0 100 0.0 29.5 100 100 0.0 59.0 200 100 0.1 88.4 300 100 0.1 117.9 400 100 0.6 103.7 500 100 1.3 77.2 600 100 3.1 70.6 700 100 4.7 65.9 800 100 5.7 69.5 899 1000 100 6.6 72.0 999 1100 100 7.3 72.2 1098 1200 100 7.7 71.7 1197 1300 100 7.7 70.5 1296 1400 100 8.3 70.4 1395 1500 100 9.4 71.3 1494 1600 100 10.4 72.5 1592 1700 100 11.2 73.8 1691 1800 100 14.0 73.5 1788 1900 100 17.2 72.8 1885 2000 100 20.2 71.6 1979 2100 100 23.1 70.6 2072 2200 100 24.6 70.4 2163 2300 100 26.2 70.3 2254 2400 100 28.6 70.6 2342 2500 100 31.2 71.2 2429 2600 100 34.3 72.2 2513 2700 100 36.5 72.1 2595 2800 100 37.6 70.8 2674 2900 100 39.2 70.6 2753 3000 100 41.0 71.4 2829 3100 100 43.2 73.0 2903 3200 100 45.5 74.9 2975 3300 100 45.8 74.4 3045 3400 100 45.7 73.4 3115 3500 100 45.2 72.1 3186 3600 100 44.7 70.8 3256 3700 100 44.9 70.1 3327 3800 100 45.0 69.8 3398 3900 100 45.1 70.8 3469 VS ft 0 0 0 0 0 1 2 7 13 23 33 45 58 71 86 101 118 137 160 185 219 254 295 338 384 434 488 545 606 668 i 732 800 869 940 1011 1082 1153 1224 1294 1365 LAT ft 0 -0 -0 -0 -0 -0 0 2 4 8 11 15 19 23 28 DEP D ' LEG BUILD TURN o ft °/100 °/100 /100 0 0.0 0.0 0.0 0 0.0 0.0 29.5 0 0.0 . 0.0 29.5 0 0.0 0.0 29.5 0 0.0 0.0 29.5 1 0.5 0.5 -14.2 2 0.8 0.7 -26.5 7 1.8 1.8 -6.6 12 1.7 1.6 -4.6 21 1.1 1.0 3.6 31 1.0 0.9 2.5 43 0.7 0.7 0.2 55 0.4 0.4 -0.5 68 0.2 0.0 -1.3 81 0.6 0.6 -0.0 33 96 1.1 1.1 0.9 38 112 1.0 0.9 1.2 44 130 0.9 0.9 1.3 50 152 2.7 2.7 -0.3 · 58 176 3.2 3.2 -0.7 68 79 93 107 123 139 156 174 193 213 234 254 .27.4 293 313 208 3.1 3.0 -1.1 241 2.9 2.9 -1.0 280 1.5 1.5 -0.2 320 1.7 1.7 -0.1 364 2.4 2.4 0.4 411 2.6 2.6 0.6 463 3.1 3.1 1.0 517 2.2 2.2 -0.1 574 1.4 1.1 -1.3 633 1.5 1.5 -0.1 694 1.9 1.8 0.7 758 2.4 2.2 1.6 825 2.7 2.3 1.9 893 0.5 0.3 -0.6 962 0.7 -0.1 -1.0 334 1030 1.1 -0.5 -1.3 356 1097 1.0 -0.5 -1.3 3.80 1163 0.5 0.2 -0.7 404 1230 0.2 0.2 -0.3 428 1296 0.7 0.1 1.0 Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling Group : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : Page 2 of 3 Date Feb. 24, 1993 Filename : 1185-450 Interpolated 100 ft of MD MD ft 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5OOO 5100 5200 5300 5400 55OO 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 CkL INC DIR TVD ft deg deg ft 100 44.8 70.6 3540 100 44.5 70.3 3611 100 44.4 70.2 3682 100 44.3 70.2 3753 100 44.2 70.2 3825 100 44.0 70.5 3897 100 43.7 71.0 3969 100 43.4 71.5 4041 100 43.5 71.5 4114 100 43.7 71.4 4186 100 43.8 71.3 4258 100 44.4 70.9 4330 100 44.9 70.5 4401 100 45.3 70.3 4472 100 45.3 70.7 4542 100 45.2 71.1 4613 100 45.1 71.5 4683 100 44.8 72.0 4754 100 44.6 72.5 4825 100 44.5 72.7 4896 100 44.6 72.7 4968 100 44.6 72.7 5039 100 44.7 73.2 5110 100 44.8 73.9 5181 100 44.9 74.5 5252 100 45.1 73.6 5322 100 45.3 72.7 5393 100 45.5 72.1 5463 100 45.5 72.8 5534 100 45.4 73.4 5604 100 45.6 73.8 5674 100 46.0 73.9 5743 100 46.5 74.1 5812 100 46.5 74.1 5882 100 46.1 74.1 5951 100 45.7 74.1 6020 100 45.4 73.6 6090 100 45.2 73.0 6161 100 45.0 72.3 6231 100 44.4 71.8 6303 VS ft 1435 1506 1576 1645 1715 1784 1854 1923 1992 2061 2130 2200 2270 2340 2411 2482 2553 2623 2694 2764 LAT ft 452 475 499 522 546 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 1363 0.4 -0.3 -0.3 1429 0.4 -0.3 -0.3 1495 0.2 -0.2 -0.1 1561 0.1 -0.1 0.0 1627 0.1 -0.1 0.0 3542 1~09 3365 0.3 0.1 0.4 3614 1129 3435 0.5 0.5 0.1 3686 1149 3504 0.5 0.5 0.1 3758 1169 3573 0.1 -0.0 0.0 3831 1189 3642 0.4 -0.4 0.0 3903 1209 3712 0.4 -0.4 0.0 3974 1229 3780 0.4 -0.3 -0.5 4045 1249 3848 0.5 -0.2 -0.6 4116 1270 3916 0.5 -0.2 -0.6 4186 1292 3982 0.7 -0.6 -0.5 3186 1006 3025 0.7 0.2 -0.9 3257 1026 3093 0.7 0.2 -0.9 3328 1047 3161 0.4 0.2 -0.6 3400 1068 3229 0.5 -0.0 0.6 3471 1089 3297 0.5 -0.0 0.6 2834 905 2687 0.0 0.0 0.0 2904 926 2754 0.0 0.0 0.0 2975 946 2822 0.4 0.1 0.5 3045 966 2889 0.5 0.1 0.6 3116 985 2957 0.4 0.1 0.6 680 2019 0.2 0.2 -0.1 703 2085 0.6 0.5 -0.4 7~26 2152 0.6 0.5 -0.4 750 2218 0.4 0.4 -0.2 773 2285 0.3 -0.0 0.4 796 2352 0.3 -0.0 0.4 819 2419 0.3 -0.1 0.4. 841 2486 0.4 -0.2 0.5 863 2553 0.4 -0.2 0.5 884 2620 0.1 -0.1 0.2 569 1692 0.3 -0.2 0.3 592 1758 0.4 -0.3 0.5 614 1823 0.4 -0.3 0.5 636 1888 0.1 0.1 -0.0 658 1954 0.2 0.1 -0.1 Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling Group : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : Page 3 of 3 Date Feb. 24, 1993 Filename : 1185-450 Interpolated 100 ft of MD MD C~L INC DIR TVD ft ft deg deg ft 8000 100 43.7 71.3 6375 8100 100 43.1 71.1 6447 8200 100 42.2 72.1 6521 8300 100 41.4 73.1 6595 8400 100 41.0 73.6 6670 8500 100 41.5 73.1 6745 8600 100 42.0 72.5 6820 8700 100 42.5 72.6 6894 8800 100 43.0 73.1 6967 8900 100 43.5 73.7 7040 9000 100 44.0 73.8 7112 9100 100 44.5 73.8 7184 9200 100 44.9 73.8 7255 9300 100 45.4 73.8 7326 9400 100 45.9 73.8 7395 9500 100 46.3 73.8 7465 9600 100 46.8 73.4 7533 9700 100 47.2 73.0 7602 9800 100 47.7 72.8 7670 9900 100 48.2 73.0 7736 10000 · 100 48.7 73.3 7803 10100 100 49.2 73.3 7869 10200 100 49.6 73.2 7934 10263 63 49.9 73.1 7975 VS ft 4255 4324 4391 4458 4525 · LAT ft 1314 1336 1356 1376 1396 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 4048 0.7 -0.6 -0.5 4114 0.7 -0.7 -0.3 4178 1.1 -0.9 1.0 4241 1.1 -0.9 1.0 4305 0.5 -0.4 0.5 o 4591 14'16 4368 0.6 0.5 -0.5 4657 1435 4432 0.6 0.5 -0.5 4725 1454 4496 0.5 0.5 0.0 4793 1474 4561 0.6 0.5 0.5 4861 1494 4626 0.6 0.5 0.5 4930 1514 4693 0.5 0.5 0.1 5000 1533 4760 0.5 0.5 0.0 5070 1553 4827 0.5 0.5 0.0 5141 1573 4895 0.5 0.5 0.0 5213 1593 4964 0.5 0.5 0.0 5284 1613 5033 0.5 0.5 -0.0 5357 1634 5103 0.5 0.4 -0.4 5430 1655 5173 0.5 0.4 -0.4 5504 1676 5243 0.5 0.5 -0.2 5578 1698 5315 0.6 0.5 0.2 5653 1719 5386 0.6 0.5 0.2 5728 1741 5458 0.5 0.5 0.1 5804 1763 5531 0.4 0.4 -0.1 5852 1777 5577 0.7 0.7 -0.2 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 5853 ft 72.3° TRUE VERTICAL DEPTH 100' INTERPOLATED Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Apex Gas Injection 7 Location : Apex Gas Injection Pad :North Slope, Alaska : Date Feb. 24, 1993 Filename : 1185-450 Interpolated 100 ft of TVD Plane of Vertical Section : 73.2° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000'ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.16°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-7 +0° O' O' ' (T) Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling Group : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : Page 1 of 3 Date Feb. 24, 1993 Filename : 1185-450 Interpolated 100 ft of TVD MD ft 0 100 200 30O 400 5OO 600 700 8OO 901 1001 1102 1203 1304 1405 1506 1608 1709 1813 1916 2023 2131 2240 2352 2466 2585 2707 2832 2962 3096 3235 3378 3520 3662 3803 3944 4085 4225 4365 4504 C~L INC DIR TVD ft deg deg ft 0 0.0 0.0 0 100 0.0 29.5 100 100 0.0 59.0 200 100 0.1 88.4 300 100 0.1 117.9 400 100 0.6 103.7 500 100 1.3 77.2 600 100 3.1 70.5 700 100 4.7 66.0 800 100 5.7 69.6 900 101 6.6 72.1 1000 101 7.3 72.2 1100 101 7.7 71.7 1200 101 7.7 70.4 1300 101 8.4 70.5 1400 101 9.5 71.4 1500 102 10.4 72.6 1600 102 11.3 74.0 1700 103 14.4 73.4 1800 104 17.7 72.6 1900 107 20.9 71.4 2000 108 23.5 70.5 2100 110 25.2 70.3 2200 112 27.5 70.5 2300 113 30.1 70.9 2400 119 33.8 72.0 2500 122 36.6 72.0 2600 125 38.0 70.3 2700 130 40.3 71.1 2800 134 43.1 72.9 2900 139 45.8 75.0 3000 143 45.7 73.6 3100 142 45.1 71.8 3200 141 44.8 70.4 3300 141 45.1 69.9 3400 141 45.0 70.7 3500 141 44.6 70.4 3600 140 44.3 70.2 3700 140 44.2 70.2 3800 139 44.0 70.6 3900 VS ft 0 0 0 0 0 1 2 7 13 23 33 45 58 72 87 102 120 138 163 190 227 267 312 362 415 480 549 625 708 797 893 996 1097 1197 1296 1396 1495 1593 1691 1787 LAT ft 0 -0 -0 -0 -0 -0 0 2 4 8 11 15 19 23 28 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 0 0.0 0.0 29.5 0 0.0 0.0 29.5 0 0.0 0.0 29.5 0 0.0 0.0 29.5 1 0.5 0.5 -14.2 2 0.8 0.7 -26.5 7 1.8 1.8 -6.6 12 1.7 1.6 -4.6 21 1.1 1.0 3.6 31 1.0 0.9 2.5 43 0.7 0.7 0.2 55 0.4 0.4 -0.5 68 0.2 0.0 -1.3 82 0.7 0.7 0.1 33 96 1.1 1.1 0.9 39 113 0.9 0.9 1.2 44 131 0.9 0.9 1.3 51 155 3.0 3.0 -0.6 59 181 3.2 3.2 -0.8 71 84 99 116 133 153 175 199 226 2'54 281 309 339 371 405 438 472 5O5 538 570 216 3.0 3.0 -1.2 253 2.5 2.4 -0.8 ,.~ 296 1.5 1.5 -0.2 343 2.0 2.0 0.2 393 2.4 2.4 0.4 455 3.1 3.1 1.0 521 2.3 2.3 -0.0 593 1.4 1.1 -1.3 671 1.8 1.8 0.6 756 2.3 2.1 1.3 848 2.2 2.0 1.5 947 0.7 -0.1 -1.0 1043 1.0 -0.5 -1.3 1138 0.7 -0.2 -1.0 1232 0.3 0.2 -0.4 1326 0.4 -0.0 0.6 1419 0.4 -0.3 -0.3 1512 0.2 -0.2 -0.1 1604 0.1 -0.1 0.0 1695 0.3 -0.2 0.3 Client Well Name Location. Eastman Teleco : Prudhoe Bay Drilling Group : Apex Gas Injection 7 : Apex Gas Injection Pad : North Slope, Alaska : Page 2 Date Feb. Filename Interpolated of 3 24, 1993 : 1185-450 100 ft of TVD MD ft 4643 4781 4919 5058 5199 5340 5482 5623 5764 5905 6045 6186 6327 6468 6610 6752 6895 7038 7182 7326 7471 7614 7756 7896 8035 8172 8306 8440 8574 8709 8845 8983 9123 9264 9407 9551 9697 9846 9996 10148 CkL INC DIR TVD ft deg deg ft 139 43.6 71.3 4000 138 43.5 71.5 4100 138 43.7 71.4 4200 139 44.1 71.0 4300 140 44.9 70.5 4400 141 45.3 70.5 4500 142 45.2 71.0 4600 142 45.0 71.6 4700 141 44.7 72.3 4800 141 44.5 72.7 4900 140 44.6 72.7 5000 141 44.7 73.1 5100 141 44.8 74.0 5200 141 45.0 73.9 5300 142 45.4 72.6 5400 142 45.5 72.5 5500 143 45.4 73.4 5600 143 45.7 73.9 5700 144 46.4 74.0 5800 144 46.4 74.1 5900 144 45.8 74.1 6000 143 45.4 73.5 6100 142 45.1 72.6 6200 140 44.4 71.8 6300 139 43.5 71.1 6400 136 42.5 71.8 6500 135 41.3 73.2 6600 134 41.2 73.4 6700 134 41.8 72.7 6800 135 42.5 72.6 6900 137 43.2 73.4 7000 138 43.9 73.8 7100 140 44.6 73.8 7200 141 45.2 73.8 7300 143 45.9 73.8 7400 144 46.6 73.6 7500 146 47.2 73.0 7600 148 47.9 72.9 7700 150 48.7 73.3 7800 152 49.4 73.3 7900 VS ft 1883 1979 2074 2170 2269 2368 2469 2569 2669 2768 2866 2965 3064 3164 3265 3366 3467 3570 3674 3778 LAT ft 601 632 662 6.94 726 DEP D ' LEG ft °/100 1786 0.4 1876 0.2 1966 0.2 2058 0.4 2151 0.6 BUILD TURN o/loo °/lOO -0.3 0.5 -0.1 0.2 0.1 -0.1 0.3 -0.2 0.5 -0.4 759 2245 0.3 0.3 -0.0 792 2340 0.3 -0.0 0.4 824 2435 0.3 -0.1 0.4 855 2529 0.4 -0.2 0.5 885 2624 0.2 -0.1 0.3 914 2718 0.0 0.0 0.0 943 2812 0.2 0.1 0.3 971 2907 0.5 0.1 0.6 999 3003 0.2 0.2 -0.1 1028 3100 0.7 0.2 -0.9 1058 3196 0.1 0.1 -0.1 1088 3293 0.5 -0.0 0.6 1117 3392 0.3 0.2 0.4 1146 3491 0.5 0.5 0.1 1174 3591 0.1 -0.0 0.0 3882 1203 3692 0.4 3984 1232 3789 0.4 4085 12'61 3886 0.5 4183 1291 3980 0.6 4280 1322 4072 0.7 4372 1350 4160 0.8 4462 1377 4245 1.1 4551 1404 4330 0.2 4640 1430 4415 0.6 4730 1456 4502 0.5 4823 1483 4591 0.6 4918 1510 4681 0.5 5016 1538 4775 0.5 5115 1565 4870 0.5 5217 1594 4969 0.5 5322 1623 5069 0.5 5428 1654 5171 0.5 5538 1686 5276 0.5 5650 1719 5383 0.6 5765 1752 5493 0.5 -0.4 0.0 -0.3 -0.4 -0.2 -0.6 -0.5 -0.5 -0.6 -0.5 -0.8 0.5 -0.9 1.0 -0.1 0.2 0.5 -0.5 0.5 -0.0 0.5 0.5 0.5 0.3 0.5 0.0 0.5 0.0 0.5 0.0 0.5 -0.2 0.4 -0.4 0.5 -0.1 0.5 0.2 0.5 0.0 Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Apex Gas Injection 7 Location - Apex Gas Injection Pad : North Slope, Alaska : Page 3 of 3 Date Feb. 24, 1993 Filename : 1185-450 Interpolated 100 ft of TVD MD C~L INC DIR TVD ft ft deg deg ft 10263 115 49.9 73.1 7975 VS ft 5852 LAT ft 1777 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 5577 0.8 0.8 -0.1 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 5853 ft 72.3° ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7,542 February 12, 1993 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit AGI-7 ARCO Alaska, Inc. Permit No. 93-27 Sur. Loc. 2291'NSL, 2515'WEL, Sec. 36, T12N, R14E, UM Btmnhole Loc. l152'SNL, 1310'WEL, Sec. 31,T12N, R15E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. 1 , Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. (~ printed on recycled paper b y C~). [ '1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll-Illb. Type of well. ExploratoryFq Stratigraphic TestE3 Development oilr-I Re-Entry [] DeepenI-II Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 49'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchorac~e. Alaska 99519-6612 ADL 34628 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 2291' NSL, 2515' WEL, SEC. 36, T12N, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1220' SNL, 1540' WEL, SEC. 31, T12N, R15E AGI-7 U-630610 At total depth 9. Approximate spud date Amount 1152' SNL, 1310' WEL, SEC. 31, T12N, R15E 2/14/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (aD and TVD) property line ADL 28301-3969' feet AGI-6-120' @ Surface feet 2560 10966' MD/10208' TVD~eet 16. To be completed for deviated wells !17. Anticipated pressure (see 20 AAC 2.5.035 (e)(2)) Kickoff depth soofeet Maximum hole angle 4s o Maximum surface 3500psig At total depth (TVD) ~800'/3850psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5tt H-40 Weld 76' 30' 30' 106' 106' 11 yds Arcticset 16" 13-3/8" 68tt L-80 B TC 3896' 29' 29' 3925' 3500' 1094 sx "E"/400 sx "G"/250 sx "C" 12-1/4" 9-5/8" 4711 L-80 NSCC 10330' 28' 28' 10358' 8046' 500 sx Class "G" 8-1/2" 7" 2611 L-80 NSCC 758' 10208'! 7940' 10966' 8476' 19. To be completed for Redrill, Re-entry, and Deepen Operations.!'37,,~ Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured)~?,"'*~':~'~:!':;~?' ............ true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby certify, ~at t,,,J.l~e.~oregoing is true and correct to the best of my knowledge Si~Ined~J'[. '~ Title Drilling Engineer Supervisor D Commission Use Only Permit Number IAPI number IApproval date ISee cover letter ?,;~, ~? 15 o- <3 z.,e~-- ~..z. $ ~,..,e I c~, ~ / ~ -"~ ,.~ If°r other requirements Conditi'ons of al~proval Samples required [] Yes ;l~l'No Mud log required [] Yes ,~ No Hydrogen sulfide measures [] Yes '~ No Directional survey requ~rea ,~ Yes [] NO Required working pressure for BOPE 1-12M; !-13M; ~5M; r-I10M; 1'-115 Other: Origir~;?~ ~'.,,~:~r~ed ~3y by order of Approved by -David W..;.,m'~ston Commissioner the commission Form 10-401 Rev. 12-1-85 Submit in triplicate WELL PLAN Wel!: APEX GAS INJECTOR #7 (AGI #7) LOCATION: Surface: Target: T.D.: 2291' FSL, 2515' FEL, Sec. 36, T12N, R14E 1220' FNL, 1540' FEL, Sec. 31, T12N, R15E 1152' FNL, 1310' FEL, Sec. 31, T12N, R15E ESTIMATED START: 14FEB93 OPR. DAYS TO COMPLETE: 20 (1 6 days drilling, 4 days completion) CONTRACTOR: AUDI RIG #2 MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEP: 45.0°/N73.17°W/500'/1 ° per 100' MD/6342' Estimated Ground level elevation is 13' AMSL. KB to ground level elevation is 36'. Item TVD(BKB) MD(_BKB) .IVJud Wt. 20" CONDUCTOR 106 106 8.5 13-3/8" SHOE 3500 3925 9.0 9-5/8" SHOE 8046 10358 9.2-10.0 TOP SADLEROCHIT 8051 10365 9.2-10.0 7" SHOE 8476 10966 9.2-10.0 TARGET 8239 10631 9.2-10.0 TOTAL DEPTH 8476 10966 9.2-10.0 CASING PROGRAM: Hole Csg Wt Grade Conn Length Top 30" 20" 91.5# H-40 WELD 76 30 16" 13-3/8" 68# L-80 BTC 3896 29 12-1/4" 9-5/8" 47# L-80 NSCC 10330 28 8-1/2" 7" 26# L-80 NSCC 758 10208 Btm 106 3925 10358 10966 COMPLETION: Tubing: 7" GLMs: None Packer: 26# L-80 NSCC 1 O131 27 1 O158 9-5/8" x 5-1/2" PERMANENT PACKER set at 10158 MD or +/- 50' above Top of liner LOGGING PROGRAM: Open H91~ 12-1/4" hole: 8-1/2" hole GR/RESISTIVITY WHILE DRILLING TO PICK CASING POINT. GR/RESISTIVITY WHILE DRILLING ACROSS SADLEROCHIT ~ased Hole SBT IN 9-5/8" before running tubing (GR to be run up to 13-3/8") APEX GAS INJECTOR #7 (AG, 7) DRILLING DISCUSSION AGI #7 is the seventh of a ten well program at the new Apex Gas Injection pad. All ten wells are to be gas injectors targeted to the apex of the Prudhoe Bay gas cap. They are intended to meet the additional gas injection requirements associated with the GHX-2' project and to "strip" residual liquid hydrocarbons from the gas cap. All ten bottom hole locations lie within an area where the Lower Cretaceous Unconformity truncates the top of the Ivishak Sand. Therefore the Cretaceous shales ("K" shales) will directly overlie the Ivishak sand injection interval (target interval) comprised of Zones 1, 2, 3, and partially truncated Zone 4. Ivishak sand thicknesses are likely to range between 350' and 405'. None of the wells are expected to encounter Putt River, Sag River, Shublik, or an oil column. The proposed casing program is the conventional 20" conductor x 13-3/8" surface casing x 9-5/8" intermediate casing x 7" liner. Gas tight connections will be used on the 9-5/8" intermediate casing as well as the 7" liner. 7" tubing with 5-1/2" tailpipe will be the completion assembly. This assembly will be run with a completion rig after the drilling has moved off the well. ANNULAR INJECTION The 13-3/8" x 9-5/8" annulus of AGI #2, AGI #3, AGI #4, AGI #5 and AGI #6 may be available for injection purposes. Ensure any annulus has been properly permitted before commencing injection. The 1 3-3/8" x 9-5/8" annulus on AGI #1 is not to be injected into. Fluids can be injected at the central CC-2 injection facility. ADEC has informed Prudhoe Bay Drilling that only associated fluids from drilling operations can be pumped down surface x intermediate annuli. Completion fluids CANNOT be injected down the aforementioned annuli. SHUTDOWN OF WEI. I~ OPERATIONS Shutdown of well operations once 9-5/8" casing has been set and cemented is planned for wells AGI #3 thru AGI #9. Wells AGI #3- AGI #9 will be drilled to 12-1/4" hole TD, 9-5/8" casing run and cemented. At this time operations will be shutdown and the rig will move to the next well and repeat the process. AGI #10 will be drilled to 8-1/2" TD, 7" liner run, and the well completed. Once AGI #10 is completed the rig will make its way back drilling 8-1/2" hole, running 7" liner and completing all the wells in which operations were shutdown. As per conversation with AOGCC (B. Wondzell) on 30DEC92 shutdown and resumption of well operations approval will be included as part of the permit approval-as long as the process is outlined in the PROPOSED DRILLING AND COMPLETION PROGRAM associated with this package-and therefore no application for sundry approval will be necessary for shutdown/resu mption of operations. The decision to drill AGI #3- AGI #10 as described above is based solely on economics and therefore dictated by prudence alone. There are no known hydrocarbon bearing sands between surface and 9-5/8" casing point in any of the AGI wells. All 9-5/8" casing points are estimated to be above the top of the Sadlerochit sands. Operations on AGI #7 are expected to resume on or about 3MAY93. All ten wells are estimated to be drilled and completed by 13MAY93. If there are any questions or if further information is required please contact J. E. Robertson at 564- 5510. FREEZE PROTECTION The 7" tubing along with the 7" x 9-5/8" annulus Will be freeze protected with diesel before the drilling rig moves off the well. CLOSE APPROACHES WELLNAME SLOT DISTANCE DEPTH (' TVD) AG! #1 AGI #1 718' 650' TVD AG! #2 " AGI #2 600' SURFACE AGI #3 AGI #3 479' 500' TVD AGI #4 AGI #4 358' SURFACE AGI #5 AGI #5 240' SURFACE AGI #6 AGI #06 120' SURFACE LGI #08 LGI #08 259' 8450' TVD LGI #10 LGI #1 0 785' 6200' TVD PROPOSED DRILLING AND COMPLETION PROGRAM AGI #7 Procedure . . ,, MIRU drilling rig. Notify AOGCC of upcoming diverter function test. N/U diverter and function test same. Drill 16" hole to surface casing point. Run and cement surface casing. Nipple up BOPE and function test same to 5000 psi, PU 12.-1/4" BHA and RIH. Test casing to 2500 psi for 30 minutes. Drill 10' of new hole and perform leak off test. . Drill intermediate hole to intermediate casing point. MU and run 9-5/8 casing string and cement as per well plan. seawater Bump cementing plug with . . RIH to 2.000' MD and displace to diesel. ND BOPE. off. NU dryhole tree and test to 5000 psi. SHUTDOWN OPERATIONS. Release rig. Move .. RESUME OPERATIONS. MIRU. BOPE. Test BOPE. Notify AOGCC of upcoming BOPE TEST. ND dryhole tree and NU . 10. 11. RIH. Displace diesel cap w/seawater. Drill to 9-5/8" shoe. Displace wellbore w/"drill in" mud. Continue drill/LOG 8-1/2" hole through reservoir to TD. MU 7" liner on 5" DP. RIH to TD. Displace wellbore w/completion fluid. Set liner hanger and liner top packer. POOH. Run 7", L-80 tubing and packer assembly with SSSV. Freeze protect with diesel. Test tubing and casing to 4000 psi. Have witnessed by state. 12.. NU tree and test to 5000 psi. Release drilling rig. ° Anticipated BHP: ° Maximum Anticipated Surface Pressure: ° Planned Completion Fluid: 3850 psi @ 8800' TVD SS 2.970 psi 8.6 PPG SEAWATER Notes: a. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/A). c. No potential productive zones are anticipated above 9-5/8" casing shoe. d. No potential hazardous levels of H2S are anticipated in this well. lVlUD PROGRAM: Well AGI #7 The mud program for this well shall fc, llow the new Mud Policy. The following are the recommended mud parameters. HUD SPECIFICATIONS- SURFACE HOI.E Surface: Casing point: Mud Weight: ppg 8.5 - 9.5 8.5 - 9.0 Funnel Viscosity sec/qt ~300 <1 O0 YP lbs/100ft2 40 - 60 20 - 40 10 sec Gel lbs/100ft2 30 - 60 15 - 20 10 min Gel lbs/100ft2 60- 80 20 - 30 pH - 9.0 - 10 9.0 - 10 APl Fluid loss mi/30 min 15-25 15-25 Hardness mg/I < 200 <200 MUD SPECIFICATIONS-INTERi~EDIATE HOLE Surface caSing shoe to Top of Sadlerochit Sandstone: LSND Gel/Water System Mud Weight . ppg 9.2-10.0 Yield Point lbs/100ft2 10 - 15 10 sec Gel lbs/100ft2 5 - 10 10 min Gel lbs/100ft2 10 - 20 APl Fluid Loss mi/30 min 6-8 pH - 8.5 - 10.0 Hardness mg/I <200 MUD SPECIFICATIONS-PRODUCTION INTERVAL: Build new mud system to replace mud used in intermediate hole. Mud Weight ppg 9.0-9.5 Yield Point lbs/100ft2 20- 30 10 sec Gel lbs/100ft2 18 - 22 10 min Gel lbs/100ft2 20 - 24 APl Fluid loss mi/30 min 6.0 - 8.0 pH - 9.5 - 10.0 Hardness mg/I <200 The mud salinity should be compatible with the Reservoir logging program. The mud will be run at +40,000 ppm chlorides. RUN LOW SHEAR RATE VISCOSITY AT 40,000+ Centipoise on mud system. AGI #7 Casing Design SURFACE CASING 13-3/8" G8#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1950 L-80 5020 2260 PBYS (#) 1069000 1556000 TJYS (#) 1300000 1 585000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) 'i'VD (FT) SI PRESSURE 14 3500 2198 Burst S.F. 1.57 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 3500 1729 Collapse S,F, 1,31 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (IT) 68 3925 PBYS Tension S.F. 4.69 Mud Wt. 9.5 ppg TJYS 5.70 String Wt. (#) 228146 AGI #7 Casing Design Production Casing 9-5/8", 47#,L-80,NSCC Casing GRADE BURST L-80 6870 COLLAPSE PBYS (#) TJYS (#) 4750 1086000 1161000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SITP 3850 Burst S.F. 1.78 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg .-. Gas Grad, Mud Wt. (ppg) TVD (FT) (psi/fi) Collapse press 10.2_ 8046 O. 1 $463 Collapse S,F, 1,37 Tension Calculation Based on full string weight in mud Casg Wt, (#/ft) MD (FT) 47 10358 PBYS Tension S.F, Z,64 Mud Wt, 10.2 TJYS Z,83 String Wt, (#) 410930 AGI #7 Casing Design PRODUCTION LINER 7", 2G#,L-80,NSCC Casing GRADE BURST L-80 7240 COLLAPSE PBYS (#) TJYS (#) 5410 604000 667000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid Fluid wt (ppg) back up (ppg) Burst Pressure SITP 9.7 9.5 3942 3850 Burst S.F. 1.84 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse Press 10.2 8476 0.1 3648 Collapse S.F. 1.48 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 26 800 Mud Wt. String Wt. (#) 10.2 17557 Tension S.F. PBYS TJYS 34.4O 37.99 CEMENT PROGRAM - HALLIBURTON SERVICES 13 3/8" SURFACE CASING CASING SIZE: 13 3/8", 68# CIRC. TEMP: 60°F LEAD CEMENT TYPE: TYPE 'E' PERMAFROST _ ADDITIVES: n/a WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX #SACKS: 1094 PUMP TIME: 4:30 hfs MIX WATER: 11.63 gps FW Mix water temp: 50-65F ~AIL CEMENT TYPE: CLASS G ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.16 ft3/sx APPROX #SACKS: 400 PUMP TIME: 4 hrs MIX WATER: 5.00 gps FW Mix water temp: 50-65 F TOP JOB CEMENT TYPE; TYPE "C" PERMAFROST (if necessary) ADDITIVES: n/a WEIGHT: 15.6 ppg YIELD:O.94 ft3/sx APPROX #SACKS: 250 PUMP TIME: 2:30 hrs MIX WATER: 3.5 gps FW Mix water temp: 50-65 F .. SPACER: 100 bbls fresh water ahead of lead slurry. The WATER temperature should be 50-65F CEMENT VOLUME 1. From top of tail to surface w/100% excess. 2. Tail slurry volume 400 sx 3. Top job volume +/- 250 sx. 5/8" INTERMEDIATE CASING CASING SIZE: 9 5/8", 47# o CIRC. TEMP 135 F TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.25% HR-5 (Retarder) + 0.2% Halad 344 (Fluid Loss) WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.00 gps.FW APPROX #SACKS: 500 PUMP TIME: 4 hrs Mix water temp: 70-80 F SPACERS: Pump 20 bbls Alpha(ARCO) Preflush; 50 bbls Alpha(ARCO) spacer @ 11 ppg. OTHER CONSIDERATIONS; Continuously mix tail slurry. Displace at 12-15 bpm. CEMENT VOLUME 1. Lead Slurry will not be needed unless the WEST SAK and UGNU give a hydrocarbon show. 2. Tail Slurry to 1000' MD above shoe w/30% excess. Prudhoe Bay AGI-07 Drilling TRUE I I00. VERTICAL VIEW SCALE 1000 Ft, / REFERENCE: R,I<,B, O~ 500-- lO00-- 0.00' 8 0 MD R.K.B. ELEVATIDN 49' ABOVE SEA LEVEL 0,00' 8 500 MD KDP/BUIL~ RATE, 1.00 OEO/lO0 FT 2.00' 8 700 MD 4,00' ~ 900 MD 6,00' ~ 1100 MD 8,00' ~ 1300 MD HFIRIZF1NTAL SCALE 500 REFERENCE: VIEW ¢t, / DIVISf~N WELL HEAD I 1 ~8.oo' e ~9oo ~ ~ooo-~ ~ ~.oo- e ~ioo ~ $~ ~o.oo' e ~5oo ~ X 34.00' ~ ~700 MD 3500 t 1360 4000-- 5000-- 6000-- 701 )l 80{ 500 5bo 100'¢ 1500 200~¢-12500 3000 3500 4000 4500 5000 5500 6000 6500 ....i .04' 8 3858 MD END DF BUILD ~ ' %~8 39~5 MD 13-3/8' CSO. PT. - CRITICAL POINT DATA ~ ] ' MDInc AzI TVD No~h ~ JR.K.B. ELEV.' 49' 0.00 0.00 0 0 0 ~ JKOP/BUILD 1/100 500 0.00 0.00 500 0 0 ~ /END OF ~UILD 325245.0473.173024 256 846 ~ ]13-3/8' CSG. PT.39~5 45.0473.173500 394 130~ ~ /9-5/8° CSG. PT.10358 45.0473.178046 171~5659 ~ IT02 1036545.0473.178051 17135663 ~ [TARGET 1063145.0473.178~39 17685844 ~ ]KAVIK 1089645.0473.178426 18~ 6083 /TOTAL DEPTH 1096645.0473.17847~ 18376071 BHL DATA SUR A ~ I~fi' ,1422'Z I SEC. 36) TI~N, RI4E ~ I~ '~5~'~l { ASP, Y = 5979989.83 ~ )North lB36'7' ) X : 688757.91 ~ ] SEC. 3]; TISNI RISE ~ ~ ASP, Y - 5981846.05 ~ I BOTTOH HOLE LOCATION ~ [ ASP, Y = __ 45,04' 8 10358 MD 9-518' CSG, PT, 5917 -p 45,04' ~ 10365 ND TBS 45.04' 8 1063~ MD TARGET 6t05 6298 45,04' 8 10896 MD KAVIK 6348 45.04' 8 1096G HD TOTAL DEPTH I 000 8000 3000 4000 5000 6000 7000 VERTICAL SECTIIIN PLANE: 73, 17 ° mith International, Inc. Proposal Report ~ Calculated using the Minimum Curvature Melhod Computed by the Sii Win-CADDS Syslem Vertical Section Plane: 0.00 deg. rvey Reference: ~JELLIJEAD ference Uortd Coordinates: Lat. 70.20.59.64 N - Long. 148.28.02.67 14 ference GRID System: Alaska State Plane Zone: Alaska 4 ference GRID Coordinates: (feet): 5979929.23 N 688757.91 E 'tica[ Section Reference: IJELLHEAD )sure Reference: I,/ELIHEAD 'th Aligned To: TRUE NORTH Page 1 Date: 1/11/93 ~etlpath ~D: AGI-7~P2 Program No: 1120/003 Last Revision: 1/1~/93 ~dhoe Bay Dri I. L lng -07 ,asured Incl Drift TVD Subsea T 0 T A L Geographic Coordinates Depth Dir. Depth Rectangular Offsets Latitude / Longitude (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) .B. ELEVATION 49' ABOVE SEA LEVEL 0.00 0.00 0.00 0.00 -49.00 0.00 N 0.00 E 70.20.59.6441N 148.28.02.6727 14 100.00 0.00 0.00 100.00 51.00 0.00 N 0.00 E 70.20.59.6441'N 148.28.02.6727 14 200.00 0.00 0.00 200.00 151.00 0.00 N 0.00 E 70.20.59.6441N 148.28.02.6727 14 300.00 0.00 0.00 300.00 251.00 0.00 N 0.00 E 70.20.59.6441 N 148.28.02.6727 W 400.00 0.00 0.00 400.00 351.00 0.00 N 0.00 E 70.20.59.6441 N 148.28.02.6727 g /BUILD 1/100 500.00 0.00 0.00 500.00 451.00 0.00 N 0.00 E 70.20.59.6441 N 148.28.02.6727 14 600.00 1.00 73.17 599.99 550.99 0.25 N 0.84 E 70.20.59.6466 N 148.28.02.6483 700.00 2.00 73.17 699.96 650.96 1.01 N 3.34 E 70.20.59.6540 N 148.28.02.5751 800.00 3.00 73.17 799.86 750.86 2.27 N 7.52 E 70.20.59.6665 N 148.28.02.4530 900.00 4.00 73.17 899.68 850.68 4.04 N 13.36 1000.00 5.00 73.17 999.37 950.37 6.31 N 20.87 1100.00 6.00 73.17 1098.90 1049.90 9.09 N 30.04 1200.00 7.00 73.17 1198.26 1149.26 12.37 N 40.88 1300.00 8.00 73.17 1297.40 1248.40 16.14 N 53.37 1400.00 9.00 73.17 1396.30 1347.30 20.42 N 67.52 1500.00 10.00 73.17 1494.93 1445.93 25.20 N 83.32 1600.00 12.00 73.17 1593.09 1544.09 30.73 N 101.58 1700.00 14.00 73.17 1690.52 1641.52 37.24 N 123.11 1800.00 16.00 73.17 1787.11 1738.11 44.73 N 147.88 1900.00 18.00 73.17 1882.73 1833.73 53.20 N 175.86 !000.00 20.00 73.17 1977.28 1928.28 62.63 N 207.03 !100.00 22.00 73.17 2070.63 2021.63 73.00 N 241.33 !200.00 24.00 73.17 2162.68 2113.68 84.32 N 278.72 1300.00 26.00 73.17 2253.31 2204.31 96.55 N 319.17 !400.00 28.00 73.17 2342.40 2293.40 109.70 N 362.62 E !500.00 30.00 73.17 2429.86 2380.86 123.74 N 409.02 E 1600.00 32.00 73.17 2515.57 2466.57 138.65 N 458.32 E 1700.00 34.00 73.17 2599.44 2550.44 154.42 N 510.45 E 1800.00 36.00 73.17 2681.35 2632.35 171.03 N 565.34 E E 70.20.59.6838 N 148.28.02.2823 g E 70.20~59.7062 N 148.28.02.0628 W E 70.20;59.7335 N 148.28.01.7947g E 70.20.59.7657 N 148.28.01.4780 14 E 70.20.59.8029 N 148.28.01.1129 g E 70.20.59.8450 N 148.28.00.6994 ~ E ~ 70.20.59.8920 N 148.28.00.2378 14 E 70.20.59.9463 N 148.27.59.7040 W E 70.21.00.0104 N 148.27.59.0748 g E 70.21.00.0841 N 148.27.58.3508 14 E 70.21.00.1673 N 148.27.57.5330 W E 70.21.00.2600 N 148.27.56.6224 W E 70.21.00.3621 N 148.27.55.6199 E 70.21.00.4734 N 148.27.54.5270 E 70.21.00.5937 N 148.27.53.3449 70.21.00.7230 70.21.00.8611 70.21.01.0078 70.21.01.1629 70.21.01.3262 N 148.27.52.0750 N 148.27.50.7189 N 148.27.49.2782 N 148.27.47.7548 W N 148.27.46.1503 W GRID Coordinates Northing Easting (ft) (ft) 5979929.23 688757.91 5979929.23 688757.91 5979929.23 688757.91 5979929.23 688757.91 5979929.23 688757.91 5979929.23 688757.91 5979929.50 688758.74 5979930.32 688761.22 5979931.69 688765.37 5979933.60 688771.16 5979936.06 688778.61 5979939.07 688787.71 5979942.62 688798.46 5979946.71 688810.86 5979951.35 688824.89 5979956.52 688840.56 5979962.50 688858.68 5979969.56 688880.04 5979977.67 688904.61 5979986.84 688932.37 5979997.05 688963.29 5980008.29 688997.31 5980020.54 689034.41 5980033.80 689074.54 5980048.03 689117.64 5980063.24 689163.67 5980079.39 689212.57 5980096.47 689264.29 5980114.46 689318.74 Closure Dist. Dir. (ft) deg. 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.87 @ 73.17 3.49 @ 73.17 7.85 @ '73.17 13.96 @ 73.17 21.80 @ 73.17 31.39 @ 73.17 42.71 @ 73.17 55.76 @ 73.17 70.54 @ 73.17 87.05 @ 73.17 106.13 @ 73.17 128.62 @ 73.17 154.50 @ 73.17 183.74 @ 73.17 216.29 @ 73.17 252.13 @ 73.17 291.20 @ 73.17 333.46 @ 73.17 378.85 @ 73.17 427.33 @ 73.17 478.83 @ 73.17 533.29 @ 73.17 590.65 @ 73.17 Vertical DLS Section (ft) (dg/lOOft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 . 0.00 0.25 1.00 1.01 1.00 2.27 1.00 4.04 1.00 6.31 1.00 9.09 1.00 12.37 1.00 16.14 1.00 20.42 1.00 25.20 1.00 30.73 2.00 37.24 2.00 44.73 2.00 53.20 2.00 62.63 2.00 73.00 2.00 84.32 2.00 96.55 2.00 109.70 2.00 123.74 2.00 138.65 2.00 154.42 2.00 171.03 2.00 International, Inc. Proposal Report Page 2 Date: ~/11/93 Wel[path ID: AGI-7~/P2 ~sured Incl Drift TVD )epth Pir. ift) (deg.) (deg.) (ft) !900,00 38.00 73.17 2761.21 ;000.00 40.00 73.17 2838.92 ;100.00 42.00 73.17 2914.38 ,200.00 44.00 73.17 2987.52 OF BUILD .251,85 45,04 73,17 3024,49 /8" CSG, PT, 924,76 45,04 73,17 3500,00 Subsea Depth (ft) 2712.21 2789.92 2865,38 2938.52 2975.49 3451.00 8" CSG, PT, 357,94 45,04 73,17 8046,00 7997,00 365o01 45,04 73,17 8051,00 8002.00 ET 631,06 45,04 73,17 8239,00 8190,00 731,06 45,04 73,17 8309,66 8260,66 831,06 45,04 73,17 8380,33 8331,33 K 895,68 45,04 73,17 8426,00 8377,00 ~31.06 45.04 73.17 8450,99 8401,99 L DEPTH ~66.44 45,04 73,17 8476,00 8427,00 TOTAL Rectangular Offsets (ft) (ft) 188,46 N 622,94 E 206,68 N 683.18 E 225,68 N 745,97 E 245,43 N 811,24 E 255,96 N 846,04 E 393,84 N 1301,77 E 1712,03 N 5658,59 E 1713,48 N 5663,39 E 1767.99 N 5843,56 E 1788.48 N 5911,29 E 1808,97 N 5979,01 E 1822,21 N 6022,78 E 1829,46 N 6046,74 E 1836,71 N 6070,70 E Geographic Coordinates Latitude / Longitude 70,21,01,4976 N 148,27,44,4669 70,21,01,6769 N 148,27,42,7066 70,21,01,8637 N 148,27,40,8715 70.21,02,0579 N 148,27,38,9638 70,21,02,1615 N 148,27,37,9468 70,21,03,5176 N 148,27,24,6276 70,21,16,4821 N 148,25,17,2814 70,21.16,4964 N 148,25,17,1413 70,21,17,0325 N 148,25,11,8744 70,21,17,2340 N 148,25,09,8947 70,21,17,4356 N 148,25,07,9150 70,21,17,5658 N 148,25,06,6355 70.21,17,6371 N 148,25,05,9353 70,21,17.7084 N 148,25,05,2347 GRID Coordinates Northing Easting (ft) (ft) 5980133,34 689375.88 5980153,08 689435,64 5980173,66 689497,92 5980195,05 689562,68 5980206,45 689597,19 5980355.83 690049,27 1360,04 @ Closure Dist. Dir. (ft) deg, 650,83 @ 73,17 713,76 @ 73,17 779,36 @ 73,17 847,55 @ 73,17 883,91 @ 73,17 73.17 5981785,31 694370,74 5911,91 @ 73,17 5981786,88 694375,50 5916.92 @ 73,17 5981846,05 694554,19 6105,16 @ 73,17 5981868,29 694621,36 6175,92 @ 73,17 5981890,54 694688,53 6246,68 @ 73.17 5981904,91 694731,94 6292,41 @ 73,17 5981912,78 694755,70 6317,43 @ 73,17 5981920,65 694779,46 6342,47 @ 73,17 Vertical DLg Section (ft) (dg/lOOft) 188.46 2.00 206,68 2,00 225,68 2.00 245,43 2,00 255,96 2,00 393,84 0,00 1712,03 0,00 1713,48 0,00 1767,99 0,00 1788,48 0,00 1808,97 0,00 1822,21 0,00 1829,46 0,00 1836,71 0,00 PPudhoe Bey Pmudhoe A61-07 AOI-7WP8 HE]P, IZnNTAL SCALE 500 AEFEAENCE: VIEW (TAUE NEATH) fi;, /DIVISION WELL HEAD 500 ~000 ~500 8030 8500 3000 3500 4000 4530 5(:E~ 5500 6000 6503 . . Smith International, Inc. Travelling Cylinder Report Computed by the Sii Win-CADDS System Least Distance Method Page 1 Date: 1/7/93 REFERENCE WELL: Prudhoe Bay Drilting Prudhoe Bay AG! AGI-07 AGI-7~P2 TVD~ N/S and E/g are measured from the gELLHEAD gellpath Slot Distance Direction LGI-02 LGI-02 3455.10 191.20 LGI-04 LGI-04 3702.75 166.31 LGt-06 LGI-06 1807.73 129.63 LG[-08 LGI-08 259.17 161.36 LG[-IO LG[-IO 784.80 106.79 LGI-12 LGI-12 2037.00 232.58 Closest Points Ref MD Ref TVD 6118.21 5050.00 100.00 100.00 10929.65 8450.00 10929.65 8450.00 7745.61 6200.00 8948.47 7050.00 Pmudhoe Ppudhoe A6I A61-07 A6I-7WPP lmeve/Lin9 CyLindep - Lees~ Distance I~e£emence We~/- AGI-7WP~° TVD: 0- 8476 f~, In~emvel, 50 £~, A~I DiPec~ions I~eL ~o Tmue NoP~h 270o WelIDo th Slot LG]-Oe LG]-C~ LG]-04 LG]-04 LG]-06 LG]-O~ LG]-08 LG]-08 LG]-IO LG]-IO LG]- 12 LG]- 300° ~40° 33O° CL ELSES'[ FC]INT S Bstonce D;rect;on Rer ND Re{ TVD N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A ~9.17 16~.~6 109L:::~.65 845000 N/A N/A N/A N/A N/A N/A N/A N/A 0o 600 55O 500 4'50 400 35O 30O ! 80° 150° Smith International, Inc. Travelling Cylinder Report Computed by the Sii Win-CADDS System Least Distance Method Page 1 Date: 1/7/93 REFERENCE WELL: Prudhoe Bay Drilling Prudhoe Bay AG! AGI-07 AGI-7gP2 TVD, N/S and E/W are measured from the WELLHEAD Weltpath Stot Distance Direction AGIO1MWD AG!-01 718.79 170.12 AGI-O2MWD AGI-02 600.01 169.94 AGI-O3M~D AGI-03 478.82 169.90 AGI-O4WP AGI-04 358.32 171.36 AGI-OSWP AGI-05 240.00 169.94 AGI-O6WP AGI-06 120.00 169.94 Closest Points Ref MD Ref TVD -.650.02 650.00 0.00 0.00 500.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 ]}is~once - Lees~c AGT-TWP3 ]3i~ec~cions Re[ ~co Tpue No~ ( tSM TH 300° 33O° 0o 600 550 500 450 400 35O 300 ,\ 60° 270° 240° ~vfllpoth AGIOI~aD AG]-04WP AGi-OSxP CLOSES7 PC]]NTS Slot AGI-C~ aG]-04 AG]-OS G stonce N/A 478.P_~ 240.00 Dinecticx~ N/A 169.90 171.36 160.94 169.04 Re£ ~D N/A 500.00 0.00 0 00 0.00 Re£ N/A N/A 0.03 0.00 003 KOP: 500 MD MAX. ANGLE: 45.0o TD Departure · 6342' WELLHEAD: FMC JER FEB93 20" Conductor MD BKB 106' mD ~ 13-3/8", 68~, L-80, BTC ~. 13-3/8" Shoe 3925'MD ~ 9-5/8", 47#, L-80, NSCC 7" Baker Hngr and Liner '~'~Top Packer 9- 5/8" Shoe 10208'MD 10358'MD ~ 7", 26~, L-80, NSCC Liner PB TD 7" Shoe 8-1/2" hole TD _+10886'MD 10966'MD 10966'M D SUi-...' 'OL~ IDIVERTER SYSTEM .. Two lines venling gO deg. apart in directions lhat ensure sale down wind venling, and e×- lending to a poin[ al leas1100' [rom any potential source ol ignition. 10' Full Opening Valves ..... 35' or es required Dresser Sleeve I0' Diverter line I. All pipe connections 1 5C~ ANSI Ranges or welded connedions .~nd secured to prevent movemenL 2. Manual 10' full opening valves m~hanically c~nnec"'ted lo ensure that one valve is Jail-sale open al all limes. 3. All lures are gO deg. and largeled. 10' Full opening ball valve w/Hyd~ulic Actuator Cellar 20' Diverter Spool w/10' Side Oullet MEM 1FJ~O /1UP . ro rluO 1 - Brandh Dual Tandem Shale Shaker 1 - ~m 6-12" Cone Shale ~sander 1- De,,~o 41611 w/16 cones & (1) Damco ,1011 w/16 cones (Desilter) 1 - Drilco Abnospl]eric Hud Degasser 1 - 200 gpm Operating Capacity. Centrifuge 15 - Brandh t-~5 Hud l-rix AgJ. tators 1 - 150 bbl. TrJ.p Tank 1 - Becording drilling ~luid pit level indicator with both visual and audio v:~rl]lng.devices at driller's console ' , o. .. AUDI #2 13 5/8" 5,000 psi Stack 2.00 4.12 1 2.72' ! .,~ 4.50 3.01 3.01 1 1.83 3.01 2.52 1.5 t, GROUND LEVEL F " RKB1 [ I DRIP PAN R G FLOOR HYDRIL 17.88 22.38 PIPE RAM BLIND RAM MUD CROSS PIPE RAM 25.3: I 3O.23 34.25 MUD CROSS k'x~ASE FLG/ 35.75 AGI-TCI4T.×LS State: Welt: Field: State Permit Casing Type Casing Size -Inches Casing Length - Feet Hole Diamete~ -Inche~ Cement- Sacks 11! Cement-Yield II1 Cement- Cubic ti II1 Cement- Cubic f~ ~ Ce~enl - Sack~ ~2 Cement - ~ield ~2 Cement - Cubic Il ~2 Cement - Cubic tt ~2 Cement - Sacks ~3 Ce~e~- Yield ~3 Cement - Cubic ti ~3 Cement - Cubic tt ~3 Ce~e~ - Cubic ti Z Vol Cement- Fill Factor ,4ta,.,'/~',~ .4Gl II7 Pf~,,dhoe ,95-27 Conductor 20.000 7G, O00 30.000 0,000 0.000 0.000 297.000 0,000 0.000 0.000 0.000 297.000 1.4.33 Engineer: Work Sheet: Date: Sud~ace 13.375 3,896.000 16.000 1,094.000 2.170 2~373.980 2,373.980 400.000 1.160 464.000 464.000 0.000 0.000 0.000 0.000 2,837.980 1.732 Careen! Volume Calc~#ation,~ ;;:."12/93 0 0.000 0.000 0,000 0,000 0.000 0.000 0.000 0,000 0.000 0.000 0,000 ~DIV?O! Casing Type Casing Size Casing Depth Hole D iamete~ Cement- Sacks Cement- Yield Cement- Cubic tt Cement- Cubic tt Cement-Sacks Cement- Yield Cement- Cubic ft Cement- Cubic tt Cement-Sacks -Inches - Feet -Inches 111 111 111 112 112 112 112 113 Cement-Yield 113 Cement- Cubic t~tI13 Cement- Cubic ft 113 Cement- Cubic l;t/'Vol Cement-Inte~¥al ft Top of Cement- Feet Intermediate ~1 0.000 8.000 0.000 0.00 0.00 0.O0 0.80 0.00 0,00 0,00 0.00 0,00 0.00 0,00 0,00 0,00 11DIV/O! t~DIV/O! Intermediate 112 0.000 0.000 0,000 0.00 0.00 0,00 0.00 0.00 0,00 0.00 0.00 0,00 0,00 0,00 0.00 0.00 IIDIV/O! I~DIV/O! P~oduction 9.725 10.358.000 12.250 500.00 1.05 525.00 525.00 0,00 0,00 0.00 0.00 0.00 0,00 0,00 0.00 525.00 1,734.80 8,623.2 Measured Depth State: Alaska Borough: Well: AGI #7 Field: Prudhoe St. Perm ;93-27 Date 2/12/93 Engr: M. Minder AGI-7.XL$ Casing interval Interval Descriptionescriptionescription Tension SEe Boffom Top Leng~ Lbs lA 13.375 151 29 120 68 2A 13.375 3500 120 3896 68 3A 9.625 8046 28 10330 47 4A 7 8476 7940 758 26 5A 0 0 0 0 0 6A 0 0 0 0 0 7A 0 0 0 0 0 8A 0 0 0 0 0 9A 0 0 0 0 0 10A 0 0 0 0 0 Grade Thread Lbs K-55 BTC 0 L-80 BTC 264928 L-80 NSCC 0 L-80 NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Collapse Wieght Gradient Gradient ppg psi/ff psi~ lB 9.5 0.494 0.394 2B 9.5 0.494 0.394 3B 10.2 0.530 0.430 4B 10.2 0.530 0.430 5B 0.0 0.000 -0.100 6B 0.0 0.000 -0.100 7B 0.0 0.000 -0.100 819 0.0 0.000 -0.100 9B 0.0 0.000 -0.100 10B 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 2198 3450 1.6 2198 49:30 2.2 :9500 6870 2.0 3500 7240 2.1 0 0 #DIVIO! 0 0 #DIViO! 0 0 #DN/O! 0 0 #DIVIO! 0 0 #OlViO! 0 0 #DIVIO! Tension Strength K/Lbs K/Lbs TDF 1C 273.088 1069 ,/3.91 2C 254.928 1556 5.87 3C 485.51 1086 2.24 4C 19.708 604 30.65 5C 0 0 #DIM/O! 6C 0 0 #DIV/O! 7C 0 0 #DIM/O! 8C 0 0 #DIV/O! 9C 0 0 #DIM/O! 10C 0 0 #DIM/0! Collapse Collapse Pr-Bot-Psi Resist. CDF 59 1950 32.776 1379 226O 1.639 3463 4750 1.372 3648 5410 1.483 0 0 #DIM/O! 0 0 #DIV/O! 0 0 #DIV/O! 0 0 #DIV/O! 0 0 #DIM/O! ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE [~ thru (3) Admin '['9 thru [lO g 13] Company ,H~( ,.~ Lease & Wel 1 YES 1. Is permit fee attached .................... , .......................... __~ 2. Is well to be located in a defined pool .............................. 3. Is well located proper' distance from property line ................... ~._ 4. Is wel 1 located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... L 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ (4) Casg ~-K'.~,~-~ ~"'~-~,S [14 thru 22] [23 thru 25] e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. [29 thru' 31] (7) Contact [32] (8) Add 29. 30. 31. 32. 33. geology: eng i neet ing :~ _ R PC.~/~ BEW JDP~ LG rev 12/92 jo/6.011 J NO REMARKS Does operator have a bond in force ................................... Is a conservation order needed ....................................... , Is administrative approval needed ..................... ' .............. Is lease nLrnber appropriate .......................................... ~" Does well have a unique name & nLrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. ~,. Is enough cement used to circulate on conductor & surface ............ ~ .. Will cement tie in surface $ intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. .--~ Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... ~ . .... Does BOPE have sufficient pressure rating -- test to.~'OC;~2psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... _, FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nLrnber of contact to supply weekly progress data ...... Additional requirements ............................................. ~. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE d Additional remarks:R'/~. ~ ~_._~ . , MERIDIAN' UM ~( ~ TYPE: Exp,.~_~..~. Inj '- SM ' - Red ri 11 Rev "rz ~-'-~ 0 cn--t Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIx. No special'effort has been made to chronologically organize this category of information. LIS VERIFICATION LISTING FOR: ARCO ALASKA, INC. AGI-7 PRUDHOE BAY' ATCM ATDC CADE CPDE DCCM GRAM GRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM Note: BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR ARCO ALASKA INC. AGI-7 Attenuation Borehole Corrected [RWD] Attenuation Dielectric Corrected [RWD] Conductivity (AT) Corrected for Dielectric Effect [RWD] Conductivity (PD) Corrected for Dielectric Effect [RWD] Calculated Dielectric Constant Gamma Ray Memory (APl) [RWD] Gamma Ray Borehole Corrected (APl) [RWD] Phase Difference Borehole Corrected [RWD] Phase Difference Dielectric Corrected [RWD] Phase Difference Elapsed Time [RWD] Resistivity (AT) Borehole Corrected [RWD] Resistivity (AT) Corrected Dielectric Effect [RWD] Rate of Penetration Averaged Rate of Penetration Resistivity (PD) Borehole Corrected [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] CDS Temperature [RWD] AT is Attenuation PD is Phase Difference RWD is Recorded While Drilling -dB -dB mmho/m mmho/m MWD-API MWD-API deg deg mins ohm-m ohm-m fi/hr fi/hr ohm-m ohm-m deg F Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Mon 4 OCT 93 9:31a != = ECHOING INPUT PARAMETERS INPUT PARAMETER FILE: TAPESCAN.INP I 2 3 4 5 6 7 ~ 123456789012345678901234567890123456789012345678901234567890123456789012 I AUTOCURV = 0 , ! Automatic Curve renaming: 0=OFF, I=ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: 0=OFF, I=ON 3 COMMENTS = 1 , ! Decode LIS Comment records: 0=OFF, I=ON 4 INFORECS = 1 , ! Decode LIS Information records: 0=NO, I=YES 5 LISTMETHOD = 0 , ! Listing Method: 0=depth units 1 =tape units 6 LISTFREQ = 50, ! Listing Frequency: Every n units 7 LISTMAX = 0 , ! Listing Maximum (0= no limit, value=list limit) 8 STATS = 0 , !Statistics generation: 0=OFF, I=ON 9 FORCETYP = 0 , ! (I=BIT,2=LI$ ... thru 35=Array Accoustic) (see table) 10 WRITEASCll = 0 , ! If 1, all ascii files will be written (file0001.dat, etc.) 11 WRITETAP = I , ! Write Tape-Image File: 0 = NO,1 =YES 12 SPLITMS = 1 , ! If 1 and WRITETAP on, split LIS logical files to physical 13 SUBFILES = /0/, ! Tape Subtile write selection (WRITETAP must be on) 14 INTERPOLATE='YES' ! Set up for TAPE2WDS to interpolate datums ('YES'or'NO') 15 END != = USER INPUT PARAMETERS AUTOCURV = 0 , AUTOFILE = 0 , COMMENTS = 1 , INFORECS = 1 , LISTMETHOD = 0 , LISTFREQ = 50, -' LISTMAX = 0 , STATS = 0, FORCETYP = 0 , .. WRITEASCII = 0 , WRITETAP = 1 , SPLITLIS = 1 SUBFILES = /0/, " INTERPOLATE = 'YES' END !-- PROCESSING INTERVAL FROM 0.000 TO !- CONSTANT PARAMETERS .......................... 0.000 ............. ! AUTOCURV= O.O00000E+O0 AUTOFILE= O.O00000E+O0 COMMENTS= 1.00000 FORCETYP= O.O00000E+O0 INFORECS= 1.00000 LISTFREQ= 50.0000 LISTMAX = O.O00000E+O0 USTMETH= O,O00000E+O0 SELFTEST= O.O00000E+O0 SPLITLIS= 1,00000 STATS = O.O00000E+O0 WRITEASC= O.O00000E+O0 WRITETAP= 1.00000 dpcoef = 1.00000 dpcte - 1.00000 d rlength = O.O00000E + O0 listwave = O.O00000E + O0 maxrecln = O.O00000E + O0 minrecln = O.O00000E + O0 nsamples= O.O00000E + O0 numcurvs = O.O00000E + O0 n umdatar= O.O00000E+O0 numrecfl= O.O00000E+O0 tfendep = O.O00000E+O0 fflevsp = O.O00000E+O0 ffstdep = O.O00000E+O0 wcrbot = O.O00000E+O0 wcrlevsp= O.O00000E + O0 wcrtop = O.O00000E +00 !-- ARRAY PARAMETERS SUBFILES( 1) = O.O00000E+O0 SUBFILES( 2) = -9999.00 ._ SUBFILES(3) =-9999.00 SUBFILES(4) =-9999.00 SUBFILES(5) =-9999.00 SUBFILES(6) =-9999.00 SUBFILES(7) =-9999.00 SUBFILES(8) =-9999.00 SUBFILES(9) = -9999.00 SUBFILES(10) = -9999.00 "" SUBFILES(11) = -9999.00 SUBFILES(12) = -9999.00 SUBFILES(13) = -9999.00 SUBFILES(14) = -9999.00 SUBFILES(15) = -9999.00 SUBFILES(16) = -9999.00 ... SUBFILES(17) = -9999.00 SUBFILES(18) = -9999.00 SUBFILES(19) = -9999.00 SUBFILES(20) = -9999.00 SUBFILES(21) = -9999.00 SUBFILES(22) = -9999.00 SUBFILES(23) = -9999.00 SUBFILES(24) = -9999.00 '" SUBFILES(25) = -9999.00 SUBFILES(26) = -9999.00 SUBFILES(27) = -9999.00 SUBFILES(28) = -9999.00 SUBFILES(29) = -9999.00 SUBFILES(30) = -9999.00 -.. SUBFILES(31) = -9999.00 SUBFILES(32) = -9999.00 SUBFILES(33) = -9999.00 SUBFILES(34) = -9999.00 SUBFILES(35) = -9999.00 SUBFILES(36) = -9999.00 -.. SUBFILES(37) = -9999.00 SUBFILES(38) = -9999.00 SEIBFILES(39) = -9999.00 SUBFILES(40) = -9999.00 SUBFILES(41) = -9999.00 SUBFILES(42) = -9999.00 SUBFILES(43) = -9999.00 SUBFILES(44) = -9999.00 -' SUBFILES(45) = -9999.00 SUBFILES(46) = -9999.00 SUBFILES(47) = -9999.00 SUBFILES(48) = -9999.00 SUBFILES(49) = -9999.00 SUBFILES(50) = -9999.00 _.. SUBFILES(51) = -9999.00 SUBFILES(52) = -9999.00 SUBFILES(53) = -9999.00 SUBFILES(54) = -9999.00 SUBFILES(55) = -9999.00 SUBFILES(56) = -9999.00 SUBFILES(57) = -9999.00 SUBFILES(58) = -9999.00 -' SUBFILES(59) = -9999.00 SUBFILES(60) = -9999.00 SUBFILES(61) = -9999.00 SUBFILES(62) = -9999.00 SUBFILES(63) = -9999.00 SUBFILES(64) = -9999.00 ,-. SUBFILES(65) = -9999.00 SUBFILES(66) = -9999.00 SUBFILES(67) = -9999.00 SUBFILES(68) = -9999.00 SUBFILES(69) = -9999.00 SUBFILES(70) = -9999.00 -. SUBFILES(71) = -9999.00 SUBFILES(72) = -9999.00 SUBFILES(73) = -9999.00 SUBFILES(74) = -9999.00 SUBFILES(75) = -9999.00 SUBFILES(76) = -9999.00 SUBFILES(77) = -9999.00 SUBFILES(78) = -9999.00 -'- SUBFILES(79) = -9999.00 SUBFILES(80) = -9999.00 SUBFILES(81) = -9999.00 SUBFILES(82) = -9999.00 SUBFILES(63) = -9999.00 SUBFILES(84) = -9999.00 -- SUBFILES(85) = -9999.00 SUBFILES(86) = -9999.00 SUBFILES(87) = -9999.00 SUBFILES(88) = -9999.00 SUBFILES(89) = -9999.00 SUBFILES(90) = -9999.00 SUBFILES(91) = -9999.00 SUBFILES(92) = -9999.00 SUBFILES(93) = -9999.00 SUBFILES(95) = -9999.00 SUBFILES(97) = -9999.00 SUBFILES(99) = -9999.00 SUBFILES(IO 1) = -9999.00 SUBFILES(103) = -9999.00 SUBFILES(105) = -9999.00 SUBFILES(107) = -9999.00 SUBFILES(109) -- -9999.00 SUBFILES(111) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(115) -- -9999.00 SUBFILES(117) = -9999.00 SUBFILES(119) = -9999.00 SUBFILES(121) = -9999.00 SUBFILES(123) -- -9999.00 SUBFILES(125) = -9999.00 SUBFILES(127) = -9999.00 SUBFILES(94) = -9999.00 SUBFILES(96) = -9999.00 SUBFILES(98) = -9999.00 SUBFILES(IO0) = -9999.00 SUBFILES(102) = -9999.00 SUBFILES(104) = -9999.00 SUBFILES(106) = -9999.00 SUBFILES(108) = -9999.00 SUBFILES(110) = -9999.00 SUBFILES(112) = -9999.00 SUBFILES(114) = -9999.00 SUBFILES(116) = -9999.00 SUBFILES(118) = -9999.00 SUBFILES(120) = -9999.00 SUBFILES(122) = -9999.00 SUBFILES(124) = -9999.00 SUBFILES(126) = -9999.00 SUBFILES(128) -- -9999.00 !-- STRING PARAMETERS INTERPOL= YES Input Tape Device, LU (1) is: TAPEC: Output Tape-Image file, LU (2) is: J:\1185\1185.TAP (Output Tape-Image file will be created) Listing Method ("LISTMETH") = 0, Depth Unit oriented listing. Listing Frequency ("LISTFREQ") is every ( 50) units of Depth. Listing output limiting (LISTMAX) not enabled... (to enable list limiting set USTMAX positive) Data Statistics reporting ("STATS") has not been enabled. (Specify STATS = 1 to enable this feature) Automatic curve renaming has been disabled by user input (AUTOCURV=0). Automatic "FILE= n" card generation is disabled. (This is the program default, AUTOFILE=0) (Specify AUTOFILE= 1 to enable this feature) LIS comment record decoding (COMMENTS= 1) has been enabled by user input. LIS information record decoding (INFORECS= 1) has been enabled by user input. The WRITEASC option has not been enabled... (to write ASCII subfiles specify WRITEASC= 1) Tape Subtile 1 is type: LIS **** REEL HEADER **** MWD 93/10/4 1185 01 **** TAPE HEADER **** MWD 93/10/4 1185 01 Tape Subtile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subtile 2 is type: LIS LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678,901234567890 TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: APl NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JO B DATA BIT RUN1 JOB NUMBER: 1185 LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD AGI-7 5O-029-22343 Arco Alaska Inc. BAKER HUGHES INTEQ 04 OCT 93 BIT RUN2 BIT RUN3 1185 S. BURKHARDT D. LENTZ J. GAFFANEY J. GAFFANEY 36.00 13,00 36 12N 14E 2291 2515 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (~I') 1 ST STRING 30.000 20.000 110.0 2ND STRING 16.000 13.375 3936.0 3RD STRING 12.250 9.625 10306.0 PRODUCTION STRING 8.500 REMARKS: $ **** FILE HEADER **** MWD .001 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 8303.0 11014.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ..... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP $ REMARKS: $ MERGE BASE NO DEPTH SHIFTING PERFORMED ON THIS TAPE. CN : Arco Alaska Inc. WN : AGI-7 FN : Prudhoe Bay COUN : North Slope STAT : Alaska LIS COMMENT RECORD(s): 123456789012345678,9012345678901234567890123456789012345678,9012345678901234567890 THIS FILE CONTAINS EDITED MERGED MWD DATA. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0000000 I 000 I Rep Code Count Bytes 68 4 16 Sum: 4 16 16 fndun a [F ] 1.00000000 Tape Subtile 3 is type: LIS **** FILE HEADER **** MWD .002 1024 LIS COMMENT RECORD(s)' 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 8303.0 10276.0 $ LOG HEADER DATA DATE LOGGED: , SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 23 FEB 93 M1.33 M1.33 MEMORY 0.0 8303.0 10276.0 0 41.3 49.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 1867-41 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 0.0 BOREHOLE CONDITIONS MUD TYPE: LT. DISPERS MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 41.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 1400 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 GR MWD 68 1 GAPI 4 4 98 660 71 6 2 RA MWD 68 I OHMM 4 4 98 660 71 6 3 ROP MWD 68 1 FPHR 4 4 98 660 71 6 4 RP MWD 68 1 OHMM 4 4 98 660 71 6 16 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 50 FRAMES * DATA RECORD (TYPE# O) 1006 BYTES * Total Data Records: 109 Tape File Start Depth = 8303.000000 Tape File End Depth = 11014.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6084 datums Tape Subtile: 2 177 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 1.430 MUD FILTRATE AT MT: 1.060 146.0 MUD CAKE AT MT: 0.000 0.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 12.250 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: $ CN : Arco Alaska Inc. WN : AGI-7 FN : Prudhoe Bay COUN : North Slope STAT :Alaska 0.0 144.0 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 4. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0 00 00 00 I 000 1 Rep Code Count Bytes 68 17 68 Sum: 17 68 68 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 ATCM MWD 68 I -dB 4 2 ATDC MWD 68 1 -dB 4 3 CADE MWD 68 1 MMHO 4 4 CPDE MWD 68 1 MMHO 4 5 DCCM MWD 68 1 4 6 GRAM MWD 68 1 GAPI 4 7 GRCM MWD 68 1 GAPI 4 8 PDCM MWD 68 I DEG 4 9 PDDC MWD 68 1 DEG 4 10 PDEM MWD 68 1 MINS 4 11 RACM MWD 68 1 OHMM 4 12 RADEMWD 68 1 OHMM 4 13 ROPAMWD 68 I FPHR 4 14 ROPSMWD 68 I FPHR 4 15 RPCMMWD 68 1 OHMM 4 16 RPDEMWD 68 I OHMM 4 17 TCDM MWD 68 1 DEGF 4 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98 660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660. 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98 660 71 6 4 98660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# O) 1014 BYTES * Total Data Records: 564 Tape File Start Depth = 8303.000000 Tape File End Depth = 10276.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 18179 datums Tape Subfile: 3 628 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subtile 4 is type: LIS **** FILE HEADER **** MWD .003 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 10316.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 10997.0 STOP DEPTH 28 APR 93 M1.33 M1.33 MEMORY 0.0 10316.O 10997.0 0 49.6 50.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 1639-35 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT)' 8.500 0.0 BOREHOLE CONDITIONS MUD TYPE: KCL FLO PRO MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 8.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 38500 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.070 MUD FILTRATE AT MT: 0.070 102.0 MUD CAKE AT MT: 0.000 0.0 0.0 102.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 10288 TO 10321' MD (7991 TO 8012' 'I'VD) WAS NOT LOGGED DUE TO BIT TO SENSOR OFFSET AT 9 5/8 IN. CASING POINT. INTERVAL FROM 10997 TO 11015' MD (8447 TO 8458' TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET AT THE 7 INCH CASING POINT. $ CN : Arco Alaska Inc. WN : AGI-7 FN : Prudhoe Bay COUN : North Slope STAT : Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 5. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141518 0 O0 1 O0 0 0 O0 0 1 0 O0 1 Rep Code Count Bytes 68 17 68 Sum: 17 68 68 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod 1 ATCM MWD 68 1 -dB 4 2 ATDC MWD 68 1 -dB 4 3 CADE MWD 68 1 MMHO 4 4 CPDE MWD 68 1 MMHO 4 5 DCCM MWD 68 I 4 6 GRAM MWD 68 1 GAPI 4 7 GRCM MWD 68 1 GAPI 4 8 PDCM MWD 68 I DEG 4 9 PDDC MWD 68 1 DEG 4 10 PDEM MWD 68 1 MINS 4 11 RACMMWD 68 1 OHMM 4 12 RADEMWD 68 1 OHMM 4 13 ROPAMWD 68 1 FPHR 4 14 ROPSMWD 68 1 FPHR 4 15 RPCMMWD 68 I OHMM 4 16 RPDEMWD 68 1 OHMM 4 17 TCDM MWD 68 1 DEGF 4 4 98 660 71 6 4 98 66O 71 6 4 98660 71 6 4 9866O 71 6 4 98660 71 6 4 98660 71 6 4 98 660 71 6 4 98660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98660 71 6 4 98 660 71 6 4 98 66O 71 6 4 98660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# O) 1014 BYTES * Total Data Records: 211 Tape File Start Depth = 10276.000000 Tape File End Depth = 11014.000000 Tape File Level Spacing -- 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12914 datums Tape Subfile: 4 281 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS **** TAPE TRAILER **** MWD 93/10/4 1185 01 **** REEL TRAILER **** MWD 93/10/4 1185 01 Tape Subtile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 4 OCT 93 9:32a Elapsed execution time = 1 minute, 1.5 seconds. SYSTEM RETURN CODE = 0 Tape Subtile 1 is type: LIS Tape Subtile 2 is type: LIS DEPTH GR RA ROP RP 8303.0000 80.9761 -999.2500 -999.2500 -999.2500 8303.5000 84.9486 -999.2500 -999.2500 -999.2500 8350.0000 74.0460 5.4456 -999.2500 5.2428 8400.0000 84.8610 5,3602 93.9002 5.4519 8450.0000 83.6978 7.9721 96.3713 7.1848 8500.0000 84.6987 9.2704 131.2550 8.2127 8550.0000 97.8417 7.4870 73.8309 6.8821 8600.0000 111.8078 7.7638 77.0410 6.9180 8650.0000 88.6303 7.0229 85.1653 6.5621 8700.0000 90.3092 8.8123 85,1653 8.2408 8750.0000 86.6815 8.0740 77.9172 7.6376 8800.0000 90.5567 7.9425 87.1931 7.4011 8850.0000 94.5273 8.5960 64.3818 8.1586 8900.0000 93.0344 6.8300 49.8732 6.6332 8950.0000 89.0323 8.6223 59.0663 8.0563 9000.0000 93.3950 11,1486 119.2488 9.7640 9050.0000 93.4743 10.4637 93.9002 9.2182 9100.0000 87.6815 7.5316 93.9002 6.8474 9150.0000 87.6568 8.5167 96.9317 9.3439 9200.0000 96.9740 12.3930 95.1572 10.5772 9250.0000 90.2221 15.9794 93.2601 14.4832 9300.0000 90.0634 12.0464 45.2112 11.0558 9350.0000 96.7200 8.5208 40.6901 8.0427 9400.0000 96.0906 9.5298 81.3161 8.3165 9450.0000 85.9301 6.2626 74.6781 5.9136 9500.0000 204.5949 4.5796 88.5971 4.6168 9550.0000 167,9152 12.0599 73.8309 9.1980 9600.0000 165.4155 4.3082 68.1516 4.2712 9650.0000 1 68,1095 5.8867 36.2585 5.5354 9700.0000 160.2967 6.2844 37.3390 6.8963 9750.0000 178.0640 4.0613 53.8121 4.1569 9800,0000 149.6133 3.7624 47.5224 3.6175 9850.0000 154.1765 5.9747 44.6599 5.2592 9900.0000 141.2989 7.8779 65.3948 6.8894 9950.0000 130.4744 8.2201 53.8545 6.6528 10000.0000 137.7301 7.8210 87.9148 6.8413 10050.0000 124.8851 4.4786 64.4342 4.5030 10100.0000 176.1715 8.3106 79.6665 8.0296 10150.0000 157.5381 7.4698 91.4806 8.2865 10200.0000 151.61 43 3.7095 66.5314 4.6380 10250.0000 215.7000 7.7014 48.1856 7.8170 10300.0000 -999.2500 -999.2500 107.7091 -999.2500 10350.0000 253,2084 11.0074 51.3606 9.1078 10400.0000 15.3919 -999.2500 78.7530 135.4872 10450.0000 15.6053 -999.2500 114.4409 264.2162 10500.0000 12.3289 -999.2500 110.0000 254.4156 10550.0000 11.4442 -999.2500 110.8856 208.7487 10600.0000 14.9213 -999.2500 101.2538 717.9972 10650.0000 9.9783 -999.2500 90.8688 513.0215 10700.0000 87.8412 -999.2500 20.7911 19.0560 10750.0000 8.1592 -999.2500 114.3188 604.4659 10800.0000 105.5729 19.2066 24.7245 9.5697 10850.0000 51.5479 -999.2500 87.1244 101.5025 10900.0000 43.6858 -999.2500 87.8374 93.2163 10950.0000 49.5205 -999.2500 84.8060 42.6921 DEPTH GR RA ROP RP 11000.0000 -999.2500 -999.2500 23.7799 -999.2500 11014.0000 -999.2500 -999.2500 26.8476 -999.2500 Tape File Start Depth = 8303.000000 Tape File End Depth = 11014.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subtile 3 is DEPTH DCCM PDEM RPCM 8303.0000 -999.2500 -999.2500 -999.25O0 8303.2500 -999.2500 -999.2500 -999.2500 8350.0000 102.7537 -999.2500 5.0297 8400.0000 100.9250 39.8333 5.2266 8450.0000 88.9175 26.8500 6.8633 8500.0000 83.67O8 40.0833 7.8303 8550.0000 90.6925 38.5333 6.5765 8600.0000 90.4717 50,6167 6.6111 8650.0000 92.6890 35.1333 6.2748 8700.00O0 83.5411 46.2833 7.8567 type: US ATCM GRAM RACM RPDE -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 80.9761 -999.2500 -999.2500 0.6745 74.0460 5.9678 5.2428 0.6864 84.8610 5.8542 5.4519 0.4557 83.6978 9.0619 7.1848 0.3859 84.6987 10.7358 8.2127 0.4876 97.8417 8.4466 6.8821 0.4684 111.8078 8.8070 6.9180 0.5219 88.6303 7.8664 6.5621 0.4096 90.3O92 10.1074 8.24O8 ATDC GRCM RADE TCDM -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 115.3811 -999.2500 -999.2500 0.7327 105.5066 5.4456 -999.2500 0.7431 120.9166 5.3602 117.0500 0.5153 119.2591 7.9721 118.4750 0.4457 120.6853 9.2704 120.4025 0.5469 139.4125 7.4870 121.7750 0.5284 159.3125 7.7638 124.1375 0.5806 126.2874 7.0229 125.1500 0.4682 128.6796 8.8123 127.2875 CADE PDCM ROPA -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 183.6349 10.1573 -999.2500 186.5598 9.9080 96.8346 125.4375 8.2799 95.4169 107.8699 7.5749 136.5168 133.5641 8.5195 75.3633 128.8028 8.4897 74.0618 142.3915 8,7895 84.1092 113.4782 7.5576 90.1138 CPDE PDDC ROPS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 190.7374 9.8880 -999.2500 183.4209 9.6398 93.9002 139.1823 8.O292 96,3713 121.7629 7.3322 131.2550 145.3051 8.2648 73.8309 144.5512 8.2360 77.0410 152.3904 8.5319 85.1653 121.3476 7.3151 85.1653 DEPTH DCCM PDEM RPCM ATCM GRAM RACM RPDE ATDC GRCM RADE TCDM CADE PDCM ROPA CPDE PDDC ROPS 8750,0000 86.7183 50.2000 7.2455 0,4507 86.6815 9.3975 7.6376 0.5091 123.5106 8.0740 128.8062 123.8546 7.9526 74.2551 130.9309 7.7041 77.9172 8800.0000 88.3319 56.4333 6.9620 0.4580 90.5567 8.9075 7.4011 0.5172 129.0322 7.9425 129.0875 125.9043 8.1208 84.0280 135.1157 7.8701 87.1931 8850.0000 83.3607 56.0167 7.8937 8900.0000 92.4744 59.9167 6.3062 0.4215 94.5273 9.8035 8.1586 0.5377 93.0344 7.5379 6.6332 0.4793 134.6899 8.5960 131.0000 0.5956 132.5626 6.8300 133.1375 116.3327 7.6034 61.3662 146.4137 8.7238 52.0182 122.5696 7.3619 64.3818 150.7567 8.4675 49.8732 8950.0000 64.9519 59.4667 7.5761 9000.0000 77.4403 30.9167 9.2699 0.4189 89.0323 10.0871 8.0563 0.3116 93.3950 12.8452 9.7640 0.4779 126.8602 8.6223 134.8250 0.3715 133.0764 11.1486 136.2875 115.9782 7.6728 59.8295 89.6973 6.7334 114.8019 124.1269 7.4258 59.0663 102.4170 6.5014 119.2468 9050.0000 79.4154 39.6833 8.7732 9100.0000 90.6557 29.9500 6.5822 0.3358 93.4743 12.5115 9.2182 0.4842 87.6815 8.6134 6.8474 0.3956 133.1895 10.4637 137.0750 0.5436 124.9355 7.5316 137.9750 95.5681 7.0041 93.9002 132.7739 8.5424 94.1283 108.4808 6.7675 93.9002 146.0418 8.2895 93.9002 9150.0000 80.5510 39.5667 8.5056 9200.0000 74.7164 31.7829 10.0272 0.4280 87.6568 9.6955 9.3439 0,2737 96.9740 14.8956 10.5772 0.4836 124.9002 8.5167 139.3250 0.3340 138.1762 12.3930 139.8875 117.4167 6.9437 95,5548 80.6907 6,3735 96.5600 107.0215 6.7040 96.9317 94.5428 6.1457 95.1572 9250.0000 65.1129 59.8656 13.5970 0.1991 90.2221 20.8667 14.4832 0.2570 128.5555 15.9794 141.5375 62.5805 5.1073 92.5928 69.0454 4.9007 93.2601 DEPTH DCCM PDEM RPCM ATCM GRAM RACM RPDE ATDC GRCM RADE TCDM CADE PDCM ROPA CPDE PDDC ROPS 9300.0000 72.8226 66.6824 10.6098 9350.0000 84.4791 201.4328 7.6685 0.2856 90.0634 14.8749 11.0558 0.4250 96.7200 9.7304 8.0427 0.3437 128.3293 12.0484 141.8000 0.4834 141.2094 8.5208 1 43.6562 82.9987 6.1793 45.5162 117.3604 7.6797 43.3902 90.4502 5.9560 45.2112 124.3369 7.4343 40.6901 9400.0000 83.1992 41.5500 7.9271 9450.0000 97.2060 60.4667 5.6646 0.3734 96.0906 11.0905 8.3165 0.5866 65.9301 6.9428 5.9136 0.4337 140.2905 9.5298 140.2250 0.6453 125.4565 6.2626 141.9687 104.9337 7.5083 81.7285 159.6772 9.3989 72.7318 120.2426 7,2658 81.3161 169.1021 9.1369 74.6781 9500.0000 108.9802 35.6500 4.4364 9550.0000 79.4970 55.7000 8.7536 0.7969 204.5949 4.9534 4.6168 0.2799 167.9152 14.7242 9.1980 0.8538 298.7049 4.5796 143.8625 0.3433 245.1532 12.0599 145.1750 218.3584 11.0050 89.7054 82.9197 7.0143 74.7545 216.5994 10. 7287 88.5971 108.7198 6.7778 73.8309 9600.0000 112.9749 67.6000 4.1095 9650.0000 100.2140 209.3333 5.3063 0.6429 165.4155 4.6461 4.2712 0.6238 168.1095 6.4958 5.5354 0.9002 237.9815 4.3082 145.6250 0.6826 240.1425 5.8867 144.8375 232.1176 11.5506 73.4127 169.8730 9.8066 35.1989 234.1274 11.2719 68.1516 180.6539 9.5401 36.2585 9700.0000 90.6042 81.6667 6.5903 0.5884 160.2967 6.9194 6.8963 0.6431 231.1549 6.2844 142.3625 159.1240 8.5027 40.9432 145.0045 8.2484 37.3390 975O.OO00 114.4177 60.6333 4.00O3 0.8908 178.0840 4.3610 4.1569 0.9472 262.0841 4.0613 1 40.6437 246.2266 11.7484 51.5915 240.5654 11.4671 53.8121 9800.0000 122.0755 91.7833 3.4874 0.9530 149.6133 4.0325 3.6175 1.0110 212.2612 3.7624 142.0812 265.7862 12.7990 49.8372 276.4356 12.5112 47.5224 DEPTH ATCM ATDC CADE CPDE DCCM GRAM GRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 9850.0000 0.6129 0.6735 167.3714 190.1447 102.6010 154.1765 227.9548 10.1319 9.8636 66.4167 6.6216 5.9747 48.6774 44.6599 5.0457 5.2592 141.8000 9900.0000 0.4603 0.5209 126.9376 145.1503 90.6471 141.2989 202.5460 8.5085 8.2540 77.3167 8.9614 7.8779 64.5492 65.3948 6.5836 6.8894 144.2750 9950.0000 0.4375 0.5002 121.6531 150.3136 92.1032 130.4744 179.4664 8.7054 8.4494 47.0500 9.4426 8.2201 52.9193 53.8545 6.3611 6.6528 145.0063 10000.0000 0.4639 0.5244 127.8615 146.1700 90,9288 137.7301 208.5687 8.5466 8.2928 48.4667 8.8897 7.8210 82.8733 87.9148 6.5396 6.8413 146.7125 10050.0000 0.8134 0.8704 223.2829 222.0762 110.2393 124.8851 181.0512 11.1759 10.8998 41.3333 4.8383 4.4786 64.3642 64.4342 4.3293 4.5030 147.2000 10100.0000 0.4372 0.4950 120.3284 124.5388 84.5406 176.1715 258.2225 7.6864 7.4410 49.9833 9.4499 8.3106 77.8179 79.6665 7.6564 8.0296 148.3250 10150.0000 0.4928 0.5477 133.8725 120.6784 84,1753 157.5381 232.2777 7.5280 7.2823 64,5833 8.4001 7.4698 87.7616 91.4806 7.7287 8.2865 148.3250 10200.0000 0.9719 1.0232 269.5808 215.6111 108.7547 151.6143 231.7133 10.9728 10.6960 256.0687 3.9411 3.7095 71.7857 66.5314 4.4560 4.6380 145.0625 10250.0000 0.4762 0.5326 129.8465 127.9266 85.5691 215.7000 300.6884 7.8315 7.5857 40.0333 8.5487 7.7014 40.7477 48.1856 7.4581 7.8170 144.0500 10276.0000 0.6836 0.7311 183.1533 122.7393 83.9741 -999.2500 -999.2500 7.6176 7.3746 47.9333 5.8705 5.4599 91.1253 90.8688 7.7690 8.1474 144.2750 Tape File Start Depth = 8303.000000 Tape File End Depth = 10276.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS DEPTH ATCM ATDC CADE CPDE DCCM GRAM GRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 10276.0000 0.6836 0.7311 183.1533 122.7393 83.9741 -999.2500 -999.2500 7.6176 7.3746 47.9333 5.8705 5.4599 91.1253 90.8688 7. 7690 8.1474 144.2750 10276.2500 0.6849 0.7315 183.2720 118.1~.~.~· 82.5337 -999.2500 -999.2500 7.4249 7.1842 48.0167 5.8050 5.4564 91.1253 91.0398 8.0668 8.4642 144.2750 10300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 104.4342 107.7091 -999.2500 -999.2500 144.7250 10350.0000 0.3072 0.3697 90.8481 109.7961 80.6937 253.2084 263.4135 6.9710 6.7312 29.5667 12.9915 11.0074 49.2665 51.3606 8.4728 9.1078 95.1125 10400.0000 -999.2500 -999.2500 -999.2500 7.3808 28.1495 15.3919 16.0122 0.7698 0.6909 19.4333 -999.2500 -999.2500 84.4332 78.7530 103.0587 135.4872 95.1125 10450.0000 -999.2500 -999.2500 -999.2500 3.7848 23.3500 15.6053 16.2342 0.3920 0.3347 10.9829 -999.2500 -999.2500 111.7970 114.4409 175.1357 264.2162 98.0375 10500.0000 -999.2500 -999.2500 -999.2500 3.9306 23.1776 12.3289 12.8258 0.4069 0.3499 11.5994 -999.2500 -999.2500 113.0445 110.0000 179.0621 254.4156 100.7375 10550.0000 -999.2500 -999.2500 -999.2500 4.7904 24.4513 11.4442 11.9055 0.5005 0.4378 14.6161 -999.2500 -999.2500 101.7171 110.8856 152.9218 208.7487 102.9875 10600.0000 -999.2500 -999.2500 -999.2500 1.3928 18.5747 14.9213 15.5226 0.1094 0.0713 11.8161 -999.2500 -999.2500 96.7785 101.2538 369.5110 717.9972 104.7875 10650.0000 -999.2500 -999.2500 -999.2500 19.7062 9.9783 10.3805 0.1763 14.3667 -999.2500 -999.2500 89.2066 300.1533 513.0215 107.3750 1.9492 0.1340 90.8688 DEPTH ATCM ATDC CADE CPDE DCCM GRAM GRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 10700.0000 -999.2500 -999.2500 -999.2500 52.4768 58.3526 87.8412 91.3815 4.0893 3.8991 32.6000 -999.2500 -999.2500 21.1978 20.7911 17.3948 19.0560 110.3000 10750.0000 -999.2500 -999.2500 -999.2500 19.1187 8.1592 8.4881 0.1410 11.0500 -999.2500 -999.2500 114.2840 333.2974 604.4659 112.6625 1.6544 0.1010 114.3188 10800.0000 0.1306 0.2063 52.0653 104.4969 78.7447 105.5729 109.8278 6.7332 6.4970 21.2000 28.4691 19.2066 25.0829 24.7245 8.9373 9.5697 115.2500 10850.0000 -999.2500 -999.2500 -999.2500 30.5343 51.5479 53.6254 1.0054 16.0500 -999.2500 -999.2500 89.4253 82.9620 101.5025 116.5625 9.8520 0.9155 87.1244 10900.0000 -999.2500 -999.2500 -999.2500 10.7277 31.4371 43.6858 45.4464 1.0876 0.9938 12.0333 -999.2500 -999.2500 88.3933 87.8374 76.8810 93.2163 117.7250 10950.0000 -999.2500 -999.2500 -999.2500 23.4236 42.8756 49.5205 51.5164 2.1572 2.0171 28.4833 -999.2500 -999.2500 67.3088 84.8060 35.5712 42.6921 119.1875 11000.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 23.2139 23.7799 -999.2500 -999.2500 122.0000 11014.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 26.8476 26.8476 -999.2500 -999.2500 122.9000 Tape File Start Depth = 10276.000000 Tape File End Depth = 11014.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subfile 5 is type: LIS
