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194-132
XHVZE Pages NOT Scanned in this Well History File 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. / ~ ~ -I ,~ ¢~, File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bev~ncent Nathan Lowell Date: [] TO RE-SCAN Notes' Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si ax,. STATE OF ALASKA AKA OIL AND GAS CONSERVATION CO ISSION OCT 0 3 ZO1Z ` REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory " 194 - 132 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 22513 - 00 -go 7. Property Designation (Lease Number): 8. Well Name and Number: _ ADL 025518 & 028231 MPE - 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point / Ku River Sands 11. Present well condition summary Total depth: measured 14570' feet Plugs (measured) None feet true vertical 7231' feet Junk (measured) 11792' feet Effective depth: measured 14520' feet Packer: (measured) None feet true vertical 7207' feet Packer: (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 32' - 112' 32' - 112' 1490 470 Surface 3784' 9 -5/8" 30' - 3814' 30' - 3021' 5750 3090 Intermediate 13712' 7" 27' - 13739' 27' - 6880' 7240 5410 Production Liner 983' 5" 13582' - 14565' 6819' - 7228' 8290 7250 Perforation Depth: Measured Depth: 14002' - 14495' True Vertical Depth: 6980' - 7195' Tubing (size, grade, measured and true vertical depth): 2 - 7/8 ", 6.5# L - 11584' 6075' Packers and SSSV (type, measured and true vertical depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): JAN 2 3 2013 Treatment description including volumes used and final pressure: SCANNED 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water-Bbl— . , Casing Pressure Tubing Pressure Prior to well operation: 58 37 2547 210 175 Subsequent to operation: 61 49 2320 200 186 14. Attachments: ❑Copies of Logs and Surveys run 15. Well Class after work: ,. ❑ Exploratory ® Development ❑ Service ❑ Stratigraphic Daily Report of Well Operations El Well Schematic Diagram s 16. Well Status after work: -, ® Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Sean McLaughlin, 564 -4387 N/A Printed m Joe s Title Drilling Technologist Si nature '`, P one 564 -4091 Date Q /3/�� Jo Prepared By Name /Number: g Joe Lastufka, 564-4091 Form 10-404 Re sed 11/201 P inIMArDivls OCT 0 5 101 bmit Original Only i'l F10l911-7 40 r % / • • Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE @54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/5/2012 12:00 - 16:30 4.50 MOB P PRE PJSM FOR RIG MOVE - PERFORM EQUIPMENT CHECKS AND FUNCTION HYDRAULIC SYSTEM, - PREPARED RIG TO MOVE OFF OF MPE -31 - MOVE CUTTINGS TANK AND CHANGE TRAILER AWAY FROM RIG - MOVE RIG OFF MPE -31 - MOVE RIG ON MATS FROM MPE -31 TO MPE -09 MOVE RIG MATS AWAY FROM MPE -31 AND PLACE AROUND MPE -09 16:30 - 18:00 1.50 MOB P PRE SPOT RIG OVER WELL - SHIM AND LEVEL RIG 18:00 - 20:30 2.50 MOB P PRE ACCEPT RIG AT 18:00 HOURS - SPOT CUTTINGS TANK - PREP TO TAKE ON SEA WATER - R/U WELL KILL MANIFOLD AND CIRCULATING LINES IN CELLAR - SPOT CREW CHANGE TRAILER AND FUEL TANK 20:30 - 22:30 2.00 MOB P PRE R/U RIG FLOOR - M/U 4" TIW AND DART VALVES FOR TESTING 22:30 - 23:00 0.50 - MOB P PRE RIG EVACUATION DRILL WITH "C" CREW - HOLD RIG EVACUATION DRILL AND AAR WITH ALL INVOLVED - GOOD CREW PARTICIPATION. - DISCUSSED WIND DIRECTION AWARENESS DURING TOUR - REVIEWED EMERGENCY SHUT DOWN SYSTEM 23:00 - 00:00 1.00 MOB P PRE CONTINUE R/U FLOOR VALVES - TAKE ON 100 BBLS OF 120 DEGREE SEA WATER 9/6/2012 00:00 - 01:30 1.50 MOB P PRE RIG UP TO KILL WELL - SPOT FLOW -BACK TANK. - RIG UP HARD LINE FROM TANK TO CHOKE MANIFOLD AND TEST. 01:30 - 02:00 0.50 MOB P PRE RIG EVACUATION DRILL WITH "D" CREW - HOLD RIG EVACUATION DRILL AND AAR WITH ALL INVOLVED - GOOD CREW PARTICIPATION. - DISCUSSED ANOUNCMENTS OVER THE HARMONY HUB. - THIRD PARTY CREWS ALL RESPONDED TO DRILL ANNOUNCEMENT. 02:00 - 05:00 3.00 WHSUR P DECOMP PJSM FOR TESTING LINES - TEST WELL KILL MANIFOLD AND ALL LINES FROM RIG PUMP TO FLOW -BACK TANK - 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES 05:00 - 07:00 2.00 WHSUR P DECOMP PJSM TO PULL BPV - M/U WELL SUPPORT LUBRICATOR - TEST LUBRICATOR TO 250 PSI, 3500 PSI, 5 MINUTES, CHARTED - PULL BPV , SITP = 1700 PSI. - IA = 1500 PSI OA= 130 PSI Printed 10/1/2012 11:00:01AM r: Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE @54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 08:00 1.00 WHSUR P DECOMP DOUBLE CHECK ALL LINES, PREP TO KILL WELL. 08:00 - 08:30 0.50 KILLW P DECOMP PRE KILL MEETING WITH ALL HANDS INVOLVED. - EMPHASIS ON PROPER VALVE ALIGNMENT, KNOWING WHERE YOUR PRESSURE IS AND SKILLED COMMUNICATION TECHNIQUES. - ASSIGN TASKS AND IMPART EXPECTATIONS. FLUID MONITORING. MILNE PT AND DRILL SITE OPERATOR NOTIFIED OF GAS VENTING. - SIGNS POSTED. 08:30 - 09:45 1.25 KILLW P DECOMP LINE UP TO BLEED GAS OFF OF THE IA THRU THE CHOKE AND TO THE FLOW -BACK TANK. BLEED OFF GAS, KEEPING PRESSURE DOWN STREAM OF THE CHOKE AT OR BELOW 150 PSI. BLEED FOR (1) HOUR WITH NO SIGN OF FLUID TO SURFACE AND SITP CAME DOWN TO 1325 PSI. CONSULT WITH ODE AND AGREE TO PROCEED TO PUMPING KILL WT FLUID. IA AT 1325 PSI. 09:45 - 10:30 0.75 KILLW P DECOMP LINE UP VALVES AND CHECK ALIGNMENT. PROCEED TO PUMP DOWN THE TUBING WITH 120 DEGREE SEAWATER, TAKING RETURNS UP THE IA, THRU THE CHOKE AND TO THE FLOW -BACK TANK. - BRING PUMP SLOWLY UP TO 4 BPM / 1275 PSI ICP. - PUMPED 80 BBLS, SHUT IN CHOKE AND BULLHEAD 35 BBLS AT 4 BPM / 1300 PSI FCP. - OPEN CHOKE HOLDING 1200 - 1300 PSI BACK PRESSURE. - PUMP 50 BBLS DOWN TUBING, RETURNS UP IA. - SHUT DOWN PUMP, SHUT IN WELL. 10:30 - 11:00 0.50 KILLW P DECOMP STRAP FLOW -BACK TANK, 30 BBLS IN TANK, NO GAIN. - CHECK PRESSURES, TBG AND I A AT 1100 PSI SHUT IN PRESSURES. 11:00 - 12:30 1.50 KILLW P DECOMP OPEN WELL AND RESUME PUMPING DOWN TBG, 5 BPM / 1100 PSI. - TAKING GAS RETURNS THRU CHOKE TO FLOW -BACK TANK. - PUMP 420 BBLS, FCP = 1200 PSI @ 5 BPM. 12:30 - 12:45 0.25 KILLW P DECOMP STOP PUMPING, SHUT IN WELL. - STRAP FLOW -BACK TANK, 66 BBLS IN TANK. - TUBING = 0 PSI, VA = 0 SPI. 12:45 - 13:15 0.50 KILLW P DECOMP OPEN WELL, RESUME PUMPING. PUMPING 5 BPM / 1300 PSI FCP, 0 PSI ON IA. - - PUMPED ANOTHER 100 BBLS, 570 TOTAL PUMPED AFTER BULLHEAD. - UNABLE TO GET FLUID RETURNS, GAS RETURNS SLOW DOWN TO NOTHING. SHUT DOWN, TBG AND IA ON A VACUUM. 13:15 - 14:30 1.25 KILLW P DECOMP CONSULT ODE, OPT TO BULLHEAD. - LINE UP AND BULLHEAD DOWN IA. - BRING PUMP ON AT 8 BPM / 0 PSI. - PUMP 425 BBLS TOTAL, DOWN THE VA. FCP AT 6 1/2 BPM = 500 PSI. Printed 10/1/2012 11:00:01AM ...... ... ... -. Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE @54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 16:30 2.00 KILLW P DECOMP SHUT DOWN PUMP, IMMEDIATELY CHECK IA AND TUBING. - BOTH IA AND TUBING ON A STRONG VACUUM. - RIG DOWN LINES AND MONITOR WELL. - LOAD DRILL PIPE INTO PIPE SHED AND STRAP. WELL IS DEAD. 16:30 - 18:00 1.50 WHSUR P DECOMP PJSM. PICK UP LUBRICATOR TO SET TWO WAY CHECK VALVE. M/U LUBRICATOR, RUNNING TOOL, AND TWC.ASSY TO TREE - ATTEMPT TO TEST LUBRICATOR, TREE VALVES NOT HOCKING PRESSURE CALLED - MPU VALVE CREW CAI_ OU T AND GREASED TREE VALVES - TEST LUBRICATOR 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED, GOOD TEST - INSTALL TWC 18:00 - 19:00 1.00 WHSUR P DECOMP TEST TWC' TEST FROM ABOVE 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - ROLL TEST FROM BELOW, 24 BBLS PUMPED, 30 PSI. ROLLING TEST FROM BELOW FAILED. NOTE, DURING BULLHEAD SEGMENT OF KILL OPERATIONS, 375 BBLS WERE BULLHEADED DOWN THE VA @ 6 - 8 BPM BEFORE ACHIEVING ANY SIGNIFICANT PRESSURES RE OVER 100 PSI. 19:00 - 21:30 2.50 WHSUR P - DECOMP PJSM, N/D TREE - N/D TREE AND ADAPTER FLANGE + - FMC REP. FUNCTION LOCK DOWN SCREWS - CHECKED TUBING HANGER THREADS, 8 RH TURNS WITH 3 1/2" NSCT PUP JT - MAINTAIN CONTINUOUS HOLE FILL THROUGH IA AT 20 BPH 21:30 - 00:00 2.50 BOPSUR P DECOMP PJSM, N/U BOP - BOP CONFIGURATION = ANNULAR, 3 1/2" X 6" VARIABLES, BLINDS, MUD CROSS, 2 7/8" SOLID RAMS - R/U TEST EQUIPMENT - M/U FLOOR VALVES -OA =PSI - 24 HR TOTAL FLUID LOSS = 1181 BBLS 9/7/2012 00:00 - 03:30 3.50 BOPSUR P DECOMP PJSM, PERFORM EQUIPMENT AND SPCC CHECKS - CONTINUE N/U BOP AND TEST EQUIPMENT - CONTINUE TO LOAD AND STRAP DRILL PIPE Printed 10/1/2012 11:00:01AM 1 yr Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE @54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 03:30 - 10:00 6.50 BOPSUR P (ft) DECOMP PJSM, TEST BOP PER AOGCC REGULATIONS ty AND DOYON TEST PROCEDURE X - PERFORM DRAW DOWN TEST ON ACCUMULATOR - FOLLOW CURRENT DOYON MPL TEST PROCEDURE - TEST ALL BOP AND CHOKE MANIFOLD VALVES TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES, CHARTED - TEST ANNULAR USING 2 7/8" TEST JOINT - TEST 3 1/2" X 6" VBR PIPE RAMS USING 4" TEST JOINT - TEST 2 7/8" SOLID RAMS WITH 2 7/8" TEST JT TEST BOTH SETS OF 2 7/8" AND 4" FLOOR VALVES - TEST USING FRESH WATER - NO FAILURES - CONTINUOUS HOLE FILL DURING OPERATION. - JEFF JONES OF AOGCC WAIVED STATE'S RIGHT TO WITNESS BOP TEST AT 15:00 HRS 96 -12 10:00 - 11:00 1.00 BOPSUR P DECOMP "RIG DOWN TEST EQUIPMENT - BLOW DOWN LINES. 11:00 - 13:00 2.00 WHSUR P DECOMP PJSM. PICK UP LOPSO / OPSO. SCREW IN TO HANGER. - PRESSURE TEST, 250 / 3500 PSI, 5 MIN EACH. - PULL TWO WAY CHECK V U L O W C C VALVE, TUBING IS ON A VACUUM. - UD TWC AND LOPSO / OPSO. 13:00 - 18:00 5.00 PULL P DECOMP PJSM, FOR PULLING HANGER TO RIG FLOOR - MAKE UP CROSSOVERS TO LANDING JT - SCREW INTO HANGER, (8) TURNS. - M/U TOP DRIVE - BACK OUT LOCK DOWN SCREWS, CLEAR FLOOR - PULL UP OBSERVE NO OVER PULL - PULL LANDING JT TO RIG FLOOR - NSCT PUP JT LEFT IN HOLE SCREWED INTO HANGER - RAN IN LOCK DOWN SCREWS - NOTIFY ODE OF OPERATIONS, RECEIVED APPROVAL TO PROCEED - LANDING JT PULLED OUT OF PUP JT DUE li TO INCOMPATIBLE THREADS - RETRIEVED NSCT PUP JT FROM HANGER - M/U NEW NSCT PUP JT TO LANDING JOINT AND SCREW INTO HANGER - BACK OUT LOCK DOWN SCREWS - MAINTAIN CONTINUOUS HOLE FILL DOWN IA AT 20 BPH Printed 10/1/2012 11:00:01AM Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE @54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 19:30 1.50 PULL P DECOMP PULL HANGER TO RIG FLOOR - HANGER PULLED FREE WITH 110K - TOP DRIVE = 40K, PULL ON TUBING = 85K. - POOH ONE FULL JT TO FIRST ESP CABLE CLAMP, PUWT = 125K - PUWT = 125K, SOWT = 70K - CUT ESP CABLE - LOWER STRING AND PLACE SLICK PIPE ACROSS BOP - LAY DOWN HANGER AND LANDING JT M/U TIW AND PUMP IN SUB 19:30 - 20:00 0.50 PULL P DECOMP UNABLE TO ESTABLISH CIRCULATION CLOSE ANNULAR - BULLHEAD 80 BBLS 8.5 SEAWATER DOWN TUBING INTO FORMATION - 5 BPM = 1220 PSI - CHECK FOR PRESSURE, OPEN ANNULAR, MONITOR WELL 10 MINUTES - MAINTAINCONTINUOUS HOLE FILL DOWN IA AT 20 BPH 20:00 - 22:00 2.00 PULL P DECOMP PJSM FOR RIG UP TO PULL ESP HANG ESP CABLE SHEVAVE IN DERRICK. RIG UP ELEPHANT TRUNK SPLASH GUARD FOR ESP CABLE. - RIG UP POWER TONGS. 22:00 - 00:00 2.00 PULL P DECOMP POH ESP COMPLETION. STAND BACK 2 7/8" TUBING - POH 2 7/8" EUE 8RD TUBING AND STAND BACK IN DERRICK. - RECOVER ESP CABLE. - REMOVE LASSALE CABLE CLAMPS. - POH TO 12,181'. UP WEIGHT 115K, DOWN WEIGHT 70K - NOTED 8K OVER PULL AT 11,826' PULLED THRU OK. - NOTED SCALE ON OUTSIDE OF PIPE AT 600'. - NO NOTICABLE DAMAGE TO ESP CABLE OR TUBING. PUMPING SEAWATER DOWN IA AT 20 BPM, NO RETURNS. LOSSES TO WELL IN LAST 24 HOURS= 526 BBL OA PRESSURE 140 PSI 9/8/2012 00:00 - 09:30 9.50 PULL P DECOMP POH 2 7/8" EUE 8RD TUBING AND STAND BACK IN DERRICK. - RECOVER ESP CABLE. - REMOVE LASSALE CABLE CLAMPS. - POH FROM 12,181' TO 682'. UP WEIGHT 85K, DOWN WEIGHT 67K. - NO NOTICABLE DAMAGE TO ESP CABLE OR TUBING. PUMPING SEAWATER DOWN IA AT 20 BPH, NO RETURNS. Printed 10/1/2012 11:00:01AM Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE @54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 14:00 4.50 PULL N WAIT DECOMP A 2" DIAMETER DUST CAP FELL FROM THE 2 7/8" ELEVATORS - THE CAP FELL 90' - DUST CAP WEIGHT .75 OZ. - DUST CAP WAS LOCATED ON TOP OF THE EVEVATOR HINGE PIN. - REPORTED TO WTL, RWO SUPERINTENDANT, BP AND DOYON SAFETY. - SENT PICTURES OF COMPONENTS TO PARTIES INVOLVED. - ORDERED REPLACEMENT ELEVATORS. - FLUID LOST TO WELL LAST (12) HOURS = 238 BBLS SEAWATER. 14:00 - 14:30 0.50 PULL P DECOMP ('OOH 2 7/8" ESP COMPLETION. - NOTICED GAS VAPORS OUT OF TUBING AT SURFACE. - BHA AT 682' - NO FLOW, END OF PIPE ABOVE STATIC FLUID LEVEL. - NO PRESSURE OBSERVED. 14:30 - 15:00 0.50 PULL P DECOMP PJSM. RIG UP CIRCULATING. - PUMP 100 BBLS SEAWATER DOWN TBG, AT 6 BPM WITH 10 PSI. - NO RETURNS. STOP PUMPING. WELL ON VACUUM. 15:00 - 16:30 1.50 PULL P DECOMP CONTINUE TO POOH AND UD ESP ASSEMBLY. `f - ASSEMBLY PARTED AT BOTTOM OF THE, l LOWER PUMP. - RECOVERED 222 LASSALE CLAMPS AND 3 PROTECTOLIZER CLAMPS. 1-UT IN HOLE. __ - LOWER 5" OF LOWER MOTOR. - TANDEM GAS SEPARATOR. - TANDEM SEAL SECTION. ONE 266 HP MOTOR. - PHOENIX MS1 SENSOR - CENTRALIZER 5.85 "OD. - TOP OF FISH 13,478' IF NOT DOWN TO TOP OF 5" LINER - TOP OF FISH 13,537' IF FALLEN TO TOP OF 5" LINER - TOWN ODE NOTIFIED, PICTURES SENT. 16:30 - 21:00 4.50 FISH N DFAL 13,500.00 DECOMP CONSULT WITH ODE, FIELD RWO SUPERINTENDENT, BAKER FISHING, AND CENTRILIFT ON PLAN FORWARD. - RECEIVED TOWN APPROVAL TO PROCEED - WILL RUN ROPE SPEAR WITH 6" OD PUSH PLATE - CONSULT BAKER FISHING SERVICE - LOAD DRILL COLLARS INTO PIPE SHED - INSTALL WEAR BUSHING. Printed 10/1/2012 11:00:01AM Common Well Name: Mk-09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE @54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 00:00 3.00 FISH N DFAL DECOMP PJSM. PICK UP FISHING BHA. - MOBILIZE FISHING TOOLS FROM DEADHORSE. - PREPARE RIG FLOOR AND PIPE SHED TO PICK UP DRILLPIPE. - MOBILIZE TOOLS TO RIG FLOOR. PUMPING SEAWATER DOWN IA AT 20 BPH, NO RETURNS. SEAWATER LOST TO WELL LAST 24 HOURS 589 BBL OA PRESSURE 144. PSI 9/9/2012 00:00 - 01:30 1.50 FISH N DFAL DECOMP `PJSM. PERFORM EQUIPMENT CHECK AND SPCC I I - RIG DOWN AND REMOVE HYDRAULIC TONGS FROM FLOOR. - RIG UP BHA HANDLING EQUIPMENT. - MAKE UP 2 7/8" SAFETY JOINT. STORE IN PIPE SHED. 01:30 - 03:00 1.50 FISH N DFAL DECOMP'` PJSM WITH BAKER FISHING REP AND CREW. - MAKE UP ROPE SPEAR WITH 6" OD STOP RING. - PICK UP DRILL COLLARS. - RIH FISHING BHA. 03:00 - 04:30 1.50 FISH N DFAL DECOMP RIH WITH 4" DRILL PIPE. - PICK UP SINGLES OUT OF PIPE SHED. - OBSERVE GAS "EXHALING" UP DP, NO PRESSURE. 04:30 - 05:00 0.50 FISH N DFAL DECOMP PJSM. MAKE UP HEAD PIN. - PUMP 50 BBLS DOWN DP, 3 BPM / 30 PSI. - NO RETURNS, WELL ON VACUUM. 05:00 - 12:00 7.00 FISH N DFAL DECOMP CONTINUE IN HOLE, PICKING UP SINGLES. - RIH F/ 1065' - 7951'. UP WT = 140K, DOWN WT = 95K. - ALL WTS INCLUDE 40K TOP DRIVE. - FLUID LOST TO WELL LAST (12) HRS = 355 BBLS SEAWATER. 12:00 - 12:30 0.50 FISH P DECOMP INSPECT EQUIPMENT AND SERVICE RIG. - CREW COMING ON HAD WEEKLY SAFETY MEETING. - DISCUSSED DRILLS & PROCEDURES FOR DRILLS. - WELL CONTROL AND CROSSOVER IDENTIFICATION. 12:30 - 17:30 5.00 FISH N DFAL DECOMP PJSM. CONTINUE TO RIH W/ 4" HT -38 DRILL PIPE. - PICKING UP SINGLES OUT OF THE PIPE SHED. - CONTINUOUSLY PUMPING 20 BPH DOWN THE WELL BORE. 17:30 - 19:00 1.50 FISH N DFAL DECOMP PJSM, SLIP AND CUT DRILLING LINE. - GATHER TOOLS AND EQUIPMENT TO SLIP AND CUT DRILLING LINE. - CUT 55' OF DRILLING LINE Printed 10/1/2012 11:00:01AM Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE ©54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 21:00 2.00 FISH N DFAL DECOMP RIH WITH FISHING BHA. - RIH WITH FISHING BHA TO 11,760', PICK UP SINGLES. - TAKE WEIGHT AT 11,760' - WORK PIPE. MAKE UP TOP DRIVE - WORK PIPE, UP WEIGHT 200K, DOWN WEIGHT 100K. SET DOWN 8K TO 10K - TURN PIPE 2 RIGHT HAND TURNS, WORK PIPE. - PASS OBSTRUCTION AND WORK DOWN TO 11,792', TAKING WEIGHT. - WORK PIPE UP AND DOWN WITH RIGHT HAND ROTATION 2 TURNS AT A TIME. - SET DOWN 15K TO 20K NO PROGRESS. - CONFIRM PICK UP WT, SLACK OFF WT AND ROTATING WT. LOWER ROPE SPEAR SLOWLY WHILE ROTATING AT 10 RPM WITH 7000 TORQUE. - TAG OBSTRUCTION AT 11,792' 21:00 - 00:00 3.00 FISH N DFAL DECOMP PJSM TO POH - DISCUSS PIPE RACKING STRATEGY. SOME PIPE WILL HAVE TO BE LAID DOWN CONTINUOUS HOLE FILL AT 20 BPH - POH STAND BACK 4" DRILL PIPE. PUMPING SEAWATER DOWN IA AT 20 BPH, NO RETURNS. SEAWATER LOST TO WELL LAST 24 HOURS 638 BBL OA PRESSURE 146 PSI 9/10/2012 00:00 - 03:00 3.00 FISH N DFAL DECOMP HELD WEEKLY SAFETY MEETING PRIOR TO STARTING SHIFT. PJSM. PERFORM EQUIPMENT CHECK AND SPCC - DISCUSSED HOLE FILL WHILE POH. - DISCUSSED STANDING BACK DRILL COLLARS AND LAY DOWN BHA. - POH FROM 8931' TO 2676', STAND BACK 4" DRILL PIPE - CONTINUOUSLY PUMPING SEAWATER 20 BPH DOWN THE WELL. - OBSERVE GAS "EXHALING" UP DP, NO PRESSURE. - STOP PULLING PIPE 03:00 - 03:30 0.50 FISH N DFAL DECOMP PJSM. RIG UP HEAD PIN AND FILL PIPE - PUMP 1 -1/2 TIMES DRILL PIPE CAPACITY - PUMP 50 BBL AT 5 BPM WITH 210 PSI. - RIG DOWN LINES. 03:30 - 04:00 0.50 FISH N DFAL DECOMP POH , STAND BACK 4" DRILL PIPE - POH FROM 2676' TO 1160' - OBSERVE GAS "EXHALING" UP DP, NO PRESSURE. - STOP PULLING PIPE 04:00 - 04:30 0.50 FISH N DFAL DECOMP PJSM. MAKE UP TOP DRIVE AND PUMP - PUMP 1 -1/2 TIMES DRILL PIPE CAPACITY - PUMP 20 BBL AT 3 BPM WITH 120 PSI. - REMOVE TOP DRIVE. 04:30 - 05:30 1.00 FISH N DFAL DECOMP POH , STAND BACK 4" DRILL PIPE - WELL IN STRONG VACUUM, NO FLOW. Printed 10/1/2012 11:00:01AM o �� 1 Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE @54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:30 - 06:30 1.00 FISH N DFAL DECOMP PJSM. BREAK DOWN ROPE SPEAR ASSEMBLY. - RECOVERED 65 - 70 OF 3/8" STAINLESS STEEL CAPILLARY TUBE. 06:30 - 07:30 1.00 EVAL P DECOMP PJSM. PICK UP HALLIBURTON RETRIEVABLE BRIDGE PLUG. - RIH TO 583', GAS VAPORS EXITING DRILL PIPE. 07:30 - 08:00 0.50 EVAL P DECOMP PJSM. CIRCULATE DOWN DRILL PIPE. ■ CIRCULATE 1 1/2 DP VOLUMES, 3 BPM / 90 PSI. 08:00 - 12:00 4.00 EVAL P DECOMP, CONTINUE TO RIH WITH RBP ON DRILL PIPE. - RIH FROM 583' TO 8544'. UP WT = 150K / 86K DOWN WT. ALL WEIGHT CHECKS INCLUDE TOP DRIVE (40K). - 462 BLS SEAWATER LOST TO WELL LAST (12) HOURS. 12:00 - 12:30 0.50 EVAL P ® DECOMP SERVICE TOP DRIVE, SERVICE AND INSPECT RIG COMPONENTS. 12:30 - 14:30 2.00 EVAL P DECOMP PJSM. CONTINUE TO RIH WITH RBP ON DRILL ■ PIPE. - RBP AT 11,600', 205K UP WT, 95K DOWN WT. 14:30 - 16:00 1.50 EVAL P DECOMP PJSM. PUMP DOWN DRILL PIPE AT 4 BPM WITH 250 PSI. - RECIPROCATE PIPE WHILE CIRCULATING. - SHUT DOWN PUMP, PUT 3 1/2 LEFT HAND TURNS IN PIPE. - RIH AND SET DOWN TO 75K . - PICK UP TO 215K, VERIFY PACKER IS SET, RELEASE FROM PACKER. - POH ONE STAND. 16:00 - 17:00 1.00 DHB P DECOMP PJSM, RIG UP AND CIRCULATE - RIG UP LINES TO CIRCULATE. - FILL LINES, CIRCULATE TO FILL WELL WITH SEAWATER. - CIRCULAYE AT 5 BPM WITH 680 PSI. 17:00 - 18:00 1.00 DHB P DECOMP PJSM, CASING TEST. - TEST 7" PRODUCTION CASING - MIT 250 PSI HELD FOR 5 MINUTES - MIT 3500 PSI HELD FOR 30 MINUTES. BOTH TESTS CHARTED. - PUMPED 5 BBL FOR HIGH PRESSURE TEST, 5 BBL BLEED OFF. APPROVAL RECEIVED FROM WTL TO PROCEED. - OA PRESSURE BLED FROM 146 PSI TO 0 PSI. - OA FLOWED BACK DIESEL FOLLOWED BY WATER. "NOTE" THE OA HAS NO FREEZE PROTECTION. 18:00 - 18:30 0.50 DHB P DECOMP PJSM, CIRCULATE. - DISCUSS FLUID MANAGEMENT. - CIRCULATE ONE BOTTOMS UP AT 5 BPM WITH 845 PSI. - DUMP DIRTY SEAWATER. - RIG DOWN HEAD PIN AND LINES. Printed 10/1/2012 11:00:01AM Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE @54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 22:00 3.50 WHSUR P DECOMP PJSM, POH STAND BACK DRILL PIPE - POH 4" DRILL PIPE FROM 11,600' TO 4943'. - RBP RUNNING TOOL DEPTH, 4943'. - POH UP WEIGHT 103K, DOWN WEIGHT 83K 22:00 - 23:30 1.50 WHSUR P DECOMP PJSM. SET AND TEST STORM PACKER. - SET 7" HALLIBURTON STORM PACKER AT 4 99' �0'` - BACK OUT RUNNING TOOL WITH LEFT J HAND TURNS. 1 STAND BACK ONE STAND OF DRILL PIPE - LAY DOWN STORM PACKER RUNNING TOOL. - CLOSE BLIND RAMS FOR TO TEST STORM PACKER' PRESSURE TEST PACKER TO 250 PSI AND 3500 PSI - BOTH TESTS FROM ABOVE FOR 5 MINUTES. 23:30 - 00:00 0.50 WHSUR P DECOMP RIG DOWN TEST EQUIPMENT - BLOW DOWN LINES. - PULL WEAR BUSHING. PUMP OUT BOP.. SEAWATER LOST TO WELL LAST 24 HOURS 605 BBL OA PRESSURE 0 PSI 9/11/2012 00:00 - 08:00 8.00 WHSUR P DECOMP PJSM. PERFORM EQUIPMENT CHECK AND SPCC - DISCUSS NIPPLE DOWN BOP AND TUBING SPOOL. MONITOR OA. SLOW INTERMITTENT WATER FLOW. GRADUALLY SLOWING DOWN. - RIG DOWN FLOW LINE AND RISER. - REMOVE TURN BUCKLES FROM BOP. - BLEED DOWN ACCUMULATOR. - CHANGE POP -OFF VALVE ON MUD PUMP. 08:00 - 09:00 1.00 WHSUR P DECOMP PJSM. FMC REP CHANGE OUT VR PLUG. PRESSURE TEST TO 250 PSI LOW AND 5000 PSI HIGH FOR 5 CHARTED MINUTES EACH. 09:00 - 10:00 1.00 WHSUR P DECOMP PJSM. NIPPLE UP RISER. MAKE UP TURNBUCKLES. FUNCTION TEST ALL BOP ELEMENTS. FMC REP INSTALL 1 BY 2- 9/16" VALVE ON IA. PRESSURE TEST TO 250 PSI LOW, 5000 PSI HIGH FOR 5 CHARTED MINUTES EACH. REMOVE VR PLUG. 10:00 - 10:30 0.50 WHSUR P DECOMP RUN IN AND INSTALL 8- 9/16" WEAR BUSING. 10:30 - 11:30 1.00 WHSUR P DECOMP PERFORM HOUSEKEEPING WHILE WAITING ON HALLIBURTON REP. 11:30 - 12:00 0.50 WHSUR P DECOMP PJSM. MAKE UP STORM PACKER RUNNING TOOL. 12:00 - 12:30 0.50 WHSUR P DECOMP PJSM. INSPECT AND SERVICE TOP DRIVE AND SKATE. 12:30 - 13:30 1.00 DHB P DECOMP RUN IN HOLE AND ENGAUGE HALLIBURTON STORM PACKER AT 99'. RELEASE AND PULL TO RIG FLOOR. UP WEIGHT 103K. BLOW DOWN CHOKE AND TOP DRIVE. 13:30 - 17:00 3.50 EVAL P DECOMP MAKE UP 7" RBP RUNNING TOOL. RIH TO RBP AT 11,600'. UP WEIGHT 200K, DOWN WEIGHT 98K. OA - 20 PSI AT 17:00 HOURS. Printed 10/1/2012 11:00:01AM t � x Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE @54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 20:00 3.00 DHB P DECOMP ESTABLISH CIRCULATION AT 2 BPM WITH 140 PSI, 3 BPM WITH 200 PSI. ENGAUGE RBP AND RELEASE. CLOSE ANNULAR. BULLHEAD 100 BBLS SEAWATER DOWN IA AT 6 BPM WITH 110 PSI, THEN PUMP 50 BBLS SEAWATER DOWN DRILL PIPE AT 6 BPM WITH 330 PSI. SHUT DOWN. VERIFY DRILL PIPE AND ANNULUS ON A VACCUM. BLOW DOWN AND RIG DOWN CHOKE AND BLOW DOWN TOP DRIVE, 20:00 - 21:45 1.75 EVAL P DECOMP PJSM. RIG UP TO LAY DOWN DRILL PIPE. POOH LAYING DOWN DRILL PIPE SINGLES FROM 11,600' MD. UP WEIGHT 200K, DOWN WEIGHT 95K PULL TO 10,124'. UP WEIGHT 185K. CONTINUOUS HOLE FEED AT 24 BPH. 21:45 - 00:00 2.25 BOPSUR P DECOMP AT 10,124' MD FLOW SHOW INCREASED. RIG CREW PROCEED WITH WELL SHUT.IN PROCEDURE. FLOOR VALVE WAS STABBED INTO DRILL PIPE AND TORQUED THEN SHUT. THE ANNULAR WAS CLOSED, THE HCR WAS ' ^', OPENED TO A CLOSED CHOKE. INITIAL SICP / WAS 20 PSI AND INCREASING TO 250 IN 40 t' MINUTES AND STABILIZING AT 260 PSI. THE - SIDPP STABILIZED AT 20 PSI. PIT GAIN 8 BBLS. NOTIFICATIONS MADE TO RWO AND RIG WORKOVER SUPERINTENDENT, ODE ENGINEER, WTL AND RIG RENEW AND MTL. RIG TEAM FORMULATE PLAN FORWARD FOR TOWN TEAM. 9/12/2012 00:00 - 03:00 3.00 BOPSUR P DECOMP WAIT FOR APPROVAL OF A BULLHEAD PLAN FORWARD. 03:00 - 04:45 1.75 BOPSUR P DECOMP HOLD PJSM WITH ALL PERSONNEL FOR BULLHEAD OPERATIONS. LINE UP TRUCKS AND POSITION PEOPLE. COMMENCE BULLHEAD OPERATIONS. PUMP DOWN DRILLPIPE WITH 130 BBLS SEAWATER AT 8 BPM WITH 425 PSI TO START, 729 PSI AT FINISH. CATCH UP TO FLUID AT 30 BBLS AWAY. DECIDE TO OVERPUMP BY 30 BBLS TO MAKE SURE PIPE IS CLEAR OF ANY INFLUX. SHUT DOWN. LINE UP ON Al AND BEGIN BULLHEADING SEAWATER AT 8 BPM. PUMP A TOTAL OF 570 BBLS DOWN THE IA. STARTING PRESSURE 239 PSI. ENDING PRESSURE 700 PSI. SHUT DOWN AND LET PRESSURE BLEED OFF UN- ASSISTED. 04:45 - 05:15 0.50 BOPSUR P DECOMP MONITOR WELL FOR 30 MINUTES. PRESSURE BLEED TO 0.0 PSI. 05:15 - 07:30 2.25 BOPSUR P DECOMP WELL STILL NOT ON A VAC. NO READABLE PRESSURE ON IA OR DRILL PIPE. CONTINUE TO MONITOR. Printed 10/1/2012 11:00:01AM Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE @54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 14:00 6.50 BOPSUR P DECOMP DISCUSS PLAN FORWARD WITH TOWN RWO GROUP. - WILL BULL HEAD 2 HOLE VOLUMES - DOWN BOTH THE DP AND IA AT THE SAME TIME. - WAIT ON TWO MORE LOADS OF KWF TO ARRIVE ON LOCATION. GIVE NOTICE TO AOGCC OF UPCOMING BOP TEST. TEST WILL BE A WEEKLY TEST WHILE ALSO TESTING THE ELEMENTS USED IN THE WELL SHUT IN. JEFF JONES WITH AOGCC CALLED BACK AND ASKED FOR AN UPDATE AT 17:00 HOURS. 14:00 - 16:00 2.00 BOPSUR P DECOMP PJSM, BULL HEAD KILL. - DISCUSS PUMP PRESSURE AND FLUID MANAGEMENT. - VERIFY VALVE ALIGNMENT. - START BULL_ HEAD DOWN THE DP AND IA. 3 BPM / DP = 20 PSI, IA = '0' PSI. 9 BPM / DP = 180 PSI, IA = 130 PSI WITH 118 BBLS PUMPED AWAY. - 9 BPM / DP = 730 PSI, IA = 690 PSI WITH 968 BBLS PUMPED AWAY. SLOW PUMPS TO 2 BPM FOR LAST 2 BBLS. - 970 TOTAL BBLS PUMPED. - PRESSURE AT SHUT DOWN / DP = 150 PSI, IA = 150 PSI. 16:00 - 17:00 1.00 BOPSUR P DECOMP MONITOR WELL FOR FIRST 10 MINUTES WITH NO FILL. AFTER 5 MINUTES PRESSURES AT ZERO. AFTER 10 MINUTES BOTH DP AND IA ON VACUUM. CONTINUE TO MONITOR FOR 30 MINUTES WITH CONTINUOUS HOLE FILL OF 20 BPH WITH NO RETURNS. BLOW DOWN CHOKE AND SURFACE LINES. AT 17:00 HOURS CHUCK SCHEVE WITH THE AOGCC WAIVED WITNESS FOR BOP TEST. 17:00 - 00:00 7.00 BOPSUR P DECOMP PULL OUT OF HOLE LAYING DOWN 4" DRILL PIPE FROM 10,124' MD TO 4,058' MD.UP WEIGHT 175K AT START AND 95K AT FINISH. CONTINUOUS FILL DOWN IA AT 25 BPH. 9/13/2012 00:00 - 01:00 1.00 BOPSUR P DECOMP PJSM. SERVICE AND INSPECT THE TOP DRIVE, IRON ROUGHNECK AND HANDLING TOOLS. 01:00 - 04:00 3.00 BOPSUR P DECOMP PJSM. PULL OUT OF HOLE LAYING DOWN 4" DRILL PIPE TO RBP RUNNING TOOL BHA. 04:00 - 05:00 1.00 BOPSUR P DECOMP MONITOR WELL FOR 5 MINUTES - NO FLOW. LAY DOWN RBP AND RUNNING TOOL. 05:00 - 06:00 1.00 BOPSUR P DECOMP CLEAR AND CLEAN RIG FLOOR. 06:00 - 07:00 1.00 BOPSUR P DECOMP PULL WEAR RING. - INSTALL TEST PLUG. 07:00 - 09:00 2.00 BOPSUR P DECOMP PJSM, R/U TO TEST BOPE. - INSPECT TEST HOSES. Printed 10/1/2012 11:00:01AM < ?%!o Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) ( ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE @54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 11:00 2.00 BOPSUR P MINUTES EACH. TEST H DECOMP TEST BOP TO 250 PSI LOW, 3500 PSI HIGH YD FOR 5 CHARTED UPPER 3 -1/2" X 6" VARIABLE RAMS WITH 4" TEST JOINT. TEST LOWER " RA WITH HIGH '\ 2 -7/8" TEST JOINT. TEST ANNULAR 2 -7/8 PSI LOW, 3500 PSI MS FOR PREVENTER 5 CHARTED TO 250 MINUTES EACH. TEST 1 ANNUPLUG LAR EAKI WITH G. 25 BPH WHILE " ST JOINT. ST A L CONTINUE TO FILL IA WITH PERFORMING 2 -7/8TE TEST. TE EH TT W MA POSIT ES LOCKS PERFORMED ENGAGED G I NUAL . CHUCK SCHEVEWITH AOGCC WAIVED WITNESS FOR BOP TEST. TEST WITNESSED BY WSL AND TOOLPUSHER. 11:00 - 15:00 4.00 BOPSUR N SFAL DECOMP PJSM. PULL TEST PLUG FOR INSPECTION. RUBBER NOT HOLDING. INSPECT AND I TE AND R ECTWWDE K CHOKE SERVCE W E TI WATER. DRIV INSPD T RRICK FILL AND CROWN. CHANGE OUT TEST PLUG . OR THE BP HSE ADVISOR CAME OUT FOR A RIG VISIT AND WALK AROUND. 15:00 - 21:30 6.50 _ BOPSUR P DECOMP TEST BOP TO 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH. TEST UPPER 3 -1/2" X 6' VARIABLE RAMS WITH 4" TEST JOINT. TEST LOWER 2 -7/8" RAMS WITH / 2 -7/8" TEST JOINT. TEST ANNULAR V PREVENTER TO 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH. TEST ANNULAR WITH 2 -7/8" TEST JOINT. EACH TEST PERFORMED WITH HYDRAULIC LOCKS ENGAGED. CONTINUE TO FILL IA WITH 27 BPH WHIOIS T - SYSTEM PRESS PERF URE - 3025 TE PI - PRESSURE AFTER CLOSER ._ NG 1700 . PSI - 200 PSI ATTAINED - 13 SECONDS -FUUE TTE - E - NITROGEN LL PRESS BOTRTLES A 8 A !INN WITH D AVERAGE 97 SCONDS - 2150 PSI 21:30 - 22: 30 1.00 BOPSUR P DECOMP RIG DOWN TEST EQUIPMENT. BLOW DOWN SURFACE LINES, CHOKE AND KILL LINES. 22:30 AND 23:00 0.50 BOPSUR P DECOMP INSPECT SERVICE ACCUMULATOR DOOR HINGES. 23:00 23:30 0.50 BOPSUR P DECOMP PULL TEST PLUG. RUN IN AND INSTALL 8 9/16" WEAR RING. 23:30 - 00:00 0.50 BOPSUR P DECOMP IN HOLE WITH 4 -3/4" COLLARS AND POOH RUN LAYING DOWN. 9/14/2012 00:00 - 00:30 0.50 BOPSUR P DECOMP PJSM. RIH WITH 4 -3/4," COLLARS. POOH LAYING DOWN 4-3/ COLLARS. 00:30 - 01:30 1.00 BOPSUR P DECOMP INSPECT TOP DRIVE AND DRA AL WWORKS OH HANDLING TOOLS. RIG UP POWER NG TO 01:30 02:30 1.00 BOPSUR P DECOMP PJSM. RUN IN EXCESS 2 -7/8" TUBING FROM WIT NGS. THE HOLE DERRICK WITH TO 1795' MD. 02:30 04:00 1.50 BOPSUR P DECOMP PULL G DOWN 2 -7/8" TUBING OUT FROM OF 1795 ' MD. LAYIN 04:00 - 04:30 0.50 BOPSUR P DECOMP PULL WEAR RING Printed 10/1/2012 11:00:01AM Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE @54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 06:00 1.50 RIGU P OTHCMP PICK UP ESP CLAMPS AND TOOLS TO RIG FLOOR. - LOAD ESP BOXES INTO PIPE SHED. - LID 3 JTS 2 -7/8" TBG FROM DERRICK. 06:00 - 07:30 1.50 RIGU P OTHCMP ,PJSM, RIG UP TO RUN 2 -7/8" ESP, COMPLETION. - HANG ESP SHEAVE IN DERRICK AND STRING ESP CABLE OVER TO RIG FLOOR. - START WITH 119 STANDS 2 -7/8" TBG IN DERRICK. AND 5 JTS 2 -7/8" TBG IN PIPE SHED. - CONTINUOUS HOLE FEED AT 25 -30 BPH WITH NO RETURNS. (SEAWATER) 07:30 - 12:00 4.50 RUNCOM P RUNCMP PJSM, M/U ESP PUMP AND MOTOR ASSEMBLY. - PER CENTRILIFT REP. - TERMINATE GAUGE CONTROL LINE @ DISCHARGE HEAD. 12:00 - 20:30 8.50 RUNCOM P RUNCMP RUN ESP COMPLETION ON 2 -7/8" TBG FROM. DERRICK CENTRILIFT REP PERFORM INITIAL CONDUCTIVITY TEST OF ESP CABLE. - CENTRALIZER, SENSOR, MOTOR, LOWER TANDEM PUMP, UPPER TANDEM PUMP, GAS SEPARATOR, PUMP, DISCHARGE HEAD, 2 -7/8" TBG PUP, 1 JTS 2 -7/8" TBG, 'XN' = 112.64' - THEN RUN 2 -7/8" TBG FROM DERRICK. - RUN 1 CANNON CLAMP ON 1ST 9 JTS THEN 1 EVERY OTHER JTS. - CHECK CONDUCTIVITY EVERY 2000' - FLUSH PUMP EVERY 2000' - 1/2 BPM = 30 PSI 20:30 - 00:00 3.50 RUNCOM P RUNCMP SPLICE ESP CABLE AT 6548' MD - CHECK CONDUCTIVITY AFTER SPLICE = GOOD - MAINTAIN CONTINUOUS HOLE FEED DOWN IA AT 25 -30 BPH, NO RETURNS - LOSSES TO WELL IN LAST 24 HOURS= 715 BBL 9/15/2012 00:00 - 05:00 5.00 RUNCOM P RUNCMP PJSM, ESP COMPLETION - CONTINUE RIH FROM 6548' MD TO 11586' MD - CHECK CONDUCTIVITY EVERY 2000' - PUMP 5 SEAWATER DOWN PIPE AT 1/2 BPM - 50 PSI - CHANGE OUT / REPLACE BENT JOINTS AS NEEDED - MAINTAIN CONTINUOUS HOLE FEED DOWN IA AT 25 -30 BPH, NO RETURNS Printed 10/1/2012 11:00:01AM Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE @54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 08:30 3.50 RUNCOM P RUNCMP MAKE UP 13 -5/8" TUBING HANGER. - INSTALL PENETRATOR - TERMINATE ESP CABLE AND CONNECT TO PENETRATOR - LAND TBG HANGER WITH 3" TYPE 'H' TWC INSTALLED. - FMC REP RILDS. - 171 CANNON CLAMPS USED - 2 HALF CLAMPS - 50 PROTECTOLIZERS - PUWT = 150K, SOW_ T = 66K 08:30 - 09:30 1.00 RUNCOM P RUNCMP PJSM, TEST TWC. -1 ATTEMPT ROLLING TEST FROM BELOW. - PUMPED 65 BBLS SEAWATER AT 5.5 BPM / 120 PSI. FAILED TEST. TEST TWC FROM ABOVE: 250 LOW / 3500 PSI FOR 10 CHARTED MINUTES. PASSED. BARRIERS IN PLACE: TESTED TWC IN THE TBG HANGER AND TBG HANGER SEALS. 09:30 - 12:00 2.50 BOPSUR P RUNCMP PJSM, N/D BOPE LOTO THE KOOMY SYSTEM. - BLOW DOWN LINES. - R/U DOWN THE ESP SHEAVE FROM DERRICK. - N/D 13 -5/8" BOP STACK 12 HRS LOSSES TO WELL = 406 BBLS SEAWATER. 12:00 - 13:00 1.00 BOPSUR P RUNCMP CREW CHANGE, PJSM, ND / NU. - N/D 13 -5/8" SPACER SPOOL. 13:00 - 14:00 1.00 WHSUB P WHDTRE PJSM,N/U 13 5/8" TREE ADAPTOR FLANGE - OPEN CELLAR DOORS. - PJSM, THE NEW TREE HAD TO BE MANEUVERED WITH TUGGER AND TAG LINES INTO THE CELLAR. - N/U 3 -1/8" NEW 5M TREE 14:00 - 17:00 3.00 WHSUB P WHDTRE PRESSURE TEST ADAPTOR FLANGE - DISCUSS HI PRESSURE TESTING. - 5 MIN 250 LOW, 30 MINUTES @ 5000 PSI. PASSED. - TEST TREE WITH DIESEL - 250 / 5000 PSI FOR 5 CHARTED MINUTES. PASSED. - CENTRILIFT CONDUCT PHASE TO PHASE FINAL TEST-ATTACHED 17:00 - 20:00 3.00 WHSUB P WHDTRE R/U WELL SUPPORT LUBRICATOR - TEST LUBRICATOR TO 250 PSI / 3500 PSI, 5 MIN, CHARTED - PULL TWC, "0" PRESSURE - TEST LUBRICATOR - INSTALL BPV 20:00 - 20:30 0.50 WHSUB P OTHCMP PERFORM ROLLING TEST FROM BELOW BPV - 5 BPM, 80 PSI, 110 BBLS PUMPED Printed 10/1/2012 11:00:01AM • rr Common Well Name: MPE -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/10/2012 End Date: 9/15/2012 X4- 00VK2- E:DRILL (1,320,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/13/1994 12:00:00AM Rig Release: 9/15/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292251300 Active Datum: Original KBE ©54.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 - 22:00 1.50 DEMOB P POST PREPARE TO RIG DOWN AND MOVE OFF - RIG DOWN CELLAR LINES AND SECURE TREE - CLEAN PITS - BLOW DOWN ALL SURFACE LINES AND PUMPS - PREP CELLAR AREA FOR MOVE OFF WELL - LOSSES TO WELL IN LAST 24 HOURS= 697 BBLS RELEASE RIG AT 22:00 HOURS Printed 10/1/2012 11:00:01AM WELLHEAD: Gen 5 FMC KB = 54 FT AMSL w /CIW 3 1/8" tree / Tbg. H lvi P E -0 w . LEVEL = 24 FT AMSL . has profile for CIW -H BPV. � MAX DEV =72 DEG 2 KOP 11-3 " CONDUCTOR I I n0 wit h! spot encrtuared in the 450 FT 3 f \ Camco 2 7/8" x 1" I 168' i 1 sidepocket KBMM GLM 9 -5/8 ", 40 # /ft,L -80, Btrs Csg 3814' , a Camco 2 7/8" x 1" 11,382' sidepocket KBMM GLM 2 -7/8" 6.5ppf, L- 80,8rd EUE tbg. P (Drift ID = 2.347 ", cap. = 0.00592bpf.) Pr HES 2 -7/8" 8rd 2.250 "XN" Profile Nipple 11,472' 7" 26 ppf, L -80 NSCC prod. casing (No -Go ID 2.205 "). (Drift ID= 6.151 ", cap. = 0.0383bpf ID Pump Model SXD, El Type 100 P31 I 11,520' El Tandem Gas Separator I 11,540' _.F GRSfTXARH6 Tandem Seal Section 11,543' Intake TVD = 6779' MEE GSB3 DB UT /LT SB /SB PFSA Mid -pert TVD = 7054' Mid -pert MD = 14248' Motor, 204 HP / 2315 Volt, 11,558' PBTD TVD = 7207' 77 Amp, MSP Model PBTD MD = 14520' Well Lift DGU / MGU w/6 fin Centralizer 11,582' TVD = 6080' Baker FB -1 pkr w /4 "ID. k 13,548' • 4 dem gas ss ep $ tatid e � x otor) / ,d VV o /08/97) LLCV removed I ‘ - - - 7" Baker hanger/ isol packer I 13582' • 16 7" 26 #, L -80 NSCC casing I 13739' PERFORATING SUMMARY: Ref. Log: Sperry EWR4 Size SPF Interval -MD Interval -TVDSS ii Ii 3 3/8" 6 14002 -14084 6914 -6947 II II NI 3 3/8" 6 14132 -14200 6980 -7007 ii ii 2 1/8" 6 14480 -14495 7187 -7195 .. II •I :I II II II II PBTD 14520' 5 ", 15 #, 13 13cr STL casing I 14565' Date By Comments 11/10/99 M. Linder ESP Changeout MILNE POINT WELL: E - 4/20/01 GMH ESP Changeout -Add Perfs API NO: 50 029 - 22513 10/17/01 B. Hasebe ESP Changeout - 4ES COMPLETION DIAGRAM 10/21/02 B. Hasebe ESP Changeout - 4ES 1/17/03 Lee Hulme ESP Changeout - 4ES 09/17/12 B. Bixby ESP Changeout - Doyon 16 B.P. EXPLORATION (ALASKA) INC. • • 1 E.-09 Pt 137Q Regg, James B (DOA) From: Sarber, Greg J [SarberJG @BP.com] I lg Sent: Friday, September 14, 2012 4:07 PM To: Regg, James B (DOA) Subject: RE: BOP Usage report for Doyon 16 on MPE -09, 9 -11 -2012 Jim, Sorry for the delay in answering your email, I was flying to the slope today. Yes, the Annular preventer was used in this event. Cheers, Greg Original Message From: Regg, James B (DOA) [mailto:iim.reggOalaska.gov] Sent: Friday, September 14, 2012 9:27 AM To: Sarber, Greg J Subject: RE: BOP Usage report for Doyon 16 on MPE -09, 9 -11 -2012 PTD is 2041320 instead of 2040132 Report does not indicate what BOPE was used; was it the annular? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 SANE MAY 0 7 2013 Anchorage, AK 99501 907- 793 -1236 Original Message From: Sarber, Greg J [mailto:SarberJGOBP.com] Sent: Wednesday, September 12, 2012 5:31 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Kilfoyle, Jeffery A; Cismoski, Doug A; Daniel, Ryan; Willingham, James M; Willingham, James M; Rossberg, R Steven; Reem, David C; Miller, Mike E; Sheffrey, Tom (Fircroft) Subject: BOP Usage report for Doyon 16 on MPE -09, 9 -11 -2012 All, 16 hours ago the Doyon 16 rig, working on Milne Point E -09 encountered flow from a well. The pit gain was caused during retrieval of an RBP that was used to secure the well for wellhead work. The well was killed by bullheading. The well is currently killed and the rig is proceeding with pulling the RBP. BOP's will be tested after retrieving the drillpipe and RBP OOH. Please see the attached report for full details. Sincerely, Greg Sarber • • Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: Greg Sarber Wellsite Leader Name: David Rhodes Contact Number: 907 - 242 -8000 Contact Number: 659 -4177 Traction Number:IR- 4229842 Well Location & Name: MPE -09 Doyon Rig 16 Permit To Drill (PTD) Number: 1941320 Date and Time of Incident: 9/11/2012 21:44 hrs. Original Scope of Work: Set 7" RBP @11600' and and 7" storm packer @ 99' md. Perform well head repair work to leaking `VR' plug. Operational Description Leading up to Well Control Event: Release 7" RBP, bull head 100 bbls KWF, circulate 50 bbls KWF, monitor well, DP and annulus on a vacuum. POH and lay down 4" DP. After pulling and laying down 47 joints of DP (1500'), a pit gain was observed and the well shut in. lt c refer , cift4I fL BOPE Used and Reason: 13 5/8" Annular and choke valves (3 -6 -5). While filling the hole at -24 BPH with out returns, as the 47 joints of DP was laid down, the well began flow and was shut -in. With an 8 bbl pit gain. Is a BOPE Test Required after use ( Yes / No): YES If no, why? 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: The well had been experiencing significant losses, so a bullhead well kill was performec The gas was displaced back into the perforations. After the bullhead kill the well was observed and both tubing and IA were on a slight vacuum. A second bullhead kill was performed to ensure the well was completely killed. After the second circulation, the well was on a strong vacuum on both the drillpipe and casing. The drillpipe will continue to be pulled from the hole and upon reaching surface a BOP test will be conducted. Then the new ESP completion will be run. Additional Comments: Instructions: 1. WSL contacts Superintendent with details of incident. 2. Superintendent then: A. Completes form with details from WSL. B. Emails copy of form to AOGCC. C. Emails copy of form to BP distribution list below. D. Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa .aogcc.prudhoe.bay(aialaska.gov 3. WSL enters completed form into daily drilling reporting system. 4. WSL fills out Traction Report and attaches copy of AOGCC BOPE Usage Form. Email CC List BOPE Usage Report for AOGCC August 2, 2010 HRE 1 • Well Site Leader WSL initiating report Well Integrity Team Leader Ryan Daniel HSE Advisor Jeff Kilfoyle Engineering Team Leader Ken Allen, John Egbejimba, John McMullen, Dave Reem Wells Operations Manager Steve Rossberg Wells Intervention Manager Doug Cismoski Organizational Capability Tom Sheffrey BOPE Usage Report for AOGCC August 2, 2010 HRE 2 STATE OF ALASKA - ALASKA. AND GAS CONSERVATION COMMISSI. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other 0 ACID STIMULATION Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ -194 -1320 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 • 50- 029 - 22513 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028231 - MPE -09 10. Field /Pool(s): y , MILNE POINT FIELD / KUPARUK RIVER OIL POOL 11. Present Well Condition Summary: Total Depth measured 14570 feet Plugs (measured) None feet true vertical 7231 feet Junk (measured) None feet Effective Depth measured 14520 feet Packer (measured) feet true vertical 7207 feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" SURFACE - 112 SURFACE - 112 Surface 3784' 9 -5/8" 40# L -80 SURFACE - 3814 SURFACE - 3032 5750 3090 Intermediate 13712' 7" 26# L -80 SURFACE - 13739 SURFACE - 6880 7240 5410 Production Liner 983' 5" 15# 13CR80 13582 - 14565 6819 - 7229 8290 7250 Liner Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 2 -7/8" 6.5# L -80 SURFACE - 13525 SURFACE - 6797 Packers and SSSV (type, measured and true vertict zois REC E 1VEi 12. Stimulation or cement squeeze summary: FEp 0 9 2011 Intervals treated (measured): NOW Oli .& ills COfis. COW nssidn Treatment descriptions including volumes used and final pressure: Ancrvhge 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 93 39 2389 188 Subsequent to operation: 94 38 2417 203 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ~ IO Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil f 111 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE] GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na e e Lastu c Title Data Manager Signatu V p Phone 564 -4091 Date 2/8/2011 RBDMS r EB / � CCI y � _ Form 10 -404 Revised 10/2010 F � �� /D - ! ( Submit Original Only MPE -09 • 194 -132 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPE -09 12/3/94 PER 14,002. 14,084. 6,980.32 7,013.1 MPE -09 12/3/94 PER 14,132. 14,200. 7,032.32 7,060.32 MPE-09 11/7/97 FIL 13,627. 14,520. 6,836.89 7,206.59 MPE-09 10/14/99 FCO 13,627. 14,435. 6,836.89 7,165.86 MPE-09 4/18/01 APF 14,480. 14,495. 7,187.42 7,194.62 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED • MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • . • MPE -09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 2/3/2011 1T /I /0= 100/220/180 ESP Acid Treatment Pump 20 bbls crude down Tbg @ 1.5 bpm 1 525 psi for Injectivity test. Pump 29 bbls 10% DAD Acid, Flush lines w/3 bbls 60/40 I meth down Tbg. Displace w/ 80 bbls crude down Tbg. Pump 105 bbls crude down [ IA. FWHP= 200/600/160. € i FLUIDS PUMPED BBLS 100 CRUDE 3 60/40 METH 29 10% DAD ACID 190 CRUDE 322 TOTAL w/ CIW 31 8" Gen MP E-09 5 Tbg. Hgr. = 54 FT AMSL G. VEL = 24 FT AMSL has profile for CIW -H BPV. - MAX DEV =72 DEG Zo ir KOP = 450 FT 13 3/8" CONDUCTOR 80' I Camco 2 7/8" x 1" 1 143' sidepocket KBMM GLM �� 9 -5/8 ", 40 # /ft,L -80, Btrs Cs gl 38 1 A '�? ■ Camco 2 7/8" x 1" I 6736' I sidepocket KBMM GLM 0 Camco 2 7/8" x 1" 1 13,313' I 2 -7/8" 6.5ppf, L- 80,8rd EUE tbg. sidepocket KBMM GLM (Drift ID = 2.347 ", cap. = 0.00592bpf.) gpmm HES 2 -7/8" 8rd 2.313 "XN" Profile Nipple 13,392' 7" 26 ppf, L -80 NSCC prod. casing (No -Go ID 2.205`). (Drift ID= 6.151 ", cap. = 0.0383bpf Triple Tandem Pump, 74 Stg. 1 GC2900, 82 Stg GC2900, I 13,436' _ 16 Stg GCNPSH GPMTAR 1:1 Tandem Gas Separator ,. GRSTXBARH6 400 Series Internals) 13 r Tandem Seal Section 1 13,483' Intake TVD = 6779' GSB3 DB UT /LT IL H6 PFS Aflas/HSN Mid -pert TVD = 7054' Motor, 266 HP 2345 Volt, 1 13,496' Mid -pert MD = 14248' � 69 Amp KMHG Model PBTD TVD = 7207' PBTD MD = 14520' 4 t Phoenix MS1 w/6 fin Centralizer I 13,523' TVD = 6797' Baker FB -1 pkr w /4 "ID. ( 13,548' (open bore - LLCV removed on 11/08/97) I 7" Baker hanger/ isol packer I 13582' ' 7" 26 #, L -80 NSCC casing I 13739' PERFORATING SUMMARY: Ref. Log: Sperry EWR4 Size SPF Interval -MD Interval -TVDSS i; 0 MB 3 3/8" 6 14002 -14084 6914 -6947 I I 3 3/8" 6 14132 -14200 6980 -7007 2 1/8" 6 14480 -14495 7187 -7195 III , , :: NI 11 II 0 PBTD I 14520' I 5 ", 15 #, 13 13cr STL casing I 14565' I Date By Comments 10/17/99 M. Linder ESP Changeout MILNE POINT WELL: E -09 11/10/99 M. Linder ESP Changeout API NO: 50- 029 -22513 4/20/01 GMH ESP Changeout - Add Perfs COMPLETION DIAGRAM 10/17/01 B. Hasebe ESP Changeout - 4ES 10/21/02 B. Hasebe ESP Changeout - 4ES 1/17/03 Lee Hulme ESP Changeout - 4ES B.P. EXPLORATION (ALASKA) IN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 54' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3731' NSL, 2029' WEL, SEC. 25, T13N, R10E, UM X = 569115, Y = 6016268 MPE-09 At top of productive interval 9. Permit Number / Approval No. 194-132 1086' SNL, 2719' EWL, SEC. 32, T13N, R11E, UM X = 579171, Y = 6011551 10. APl Number At effective depth 50- 029-22513-00 1399' SNL, 3104' EWL, SEC. 32, T13N, R11E, UM X = 579560, Y = 6011242 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1425' SNL, 3138' EWL, SEC. 32, T13N, R11E, UM X = 579595, Y = 6011216 Sands 12. Present well condition summary Total depth: measured 14570 feet Plugs (measured) true vertical 7231 feet Effective depth: measured 14520 feet Junk (measured) true vertical 7207 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 3784' 9-5/8" 748 sx PF 'E', 250 sx Class 'G' 3814' 3032' Intermediate 13712' 7" 195 sx Class 'G' 13739' 6880' Production Liner 983' 5" 150 sx Class 'G' 13582'-14565' 6819'-7229' Perforation depth: measured 14002' - 14084', 14132'- 14200', 14480' - 14495' true vertical 6980' - 7013', 7033' - 7060', 7187' - 7195' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 8rd EUE 13525' Packers and SSSV (type and measured depth) None 13, Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Dailv Averaee Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 566 245 1486 Subsequent to operation: 609 247 1588 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that_t_..tJ3~foreggjng is true and correct to the best of my knowledge Si,qned Son -a~Stewm~~~Title TechnicalAssistant Date ..... ~ ~.~_~ ,~ ~ ~ ~ .,~ ~f~Ft~ Prepared By Name/Number:. Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 ~[~N~ ~F~. ;'~i , Submit In Duplicate '-~,'~ '; " ..... '~-~ FEB 2 z~ ~P,a~ BP EXPLORATION Page I of 2 Operations Summary 'Report Legal Well Name: MPE-09 Common Well Name: MPE-09 Spud Date: 10/13/1994 Event Name: WORKOVER Start: 1/12/2003 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/17/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From-Th Hours TaSk Code NPT Phase Description of©perations 1/13/2003 20:00 - 00:00 4.00 MOB P PRE PJSM. SCOPE DOWN DERRICK. REPLACE 3500' OF SANDLINE. MOVE CAMP & PIPESHED TO MPE-06. 1/14/2003 00:00 - 01'00 1.00 MOB P PRE PJSM. LAY OVER DERRICK. 01:00 - 04:00 3.00 MOB P PRE MOVE RIG COMPONENTS F/MPJ-06 TO MPE-09. 04:00 - 07:30 3.50 MOB P PRE SPOT COMPONENTS & RIG UP ON MPE-09. 07:30 - 09:00 1.50 MOB P PRE PJSM. RAISE & SCOPE OUT DERRICK. RIG ACCEPTED @ 09:00 HRS 01-15-03. 09'00 - 11:00 2.00 KILL P DECOMP SPOT TIGER TANK, RIG UP LINES, FILL PITS W/9.1 PPG BRINE. 11:00 - 12:30 1.50 KILL P DECOMP PULL BPV. 900 PSI ON TUBING, 1080 PSI ON I/A. TEST LINES TO 3500 PSI, OK. 12:30 - 13:00 0.50 KILL P DECOMP PJSM. C-MAN, T-PUSHER & ALL HANDS PRESENT DISCUSS WELL KILLING OPS, POINTS OF CONCERN, SAFE AREA & SHUT IN PROCEDURE. 13:00 - 18:00 5.00 KILL P DECOMP KILL WELL @ 2.5 BPM / 900 PSI ICP. TAKE RETURNS THRU CHOKE TO TIGER TANK. AFTER PUMPING (1) TUBING VOLUME, BULLHEAD 50 BBLS @ 2.5 BPM / 500 PSI. RESUME WELL KILL @ 4 BPM / 1000 PSI. CIRCULATE TOTAL OF 590 BBLS. 18:00 - 20:00 2.00 KILL P DECOMP MONITOR WELL & CIRCULATE BACK TO PITS @ 4 BPM / 1250 PSI. LOSS RATE OF 14 BBLS IN 5 MIN. 20:00 - 21:00 1.00 KILL P DECOMP INSTALL 2 WAY CHECK. TEST FROM TOP @ 2000 PSI, OK TEST FROM BOTTOM, BULLHEADING @ 4 BPM / 1000 PSI, OK. 21:00 - 22:30 1.50 BOPSUF P DECOMP N/D TREE & PREP WELLHEAD. 22:30-00:00 1.50 BOPSUFP IDECOMP N/U135/8"x5MBOPE. 1/15/2003 00:00 - 01:30 1.50 BOPSUF; P DECOMP CONTINUE TO N/U BOPE. 01:30 - 04:30 3.00 BOPSUF; P DECOMP PERFORM FULL TEST ON BOPE COMPONENTS. AOGCC STATE REP CHUCK SCHEVE WAIVED WITNESSING, 24HRS NOTICE GIVEN. NO FAILURES. 04:30 - 05:30 1.00 BOPSUF P DECOMP RIG UP LUBRICATOR, PULL 2 WAY CHECK WELL ON SLIGHT VACUUM. 05:30 - 06:00 0.50 PULL P DECOMP PJSM-P/U LANDING JT, BOLDS. 06:00 - 06:30 0.50 PULL P DECOMP PU / UNSEAT HGR W/95 K PULL HGR TO FLOOR. 06:30 - 07:30 1.00 PULL P DECOMP PUMP DN TBG, 3 BPM AT 500 PSI, MONITOR WELL. ATTACH CABLE TO SPOOLING UNIT. 07:30 - 12:00 4.50 PULL P DECOMP TOH WITH TBG / ESP ASSY. 12:00 - 13:00 1.00 PULL P DECOMP CHANGE OUT SPOOLS IN UNIT. 13:00 - 18:00 5.00 PULL P DECOMP CONT TOH W / TBG / ESP ASSY. 18:00 - 21'00 3.00 PULL P DECOMP LD PUMP AND DRAIN MOTOR. 21:00 - 23:00 2.00 PULL P DECOMP CLEAR / CLEAN FLOOR. RU TO RUN ESP/TBG 23:00 - 00:00 1.00 PULL P DECOMP PJSM-PU SERVICE NEW PUMP W/PHOENIX MS1. 1/16/2003 00:00 - 03:00 3.00 RUNCOr~ F' COMP CONTINUE TO PU AND SERVICE ESP ASSY WITH PHEONIX MS1. 03:00 - 04.00 1.00 RUNCOI~P COMP PULL NEW ESP CABLE OVER SHEAVE ATTACH AND SECURE TO ESP ASSY. TEST...GOOD. 04:00 - 06.00 2.00 RUNCOI', P COMP START IN WITH ESP ASSY AND 2 7/8" TBG 106:00 - 11:00 5.00 RUNCOI~F' COMP CREW CHANGE SERVICE RIG. PJSM. CONTINUE TIll WITH ESP ASSY AND 2 7/8" TBG. 11:00 - 15:00 4.00 RUNCOI~ F' COMP CHANGE OUT SPOOLS. MAKE REEL / REEL SPLICE. 15.00 - 19:00 4.00 RUNCOI~P COMP CONT. TIH - CHECK CABLE FILL TBG-1.5 BPM / 1700 PSI 19'00 - 20:00 1.00 RUNCOI~ P COMP HIT TIGHT SPOT AT 11766'. ATTEMPT TO WORK THRU WITH I Printed 2/20/2003 2 27 53 PM BP EXPLORATION Page 2 of 2 Operatio.ns Summary Report Legal Well Name: MPE-09 Common Well Name: MPE-09 Spud Date: 10/13/1994 Event Name: WORKOVER Start: 1/12/2003 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/17/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 1/16/2003 19 00 - 20:00 1.00 RUNCO~) COMP 8 K SET DOWN WT. PU, STAND BACK 1 STAND. CREW CHANGE, PJSM. 20:00 - 21:30 1.50 RUNCO~ ~ COMP MIX 40 BBL, 4% EP LUBE PILL 21:30 - 23:00 1.50 RUNCO~ ~ COMP PUMP 42 BBL EP LUBE FOLLOWED W / 41 BBL BRINE PLACING 15 BBL PILL BEHIND PIPE. 23:00 - 00:00 1.00 RUNCO~ ~ COMP PU STAND AND RIH. WORK THRU TIGHT SPOT AT 11766' W / 14 K DOWN WT. CONT TIH SLIGHT BOBBLE ON 2ND STAND. PUMP REMAINING 27 BBLS EP LUBE PILL. CONT TIH WITH NO FURTHER PROBLEMS.(CENTRILIFT REPORTS INDICATE THIS SAME PROBLEM WAS ENCOUNTERED ON 2 OF LAST 3 COMPLETIONS ON THIS WELL.) 1/17/2003 00:00 - 01:00 1.00 RUNCO[~ ~ COMP CONTINUE TIH WITH ESP ASSY AND 2 7/8" TBG. 01:00 - 02:00 1.00 RUNCO~ ~ COMP MAKE UP TBG HANGER. LANDING JT. INSTALL PENETRATOR. 02:00 - 03'30 I 50 RUNCO~P COMP SPLICE FIELD CONNECTOR. ATTACH TO HANGER. TEST. 03:30 - 04:00 0.50 RUNCO~ ~ COMP LAND HANGER. RILDS. PU WT = 86K...SOW = 34K. 04:00 - 04:30 0.50 RUNCO~ ~ COMP LAY DOWN LANDING JT. INSTAL TWC. 04:30 - 06'30 2,00 BOPSUF P COMP NIPPLE DOWN BOPE. 06:30 - 07:30 1,00 WHSUR P COMP NIPPLE UP PRODUCTION TREE. 07:30 - 08:00 0.50 WHSUR P COMP TEST TREE AND ADAPTOR FLANGE TO 5,000 PSI. GOOD. 08:00 - 08:30 0.50 WHSUR P COMP RU LUBRICATOR. PULL TWC. INSTALL BPV. RD LUBRICATOR. FINAL ESP CABLE TEST. GOOD 08:30- 09.00 0.50 RIGD P COMP BLOW DOWN LINES. RIG DOWN CELLAR. SECURE WELL. RELEASE RIG. ~ I Printed 2/20/2003 2 27 53 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 54' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3731' NSL, 2029' WEL, SEC. 25, T13N, R10E, UM MPE-09 At top of productive interval 9. Permit Number / Approval No. 194-132 1154' SNL, 2804' EWL, SEC. 32, T13N, R11E, UM 10. APl Number At effective depth 50- 029-22513-00 1399' SNL, 3104' EWL, SEC. 32, T13N, R11E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1425' SNL, 3138' EWL, SEC. 32, T13N, R11E, UM Sands 12. Present well condition summary Total depth: measured 14570 feet Plugs (measured) true vertical 7231 feet Effective depth: measured 14520 feet Junk (measured) true vertical 7159 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 3784' 9-5/8" 748 sx PF 'E', 250 sx Class 'G' 3814' 3032' Intermediate 13712' 7" 195 sx Class 'G' 13739' 6880' Production Liner 983' 5" 150 sx Class 'G' 13582'-14565' 6819'-7229' Perforation depth: measured 14002'- 14084', 14132'- 14200', 14480'- 14495' true vertical 6980' - 7013', 7033' - 7060', 7187' - 7195' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 8rd EUE 13504'RECEIVED Packers and SSSV (type and measured depth) None NOV 0 002 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) ,~a~l 0il & Gas g0rls, C0mmlssl0n Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 403 1430 1306 Subsequent to operation: 619 1360 2813 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the forgoing is true and_correct to the best of my knowledge Si.qned So~e TechnicalAssistant Date ~ ' Prepared Bv Name/Nurnbec Sondra Stewman, 564-4750 ~1f3~7 , n Form 10-404 Rev. 06/15/88 Submit In Duplicate Legal Well Name: MPE-09 Common Well Name: MPE-09 Spud Date: 10/13/1994 Event Name: WORKOVER Start: 10/18/2002 End: 10/21/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/21/2002 Rig Name: NABORS 4ES Rig Number: 4ES i:i:!i i:ii ii~?Tb..'i ::.i~r~ii! :~ lilC~dei' -P~ i:i :: Description of Operations 10/18/2002 18:00 - 00:00 6.00 MOB P PRE MOVE RIG FROM MPI-02 & RIG UP ON MPE-09 & SAFE OUT EQUIPMENT. RIG ACCEPT @ 00:01 HRS. 10/19/2002 10/19/2002 00:00-01:00 1.00 KILL P DECOMP RIG UP TO KILLWELL 01:00 - 01:30 0.50 PULL P DECOMP RIG LUBRICATOR & PULL BPV SITP=2550 PSI. SICP= 2550 PSI. 01:30 - 10:30 9.00 KILL P DECOMP CIRC. WELL BORE WITH HOT SEAWATER 8.5 PPG. & REMOVE WELLBORE INFLUX & SlTP-190 PSI. CIRC. WELL BORE TO 9.2 PPG. FLUID & MONITOR SAME (STATIC) & . S ET TWC 10:30 - 12:00 1.50 WHSUR P DECOMP NIPPLE DN TREE 12:00 - 14:00 2.00 BOPSUIq P DECOMP NIPPLE UP BOP (INSTALL RE-BUILT HYDRAULIC CHOKE. 10,OOOPSI. 14:00 - 17:30 3.50 BOPSUR P DECOMP PRESSURE TEST BOP TO 250/3500 PSI. TEST WAIVED BY CHUCK SHEVE WITH AOGC. 17:30 - 18:30 1.00 PULL P DECOMP RIG LUBRICATOR & PULL TWC. 18:30 - 00:00 5.50 PULL P DECOMP PULL HANGER TO FLOOR & LAY DN & PULL ESP COMPLETION. 10/20/2002 00:00 - 06:00 6.00 PULL P DECOMP POOH & LAY DN ESP ASSY. 06:00 - 07:00 1.00i PULL P DECOMP MOVE ESP OUT OF SHED AND LOAD NEW ESP ASSY. & CLN-RIG FLOOR 07:00- 12:00 5.00 RUNCOI~ COMP MU ESP ASSY. 12:00 - 14:00 2.00 RUNCO~ P COMP RIH WITH ESP ASSY. TESTED BAD AT CHECK@ 1900' 14:00 - 16:00 2.00 PULL N DFAL COMP POOH & INVESTIGATE PROBLEM (SHOWED WATER IN POTHEAD AT MTR. POSSIBLE IN MTR. 16:00- 18:00 2.00 PULL N DFAL COMP LAY DN ESP MTR. 18:00 - 20:30 2.50 PULL N DFAL COMP MU & SERVICE ESP ASSY. 20:30 - 00:00 3.50 RUNCOI~ COMP RIH WITH ESP ASSY (CHECK & CIRC THROUGH PUMP EVERY 2000' 10/21/2002 00:00 - 07:30 7.50 RUNCOI~ COMP RIH WITH ESP COMPLETION TO SETTING DEPTH @ 13503' 07:30 - 09:30 2.00 RUNCOI~ COMP MU HANGER & MAKE EFT CONNECTOR & LAND SAME & RILDS & TEST HANGER TO 5000 PSI. & SET BPV. 09:30 - 11:00 1.50 WHSUR 3 COMP NIPPLE DN BOP'S 11:00 - 12:00 1.00 WHSUR ~ COMP NIPPLE UP TREE & TEST TO 5000 PSI. 12:00 - 13:00 1.00 WHSUR ~ COMP PULL TWC & SET BPV & SECURE WELL AREA. RIG RELEASED @ 1300 HRS. 10/21/2002 Printed: 10/28/2002 2:24:58 PM .... STATE OF ALASKA ALASKA ,..,IL AND GAS CONSERVATION COMM~oSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 54' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3731' NSL, 2029' WEL, SEC. 25, T13N, R10E, UM MPE-09 At top of productive interval 9. Permit Number / Approval No. 194-132 1154' SNL, 2804' EWL, SEC. 32, T13N, R11E, UM 10. APl Number At effective depth 50- 029-22513-00 1342' SNL, 3035' EWL, SEC. 32, T13N, R11E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1425' SNL, 3138' EWL, SEC. 32, T13N, R11 E, UM Sands 12. Present well condition summary Total depth: measured 14570 feet Plugs (measured) true vertical 7231 feet Effective depth: measured 14420 feet Junk (measured) true vertical 7159 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 3784' 9-5/8" 748 sx PF 'E', 250 sx Class 'G' 3814' 3032' Intermediate 13712' 7" 195 sx Class 'G' 13739' 6880' Production Liner 983' 5" 150 sx Class 'G' 13582'- 14565' 6819'-7229' Perforation depth: measured 14002'- 14084', 14132'- 14200', 14480'- 14495' true vertical 6980'- 7013', 7032'-7060', 7387'- 7195' ~ F ~ ~ I\/~ D ,' 4 200! Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 8rd EUE 13495' ,,~,!ask,.a Oil &. ~a~ (?:,~'~s. Coiaraissior. Packers and SSSV (type and measured depth) None Ar~ch0r~'.ge 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 192 190 651 Subsequent to operation: 531 356 1191 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Si~lned ~ Title Technical Assistant Date [ (~ -r.~--~-? } Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate ~'' i ti :ns sUmmary Report Legal Well Name: MPE-09 Common Well Name: MPE-09 Spud Date: 10/13/1994 Event Name: WORKOVER Start: 10/12/2001 End: 10/15/2001 Contractor Name: NABORS Rig Release: 10/15/2001 Rig Name: NABORS 4ES Rig Number: Date Hours Acti~i~ Code ~NPT l! ~hase' Description of Operations 10/9/2001 00:00- 14:00 14.00 MOB N RREP DECOMP MOVING RIG TO E-PAD. REPAIR BLOWN TIRE ON MAIN SUBSTRUCTURE. 14:00-00:00 10.00 MOB N RREP DECOMP ~ D VERT RIG TO C PAD TO REPLACE ALL TIRES & RIMS ON SUB. 10/10/2001 00:00- 00:00 24.00 MOB N RREP DECOMP REPLACING TIRES & RIMS ON SUBSTRUCTURE. 10/11/2001 00:00 - 00:00 24.00 MOB N RREP DECOMP REPLACE TIRES & RIMS ON SUBSTRUCTURE. 10/12/2001 00:00- 09:00 9.00 MOB N RREP DECOMP REPLACED TIRS & RIMS ON SUB. 09:00 - 13:00 4.00 MOB P DECOMP MOVE FROM C-PAD TO MP E-09. 13:00 - 18:00 5.00 RIGU P DECOMP MIRU. RAISE & SCOPE OUT DERRICK. 18:00 - 21:30 3.50 REST P DECOMP SPOT & BERM TIGER TANK. PJU LINES. 21:30 - 22:00 0.50 REST P DECOMP PULL BPV. 22:00 - 23:00 1.00 REST P DECOMP R/U LINES TO TREE & PRESS. TEST. 23:00 - 00:00 1.00 REST P DECOMP OPEN UP WELL. TBG. 100 PSI. CSG. 700 PSI. START CIRC. 4 1/2 BPM @ 1250 PSI W/SEAWATER. 10/13/2001 00:00 - 03:30 3.50 REST P DECOMP CIRC. WELL W/SEAWATER. SHUT IN & MONITOR. SLIGHT FLOW ON TBG. 03:30 - 04:30 1.00 REST P DECOMP BULLHEADED 35 BBLS. DN. TBG. CIRC WELL BACK TO PITS. 4 1/2 BPM @ 1350 PSI. SLIGHT VAC. ON TBG. & CSG. 04:30- 05:30 1.00 REST !P DECOMP SET TWC & TEST. 05:30 - 07:00 1.50 REST P DECOMP ND TREE. 07:00- 09:30 2.50 REST P DECOMP NU BOPE. 09:30 - 13:30 4.00 REST P DECOMP PRESS. TEST BOPE 250/3500 AS PER BP/AOGCC REGS. WITNESSING WAIVERED BY JOHN CRISP 05:30 AM 10/13/2001. 13:30 - 14:30 1.00 REST :) DECOMP PULL TWC. 14:30 - 16:00 1.50 REST :) DECOMP PU LANDING JT. MU HANGER. BOLDS. PULL HANGER TO FLOOR. PU 84K. 16:00 - 00:00 8.00 REST ~ DECOMP ATTACH ESP CABLE TO SPOOLING UNIT. POOH WI 2 7/8" TBG. & ESP. 10/14/2001 00:00 - 04:30 4.50 REST ~ DECOMP CONT. TO POOH W/2 7/8" TBG & ESP. 04:30 - 08:00 3.50 REST ~ DECOMP LD PUMP & MOTOR. 08:00 - 10:00 2.00 REST = DECOMP CLEAR RIG FLOOR. CIO ESP SHEAVE. INSTALL ESP SPOOLS IN SPOOLER. 10:00 - 16:00 6.00 REST :~ DECOMP PU PUMPS & MOTOR. SERVICE & TEST. 16:00-00:00 8.00 REST = DECOMP !RIHW/2 7/8"TBG. & ESP. 10/15/2001 i00:00 - 07:30 7.50 RUNCOr~P COMP 07:30 - 10:00 2.50 RUNCOI~F~ COMP MU HANGER & MAKE ESP CONNECTOR & TEST & LAND HGR.& RILDS 10:00 - 12:00 2.00 BOPSUF~ = COMP SET TWC & TEST & ND BOP 12:00 - 15:00 3.00 WHSUR P COMP INSTALL TREE & TEST TO 5000 & PULL TWC & SET BPV. & RELEASE RIG @ 1500 HRS. 10/15/2001 Printed: 10/22/2001 10:44:58 AM STATE OF ALASKA . ALASKA ,~,IL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 54' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3731' NSL, 2029' WEL, SEC. 25, T13N, R10E, UM MPE-09 At top of productive interval 9. Permit Number / Approval No. 194-132 1154' SNL, 2804' EWL, SEC. 32, T13N, R11E, UM 10. APl Number At effective depth 50- 029-22513-00 1345' SNL, 3047' EWL, SEC. 32, T13N, R11E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1418' SNL, 3153' EWL, SEC. 32, T13N, R11E, UM Sands 12. Present well condition summary Total depth: measured 14570 feet Plugs (measured) true vertical 7231 feet Effective depth: measured 14420 feet Junk (measured) true vertical 7159 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 3784' 9-5/8" 748 sx PF 'E', 250 sx Class 'G' 3814' 3032' Intermediate 13712' 7" 195 sx Class 'G' 13739' 6880' Production Liner 983' 5" 150 sx Class 'G' 13582'-14565' 6819'-7229' Perforation depth: measured 14002'- 14084', 14132'- 14200', 14480'- 14495' true vertical 6980'- 7013', 7032'-7060', 7387'- 7195' RECEIVED Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 8rd EUE 13506' fvl/ Y 0 3 _001 Packers and SSSV (type and measured depth) Baker FB-1 Packer at 13548' Alaska Oil & Gas Cons. Commission 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 192 190 651 Subsequent to operation: 531 356 1191 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that t~.~/o~going is true and correct to the best of my knowledge Signed Son~~~,,~.2.~ _._Title TechnicalAssistant Datef~--~___~','~L__~.l ' .. ~ ~-~ ~ ~'~, ~ ~ i f~, ~ Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 : !i ioperatiOns Summary Report Legal Well Name: MPE-09 Common Well Name: MPE-09 Spud Date: Event Name: WORKOVER Start: 4/15/2001 End: 4/19/2001 Contractor Name: NABORS Rig Release: 4/19/2001 Group: RIG Rig Name: NABORS 4ES Rig Number: :Oate~;:~:: FrO:~:;~o: Hou~S:[i:Task codeSUb: ~ Phase Description of Operations 4/15/2001 04:00 - 06:00 2.00 MOB PRE SCOPE DOWN AND LOWER DERRICK 06:00 - 12:30 6.50 MOB PRE MOVE RIG FROM MPL-12 TO MPE-09 12:30 - 15:30 3.00 RIGU PRE RAISE DERRICK AND SCOPE UP. TAKE ON BRINE 15:30 - 17:30 2.00 RIGU PRE RIG UP TIGER TANK AND HCR VALVE 17:30 - 18:00 0.50 WHSUR DECOMP PICK UP LUBRICATOR AND PULL BACK PRESSURE VALVE 18:00-19:30 1.50 WHSUR DECOMP HOOK UP HARD LINES TO TREE AND TIGER TANK AND TEST TO 3500 PSI 19:30 - 22:30 3.00 WHSUR DECOMP PJSM WITH CO REP AND PUSHER / CREWS OPEN WELL TO CHOKE WITH 310 PSI TBG AND 370 PSI SICP. PUMPED 8.8 PPG BRINE DOWN TUBING AT 4 BPM BULL HEADED INFLUX W/20 BBLS. CIRCULATED 240 BBLS OF CRUDE TO TIGER TANK. PUMPED A TOTLA OF 530 BBLS RAN OUT OF FLUID STILL HAD OIL AT SURFACE ON ANNULUS. 22:30 - 23:00 0.50 WHSUR DECOMP MONITOR WELL WITH 0 PSI ON TUBING AND SLIGHT BLOW ON CASING. 23:00 - 00:00 1.00 WHSUR DECOMP WAIT ON PEAK TO HAUL FLUID 4/16/2001 00:00 - 02:30 2.50 WHSUR DECOMP WAIT ON PEAK TO HAUL FLUID 02:30 - 03:30 1.00 WHSUR , DECOMP TAKE ON SEA WATER AND WT UP TO 8.8 PPG 03:30 - 05:00 1.50 WHSUR DECOMP PUMP DOWN TBG @3 BPM AT 600 PSI CIRCULATED OIL OUT. 05:00 - 05:30 0.50 WHSUR DECOMP MONITOR WELL--TUBING AND CASING ON VAC 05:30 - 06:00 0.50 WHSUR DECOMP SET TWC AND TEST TO 3,500 PSI 06:00 o 07:30 1.50 WHSUR DECOMP NIPPLE DOWN TREE 07:30 - 10:00 2.501 WHSUR DECOMP NIPPLE UP BOPE 10:00 - 13:00 3.001WHSUR DECOMP TEST BOPE TO 250/3500 PSI ANNULAR TO 250/2500 PSI. ACCUMULATOR TEST 13:00 o 14:30 1.50 WHSUR DECOMP RIG UP LUBRICATOR AND PULL TWCV 14:30 - 16:00 1.50 WHSUR DECOMP MAKE UP LANDING JOINT/BOLDS/PULL HANGER TO FLOOR 95 K PU WT./50 K SO WT. LD HANGER AND CLEAR FLOOR 16:00 - 21:30 5.50 WHSUR DECOMP POH WITH 2 7/8" ESP COMPLETION 21:30 - 22:30 1.00 WHSUR DECOMP CHANGE OUT SPOOLS & MAG CABLE 22:30 - 00:00 1.50 WHSUR DECOMP CONTINUE TO POH WITH 2 7/8" ESP COMPLETION TO 3620'-- SLM 4/17/2001 00:00 - 02:30 2.50 PULL DECOMP POOH W/2 7/8" COMPLETION STRING. 02:30 - 04:30 2.00 PULL DECOMP PULL ESP. INSPECT & L/D SAME. 04:30 - 05:00 0.50 PULL DECOMP CLEAR FLOOR. R/U TO P/U MOTOR. 05:00 - 13:00 8.00 CLEAN DECOMP P/U BIT & MOTOR. RIH ON 2 7/8" TBG TO 13376'. FILL EVERY 3000'. 13:00 - 13:30 0.50 CLEAN DECOMP CHANGE OUT HANDLING TOOLS F1 2 7/8" TO 3 1/2" DP. 13:30 - 19:00 5.50 CLEAN DECOMP P/U 3 1/2" DP & RIH TO 14278'. TAGGED UP. P/U CIRC HEAD & WASH THRU. CON'T RIH TO 14523'. 19:00 - 20:30 1.50 CLEAN DECOMP CIRCULATE HOLE. WAIT ON ORDERS. NO CMT IN SHOE TRACK. 20:30 - 00:00 3.50 CLEAN DECOMP MIX & PUMP SWEEP CIRC HOLE CLEAN. 4/18/2001 00:00 - 00:30 0.50 CLEAN DECOMP SWEEP & CIRCULATE HOLE CLEAN. 00:30 - 01:00 0.50 CLEAN DECOMP MONITOR WELL, FL 20 BPH. 01:00 - 03:00 2.00 CLEAN DECOMP DROP BALL POOH W/CLEAN OUT STRING. 2 7/8" COLLARS HANGING UP ON PKR BORE. 103:00 - 03:30 0.50 CLEAN DECOMP CHANGE OUT TO 2 7/8" TBG HANDLING TOOLS. 03:30 - 10:30 7.00 CLEAN DECOMP SHEAR CIRC SUB W/2800 PSI, POOH W/2 7/8" TBG STRING. ] (SLM) / 10:30 - 12:00 1.50 CLEAN ! DECOMP L/D MOTOR & CLEAR FLOOR. 12:00 - 15:00 3.00 BOPSUI~ DECOMP ATTEMPT TO TEST VARIABLE RAMS, NO TEST INSTALL 2 7/8" / TBG RAMS & TEST SAME. 15:00 - 15:30 0.50 BOPSUR DECOMP L/D TEST PLUG. 15:30 - 21:30 6.00 PERF DECOMP R/U SCHLUMBERGER. RIH & PERFORATE 14480 -14495'. W/2 1/2" Printed: 5/1/2001 10:10:34 AM : : ii:: i i i: i iiOPerationS SUmmary Report Legal Well Name: MPE-09 Common Well Name: MPE-09 Spud Date: Event Name: WORKOVER Start: 4/15/2001 End: 4/19/2001 Contractor Name: NABORS Rig Release: 4/19/2001 Group: RIG Rig Name: NABORS 4ES Rig Number: ?~ :Date ~ i :From:TO R0Urs 'TaSk ! SUb Phase Description of Operations , Code : 4/18/2001 15:30 -21:30 6.00 PERF DECOMP GUN 120 DEGREE PHASING.. R/D SCHLUMBERGER. FILL HOLE W/32 BBLS. 21:30 - 00:00 2.50 RUNCOI~I COMP M/U, SERVICE & TEST ESP. 4/19/2001 00:00 - 01:00 1.00 RUNCON1 COMP INSTALL CABLE IN ESP & CHECK SAME. 01:00 - 06:30 5.50 RUNCOI~I COMP RIH W/2 7/8" COMPLETION STRING. 06:30 - 09:00 2.50 RUNCOlYl COMP MAKE MID-RUN SPLICE. CHANGE OUT SPOOLS. 09:00 - 11:30 2.50 RUNCOI~I COMP RIH WI 2 7/8" COMPLETION. TAGGED UP @ 11700'. SEVERE DOGLEG. 11:30 - 14:00 2.50 RUNCOI~I COMP MIX 2 BBLS EP MUD LUBE & CIRC DOWN ALONG SIDE OF PUMP. WORK THRU TITE SPOT, LESS THAN I STAND. 14:00 - 15:30 1.501RUNCO~ COMP CON'T RIH W/2 7/8" COMPLETION STRING. 15:30 - 17:30 2.001 RUNCOIt COMP MAKE UP TBG HANGER. ALIGN & INSTALL PENETRATOR. ATTACH LOWER CONNECTOR. 17:30-18:00 0.50 RUNCOF~ COMP LANDTBGHANGERRILDS. P/UWT81K, S/OWT41K. 18:00 - 18:30 0.50 WHSUR COMP INSTALL TWC. 18:30 - 20:30 2.00 BOPSUF COMP N/D DOPE. 20:30 - 21:30 1.00 WHSUR COMP N/U X-MAS TREE. 21:30 - 22:30 1.00 WHSUR COMP PRESSURE TEST ADAPTER FLANGE & TREE TO 5000 PSI, OK. MAKE FINAL CHECK ON ESP. 22:30 - 23:30 1.00 WHSUR COMP PULL TWC & INSTALL BPV. 23:30 - 00:00 0.50 WHSUR COMP SECURE WELL & CLEAN CELLAR. RELEASE RIG @ 2400 HRS, 4-19-01. I Printed: 5/1/2001 10:10:34 AM C:LORi~ILIV[.DOC 9 &.'..-- i 32 9a.-- i32 6388 (3 D i".! / F N L. C D R / F' i",J L C P i/NWD CPIi/TVD 9a.-.. i92 EWR/DGR k~D ~6880'-'72.'q0 'i li.)'1/05/95 9a--' i 32 EWR/C'GFa TVD .~6880'-~7230 i 0 i/'05/'95 9 ,q. -'- i 32 9/~, .... 17}2 GR/,'£CL SF'OT T,SF' --~i26/~0"'i39'79 1 'i2/'2i/'9/~ F' B, !... S F' R E S S/" T E H P ~:~:r~O .... i 203 a. i i ';.! / 2 i/" 9 9 ~-~ 132 I'VD/,3IZ, N/FNL C~'~600 .... ?000 j 02./'1z.)'2/S5 9 h- --- 'i 32 T V [3,/C D R .~3000 '-' 7000 '1 0 ;!/' 02 / 95 We l'i C ,S, k~ i,~ E N T S Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) March 30, 1995 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the MWD GR & MWD GR TVD for well -J~t~:.~._.,~T_I., Job # 95095 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 3 Bluelines each 2 Film ¢¢*¢ State of Alaska Alaska Oil & Gas Conservation Comm. Attn: Larry Grant ~ 3001 Porcupine Drive ........ · . Ancllorage, Alaska 99501 . -. 1 OH LIS Tape 1 Blueline each 1 RF Sepia each OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail P 905 127 803 PLEASE NOTE; NO DEPTH SHIFTING PER GENE PIEKENPROCK PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Courier: Date Delivered: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Schlumberger- GeoQuest A Division of Schlumberger Technologies Corporation F E B 0 2:199 5 500 w, International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) Alaska 0ii & Gas Cons. Commjssior~ (907) 563-3309 (Fax) Anchorage February 2, 1995 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 ~ . he foiio~g data of the LWD DEPTH CORRECTED CDR. CDN. CDR-TVD & CDN,TVD b# 94361 was sent to: for well BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 1 OH Depll] Shift Monitor Plot & Listing 3 Bluelines 1 Film Returning CDR, CDN, CDR-TVD & CDN-TVD Field Film State of Alaska Alaska ~~ation Comm. Att, p'.~E~ rry Grant 3(~01 Porcupine Drive A~ch_.,orage, Alaska 99501 -1-OH-L-tS-T-ap~_ 1 Blueline "~ 1 RFolded Sepia OXY USA, Inc Attn: Erma Galindo . P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline I RFolded Sepia Sent Certified Mail P 905 127 771 PLEASE NOTE; NO QEET, I-&$ -IIFTING-PER GENE PIEKENPROCK RI CEIV ,u FEB 02 1995 PLEASE ACK~O~W~pg ~~b~IGNING AND RETURNING ONE COPY EACH TO: ... .. BP EXPLORATION (ALAS~) INC. PETROTECHNICAL DATA CENTER. MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALAS~ 9951.9-6612 · .. - Schlumberger Courier:~ ~ Received By: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 8 December 1994 Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION PLS FINAL BL PLS FINAL RF MPE-09~ ~ GR/CCL FINAL BL / MPE-09 1 PLS FINAL BL I PLS FINAL RF 1 PLS FINAL RF ECC No. Run # 1 6223.02 Run # 1 Run # 1 6313.02 Run # 1 Run # 1 6313.00 Run # 1 Run # 1 6313.01 Run # 1 Run # 1 , 6314.00 Run # 1 Please sign and return to~ Attn. Ro n b~~~_ _~ Or~~w,~~to (907) Received ~/~/~ ~ Dat e--~~ ~ 0 I:i I I_1_ I I~1 r~- '-T- WELL LOG TRANSM/TTAL To~ ARCO Alaska Inc. Attn: Larry Grant, AOGCC P.O. Box 100360 Anchorage, Alaska 99510-0360 MWD Formation Evaluation Logs - MPE-0~ December 28, 1994 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention oF ) .g'h Fun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 fr'~ 2" x 5" MD Resistivity and Gamma Ray Logs: 1 Blueline 1 Folded Sepia 2"x 5" TVD Resistivity and Gamma Ray Logs: 1 Blueline 1 Folded Sepia 1 Magnetic Tape w/LDWG Listings 4/~0,~, 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company .... STATE OF ALASKA .?. ALASKA _ ,L AND GAS CONSERVATION CC.~.,,vllSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well []Other Change Out ESP 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3731' NSL, 2029' WEL, SEC. 25, T13N, R10E, UM At top of productive interval 1079' SNL, 2732' EWL, SEC. 32, T13N, R11E, UM At effective depth 1345' SNL, 3047' EWL, SEC. 32, T13N, R11E, UM At total depth 1418' SNL, 3153' EWL, SEC. 32, T13N, R11E, UM Type of well: ~¢] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE - 54' 7. Unit or Property Name Milne Point Unit 8. Well Number MPE-09 9. Permit Number / Approval No. 194-132 10. APl Number 50- 029-22513 1. Field and Pool Milne Point Unit/Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 14570 feet 7231 feet 14420 feet 7159 feet Length Size Structural Conductor 80' 20" Surface 3784' 9-5/8" Intermediate 13712' 7" Production Liner 983' 5" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx.) 748 sx PF 'E', 250 sx Class 'G' 195 sx Class 'G' 150 sx Class 'G' MD TVD 112' 112' 3814' 3032' 13739' 6880' 13582'-14565' 6819'-7229' Perforation depth: measured 14002'-14084',14132'-14200' true vertical 6980'-7013', 7032'-7060' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 8rd EUE 13518' Packers and SSSV (type and measured depth) Baker FB-1 Packer at 13548' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ~lasl<a 0il & (;as Cons. (;0rnmissi0r~ Anchorage 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the for~egoing is true and correct to the best of my knowledge Signed ,~",/~ ~ Terrie Hubble . Title Technical Assistant III Prepared By Name/Number: Date IZ'O~'(~ ~ Terrie Hubble, 564-4628 '~.~ ~ ~n ~uuplicate.~..~ Form 10-404 Rev. 06/15/88 Facility Datefrime 07 Nov 99 08 Nov 99 M Pt E Pad Progress Report 06:00-12:00 06:00-12:00 Well MPE-09 Page 1 Rig Nabors 4ES Date 30 November 99 12:00 12:00-14:30 12:00-14:30 14:30 14:30-15:30 14:30-15:30 15:30 15:30-22:00 15:30-18:30 18:30 18:30-19:00 19:00 19:00-21:00 21:00 21:00-22:00 22:00 22:00-23:00 22:00-23:00 23:00 23:00-00:30 23:00-00:30 00:30 00:30-02:30 00:30-02:30 02:30 02:30-05:00 02:30-03:30 03:30 03:30-05:00 05:00 05:00-06:00 05:00-06:00 06:00 06:00-17:30 06:00-17:30 17:30 17:30-06:00 17:30-01:30 09 Nov 99 01:30 01:30-06:00 Duration 6hr 6hr 2-1/2 hr 2-1/2 hr lhr lhr 6-1/2 hr 3hr 1/2 hr 2hr lhr lhr lhr 1-1/2 hr 1-1/2 hr 2hr 2hr 2-1/2 hr lhr 1-1/2 hr lhr lhr 11-1/2 hr 11-1/2 hr 12-1/2 hr 8hr 4-1/2 hr Activity Move rig Rig moved 100.00 % MI/RU At well location - Slot Derrick management Rigged up High pressure lines Rig up Tiger tank & lines & take on sea h20 Equipment work completed Wellhead work Removed Hanger plug Equipment work completed Well control Circulated closed in well at 13402.0 fl test lines to 3000 psi. & sicp=650 psi. tbg=650 psi. & circ. well clean of influx with seah20 Hole displaced with Seawater - 200.00 % displaced Monitor wellbore pressures Observed pressures - string: 0.000 psi, annulus: 270.000 psi Circulated closed in well at 13403.0 fl Hole displaced with Seawater - 100.00 % displaced Monitor wellbore pressures well Static & set twc. Observed well static Wellhead work Rigged down Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Test waived by John Crisp with AOGC Pressure test completed successfully - 3500.000 psi Wellhead work Removed Hanger plug Equipment work completed Removed Tubing hanger Equipment work completed Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 500.0 fl Stopped: To hold safety meeting Pull Single completion, 2-7/8in O.D. (cont...) Pulled Tubing in stands to 0.0 ft pulll & lay dn esp & conduct a onsite investigation (found that the connector on flat lead was faulty Completed operations Run Single completion, 2-7/8in O.D. Serviced ESP Rig floor & make up esp assy & service same & damaged esp flat lead while pulling over sheave & had to replace & splice same to esp cable. Equipment work completed Ran Tubing in stands to 6074.0 ft RECEIVED PTC 03 1999 ~Oit l Gas Cons. Commi~on Facility Date/Time 10 Nov 99 Progress Report M Pt E Pad Well MPE-09 Page 2 Rig Nabors 4ES Date 30November 99 06:00 06:00-20:30 06:00-13:00 13:00 13:00-16:00 16:00 16:00-18:00 18:00 18:00-20:30 20:30 20:30-21:00 20:30-21:00 21:00 21:00-22:30 21:00-22:30 22:30 22:30-23:30 22:30-23:30 23:30 23:30-06:00 23:30-00:00 00:00 Duration 14-1/2 hr 7 hr 3hr 2hr 2-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr lhr lhr 6-1/2 hr 1/2 hr Activity Stopped: To hold safety meeting Run Single completion, 2-7/8in O.D. (cont...) Ran Tubing in stands to 11900.0 ft Observed 15.00 klb resistance Circulated at 11900.0 ft Esp completion begin taking wt. & mixed 2-bbl. of ep mud lube & when fluid exited pump friction was reduced so that pump & motor assy went through with little resistance. (Note: this acted as well bore geomentry ( don"t Know)??? Obtained req. fluid properties - 25.00 %, hole vol. Ran Tubing in stands to 13526.0 ft Completed run with ESP to 13526.0 ft Serviced Completion equipment Make EFT hanger connection Equipment work completed Wellhead work Installed Tubing hanger Install hanger & set twc & test same to 2500 psi. Tie-down bolts energised Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree Test tree & hanger to 5000 psi. Equipment work completed Wellhead work Removed Hanger plug Remove twc & set BpV Equipment work completed -.~---. STATE OF ALASKA --'- ALASK/-, .,IL AND GAS CONSERVATION C~MMISSlON REPORT OF SUNDRY WELL OPERATIONS !1. Operations performed: i2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Operation Shutdown [] Stimulate [] Plugging [] Pull Tubing []Alter Casing [] Repair Well []Other 5. Type j~ well: Development [] Exploratory [] Stratigraphic []Service 4. Location of well at surface 3731' NSL, 2029' WEL, SEC. 25, T13N, R10E, UM At top of productive interval 1079' SNL, 2732' EWL, SEC. 32, T13N, RllE, UM At effective depth 1345' SNL, 3047' EWL, SEC. 32, T13N, R11 E, UM At total depth 1418' SNL, 3153' EWL, SEC. 32, T13N, RllE, UM [] Perforate Change Out ESP 6. Datum Elevation (DF or KB) KBE = 54' 7. Unit or Property Name Milne Point Unit 8. Well Number MPE-09 9. Permit Number / Approval No. 94-132 10. APl Number 50- 029-22513 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 14570 true vertical 7231 Effective depth: measured 14420 true vertical 7159 Casing Length Structural Conductor 80' Surface 3784' Intermediate 13712' Production Liner 983' feet Plugs (measured) feet feet Junk (measured) feet Size Cemented 20" 250 sx Arcticset I (Approx.) 9-5/8" 748 sx PF 'E', 250 sx Class 'G' 7" 195 sx Class 'G' 5" 150 sx Class 'G' MD TVD 112' 112' 3814' 3032' 13739' 688O' 13582'-14565' 6819'-7229' Perforation depth: measured true vertical 14002'-14084',14132'-14200' 6980'-7013', 7032'-7060' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 8rd EUE 13516' Packers and SSSV (type and measured depth) Baker FB-1 Packer at 13548' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ' · Terrie Hubble' , Title Technical Assistant III Prepared By Name/Number: Date I O'~'C~ , ~.... Terrie Hubble, 564-4628 ~ Submit In Duplicat.~ee ~a Form 10-404 Rev. 06/15/88 Facility Date/Time 12 Oct 99 13 Oct 99 14 Oct 99 Progress Report M Pt E Pad Well MPE-09 Page 1 Rig Nabors 4ES Date 25 October 99 12:00-17:00 12:00-17:00 17:00 17:00-01:30 17:00-20:00 20:00 20:00-01:30 01:30 01:30-02:00 01:30-02:00 02:00 02:00-02:30 02:00-02:30 02:30 02:30-03:00 02:30-03:00 03:00 03:00-06:00 03:00-05:00 05:00 06:00-07:30 06:00-07:30 07:30 07:30-08:30 07:30-08:30 08:30 08:30-21:30 08:30-21:30 21:30 21:30-01:00 21:30-01:00 01:00 01:00-06:00 01:00-06:00 06:00 06:00-20:30 06:00-08:30 08:30 08:30-15:00 15:00 15:00-20:30 Duration 5hr 5hr 8-1/2 hr 3hr 5-1/2 hr lhr lhr 13hr 13hr 3-1/2 hr 3-1/2 hr 5hr 5hr 14-1/2 hr 2-1/2 hr 6-1/2 hr 5-1/2 hr Activity Derrick management Rigged up High pressure lines Set tiger tanks & rig lines to same. & pull BPV Equipment work completed Well control Circulated closed in well at 14002.0 ft Test lines to 3000 psi. & displace well bore fluids 8.5 PPG. sea H20 & bullhead 14-Bbl. to perf. & shut welll in & monitor SITP--20 PSI. SICP = 50 PPSI. Hole displaced with Seawater - 150.00 % displaced Circulated closed in well at 14002.0 ft Raise brine wt. to 8.7 & shut in and monitor well Static. Influx Out of hole Wellhead work Installed Hanger plug Equipment work completed Wellhead work Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi Test well control equipment (cont...) Tested BOP stack Pressure test completed successfully - 3500.000 psi TEST WAIVED BY LEW GRIMMALDI. WITH AOGC Wellhead work Removed Hanger plug Equipment work completed Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 13534.0 ft Electrical submersible pumps laid out Slickline wireline work Conducted slickline operations on Slickline equipment - Tool run RIG HES & RIH WITH 3.77" SWEDGE & FIND TD. @ 14074' WLM. Completed run with Blind box from 0.0 ft to 14074.0 ft 2-7/8in. Surge string workstring run Ran Tubing in stands to 10562.0 ft RIH WITH MULE SHOE FOR CLEAN OUT. Stopped · To hold safety meeting 2-7/8in. Surge string workstring run (cont...) Ran Tubing in stands to 14097.0 ft Observed 15.00 klb resistance Reverse circulated at 14435.0 ft reverse circ. sand from 5" liner F/14097' to 14435' & clean fluid & monitor well bore. lost app. 180 bbl. on clean out. Hole displaced with Brine - 250.00 % displaced Pulled Tubing in stands to 0.0 ft Facility Date/Time M Pt E Pad Duration 20:30 20:30-06:00 20:30-06:00 9-1/2 hr 9-1/2 hr 15 Oct 99 06:00 06:00-13:00 06:00-13:00 13:00 13:00-14:00 13:00-14:00 14:00 14:00-15:30 14:00-15:30 15:30 15:30-17:00 15:30-16:30 16:30 16:30-17:00 7hr 7hr lhr lhr 1-1/2 hr 1-1/2 hr 1-1/2 hr lhr 1/2 hr 17:00 17:00-06:00 17:00-18:00 13 hr lhr Progress Report 18:00 Well MPE-09 Page Rig Nabors 4ES Date Activity Completed operations Run Single completion, 2-7/8in O.D. Ran Tubing in stands to 6400.0 ft Rig floor & make up esp assy & service same & rih to 6400 feet & make mid-line splice. Stopped: To hold safety meeting Run Single completion, 2-7/8in O.D. (cont...) Ran Tubing in stands to 13489.0 ft ran esp to setting depth & install hanger & splice esp cable & land hanger & rilds. Completed run with ESP to 13489.0 ft Wellhead work Installed Hanger plug Equipment work completed Nipple down BOP stack Rigged down BOP stack Equipment work completed Wellhead work Installed Xmas tree test hanger & tree to 5000 psi. (FMC) Equipment work completed Installed Hanger plug pull twc & set bpv. Equipment work completed Fluid system Freeze protect well - 15.000 bbl of Diesel Freeze protect tbg. only (PE's to freeze protect annulus. Completed operations 2 25 October 99 ...... STATE OF ALASKA -- ALASKA C,,. AND GAS CONSERVATION COM~,,,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate []Alter Casing []Repair Well I--IOther 5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service [] Pull Tubing 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3731' NSL, 2029' WEL, SEC. 25, T13N, R10E, UM At top of productive interval 1079' SNL, 2732' EWL, SEC. 32, T13N, R11E, UM At effective depth 1345' SNL, 3047' EWL, SEC. 32, T13N, R11E, UM At total depth 1418' SNL, 3153' EWL, SEC. 32, T13N, R11E, UM 12. Present well condition summary 6. Datum Elevation (DF or KB) KBE = 54' 7. Unit or Property Name Milne Point Unit 8. Well Number MPE-09 9. Permit Number / ApprovalNo. 94-132 397-193 10. APl Number 50-029-22513 11. Field and Pool Milne Point Unit / Kuparuk River Sands .. · · Total depth: measured 14570 feet Plugs (measured) true vertical 7231 feet Effective depth: measured 14520 feet Junk (measured) true vertical 7207 feet Casing Length Size Cemented Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) Surface 3784' 9-5/8" 748 sx PF 'E', 250 sx Class 'G' Intermediate 13712' 7" 195 sx Class 'G' Production Liner 983' 5" 150 sx Class 'G' MD .... ~';~': TVb 112' 112' 3814' 3032' 13739' 6880' 13582'-14565' 6819'-7229' Perforation depth: measured 14002'-14084', 14132'-14200' true vertical (Subsea) 6914'-6947', 6980'-7007' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 8rd EUE 13535' Packers and SSSV (type and measured depth) Baker FB-1 Packer at 13548' (LLCV at 13548' removed) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 17. I hereby certify that the f,eregoing i,s true.and correct to the best of my knowledge Signed ..,/~, -jr~/~ ~ Terrie Hubble , Title Technical Assistant III Prepared By Name/Number: I16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Du Progress Report Facility M Pt E Pad Well MPE-09 Page 1 Rig Nabors 4ES Date 10 February 99 Date/rime 02 Nov 97 00:00-06:00 06:00-06:30 06:30-15:00 15:00-16:30 16:30-18:00 18:00-18:30 18:30-20:00 20:00-23:00 23:00-06:00 03 Nov 97 06:00-06:30 06:30-18:00 18:00-19:00 19:00-23:00 23:00-00:00 04 Nov 97 00:00-00:30 00:30-02:30 02:30-04:30 04:30-06:00 06:00-06:30 06:30-22:30 22:30-06:00 05 Nov 97 06:00-06:30 06:30-06:00 06 Nov 97 06:00-06:30 06:30-10:30 10:30-17:00 17:00-18:30 18:30-06:00 07 Nov 97 06:00-06:30 06:30-08:00 08:00-10:00 10:00-13:00 13:00-19:30 19:30-04:00 08 Nov 97 04:00-05:30 05:30-06:00 06:00-06:30 06:30-12:00 12:00-18:00 18:00-19:30 19:30-05:00 09 Nov 97 05:00-06:00 06:00-06:30 06:30-07:30 07:30-09:30 09:30-10:30 10:30-06:00 10 Nov 97 06:00-06:30 06:30-11:30 11:30-12:30 12:30-14:00 14:00-15:30 15:30-17:00 17:00-18:00 Duration 6hr 1/2 hr 8-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 3hr 7hr 1/2 hr 11-1/2 hr lhr 4hr lhr 1/2 hr 2hr 2hr 1-1/2 hr 1/2 hr 16hr 7-1/2 hr 1/2hr 23-1/2 hr 1/2 hr 4hr 6-1/2 hr 1-1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr 2hr 3hr 6-1/2 hr 8-1/2 hr 1-1/2 hr 1/2hr 1/2 hr 5-1/2 hr 6hr 1-1/2 hr 9-1/2 hr lhr 1/2 hr lhr 2hr lhr 19-1/2 hr 1/2 hr 5hr 1-1/2 hr 1-1/2 hr 1-1/2 hr lhr Activity Rig moved 100.00 % Held safety meeting Circulated at 14000.0 ft Removed Xmas tree Installed BOP stack Held safety meeting Rigged up BOP stack Tested BOP stack Rig waited: Equipment Held safety meeting Rig waited: Equipment Rigged up Handling equipment Circulated at 14000.0 ft Retrieved Tubing hanger Held safety meeting Cut Tubing at 13250.0 ft Serviced Tubing handling equipment Cut Tubing at 13120.0 ft Held safety meeting Cut Tubing at 7830.0 ft Rig waited: Equipment Held safety meeting Cut Tubing at 0.0 ft Held safety meeting Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Rigged up Pipe ram Ran Drillpipe to 12000.0 ft (3-1/2in OD) Held safety meeting Ran Drillpipe to 13548.0 ft (3-1/2in OD) Retrieved Completion equipment Circulated at 13458.0 ft Pulled Drillpipe in stands to 0.0 ft Conducted slickline operations on Slickline equipment - Tool run Ran Drillpipe to 1050.0 ft (2-3/8in OD) Ran Drillpipe to 1500.0 ft (3-1/2in OD) Held safety meeting Ran Drillpipe in stands to 14137.0 ft Washed to 14511.0 ft Circulated at 14511.0 ft Laid down 13500.0 ft of 3-1/2in OD drill pipe Serviced Block line Held safety meeting Laid down 1000.0 ft of Drillpipe Removed Wellhead integral components Rigged up Handling equipment Ran Tubing to 12600.0 ft (2-3/8in OD) Held safety meeting Installed Tubing hanger Rigged down BOP stack Installed Adapter spool Tested Xmas tree Freeze protect well - 85.000 bbl of Diesel Installed Accessories Facility M Pt E Pad Progress Report Well MPE-09 Page 1 Rig Nabors 4ES Date 12 February 99 Date/Time 17 Apr 98 18 Apr 98 19 Apr 98 20 Apr 98 21 Apr 98 16:00-02:00 02:00-06:00 06:00-06:30 06:30-13:00 13:00-14:00 14:00-14:30 14:30-16:30 16:30-20:30 20:30-22:30 22:30-01:00 01:00-06:00 06:00-12:30 12:30-16:00 16:00-22:00 22:00-23:30 23:30-00:00 00:00-04:30 04:30-06:00 06:00-11:30 11:30-12:00 12:00-17:00 17:00-17:30 17:30-06:00 06:00-09:30 09:30-11:00 11:00-13:00 13:00-15:00 Duration 10hr 4hr 1/2 hr 6-1/2 hr lhr 1/2 hr 2hr 4hr 2hr 2-1/2 hr 5hr 6-1/2 hr 3-1/2 hr 6hr 1-1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 5-1/2 hr 1/2 hr 5hr 1/2hr 12-1/2 hr 3-1/2 hr 1-1/2 hr 2hr 2hr Activity Rig moved 100.00 % Fill pits with Water Tested High pressure lines Circulated closed in well at 14000.0 ft Flow check Rigged down Xmas tree Rigged up BOP stack Tested BOP stack Retrieved Tubing hanger Circulated at 14000.0 ft Pulled Tubing in stands to 8078.0 ft Pulled Tubing in stands to 0.0 ft Conducted slickline operations on Slickline equipment - Tool run R.I.H. to 14114.0 ft Reverse circulated at 14083.0 ft R.I.H. to 14145.0 ft Reverse circulated at 14420.0 ft Reverse circulated at 14420.0 ft Pulled out of hole to 0.0 ft Worked on BOP - Lubricator Conducted electric cable operations Worked on BOP - Lubricator Ran Tubing in stands to 13549.0 ft Installed Tubing hanger Rigged down BOP stack Installed Xmas tree Freeze protect well - 70.000 bbl of Diesel A~SKZ LAND GAS CONSERVATION OOM i SION APPLICATION FOR SUNDRY APPROVAL 1. TyPe of Request: [~ Abandon []Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance ~ Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well ~ Stimulate BOP Confi~luratlon Change 2. N-a~n'e of Operator " 5, Type of well: 6.' Datum Elevation (DF or KB) BP Exploration (Alaska) lnc, ~ Development KBE = ~4' · . [] Exploratory 7. Unit or Property Name Milne Point Unit 3. Address [] Stratlgraphic P.O, Box 196612, Anchorage, Alaska 99519-6612 [--I Service .............. ...... 8. Well Number 4, Location of well at surface MPE-09 3731' NSL, 2029' WEL, SEC. 25, T13N, R10E, UM 9. Permit Nu~er At top of productive inten, al 94-132 1079' SNL, 2732' EWL, SEC. 32, T13N, R11E, UM 10. APl Number At effective depth 50-029-22513 1345' SNL, 3047' EWL, SEC. 32, T13N, R11E, UM 11, Field ar~'~[ Pool At total depth Milne Point Unit / Kuparuk River 1418' SNL, 3153'___E~__L,_S_E_C. _._,3_2,..T. 13N, R11E, UU ........ Sands 12. Present well condition summary Totaldepth: truemeasuredvertical 14870 feet7231 feet Plugs(measured)0RJ(~INAL Effective depth: measured 14520 feet Junk (measured) true vertical 7207 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arctlcaet I (Approx.) 112' 112' Surface 3784' 9~5/8'' 748 sx PF 'E', 250 sx Class 'G' 3814' 3032' Intermediate 13712' 7" 195 sx Class 'G' 13739' 6880' Production Liner 983' 5" 150 sx Class 'G' 1358:~'-14565' 6819'-7229' Perforation depth: measured 14002'-14084', 14132'-14200' true vertical (Subsea) .(.ii(~'- [- 6914'-6947', 6980'-7007' Tubing (size, grade, and measured depth) 2-7/8" 5,46#/ft L-80 Coiled Tubing to 13329' /i]asko 0,'7 ~ ~; Oons.- ......... . . .. Packers and SSSV (type and measured depth) Baker FB-1 Packer at 13554'; LLCV at 1,3548' 13. Attachments [~ Description summary of prOpOSal '...r'i Detailed operations program [] BOP sketch 14. Estimated date for commencing operation 15. Status of well classifications as: October 30, 1997 16. If proposal w~s verbally approved [] Oil [] Gas {~ Suspended Blair Wondzell 10/27/97 Service Name of appmv~r ..... Date approved .................. Contact Englne~r N~melNurnb~r: Bob Laule, &$4~ S f SS Prepared By Narne/NUl'~g)e~: Kathy Campoarn~r, 564-5122 ~-~F. ey'1>.,~, 6/--' ' ........ 'Q__.- Title Dr]lli,~ Superlrltenden! ... Date //~;2 -' 2 ~ ~7 Commission Use Only Conditions of Approval: Notify Commission so representative may witness [Approval No. Plug integrity __ BOP Te~t e,"" Location clearance ~ ' '-' Mechanical Integrity Test__ Subsequent form required 1 0ri~in~l Sl~ined BY , Approved by or.d_e!~f t. he....C_o_m_m_.[ssion DaVid W. J.~h_rls..TM Commissioner Date[l Form 10-403 Rev. 06/15/88 Submi', In '] riplicate Approved Copy MIFtU on MP E -09 Pull 4" BPV with lubricator CircL~iate out freeze protection and circulate well with 8.8 ppg brine. Reverse in kill pill to the perforated tubing and bullhead to the formation. install 4" TWC ND Tree and 4-1/16" X 7-1/16" adapter flange.( Prior to ND adapter check for trapped press via port in 7 x 4 adapter ) Be sure to pull SBMS seal to allow landing ioint to engage landing thread. NU 7-1/16 X 13-5/8 spool and BOP. Test Pull TWC with lubricator RU landing joint XO to 3" 4 pitch Acme landing thread. Notify Tool services to provide NORM Inspection. Obtain Metal cuttings boxes size (minimum 4) Pull ¢oil tubing PJOM ( stress concerns of the operation of slip type elevators and the issue of the residual bend which will be retained In the tubing) Address the safety hazard of laying down the tubing cutoff,), If additional tool service hands are required to orientate the tubing cutoff in the metal boxes insure good communications are established and stressed in the pre job safety meeting, Also discuss the unique well shut in procedures i,e. shear rams First cut RU hydraulic tubing cutters from air tugger. Pull tubing hanger to floor and set in tubing in air slips. Install safety clamp at floor level, Secure tubing tail with clamp and safety chains to cutter. Locate hydraulic cutter into position 3' above safety clamp. Clear floor and remotely actuate. Remove safety ohains from the tubing out-off. Lay down tubing hanger and tubing stub. Lower tubing cutter to allow inst~llation of an additional safety Subsequentcuts PU YT slip type elevators dressed for 2-7/8". Set YT below the safety clamp, PU and remove lower safety clamp. PU and Pull approximately 10' (ultimately in longer sec'dons) of tubing allowing the tubing cutter to ride the pipe. 04:1~PM 5HRRED ~LNV£CLW UNLLL£M~ Set in slips, Install an additional safety clamp above floor slips, Slack off to relax tension in tubing to be cut off. Note the YT elevator slips may be unset but have safety clamp backup. Position the hydraulic cutter 3' above floor level. RU and secure the tail of the tubing to be cut. Install lower safety clamp, Clear floor and remotely actuate, Observe cutoff reaction after cut. Remove safety chains. Lay down cut off tubing. Note the amount of residual bend retained in the tubing. Lower cutoff tubing down the pipe skate_ Install safety clamp below cut point upset and remove safety clamp at floor level. Have tool service provide additional hands to orientate the cutoff tubing in the metal boxes. Install 7" BPV in false bowl, ND BOP ,7x13-5/8 spool. Confirm there is no trapped pressure in 7" X 11" adapter flange. ND adapter flange. NU 11 X 13-5/8 spool and BOP. Test for trapped pressure via annulus valve, Puli BPV without lubricator. Install 6" test plug and test BOP. After checking for trapped pressure Pull test plug without lubricator. Pull false bowl from the tubing spool. Install bowl protector. RIH to recover the LLCV with Camco LLC-2 "J" stot retrieving tool ,bumper sub on 3.5" DP. Circulate down as required. Slack off on contact with LLC-2. The tool will automatically latch. Utilise the bumper sub to locate the neutral point. Pick up 2 K over string weight and rotate to the right 15 turns to release the anchor. POH. RU wireline and attempt to tag fill in the liner, (If unsuccessful at entering both the FB packer and liner top with wireline to tag fill. RIH with mule shoe, 1100' 2-7/8 PAC XO to 3-1/2 DP and tag fill.) tf necessary cleanout to a minimum of 100' below the perforation, POH, RIH with E,.qP completion on 2-7/8 EUE 8 rd tubing, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 94-132 3. Address 8. APl Number P. O. Box 196612, Anchora~le, Alaska 99519-6612 5 o- 029-22513 4. Location of well at surface 9. Unit or Lease Name 3731' NSL, 2029' WEL, SEC. 25, T13N, RIOE, :'. '!~'. ! i-, .,.:;,i, , ] ~ [ Milne Point Unit [ ~"~-~'":/-~i// :~ ,LZT/ 10. Well Number At Top Producing Interval ; ~ ;'.~-7,~ MPE-09 1079' SNL, 2732' EWL, SEC. 32, T13N, R11E '.'"~i: ;~:',;:~; ~ ! ;~t~r¢~ ~ 11. Field and Pool i. ~,~'- ~ i ~.~? ~ilne Point-Kuparuk River Sands At Total Depth 1418'SNL, 3153' EWL, SEC. 32, T13N, R11E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 54' ADL 28231 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore ~16. No. of Completions 10/13/94 11/26/94 1~29/94 N/A feet MSL~ One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+~D) 19. Directional Survey J20. Depth where SSSV set 121. Thickness of Permafrost 14570'MD/7231' TVD 14435' MD/7166' TVD ~S B ~ B~ LLCV ~ 13548' feet MD~ 1800' (Approx.) 22. Type Electric or Other Logs Run GR/RES ~23. CASING, LINER AND CEME~ING ~D S~NG DE~H MD CASING SIZE ~. PER ~. G~E TOP ~ HO~ Sl~ C~E~NG RE,RD ~OU~ PULLED 20" 91.5~ H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40~ L-80 30' 3814' 12-1/4" 748 sx PF "E'F250 sx "G" 7" 26~ L-80 27' 13739' 8-1/2" 195 sx Class "G" 5" 15~ 13CR/L-80 13583' 14565' 8-1/2" 150 sx Class "G' 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RE,RD inte~al, size and number) SIZE DEPTH S~ (MD) PACKER S~ (MD) Gun Diameter 3-3/8" 6 spf 2-7/8", HS-70 13440' 13554' MD ~O (~) 14002L14084, 6914L6947, Coil tubin9 14132L14200' 6980L7007' 26. ACID, F~CTURE, CEME~SQUE~E,~C. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 1/5/95 ESP Date of Test Hours Tested TEsTPRODU~ONpERIOD FOR~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR ~TE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Base HRZ 12930' 6599' Top KC1 13968' 6855' Top Kuparuk 'B' 14088' 6914' RECEIVED MAR - 2 1995 A~as~ ut~ & Gas Cons. Commission 31. LIST OF A'I-rACHMENTS J~,rJcJzoJ'~ ,-. 32. i hereby certify ~at the foregoing is true and correct to the best of my knowledge Signed / [ Title Drilling Engineer Supervisor 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 MP E-09 10/13/94 379' FINISH MOVE RIG F. MP E-06 TO MP E-09. NU 20" DIVERTER. PU 5" HWDP AND STAND BACK IN DERRICK. FUNCTION TEST DIVERTER SYSTEM. MU BHA. FILL HOLE AND CHECK CIRC SYSTEM FOR LEAKS. DRLG F/112- 287'. FINISH MU BHA. DRLG 287- 379'. ACCEPT RIG @ 1800 HRS ON 10- 12-94. 10/14/94 3,068' DRLG AND MWD SURVEY F/379-1087'. SHORT TRIP TO 250'. NO PROBLEMS. DRLG AND MWD SURVEY F/1087-2030'. FLOW CHECK. CBU. POH 10 STDS. PU 30 JTS DP. NO PROBLEMS. DRLG AND MWD SURVEY F/2030-2976'. FLOW CHECK. CBU. POH 10 STDS. PU 30 JTS DP. NO PROBLEMS. DRLG AND MWD SURVEY F/2976-3068'. 10/15/94 3,834' DRLG AND MWD SURVEY F/3068- 3834'. PUMP SWEEP. CBU. SHORT TRIP TO HWDP. SLM. NO CORRECTION. NO PROBLEMS. CIRC AND CONDITION MUD FOR CSG. POH. LD BHA. CLEAR FLOOR. RU TO RUN CSG. RIH W/9 5/8" CSG. 10/16/94 3,834' LAND CSG AT 3414'. CIRC AND CONDITION MUD. NO LOSSES. PUMP 75 BBLS H20, 748 SX LEAD CEMENT AND 250 SX TAIL. DISPLACED W/RIG PUMPS. BUMPED PLUG. CHECK FLOATS. RD CEMENT HEAD. PERFORM TOP JOB. ND DIVERTER. INSTALL FMC SPEED HEAD. NU BOPE. TEST BOPE. REPAIR HCR VALVE. TEST. SLIP AND CUT DRLG LINE. SERVICE TOP DRIVE. PULL TEST PLUG. INSTALL WEAR BUSHING. MU BHA AND RIH. 10/17/94 5,180' 10/18/94 7,445' FINISH RIH W/DP TO FC. TEST CSG. DRILL OUT FE, CEMENT AND NEW FORMATION TO 3844'. CIRC AND CONDITION MUD. PERFORM LOT. LEAKED OFF AT 12.7 PPG STABILIZED AT 12.5 PPG. DRLG AND MWD SURVEY F/3844 - 5180'. CIRC SWEEPS. POH W/3 STDS. HOLE SWABBING. RIH. CIRC SWEEPS. BACK REAM 15 STDS TO SHOE. RIH SLOWLY. REAMED 4263- 4290'. REAMED LAST STD DOWN. CIRC SWEEPS. RU ATLAS WL. RUN GYRO SURVEY. WORK PIPE FREQUENTLY. NO PROBLEMS. RD ATLAS. .~i~sk~ Oil & Ga~ C~ns. ~mmission DRLG AND MWD SURVEY 5180 - 6220'. PUMP SWEEP. POH TO SHOE. HOLE SWABBING. BACK REAM TO 4897'. PU AND RIH W/"G" DP. CHECK SHOT AT 4309'. DRLG AND MWD SURVEY 6220 - 7258'. CIRC AND PUMP SWEEPS. MONITOR WELL. BACK REAM TO 6406'. P©H TO 6220'. PU 30 JTS "G" DP. NO PROBLEMS. DRLG AND MWD SURVEY 7258- 7445'. 10/19/94 7,823' DRLG AND MWD SURVEY F/7445 - 7823'. CIRC SWEEPS. MONITOR WELL. PUMP PILL, POH. LD BHA, NO PROBLEMS. PU TURBINE. CHANGE STAB BLADES, MU BHA #3, LOAD SOURCE, RIH W/BHA. SHALLOW TEST BHA. SERVICE TOP DRIVE. CHANGE SWIVEL PKG AND CHECK SAME. RIH, BOOT IN FLOWLINE LEAKING, REPLACE SAME. RIH TO 4323'. RIH. TIGHT AT 6285 - 6295'. REAMED 6445 -6465', TIGHT AT 7518'. PRECAUTIONARY REAM TO BOTTOM WHILE PU SINGLES, 10/20/94 10,416' DRILL F/7823 - 9376'. CIRC BOTTOMS UP. SHORT TRIP 17 STANDS F/ 9376 - 7770'. NO PROBLEMS. DRILL F/9376 - 10416'. 10/21/94 12,246' DRILL F/10416-10886'. CIRC BOTTOMS UP. SHORT TRIP 17 STANDS. NO PROBLEMS. DRILL F/ 10886-12246'. 10/22/94 13,175' DRILL F/12246- 13175'. CIRC SWEEP AROUND. POH TO 10710'. TIGHT SPOT 12358 - 12075'. PERFORM REPEAT PASS TO VERIFY CDR TOOL F/ 10710 - 10810', OK. FINISH POH TO CASING SHOE. TIGHT FROM 5833 - 5600'. SERVICE TOP DRIVE AND RIG. RIH. INSTALLING DRILL PIPE RUBBERS FROM 2500 - 500'. 10/23/94 13,508' FINISH RIH INSTALLING DRILL PIPE RUBBERS. DRILL F/13175 - 13508'. 10/24/94 13,583' DRILL F/13508 - 13583'. CIRC BOTTOMS UP. PUMP PILL. POH FOR NEW BIT. UNLOAD SOURCE, L/D LWD, MWD, AND TURBINE. PULL WEAR RING AND TEST BOPES. PULL TEST PLUG AND INSTALL WEAR RING. M/U BHA #4. LOAD SOURCE, TEST MWD, AND RIH TO CASING SHOE. CIRC BOTTOMS UP WHILE SLIPPING AND CUTTING DRILL LINE. NO MUD LOSSES. FINISH RIH. BENCHMARK SURVEY @ 4311'. RE-TORQUE DRILL PIPE RUBBERS. REAM 66' TO BO-I-FOM. .~. E 61Fl.. iV ~ 0 ~AR -2 1995 0il & Gas Cons. Commission 10/25/94 13,938' REAM 75' TO BOTTOM FOR TIE-IN LOGS. DRILL F/13,583 - 13938'. TOP OF SAND @ 13840/6992' TVD. INCREASE IN DRILLING RATE. CHECK FOR FLOW. WELL FLOWING SLIGHTLY. SHUT WELL IN. NO PRESSURES ON DP OR CASING. CIRC THRU CHOKE AND INCREASE MUD WT FROM 10.3 TO 10.5 PPG. AFTER COMPLETE CIRC MUD WT COMING OUT 7.9 PPG. INCREASE MUD WT TO 10.6 AND CIRC AROUND. MUD WT COMING BACK @ 8.5 PPG. PRESENTLY INCREASING MUD WT TO 10.7 PPG. 10/26/94 13,938' SHUT WELL IN. CHANGE OUT GAUGES. CIRC AND BUILD 300 BBLS 10.7 MUD. SICP INCREASED TO 160 PSI AND SIDP REMAINED AT 0 PSI. MIX 70 BBLS 40 PPB LCM PILL. CIRC THROUGH CHOKE. MIX AND PUMP 90 BBL LCM @ 3 BPM W/700 PSI THROUGH CHOKE UNTIL PILL WAS IN SCHRADER BLUFF. INCREASED PUMP RATE. CIRCULATE. PUMPED TOTAL 11500 STROKES. LOST 100 BBLS THIS CIRC. SHUT IN AND MONITOR WELL. 10/27/94 13,938' MONITOR WELL. CIRC AND INCREASE MUD. MIX 90 BBLS LCM PILL. SICP INCREASED TO 120 PSI WHILE WEIGHTING UP MUD SYSTEM. PUMP 90 BBL LCM AND 11.0 MUD THRU CHOKE. CONTINUE CIRC THRU CHOKE WHILW MIXING 15 PPB LCM. PUMPED A TOTAL OF 20000 STROKES. SHUT WELL IN. LOST 150 BBLS MUD DURING THIS CIRC. OPEN WELL. NOT FLOWING. CIRC THRU OPEN WELL. ROTATE AND RECIPROCATE DRILL PIPE. PUMP 16000 STROKES. LOST 250 BBLS WHILE CIRC. HAD TO CUT PUMP RATE TO 1 BPM AND MUD WT 10.6 PPG ONCE HEAVY FLUID REACHED SURFACE. PRESENTLY PUMPING 10.6 @ 1/2 BPM WITH 800- 900 PSI. TOTAL FLUID LOSS IS 400 BBLS. BUILT 300 BBLS MUD WHILE CIRC. 10/28/94 13,938' CIRC @ 1/2 BPM WITH 800 - 900 PSI. LOST 118 BBLS WHILE PUMPING 265 BBLS. MONITOR WELL- STATIC. LOST ALL RETURNS. WAIT ON ORDERS. SPOT 50 BBL - 15 PPB ON BOTTOM. PUMP OUT OF HOLE. PUMP OUT 7 STANDS AND MONITOR WELL. WELL STATIC. CONTINUE PUMPING OUT WITH ANNULUS STAYING FULL. PUMP OUT OF HOLE TO 1600' WELL STARTED FLOWING. SHUT WELL IN. NO SlOP OR SIDP. CIRC 10.6 MUD WT IN WITH 7.5 MUD WT OUT. 10/29/94 13,938' CIRC THRU CHOKE. MONITOR WELL AND PREPARE TO STRIP IN HOLE. STRIP IN WELL TO 8707'. ESTABLISH SIDP. CONTINUE STRIPPING IN RE£1::iVI:I.) MAR -2 1995 Ai~$ka U~I & Gas Cons. Comn!Jssi.o. rl AND LOST 110 BBLS. MONITOR WELL. PREPARE TO SPOT HEAVY PILL ON BO'I-I-OM. 10/30/94 13,938' MONITOR WELL. WAITING ON ORDERS. PUMP 2 BBLS EVERY 30 MINUTES WHILE WOKING PIPE. STRIP IN HOLE TO 13380' WITH 40 K DOWN WT. ABORTED EFFORT TO GET TO TD. A'I-FEMPT TO CIRC. POH TO 13200'. WORKED PIPE AND ESTABLISH PUMP RATE. INTIAL PUMP RATE WAS 3 BPM. PUMPED A TOTAL OF 130 BBLS OF 13.0 MUD WITH NO RETURNS. SINCE PIPE OFF AT 13200' CALCULATED KILL WT MUD NEEDED TO BE 14.0 PPG FROM 13200 - 8000'. SHUT WELL IN AND INCREASE MUD WT FROM 13.0 TO 14.0 PPG. SPOT 400 BBLS 14.0 PPG FOLLOWED BY 142 BBLS 10.1 PPG. INTIAL PUMP PRESSURE 7 BPM @ 1200 PSI, FINAL PUMP PRESSURE 1950 PSI. NO RETURNS. 10/31/94 13,938' STRIP OUT HOLE TO 8200'. PUMPED 25 STROKES PER STAND. BRING PUMP ON LINE WITH NO INCREASE IN CASING. PUMP 65 BBLS OF 15 PPB LCM PILL. FIRST 25-30 RETURNS WERE CRUDE OIL THEN STARTED GETTING SOME MUD RETURNS. CONTINUE PUMPING 10.1 PPG MUD WITH 8.8 RETURNS. AFTER PUMPING TWO SURFACE TO SURFACE VOLUMES WITH 10.1 MUD IN AND 9.12 OUT. MONITOR WELL AND INCREASE MUD WT TO 10.2 IN PITS. CIRC 10.2 MUD IN WITH 9.8 RETURNS @ 4 BPM WITH 500 PSI. NO MUD LOSSES. CIRC 10.4 MUD IN WITH 10.1 RETURNS @ 5 BPM WITH 750 PSI. NO MUD LOSSES. CHECK PRESSURES. OPEN HYDRIL AND MONITOR WELL. WELL STATIC. GAS BUBBLES BREAKING OUT @ FLOW LINE. CIRC. RECIPROCATE DP AND ROTATE @ 100 RPM. NO MUD LOSSES. 11/01/94 13,938' CIRC DOWN FLOWLINE. NO LOSSES. MONITOR WELL, STATIC. POH FILLING THRU DP EVERY STAND. MONITOR WELL AT SHOE. DOWNLOAD SOURCE AND LD BHA. CLEAR FLOOR AND FUNCTION RAMS. M/U MULE SHOE, INSIDE BOP, 1 JT DP, PLUG CATCHER, AND RIH TO SHOE. WEIGHT MUD TO 13.0 IN PITS. MONITOR ANNULUSE. CONTINUE RIH FILLING DP WITH 34 BBLS EVERY 3800'. 11/02/94 13,938' FINISH RIH TO 13938' WITH MULE SHOE. R/U HOWCO AND FINISH FILLING DP. PUMPED A TOTAL OF 2500 STROKES. TEST LINES. MIX AND PUMP 20 BBLS SPACER, 37 BBLS 17.0 PPG "G" CEMENT AND 2 BBLS WATER. DISPLACE W/RIG PUMPS. SLOWED RATE TO 4 BPM TO LATCH PLUG. PLUG DID NOT LATCH AFTER 2500 STROKES. PULLED 10 STANDS DRY. PUMPED 80 STROKES BEFORE PRESSURING UP DRILL PIPE. PUMPED RECEIVED MAR -2 I995 Oil .& Gas Cons. Cornmission 5 STANDS DOWN DP. PUMPED 56 BBLS. FOUND DP WIPER DART @ 6981' LODGED INSIDE A 2 7/8" TUBING PROTECTOR. MONITOR WELL, WAITING ON CEMENT. PUMPED 22 BBLS DOWN DP AND FILLED ANNULUS WITH 8 BBLS. POH FILLING DP EVERY 5 STANDS DOWN DP TO 4932'. WELL TRYING TO SWAB. PUMP OUT OF HOLE TO CASING SHOE. FINISH POH FILLING DOWN DP. PUMP AND ROTATE FROM 860' TO SURFACE. DP COATED WITH CEMENT. LOST 33 BBLS MUD. CLEAN RIG FLOOR AND SERVICE DP INSIDE BOP. NO MUD LOSSES. MU MULE SHOE, INSIDE BOP. 2 STANDS, PLUG CATCHER AND RIH. DRIFT EACH STAND GOING IN HOLE. 11/03/94 13,938' FINISH RIH W/MULE SHOE, INSIDE BOP AND PLUG CATCHER. DRIFT EACH STD. TAGGED CMT @ 13017'. FILL DP. RU HALLIBURTON. BATCH MIX CMT. TEST LINES. DISPLACED W/3 BBLS H20 AND 13 PPG MUD W/ RIG PUMP. POH SLOWLY W/10 STDS. SHEAR DART. PUMP 3 BBLS MUD. BLOW DOWN TOP DRIVE. POH TO 7300'. WOC. MONITOR WELL. WORK PIPE. SURFACE SAMPLES FIRM. RIH. TAGGED UP AT 11925'. 20K WT WHILE CIRC 1 - 2 BPM. POH SLOW. 11/04/94 13,938' POH W/10 STDS TO 9653'. MONITOR WELL. POH SLOWLY TO SHOE. FILL THROUGH DP AND ANNULUS. BREAK CIRC. PUMP 20 BBLS 10.4 MUD. MONITOR WELL. CONT TO CIRC. HAD FLOW INCREASE WHILE CIRC. SHUT DOWN. HAD SMALL FLOW. SHUT WELL IN. NO PRESSURE. CIRC THROUGH CHOKE 10.4 MUD WT IN AND OUT. CBU. MONITOR WELL. ANNULUS STATIC. HAD FLOW OUT DP. CONFIRM WELL IS U-TUBING. PUMP SMALL PILL. PU INSIDE BOP VALVE AT 27E. INSPECT AND TEST SAME. MONITOR WELL WHILE WAITING FOR WINDS TO SUBSIDE. POH W/ DP. STEM ON GRAY VALVE WAS BROKEN. INSTALL WEAR BUSHING. MU BHA. 11/05/94 13,938' PU BHA. RIH TO SHOE. CIRC AND CONDITION MUD. MONITOR WELL. CLEAR ICE PLUG IN CHOKE LINE. RIH TO 5011'. CIRC AND CONDITION ~u~. ~o~,-ro~ w~,,. o~. ~,~ To ~04~'. c,~c A~ CO~,~,O~ ~U~. MONITOR WELL, OK. RI" TO 6992'. ClRC AND CONDITION MUD. MONITOR WELL, OK. REDUCED PUMP RATE F/8 TO 4 BPM TO PREVENT MUD LOSS. INCREASED TO 8 BPM AFTER BOSOMS UP W/NO LOSS. MONITOR WELL, OK. RIH TO 7463'. ClRC AND CONDITION MUD UNTIL 10.4 IN AND OUT. ~O.~TO. w~.., o,. ,,~ TO ~001'. C,.C .~ CO.~T~O. ~U~. ~O.,TO. W..., O.. C~.C..~ .~.~ ./~001-~04', ~O ..O..~S. C~.C..~ CO.~T,O. ~U~. ~O.,TO. W..., O.. C~.C..~ ...~ ./~04-~9~', ~O ..O...~S C~.C..~ CO.~.T~O. ~U~. ~/06/94 ~3,938' REEEIV Cb A~s~ Oil & Gas Cons. Commission CIRC AND CONDITION MUD. MONITOR WELL, OK. REAM AND CIRC F/ 8976 - 9450'. CIRC AND CONDITION MUD. MONITOR WELL, OK. REAM AND CIR F/9450 - 9920'. CIRC AND CONDITION MUD. MONITOR WELL, OK. REAM AND CIRC F/9920 - 10393'. CIRC AND CONDITION MUD. MONITOR WELL, OK. REAM AND CIRC F/10393 - 10865'. CIRC AND CONDTION MUD. MONITOR WELL, OK. REAM AND CIRC F/10865 - 10334'. WORK THROUGH TIGHT SPOTS F/11225 - 11295'. CIRC AND CONDITION MUD. MONITOR WELL, OK. REAM F. 11428- 11523'. WORK THROUGH SHALE STRINGERS. CIRC AND CONDITION MUD. INCREASE PUMP RATE F/8 TO 11 BPM. NO MUD LOSS. REAM AND CIRC F/11523- 11618'. WORK THROUGH SHALE STRINGERS. PACKING OFF AROUND STABS. HOLE SEEMS TO BE IN GOOD CONDITION AFTER REAMING THROUGH TIGHT HOLE. CIRC AND CONDITION MUD. MONITOR WELL, OK. REAM AND FIR F/11618 0 11760'. WORK THROUGH SHALE STRINGERS. 11/07/94 13,938' CIRC AND REAM F/11760- 11772'. ACTS LIKE BIT IS UNDERGAUGE. PUMP SWEEPS AROUND. MONITOR WELL. POH W/10 STDS. LIGHT SWABBING. CIRC AND WORK PIPE. OK. POH TO SHOE. SLM. NO CORRECTION. HOLE TOOK PROPER FILL. NO TIGHT HOLE. MONITOR WELL WHILE CUT AND SLIP DRLG LINE. SERVICE TOP DRIVE. POH. GAUGE ON BIT AND STAB OK. CHANGE BIT. RIH TO 3656'. FILL DP. CBU. HANG DP ON RTTS W/STORM VALVE AT 68'. PULL WEAR BUSHING. INSTALL TEST PLUG. TEST BOPE. REPAIRED SEVERAL SMALL LEAKS. REAPIR AND TEST CHOKE LINE HCR TO 500 PSI. INSTALL WEAR BUSHING. 11/08/94 13,938' RETRIEVE STORM PKR. MONITOR WELL. STATIC. LD PKR. RIH. FILL DP EVERY 25 STDS. REAM LAST 3 STDS TO BOTTOM. NO HOLE PROBLEMS. REAM AND DRILL F/11772 - 11780'. DRLG W/25K WT AND 80 RPM. CIRC AND COND MUD. FLOW CHECK AND PUMP PILL. POH. HOLE TOOK PROPER FILL. NO PROBLEMS. LD BHA. CLEAR FLOOR. MU BHA. TEST MWD. RIH. FILL DP EVERY 25 STANDS. BENCHMARK SURVEY AT 4293'. 11/09/94 13,938' RIH TO 11399'. FILL PIPE EVERY 25 STANDS. CHECKSHOT AT 4293' AND 10286'. CIRC AND REAM F/11399- 11410'. PACKING OFF W/HIGH TORQUE AND DRAG. WORKED PIPE FREE. BAOKREAM TO 11112'. PIPE PULLING FREE AT 11019'. CIRC AND REAM TO 11210'. ClRC AND CONDITION MUD. PUMP OUT OF HOLE TO 10644'. PUMP PILL. BLOW DOWN TOP DRIVE AND LINES. POH, NO PROBLEMS. SERVICE WEAR BUSHING. RIH W/MULE SHOE, 7 STDS DP AND PLUG CATCHER~ [ C [ I~ ~ ~ 11/10/94 13,038' ~a~.~a, Oit & Gas Cons. Commission -" Anchor~ ' RIH TO 11169'. WASH AND REAM TO BOTTOM @ 11780'. CIRC AND CONDITION MUD. MIX 17 PPG PILL. SPOT PILL F/11780 - 11600'. POH TO 10700'. CBU WHILE RECIPROCATE AND ROTATE PIPE. WASH TO 10980'. CBU. RU CEMENT HEAD. TEST LINES. BATCH MIX CEMENT. PUMP 20 BBLS 11.4 SPACER, 39 BBLS CEMENT AND 7 BBLS SPACER. DISPLACED W/RIG PUMPS. SHEARED PLUG CATCHER AT 3200 PSI. POH W/20 STDS. CIRC AT 12 BPM. 11/11/94 13,938' MONITOR WELL. WOC. RIH. FILL PIPE EVERY 25 STDS. WASH F/10300 TO 10580'. TAG GREEN CEMENT AT 10480'. CBU. TREAT MUD FOR CEMENT CONTAMINATION. WASH F/10580- 10600'. DRILL CEMENT TO 10638'. STACK 30K ON BIT W/10 BPM RATE W/NO PUMP OFF. CIRC AND CONDITION MUD. INCREASE RATE TO 550 GPM. NO LOSS. FLOW CHECK. PUMP PILL. POH W/15 STDS. WELL NOT TAKING CORRECT DISPLACEMENT. FLOW CHECK, OK. RIH W/6 STDS. SMALL FLOW. SHUT WELL IN. MONITOR WELL. OPEN WELL, NO FLOW. RIH TO TD. CIRC AND CONDITION MUD. NO GAS OR OIL IN MUD. BLOW DOWN PUMPS AND TOP DRIVE. POH. SLM. HOLE TOOK PROPER FILL. NO TIGHT HOLE. SERVICE WEAR BUSHING. REPAIR HOSE TOP DRIVE. RIH W/BHA. TEST MWD. BENCHMARK SURVEY AT 4292'. CONT'D RIH. 11/12/94 11,162' RIH. FILL PIPE EVERY 25 STDS. REAM LAST STD TO 10638'. HAD BRIDGE AT 10549'. CIRC AND CONDITION MUD. SLIDE F/10638 - 10690' W/BIT AT 90 DEGREE. ROTATE TO 10737'. HOLE PACKING OFF. POH W. 1 STD. WORK PIPE AND CIR UNTIL HAVE FULL RETURNS. CIRC AND CONDITION MUD UNTIL HOLE IS CLEAN. CONFIRM WELL IS SIDE TRACKED. DRLG AND MWD SURVEY F/ 10690 - 11162'. 11/13/94 12,058' DRLG AND MWD SURVEY F/11162- 11493'. PUMP LO/HI VIS SWEEPS. CBU. SHORT TRIP TO 10600'. NO HOLE PROBLEMS. DRLG AND MWD SURVEY F/11162- 11493'. PUMP LO/HI VIS SWEEPS. CBU. MONITOR WELL. PUMP PILL. POH. NO HOLE PROBLEMS. 11/14/94 12,368' POH. MONITOR WELL AT SHOE AND AT HWDP. SERVICE WEAR BUSHING. RIH W. ATJ-P05D BIT, BHA AND HWDP. TEST MWD. CUT AND SLIP DRLG LINE. CHANGE OUT SAVER SUB ON TOP DRIVE. POH AND CHANGE BITS. RIH . FILL PIPE EVERY 25 STDS. BENCHMARK SURVEY AT 4293'. CIRC AND CONDTION MUD. REAM LAST STD TO BOTTOM. NO PROBLEMS. DRLG AND MWD SURVEY F/12058- 12368'. P~F_.L F..IV 11/15/94 12,766' DRLG AND MWD SURVEY F/12368 - 12640'. SHORT TRIP TO 11900'. TIGHT AT 12220'. WIPE THROUGH OK. RIH, NO PROBLEMS. DRLG AND MWD SURVEY F/ 12640 - 12766'. 11/16/94 12,766' CIRC HI/LO VIS SWEEPS AROUND. MONITOR WELL. PUMP PILL. BLOW DOWN LINES. POH. MONITOR WELL AT SHOE. NO HOLE PROBLEMS. PULL WEAR BUSHING. INSTALL TEST PLUG. TEST ALL BOPE EQUIPMENT W/ANNULAR. CHOKE LINE HCR LEAKED. PULL TEST PLUG. MONITOR WELL. REMOVE AND REPLACE HCR VALVE. INSTALL TEST PLUG. TEST. SERVICE TOP DRIVE. PULL TEST PLUG. INSTALL WEAR BUSHING. BLOW DOWN LINES. CHANGE OUT MUD MOTORS. ORIENT MWD. RIH. FILL PIPE EVERY 25 STDS. BENCHMARK SURVEY @ 4292'. 11/17/94 13,298' RIH TO 13629'. FILL PIPE EVERY 25 STANDS. REAM F/12629 - 12766' BTM. DRLD, LOG AND SURV F/12766 - 12792'. MONITOR WELL DUE TO HIGH FLOW AFTER BTTMS UP. CBU (PRECAUTIONARY). DRLD, LOG AND SURV F/12792- 13194'. WHILE CIRC HI-VIS SWEEP AROUND. 10 STD SHORT TRIP F/13194- 12260', NO PROBLEMS, REAM LAST STD TO BTM, D-1 DRILL, SECURED WELL, ALL HANDS IN PLACE. DRLD, LOG AND SURV F/ 13194 - 13298'. 11/18/94 13748' DRLD, LOG AND SURV F/13298 - 13572'. 6 STD SHORT TRIP, REAM LAST STD TO BTM, NO PROBLEMS. DRLD, LOG ANDSURV F/13572- 13744'. CIRC HOLE CLEAN W/LOW VIS SWEEP. SLUG PIPE, 34 STD SHORT TRIP TO 10600', NO PROBLEMS. DRLD, LOG AND SURV F/13744- 13748'. 11/19/94 13,755' FINISH 34 STAND SHORT TRIP. NO PROBLEMS. DRLD, LOG AND SURV F/ 13744-13755'. ClRC HOLE CLEAN, SPOT 100 BBL THERMA THIN PILL ON BTM. MONITOR WELL, NO L/G SLUG PIPE. POH RAC BACK 37 STDS 5" DP, LD REST TO 7800'. SPOT 55 BBLS OF BARAFIBRE/BARAOARB LOM F/7800 -6600', OK, SLUG PIPE. POH. L/D 5" DP. LD BHA #9, CLEAR FLOOR. PULL WEAR RING, C/O TOP RAMS TO 7", TEST BONNET SEALS. RU CSG EQUIP. RUN 7" FLOAT EQUIPMENT BETWEEN JTS, PUMP THROUGH SAME, OK. RIH W/7" 26# NSOC. CBU AT 9 5/8" CSG SHOE, 3 BBL LOSS. RUNNING 7" CSG, RAN TOTAL OF 107 JTS AT PRESENT. 11/20/94 13,755' R~C~I~ELb ¢,~s_~- iji[ .& Gas Cons. Commission '--' :, Anchor~ FINISH RUNNING 7" 26# L-80 NSCC W/ES CMTR, TOTAL OF 333 JTS, MU AND LANDED 7 5/8" FMC FLUTED HGR W/LANDING JT. FS @ 13739, FC @ 13694', LC @ 13652' AND ES CMTR @ 7896'. FLUID LOST WHILE RUNNING CSG 78 BBLS. CIRC 287 BBLS, LOSS 59 BBLS THEN GAIN 28 BBLS. RU HALLIBURTON CMT LINES. RU CMT HD. PUMP 5 BBL FW, TEST LINES. DROP BTM PLUG WHILE PUMP 15 BBLS FW, 70 BBLS ALPHA SPACER. DROP TOP PLUG, PUMP 40 BBLS PREMIUM 'G' CMT W/ADD'T @ 6 - 5 BPM. BUMP PLUG @ 3 BPM 2000 PSI, CK FLOAT EQUIP, NOT HOLDING AND WELL FLOWING ON ANNULUS. SHUT IN WELL ANNULUS PRESSURE. PRESSURED UP DN CSG TO 1000 PSI. SHUT IN WELL. MONITOR WELL. WAITING ON CMT, ANNULUS PRESSURE INCREASED F/100 - 160 PSI AFTER APPLYING 1000 PSI DN 7" CSG. 11/21/94 13,755' BLED CSG F/1200 - 0 PSI W/3 BBLS RETURNED, ANNULUS F/80 - 0 PSI NO RETURNS, OPEN WELL, MONITOR, NO FLOW. WELL STABLE. LOAD CLOSING PLUG. PRESSURED UP ON 7" CSG, SHEARED ES CMTR OPEN, CBU TWICE, SHUT DN OBSERVED, NO FLOW. LOSS 34 BBLS. PREFORMED STAGE II CMT JOB, TEST LINES. DROP PLUG, BUMP PLUG. CLOSED ES CMTR. RELEASED PRESSURE, NO FLOW, LOSS 40 BBLS. RD CMT AND CSG EQUIPMENT, LANDING JT. FLUSH STACK W/WATER, SET AND TEST PACKOFF. C/O TOP RAMS TO 3 1/2", TEST RAMS, SET WEAR RING. CHANGE TOP DRIVE TO 3 1/2". CUT AND SLIP 100' OF DRILL LINE. SERVICE TOP DRIVE AND DRAWWORKS. PU BHA #10, RIH PU AND DRIFTING 3 1/2" DP. SHALLOW TEST MWD. REPAIR LINK ADAPTER SUPPORT PLATE ON TOP DRIVE. CONTINUE RIH PU AND DRIFTING 3 1/2" DP AT 5000'. 11/22/94 13,755' RIH, PU AND DRIFT 3 1/2" TAG AT 7885'. CBU. DRILL OUT CMT AND ES CEMENTER F/7885 - 7900'. CBU'S. WASH AND REAM CMT F/7950 - 8250'. RIH F/8250 - 8400'. CBU. TEST CSG, OK. RIH, PU AND DRIFT 3 1/2" DP, TAG AT 13648'. C & C, WEIGHT UP F/10.4 PPG TO 11.2 PPG. TEST CSG, OK. BLOW DN CHOKE MANIFOLD AND TOP DRIVE. POH 13 STANDS OF 3 1/2" DP, RACK BACK IN DERRICK, PU, RIH W/3 1/2" DP TAG @ 13648'. CHANGE BAILS. DRILL OUT CMT AND FLOAT EQUIPMENT F/13748 - 13682', ADDING 2#/BBL OF E P MUD LUBE DUE TO HIGH TORQUE OF 650 - 700 AMPS. 11/23/94 14,050' DRLD FLOAT EQUIP AND 10' OF NEW HOLE TO 13772'. C AND C MUD W/ WT IN/OUT AT 11.2 PPG, PREFORM F,I.T. DRLD, LOG AND SURV F/13772- 14050'. HOLE STABLE. 11/24/94 14,085' DRILL F/14050- 14085'. PUMP LO-HI VIS SWEEPS. MONITOR WELL. WELL FLOWING. GAS BREKING OUT ABOVE ROTARY TABLE. SHUT WELL IN. ZERO PRESSURES ON DP AND CASING. CIRC THRU CHOKE AND INCREASE MUD WT TO 11.4 PPG. OPEN WELL. WELL FLOWING. SHUT IN. INCREASE MUD WT TO 11.6 AND CIRC THRU CHOKE. OPEN WELL - STATIC. CIRC BOTTOMS UP THRU FLOW LINE WITH 11.6 PPG. SHORT TRIP TO CASING SHOE. CIRC BOTTOMS UP AFTER MAKING SHORT TRIP. MUD CUT TO 10.7 PPG ON BOTTOM UP. INCREASES MUD TO 11.8 PPG FOR TRIP MARGIN AND CIRC AROUND. POH FOR NEW BIT. L/D MOTOR. PULL WEAR RING AND INSTALL TEST PLUG. 11/25/94 14,085' MONITOR WELL. GAS AND OIL BREAKING OUT @ SURFACE. INSTALL WEAR RING. M/U NEW BIT, BHA #11 AND FLOW CHECK MOTOR. RIH. MONITORING RETURNS TO TRIP TANK. HIT BRIDGE @ 13975'. WORK PIPE. TRYING TO PACK OFF AND TORQUED UP. POH TO CASING SHOE. CIRC AND INCREASE MUD WT TO 12.0 PPG. OIL AND GAS CUT MUD TO SURFACE AT B/U. WASH AND REAM F/13379 - 14085'. CIRC BOTTOMS UP WITH 12.2 PPG. MONIOTR WELL- STATIC. POH TO CASING SHOE. MONITOR WELL- STATIC. MONITOR WELL- STATIC. CIRC BOTTOM UP. MONITOR WELL. WELL STATIC. POH 45 STANDS TO 10044'. M/U STORM PACKER AND TEST SAME. PULL WEAR RING AND SET TEST PLUG. TEST BOPE. HYDRIL WOULD NOT TEST. PULL TEST JT AND CHANGE OUT HYDRIL RUBBER. 11/26/94 14,465' CHANGE OUT HYDRIL RUBBER. INSTALL TEST JT AND TEST ANNULAR. NU FLOWLINE AND RISER. INSTALL WEAR RING. UNSEAT STORM PACKER AND LD SAME. MONITOR WELL - STATIC. RIH TO 13821'. WASH AND REAMM F/13821 - 14085'. CIRC BOTTOMS UP. DRILL 8 1/2" HOLE F/ 14085 - 14465'. 11/27/94 14,570' DRILL 6" HOLE F/14465 - 14570'. CIRC BOTTOMS UP. SHORT TRIP TO CASING SHOE. WORK THRU TIGHT SPOT @ 14028'. CIRC BO'I-I-OMS UP. DROP RABBIT AND POH TO RUN LINER. SLIP AND CUT DRILL LINE. ADJUST BRAKES. FINISH POH. LD BHA. RU CASING EQUIPMENT. MU 22 JTS 5" LINER, SHORT JT, AND BAKER HYDRAULIC SET HANGER WITH ISOLATION PACKER. CIRC VOLUME OF LINER. RIH WITH LINER HANGER ON 3 1/2" DP. 11/28/94 14,570' FINISH RUNNING LINER. TAG BOTTOM @ 14570'. CIRC AND COND MUD. NO MUD LOSSES. BATCH MIX CEMENT WHILE CIRC. RECIPROCATED LINER WHILE CIRC. TEST HOWCO LINES. RELEASE FROM LINER HANGER RECEIVED MAR -" 2. 1995 0il & Gas Cons. Comml.q.~inn AND PULL ONE STAND. RU TO REVERSE OUT. RING GASKET ON KILL LINE LEAKING. POH. LD RUNNING TOOL. MU 6" BIT, SCRAPER, 3 - 4 3/4" DC, 27- 4 1/2" HWDP. 11/29/94 14,570' SERVICE TOP DRIVE AND CHANGE OUT IBOP ACTUATOR. FINISH RIH WITH 6" BIT. HIT CEMENT STRINGER @ 12983'. WASH DOWN F/12983- 13347'. WASH AND REAM F/13347 - 13582'. TOL MEDIUM TO SOFT CEMENT. CIRC OUT CONTAMINATED CEMENT. POH. LD 24 JTS HWDP AND 3 JTS DP. MU 4 1/4" MILL. 24 - 3 1/16" DC, AND 8 JTS 2 7/8" DP. RIH WITH SAME. 11/30/94 14,570' FINISH RIH. TAG LANDING COLLAR @ 14435'. CIRC AND COND MUD. TEST LINER. NO PRESSURE LOSS. DRILL L/C AND HARD CEMENT TO TOP OF FLOAT COLLAR @ 14520'. RETEST LINER. NO LOSSES. CIRC AND DISPLACE WELL WITH 500 BBLS SOURCE WATER, FOLLOWED BY 30 BBLS HI-VIS SWEEP, 50 BBLS DIRT MAGNET, 30 HI-VIS SWEEP. THEN DISPLACED WELL WITH 12.0 BRINE. FILTERED TWO CIRCULATIONS TO A VALUE OF 4 NTU. ADDED CORREXIT 7726 ON LAST CIRC. POH. CUT AND SLIP DRILL LINE. FINISH POH. LD CLEAN OUT ASSEMBLY. 12/01/94 14,570' LD BHA. CLEAR FLOOR. SERVICE WEAR BUSHING. MU TCP BHA AS PER PLAN. MU AND RIH W/2 7/8" TBG. MU CHAMP PKR ASSY AND 4 3/4" DC'S. RIH ON 3 1/2" DP. RA SUB @ 12884' AND GUN BULL PLUG @ 14200'. RU ATLAS. CORRULATE DP MEASUREMENT W/ANADRIL AND SPERRY SUN MUD LOGS. 2' CORRECTION. RIH AND TAG FLOAT COLLAR TO VERIFY CORRALATION. OK. POH, SET PKR W/GUNS ON DEPTH AS PER PLAN. RU HALLIBURTON MANIFOLD AND BJ. TEST EQUIPMENT. 12/02/94 14,570' DISPLACE DP W/N2 TO PORTED SUB AT 13101'. CLOSE BYPASS ON PKR. REPLACE LEAKING CHIOKSAN. RETEST. PRESSURE DROPPED. MONITOR WELL, RU ATLAS WL, TEST LUBRICATOR, RIH W/PRESSURE TOOL, UNABLE TO WORK TOOL BELOW 4900'. POH. WAIT ON TOOLS FROM PRUDHOE, MU ADDITIONAL SINKER BARS W/ROLLERS. TEST LUBRICATOR, RIH W/PRESSURE TOOLS. UNABLE TO WORK TOOLS BELOW 12032', CHECK PRESS AT 11732' AND 9404'. POH. CHECK PRESS AT SURFACE, RD ATLAS, OPEN BY PASS ON PKR. BULL HEAD 17 BBLS 12 PPG BRINE DOWN ANNULUS. ANNULUS PRESSURE AT 1000 PSI. HOLD ANNULUS PRESSURE AND REVERSE AT N2 F/DP. SHUT WELL IN AFTER BRINE REACHED SURFACE, MONITOR WELL AND ALLOW N2 IN DP TO MIGRATE TO SURFACE. P~ E £ E IV E D ~j~.s[~a. Oil .& Gas Cons. Commission Anchor~ 12/03/94 14,570' REVERSE CIRC THROUGH CHOKE THROUGH PORTED SUB AT 13100'. MONITOR WELL. N2 IS MIGRATING. REVERSE CIRC THROUGH CHOKE W/ NO FLUID LOSS. MONITOR WELL. CIRC CONVENTIONAL THROUGH CHOKE. NO FLUID LOSS. RELEASE PKR. LD PUP JT. MONITOR WELL FOR ADDITIONAL N2 MIGRATION. WELL IS STATIC. POH W/86 STDS DP. CUT AND SLIP 385' DRLG LINE. ADJUST KICK BACK ROLLERS. POH W/53 STDS DP TO DC'S. N2 BREAKING OUT AT SURFACE W/FLOW. SHUT WELL. CIRC THORUGH CHOKE W/75 PSI BACK PRESS TO REMOVE N2. SUSPECK N2 BREAKING OUT OF PERF GUNS. WELL IS STATIC. POH LD DC'S, PKR, 2 7/8" TBG AND TCP GUNS. ALL SHOT FIRED. RIH W/25 STDS 3 1/2" DP. 12/04/94 14,570' FINISH RIH W/DP TO 2300'. CBU. HAD SMALL AMOUNT OF N2 IN RETURNS. WELL IS STATIC. RU ATLAS. RUN 1 11/16" GR/CCL F/14520 - 11750'. CCL NOT PICKING UP 7" CSG COLLARS VERY WELL. POH AND CHANGE TOOLS. RIH AND RELOG LINER LAP TO CONFIRM 7" COLLAR ABOVE LAP. POH AND RD ATLAS. POH W/DP. RIH W/7" BAKER FB-1 PKR ON 3 1/2" DP TO 13500'. BREAK CIRC. TAG TOL @ 13582'. SPOT PKR 25' ABOVE TOL @ 13554'. BOTTOM OF PKR AT 13557'. DROP BALL. PUMP SAME DOWN TO SETTING TOOL. PRESSURE DP TO 1500 PSI. PULL 20K OVER STRING WT TO SET AND RELEASE FROM PKR. CIRC HOLE VOLUME. SMALL AMOUNT OF N2 AT BOTTOMS UP. POH W/DP. 12/05/94 14,570' FINISH POH LD DP AND SETTING TOOL. MU BAKER 7" WL RETRIEVALBE BRIDGE PLUG AND RIH TO 4493'. DROP BALL AND PUMP SAME DOWN. PRESSURE DP TO 3300 PSI TO SET AND RELEASE FROM PLUG. PLUG SET AT 4490'. TEST RBP TO 2500 PSI. BLED PRESSURE OFF DP. PRESS WOULD NOT BLEED OFF ANNULUS. HAVE RESTRICTION IN SETTING TOOL. POH W/SETTING TOOL. RETEST RBP, OK. RIH W/DP TO 4400'. POH AND LD DP TO 2500'. DISPLACE WELL AT 2500' W/HEATED DIESEL. MONITOR WELL- STATIC. POH LD 3 1/2" DP. STEAM EACH JT IN MOUSE HOLE TO REMOVE DIESEL. BLOW DOWN ALL PUMP LINES. TOP PIPE RAM NOT FULLY RETRACTED. OPEN RAM DOOR. RAM BACK BOLTS ARE STRIPPED OUT. CHANGE RAMS TO 5". PULL WEAR BUSHING. INSTALL FALSE BOWL AND BPV. ND BOPE. 12/06/94 14,570' ND AND SET BACK BOP. NU HOLD DOWN FLANGE, 2 - 7 1/16" FMC VALVES AND TREE CAP. TEST FALSE BOWL AND HOLD DOWN FLANGE. PULL BPV. FILL TREE W/DIESEL AND TEST TREE AGAINST CSG. BLEED PRESSURE. INSTALL BPV. SECURE WELL. CHANGE TOP DRIVE TO 5". N I::LI::I V Gas Cnns Cnmmission gy Idata B.P. EXPLORATION (Alaska)Inc. Miine Point MPE-09 North Slope Alaska Nabors 22-E Gyro Multishot of 4 1/2 Inch Drillpipe Survey date: 17. October, 1994 Job number: AK1094G239 Anchor: SR239.DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 October 21, 1994 Ms. Marian Sloan B.P. Exploration Prudhoe Bay Drilling Department 900 E. Benson Blvd. Anchorage, Ak 99508 Re.' Dear Ms. Sloan, Milne Point MPE-09 North Slope Alska, Nabors Rig 22-E Enclosed please find one (1) original and six copies (9) of the completed survey of Well 09 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. .. Sincerely Assistant Operations Manager RJS/gr Serving the Worldwide Energy Industry with Precision Survey Instrumentation CONTENTS JOB NUMBER: AK1094G239 . DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR239.DOC gyro/data 1. DISCUSSION , SURVEY CERTIFICATION SHEET SR239.DOC gyro/data DISCUSSION JOB NUMBER: AK1094G239 Tool 53 was run in well Milne Point MPE-09 on a Atlas 15/32" Wireline in the 4 1/2 inch drillpipe to a depth of 4880. The wireline rezero on return to surface 00006. SR239.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER · AK1094G239 The data for this survey and the calculations for this survey were obtained and performed by me according to the standards and procedures as set forth by Gyrodata, Inc., and are true and correct to the be.st of my knowledge. ROB SHOUP OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. ~ This report represents a true an_.d correct directional survey of this well based on the original data obtained at the wellsite. Checked by :- ERNIE SURMAN OPERATIONS ENGINEER SR239.DOC gyro/data 2. SURVEY DETAILS SR239.DOC gyro/data' SURVEY DETAILS JOB NUMBER: AK1094G239 CLIENT: B.P. EXPLORATION (ALASKA)INC. RIG: NABORS 22-E LOCATION: NORTH SLOPE ALASKA WELL: MILNE POINT MPE-09 LATITUDE: 70.454806 N LONGITUDE: 149.43598W SURVEY DATE: 17-OCT-1994 SURVEY TYPE : DRILLPIPE SURVEY OF 9 5/8" CASING DEPTH REFERENCE: MAX. SURVEY DEPTH: SURVEY TIED ONTO: NABORS R.K.B. 4880 SURFACE SURVEY INTERVAL: 100 ft OUTRUN TARGET DIRECTION: 116.02 GRID CORRECTION: o CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD/SHOUP SR239.DOC gyro/data 3. OUTRUN SURVEY LISTING SR239.DOC A Gyrodat a Di re c t i ona i Survey for B.P. EXPLORATION WELL: MPE-09, 4.5" DRILLPIPE Location: MILNE POINT, MILNE POINT FIELD 'Job Number: AK1094G239 Run Date: 17-0ct-94 01:15: Surveyor: TOM STODDARD/ROB 'SMOUP Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.454806 deg. N Sub-sea Correction from Vertical Reference: 54 ft. Bearings are Relative to True North Proposed Well Direction: 116.020 deg Vertical Section Calculated from Well Mead Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i r e c t i ona I Survey B.P. EXPLORATION WELL: MPE-09, 4.5" DRILLPIPE Location: MILNE POINT, MILNE POINT FIELD Job Number: AK1094G239 Page MEASURED I N C L AZIMUTH DOGLEG VERTICAL DEPTH SEVERITY DEPTH feet deg. deg. deg./ feet 100 ft. SUBSEA VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. H O R I Z O N T A L COORDINATES feet 0.0 0.00 0.00 0.00 0.0 -54.0 0.0 0.0 0.0 0.00 N 0.00 E 0 - 4880 FT. GYRO SURVEY RUN IN 4 1/2" DRILLPIPE MEASURED DEPTHS REFERENCED TO NABORS RIG 22-E R..K.B. THE R.K.B. IS 54 FT. ABOVE SEA LEVEL 100.0 .10 102.64 .10 100.0 46.0 200.0 .11 21.55 .14 200.0 146.0 300.0 .12 133.19 .19 300.0 246.0 400.0 .24 67.23 .22 400.0 346.0 500.0 1.12 91.55 .90 500.0 446.0 .1 .2 .3 .5 1.5 .1 102.6 .2 77.0 .3 78.0 .6 82.2 1.8 85.5 .02 S .09 E .05 N .21 E .07 N .32 E .08 N .59 E .14 N 1.76 E 600.0 2,78 94.63 1.66 599.9 545.9 700.0 4.23 100.34 1.49 699.7 645.7 800.0 5.48 104.64 1.30 799.4 745.4 900.0 7.29 107.12 1.83 898.8 844.8 1000.0 8.84 107.27 1.55 997.8 943.8 4.7 10.5 18.7 29.7 43.5 5.2 90.9 11.2 94.8 19.6 98.2 30.7 101.1 44.7 103.0 .08 S 5.15 E .94 S 11.20 E 2.81 S 19.44 E 5.89 S 30.12 E 10.03 S 43.52 E 1100.0 10.55 108.17 1.72 1096.3 1042.3 1200.0 13.27 107.14 2.73 1194.2 1140.2 1300.0 15.91 106.67 2.64 1290.9 1236.9 1400.0 17.90 105.03 2.04 1386.6 1332.6 1500.0 20.36 103.90 2.49 1481.1 1427.1 60.2 80.6 105.4 134.1 166.2 61.5 104.3 82.1 105.1 107.2 105.5 136.3 105.6 169.1 105.4 15.17 S 59.56 E 21.41 S 79.22 E - 28.72 S 103.32 E 36.64 S 131.29 E 44.80 S 163.03 E 1600.0 24.03 103.65 3.67 1573.7 1519.7 1700.0 26.78 101.98 2.84 1664.0 1610.0 1800.0 27.95 100.65 1.32 1752.8 1698.8 1900.0 30.33 100.92 2.38 1840.1 1786.1 2000.0 33.11 100.79 2.78 1925.2 1871.2 203.1 244.8 289.3 336.3 387.0 206.8 105.1 249.7 104.7 295.6 104.2 344.2 103.7 396.7 103.3 53.79 S 199.72 E 63.27 S 241.55 E 72.28 S 286.62 E 81.39 S 334.46 E 91.29 S 386.09 E A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MPE-09, 4.5" DRILLPIPE Location: MILNE POINT, MILNE POINT FIELD Job Number: AK1094G239 Page MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL CLOSURE DEPTH DEPTH SECTION DIST. AZIMUTH feet feet feet feet deg. HORIZONTAL COORDINATES feet 2100.0 36.07 100.96 2.95 2200.0 38.31 99.24 2.48 2300.0 40.02 101.62 2.28 2400.0 41.89 101.17 1.89 2500.0 43.57 102.07 1.79 2007.5 2087.2 2164.7 2240.2 2313.7 1953.5 2033.2 2110.7 2~.86.2 2259.7 441.8 499.9 560.7 624.2 689.9 453.5 103.0 513.8 102.7 576.9 102.4 642.5 102.3 710.3 102.2 102.00 S 441.84 E 112.57 S 501.34 E 124.03 S 563.44 E 136.97 S 627.69 E 150.64 S 694.15 E 2600.0 45.14 101.54 1.61 2700.0 47.34 101.60 2.20 2800.0 50.50 101.13 3.].8 2900.0 52.75 103.71 3.02 3000.0 55.29 102.99 2.61 2385.2 2454.3 2520.0 2582.1 2640.9 2331.2 757.6 780.2 102.2 2400.3 827.6 852.4 102.2 2466.0 900.5 927.8 102.1 2528.1 976.7 1006.2 102.1 2586.9 1055.6 1087.1 102.2 164.94 S 762.58 E 179.42 S 833.33 E 194.26 S 907.22 E 211.14 S 983.76 E 229.81 S 1062.49 E 3100.0 57.68 105.01 2.92 3200.0 59.14 108.19 3.08 3300.0 61.06 110.38 2.70 3400.0 63.60 110.71 2.56 3500.0 64.24 112.35 1.61 2696.1 2748.5 2798.3 2844.7 2888.7 2642.1 1137.1 1170.4 102.3 2694.5 1221.2 1255.3 102.6 2744.3 1307.3 1341.5 103.1 2790.7 1395.4 1429.3 103.5 2834.7 1484.9 1518.3 104.0 250.00 S 1143.37 E 274.35 S 1224.98 E 302.99 S 1306.79 E 334.07 S 1389.71 E 367.04 S 1473.26 E 3600.0 64.43 113.89 1.40 3700.0 65.25 113.47 .91 3800.0 66.11 115.50 2.04 3840.0 65.75 116.01 1.48 3870.0 66.18 116.07 1.46 2932.0 2974.5 3015.7 3032.0 3044.2 2878.0 2920.5 2961.7 2978.0 2990.2 1575.0 1665.4 1756.5 1793.0 1820.4 1607.3 104.5 1696.8 105.0 1786.7 105.5 1822.6 105.7 1849.6 105.8 402.43 S 1556.15 E 438.78 S 1639.04 E 476.56 S 1721.96 5 492.43 S 1754.85 E 504.46 S 1779.47 E 3900.0 66.48 116.46 1.55 3930.0 66.89 116.67 1.52 3960.0 67.25 116.71 1.18 3990.0 67.86 117.36 2.88 4020.0 67.98 117.21 .60 3056.3 3068.2 3079.9 3091.3 3102.6 3002.3 1847.9 1876.6 106.0 3014.2 1875.4 1903.7 106.1 3025.9 1903.1 1930.9 106.3 3037.3 1930.8 1958.1 106.4 3048.6 1958.6 1985.4 106.6 516 · 62 S 528.94 S 541.35 S 553.95 S 566.69 S 1804.11 E 1828.75 E 1853.44 E 1878.14 E 1902.84 E A Gyrodata Dire c t i o n a 1 Survey B.P. EXPLORATION WELL: MPE-09, 4.5" DRILLPIPE Location: MILNE POINT, MILNE POINT FIELD Job Number: AK1094G239 Page MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL CLOSURE DEPTH DEPTH SECTION DIST. AZIMUTH feet feet feet feet deg. HORIZONTAL COORDINATES feet 4050.0 67.59 117.00 1.44 4080.0 66.43 116.86 3.87 4110.0 66.20 116.93 .82 4140.0 66.43 116.44 1.66 4170.0 65.96 116.57 1.61 3113.9 3125.6 3137.7 3149.8 3161.9 3059 3071 3083 30''95 3107 .9 1986.3 2012.7 106.7 .6 2014.0 2039.9 106.9 .7 2041.4 2067.0 107.0 .8 2068.9 2094.1 107.1 .9 2096.3 2121.2 107.2 579.35 S 1927.56 E 591.86 S 1952.19 E 604.28 S 1976.69 E 616.62 S 2001.23 E 628.87 S 2025.79 E 4200.0 65.96 117.00 1.31 4230.0 65.73 117.29 1.17 4260.0 65.49 117.42 .91 4290.0 65.23 117.50 .87 4320.0 64.99 117.56 .82 3174.1 3186.4 3198.8 32il.3 3223.9 3120 3132 3144 3157 3169 .1 2123.7 2148.2 107.4 .4 2151.1 2175.2 107.5 .8 2178.4 2202.1 107.6 .3 2205.7 2229.0 107.7 .9 2232.9 2255.8 107.8 641.22 S 2050.25 E 653.70 S 2074.61 E 666.26 S 2098.88 E 678.83 S 2123.07 E 691.41 S 2147.21 E 4350.0 64.84 117.46 .61 4380.0 64.99 117.58 .64 4410.0 64.77 117.81 1.00 4440.0 65.80 118.05 3.52 4470.0 66.17 118.49 1.80 3236.6 3249.3 3262.1 3274.6 3286.8 3182 3195 3208 3220 3232 .6 .3 .1 .6 .8 2260.0 2287.2 2314.4 2341.6 2369.0 2282.6 108.0 2309.4 108.1 2336.2 108.2 2363.0 108.3 2390.0 108.4 703.96 S 716.51 S 729.14 S 741.90 S 754.88 S 2171.31 E 2195.40 E 2219.45 E 2243.53 E 2267.67 E 4500.0 65.95 119.03 1.82 4530.0 65.72 119.26 1.02 4560.0 65.66 119.53 .87 4590.0 65.62 119.76 .69 4620.0 65.71 119.54 .74 3299.0 3311.3 3323.6 3336.0 3348.3 3245 3257 3269 3282 3294 .0 .3 .6 .0 .3 2396.4 2417.0 108.5 2423.7 2443.9 108.6 2451.0 2470.8 108.8 2478.3 2497.6 108.9 2505.5 2524.5 109.0 768.07 S 781.40 S 794.82 S 808.34 S 821.86 S 2291.70 E 2315.61 E 2339.43 E 2363.18 E 2386.94 E 4650.0 66.87 119.33 3.93 4680.0 67.12 119.24 .86 4710.0 66.89 118.98 1.12 4740.0 66.91 118.56 1.31 4770.0 66.46 118.30 1.69 3360.4 3372.1 3383.9 3395.6 3407.5 3306 3318 3329 3341 3353 .4 2533.0 2551.5 109.1 .1 2560.5 2578.7 109.2 .9 2588.1 2605.9 109.3 .6 2615.7 2633.1 109.4 .5 2643.2 2660.3 109.5 835.36 S 848.87 S 862.30 S 875.58 S 888.70 S 2410.86 E 2434.95 E 2459.07 E 2483.26 E 2507.49 E A G y r o d a t a D i r e c t i o n a i S u r v e y B.P. EXPLORATION WELL: MPE-09, 4.5" DRILLPIPE Location: MILNE POINT, MILNE POINT FIELD Job Number: AK1094G239 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. 4800.0 66.32 118.02 4830.0 66.05 117.80 4860.0 66.03 117.80 4880.0 66.03 117.96 Final Station Closure: .98 3419.5 3365.5 1.12 3431.6 3377.6 .07 3443.8 3389.8 .77 3451.9 33.97.9 Distance: 2759.90 ft 2670.7 2687.5 109.6 2698.1 2714.7 109.7 2725.5 2741.8 109.8 2743.8 2759.9 109.8 Az: 109.82 deg. Page 4 HORIZONTAL COORDINATES feet 901.67 S 2531.73 E 914.52 S 2555.98 E 927.30 S 2580.23 E 935.85 S 2596.38 E Quality Control Comparisons B.P. EXPLORATION WELL: MPE-09, 4.5" DRILLPIPE Location: MILNE POINT, MILNE POINT FIELD Job Number : AK1094G239 / AK1094G239 inrun/outrun Comparison inrun outrun Depth Inc Inc Delta 1000.0 8.74 8.84 -.101 1100.0 10.51 10.55 -.040 1200.0 13.26 13.27 -.005 1300.0 15.87 15.91 -.036 1400.0 17.86 17.90 -.038 1500.0 20.33 20.36 -.038 1600.0 23.99 24.03 -.037 2000.0 33.13 33.11 .013 3000.0 55.25 55.29 -.048 3500.0 64.23 64.24 -.016 3600.0 64.42 64.43 -.008 3700.0 65.27 65.25 .020 For Inclinations Greater than 10 Average Inclination Difference = Average Azimuth Difference = inrun Az 108.43 108.74 107.21 106.95 105.04 104.79 104.50 101.52 102.94 111.95 113.09 113.22 degrees: -.0213 deg. .17269 deg. outrun Az 107.27 108.17 107.14 10~.67 105.03 103.90 103.65 100.79 102.99 112.35 113.89 113.47 Delta 1.153 .562 .068 .274 .019 .888 .852 .736 -.049 -.407 -.794 -.250 A Gyr oda t a D i r e c t i ona i Survey for B.P. EXPLORATION WELL: MPE-09, 4.5" DRILLPIPE Location: MILNE POINT, MILNE POINT FIELD Job Number: AK1094G239SS Run Date: 17-0ct-94 01:15: Surveyor: TOM STODDARD/ROB SHOUP Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.454806 deg. N Sub-sea Correction from Vertical Reference: 54 ft. Bearings are Relative to True North Proposed Well Direction: 116.020 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MPE-09, 4.5" DRILLPIPE Location: MILNE POINT, MiLNE POINT FIELD Job Number: AK1094G239SS Page SUBSEA I N C L AZIMUTH VERTICAL DOGLEG VERTICAL DEPTH DEPTH SEVERITY SECTION feet deg. deg. feet deg./ feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet -54.0 0.00 0.00 0.0 0.00 0.0 0.0 0.0 0.00 N 0.00 E 0 - 4880 FT. GYRO SURVEY RUN IN 4 1/2" DRILLPIPE MEASURED DEPTHS REFERENCED TO NABORS RIG 22-E R.K.B. THE R.K.B. IS 54 FT. ABOVE SEA LEVEL 100.0 .11 58.85 154.0 .12 200.0 .11 81.84 254.0 .16 300.0 .19 97.57 354.0 .21 400.0 .72 80.36 454.0 .59 500.0 2.01 93.21 554.0 1.31 .1 .2 .4 1.1 3.2 .2 88.8 .3 77.5 .6 80.3 1.8 84.0 5.2 88.5 .04 N .15 E .06 N .27 E .07 N .47 E .11 N 1.22 E .11 S 3.59 E 600.0 3.57 97.73 654.0 1.57 700.0 4.91 102.68 754.0 1.39 800.0 6.47 106.00 854.0 1.59 900.0 8.15 107.21 954.0 1.68 1000.0 9.81 107.79 1054.0 1.65 7.8 15.0 24.7 37.4 53.0 11.2 93.0 19.6 96.7 30.7 99.8 44.7 102.1 61.5 103.7 .55 S 8.43 E 1.96 S 15.69 E 4.50 S 25.31 E 8.20 S 37.60 E 12.96 S 52.67 E 1100.0 12.15 107.56 1154.0 2.31 1200.0 14.90 106.85 1254.0 2.68 1300.0 17.22 105.59 1354.0 2.25 1400.0 19.66 104.22 1454.0 2.37 1500.0 23.25 103.70 1554.0 3.42 72.2 96.0 124.3 157.0 195.2 82.1 104.8 107.2 105.4 136.3 105.6 169.1 105.4 206.8 105.1 18.85 S 71.15 E 25.93 S 94.12 E 33.94 S 121.76 E 42.46 S 153.93 E 51.88 S 191.93 E 1600.0 26.48 102.16 1654.0 2.93 1700.0 27.99 100.65 1754.0 1.34 1800.0 30.79 100.90 1854.0 2.45 1900.0 34.15 100.85 1954.0 2.84 2000.0 37.38 99.95 2054.0 2.67 240.2 289.9 344.5 406.2 475.7 249.7 104.7 344.2 104.1 396.7 103.6 453.5 103.2 513.8 102.8 62.22 S 236.93 E 72.40 S 287.29 E 83.01 S 342.88 E 95.04 S 405.61 E 108.17 S 476.58 E A Gyro da t a D i re c t i ona i Survey B.P. EXPLORATION WELL: MPE-09, 4.5" DRILLPIPE Location: MILNE POINT, MILNE POINT FIELD Job Number: AK1094G239SS SUBSEA I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet DOGLEG VERTICAL SEVERITY SECTION deg./ feet 100 ft. 2100.0 39.79 101.29 2154.0 2200.0 42.20 101.34 2254.0 2300.0 44.45 101.77 2354.0 2400.0 47.33 101.60 2454.0 2500.0 51.73 102.54 2554.0 2600.0 55.86 103.47 2654.0 2700.0 59.36 108.43 2754.0 2800.0 63.74 111.06 2854.0 2900.0 64.85 113.67 2954.0 3000~0 66.42 116.39 3054.0 2.31 552.4 1.87 636.5 1.69 728.1 2.20 " 827.2 3.09 942.2 3100.0 66.26 116.49 3154.0 3200.0 64.91 117.67 3254.0 3300.0 66.26 119.44 3354.0 3397.9 66.03 117.96 3451.9 2.69 1075.0 3.03 1230.7 2.36 1414.3 1.14 1621.7 1.53 1842.6 1.65 2078.5 .77 2297.2 2.24 2518.4 .77 2743.8 Final Station Closure: Distance: 2759.90 ft Az: Page CLOSURE DIST. AZIMUTH feet deg.. HORIZONTAL COORDINATES feet 576.9 102.4 710.3 102.3 780.2 102.2 852.4 102.2 1006.2 102.1 1170.4 102.2 1341.5 102.7 1518.3 103.6 1696.8 104.8 1876.6 106.0 2121.2 107.2 2336.2 108.1 2551.5 109.1 2759.9 109.8 122.45 S 554.89 E 139.54 S 640.18 E 158.71 S 732.76 E 179.35 S 833.00 E 203.50 S 949.10 E 234.62 S 1081.73 E 277.53 S 1234.07 E 341.01 S 1407.30 E 421.23 S 1599.01 E 514.30 S 1799.42 E 620.92 S 2009.85 E 721.15 S 2204.24 E 828.18 S 2398.15 E 935.85 S 2596.38 E 109.82 deg. ,gyro/data 4. QUALITY CONTROL SR239.DOC /roldata QUALITY CONTROL REPORT JOB NUMBER: AK1094G239 TOOL NUMBER: 053 MAXIMUM GYRO TEMPERATURE: 74.24°C. MAXIMUM AMBIENT TEMPERATURE: 25.48°C MAXIMUM INCLINATION: 67.98° AVERAGE AZIMUTH: 109.82° WIRELINE REZERO VALUE: 00006 ff REZERO ERROR / K: 1.23/K CALIBRATION USED FOR FIELD SURVEY: 14-SEP-1994 CALIBRATION USED FOR FINAL SURVEY: 14-SEP-1994 PRE JOB MASS BALANCE OFFSET CHECK: -.30241 POST JOB MASS BALANCE OFFSET CHECK1 · .- CONDITION OF SHOCK WATCHES -.24205 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ANCHORAGE: OK BOTTOM LINE COMPARISONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 4880 66.03 117.96 3451.9 -936.1 2596.8 FINAL SURVEY 4880 60.03 117.96 3451.9 -935.85 2596.38 SR239.DOC gyro/data FUNCTION TEST JOB NUMBER: AK1094G239 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D.~ 1 2 3 4 5 11870 65.62 65.62 65.62 65.61 65.62 AZIMUTH M.D. ft I 2 3 4 5 11870 119.51 119.78 119.19 119.62 119.13 SR239.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR239.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK1094G239 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 053 GYRO SECTION A0008 DATA SECTION A0020 POWER SECTION A0037 BACKUP TOOL No. 702 GYRO SECTION A0016 DATA S ECTI ON A0060 POWER SECTION A0050 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0053 A0058 A0029 A0042 A0078 A0056 A0036 A0052 WIRELINE COMPANY: WESTERN ATLAS CABLE SIZE: 15/32" RUNNING GEAR 2 1/4 inch system using the eccentric weight bar. TOTAL LENGTH OF TOOL: MAXIMUM O.D.: TOTAL WEIGHT OF TOOL' 22 feet 2 14inches 200 Lbs. SR239.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER · AK1094G239 15-OCT-94 07:30 Arrive at airport. 12:30 13:30 Arrive Atlas Check out tools. OK Standby 16-OCT-94 20:00 On location. 21:00 Assemble tool. 17-OCT-94 01:15 01:20 Pickup tool proceed with survey. .. Laydown tool and change out data section. 05:10 07:20 Rig down tool and returned to Atlas. Post run tool check. 10:30 Processed survey and faxed copy to rig. 18:10 19:50 Depart for Anchorage. Arrive in Anchorage. SR239.DOC gyro/data SR239.DOC ********~ SCHLUMB~GER ********** **~****~, ****~***., ******************************************************* [C~MF'ANY BP WELL HAME MPE-09 LOCATION 1 MIULE F~INT LOCATION 2 ALASFA MAGHETIC DECLINAT!OH C~:iD O]~ERGENCE A~3LE 0,00 DATE: WELL ~ WELL HEAD ~CATI~: LAT(N/-S) 0+00 DEP(E/-W) 0,00 AZIMUTH FROM ROTARY TiE IN POiNT(TIP) : MEASURED DEPTH 100.00 ~UE VERT'DEP~ 100,00 I~LiNATiON 0,i0 ^~,~. !02.64 L~ITU~E~N/-~) 0,00 vEF,R~uRE~n/-W~ O,uu ! Oil & Gas Cons. Commission Anchor: MEADJRET] INTERVAL VER2ICAL DEPTH DEPTH ft ft ft 100,¢4~ 0.0 100,00 200:00 100.0 200:00 300.~) !00,0 300,(K~ ' 400:00 100:0 400,00 500.00. 100.0 4.~.' .9? TARGET STATION AZIMUTH o~si!u~ INCLN, 0,00 0,1o -o~ ~ 0,!6 o.i2 ~ ~ 0.42 0,24 ~ '~' t,52 1,12 ~?,3~.. , OEr MB._,._.EE ¥)I oF L~CEMEN: at AZIMUTH E/-W f t f t 0,00 0.00 O,t2 0,:4 59~76 0.2A 0.31 . -". ~. _ "~ 0.6i 69.39 ~ ~ ...... ,< j t+7E AA.O'? ~LS des./ iOOft 0.00 0,12 0,!2 600~00 100.0 599.93 700~00 100.0 6%'.',74 ~40,00 lO0.O 799,38 tO00,O0 100~0 997,77 10,40 4,23 99,66 -0,77 11,20 11,23 73.v2 1.53 t8.56 = = 'tv ~,4o I02,~3 -~,44 .,47 19.82 97.i4 29,43 7,2? 105,5! -5.t9 30,21 30.6.~ ??.74 1,86 43,25 ~,84_ . 106,87 -9.11 4o,o8~ ' 44,62 101 ...'~'? 1,sA_. 1100.C0 1200,® 1300,® 1400.00 !500.00 1600,00 1700,00 1800,00 2000.00 100,0 1096,34 100.0 t174,i8 100,0 1290,94 103,0 1386,62 !00.0 1481,09 100.0 !573,66 1¢<,,0 16&3.98 i~0.0 1752,79 1~.0 1840,13 !00,0 19~,18 59,89 10,55 107,28 -14,06 59..78 61.41 103.24 1.7! ~3.~, ~o,~/ 10o,~ -20,il 79.51' 8~,01 104.20 105,11 15.9! 106,I~ -27,26 103,66 107<18 104,74 2.65 ~ ..... ~ !04.94 la~./~ 17.~0 105,28 -~'~i3 13i,85 i36.25 !65,85 20.36 !04.24 -43.46 163.34 169.02 104.70 2,48 :_~,~o 24,03 t03,04 244,46 26,78 102,22 -61,70 289,03 27,95 I0i,.5~ .-7!,16 336,13 -_~.33 10i,06 -80,74 -386,85 33,11 100,51 -90,57 -'^ -~ 5,70 200.05 ~0..~ 104.66 241,91 247~, 104,3). 2.77 2A~ =o 295.59 !03,74 1,2n 334,~J 344,23 103,57 2.39 o~ -,* 39A~75 t03,20 2,7'~ ¢~,.,, £/ .... 2100,00 2200,00 2300,00 2400,00 100,0 2007,50 100,0 i~87,16 100,0 2164,69 · ~4 tO0.O gZ40,~i 100,0 F313,.% 441,58 36,07 100,70 -!01.02 442,07 453.46 102.8.7 ~o,ol i00+75 -t12=27 50!,45 =" :~ - · 560,84 40.02 101,01 -124,!9 563,47 576,79' 102,43' 1,72 624,16 41.89 101,i5 -136,78 627,79 642,52 102.29 &.¢, 101,60 '1~0,i5 - 689,8i o r~ = 694.31 710.37 102.2a? 1,7t 2800,00 2900.00 IOC,+O 2454,32 100,0:20.02 100,0 2582,10 !00.0 2640,8.5 757,50 45.14 101,50 -!64.15 827,49 47.34 t02,01 -178,87 9CX),65 50.50 102,19 976.88 52,75 i02~8~ -2!i.70 ,5,~. 104,~J -~O.~ 1055.89 ~ 7~ .... 762,81 780,27 102,14 t,57 833,51 855:.49 102.i! 2,23 ~07,21 927.86 102.11 3,16 ?83.72 1006.25 102,14 2,32 !062,38 t087.14 tn~ ~ - ~ 3!00,00 3200,00 ~800.00 3400,00 I00,0 100,0 W48,45 tOO,O 2798,30 100,0 2844,73 I00,0 2888,70 1137,75 57.68 106,05 -252,43 122t,82 59.14 !07,46 1307,73 61,06 109,33 -304,36 1395,83 63,60 111,t0 -~4,97 1485.38 64,24 112~16 -368,08 1142,85 1170,40 102,% 1224,41 1255,35 102.75 1306,66 1341,64 103,11 1389.75 ~4~.,,5 103,55 1473,24 1518,52 1:o4,03 2,84 2,'51 2,98 1,15 3600,00 ~00,00 3~40,~ 100,0 2932,01 100,0 2974,52 I00,0 ~ ~ ' 301>,,! 40.0 ~" ^~ 30,0 ~44,24 1575.36 64,43 1i3,19 -402,~3 t665,80 A~. _., ~ _. 114,25 -439,24 !756,90 66,il 114,97 -477,20 17'~,42 65,75 115.41 -492.75 1820,81 66,!8 116,17' -504,68 1556,40 1607.69 t04.51 1&39.27 1697.09 105.(E~ !722.11 1787.00 t05,49 !755,15 i823.01 !05,68 1779,82 1849,?? 105,83 0.95 1.26 1,31 **** ANADRtLL ************** o~El CALCULATIONS **********~** CIRCULAR ARC ~THOD******** MEASURED IN%RVAL V~Ti~ 3900,00 30.0 3056,28 3930,(~0 30.0 3068,i6 3960,00 30.0 3079.85' 39?0,00 30.0 3091,%¢~ · )20,00 30.0 3!02,58 TARGET STATION AZ!MU~ ~Ti~]DE SE~T!C~ INCLN, N/-S ft deo O~ ft 18~,,~'''~ A~,48.. 116,46.. -516,$5 1875,64 66,8? !16,67 !90S,47 67,25 116,71 -541,59 · 1931~~°~, 67.86 117,36 -554.20 i'~58.'78 ^' '~ ./,y~ 117.21 DEPARTURE DISPLACEMEHT '_at ft ft 1804,45 1877,01 1829,0'? 1904,10 1853,77 !931,27 1676,47 1958,52 AZIMUTH Oeo 105, ?8 10~.,,~4 106,29 106,44 106.59 DLS lOOft 1,30 1,51 1,21 2,65 0,60 4050.00 4080.00 4!10,00 4140.00 ~.0 3113,92 30.0 3!25.64 30,0 30,0 3149,74 30,0 3161,85 1986.75 67,55 !17.00 =~14,o6 ~.4o li6,&~ -592,10 2041,63 66.20 116,93 -604,53 2069,30 &6.43 116,44 -616.87 2096,75 65,96 116,57 -62~,i2 1927.90 2013,t4 !06,73 t752,52 2040,33 106.87 1977.02 2067.38 107.00 2001,57 ~094,47 107,i3 2026,13 2121,56 107,25 1,45 0,79 1,66 1,6! 4200,00 4230,® 4260,00 4290,¢~ 4320,00 30,0 3174,07 3~.0 3!~,34 30,0 3198,73 30.0 ~Ii,24 ~),0 3223,~7 2124,15 65,96 117,® -M1,46 215i,51 65,73 !17,29 -653,95 2178,~ 65,49 117,42 -666,51 2206.0? 65.23 117,50 -679,0~ 2233,2? 64.?? 117,S6 -691.66 2050,59 2146,58 t07.37 2074.?5- 2175.56 107.49 2099,~ ~'~ 2202,49 107.^1. 2123.41 2229.36 I07,73 2147.54 2256,18 107,~5 1.31 i.17 0,89 0,90 ,¢~- .~ 4380,00 4410.00 4440,00 4470.~ 3~,0 32C~(,.59 38.0 3249,30 30,0 3262,(~ 30.0 3274,58 ~,0 3286,79 ~60,45 64,84 117,46 -704,21 2287,61 64,99 tt7,~ -716,77 ~i4,77 64,77 117,81 ~729,39 23-42,00 65,80 118u5 -742.15 2369,~ ~,17 118,49 -755,~ 2171.64 228~,97 107.97 2195,74 ~309.77 108,06 lOo.ly 22!9.79 ~ =~ ~ " 2243,87 ~363,41 106,30 2266,00 2370,41 IOB,42 0,58 0,62 1,01 3,51 1,82 4500.00 4560,00 4590,00 4620,00 ~11,25 30,0 .~23,60 30,0 ~ °~ C~],0 3348,33 2~6,77." 65,95 119,03 -7..q,33 2424,10 65,72 119.26 -781,66 2451.39 65,66 119,53 -,~5,07 2478,67 65,62 119,76 -808.59 2505,95 65,71 1t9,54. -622,11 2292,04 2417,39 t08,53 =~l~.~w 2444,30 !0A,65 2339.76 2471,16 t06,77' ~.o.J2 2496,00 108,69 2387,27 2524~86 109,00 1.04 0,84 0.71 0,73 4710.00 4740,00 4770,~, 30,0 3360,~ :30,0 '"""" _ .'_' 30,0 ~A.-,,.,4 30,0 3~3,0 3407,48 2533,37 66,87 119,~ -835,61 2588,51 66,89 118,% -862,56 2616.08 66,91 1i8,56 -&75,84 2643~60 66.46 118,30 -888,95 2411.19 2551,88 109.11 2435,28 257~.07 109.22 2459.41 2606.28 !09.33 2463,59 ~633,50 109,43 2507,82 2660,71 109.52 0,88 !,11 1,29 1.70 480O,00 4834),00 4860,00 4~,0,00 4907,18 30,0 34i9,50 30,0 3431.61 30.0 ~43,80 20,0 3451.92 27,2 3462,79 2671,07 66,32 118,02 -901,'-T.'.'.'3 ~^98,5~ ~ ~ 117,8A -914,79 U25,90 66,03 I17.P_X) -~7,58 27a4,17 66+03 117,96 -936,13 2769.07 66,83 116,~ -947.62 2532,06 2687,69 109,61 2556,30 2715,05 109.69 2580.55 2742,19 109,77 2596,70 2760,29 109,62 2618,80 2784,98 109,69 0,?7 t,02 . 0,17 0,73 4~41 5002.89 5096,19 5190,t6 5284,!8 5378.42 93.3 ~34~16 94,0 2570,6i 94,0 $609,03 94,2 3646,23 2857,52 ~ ~ = &o 2944,08 67,93 115,57 -1024,22 3030,68 ~,.44 t17,64 -1063,00 3116,46 65,3! 117.02 -1102,40 3~02,t4. ,~.~.sq.~.117,60 ' -1!41,72 2698,09 2672.89 t10,09 2776,16 2959.07 t10,25 2853.60 3045,16 110.43 297,82 3130,36 110,62 3005,97 3215,49 110,80 0,35 2,58 1.34 0,61 ***** ~**** ANADRILL ************** SURVEY CALCL%A?!ONS ************* CIRCULAR MPB-09 ME,E~]n~D !N~Rv~L t,~R~tCAL DEPTH DEPTH ft ft 5566,9~ ?6,7 37~3,i? 5663,66 94,7 ~" ~58,42 ?4,8 3797,82 5~54,64 96,2 ~36,64 ?ARGE? STATION AgiMU?H LATITUDE SECTION INCLN, N/-S ft deg deg ft 326~,06 67.1! 117.06 -1181.17 3377,30 67.56 1t7,05 -122!.77 3464,55 ~.,83 117,27 -1261,60 3637,28 &~,18 116,~9 -1342,43 D£PARTUR~ giSPLACEM£~ at AZIMUTH BLS E/-W ft ft deg 10Oft 3082,32 3300,8? 110,77 1,76 3!44,80 336?,65 t11,13 0,47 ~o ~ 3476,4~ 111,2~ 0.80 . . ,,8 0,?5 3394,43 3450,24 111 ~' 5949.96 6042.~ 6134,i6 6226,82 6320,72 95,3 .38,'-5.,07 92,i 3912,20 92,i 3949,54 92,7 39&6,17 93,? ~22,33 3~.v,¢ 65,93 i17~24 -14i9,51 3895,01 66,~ 118,62 3980,00 67,16 117,22 -1500,07 4066,54 67,56 1!8,~ -1542,19 3472,4~ 3737,23 !!i,70 3547. ,,,~ 3821,22 !11,8.1 %22,14 3904,91 tlr.?4 3696,62 3789~40 !12,07 3772,37 ~v/~-, o 112,24 .C; ,80 1,18 1,41 1,16 6416,42 6511 ~ 6605,52 6700,12 67?4,37 ~,7 4059.12 95,2 4095,54 ~,? 4131,28 94,6 4167,58 94,3 4203,80 4154,72 67,~ 120.14 -1585,73 4242,50 A7 TM . ./~ 118,27 -1628.63 4329.34 67.50 117.23 -!667,08 4416.66 67,37 !t7.83 '1709~46 4503,65 67,43 116,67 -1749,30 38~?,24 4163,07 !12,39 3925,?8' 4250,38 t12,53 4002,A^ ~'" 4¢J~,¢1 112 ~ 4080,33 4423,~5 112.73 4157,68 4510,69 112,82 1,23 t 1,07 0,60 1,!4 ,.4888,35 6982,55 7079,05 7172,~3 7266,45 94,0 '4239,66 94,2 4uJ,o5 ?3,6 4347,16 93,8 4385,03 4590,52 67.71 116,77 -1788,49 4677,~ 67,36.' 116,62 -1827,87 4766,48 67,06 118,26 -1869.CX~ 4852,77 67,52 116,95 -1909,00 .yoY,.o 67,53 116,8~ -t748.24 4235,21 4597.36 4312,84 4684.19 112,97 437t.72 4772,88 !13,05 4466,22 4858,73 113,13 4545,52 4945,44 t13,20 0,42 0,41 1,41 1,38 0,07 7457,10 7:'='A ! 7646,56 7¢3.5,04 YJ,~ 4421,75 95,4 4458,89 ?3,6 44?5,46 ?S,? 4533,3.3 &?,5 45,-.',6,43 5027,31 67,11 117,74 -1988,56 5115,18 A' ~ .. ./,uS 116,55 -2028,M 5201.32 66,71 !16,17 -2066,92 5269,39 66,55 116.14 -2105~74 5371,71 67,28 1t6,17 -2142.03 4623,60 5033,10 113,27 4701.61 5!20,79 t13.34 4776.79 5206.81 11¢,~ .... ' 4856,04 5274,7& t13,43 4931,73 5377.01 113,48 1,14 0°43 0,82 7766.74 7860,63 7957,38 6140,23 32,? 4560,88 91.7 4615,~ 96.7 4651,74 ?0,7 4721 5~)2.15 66,23 1!7,i? -2155,70 5487.13 ^7.68 117,23 ~ ' ~ 5576,66 67,80 !15,28 -'2234.17 5~1,85 67,61 113,62 -2269,44 5745,74 67,93 112,71 -2302,48 4y~¥,k, 5407.41 113,49 5034,72 5492,22 113.55 5115,02 5581,66 113.60 519'2.60 5666.87 113.61 5267.62 5750,86 t 13.60 0,60 1,68 t,O0 8236,51 8328,50 8422,65 8519,76 8613,51 96,3 4757.79 ?2,0 4793,39 94,2 4830,t7 97,3 ~68,12 93,5 4704,75 58,34,5? 67.42 111,40 5919,20 67,05 112,78 -2367,82 6005,75 66~77 113,01 -2401,54 60~5 % ,~. 67 11 113,67 -2437.04 616!,16 66,53 113,53 -2471,47 5352,36 5839,8? 113,58 5430,75 5?24.66 113,56 5510,80 6011,35 113,55 JJ.J,v, 6100,~5 t13,54 5671,88 6186,95 113.54 !,44 0,24 0,64 0.64 8707,47 .8601.~1 8897,41 ?088,08 ~,v 4943,03 94.3 4982,01 95,6 ~21,69 95,4 5~.1.31 ,.,~ 5100,69 6267,03 65,65 1!5,52 -2507.1t 6~ '"~ 6~,~^ 114,53 -2543,4A 0J£~70 ~ _. . b~oY,86 65,40 113,80 6526,67 65,55 117,42 -2616,57 66i3,37 65,60 1~ b,v. -~654,91 5750,01 6272,62 113,56 5827,86.' 6355.71 113,58 5907,22 6445,68 113,57 S?SS,50 6532,44 113.61 6063,26 6619,04 113,65 3,45 ~ NO. 6**** ANADRiLL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC M£THOD******.** MEASL~ED INT~VAL VERTICAL TARGET D~'~ DEPTH SECTI~4 ~t ~t ~t ft 9!79,77 9!,7 5138.70 66%.83 9275.46 ~,7 5178,14 67&3,97 '~372,70 97.z 52i7,81 ~' ~ 9464,45 91,8 5255,15 6956,53 9557~75 ~3.3 5293,21 7041.71 ~ATION AZIMUTH ~TITUDE INCLN, N/-S deg. deg ~t 65,43 115,54 -2690,58 ~,~8 i18,4~ -2730,15 65,98 115,59 -2770,48 65,98 115,31 -28(~.,49 65,58 116,01 ' ~' DEPARTURE DISPLACEM~T at ~/-W ft ft 6138,75 6702,48 6216,38 6769,48 6295,46 6876,11 6371,13 6961,88 6447,91 7047.01 AZIMUTH deo 113.67 113,71 113,75 113,77 113,80 DLS de~/ lOOft ~ 2,~2 ~,70 0,28 0,69 9652,46 '.'.~37 "'~ · 1003~,46 94,7 5~i,27 7128,43 yo,4 5369,33 7216,96 '~4,0 5.406,33 7303,41 95,0 ~43,47 7390,.88 94,5 5460,29 7477,~8 66,74 1!4,~0 -2880.58 66,76 115,7.5, -2916,~ 66,89 114,93 -2954.71 67,10 114,50 -299!,28 67,05 113.68 -3026,82 6526,?_S 7133.71 !13,82 6~)6,51 7222,25 t13.~3 .A6'84.79 730~,68 113,85 6764,26 7396,15 113,86 6843.74 7483,21 !13,66 1,48 0,43 0,35 0,47 0,80 10117,60 10317,05 t0410.'~ i05~)5,41 ~,1 ~i7~10 7565,60 95,4 ~53.57 7653,72 94.1 5-589,52 77~%65 93.9 5625.+35 78Z7,._~ 94.5 5561.23 79!4.79 67,45 117,52 -3064,72 67,58 116,11 -3104,48 67,48 115,16 -3142,09 67.64 115.12 -3178,94 67.74 114,~ -32i5,55 ..9zz,65 7570.89 113.~* 7001,50- 7656,90 !13,'91 7079,67 7745,79 113,93 7158.40 7832,51 113.95 7~ ~9 ~x.x. 7919,93 113,95 3,75 1,37 0,17 0,71 lObOl,JJ 10694.78 10787.52 10882,65 OV76.Jo 96,1 5697.65 8003,74 93,2 5732.89 ~90,06 .~2,7 5768,15 8175,83 v..~ 5~4,59 82,:'.3,69 '~,'? 5840,72 8350,~ 67,74 115,01 -3252,74 67,65 116,10 -3289~98 67,46. 115,7I -3327.45 67,49 114,65 -236.4,84 67,26 115.22 -3401,38 7316,62 ~06,91 113,96 7396,50 8095,19 t13,78 7473,65 8180,~ 114,00 7553,17 8268,77 114,01 7631,77 8355.44 114,02 0,59 t,09 0,57 1,03 0,61 11071,41 11167,25 11260,25 11354,55 11450,12 94.9 5877.28 ~J,~'~,~.°? 95,8 5914,14 8526,31 93.0 5950.33 8611,96 94,3 5987,62 8698,57 95.6 60~.62 8786.27 67,39 115,02 -3438,53 67,37 114,80 -3475,80 66,83 114,~ -3511,71 66,58 116,30 -3549,04 66,57 115.62 -3587,43 7711,01 8442,94 114.03 7791,25 8531,40 114,04 7869,03 8617,06 114,05' 7947,18 8703,64 114.~. 8026.03 6791.29 114,08 0,24 0,21 0,59 1,51 0,65 11543.65 11636,60 11731,96 11624,92 11920.27 ~,5 6062,80 8672,08 93,1 ~'-79,78 8957.57 95,2 6137.35 9045,00 93,0 6173.90 9130,~. 95.3 6211.47 .-7218,08 66.58 117,28 -2E,25,66 66,64 115,41 -3663,59 M a~ 117,18 -3702,32 66,84 116,96 -3741,22 66,74 116,41 -3780,58 8102,86 5677,04 114,11 8179,47 6962,46 114,13 8257,85 9049.82 !14,15 8333,96 9135,19 114,16 '8412,26 ~22,73 114,20 1,63 1,84 1,72 0.22 (~,.,4 12011 12106.37 12~6,01 IZ390.56 91,4 6247,62 9302,04 94,7 6285,09 ..,~ &_qZ~,64 9476,50 94,4 &_'_~9,84 ~63.26 94,5 6397.23 96~b.10 66,68 117,15 -3818,41 8467,22 9306,62 66,69 11&97 -3857,97 8564,65 . ~93,47 66,86 115,42 -3896,../-.0 8643,18 9480,93 ~.,73 115,46 -3933.B7 8721,54 ~67,69 66,68 115,12 -3970.97 8800,06 9654,52 114,22 114,25 114,27 114,28 114.29 0.75 0,-17 1,51 0,14 0,33 12579,01 lZo~,~l 12765,03 1~o 10 94,7 6434,72 9737,05 93,7 6471,94 9823.09 93,9 65.~?,55 ~09.12 92,1 6546,73 9%'3,4! 94.! 6584,90 10079,3~ ~..67 115,52 -4008,16 8876,67 9741,46 66,55 115,~ -4045~06 8956,39 9827,49 .~.,.24 116,24 -4082,44 9033,88 9913.50 66.16 116,~ -4119.59 9109,54 9997,74 65,96 114,25 - -4156,14 9187,37 10083,71 114,30 114~31 114,32 114,33 114.34 0.39 0.28 1,00 0,20 1.77 ****-~ ~**** ANADR!LL ************~* SURVEY ~LCL~ATIO~ *********.**** CiEC.;ULAR ¢¢<C. METICDD******** M£AS~R~D it 13053,64 13141,60 13240,76 i3334.~ I~RVAL V~TICAL T~GE? S~ATION D~F'TH SECTION tNCLN, ft ft ft 94,5 ~23.,51 10165.57 65,81 100,3 ~q"~ :~ ...~ 10257.02 65,83 87,8 6700,73 '10336,99 65,5! 99,2 6741,77 ~v.u,co 55,59 ~,3 6760,34 10512,21 AZIML~H LATI~DB D~PARTUR£ DiSPLAC£ME~ at N/-S ~/-W deg f~ ft ft 114,54 -4171,75 ~265.?0 10169,94 115.73 -4~0,60 9348,70 10261,3? 115.59 -4265.23 9420,78 10341.34 115,62 -4304,38 9502.12 10431,56 115,26 -434i,01 9576,77 10516,52 !o427,4J 13526,02 98,6 1~!9.95 93,9 13713.~ ~,4 13808,40 95.0 PREk;EC%'~., lt3 T~ 6818,90 :"? ~2 10~.,~. 65,65 113,61 -4376,19 9656,20 10601,57 6860,19 10686,68 64.83 114,3~ -4412,59 9737,78 10691.08 6900,11 10,'-7.1,66 64,8~ 113.76 -4447,27 9~15,61 10776,10 6c/~,57 10856,23 65,17 115,70 -4482,70 98~2,54 108~0,80 6979,29 10942,63 65,39 116,43 -4520,62 9970,06 10947,06 7033,26 11060.46 65,39 116.43 -4573.07 AZIMU?H 114,34 114~35 114,3~ !.14,37 114,38 114,38 114.3~ 114.37 114,38 10075~58 11064,82 114,41 OLS Oeo/ tOOft 0,32 t 0,3? 0 0,55 1.61 1,09 0,60 1,91 0.73 0,02 ;'AGE COMPANY BP WELL >~ME MPE-09+ SIDETRACK LOC~TtON I MiLNE F~iNT ~g~=Tm~ ~.~,~. ~ ~ DECLINATION 29+0~. GRID C~NVERGE~CE~=~''~'~ O~O0 15-N~J-?4 YEgg ?~]MB~R 0 WELL H£~D LOCAT!ON~ LAT(N/-S) 0,00 AZIMUTH ~M ROTARY TABL~ TO ?ARGOT iS TIE i!4. F'OiNT,'..T!P) ,- M=~oUR~:, DEPTH TRUE VERT DEPTH t~CLi~TION AZIMUTH LATITUDE(W-S) DEPARTURE(~z-W) ~0601 s~ sag7 67,74 1!5~.01 -3252 ~74 7318,2i DEF'(~/-W) 0~00 Gas Cons. Commission Anchor~ CAGE'~+ 2 ,._.MPE-O?, SiDETF~CE ME~BURED iMT~',VAL '~ DEPTN DEPTH ft ft ft 10673,81 72.3 579.08- !0855~55 93.2 57~5~i~ 10950.67 95,! 5832.38 TARGET STATiC~.t AZIMUTH LsT~ SECTiC~4 iN[:LN. N/-S ft deo ~_~. ft 0,00 67 ..74 115:01 -3252.74 66 .-'~5 67,65 116.66 -3281,87 '"' =~ A7 '-'~' ~ ~g ='~ '-'"' "' -" 14;~. J_, .... ,.r 2~4,39 67 '~''' i ,-, _ ,..o ,1=, ...... -3361,73 32t+ :.,_, ~ AA,67.. i2I, &9 -340.6,36 DEPARTL~:E DISPLACEMENT at ft ft /o18,9~ 8006.53 7378,38. 8075,34 7450,80 8156,91 7525.82 8242..~ 760!,10 ~29,47 ~ZIMUTH 113.'.?.0. 1i4,02 114,07 114,i4 de.o/ lOOft 0,00 2,!1 2,06 1,26 1,67 11044,89 !!i39,2! t1234,22 11323.79 11423,39 94,2 5~.9,53 ~o.~ 5906.16 96,0 5943,19 94,6 5979~32 94,S 6015~18 407.96 66.69 !!8,94 -3449,92 493.68 66.88 !!8.83 -349!.38 582.14 67~74 119.13 -3534.29 669~38 67,35 119+79 -3577.28 v~A.~ A~.,~O 117.69 -3619.36 :_.?~ .~- ~ 7675,93 8415.57 !14,20 7751.0~ 8501 '~ 114 ~= 7828.5~ ~589,39 114,30 7904,66 8676.44 114.35 798!.41 8763,72 t~4,39 2,49 0,!0 0,95 0.77 2.20 !!6!2.7! 1!892,15 95.! 94,3 6085,24 '"~.0 Al19,77 92,9 6154,89 94,6 845,06 65,43 118,19 -3~40,73 932.58 68.i7 t18.!5 -3702.07 10i7.7! 67,80 i19.~ -3743,22 1i03.48 67,70 119,~8 -3785,83 I191,~ 65.64 117.ii -38Z~,72 8059,42 8851.85 114,43 ~A,62 8939.24 i14,46 82i!,2B ?024,23 114.51 8285.92 9109.&3 114,56 8380,11 9197,45 !t4.59 0,60 0.28 1,49 0,32 2,89 !2060.4~ ~2!70.77 12362.87 94,4 6224~52 93,9 6259.34 90,3 6294.83 97,9 ~qo~.~7 95,2 6376,05 1279,14 68.58 116,64 -3867,47 13~5.+27 67.89 t19,3'? -3908,41 · .- ~.~ , ~r ,', 1449~13 ^~.82 l~,il i538.!0 65,16 I!~.51 -3??3.24 !624,05 64,35 !19,22 -4034,79 A441,54_ o?~¢._=.,o~n 114,61 8518,5i 9372,33 1i4.65 8590,~4~ 9455.04 114,69 86~8,31 9543,87 1i4,73 8743,68 9629.71 114,77 0,47 2.82 2,40 1,63 !2549.43 i2646,'99 12696.47 12740,24 91,5 64i5.71 9i,I ,. 4.,_,,4,., 97,6 6494 a,- 49,5 4~' ~ =4 ;...~ A -I' ', -" , ~.:,,;, 65WI ,/5 t706,~? 64,27 116.69 -4074,70 179!,6! oJ./4 ~16,.~ -4114,24 !gAO.R^ A~ i~ ~ ~o -4!54.15 1926,26 '^ .... ~ 4~ .. o..,~ ~1~,-~ -4174,~3 1965,49 67,26 114,01 -4190,86 8815,82 9711,94 114.31 8891,34 9797.09 114,83 8971,18 9856,31 114.85 9011,99 9931.70 114,35 9048,55 9971,94 114.85 0.54 2.55 0.94 2. ,08 2:,54 ~$a~ 41 12926,72 130~j,40 !3113~i3 13~08.02 95,2 6566,87 '=~ ':' 6597, 93.7 8626.72 94,9 6683 2054.92 A9,43 1t5,72 ~o c~ 2140,88 71.18 t17,34 -4266,47 2229,~.~ ~ 72,65 !18,67 -4308,29 23t8,!2 72,47 121,13 -4352,3'? 2408~08 7!,99 121,74 -4399,52 9!28,79 10060.38 114.85 9205,69 !0146,3t 114,~, 92:!.4,30 i02~5.21 114, ,.,Y '~'' 9360,98 10323,33 114..-94 9438,09 i0413,13 114,99 2~83 ;_:,55 2,06 0 13303,89 t3400.27 124~4 ~n .... 12587,60 95,'? 671S,2z · -_ ~=~ ~4,~ k7~.sn · .... ~ 93,3 682!,48 /?.g 685i.73 =,..,~,°~ ~ 69,17 .z¢,YO -4448,S0 ..... 9S14,07 10502,69 6~,~ 125,17 -4499,40 9588,04 2.5.72.78 67,92 124,99 -4549,53 9659,41 10677,19 ~757,73 ,~5.74 125,73 -4599.35 9729,62 10761,95 282S.30 ~7,44 125.00 -464i.31 9787.66 10832.36 115.06 115.!4 115.22 115.30 11o.o7 · ~ 0.35 1~46 0.96 13765,20 13853,90 13939,20 140C~,20 70,7 69i6.!8 86.3 6955,65 65.0 69~1,20 29!9,32 68,00 125,80 -4695,49 2983,73 67,80 127,20 -4734,45 ~ ....~: 6/,70 128,50 -4742,97 3077.0i z*,30 126,20 -47~,59 3!35,27 66.40 ~2~,60 -483.1.11 9862,50 !0923.21 115,~5 9915.16 109B7.5i 115.52 9926,12 11001.08 115,54 9990,i0 11080.64 1!5,6~' i0036,6i 11138.82 115.70 0,59 1,86 8.05 0,55 2,42 .AGg'NO, 3 MPE-09~ SIDETRACK _,'~T,.RYM,. V~F, TiCAL ft ft ft !420!,60 ?6,5 7~6!,00 ~oo~ ~,~, '~0 7143,00 , 14477,10 ?0,9 7!86,03 4.~i,60 14,5 PROJECTED ?0 TD 14570,00 76,4 7193,00 7230,53 TARGET STATION ^~'*~' ML~MoiH LATITUDE SECTION !NCLN, bV-S ft deo ~ea ft 3~!i,26 65,20 129,70 -4944,54 3389;66 ~:,50 130,00 -4996~n 4,~,~. ~2,4v !27,7o -5049,0~ 3550,29 6!,!0 !30.60 -5099,34 "=: ~'o ~,.,~ .~ ,'.,:'? 6!,40 127.70 _ -5107 3~30,06 61~40 127,70 -514'?,46 DEPARTURE DiSPCACEHEHT at AZIMLITH DLS B/-W ~eq/ it ft de~ lOOft 10177,07 11314 4~ ~ = "' " 102S?,08 11393,06 116,01 i0305,!9 11475,63 ii6,i0 2,~7 10367,50 !!553,71 116,19 3,59 MEMORANDUM TO: THRU: Chairmafl/,"' Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 15, 1994 FILE NO: awohkobd.doc FROM: Doug Amos, '-~ ~ SUBJECT: Petroleum Inspector BOPE Test Nabors 22E BPX MPU E-09 Kuparuk Rv. Field PTD No. 94-132 Tuesday. November 15, 1994: I traveled to BPX MPU, E-09 well to witness the BOPE test on Nabors Rig No. 22E. As the attached BOPE test form indicates, the Choke HCR Valve at the Stack failed. This is the second test that the HCR valve has failed, therefore I instructed, AA! representative, Donnie Lutrick to replace or repair the valve before continuing the drilling operations. The valve was replaced and drilling operations continued on 11/16/94. I found the rig and location in good condition. The drilling personnel were courteous, understood the test procedurejand the operation of all their BOP Equipment. SUMMARY: Witnessed the BOPE Test at BPX MPU E-09 well on Nabors 22E. 4 test hours 25 valves tested 1 failure Attachment: AWOHKMBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drig Contractor: Nabors Rig No. Operator: BP× Well Name: MPE - 09 Casing Size: 9 5/8" Set @ 3,818 Test: Initial Weekly X Other 22E PTD # Rep.: Rig Rep.: Location: Sec. DATE: 11/15/94 94-132 Rig Ph.# 659-6475 Brian Busby Donnie Lutrick 25 T. 13N R. 10E Meridian Umiat MISC. INSPECTIONS: Location Gert ' ~r~ vve, Sign OK Housekeeping: OK (Gert) Dri. Rig OK Reserve Pit NiA BOP STACK: Quan. Annular Preventer 1 Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves 2 KJ!! Line Valves ! Check Valve Test Pressure P/F 250/3500 P 1 250/5000 P 1 250/5000 P 1 250/5000 P 1 250/5000 P 250/5000 250/5000 P!F ~'~/~' N/A N/A i ,il,r-{ MUD °"°'"'-"'- ~.~, ~,v,. 'visual ~1~, Trip Tank OK OK Pit Level Indicators OK OK Flow indicator OK OK Methane Gas Det. OK OK H2S Detectors N/A N/A FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Keiiy/ IBOP Ball Type inside BOP Test Quan. Pressure P/F 1 250 / 5000 P I 250/5000 P 1 250/5000 P 250/5000 CHOKE MANIFOLD: No. Valves t7 / No. Flanges 36 Manual Chokes 2 Hydraulic Chokes 1 Test Pressure P/F 250 / 5000 P 250/5000 P P Functioned Functioned ACCUMULATOR SYSTEM: ~,,~+,-m Pressure -.,.~.~.~1.~.., ! i i Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 8 @ 1900 3000 ! P 1350 P minutes 25 sec. minutes 48 sec. X Remote' X Psig. ...... ~:~:e;r':g~:'~'~'i:i~i;e~ .............. ?;' ........... ':::Y;;t";YiA;;':' ........ ~ ............ H:0:U:~.:.:::N:u:~ro_.~.:valves tested 25 Repair or Replacement of Failed IEquipment will be made within .Se...e Note. days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The Choke HCR valve at the stack failed. The valve shall be repaired and retested before ddlling ahead. 11116/94 Brian Busby call this date and informed me that the HCR had been replaced and retested. Distribution: ofig-We!! File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO ! Waived By: Witnessed By: Dou~I Amos FI-021L (Rev. 2/93) AWOHKOBD.XLS MEMORANDUM TO: David Jo~ Chairm~ih~5-~--~' THRU' Blair Wondzell,~ ~ P. I. Supervisor FROM' Lou Grimaldi,~ Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 1, 1994 FILE NO: GWOJKABD.DOC SUBJECT: Well Control procedures BPX well E-9 Nabors rig 22-E PTD # 94-132 This is the second part of the previously submitted report (GWOJJ4BD.DOC) on the well control procedures being performed on BPX well E-9 in the Milne Point Unit. Note:The first portion of the report ended the evening of Sunday, October 30, 1994 with the rig ciculating 10.1 at. 8200' this was in error the mud weight was actually 10.2 ppg. Monday, October 31, 1994: The circulating procedure continued until approximately 0200 hrs when the returns cleaned up considerably and the mud weight was brought up to 10.4. This mud was circulated two times and the well was checked with no pressure on the casing or annulus. The rig then tripped out of the hole at approximately 0800 hrs displacing the drill pipe on the way out. The rig was on the bank at approximately 1500 hrs and the BHA was broke down. As the hole had seemed to be wanting to get tight I waived the weekly BOP test and a function test of the rams was performed. The rig picked up a muleshoe and ran back in at 1800 hrs to cement the Kuparuk. At approximately 0800 hrs. the cement job was began. A 37 bbl batch of 17 ppg class G was pumped with a 20 bbl lead and 2 bbl tail of drill water. Returns during the cement job seemed to be going OK but as the cement turned the corner and displaced the annulus they would fall off then come up again. The wiperpl~ showed no indications of latching, 10 stands were pulled dry, pumped 80 strokes before DP showed any pressure and 50 bbls total at 5 bpm. The rig then tripped out filling DP every 5 stands. They pulled out to 6950' (The wiper was found at 6981' stuck inside a 2 7/8 thread protector and lodged in the drillpipe) and stood by for cement (cure). The decision was made to pull out of the hole at approx 1700 hrs. I left location to pick up Jerry Herring. MEMORANDU State of *!aska TO: THRU: Alaska Oil and Gas Co.,servation Commission Blair Wondzell, ~ P. I. Supervisor p~ctor DATE: November 7, 1994 FILE NO: awokkfbd.doc BOPE Test - Nabors 22E BPX Milne Point Unit MPE-09 PTD # 94-132 Sunday, November 6, 1994: I traveled to BPX's Milne Point Unit to witness a B.O.P.E. test on Nabors rig 22E. The B.O.P.E. Test Report is attached. The test began at 9:00PM and lasted for (6) hours. This rig had been in a well control mode for nearly two weeks. There were (7) failures. A choke line flange leaked, the inside manual kill line valve leaked, the choke line HCR valve leaked, one choke manifold valve leaked, and various problems with the mud control panel were found. All of these problems have since been repaired. I am glad I was there to witness the test even though it did not end until 3:00AM the next morning. Summary: I witnessed a B.O.P.E. test on Nabors 22E drilling well MPE-09, MPU. The test lasted for (6) hours and there were (7) failures. Attachment: awokkfbd.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: ~ Drlg Contractor: Nabors Rig No. 22E PTD # 94-132 Operator: BPX Rep.: Well Name: MPE-09 Rig Rep.: Casing Size: 9-5/8" Set @ 3813' Location: Sec. ~ Test: Initial Weekly Other X DATE: 11/6/94 Rig Ph.# 659-2563 Donnie Lutrick Leonard Schiller 35 T. 13N R. 10E Meridian Umiat MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F I 250 / 3500 P I 250/5000 P I 250/5000 P I 250/5000 P 2 250/5000 P 1 250/5000 F/P I 250/5000 F NIA N/A N/A MUD SYSTEM: Visual Alarm Trip Tank F N/A Pit Level Indicators OK F Flow Indicator OK F Methane Gas Der. OK OK Test FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 1 250 / 5000 P 1 250/5000 P 1 250/5000 P 1 250/5000 P CHOKE MANIFOLD: No. Valves 17 I No. Flanges 36 Manual Chokes 1 Hydraulic Chokes 2 Test Pressure P/F 250 / 5000 F/P 250/5000 Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained -2 Blind Switch Covers: Master: Nitgn. Btl's: 8 Bottles 1800 Ave. 3,100 I P 1,500 P minutes 37 sec. minutes 59 sec. OK Remote: OK Psig. Number of Failures 7 Test Time 6.o Hours Number of valves tested 25 Repair or Replacement of Failed Equipment will be made within 2 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Choke line flan~e leaked and was repaired. Inside manual kill line valve leaked. Choke line HCR valve leaked. One choke manifold valve leaked. Trip tank gain & loss lights not functioning and there is no trip tank horn. Pit level gain horn not functioning. Flow indicator high & Iow horn not functioning. Valve failures to be repaired prior to continuation of drilling operation. Distribution: odg-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Jerry HerrJn~l FI-021L (Rev. 2/93) AWOKKFBD,XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: DATE: David Johnst~ Chairman-~ Blair Wondzell, ~/:~ P. i. Supervisor FROM: Leu Grimaidi,~-~ SUBJECT: Petroleum Inspector FILE NO: October 30, 1994 GWOJJ4BD.DOC Well Control procedures EIPY,, well Nabors rig 22-E PTD # 94-132 ~..h.,.u._rsdav. Oct.ober 28, 1994: I traveled to the Milne Point Unit Io observe the Well Control procedures being perft3rmed tnn RPX well # F-.q. The history of this well thai I have been able to gather is that at approx. 2300 hfs o~] October 24, 1994 the rig was drilling ahead at a depth of 13,938' when the driller noticed that the flow had increased I have not been able to determine how much it increased but the Company man, Jimmy Pyron, told me that there was no reportable pit gain from that time to when the driller shut in the Annular preventer. At this time the drill pipe and casing pressures were at 0 psi each, I have heard differing stories about the casing and tubing gauges on the choke panel being inaccurate and found that they were using 5' tree gauges in the :3500 psi range instead of the panel gauges which were disconnected. The mud was weighted up 1 point from 10.3 to 10.4 as they thought they just had a small influx due to they had scratched the Kuparuk cap. The returns taken upon bottoms up were mostly gas and oil cut mud in the 8.9 area. At this point it seems that returns stopped completely and were being lost somewhere downhole. There are two zones at approx. 8000' Schrader bluff and above it the Ugnu. These were the prime suspects although I feel that we cannot completely rule out the shoe at approx. 3500', The well was shutin and a series of LCM pills were pumped in differenl batches over the next two days trying to shut off the thief zc~e, all the while taking ~wd returns to ~urface or when they did get returns it was crude oil. On the afternoon of Oct. 27, a 15 PPG pill was spotted at the Kuparuk and the well seemed to die but as the hole had sloughed somewhat they had to pump there way out from 13~t I to 12840. The rig was up in the casing at 1600' when the well started to flow on them again the dart valve was stabbed and after conferring with town they started to strip back in the hole, I arrived the following afternoon October 28, at approx. 1530 to find them at 8707' feet and stripping In. The morning of October 29, 0300 hours the rig could not get back to bottom as the hole was trying to grab the string (~ 13205. q-hey circulated 10.7 PPG and lost 110 bbls and received back 50 bbls of mostly crude oil. SlDP 300/SICP 225. Another attempt wes made tt") On to bottom ~nd spot a 13 PPG pill but it had to be laid at 13380 the pill was raised to 14 PPG and pumped at depth and while stripping out to 8200'. Batch up 10,1 and circula{e at Schrader bluff casing pressure at 60 psi DP at 225 psi. Returns are heavy gas cut mud in the 8.8 average. Evening of Sunday, October 30, 1994 the rig is still circuleting at 2 bbl/min 10.1 and returns are still gas cut mud in the 9.0 range, SUMMARY: Atta._c_hments: STATE OF ALASKA ~ AL ,SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon .__ Suspend __ Operation Shutdown Re-enter suspended well__ Alter casing __ Repair well__ Plugging __ Time extension __ Stimulate __ Change approved program x Pull tubing __ Variance__ Perforate __ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 4. Location of well at surface 3731' NSL, 2029' WEL, SEC. 25, T13N, RIOE At top of productive interval 4420' NSL, 2540' WEL, SEC. 32, T13N, R11E At effective depth N/A At total depth 4207' NSL, 2108' WEL, SEC. 32, T13N, R11E 6. Datum elevation (DF or KB) KBE = 54' feet 7...Unjt.~ PF).Ee¢ y name ' ~l'aC'f,~i~J~ U[lll 8. Well number MPE-09 9. Permit number 94-132 10. APl number 50- 029-22513 11. Field/Pool ~,~p¢,~ F'?~( ~ P~ra~/hoe-Ba~'etd/Oi/-Pool~ 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 3784' Intermediate Production Liner Perforation depth: measured None 13938 feet 7014 feet feet feet Size 20" 9-5/8" Plugs (measured) Junk (measured) Cemented true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 250 sx Arcticset (Approx.) 748 sx PF "E"/250 sx "G" Measured depth True vertical depth 112' 3814' 112' 3021' RECEIVED 0CT 2 8 1994 Alaska 0il & Gas Cons. Commission Anch0r~..,~-~ 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 10/27/94 16. If proposal was verbally approved Oil x Gas ~ Name of approver B. Wondzell 10/27/94 Date approved Service 17. I hereby certi~ that the foregoing isFue and correct to the best of my knowledge. Signed '~6 ~_'~-/--.~ ~,, TitleDrilJlngEngJnoerSupervisor co ss,o. Conditions of approval: Notify Commission so representative may witness 15. Status of well classification as: Suspended __ I Approval No.o~, ~,' _ ~., ~ ~ Plug integrity BOP Test__ Mechanical Integrity Test__ Approved by order of the Commission Form 10-403 Rev 06/15/88 Location clearance Subsequent form required 10-/-/¢7 Original Signed By _ri,vid W. Johnston Commissioner Approved Copy Returned SUBMIT IN TRIPLICATE Change of Program MPE-09 Due to abnormal pressures encountered in the Kuparuk River Sands a change of program is requested. The bottom hole location has been changed approximately 200' to the South East (directional diagrams attached). Proposed measured depth is 14417', 7192' TVD. Casing program change: 7", 26#, L-80 casing will be run and cemented at 13970' MD. Drill 6" hole to TD at 14417' MD and run a 5", 15#, L-80 liner cemented with 75 sacks Class "G" cement. RECEIVED OCT 2 8 i~ Alaska 0il & Gas Cons. Commission Anchor~., -- PFtd'DHo'E BAY Ei'R iLLI'N6 RoUP ..... [_ . /InadrJ ~_] Sch]uc. berger . ~, __ i i u il mill ,j I _ .... MPE-09 (P'i3) .......... PLAN VIEW CLOSUIqE ' 13512 feet. at &zi~uth ~t4.ra2 o~ , , ISC~LE ....... : I incll = 3300 feel = _. ~e ........ : ....I 1 ..... :i [DRAWN ....... : ]0/10/94 ........ F ...................................... ? I ....... garker Ideal if ~cat ion ~D N/S E/~ . . . ~] KB ~ ~ 0 ~ ~ BI KOP/BUILO ]/~OO 400 0 : BI B~ILO ~d~O0 900 6 .... ;' El B~ILD 2 5/~00 t300 24 ~ - . F) CtlRVE 3/100 ~80 21~ ~0~ ' 'Gl END OF 3/iO~ CURVE ~24 407 .......... ~ .......... ~ ........... ~l ..... ~~~ Xt 9-5/8" C~SIt~ POINT 3800 518 ~702 ]J ....... TARB[ T ....... ~ ]892 4585 ~0032 ~ ~ . d] TO t~417 4797 JO465 . .......................... ' ...... ~ ............. . ............ ~ ............. ~ ............ , . % ~ I ~ i ~ I '" g: o. ~ : i 200 FT ~AnUEr R~DIUS _ , - I ~' .,.. ,, ; ....... , ' -'t " i ...... ' .i __ ~ , 650 0 650 1300 ~950 2~500 3?.50 390l} 4550 5201} 5B50 6500 7i50 7BOO 849) 9100 975~} 10408 1]059 <- WEST - EAST -> ~nadrJ[] [C~93 I~FE,%q~]3 BI.5~? .~ 50 ~J~ tl [ .... PRUOHOE BAY DRZ LLZN6 _ --. SEgfI,I ]NCLN O 0,00 3 2.00 899 25 6,50 t29~ 96 i4.50 2BB:] 1111 59.00 28Bfi 1503 55.72 2995 1756 65.72 6984 ]'1026 66.72 7192 11509 66.7~ 14arkeff 'idonti f ica[ ion B) ~<OP/B~'JILD I/lO§ ....... C) .BIIILD. 1.5/100 ...... 6~.0_.. 600 O] BIIILD 2/t00 900 E} 8tHI. D 2,5/100 1300 FI CURVE 3/100 3~)80 Gl EI.JD 8F 3/]00 CURVE 352.4 It) 9-5/8" .C~.SIN6 POIN1 3800 I) ....... IAMET ........ 13892 J) lO 144]7 'isRouP [i [[ · .[ , .... · _ ~ ill ....... 4na#r i ] ] ,Sc, h/umberge_r MPE-O9 (P~t3) VERTICAL SECTION VIEW Section at: ~6.02 fro Scale,' ~ inch = 1500 feet Dep Scale,' 1 inch : ~500 feet Drawn ' i0/t0/94 Section De_partur;e 'i' ,,- ' ......... {~cotlri]l 16)93 qFtagPJ;] FJ;.,.:~ 9:45 04 t) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David Johnst..~.[~. Chair~ Blair Wondzell, P. I. Supervisor DATE: October 23, 1994 FILE NO: AWOLJWBD.doc FROM: John Spaulding~ SUBJECT: Petroleum Inspector BOP Test Nabors 22E BPX / MPU / Well MPE-09 Milne Point Unit P.T.D. # 94-13~. Sunday October 23, 1994; ! traveled to BP×'s Milne Point Unit well MPJ-09 to witness a BOP test on Nabors 22E. The AOGCC BOP Test Report is attached for reference. Although the drill sites at Milne Point are quite small, the rig and adjacent area was well laid out and very clean. No failures were observed. Summary: I witnessed the BOP Test on Nabors 22E, BPX Milne Point Unit well MPE-09, 0 failures, 4 hour test time. Attachment: AWOLJWBD STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Nabors Operator: BP× Well Name: MPE-09 Casing Size: Set @ Test: Initial Weekly Rig No. 22E PTD# 94-132 Rep.: Rig Rep.: Location: Sec. X Other DATE: Rig Ph.# Brian Busby 10/23/94 659-6475 Jimmy Pyron 25 T. 13N R. 10E Meddian Umiat MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F 1 250 t3000 P 1 250/5000 P 1 250/5000 P 1 250/5000 P I 250/5000 P 2 250/5000 P 1 250~5000 P N/A N/A N/A MUD SYSTEM: V?sual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Methane Gas Det. ok ok H2S Detectors ok ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250 / 5000 P 1 250/5000 P 1 250/5000 P 1 250/5000 P CHOKE MANIFOLD: No. Valves 17 No. Flanges Manual Chokes Hydraulic Chokes 1 Test Pressure P/F 250 / 5000 P 36 250/5000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 8 AVG. 1850 3O0O ! P 1500 P minutes 31 sec. minutes 43 sec. X Remote: X Psig. Number of Failures 0 Test Time 4 Hours Number of valves tested 25 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 '11 I REMARKS: V?ry good test Distribution: odg-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: dohn H. Spauldmg F1-021L (Rev. 2/93) AWOLJWBD.XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David J.~o~:;~, Chairm~ Blair Wondzell ¢~,,~ P. I. Supervisor FROM: Bobby Foste~.~ SUBJECT: Petroleum Inspector DATE: FILE NO: October 15, 1994 AWOIJOBD.doc BOPE Test - Nabors 22E BPX - MPU - E-09 PTD # 94-0132 Milne Point Field Saturday, October 15, 1994: I traveled this date to BPX's MPU well E-09 being drilled by Nabors rig 22E and witnessed the initial BOPE test. As the attached AOGCC BOPE Test Report shows there were 3 failures. The ring gasket between the bottom pipe rams and the well head leaked; the HCR valve on the choke line leaked; a grease fitting on the manual choke line valve leaked. All of these items were repaired and retested. I arrived at the rig and the BOPE was not nippled up and I ask why. I was told by the company rep. that a" top job" had to be done because cement was not circulated to the top. The crew rigged up and a 150 Bk. slurry was pumped down the outside of the surface pipe and good cement was received at the surface. The location was clean and good access to the rig was aviable to all areas of the rig. The rig was clean and all equipment seemed to be in good working condition. Summary: ! witnessed the BOPE test on Nabors 22E on BPX's MPU well E-09 - test time 5 hours - 3 failures. ~,... Attachment: AWOIJOBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9.625" Test: Initial X Workover: DATE: 10/15/94 NABORS Rig No. 22E PTD # 94-0132 Rig Ph.# 659-6475/76 BPX Rep.: DONNIE LUTRICK E-O9 Rig Rep.: BRAIN BUSBY Set @ 2515' Location: Sec. 25 T. 13N R. IOE Meridian U Weekly Other Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Dri. Rig OK BOP STACK: Quan. Annular Preventer Pipe Rams Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Pressure P/F 300/3,000 P I 500/5,000 P P 500/5,000 P 500/5,000 P 500/5,000 F/P 500/5,000 P N/A MUD SYSTEM: Visual Alarm Trip Tank OK YES Pit Level Indicators OK YES Flow Indicator OK YES Meth Gas Detector OK YES H2S Gas Detector OK YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F I 500/5, O0O P CHOKE MANIFOLD: No. Valves 17 No. Flanges Manual Chokes Hydraulic Chokes I I 500/5,000 P I 500/5,000 P f 500/5,000 P Test Pressure P/F 500/5,000 P 42 500/5,000 P I P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: Functioned Functioned P 3,100 P 1,450 P minutes 34 minutes 56 YES Remote: 4~ 2000 4~, 1800 Psig. sec. sec. YES Number of Failures: 3 ,Test Time: 5.0 Hours. Number of valves tested 23 Repair or RePlaCement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-361)7 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Failures: 1)The flange below the bottom pipe rams leaked- tightened and tested OK. 2) The HCR on the choke line leaked- repaired- tested OK. 3) A grease tiffing leaked on the manual choke line valve leaked- tightened and held OK. Distribution: odg-Well File c- Oper./Rig c- Database c - Tdp Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Wrtnessed By: BOBBY D. FOSTER FI-021L (Rev. 7/19) AWOIJOBD.XLS WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 October 10, 1994 Adrian Clark, Drlg Engr Supv BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Company Permit # Surf Loc Btmhole Loc Milne Point Unit MPE-09 BP Exploration (Alaska) Inc 94-132 3731'NSL, 2029'WEL, Sec 25, T13N, R10E, UM 4298'NSL, 2293'WEL, Sec 32, T13N, R11E, UM Dear Mr Clark: 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 n the Nodh Slope pager at 659-3607. David W JohnsOn \ ~ ~ Chairman BY ORDER OF THE COMMISSION jo/encI c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - wlo encl .... STATE OF ALASKA -'-- ALASK. .)IL AND GAS CONSERVATION C~.,VlMISSION PERMIT TO DRILL 2O AAC 25.005 Re-Entry [] DeepenDI Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 54' feet Milne Point - Kuparuk River 3. Address 6. Property Designation Sands P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL~ ~ 1~.,~q~ / /¢/~_.. 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o ^^c 3731' NSL, 2029' WEL, SEC. 25, T13N, RIOE MIIne Point Unit At top of productive interval 8. Well number Number 4420' NSL, 2540' WEL, SEC. 32, T13N, R 11E MPE-09 2S 100302630-277 At total depth 9. Approximate spud date Amount 4298' NSL, 2293' WEL, SEC. 32, T13N, R11E 10/10/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD property line ADL 25516-1123' feet No close approach feet 2560 14193'MD/7102' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ,~,c 25.035 Kickoff depth ,~oo feet Maximum hole angle 6r o Maximum sudace 2860 psig At tolal depth (TVD) 698473560 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD M D ~ TVD (include stage data) 24" 20" 91.111 H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 401/ L-80 BTRC 3769' 31' 31' 3800' 3000' 748sx PF"E"/25Osx"G"/250sxPF"E" 8-1/2" 7" 26# L-80 NSCC 14163' 30' 30' 14193' 7102' 372 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary , Total depth' measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casingstructural Length Size Cemented Measured ;[~ EEl ~(~[~ertical depth Conductor Surface Intermediate C)CT -' G Production Liner /:;i;~.sk~ 0ii & Gas Cons. Commission Perforation depth: measured 'Anch°r""-':~: true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program ITl Drilling fluid progr2m [] Time vs de~oth pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. ! hereby'/~ ~ (-'~-----f-"'"~-~f~C~~g is true and correct to the best of my knowledge¢__.,/~//~ Signed Tit le Dr//ting Engineer Supervisor Date / Commission Use Only Permit Number IAPI number IApproval date _ ISee cover letter '~/---/'-/'/,.~2_., 150- 0.2- ?- .2,, 2.-,.~'//,_~ I / ¢-- /¢'"'- ,~/~/ If°r other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required, []YCs .IAI No Hydrogen sulfide measures [] Yes [] Nb Directional survey required [] Yes [] No Required working pressure for mOPE []2M; F-13M; ~5M; 1-11 OM; []15M; Other: Original Signed By by order of Approved by David W. Johnston Commissioner tne commission Dater-¢,[~,~/~,( Submit in triplicate Well Name: IMPE-09 I Well Plan Summary Type of Well (producer or injector): [ Kuparuk Producer Surface Location: Target Location: Bottom Hole Location' 3731 NSL 2029 WEL Sec 25 T13N R10E UM., AK. 4420 NSL 2540 WEL Sec 32 T13N R11E UM., AK. 4298 NSL 2293 WEL Sec 32 T13N.RllE UM., AK. [AFE Number: [ 330064 Estimated Start Date: [ 10/10/94 I MD: ] 14193 [ [ TVD' I Well Design (conventional, slimhole, etc.)' Rig: ]Nabors 22-E [ Operating days to complete: ] 12 17102' bkb I IKBE: I54' ] Milne Point Ultra Slimhole 7LS Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1900 1847 NA 7129 4314 Top of Schrader Bluff (West Sak) Sands OB 8043 4529 Seabee Shale 7799 4525 Base of the Schrader Bluff (West Sak) Sands HRZ 10048 6534 High Resistivity Streak Top Kup 13359 6774 Kuparuk Cap Rock Top C1 Sand--Target 13891 6984 Target Top B7 Sand 14043 7044 Total Depth 14193 7102 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 3769 31/31 3800/300( 8 1/2" 7" 26# L-80 nscc 14163 30/30 14193/710 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3550 psi is 2850 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface Intermediate Final MWD Directional Only N/A 1. Insert Bit to Seabee Top w/MWD GR/RES (CDR). - 2. PDC Bit f/Seabee to TD w/MWD Dir and LWD (GR/CDR/CDN). Cased Hole Logs: GR/CCL will be run in 7" casing to coincide with Wireline Perforating Operations without a Rig on the well. CBL run only if necessary. RECEIVED 0CT 6 1994 f-,.~as~a 0it & Gas Cons. Commission Anch0ra:j~ A GR/CCL Log will be obtained in the 7" casing in conjunction with WL Pcrforating. Mud Logging is not required. Mud Program: I Special design considerations [None- SPUD MUD Surface Mud Properties: ] Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 tO tO tO tO tO tO tO 9.6 90 35 15 30 10 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I None- LSND freshwater mud Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 tO tO tO tO tO tO tO 10.2 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file wi~ AOGCC. Directional: 1' KOP' 1400' IMaximum Hole Angle: Close Approach Well: 67 degrees (No Shut Ins) iRECEIVED OCT - 1994 Disposal' Cuttings Handling' CC2A A~aska Oil & Gas Cons, Commission Anch0ra,? Fluid Handling' All drilling and completion fluids can be annular injected. Otherwise, Haul to CC2A. Since the MPE-09 annulus will not be available for annular injection until after the 7" casing is cemented, all drilling fluids will be hauled to CC2A. Annular Injection' The MPE-09 annulus is permitted for drilling & completion fluid injection. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES ' (BBLS) (BBLS) Milne Point MPE-09 0 35,000 6/1/94 to , 12/31/94 FREEZE PROTECTION' Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annulus was injected into to avoid freezing. · 2. 3. 4. 5. , . , 10. 11. 12. 13. 14. 15. MPE-09 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. Prepare location for dg move. MIRU Nabors 22E ddlling dg. NU and test 20" Diverter system. Build Spud Mud. Ddll a 12-1/4" sudace hole and run and cement 9-5/8" casing. Run only Dir MWD (No LWD Required). ND 20" Diverter, NU and Test 13-5/8" BOPE. RIH w/Insed bit on Low Speed/High Torque Motor, and Directional MWD and LWD CDR (GR/RES). Test 9-5/8" casing to 3000 psig, Drill out float equipment and 10 feet of new formation, Pedorm a LOT (Do not exceed 12.5 ppg). " Drill ahead to the base of the Schrader Bluff (West Sack) into the Seabee Shale, CBU, Wiper Trip to the BHA, Circulate & Condition for Logging, POOH. LD the Insert Bit and Motor. Send Schrader Bluff Logs to town -- ASAP. MU a Hughes R417G PDC bit on a turbine, with Directional/Gamma Ray, Resistivity/Neutron/Density (Triple Combo) MWD/LWD tools. RIH. Mad Pass the O Sand Interval as outlined by the Geological review of the Schrader Bluff GR/RES Logs. Drill 8.5" hole to TD and Run and Cement 7" casing (2 Stage Cement Job to cover the Schrader Bluff). This hole section will be logged LWD with Triple Combo (G R/Res/Neu/Dens). RIH while PU 3-1/2" ddll pipe with 7" 264¢ bit and scraper. Ddll out ES Cementer, RIH to PBTD, displace the drilling mud out of the hole with source water, while performing a casing wash, filter source water to 2 micron absolute. POOH & PU Ddll Pipe Conveyed Perforating Guns. RIH and Set Packer. RU Nowcam and ROP pedorate the well. Kill well while circulating kill weight bdne. POOH laying down 3-1/2" Drill Pipe. ND mOPE, NU the False Bowl and Dry Hole Tree to Prepare Well for Running ESP with Coil Tubing at later date. · RDMO Nabors 22E drilling rig to drill next well. RECEIVED 0CT'-6 ]994 0il & Gas C0r~s. Commission Anch0m;~ MPE-09 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" SPACER' 75 bbls fresh water. CIRC, TEMP 50degFat2500'TVDSS. LEAD CEMENT TYPE' ADDITIVES: Retarder WEIGHT: 12.0 ppg gal/ak APPROX #SACKS: 748 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER' 11.63 THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE' ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg gal/ak APPROX #SACKS: 250 FLUID LOSS' 100-150 CC PremiUm G YIELD:1.15 ft3/sx MIX WATER: 5.0 THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Permafrost ADDITIVES' Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx gal/ak APPROX NO SACKS: 250 i,., MIX WATER: 11.63 CENTRALIZER PLACEMENT: 1. I Bowspring centralizer per joint of 9-5/8" casing on bottom 10 joints of casing (10 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Pedorm lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly--batch mixing is not necessary. CEMENT VOLUME' 1. The Tail Slurry volume is calculated to cover 500' md abUve the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry Volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 4. 80'md 9-5/8", 36# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. ~ [ E ~IV 7~! CEMENT MPE-09 PRODUCTION CASING PROGRAM- HAIJLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140o F BHST 170degFat7040'TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 197 FLUID LOSS: < 50cc/30 min @ 140° F MIX WATER: 5.0 galls THICKENING TIME:3 112- 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. · STAGE I! CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS CIRC. TEMP: 60°F BHST 80 deg F at 7040' TVDSS. SPACER: 75 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 fl3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: NONE THICKENING TIME: Greater than 4 hrs at 50,_~,F-~ ¢ F IV ~ D TAIL CEMENT TYPE: Premium G , ADDITIVES: 0.2% CFR-3, 0.2% Halad 344, 2.0% CaCI2 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk ,,~.?:~:..:,::t~. ()ii & Oas Cons. 6omrr,.issior~ Anchor.'. MIX WATER: 5.0 gal/sk APPROX Cf SACKS: 1 75 THICKENING TIME: 4 hours @ 50 FLUID LOSS: 100-150 cc FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 22 joints of 7" (40 total). This will cover 300' above the C Sand. 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 5600' - 4850' to cover the St Bluffs .Sands (23Total). 3. Run one 7"x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7"x 8-1/4"Straight Blade Rigid Centralizers needed is 64. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud progra ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to p~ job requirement. Displace at 8-10 bpm. Batch mixing is net necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 750' md above the C Sand with 30% excess. 2. Stage 2 cement volume is calcula'ed to cover from the OG base to the to 500' above the NA Top with 30% excess. IWELL PERMIT CHE( ADMINISTRATION ENGINEERING 1. Permi 2. Lease 3. Uniqu 4. Well 5. Well 6. Well 7. Suffi 8. If de 9. Opera 10. Opera 11. Permi 12. Permi 13. Can p ' GEOLOGY 14. Condu 15. Surfa 16. CMT v 17. CMT v 18. CMT w 19. Casin 20. Adequ 21. If a 22. Adeq~ 23. If di 24. Drill 25. BOPEs' 26. BOPE 27. Choke 28. Work 29. Is pr; APPR 30. 31. 32. 33. 34. Permi Data Seisn Seabe Conta GEOLOGY: HOW/jo - A:~FORMS~cheklist rev 03/94 BAy' Marker ldenti fi,'at ioq MD 5KB A) ~O O 0 8] K~/BU[I D 1/lO0 ,100 400 C] BUILD 1.5/I00 .... 600- 500 51 BUILD 2/100 900 899 E~ 8UILO 2.5/~00 1300 1292 F) CL~VE 2.5/~00 3DflO ~83 G) END 2.5/~00 CURVE 36~5 29~1 R] ........l ~DOEI ....... 13893 6984 l~ TO i4193 7']02 DR'I LL I NG GROUP ....... r' --: :-- SEC, IN INCLN 0 a .00 0 O.OO 3 ...... 2 (~0... 25 6.50 96 14.5B iiti 59.00 1503 1~6.75 · 1 ~026 66.75 t1302 66.75 Anadr/ ]] Soh]umberger MPE-O9 (PLO) VE tT IC L SECTION TVD Scale.' I inch : i500 feet [Oep Scale,' 1 inch = 1500 feel :Drawn ' 09/29/94 0 750 ' ' i50[~ ?250" 3000 ·3750 4500 .5250 ..6000. .67~ .... 7500 B250 9000 9750 10500 1 t250 12000 12750 . . Section Departure ...... (~n~or,)l Icl9t HnEO~JIJIO B1.52 i:29 I:N 1) -0 I Cd I -n m Z C3 m Fn WELL PERMIT CHECKLIST COMPA.NY ~/~ GEOL ~ ~ ? 0 UN~# PROGRAM: exp [] dev~ redrll [] serv [] //3~ ~ o~/o~ s~o~ ~n3 ADMINISTRATION 1. 3. 4. 5. 6. · 7. 8. 9. 10. 11. 12. 13. Permit fee attached .................. Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary.. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ....... ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ,~ N 16. CMT vol adequate to circulate on conductor & surf csg. .? N 17. CMT vol adequate to tie-in long string to surf csg . . . 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip llst adequate .~ N 25. BOPEs adequate ................ _ ..... 26. BOPE press rating adequate; test to ~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N~ 29. Is presence of H2S gas probable ............. Y GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y ~ 31. Data presented on potential overpressure zones ..... Y /N 32. Seismic analysis 9f shallow gas zones .......... V N 33. Seabed condition survey (if off-shore) ......... ~ N 34. Contact name/phone for weekly progress reports .... / Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISS ION: Comments/Instructions: HOW4o - A%FORMS~cheklist rev 03/94 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, informati;3n 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. SEQUENTIAL REEL NO. SEQUENTIAL FILE NO. WELL # 001: MP E-09A DEPTHS : 13587.000 TO 15000.000 FT OUTPUT TO : RAWDATA.TIF 1'*** LIS WRITE **** ~/l~ CURVES OUTPUT FROM PETCOM DATABASE TO LIS IMAGE : PETCOM OUTPUT CURVE CURVE UNITS DEPTH DEPT FT GR100 GR10 AAPI ROP100 ROP1 FT/H RPX100 RPX1 OHMM RPS100 RPS1 0HMM RPM100 RPM1 OHMM RPD100 RPD1 OHMM FET100 FET1 HOUR GR200 GR20 AAPI ROP200 ROP2 FT/H RPX200 RPX2 OHMM RPS200 RPS2 OHMM RPM200 RPM2 OHMM RPD200 RPD2 OHMM FET200 FET2 HOUR SEQUENTIAL REEL NO. 1 SEQUENTIAL FILE NO. 1 WELL # 001: MP E-09A **** LIS WRITE **** DEPTHS : 13587.000 TO 15000.000 FT OUTPUT TO : MPE09A.TIF CURVES OUTPUT FROM PETCOM DATABASE TO LIS IMAGE : PETCOM OUTPUT CURVE CURVE UNITS DEPTH DEPT FT SFXE FET HOUR SGRC GR AAPI SEXP RPX OHMM SESP RPS OHMM SEMP RPM OHMM SEDP RPD OHMM SROP ROP FT/H * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION (ALASKA) INC. WELL NAME : MPE-09 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292251300 REFERENCE NO : 98224 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE · 98/05/13 ORIGIN : FLIC REEL NAME : 98224 CONTINUATION # : PREVIOUS REEL : COGENT : BP EXPLORATION, MPE-9, MILNE POINT, API# 50-029-22513-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE · 98/05/13 ORIGIN · FLIC TAPE NAME : 98224 CONTINUATION # : 1 PREVIOUS TAPE : COR~4ENT : BP EXPLORATION, MPE-9, MILNE POINT, API# 50-029-22513-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MPE- 09 API NUMBER: 500292251300 OPERATOR: BP EXPLORATION (ALASKA) INC. LOGGING COMPANY: WESTERN ATLAS TAPE CREATION DATE: 13-MAY-98 JOB NUMBER: 98224 LOGGING ENGINEER: D CAIN OPERATOR WITNESS: H THACKERAY SURFACE LOCATION SECTION: 25 TOWNSHIP: 13N RANGE: 10E FNL: FSL: 3731 FEL : FWL: 2029 ELEVATION (FT FROM MSL O) KELLY BUSHING: 54. O0 DERRICK FLOOR: GROUND LEVEL: 24. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 000 13739.0 29. O0 2ND STRING 5. 000 14565. 0 15. O0 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: GR RUN NUFiBER : PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. 88888.0 14286.5 14281.0 14278.0 14274.5 14273.5 14267.5 14264.5 14264.0 14254.5 14253.5 14246.5 14244.5 14243.0 14239.5 14238.5 14228.5 14226.0 14224.5 14214.0 14213.0 14203.5 14202.0 14200.0 14195.0 14186.0 14182.0 14173.5 14172.0 14169.0 14165.0 14164.0 14156.0 14154.0 14146.0 14144.0 14140.5 14138.5 14135.5 14130.5 14129.0 14124.0 14123.5 14113.0 14111.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88889.0 88889.5 14275.5 14273.5 14269.0 14265.0 14254.0 14245.5 14243.5 14240.0 14231.0 14228.0 14216.5 14205.0 14202.5 14201.5 14191.0 14184.0 14173.5 14172.0 14167.0 14156.5 14153.5 14147.5 14145.0 14141.0 14139.0 14132.0 14131.0 14125.0 14113.5 14288.0 14281.5 14279.0 14275.5 14265.0 14253.5 14246.0 14243.5 14240.5 14227.5 14214.5 14205.0 14195.5 14175.5 14166.5 14141.0 14132.5 14124.5 14113.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 14108.5 14107.0 14106.5 14098.0 14096.0 14092.5 14091.5 14088.0 14078.0 14077.0 14073.0 14070.5 14058.0 14055.0 14050.0 14045.5 14043.5 14041.0 14037.5 14034.5 14031.5 14028.5 14024.0 14023.5 14022.0 14016.0 14009.0 14008.5 13999.0 13994.5 13994.0 13990.0 13982 5 13981 5 13978 5 13977 0 13974 0 13970 0 13967 5 13967 0 13965.0 13960.5 13955.5 100.0 $ REMARKS: 14108.0 14106.0 14097.0 14093.5 14089.0 14078.5 14072.0 14059.5 14056.5 14051.0 14046.5 14041.5 14039.5 14033.5 14032.5 14024.0 14023.0 14016.0 14010.0 13999.5 13994.5 13992.0 13982.0 13976.5 13973.5 13970.0 13965.0 13961.5 13960.0 13956.0 100.5 14108.0 14096.5 14093.5 14079.0 14072.0 14043.5 14030.0 14024. 0 14008.5 13996.0 13982.0 13976.5 13965.5 98.0 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON BP EXPLORATION'S MPE-09 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS GAM~A RAY, ALSO BASE PASS #1 SIGMA AND THE BCS GAffff4A RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. THIS DATA WAS LOGGED BY WESTERN ATLAS AND PROCESSED BY SCHLUMBERGER. $ $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~BER : 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE StC4MARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 14281 . 0 13954 . 5 TDTP 14296.5 13952.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NTJMBER : .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 1 1 1 4 68 0000000000 DEPT FT 189771 SCMA PDK CU 189771 O0 000 O0 0 1 1 1 4 68 0000000000 RATO PDK 189771 O0 000 O0 0 1 1 1 4 68 0000000000 MSD PDK CU 189771 O0 000 O0 0 1 1 1 4 68 0000000000 BKS PDK CPS 189771 O0 000 O0 0 1 1 1 4 68 0000000000 BKL PDK CPS 189771 O0 000 O0 0 1 1 1 4 68 0000000000 SS PDK CPS 189771 O0 000 O0 0 1 1 1 4 68 0000000000 LS PDK CPS 189771 O0 000 O0 0 1 1 1 4 68 0000000000 RICS PDK DIM 189771 O0 000 O0 0 1 1 1 4 68 0000000000 RIN PDK DIM 189771 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH PDK GAPI 189771 O0 000 O0 0 1 1 1 4 68 0000000000 TENS PDK LB 189771 O0 000 O0 0 1 1 1 4 68 0000000000 CCL PDK V 189771 O0 000 O0 0 1 1 1 4 68 0000000000 RBOR PDK 189771 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 14296.500 SCMA.PDK 27,994 RATO.PDK 24.716 MSD.PDK BKS.PDK 233.661 BKL.PDK 108.989 SS.PDK 26397.547 LS.PDK RICS.PDK 18.883 RIN. PDK 11.826 GRCH. PDK -999.250 TENS,PDK CCL.PDK 300.000 RBOR.PDK 1.727 DEPT. 13952.000 SGMA.PDK 41.073 RATO. PDK 30.764 MSD.PDK BKS.PDK 308.627 BKL.PDK 147.559 SS.PDK 18850.914 LS.PDK RICS.PDK 22.548 RIN. PDK 12,457 GRCH. PDK -999.250 TENS,PDK CCL.PDK 0.000 RBOR.PDK 1.771 0.594 1067.658 189.133 O. 499 616. 990 31.182 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE · 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SOT4MARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 14218.5 13940.0 TDTP 14233.0 13937.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 14225.0 14221.0 14211.5 14206.5 14204 5 14201 5 14198 5 14195 0 14193 5 14187 0 .......... EQUIVALENT UNSHIFTED DEPTH GRCH TDTP .............. 88891.5 88891.0 14208.0 14205.0 14201.5 14197.0 14228.0 14224.5 14215.0 14208.0 14195.5 14188.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: 14182.0 14183.0 14173.5 14175.5 14166.5 14168.5 14164.0 14166.5 14160.0 14162.0 14158.5 14161.0 14154.5 14157.0 14140.5 14141.5 14136.0 14138.0 14130.0 14132.0 14129.5 14132.5 14129.0 14131.0 14126.5 14127.5 14124.0 14124.5 14121.0 14125.5 14117.5 14120.5 14114.0 14116.0 14113.0 14116.5 14111.0 14113.5 14107.0 14108.0 14105.0 14105.5 14095.5 14095.5 14085.5 14087.0 14083.5 14084.5 14079.5 14079.0 14073.5 14073.0 14070.0 14072.5 14067.5 14066.5 14067.0 14068.0 14062.5 14061.5 14059.5 14059.0 14055.5 14056.5 14053.0 14053.0 14049.0 14049.0 14044.5 14043.5 14044.0 14047.0 14038.0 14039.5 14035.5 14036.0 14032.0 14032.5 14031.5 14032.5 14029.0 14030.0 14025.5 14024.0 14023.5 14023.0 14023.0 14023.0 14013.5 14016.0 14009.0 14010.0 14008.5 14008.5 14007.0 14005.0 14000.0 13999.5 13995.0 13996.0 13993.5 13992.0 13990.0 13991.5 13989.0 13986.5 13984.5 13984.5 13982.5 13982.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: 13981.0 13980.5 13979.0 13976.5 13976.5 13976.5 13973.5 13973.0 13967.5 13965.5 13967.0 13965.5 13960.5 13960.0 13960.0 13957.5 13956.0 13956.0 100.0 100.0 97.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP DOWN PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH DOWN PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA DOWN PASS #1 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189771 O0 000 O0 0 2 1 1 4 68 0000000000 SGMA PDK CU 189771 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~I CODE (HEX) RATO PDK 189771 O0 000 O0 0 2 1 1 4 68 0000000000 MSD PDK CU 189771 O0 000 O0 0 2 1 1 4 68 0000000000 BKS PDK CPS 189771 O0 000 O0 0 2 1 1 4 68 0000000000 BKL PDK CPS 189771 O0 000 O0 0 2 1 1 4 68 0000000000 SS PDK CPS 189771 O0 000 O0 0 2 1 1 4 68 0000000000 LS PDK CPS 189771 O0 000 O0 0 2 1 1 4 68 0000000000 RICS PDK DIM 189771 O0 000 O0 0 2 1 1 4 68 0000000000 RIN PDK DIM 189771 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH PDK GAPI 189771 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PDK LB 189771 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PDK V 189771 O0 000 O0 0 2 1 1 4 68 0000000000 RBOR PDK 189771 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 14233.000 SGMA.PDK 30.391 RATO.PDK 29.941 MSD.PDK BKS.PDK 5916.094 BKL.PDK 4516.074 SS.PDK 23132.824 LS.PDK RICS.PDK 20.287 RIN. PDK 12.350 GRCH. PDK -999.250 TENS.PDK CCL.PDK 400.000 RBOR.PDK 1.727 DEPT. 13937.500 SGMA.PDK 43.212 RATO. PDK 37.967 MSD.PDK BKS.PDK 5311.129 BKL.PDK 1950.636 SS.PDK 17973.098 LS.PDK RICS.PDK 23.971 RIN. PDK 12.988 GRCH. PDK -999.250 TENS.PDK CCL.PDK 189.750 RBOR.PDK 1.827 0.575 767.049 -500.000 1. 285 467. 482 -272. 634 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 98/05/13 M_AX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: 10 FILE HEADER FILE NOMBER: 3 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCRE~iENT 0.5000 PASSES INCLUDED IN AVERAGE LDWC TOOL CODE PASS NUMBERS 1, TDTP $ REMARKS: THIS FILE CONTAINS EDITED BASE PASS #1. NO AVERAGE WAS CALCULATED BECAUSE THE OTHER PASS IS A DOWN PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEP? FT 189771 O0 000 O0 0 3 1 1 4 68 0000000000 SGMA PNAV CU 189771 O0 000 O0 0 3 1 1 4 68 0000000000 RATO PNAV 189771 O0 000 O0 0 3 1 1 4 68 0000000000 MSD PNAV CU 189771 O0 000 O0 0 3 1 1 4 68 0000000000 BKS PDK CPS 189771 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: 11 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BKL PDK CPS 189771 O0 000 O0 0 3 1 1 4 68 0000000000 SS PNAV CPS 189771 O0 000 O0 0 3 1 1 4 68 0000000000 LS PNAV CPS 189771 O0 000 O0 0 3 1 1 4 68 0000000000 RICS PNAV DIM 189771 O0 000 O0 0 3 1 1 4 68 0000000000 RIN PNAV DIM 189771 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH PDK GAPI 189771 O0 000 O0 0 3 1 1 4 68 0000000000 RBOR PNAV 189771 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 14296.500 SGMA.PNAV 27.994 RATO. PNAV 24.716 MSD. PNAV BKS.PDK 233.661 BKL.PDK 108.989 SS. PNAV 26397.547 LS.PNAV RICS.PNAV 18.883 RIN. PNAV 11.826 GRCH. PDK -999.250 RBOR.PNAV DEPT. 13952.000 SGMA.PNAV 41.073 RATO. PNAV 30.764 MSD.PNAV BKS.PDK 308.627 BKL.PDK 147.559 SS.PNAV 18850.914 LS.PNAV RICS.PNAV 22.548 RIN. PNAV 12.457 GRCH. PDK -999.250 RBOR.PNAV O. 594 1067. 658 1. 727 O. 499 616. 990 1. 771 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NIIMBER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: 12 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SO?4MARY VENDOR TOOL CODE START DEPTH PDK 14303.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY PDK THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL STOP DEPTH .......... 13943.5 TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 20-APR-98 JO01 1503 20-APR-98 14520.0 14502.0 13954.0 14295.0 900.0 TOOL NUMBER 2725XA 79712 14565.0 PRODUCED THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNTRATE SCALES SET BY FIELD ENGINEER LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: 13 FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0 30 0 30 REMARKS: LOG CORRELATED TO GAMMA RAY (03-DEC-94) 2 3/4" ROLLER WHEELS RUN ABOVEAND BELOW TOOL STRING THIS FILE CONTAINS THE RAW DATA FOR MAIN PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189771 O0 000 O0 0 4 1 1 4 68 0000000000 SGMA PS1 SU 189771 O0 000 O0 0 4 1 1 4 68 0000000000 RATO PS1 189771 O0 000 O0 0 4 1 1 4 68 0000000000 MSD PS1 SU 189771 O0 000 O0 0 4 1 1 4 68 0000000000 BKS PS1 CPS 189771 O0 000 O0 0 4 1 1 4 68 0000000000 BKL PSl CPS 189771 O0 000 O0 0 4 1 1 4 68 0000000000 SS PS1 CPS 189771 O0 000 O0 0 4 1 1 4 68 0000000000 LS PS1 CPS 189771 O0 000 O0 0 4 1 1 4 68 0000000000 RICS PS1 DIM 189771 O0 000 O0 0 4 1 1 4 68 0000000000 RIN PS1 DIM 189771 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: 14 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUNB SAMP ELEM CODE (HEX) GR PS1 API 189771 O0 000 O0 0 4 1 1 4 68 0000000000 TEN PS1 LBF 189771 O0 000 O0 0 4 1 1 4 68 0000000000 CCL PS1 V 189771 O0 000 O0 0 4 1 1 4 68 0000000000 SPD PS1 FPM 189771 O0 000 O0 0 4 1 1 4 68 0000000000 G1 PS1 CPS 189771 O0 000 O0 0 4 1 1 4 68 0000000000 G2 PS1 CPS 189771 O0 000 O0 0 4 1 1 4 68 0000000000 MON PS1 CPS 189771 O0 000 O0 0 4 1 1 4 68 0000000000 CSS PS1 API 189771 O0 000 O0 0 4 1 1 4 68 0000000000 ISS PS1 CPS 189771 O0 000 O0 0 4 1 1 4 68 0000000000 RBOR PS1 189771 O0 000 O0 0 4 1 1 4 68 0000000000 SGNT PS1 189771 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 14303.000 SG?rLA.PS1 0.000 RATO.PS1 0.000 MSD.PS1 BKS.PS1 0.000 BKL.PS1 0.000 SS.PSI 0.000 LS.PS1 RICS.PS1 0.000 RIN. PS1 5.000 GR.PS1 0.000 TEN. PSi CCL.PS1 300.000 SPD.PS1 0.000 Gl.PSi 0.000 G2.PS1 MON. PS1 0.000 CSS.PS1 0.000 ISS.PS1 0.000 RBOR.PS1 SGNT. PSl 0.000 DEPT. 13943.500 SGMA.PS1 41.310 RATO.PS1 29.968 MSD.PS1 BKS.PS1 263.010 BKL.PS1 120.736 SS.PSI 18108.156 LS.PS1 RICS.PSi 23.109 RIN. PS1 12.454 GR.PS1 64.899 TEN. PSi CCL.PS1 0.000 SPD.PS1 899.910 Gl. PS1 2130.161 G2.PS1 MON. PS1 2247.716 CSS.PS1 13386.000 ISS.PS1 309333.625 RBOR.PS1 SGNT. PS1 61.310 0.000 0.000 -500.000 0.000 -1.000 0.600 603.939 44.581 196.852 1.774 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE · 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: 15 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O . 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 13908.0 14235.5 PDK $ LOG HEADER DATA DATE LOGGED: 20 -APR - 98 SOFTWARE VERSION: JO01 TIME LOGGER ON BOTTOM: 1503 20-APR-98 TD DRILLER (FT) : 14520.0 TD LOGGER (FT) : 14502.0 TOP LOG INTERVAL (FT) : 13954.0 BOTTOM LOG INTERVAL (FT) : 14295. 0 LOGGING SPEED (FPHR) : 900.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~ff~A RAY PDK THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : TOOL NUMBER 2725XA 79712 14565.0 PRODUCED LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: 16 FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 30 NEAR COUN~ RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30 TOOL STANDOFF (IN): REMARKS: LOG CORRELATED TO GAMMA RAY (03-DEC-94) 2 3/4" ROLLER WHEELS RUN ABOVE AND BELOW TOOL STRING THIS FILE CONTAINS THE RAW DATA FOR DOWN PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: 17 ** SET TYPE- CHAN ** N~a2~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189771 O0 000 O0 0 5 1 1 4 68 0000000000 SGMA PS2 SU 189771 O0 000 O0 0 5 1 1 4 68 0000000000 RATO PS2 189771 O0 000 O0 0 5 1 1 4 68 0000000000 MSD PS2 SU 189771 O0 000 O0 0 5 1 1 4 68 0000000000 BKS PS2 CPS 189771 O0 000 O0 0 5 1 1 4 68 0000000000 BKL PS2 CPS 189771 O0 000 O0 0 5 1 1 4 68 0000000000 SS PS2 CPS 189771 O0 000 O0 0 5 1 1 4 68 0000000000 LS PS2 CPS 189771 O0 000 O0 0 5 1 1 4 68 0000000000 RICS PS2 DIM 189771 O0 000 O0 0 5 1 1 4 68 0000000000 RIN PS2 DIM 189771 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS2 API 189771 O0 000 O0 0 5 1 1 4 68 0000000000 TEN PS2 LBF 189771 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS2 V 189771 O0 000 O0 0 5 1 1 4 68 0000000000 SPD PS2 FPM 189771 O0 000 O0 0 5 1 1 4 68 0000000000 G1 PS2 CPS 189771 O0 000 O0 0 5 1 1 4 68 0000000000 G2 PS2 CPS 189771 O0 000 O0 0 5 1 1 4 68 0000000000 MON PS2 CPS 189771 O0 000 O0 0 5 1 1 4 68 0000000000 CSS PS2 API 189771 O0 000 O0 0 5 1 1 4 68 0000000000 ISS PS2 CPS 189771 O0 000 O0 0 5 1 1 4 68 0000000000 RBOR PS2 189771 O0 000 O0 0 5 1 1 4 68 0000000000 SGNT PS2 189771 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 13908.000 SGMA.PS2 0.000 RATO. PS2 0.000 MSD.PS2 BKS.PS2 0.000 BICL.PS2 0.000 SS.PS2 0.000 LS.PS2 RICS.PS2 0.000 RIN. PS2 5.000 GR.PS2 0.000 TEN. PS2 CCL.PS2 1000.000 SPD.PS2 0.000 Gl.PS2 0.000 G2.PS2 MON. PS2 0.000 CSS.PS2 0.000 ISS.PS2 0.000 RBOR.PS2 SGNT. PS2 0.000 DEPT. 14235.500 SGMA.PS2 35.746 RATO. PS2 0.000 MSD.PS2 BKS.PS2 5775.324 BKL.PS2 0.000 SS.PS2 21658.480 LS.PS2 RICS.PS2 21.344 RIN. PS2 5.000 GR.PS2 0.000 TEN. PS2 CCL.PS2 400.000 SPD.PS2 0.000 Gl.PS2 3461.809 G2.PS2 MON. PS2 2218.334 CSS.PS2 15159.063 ISS.PS2 323561.938 RBOR.PS2 SGNT.PS2 45.321 0.000 0.000 -500.000 0.000 -1.000 1.238 0.000 -500.000 220.731 1.752 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 12:29 PAGE: 18 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/05/13 ORIGIN : FLIC TAPE NAME : 98224 CONTINUATION # : 1 PREVIOUS TAPE : CO~ff4~TT : BP EXPLORATION, MPE-9, MILNE POINT, API# 50-029-22513-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/05/13 ORIGIN : FLIC REEL NAME : 98224 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, MPE-9, MILNE POINT, API# 50-029-22513-00 IS Tet, e Ver~f~¢mt, fon l,istIno chlUn-herqe~ ~,]e,~Ka Co~'~:utipc~ CenLer 995 13: 2,i 5o020225.130 1, BP g×b'lora t'. ior'~ SCHht, itkP, it:/RGER ~Ebf, SERVICES 950C~5 25 i 3 1 () E 3'13 1. 2 0 2 q 5 4,. () 0 PAGEI P A 6 E; D ~' P ~" ~ ..[ F, C R E: H k.: i'~ T: O, S u f) 0 S CI.![tVE., 8H.I'FT D~T.~ (,'4E?:iSt.~RE';[) D~',t:T!.]) IS Tar, e Ver~.fi. catJor', l,.~..st'in~ ct-,J, urr, herc!~,r A.I. aSKa Co~'.~'urinc~' Center 2 q'-~:~'~ N- 19o5 i[3'..24 PAGE '~ *., ...... ~;--;; ............... ..-.;.-...~. ...... ----~;;-.--..;. o o, 0 0 I :1 6 2 000000 6,0 006 O0 0 1 'I. 1 4 68 O00000OO00 O0 (')00 O0 0 1 1 1 4 68 0000000000 00 0 U 0 ~) 0 0 I ] 1. 4 68 0000000000 21,,.800 22.800 42.600 60,400 73.900 87,100 79.600 IS ~ene ~erification I,.i. st. iDq chlur,,~.eroer ~lesk. a Corrput. lno Center 2.9-14t.~-1995 t3:~4 PAGE: 171.700 R 1~,: ~, L, ' '171 f"l. 6 13755,0 .I. O' 6 0 0 . 0 1.3695.0 54.2 72.6 .'.[,~ ~'ar.e Veri:f:.i. cat.t, on chlur:,her~.~er ~]a~ia Com!,;'.uti. nq Cent. eF $ t',; EIIT P U ~,.t ;,,,ATR iX f I f~ I,,,, ~ C ('ii F~ R F: C T [ ('i i~ ( T r,,i ); I ,ii 500 LS~!D 0,009 O.O0O 0.0 0,0 '.I, 66 0 2 65 0 3 7 .it 3 ~ 73 ~ ?a~e ~'erifJ. cat. J. on c~lUa'~be~oer Alaska Co:r~p~.~t.j..ng Ce~teF 995 1B; 24 PAGg: mmmmm~mm~mmmmmmmmm{mm#mmmmmmmm · 'Ti.': [) F P T , l, .6 2. '7 0 i) R (] P E. R h W 6 (.~ 2 0, q: 0 0 12000,0 O (} G R. R h i),; 14.8.000 R PE.R~,,i -g99.250 GR.Ct3R -999.250 GR.M¢ID 12.1.00 R () P g. ,t'.~ ~4 D 2t.8u0 ROPE.NWI4 79.000 GR.COR 49.100 GR.MWD 22. 200 POPE. MWD 22. SO0 ROPE.I~WH b3. 700 GR.C014 52.1 C) O GR. NWD 7 1.. 1, 0 0 R 0 P E;. :~,~ w 0 42.600 R 0 P ,E. ]'4 W H 108. 700 GE:. COR 67. 600 GR. !U:WD 1, ~'~:. 4. ? (,} 0 R (:} P E. r,:'t: ~.~,I [) 60.4 00 R 0 P .,E. M W H !.i~ 400 GR.tJJN 73,700 GR N~[, 8 0.80 (:) ~ 0 P E',. ~'4 ~4 i.:) 87. :t. 00 R 0 P E. M w 1:4 -999.250 21,800 1,53.400 22.800 162.700 42.600 211,.200 60.400 1.48.000 73.900 230.00 0 87.. 100 ChlU'~,ber~er ,~.Iasi<a C(;rri.:~.~tJ.r~ Cent. er 2 n. ,.~ .,h. P - 'l 9 q 5' i .3 ,.', 2 ! PAGE: -5 ,I_0 C;k',Cf!k 40 U 600 31..200 ]7~1 .700 G R . ~ W D 202.000 79.606 97.400 !.71.700 ~.!PE-09 ST.!.., 50-029-22513-01 50-029-225 1. 3-0 i, RECEIVED FEB 02 1995 Alaska Oil & Gas Cons. Commission Anchorage ******************************* ~:~DO~!GN : ~,}ORTH SLOPE BOROUGH APl ~,~{J?,4~)~ : 50-029-22513 31-JA:',i- 1995 t5:55 PAGE: 5002922513 B.~. g×ploration SCHLti~BEPGER ~!EbL SERVICES b]."Y P,'~?! i BIT RUr'~ 2 STT RUN 3 St, Amour St, APour St. Arno,Jr 'L ~)':i' P I C F~ L t) T R I C K P Y R 0 N 25 373~ 2029 2~.30 PAGE: snl~ted and c.l. ip~ed curves: all bit ru~s merged. FOe .......... Fg~.IIVAX,E~T UMSHIFTMD DEPTH---------- 31-JA.~-1995 I5155 APl AP1 AP1 AP1 FIbE NUMB NUMB SIZE REPR PROCESS LOG TYP~ CbAS8 NOD ~.,:U~B SAMP ELE~4 CODE (HEX) ;~ ; J ~8 oooj' ,',) o o 0. 0 1 I 4 0 0 0 0 0 0 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 211. ' '*~ . '-on .... .~995 .!5:55 PAGE{ 137.~6a 34.700 122.~50 ROP.plWD 3.007 DER.~WD 2.529 DRHO.~WD 42.400 210.6~G POP. FtWD 5.207 D E R. ~,.~', w, D 2.437 ~i3.600 122,352 ROP.i~WO 6.308 DER.i'4WD 2,485 BRHO.~WD 36.400 1'16.983 ROP.~4wD 5.372 DER.MWD 2.497 DRHO,i~WD 3~.200 i87.0Ol ROP.MWO 2.3~6 DER.~WO 2.372 DRHO.k~O 3~.900 106,32~ ROP.~WO 3,281 DER,p~wD 2,385 DRHO.M;qO 30.000 3,276 DER.~WO 2.44.3 DRHO,MWD 33.800 97.2i~ ROP.~WD 3.!86 DER.~WD 2.360 DRRO,dWD 92,970 ROP.i~WD 2,923 DER,~4~D 2.392 [)RHO,~WD 37.700 ~7,282 ROP.~WD 2,283 DRHD.<WD 38.0O0 32.666 FET.MWD 2.740 VRA,~WD 0.035 PEF,~wD 92.624 FET.~WD 2.727 VRA.WWD 0.052 PEF.MWD 112.493 FET.M~D 3,947 VRI.~WD 0,050 PEF.~O 119.205 FET.MWD 5.839 VRA.~D 0.050 PEF.MWD 185.526 FET.M~D 5.009 VRA.M~D 0,047 PEF.~WD 191. 243 FET.~D 2:257 VRA.~WD 0,047 PEF.~WD 282,48~ FET.~D 3,279 VRA.MWD 0.051 PEF,MWD 219 994 FET.MWD 3!261 VR.h.MWD 0 044 PEF.~D 251,039 FET.~D 3 278 02064 PgF'~D 1.49 99! FET.MWD 2:836 VRA.~WD 23~.513 FET,MWD 2.765 VRA,~WD 0,08,4 PEF.MWD 2.458 2,515 2.991 0.892 2,065 3.956 0.486 2,964 3.927 0 685 3,272 964 3,790 ]606 004 3,3 ! 3 0.603 142 3.1 15 0.312 3'058 2,767 o'==. '788 ~,998 0.516 2' 778 2,713 c~lumberq!~r Alaska 3!-dA~t-190,5 1..5:55 PAGE: ~2.953 2.694 2.416 35.~00 -999.750 19.630 -999.250-999.250 -999.250 2.a43 -999.250-~99.250 -999.250 4.00R -999.250-999.250 -999.250 19.193 -999.250-999.250 -999.250 5.476 -999.250-999.250 -999.250 5.744 -999.2b0-e9~.25o -999.250 7.155 -999.250-999.250 -999.250 9.673 -999.250-999.250 -999.25o -999.250 -999.250 [)ER. DRHL~. fqwD ROP. i4WD DER MWD DRHO. MWD ROP.MWD .~.~Wl) DRHO,MWD RDP.~WD DFR.MWD DRHO.MWD ' p MW[) RO,.. , D[:R. MWD DRNO.~WD RD P. DFR. ~4WD P R H 0. ~ W D RUP. MND D g R. ~q W D DRHO. MWP ROP.MWD DER.;~WD DRNO,MWD ROP.NWD DER,~WD 227.837 2,720 0.064 -999.250 19.586 -999.250 -999.250 2.425 -999.250 -999 250 3:976 -999.250 -999.250 18.552 -999,250 -999,250 5.448 -999.250 -999.250 5 t~ 30 -9992250 -999.250 7.044 -999.:250 =999,250 -999 50 :999,250 999,250 -999.250 FET.NWD WET.~WD VRh. MwD PEF.~wD FET.MWD PEF..wD FET.~WD VRA.~WD PFF.~WD FET.MWD VRA.MWD PEF.MWD FET.~WD VRA.~D PEF.MwD FET,~WD VRA.mWD PEF.~WD FET.~D VRA.~WD PEF.~WD FET.MWD VRA.MWD PEF.~WD FET.~ND VRA,MWD PEF,MWD 0.653 2.704 2.893 0.452 t9.907 -999.250 0.103 2.568 -999.250 0.303 4,336 -999.250 0 400 23i190 -999 250 O. 253: 7' 006 -999,250 0 ,13 0 5' 944 -999. 250 ,285 ,297 -999.250 0,302 9,65! '999,250 ' 999,250 'ggg,250 -999.250 ChlUmber(~er A.]aS~a C,gmc,.;tt, r'..r.'~ center 3!-dA~-1995 15:5'3 PAGE= S~RV[C~ ~ P[~TC V ER S'[ r3 h.~ : nO'COt D~TF : ~5!01t]1 FILE I'Y P~5 : MAD Si~l~ted aha clip.e(! curves; all ~.~AD runs mer~ea usinn earliest passes. S T ,~ R T O. ~: P T H DEPTH ';;;[';'"1 . MERGE BASE I$ Tar:e ~el:i.[i. car. Ic..n LJsttna 15:55 PAGEI AP1 hP .P ~PT ~1 ~ NUM~ NU SIZE RE ROCES$ LO(; 7YPR CLASS ~OD ~UM8 SAMP EbEM CODE [HEX) ........................ r" ....... '"'" ..... o c)O0 O0 0 2 ! 4 68 O0 000000 90 000 O0 o 2 1 1 4 68 0000000000 oo o00 O0 0 2 1 1 4 68 0000000000 90 000 oo o 2 I 1 4 68 0000000000 ~)n O0o O0 0 2 1 1 4 68 0000000000 O0 00o O0 0 2 i t 4 68 0000000000 OO cO0 O0 0 2 I 1, 4 68 0000000000 O0 cOO O0 0 2 1 1 4 68 0000000000 ~099.250 ROP.aAO 989.98~ RA.MAD -qgq 250 v R A. ~:,IA~. -999.~50 VRP.MAD 124.3i4 ROP.MAD 999,250 RA,MAD -999. 250 -999.250 999.,250 I8 g'a~e \~r{ticat.io,-~ chlUm~,erger Alasv,~ Co~'c~,.~i:~.r~¢~ Center 15:55 PAGE: E'..DITEI> ~,,',.{P PASSF5 [~e~t.b, st'~,l, ft. ed and c].Jp~e~"! curves ior each t~ass of each rlln i1~ separate files, STOP DEPTH ....~ c.,~ ;7~'" .......... V;OUIVALE~,;T U~SHIFTED Df]PTH ....... --- 1S Tar, e YerJ(icatJon t.;istin<~ chlu,berc.~r i:~:!.as~:.a Co:,~P~t~t,,<! Cet~ter 31-J~-~ 995 15:55 ....... APl ~7 .... I FII,E. ~ii.,M~ ........NUMB '''''''''''''''''''''''IZ REPR pR C ChAS8 ~iO'D NUMB SAMP ELE~4 CODE (HEX) DFp'r. I<~81,9.5(;o GR. !,45D -999.250 R[,IP. aAD 989 982 RA.MAD ~999,250 999,250 IS ~ane '":~rffi~cation ;~istino 15;55 PAGE: 10 Curves and loc, heaaer data ilor each bit run in separate f, iles. DEPTH 7820.5 I g - 0 C T - 9 4 FAST 2.5 ¥4,0C NE~ORY 7820.5 3758.0 7772.5 64.~ 68,3 C 0 R I$ ~,'ar~e t"eri, ticat~on I,j. SLJr~n chlu,n~ere~.r r~].asKa ¢:omp~t~no Center' 31-JAN-1995 I5;55 :'.": A 'r P I ",( 8.500 3813.0 b ,fi ki i) 9.30 4,2.0 !40.0 2,77(.) SA~!DSTONE 2.65 8.500 1,000 Res To mit.: 47.78 Drilled Interval.: 3834' to 7820' CDR only !o~n~ too], in BH~ th~s run, Data from DowDhol~ so{tware V4.0C S 74.0 PAGE: 11 ~6 0 73 28 ¢5 ¢~ 0,5 65 FT 66 36 I~ 'Tape verfficati, or~ r..istl,~:,,: Jl-jAN-1995 15;55 PAGE: 12 ; ........ ;'~"r ......... ;';; ..... ~"~ .... ;~[;'";~'[ ...... Og TYPF CLASS ~[)D NUMB SA~P ELEM CODE (HEX) ; .............. ~ ........ ; ....... .--.; ............... ~;--o-- Ouooo 4 , I 68 00o0 o000 O gO0 O0 (~ 4 ~ ~ 4 68 0000000000 0 aO0 90 C 4 1 1 4 68 0000000000 o oO0 O0 (~ 4 1 ] 4 68 0000000000 0 OoO O0 (; 4 1 1 4 68 0000000000 0 ~Oe 00 0 4 1 1 4 68 OOO0000000 a OeO O0 C 4 1 I 4 68 0000000000 mmmimmm~mimmm~mm~mmmmmmmmmmmmmmmmimmmmmmmmmmmmmmmmm#mmmm~mm 99. 250 ROPE. b'Wl, 101.122 TAB. -99o 250 DER,hW1 999.250 55.210 ROPE.bW1 425.923 TAB.I,W! 19.630 [)ER.LWi 19.586 53.795 ROPE,LWl 263 662 TAB.LW1 2 443 DER, LW 1. 2~425 75.764 ROPE.LWi 160.353 TAB.LWI 4. 008 I:)ER. bWl 3. 976 29.900 "P~, . RO.,E LWi ~27 635 TAB D....R. 1 t g. ! 9.3 E b W ~3.273 ROPE.bWI 403.207 TAB,LWl 5.476 DER, f~,'~' 1 5,448 ~.559 ~OPE.~.,WI: 609 371 TAB.LW! 5.744 DER.bwI 5 830 b2 .49:~ Rr]PE,LWi 490 B94 TAB LWI , ~ , ,. ,.., .. ~ · 7 155 DE R ~ W ......... .~, ! 7 ~ 044 -999.250 0.452 o'~,o~ 0,30~ 0,400 0,253 0,:I30 0.285 IS ta~e '~erifJ, catfor~, [~iStina :t, 5:55 '~2.210 aOPM.LWl 12.733 -999.?50 848.239 9.600 -999.250 -999.250 TAB.!,W1 PAGE: 13 0,302 -999.250 SERVICE ~ ~LIC oA'r~ : qS/O.t/31 NAX RFC 8~Z,F; : !C~24: FI.' bP tYPE header data 2 0. for V ERS I Ot'.'~: F: ?, ~ !,,-, T ! ~< f,< ): bit run in separate STOP DEPTH 7669.5 22-0CT-94 FAST 2,5 V4,0C 13583.0 7732.5 files. cblumher<ier A!.as<a Com?dri,.~ :'eh[er 31-dAN-!.995 15:55 PAGE." 14 13426.0 82 65,4 67,9 TOOL NUMBER ~,iDS 22 ,n.~4TL!.,ER5 Cr<~Sl;,~(; r';i:/;~!'H 8,500 3813.0 [, S N D 1,0,20 42.0 t, 40,0 2,540 SANDSTONE 2.65 8,500 1 · 000 ****~,:******** Rt,i~:~ 2 ************************ To ~it: 56.8P ft Gr 'T'o aj,.t: 67,30 ft To ¢it: 1,2<t.49 ft k, eUt To Bit: ~.31.47 ft, ~>rlled Tr~t, erva!: 7820 To 13583 ft ass J:r':~terval: !,C, 6.33 To 10760 ft i:ass made 3~ hotlrs after hole originally drilled ~ro~."~ do,,~'nr~o,l,,e memory Do~nhole soft~,,are V4.(~C 90.0 15:55 PAGE: FT O0 _ 0 I. 1 4 68 0000000 O0 G~P] Oa 000 O0 0 5 3. 1 4 68 0000000000 F/H~ O0 00o O0 0 5 t 1 4 68 0000000000 h~ O0 000 O0 0 5 ! ~ 4 68 0000000000 ?~ O0 000 Oo 0 5 I 1 4 68 0000000000 o ~i ~'~ ~: 00 000 00 0 5 I 1 4 68 0000000000 0 ~'~ ~ ~,~ 00 000 00 0 5 ! ! 4 68 0000000000 (:} H ~, ~ 00 000 o 0 0 5 ! 1, 4 68 0000000000 G/C3 On 000 O0 0 5 1 I 4 68 0000000000 P~ oo Ouo O0 o 5 ] I 4 68 0000000000 G/C3 O0 00o O0 o 5 ! I 4 68 0000000000 ~>~/F: UO 000 O0 0 5 ] t 4 68 0000000000 l~,~ O0 000 O0 0 5 1 t 4 68 0000000000 P~ O0 000 O0 0 5 ~ 1 4 68 0000000000 15 D~PT . 135 f~ 3. <.;i.]' L; <~ F:. L t~,.: 2 -99q 25C; ROiP g. L~'~ 2 57.935 TAB.LW2 -Q~':~ ~5~:' A'r?.L~':~2 'q96'250 PAP.LW2 -999 250 DER,LW2 999:,:250 999.,~50 -999, 50 I$ Tape .t 1 -dA?,~-l. 9~5 15:55 122.85(? nOPg.bW2 2.~i? PSR.Lw2 7.400 014HO, UW2 42.4c'0 210.666 PUPE. b. W2 3.005 PSR.bW2 l?.9UO D~NO.bW2 1.22.352 ROPE.LW2 4.585 PSR,bW2 I¢~.000 DRNO.UW2 36.400 176.9U3 ROPE.BW2 3.880 PSR.bW2 g.2OO D~HO.LW2 38.20O 187.0~! ROPE.Lw2 2.~35 PSR.bW2 16.9u0 DRMO.LW2 IU6.323 ~OPE.Lw2 3.277 PSR.I~W2 i6,~00 DNHO.bW2 30.000 ti0.686 ROPE.LW2 3.234 PSR.bW2 i2.500 DRMO.hW2 33.800 97.218 ROPB.LN2 3.483 PSR,BW2 17.600 DRNO,bW2 38.800 92,970 ROPB,BW2 2.704 PSR,bW2 15.700 DRHO,LW2 37.700 87.2~2 POPE.LW2 2,768 PSR.bW2 22.200 DRRO.LW2 32.666 TAB.LW2 2.808 OER.LW2 -999.250 PEF.Lw2 92.624 TAB.!,w2 3.007 DER.I, W2 0.052 PEF.LW2 2 493 TAB.LW2 15:207 OgR.[,~2 0.050 PES.bW2 !i9.205 TAB.LW2 6.308 OE~.I, W2 0.050 PEF.LW2 185 526 TAB.IW2 5~372 DER.[.,W2 0.047 PEF.L!W2 191.24t TAB.LW2 2 346 DER.LW2 0~047 PEF.I,,W2 281.48~ TAB.LW2 .281 DER.bW2 0.051 PEF.LW2 219.99.4 TAB bW2 3.276 DER]bW2 0.044 PEF.LW2 251.039 TAB.bW2 3.186 DER.bW2 0.064 PEF.LW2 !49.991 TAB.LW2 2.923 DER.LW2 0.045 PEF'bW2 238.513 TAB,bW2 2.763 DER,LW2 0.084 PEF.LW2 PAGE: 1.6 2.458 2.740 -999.250 0.892 2.727 3.956 0.486 3,947 3.927 0,685 5,839 3,272 0.531 5.009 3.790 0.~06 2, 57 3,313 0,603 3,279 3.001 0.654 3,26 I. 3,115 0" 3.2 .8 2"767 o. 8224 2. 36 2.998 0.516 2.765 2.713 3~-J~.r,~-t995 15:55 PAGE: 17 d2.953 ROP~t. Lw2 i4.20o DRHr..Lw2 35.~00 227.837 2.694 0.064 TAB.[.,W2 PEF.I, W2 0.653 2.,720 2,893 -999.250 -999.250 -999.250 3 ~,'). S 0 O 0 each 1393~, 0 bit: r~p in separate STOP DEPTH ,134, e9. 13404.5 24'0CT-94 files. IS Taoe '~erif~cat!on ChlU:rbero,~r ~]dSKa CO~Uti. nq Center 3,!-JaN-t995 15:55 F~,ST 2.5 V4,0C MEN!O~Y 13938.0 !3404,~ 113893 80 ~4.~ 65,4 r3RTL~,EPS CA?;I'~,C D!~Pl'tl (FT): LSND 10.30 48.0 30 145,0 2,310 1,840 O,OOO 8!.0 68.0 0.0 SANDSTONE 2,65 8,500 E:.,~;P F'RF:(')U.i},.',t,:~CY (ii?:): 1,000 *****:*g*****~* RUN 3 *********************** ~es to !!~it: 44.92 £t Gr To ~lt: 55.34 ft Oei~ ?o ~{it: 1~2.5S ft i',teut TO Bit: ~19,56 ~t Drll, ed Interval: !.3583 TO 13938 ft :,~ell kicked at 13938 ft ~ 22:23 OCT-24. Fa.ise~ ~'~ ~t. ~r'o~ !~.3 to 1.1 ~/~al circulated ,,,at this depth for 50,7 9rs De,ore TrJ..pvinO, iinable to ori]! past !393~ due to hole'~ondltions L~ata ~rom dowmhole memory Ooxni~ole so(tware V4.0C $ PAGE: 1.8 IS 'ra~e \~eriti. cat!t~ 31 -JA~.~-.1995 15:55 PAGE: 19 · - 7"'P CC"~i~,h: V tXLUK ii,i~ ii ~i, ~I i~ ii. ,i~ ,I, Ii ii ii Ii ail ,,i ii I~ ,il ~ .i t,,, ii ii ,it ~Ii ii -i iii ,ii ,ii ........................... 7; ........ ; .............. ;- ................ . ..... . .... ...;.. DEPq'~,, ~;"'r 0"0~ n 0 6 1,. 4 68 00000000 0 IS Ta~e Ver-ific~l~Cion i,istJr~a chlur,.ber<:j~r AI. sSK~ ~or.,~':utip.': Center 995 !5:55 PAGE~ 20 42.056 -999.250 -999.250 -999.250 2.901 0.035 -999.250 -999.250 -999.250 TAB.LW3 DER !.,W3 PEF:LW3 TAB.LW3 DER.LW3 PEF.LW3 TAB.LW3 PEF.LW3 -999.250 -999.250 -999.250 -999.250 2,791 2,991 -99 250 -99 250 001 0510t/31 ii 0. e~ch ~ass Of each 8 T C P L) ~; p T i4 T'";7 .... 0 6.3 0 run in separate files, IS Tat-e Verification l~iSt,i:~ chlU~,herqar ~.].ask,,,a co:~:,]t~r~a Cente~ 31 -JA.~.~-1995 15:55 PAGE: 21 23-~CT-94 wlS£ 2.5 V4.1)C !0760.o 67.5 6~.9 Cr~gE T091: TYPE TOOL NUMBER o & bF:r.jSI'TY POk NOS 22 pt:~,aS~ a A~p R~SISTiVITt ~GS 22 C.I$Z~'.~G DEPTH (FT): 3913,0 (i,b/G}: 10,20 Y ( S ): 42,0 C ~ J: (OH~.~,:;~) AT T~ ~p~I~ATURE ~r) EGF): SA N DS TONE D ~':l ?'.,' 8 .T T Y: 2,65 TO ~:~it: 1~4.49 ft Neut To k~lt: 13~.47 Prlled Ir~terva!: 78~b To ~3583 Pass Interval: 10633 To !C760 ~:;~ass ~ade 3~ hours aiter hole 90.0 Oo'^a~,~ie soft-are V4.OC 15:55 PAGE: 22 C, OO O0 0 7 :1 t 4 68 0000000000 000 O0 0 7 ,1 I 4 68 0000000000 000 O0 O 7 1 1 4 68 0000000000 900 U 0 0 7 ,1 I 4 68 0000000000 300 O0 0 7 1 1, 4 68 0000000000 0 o 0 00 t) 7 1 1 4 68 0000000000 ROPE,MOl 989,982 ATR.~D1 -999.250 CblO:~ercer A!as~a Co~-~,ut~.no ~'emter 3~-JAN-1995 15:55 PAGE~ 2] ~24.344 POP~,MDI -999.250 ATP.~D1 -999.250 TAPE : ? i~ t C ?"! A ?~ E: C 0 ::",i ~ I r'~ ti r~ T .T i) ~~ ~ : 1 : gF:' (,.XPl'.F::~ATJ[,'q..'?'.i (~,[;~8KA), W:PE-09, MILNE POINT, IPI 50-029-22513 * ALASKA COMPUTING CENTER , ****************************** *------- SCHLUMBERGER -------* ****************************** COMPANY NAME : BP EXPLORATION W~hb NAME FIELD NAME ~ NIl, NE POINT BOROUG}~ : NORTH SLOPE STATE : ALASKA API NU~BE~ : 50-029-22513-01 REFERENCE NO : 95095 RECEIVED IS Tape Verification l,istlnq chlumberger AlasKa Co~puting Center 29-MAR-!995 13124 **** REEl, HEADER **** SERVICE NAME I EDIT DATE : 95/03/29 ORIGIN : FLIC REEL NA~E : g5095 CONTINUATION # : PREVIOUS REEL : COM~ENT : BP EXPI.ORATION, MILNE POINT, MPE-09 ST1, 50-029-225!3-01 **** TAPE HE~DER **** SERVICE NAME : EDIT DATF : 95/03/29 ORIGIN : FLIC TAPE NAME : 95095 CONTINUATION ~ : 1 PREVIOUS TAPE : COM"ENT : BP EXPI.ORATION, MILNE POINT, MPE-09 ST1, 50-029-22513-01 TAPE HEADER MILNE POINT MWD/MAD LOGS AP1 NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: #0 J.B DATA LOGGING ENGINEER: OPERATOR WETNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: ESL: FWL: ELEVATION(FT FRO~ ESL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: W~,~I,~[, CASing RECORD BIT RUN 95095 STRING MPE-09 500292251301 BP ExPloration SCHLUMBERGER WELL SERVICES 29-MAR-95 BIT RUN 2 BIT RUN 3 25 3731. 2029 54 O0 51oo OPE~! HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH 12,125 9.625 3813,0 8.500 PAGE{ IS Tame Verlflcatlon Listimq chlumberqer Alaska Computlnq Center STRING PROD~CTIO~ STRING PE~ARKS: SHIFTS **** FILE ~EADER **** FILE MA~E : EDIT .001 SERVICE : FLIC YERSION : 001CO! DATE : 95/03/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 29-~AR-~.995 13:~4 PAGE~ F!LF HEADER FILF NUMBER: EDITED ~ERGED lpped curves; all bit runs merged, Depth shifted and c D~PTH' I~CREMENT: . 0 50O0 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH WD 1369 ,0 1.0600.0 BASELINE CURVE FOR S~IFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------,-E~UIVALENT UNSHIFTED DEPTH---.------- ~ASELINE DEPTH · $ NE~GED DATA SOURCE LDWG TOOL CODE ~E~ARKS: NO DEPTH SHIFTS APPLIED, $ LIS FORMAT DATA BIT RUM NO, MERG.~ TDP BASE ~ERGE' IS TaPe Verification Listino cblumberger Alaska Computin6 Cen ter 2g-MAR-1995 13:24 PAGE~ ** DATA FORMAT SP£CIFICATIO ** SET TYPE - 64E 4 66 11 66 12 68 13 66 14 65 15 66 16 66 0 66 RECORD ** CODE AL E 0 0 16 1 0.5 FT 6~ 0 FT 68 1 O ** SET M~ SERV U T ID DEPT FT GRRW MWD AAPI GRIN MWD AAPI TYPE - CHAN ** ,-.--.---,,-..-.-......---........,.................................. ERVICE I AP1 AP1 ApI FILE .UMB NUMB SIZE REPR PROCESs ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 i 1 I 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 I 1 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 I i 1 4 68 0000000000 ** DATA ** DEPT. 13755.000 GRRW.NWD -g99.~50 GRIN.MWD -ggg,~50 ROP,MWD DEPT. 13500.000 GRRW.~WD I53,400 GRIN,MWD 153,400 ROP,~WD D~PT, 13000,000 GRRW,MWD 162,700 GRIN,MWD 162,700 ROP,NWD DEPT. 12500.00G GRR~.~WD 211.200 GRIN,MWD 211.200 ROP.~WD DEPT. 12000.000 GRR~.~WO 148.000 GRIN.MWD 148.000 ROD,END DEPT.. 11.500.000 GRRW.I~WD 230.000 GRIN.MWD 230.000 ROP.MWD D~PT. llO00.OOO GRRM'.~WD 202.000 GRIN.MWD 202.:000 ROP,MWD 21',800 22.800 42,600 60,400 73.900 87.100 79,600 IS Tame Vertflcatlon Listing chlumberger Alaska Computinq Center 2g-MAR-l. 995 13:~4 PAGE: DEPT. 10600.000 GRRW.MWD 97.400 GRIN.MWD 97.400 ROP.MWD 171.700 DATA FILE NAME : EDIT .001 SERVICE : FLIC VERSION : DATE : ~AX REC SIZE : FILE TYPE : LO LAST FILE : FILE NA~E : EDIT .002 SERVICE : FLIC V~RSION : DATE : 95/03/~9 MAX REC SIZE : ~024 FIL~ TYPE : LO LAST FILE : FILE HEADER FIL~ NUMBER 2 RAW Curves and lo~ header data ~or each bit run in separate ~lles. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH :"~'· D ....... '''''' ''''~, 375. .... $ LOG HEADER DATA ~ATE BOGGED: SOFTWARE: SURFACE SOFTWARE VERSIOn: DOWNHOLE SOFTWARE VERSION: DATA TYPE (NE~ORY or REAL-TI~E): TD DRILLER (FT): TOP LOG !NTERYA5 (ET): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RP~): MOLE INCLINATION {DEG) MINIMUM ANGLE: STOP DEPTH 10600.0 !B-NOV-94 REAL'TIME 13755.0 0600.0 3695,0 64.8 72.6 0°0 0'0 0'0 000'0 000'0 000°0 O'EISE 00§'8 a3~WflN 900~ :(ZH) ADN21'IO3~ :(N!) ~OQNVi~ rIoo& :(NI) NOIZD3~O0 ~QOH :A£I~N3Q XI~iVN 900£ : 3~fii~3dN3i DNOI£VqflD~ID X~W ~V :(~dd) S~OI~OqH3 Oli~ :Hd :(S) I&ISODSIA OflW :~dA& dflW SNOI~IQNOD 3'iOH3~OU :(Z~) H&d3O DNISYD SHM~qI~O dX& (NO&&O~ O& dO$) DNI~£S IS Tame Verification Listino chlumberger Alaska Computlno Center 29-MAR-1995 13:24 PAGE~ 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 ! DEPT G~ RAW GR COR GR MWD G R ~ W H ROPE RAW ROPF MUD ROPE MwH VDEP MWD ** SET TYPE - CHAM ** ~ .......... UNIT SER''~''''''''';''''''''E AP1 A API .... AP1F!L'''~ .... NUMB''''''''''~;~'''~;;'''''''''''''PROCESS D ORDER # bOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ------------------------------------------------------------------------------FT O0 000 0 0 2 ! ! 4 68 000000000 000 O0 0 2 1 ! 4 68 0000000000 CPS O0 CPS O0 000 O0 0 2 1 I 4 68 0000000000 AAPI O0 000 O0 0 2 1 I 4 68 0000000000 AAPI 00 000 O0 0 2 1 1 4 68 0000000000 F/HR O0 000 O0 0 2 1 1 4 68 0000000000 F/HR O0 000 O0 0 2 I 1 4 68 0000000000 F/HR O0 000 00 0 2 1 1 4 68 0000000000 ET O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA DEPT. GR, MWH VDEP,M~D DEPT, GR,MWH VDEP,NWD DEPT, VDEP.~D DEPT. G~,MWH VDEP,MWD DEPT, G~,MWH ~DEP,MWD DEPT, G~ YDEP,MWD 13755 000 GR.R~W -999,250 GR,COR -999. 250 GR,MWD '999i2506886300 ROPE,RAW 12,100 ROP~i,MW:D 21.',800 ROPE,~WH 13500-000 GR.RAW 79,000 GR,COR 49 ~00 GR.MWD 153o400 ROPE'RAW 22,200 ROPE,~WD 22: O0 ROPE,MWH 6787,700 13000,000 GR.RAW 83.700 GR,COR 52 100 GR,MWD 1.62700 ROPE,RAW 71'i00 ROPE,MWD 42:600 ROPE,MWH 6 ,2o: 12500,000 21!.200 6434.601 !2000,000 i48.000 6229.50O 230.000 60.43.601 GR,RAW 108.700 GR,COR 67600 GR,MWD ROPY'RAW 144'200 ROPE,MWD 60',400 ROPE,MWH GR,RAW 76.200 GR,COR 47,400 .GR.~WD ROPE*RAW 82.000 ROPE,MWD 73':900 ROPE,MWH GR,RAW !18.400 GR,COR 73,700 GR,MWD ROPE,RAW 80,800 ROPE*MWD B7'100 ROPE,MWH '999.,250 2i ,800 40 0 162 ,.7 O0 42.600 21 !', :200 60.400 3*900 230,000 87,100 IS Tame Verification 5ist~nO chlu~berger AlasKa Computing Center 2g-~AR-~.9g5 13:24 PAGE{ DEPT. 11000.000 GR.RAW GP.~wH 202.000 R{]PE.RA~ VDEP.MWD 5851.800 DEPT. 10600.000 GR.RAb GR.~wH g7.400 ROPE.RA~ VDEP.MWD 55.400 GR.COR 82.500 ROPE.MWD 50.100 GR.COR 174.400 ROPE.MWD 34.400 GR,MWD 79.600 ROPE.~WH 31.200 GR.MND 202.000 79.600 97.400 171,700 **** FILE TRAILER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 95/03/29 M~X REC SIZE : ~024 F!LF TYPE : bO LAST FILE : **** TAPE TRAILER SERVICE NAME : EDIT DATF : 95/03/29 O~IGIN : FLIC TAPE NAME : 95095 CONTINUATION # : ~ PREVIOUS TAPE : CO~E~T : ~P E×PLORATION, MILNE POINT, MPE-09 ST1, 50-029-225~3'01 **** REEL TRAILER **** SERVICE NANM : EDIT DATE : 95/03/29 ORIGIN : FLIC REEL NAME : 95095 CONTINUATION ~ : PREVIOUS REEL : COMMENT : :BP EXPLORATION, ~ILNE POINT, MPE-O9 ST)., 50-029-22513-01
