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200-097
STATE OF ALASKA WELLeLASKA OIL AND GAS CONSERVATION COMMI MPLETION OR RECOMPLETION REPO AND LOG F. . C 1a. Well Status: Oil ❑ Gas 0 SPLUG 0 Other 0 Abandoned IO ' Suspended 0 lb.Well Class: DD 20AAC 25.105 20AAC 25.110 Develolp ‘t i ®cp*�C7iy ❑ GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero • Service ❑ Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Pe, i o s •i= undry BP Exploration(Alaska),Inc 11/21/2017 200-097 • 317-420 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 8/19/2000 50-029-22772-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number 8/20/2000 PBU H-37A• Surface: 3261'FSL,1265'FEL,Sec.21,T11N,R13E,UM ' 9 Ref Elevations KB 75.48 • 17. Field/Pool(s): Top of Productive Interval: 121'FNL,4586'FEL,Sec.28,T11N,R13E,UM GL 45.10 • BF 46.64 • PRUDHOE BAY,PRUDHOE OIL Total Depth: 659'FNL,281'FEL,Sec.29,T11N,R13E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: • 10520'/8919' • ADL 028284.028287&028288 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface:x- 643340. y- 5958770 - Zone - ASP 4 . 11760'/9156' • 74-064 TPI: x- 640091 y- 5955326 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 639128 y- 5954770 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No ® 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) • 11565'/9052' - 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 94# H-40 31' 111' 31' 111' 30" 260 sx Arctic Set(Approx.) 9-5/8" 40# L-80 31' 3775' ' 31' 3635' 12-1/4" 1800 sx CS III,400 sx Class'G' 7" 26# L-80 28' 10460' 28' 8886' 8-1/2" 493 sx Class'G' 4-1/2" 12.6# L-80 10425' 11565'' 8868' 9052 6" 142 sx Class'G' 2-7/8" 6.16# L-80 11440' 11760' 9029' 9156' 3-3/4" Uncemented Slotted Liner 24. Open to production or injection? Yes 0 No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#L-80 10290' 10192'/8752' 4-1/2"12.6#L-80 10393'-10410' 10393'/8853' pc.6., a W,� 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. -------7--7"-- ----- `'�n' Was hydraulic fracturing used during completion? n ( Per 20 AAC 25.283(i)(2)attach electronic and printed Yes 0 No D • ���� � j1r 1r r�# ! 1111.,,1��" information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED u..-- 10530' Set Whipstock Packer 10520' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size Gas-Oil Ratio: Test Period .i..i. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corn): Press 24 Hour Rate �► Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only V7 - /Z/Z 1 i i. -/O , RB a3 �" --v ri n 2Q17 G ,./.5-.7t, 28. CORE DATA • Conventional Core(s) Yes ❑ No I -• Sidewall Cores Yes 0 No i If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Permafrost-Top Well Tested? Yes 0 No F Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 10562' 8941 separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit-Zone 4 10562' 8941' Kicked off from Parent Well 11565' 9052' (H-37) 11739' 9140' CGL-Zone 3 Formation at total depth: Zone 3 11739' 9140' 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka,Joseph N Contact Name: Browning,Zachary H Authorized Title: Info and Dap C tilK.6 Iter Contact Email: Zachary.Browning©bp.com Authorized Signature: : (STRUCTIO Contact Phone: +1 907 564 5220 INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and ND for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • • Daily Report of Well Operations H-37A ACTIVITYDATE SUMMARY ***WSR continued from 06-22-17*** (LRS Unit 70 -Assist Slickline: Load &Test) MIT-IA***PASSED***to 2654 psi, Max Applied Pressure = 2750 psi, Target Pressure = 2500 psi. Pressured IA to 2740 psi with 2 bbls crude. IA lost 72 psi in 1st 15 minutes and 14 psi in 2nd 15 minutes, for a total loss of 86 psi during 30 minute test. Bled IA to 400 psi, returned —2 bbls. MIT-OA***PASSED***to 1104 psi, Max Applied Pressure = 1200 psi, Target Pressure= 1080 psi. Pressured OA to 1180 psi with 4.9 bbls crude. OA lost 58 psi in 1st 15 minutes and 18 psi in 2nd 15 minutes, for a total loss of 76 psi during 30 minute test. Bled OA to 10 psi, 6/23/2017 S-line on well on departure. WV=Closed. SV, SSV, MV=Open. CV=OTG. ***CONTINUED FROM 06-23-17 WSR*** SET 4-1/2"XX PLUG IN X-NIPPLE @ 10,278' MD LRS PERFORMED PASSING MIT-IA LRS PERFORMED PASSING MIT-OA EQUALIZED AND PULLED 4-1/2"XX PLUG FROM 10,278' MD DRIFTED TO 10,453' SLM W/20' x 3.70" DUMMY WHIPSTOCK(unable to get deeper) DRIFTED TO DEVIATION @ 10,637' SLM W/20' x 2-7/8" DUMMY GUNS CURRENTLY RIH W HES CALIPER 6/23/2017 ***CONTINUED ON 06-24-17 WSR*** ***CONTINUED FROM 06-23-17 WSR*** RAN HES 40 ARM CALIPER FROM 10,615' SLM TO 9,520' SLM (good data) 6/24/2017 ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** T/I/O= 0/0/0 WELL HOUSE SUBSIDENCE. Removed WH. Pulled Floor Kit. Did dirt work (placed and compacted 15 yards of gravel) to bring floor back to grade. Set floor kit. Set 8/6/2017 WH. RDMO. ***Job Complete*** FWHP 0/0/0 CTU#8 1.75" CT. Job Scope: Set Whipstock MIRU CTU. Bullhead 135 bbls 1% KCL. RIH w/ HES 2-7/8" Logging Carrier& Baker Dummy Whipstock BHA. Tag at 10721' (deeper than target depth). Appears we were pushing something in the hole. Log from 10700'to 9600'. Flagged pipe at 10500'. Pooh. Tie- in to PDS Coil Flag dated 25-Jan-03. (-15' correction). RIH and set snap latch with female receptacle and 45 KB Whipstock Packer with Mid Element at 10533'. Pooh. Pulled heavy from 10423' and hung up at WLEG @ 10286', unable to pull through. Drop down, pump down coil to no avail. Finally managed to pass through after a few attempts and holding pipe in tension. Drug heavy for another 300' in the tubing when it looked as whatever was dragging let go. Pooh. Top of Whipstock Pkr= 10530.0' /Middle Element Depth= 10533.9'/ Btm of Pkr= 10538.4'. 11/5/2017 **Continued on 11/06/17** • • Daily Report of Well Operations H-37A CTU#8 1.75" CT. Job Scope: Set Whipstock OOH with setting tool and caliper BHA. Breakdown tools. HES memory caliper showed orientation of whipstock anchor at 96* ROHS. MU Baker 3-5/8"Venturi with 3.67" Mule Shoe Btm. Dry drift clean down to Flag. Puh back up into Tbg Tail with no issues. RIH back down to Flag. Correct depth to bottom of Venturi. Venturi below the open lateral down to -10' above the Whipstock Packer. Did not want to tag packer so we do not potentially bend the orienting guide. Make 2 reciprocations. Pooh. Venturi empty- nothing recovered. MU & RIH w/ Baker Whipstock with 45KB ML Snap Latch. Correct depth at Flag. Sting into Packer at 10530'. Repeat multiple times to confirm whipstock is stung in. Launch 1/2" ball & release from Whipstock. Pooh. Well is Freeze Protected with 38 bbls 60/40 Methanol. At surface tools look good. Rig Down CTU. Top of Whipstock Tray at 10519.77'. Whipstock RA Tag at 10528.77'. 11/6/2017 ***Job Complete*** T/I/O=Vac/50/150. Pre CDR2. Set 4" "H"TWC#430 at 125". LTT Passed. PT TWC to 3500 psi. Pass. PT Tree cap to 500 psi. ***Job Complete*** See log. Final WHP's TWC/50/150. 11/7/2017 T/I/O=TWC/0/0 R/D 4" production tree, R/U 4" CDR 2 Tree. Installed upper work platform. 11/10/2017 FWP's TWC/0/0 see log for details. T/I/O = TWC/130/70. Temp= SI. Bleed IAP, OAP. (Pre-rig). IA FL = near surface, OA FL = @ surface. Pad expansion, dirt work ongoing at this time, unable to bleed due to heavy equipment operation. Well house, production riser, flow line, SSV removed. 11/14/2017 SV, WV= C. MV= O. IA, OA= OTG. 02:10 T/I/O = TWC/110/110. Temp = SI. Bleed IA&OA to 0 psi. (Pre-Rig). IA FL = near 11/16/2017 surface, OA FL @ Surface. Bled OAP from 110 psi to 0 psi in 1 hour. Continued on WSR Continued from WSR 11-16-17. T/I/O = TWC/110/110. Temp = SI. Bleed IA&OA to 0 psi. (Pre-Rig). IA FL = near surface, OA FL @ Surface. Bled OAP from 110 psi to 0 psi in 1 hour. Bled IAP to 0+ in 30 minutes, hold open bleed for 1 hour. No change in WHP's during 1 hour monitor. Final WHP's = TWC/0/0. 11/17/2017 SV, WV, WV= C. MV= O. IA, OA= OTG. 02:10 T/I/0 = TWC/0/20. Temp = SI. WHP's. (Pre-rig). No change in IAP, OAP increased 20 psi in 2 days. 11/19/2017 SV, WV, WV= C. MV= O. IA, OA= OTG. 02:30 • • North America-ALASKA-BP Page 1 of,' Operation Summary Report Common Well Name:H-37 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/19/2017 End Date: 11/25/2017 X3-018P1-C:(2,304,000 00) Project:Prudhoe Bay Site:PB H Pad Rig Name/No.:CDR-2 I Spud Date/Time:7/3/1997 12:00:00AM Rig Release:11/29/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000444 Active datum:KB @75.48usft(above Mean Sea Level) Date I From-To 1 Hrs 1 Task 1 Code NPT Total Depth Phase Description of Operations (hr) i (usft) 11/19/2017 13.30 - 17:30 4.00 RIGD P I I PRE CONDUCTING RIG DOWN OPERATIONS ON R-28 AFTER SECURING AND LEAK-TIGHT TESTING THE TREE CAP TO SECURE THE I I WELL -COMPLETE RIG DOWN CHECKLIST FOR RIG MOVE PROCEDURE CONDUCT PHASE 3 NOTIFICATION AFTER I I DRILL ANNOUNCEMENT OVER HARMONY RADIO SYSTEM. PROVIDE INFORMATION TO SENIOR WELL SITE LEADER GREG SARBER. 17:30 - 21:30 4.00 RIGD P PRE I CONDUCT PJSM FOR PULLING OFF WELL WITH PEAK AND NABORS CREW. I DISCUSS USE OF STOP BLOCK,STOP COMMAND AND SPOTTER POSITIONS. I PULL BOTH MODULES OFF WELL. INSTALL JEEPS FOR ROAD TRAVEL. MOVE BOTH MODULES TO H-PAD. I STAGE DRILLING SUB ON PAD,REMOVE _ I JEEP. 21:30 - 00:00 2.50 RIGD P FIRE PJSM FOR PULLING OVER THE WELL WITH NABORS AND PEAK CREWS. DISCUSS 2 FT RULE,STOP THE JOB AUTHORITYAND MITIGATIONS FOR COLD WEATHER OPS. PULL DRILLING SUB OVER THE WELL AND j I SET IT DOWN. *** RIG ACCEPTED 23:00 *** I I CREW CHANGE AND PJSM WITH ONCOMING CREW FOR SPOTTING MUD MODULE. 11/20/2017 00:00 - 04:30 4.50 RIGD I P PRE SPOT MUD MODULE IN POSITION AND SET IT DOWN. START RIG UP CHECKLIST. HOOK UP INTERCONNECT LINES. 1 I HOOK UP MPD LINE. LEAK TIGHT TEST SWAB AND MASTER VALVES. HOOK UP OAAND IA SENSORS. SPOT AUXILIARY EQUIPMENT. I REMOVE TREE CAP. 04:30 - 08:00 3.50 BOPSUR P ' I PRE �PJSM FOR INSTALLING BOPS. I -NU BOP,ENERGIZE AND FUNCTION TEST -FILL STACK,ENSURE LINES ARE FLUID PACKED,BODY TEST BOP Printed 12/4/2017 10.52:40AM *AII depths reported in Drillers Depths* IIINorth America ALASKA BP • Page 2 Or Operation Summary Report Common Well Name:H-37 AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:11/19/2017 I End Date:11/25/2017 1X3-018P1-C:(2,304,000.00) I I 1 Project:Prudhoe Bay I Site:PB H Pad • Rig Name/No.:CDR-2 i Spud Date/Time:7/3/1997 12:00:00AM I Rig Release:11/29/2017 Rig Contractor.NABORS ALASKA DRILLING INC. I BPUOI:USA00000444 Active datum:KB e!75.48usft(above Mean Sea Level) Date I From-To i Hrs Task Code NPT Total Depth Phase Description of Operations ± (hr) (usft) 08:00 - 14:00 I 6.00 BOPSUR P PRE TEST BOP EQUIPMENT PER AOGCC,BP,AND • CONTRACTOR PROCEDURES AND REQUIREMENTS I 1-TEST ALL ALARMS I-BOP CONFIGURATION: • I-TOP TO BOTTOM:ANNULAR PREVENTOR, I [BLIND SHEARS,2-3/8"PIPE/SLIPS,MUD CROSS,3"PIPE/SLIPS,23/8"X 3-1/2"VBR, 1 MUD CROSS,BLIND SHEARS,2-3/8"PIPE SLIPS � -TEST BOPE TO 250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH -TEST WITH 2-3/8"x 3.0"x 3.5"MULTI-JOINT I I-ALL RAMS TESTED ON RAM LOCKS I-ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS TEST WITNESSED BY AOGCC REP LOU LAUBENSTEIN 14.00 - 16:30 2.50 BOPSUR P PRE 1 LAY DOWN TEST JOINT. CHANGE OUT TEST LUBRICATOR. `'GET RKB MEASUREMENTS. 16:30 - 17:00 0.50 1 BOPSUR P PRE I CHANGE OUT CT PACKOFFS MAKE UP NOZZLE,GET ON WELL. 17:00 19:00 2.00 BOPSUR P • I PRE +FILL REEL WITH FRESH WATER FOR TESTING I IRV AND CT STRIPPER. I LINE UP VALVES TO REVERSE CIRCULATE I I FOR TESTING INNER REEL VALVE AND 1 STRIPPER. I WELLS SUPPORT CHECKS TORQUE ON TREE . BOLTS. 19:00 - 21:00 2.00 BOPSUR P I PRE PRESSURE TEST IRV AND STRIPPER TO 250/ 3,500 PSI,GOOD. INSTALL CHECK VALVES IN UQC. PT BHA I CONNECTION AND CHECK VALVES TO 3,500 21:00 22:30 W 1.50WHSUR I PSI,GOOD. P PRE REMOVE QTS FROM STACK INSTALL 2-FT I RISER. 'PJSM AND REVIEW PROCEDURE WITH I WELLS SUPPORT CREW AND NABORS TO PULL TWC. BRING BPV LUBRICATOR AND PULLING TOOLS TO RIG FLOOR. VERIFY RKB MEASUREMENTS. I MAKE UP PULLING ROD EXTENSIONS AND I BPV LUBRICATOR TO RISER. 122:30 - 23:00 0.50 WHSUR P PRE RIG EVAC EXERCISE AND AAR WITH MILLER I CREW. ALL PERSONS MUSTER AND ACCOUNTED FORIN3MIN. -- _ i CONDUCT PRE-SPUD WITH MILLER CREW. 123:00 - 00:00 1.00 WHSUR P PREINSTALL BPV LUBRICATOR AND PRESSURE 1 TEST 250/3,500 PSI,GOOD. 11/21/2017 00:00 - 01:00 1.00 WHSUR P PRE I PULL TWC. WELL IS ON VAC. OFFLOAD BPV LUBRICATOR AND PULLING .L. i TOOLS. Printed 12/4/2017 10:52:40AM *All depths reported in Drillers Depths* etea- fA- P ,, Operation Summary Common Well Name:H-37 AFE No Event Type.RE-ENTER-ONSHORE(RON) Start Date:11/19/2017 End Date:11/25/2017 X3-018P1-C:(2,304,000.00) Project.Prudhoe Bay Site:PB H Pad Rig Name/No.:CDR-2 Spud Date/Time:7/3/1997 12:00:OOAM Rig Release:11/29/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI.USA00000444 Active datum:KB @75.48usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 01:00 - 07:00 6.00 RIGU P PRE PJSM AND VERIFY FLOW PATHS FOR PUMPING. MAKE UP INJECTOR TO WELL,DISPLACE FRESH WATER OUT OF REEL WITH MUD. GREASE CHOKE AND STACK VALVES WHILE DISPLACING. OUT MM READING HIGH,STOP AND RECALIBRATE. -CONTINUE WITH BULLHEAD KILL -CIRCULATE 290 BBLS 140°KCL DOWN FOLLOWED BY 40 BBLS HI-VIS PILL AND 8.6 PPG MUD SYSTEM. INITIAL CIRCULATION OF 4.7 BPM,1190 PSI. FINAL CIRCULATION AT 4.7 BPM,1490 PSI. -SHUT DOWN PUMPING,PRESSURE DROPPED TO 1200 PSI Printed 12/4/2017 10:52:40AM *AII depths reported in Drillers Depths* II) North Ami-ALASKA-BP III P4044404 Operation Summary Report Common Well Name:H-37 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/19/2017 End Date:11/25/2017 X3-018P1-C:(2,304,000.00) Project:Prudhoe Bay Site:PB H Pad Rig Name/No.:CDR-2 Spud Date/Time:7/3/1997 12.00:00AM Rig Release.11/29/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000444 Active datum:KB©75.48usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 07:00 - 11:15 4.25 RIGU P PRE MONITOR WELL. CONDUCT EXTENDED FLOW CHECK DUE TO SLOW PRESSURE BLEED OFF TO OPEN WELLBORE AFTER BULLHEAD OPERATION. -PRESSURE BLED TO 640 PSI OVER 1 HOUR PERIOD. NO INDICATIONS THAT WELLBORE IS BREATHING,CERTAINLY INDICATIONS :THAT WELL IS"CHARGED"FROM THE BULLHEAD KILL PROCESS. -OPEN WELL TO FLOW BACK TANK (ROUTINE PRACTICE IN SUMMER-MORE CAUTIOUS IN WINTER)AND IMMEDIATE PRESSURE DROP TO 320 PSI. CLOSE IN, SLIGHT RISE IN PRESSURE,OUT DENSITY GOOD AT 8.68 PPG(DENSITY IN 8.70 PPG). OPEN AGAIN TO FLOW BACK TANK,DROP TO 170 PSI AND CLOSE IN. RISE AGAIN TO 240 PSI. VERY SLOW BLEED OFF WHILE MONITORING TO CLOSED CHOKE. -BREAK CIRCULATION AT.2 BPM WHILE i OPEN TO FLOW BACK TANK TO ENSURE LINE WON'T FREEZE AND CONTINUE TO LET PRESSURE BLEED. FAIRLY RAPID DROP FROM.8 BPM OUT TO.4 BPM OUT WHILE CIRCULATING. DENSITY IN 8.70 PPG, DENSITY OUT 8.68 PPG AND NO INDICATIONS OF GAS AT SURFACE. -CLOSE IN,NO PRESSURE FROM WELL. OPEN WHITEY AT LUBRICATOR WITH 5-GALLON BUCKET AND TIME RETURNS. FILL TO 4-GALLONS ON 3 SUCCESSIVE TIMED EVENTS WITH FILLING TAKING 15 SECONDS LONGER EACH TIME. NO GAS READING ON HAND-HELD MONITOR. -CLOSE IN WHITEY,NO PRESSURE AT GAUGE. NO IA PRESSURE,OAAT 55 PSI. -OPEN UP TO FLOW LINE,DENSITY OUT 8.68 PPG,NO GAS ON SHAKER METER. FLOW RETURN IS IN FREQUENT DROPS,NO STEADY STREAM. OPEN WHITEY AT LUBRICTOR TO OPEN AIR-LOCK,AGAIN JUST STEADY DROPS COMING OUT,NO STREAM. WAIT UNTIL DROPS DIMINISH TO ERRATIC DRIP EVERY FEW SECONDS. CREWAGREES THAT THERE IS NO INDICATION OF FLOW, DRIP WILL CONTINUE DUE TO PLUMBING. CLOSE IN,NO PRESSURE. -PJSM ON POPPING OFF WITH INJECTOR. DISCUSS DIFFERENCES IN WELLBORE BREATHING,BALLOONING AND EXHALE TEST (20 MINUTES WITH WELL CLOSED IN,NO PRESSURE BUILD). I-POP OFF WITH INJECTOR AND MONITOR AT LUBRICATOR. FLUID LEVEL JUST ABOVE MUD CROSS BUT EVENTUALLY ROSE TO TOP OF LUBRICATOR(JUST UNDER 1/2 BBL CAPACITY)OVER 10 MINUTE PERIOD. STAB BACK ON WITH INJECTOR WITH NOZZLE AND CHECKS. -DISCUSS PLANS TO PROCEED WITH ODE. AGREE TO CONDUCT TIMED EXHALE TEST (40 MINUTES HAS ELAPSED). OPEN WHITEY, Printed 12/4/2017 10:52:40AM *All depths reported in Drillers Depths* • North America ALASKA-BP . atIe 5 Operadon Summary R, Comm on Wet Name:H-37 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/19/2017 End Date:11/25/2017 X3-018P1-C:(2,304,000.00) Project:Prudhoe Bay Site:PB H Pad Rig Name/No.:CDR-2 Spud Date/Time:7/3/1997 12:00:00AM Rig Release.11/29/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI USA00000444 Active datum:KB @75.48usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) NO FLUID COMING OUT. CLOSE WHITEY, BREAK CIRCULATION TO GET FLUID LEVEL TO WHITEY AND SHUT DOWN. OPEN WHITEY,TOOK 30 MINUTES TO FILL BUCKET TO 3-GALLONS AND IT SLOWED TO DRIPS; MOST LIKELY LUBRICATOR CAPACITY FILLED BUCKET. TOOK ANOTHER 30 MINUTES TO I FILL HALF OF 16 OUNCE COFFEE CUP. CONTINUE WITH TEST,NO FLUID OR DRIPS IN THE NEXT 30 MINUTES. PJSM ON POPPING OFF AND MONITORING WELL. POP OFF,FLUID AT LUBRICATOR LEVEL BUT STATIC. IA 0 PSI,0A 48 PSI. 11:15 - 12.45 1.50 STWHIP P WEXIT MOVE INJECTOR BACK,BREAK OFF NOZZLE WHILE MONITORING WELL. NO FLUID ,MOVEMENT. MAKE UP 3.80"MILLING BHA,SCRIBE WHILE CONTINUING TO MONITOR WELL. -MU TO INJECTOR,STAB ON,PRESSURE TEST QUICK TEST SUB. NO PRESSURE 'SEEN ON GAUGES. -IA 0 PIS,OA 44 PSI 12:45 14:50 2.08 STWHIP P WEXIT OPEN UP TO PITS AND BREAK CIRCULATION. RN HOLDING 100 PSI BACK PRESSURE ON CHOKE -LOST 13 BBLS ON FIRST 3000'OF RUNNING IN WELL WITH THE BACK PRESSURE BEING HELD -CONTINUE RIH WITH OPEN CHOKE AND LOSING FLUID WHILE PUMPING AT.45 BPM, 955 PSI. DENSITY IN 8.71 PPG,DENSITY OUT 8.72 PPG. -LOSSES WITH BACK PRESSURE AS HIGH AS I � 36 BPH BUT DROPPED TO-22-24 BPH ONCE BELOW THE OPEN LATERAL SECTION. 14:50 - 15:05 0.25 I STWHIP P 10,463.00 WEXIT LOG TIE-IN FOR GEO PDC CORRELATION,-22' CORRECTION -IAO PSI,0A41 PSI 15.05 - 17:00 1.92 STWHIP P 10,524.00 WEXIT MOVE DOWN AND TAG UP ON WHIPSTOCK AT 10,524'MD -CIRCULATE THROUGH MOTOR AT MIN RATE TO CLEAR UNKNOWN FLUID OFF OF WHIPSTOCK AND ABOVE BHA. OPEN EDC, BEGIN BOTTOMS UP CIRCULATION THROUGH EDC AT 4.5 BPM IN,2.62 BPM OUT,3760 PSI MW IN 8.81 PPG,MW OUT 8.74 PPG, INITIALLY LOSING FLUID AT-90 BPH BUT IT DROPPED TO 60 BPH. REDUCE RATE TO 2 BPM,LOSS RATE DROPPED TO-35 BPH. MW IN 8.74 PPG,MW OUT 8.73 PPG. -TAKE RETURNS OUT TO FLOW BACK TANK 20 BBLS PRIOR TO BOTTOMS UP(CONCERN OF CONTAMINATED OR GASEOUS RETURNS FROM BOTTOM). CIRCULATE UNTIL BOTTOMS UP PLUS 20 BBLS OUT TO FLOW BACK TANK. CONDUCT STATIC FLOW CHECK,INITIAL FLOW BACK AT.15 BPM THAT DIED OFF OVER THE 15 MINUTE FLOW CHECK. MICROMOTION MW IN 8.71 PPG,MW OUT 8.72 PPG. MUD ENGINEER CHECK,DENSITY AT 8.70 PPG.. Printed 12/4/2017 10.52:40AM 'All depths reported in Drillers Depths* North America ALASKA-BP • Page 6 434 Operation Summary Report Common Well Name:H-37 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/19/2017 End Date:11/25/2017 X3-018P1-C:(2,304,000.00) Project:Prudhoe Bay Site:PB H Pad Rig Name/No.:CDR-2 � Spud Date/Time:7/3/1997 12:00:00AM Rig Release:11/29/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000444 Active datum:KB t75.48usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth I Phase Description of Operations (hr) — .__ (usft) (rA y/.r 17:00 - 17:05 0.08 STWHIP P 10,524.00 WEXIT BEGIN MILLING OPERATIONS FROM 10,524' J, C/I ! -BRING ON PUMPS,MOVE DOWN TO ,51?) INITIATE MILLING,INSTANT STALL. ATTEMPT I TO PICK UP,STUCK 1-ABLE TO ORIENT WITH BHA BUT CANNOT PICKUP 17:05 - 20:20 3.25 -t STWHIP N 10,524.00 WEXIT MAKE ATTEMPTS TO WORK PIPE AND GET !FREE j I-CYCLE PUMPS IN TENSION AND [COMPRESSION. NO SUCCESS. DISCUSSIONS WITH ODE ON PLAN FORWARD. -OPEN EDC. BREAK CIRCULATION. -GENTLY WORK PIPE UP AND DOWN. START 1 MOVING SLOWLY UPHOLE 8'WHILE CIRCULATING THROUGH OPEN EDC. REACTIONS ON WOB BOTH DIRECTIONS -CLOSE EDC. COME ONLINE. MOTOR IN 'PARTIAL STALL. STARTING BEING ABLE TO CIRCULATE THROUGH MOTOR AT 0.87 BPM/ 0.77 BPM OUT AT HIGH DIFFERENTIAL PRESSURE. RIHAND POPPED FREE DOWN. PU AND 1TOOLSARE FREE. MOTOR DIFFERENTIAL FELL OFF. -PULL UP ABOVE SUMP PACKER ASSEMBLY. -OPEN EDC, CIRCULATED BOTTOMS UP 20:20 - 20:45 0.42 STWHIP N 10,524.00 WEXIT j PERFORM DYNAMIC FLOW CHECK PER 1 FINGERPRINTING RP. -2.80 BPM IN/2.53 BPM -DROP RATE TO 0.2 BPM IN. TREND .RETURNS. -TOOK 23 MINUTES TO FALL TOA STABLE IN AND OUT. -FCBO OF 5 BBL GAIN FROM FULL DRILLING 1 RATE TO MINIMUM RATE OUT 20:45 - 23:06 2.35 STWHIP N 10,524.00 WEXIT -MUD WEIGHT:8.72 PPG IN,8.68 PPG OUT -RATE:1.52 BPM IN,1.07 BPM OUT -CIRC PRESSURE:1233 PSI NO ISSUES PULLING INTO TUBING TAIL OF _— MOST RECENT COMPLETION. 23:06 - 00:00 0.90 STWHIP N 10,524.00 WEXIT 1 STOPAT 300' PERFORM FLOW CHECK TO PITS. BLED 3.4 BBLS TO PITS AND DIED OFF OVER 30 MINUTES. CLOSE DRILLING CHOKE OPEN NEEDLE VALVE ON INJECTOR TO PERFORM FLOW CHECK /BLEED BACK. Printed 12/4/2017 10:52:40AM *AII depths reported in Drillers Depths* 4-1/8"WI H 3 7A VVH LFEAD= FMC-GEN 5 SA ES: HIGH DOG LEG SEVENTY(35+1100')10417'- 10500' MPLET®LATERAL.WILL>TV@ 10587'. ACTUATOR= BAKER OKB= 75.48' H-37L1 NOTE 1"OGLV LOST IN HOLE-LOCATION UNKNOWN. REF tiEl1 1 APPEARS TO BE B13.0W EDT(KSB-01-02-05) /= 7548' BF.BEV= 46.64' ES csvw7� H 1767' 1 KOP= 2387' L 2078' 1-4-1/2"I-ES HXO SSSV NP,D=3.813" Max Angle= 94°@ 10746' - ----- - _ Datum MD= 10439' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum TVD = 8800'SS L 6 3310 3249 28 CAMCO DMY NT 0 06/22/17 9 5/8"CSG.40#,L-80,D=8.835' H 3775' 5 5755 5250 36 KBG-2-LS DMY M 0 06/22/17 Minimum ID =2.44" @ 11440' y 4 7160 6397 34 CAMCO DMY NT 0 06/22/17 4-1'2" K B LNR TOP PKR 3 8021 7109 35 KBG-2-LS DMY NT 0 02/17/15 2 8881 7810 36 KBG-2-LS DMI' INT 0 08/15/97 RA TAG H 10107' H. 1 9737 8494 46 CAMCO DMI' NT 0 02/17/15 I I 10181' H4-1/2"HES X NP,D=3.813" Z �/ ' 10192' H 7'X 4-1/2"BAKER S-3 PKR,D=3.952" ,L, 10267' -14-1/2"FES X NIP,D=3.813" I I 10278' H4-1/2"HESX MP(FP),D=3.813" 4-1/2"TBG,12.6#,L-80,.0152 bpf,ID=3.958" H 10289' 1--_/ \ . , 10290' -14-1/2-VVLEG,D=3.958' FISFt LOST 2 KICK SPRINGS DH @ UNKNOWN H{ ? ilif [10286' -ELK)TT LOGGED 09/01/00 i DEPTH(08/18/13) 7"WO_L E D VMDOW- 10372'to 10384' NOTE ND LNR N H-37L1 LIFER LATERAL RA TAG H 10366' H. OPB'IHOLETD H 11500' H-37L1 X „ 10393' H4-1/2"X 7"BKR Not_PKR,D=3.875" ' 10403' H4-1/2"FES X NP,D=3.813" 4-1/2"TBG,12.641,L-80 BT,.0152 bpf,D=3.958" H 10409' 1---- 10410' H4-1/2"WLEG,D=4.00" 10410 i--E.MO Ti LOGGED 09/01/00 10426 H BKR TIEBACK SLV,D=5.25" ►. 10433 H 7"X 5"BKR ZXP PKR WI FMC HGR,0=4.408" ■ ■ 7"CSG,26#,L-80,D=6.276" H 10460' 4-1/2"BKR ML KB BKR WS w IRA TAG @ 10529'(11/06/17) H 10620' !'1•." ? -FISH:WFD TRE ATNG PKR ELEMENT,.95'X.4"(08/21/12) la 4-1/2"KB WI NOCK PKR(11/06/17) I- 10630' : PUSHED OH TO UNKNOWN DEPTH(11/6/17) 11166' -14-1/2"WFD WRP PLUG-03/28/01 PERFORATION SUMMARY REF LOG:MWD GR ON 07!29/97 11440' -14-1/2"BKR KB LNR PKR,D=2.44" ANGLE AT TOP PE RE:640 @ 10565' Note:Refer to Production DB for historical perf data 11469' --{2-7/8-LNR TOP,D=2.372' SIZE SPF INTERVAL Dpn/Sg2 SEDT SQZ 2-7/8" 6 10565-10614 C 01251034-1/2"LIR, 12.6#,L-80, -{ 11565' Al. / 2-3/4" 4 10650-10900 C 08/01/97 .0152 bpf,D=3.958" Z 2-3/4" 4 10950-11130 C 08/01/97 � TD H 11760' 2-3/4" 4 11185-11230 C 03/28/01 2-7/8"SOLOLNR,6.16#,L-80, -1 11695' 2-7/8" 4 11290-11370 C 03/28/01 .0058 bpf,D=2.372" ` ` :q 2-7/8" SLID 11695-11758 C 03/28/01 2-7/8"SLID LNR,6.16#,L-80, --1 11758' .0058 bpf,D=2.372" DATE REV BY COMMENTS DATE REV BY COMIvENTS PRUDHOE BAY MT 08/16197 CHH MULTI-LAT COM PL-REG 2E5 01/06/16 GJB/JMD SET XX PLUG(01/03/16) 'RL: H-37A/L1 08/22/00 CTD-RUN 2-7/8"SLID LNR 06/27!17 DEG/JPD GLV C/O(06/22/17) FER AF No: 2000970/1971030 01/25/03 TN91' ELMD TT LOGGE DIADFERF 08/30/17 JN/JEuD ADD®REF&BF B-EV API No: 50-029-22772-60/01 11/25/14 LEG PJC PULL X LOCK w/SBR 10116/17 IICB/JIVD PULLED XX RUG(06/21/17) SEC 21,T11 N,R13E,2019'FPL&1264'Fa. 01/19/15 PJC MN D COITION 11/08/17 TFA/JI D SET WSIVVS FKR/PJSFU)FISH DH 02/17/15 SIF/PJC GLV C/O BP Exploration(Alaska) • ®F THE STATE Alaska Oil and Gas of Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279 1433 AILA.914 Fax: 907.276.7542 www.aogcc.alaska.gov Uchenna Egbejimba Engineering Team Leader—CTD and RWO BP Exploration(Alaska), Inc. ;'�� 4" 1 2017 P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H-37A Permit to Drill Number: 200-097 Sundry Number: 317-420 Dear Mr. Egbejimba: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1111.40 Hollis S. French Chair DATED this t 2- day of September, 2017. RDDMS Lv SLS 1 9 2017 STATE OF ALASKA IONLASKA OIL AND GAS CONSERVATION COMMI�,, APPLICATION FOR SUNDRY APPROV 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 • Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 200-097• 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 121 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22772-01-00 • 7. If perforating: 8. Well Name andr: What Regulation or Conservation Order governs well spacing in this pool? C E I V ED Will planned perforations require a spacing exception? Yes 0 No 0 PBU H-37A • 9. Property Designation•(Lease Number): 10. Field/Pools: AUG 3 12017 ADL 028284,028287&028288 " PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): rGCC (MD): 11760 . 9156 • 10403 8858 2369 10403.11155nknown,10460 Casing Length Size MD TVD Burst Collapse Conductor 80 20" 31-111 31-111 1530 520 Surface 3745 9-5/8" 31-3775 31-3635 5750 3090 Intermediate 10432 7" 28-10460 28-8886 7240 5410 Liner 17 4-1/2" 10393-10410 8853-8861 8430 7500 Liner 1140 4-1/2" 10425-11565 8868-9052 8430 7500 Liner 320 2-7/8" 11440-11760 9029-9156 13450 13890 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11695-11758 9108-9154 4-1/2"12.6# L-80 26-10290 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 10192/8752 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary H Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 • Service 0 14.Estimated Date for Commencing Operations: October 1,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 ` 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Browning,Zachary H be deviated from without prior written approval. Contact Email: Zachary.Browning@bp.com Authorized Name: Egbejimba,Uchenna J Contact Phone: +1 907 564 5220 Authorized Title: EngineeringinTeam Leader- TD&RWO Authorized Signature:. _--'f Date: 8/,31,2- C.) 1 - J 2,,e.._ ' COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test Ly Mechanical Integrity Test 0 Location Clearance 0 Other: 73 0 p trsf -f0 3 57) D P bco s r nrV�vz�fc� Si lc 2_ 5-/, }� -�- jev1t/� Gt ��ff✓vi �r i/� ,�7r �2 si �9C 25�. 162GL Post Initial Injection MIT Req'd? Yes 0 No / Ol,p fir Spacing Exception Required? Yes 0 No ® Subsequent Form Required: j d —÷/7 APPROVED BYTHE } Approved by: a 11 0 0 COMMISSIONER COMMISSION Date:C I -1--11q . .DIGIN 0.1 RDDMS LA, 5 ��r/1 9 2017 f/3//� p,s •/7 Submit Form and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. • •• To: Alaska Oil & Gas Conservation Commission 0 bP From: Zach Browning CTD Engineer Date: August 29, 2017 Re: H-37, H-37L1 and H-37A Sundry Approval Request Sundry approval is requested to plug the H-37, H-37L1 and H-37A perforations as part of the preparation, drilling and completing the proposed H-37B coiled tubing sidetrack. History of H-37: Well H-37 was originally drilled and completed in 1997 as a multilat Zone 4 producer with an open hole completion in the Sag River. In 2000 the toe was drilled out with coil tubing into Zone 3 and completed as a service well to provide pressure support from the aquifer. However, the well's production was still low with high water cut. The well has been shut in since 2007. Any well work options are complex and expensive to get the • well back on line, and so the best use for the wellbore is a sidetrack. Proposed plan for H-37B: The proposed H-37B CTD sidetrack will be an approximately 1000' Zone 4 slant well to replace the parent production from this isolated fault block. There is one injector in the fault block and this well will be the single offtake point. The sidetrack will be drilled with the Nabors CDR2 rig on or around November 15th 2017. A 4-1/2"whipstock will be set pre-rig with service coil inside the 4-1/2" liner. The rig will move in, kill the well and mill a 3.80"window, -10' long. The well kicks-off in the Shublik and will kick out away from the parent before beginning to slant down through section to the oil water contact. The proposed sidetrack is a -1000' horizontal Ivishak producer to be completed with a 3-1/4" 13Cr solid liner, cemented in place and selectively perforated. This Sundry covers plugging the existing H-37, H37L1 and H-37A offtake via the V whipstock, liner cement lob or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre-Rig Work(scheduled to begin October 1St, 2017) 1. C Drift for WS. Set WS. 2. V Pre-CTD Tree work. Set TWC Rig Work(scheduled to begin November 15th, 2017) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,369 psi). 2. Kill well. Mill 3.80"Window. 3. Drill build section: 4.25" OH, -390' (35 deg DLS planned). 4. Drill lateral section to TD: 4.25" OH, -629' (12 deg DLS planned). 5. Run 3-1/4" 13Cr liner leaving TOL at-10,220' MD. 6. Pump primary cement job: 17.3 bbls, 15.3 ppg Class G, TOC at TOL (-10,220' MD)* 7. Freeze protect well to a min 2,200' TVDss. 8. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) //gy�pp Post-Rig Work: e (./c## Iocr .60 1. V: Tree work as necessary. Cca►�Gv�' �� s do 0 2. F: PT liner lap. . vti r4 A Water Cdr �y5"o c f�ti 3. C: Perforate -500'. V 4. S: Set LGLVs. LTP set post rig if needed, and test* no re.carit Wh cycieoJ P10,"/ M/ 5. T: Portable test separator if perf>500' 6. SP: Regulatory compliance SBHPS (within 6 months of initial POP) `,ly Vvd motellt Afo&k Q/lo✓ Zach Browning CC: Well File , ti 0It/ ( (AIery fro" 74d- PO-tioi CTD Engineer Joe Lastufka ,,,� "" 564-5220 OC Tie Mt W/ TREE° 4-1/8"CIW VVH-LFEAD= FMC-GEN 5 • H - 7A SAES: HIGH DOG LEG SEVERITY( 5+/ 100')10417'- • ACTUATOR= BAKER 10500' MPLETED LATERAL.WELL>70°@ 10587'. OKB= 75.48' H-37 H-37L1 NOTE 1"OGLV LOST IN HOLE-LOCATION UNKNOWN. REF ELEV APPEARS:-,---------75.48':-,---------75.48' TO BE BF30W EOT(KSB-01-02-05) BF.ELEV= 46.64' 6 CHMiHNIER — 1757' 1-- KOP= 2387' Max Angle= 94°@ 10746' 2078' -1 4-1/2"FES HXO SSSV NP,13=3.813" Datum MD= __ 10439' Datum TVD = 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 5/8"CSG.40#,L-80,D=8.835" — 3775' A , 6 3310 3249 28 CAMiCO DMY INT 0 06/22/17 5 5755 5250 36 KBG-2-LS DMY NT 0 06/22/17 Minimum ID =2.44" @ 11440' L 4 7160 6397 34 CAM1CO DMY NT 0 06/22/17 3 8021 7109 35 KBG-2-LS DMY INT 0 02/17/15 4-1/2" KB L N R TOP PKR 2 8881 7810 36 KBG-2-LS DMY NT 0 08/15/97 1 9737 8494 46 CAMCO DMY INT 0 02/17/15 RA TAG H 10107' HI I I 10181' —14-1/2"FES X NI),D=3.813" Z Z 10192' —7'X4-1/2"BAKER S-3 PKR,D=1952" I I 10257' H4-1/2"FES X NP,D=3.813" I I 10278' —4-1/2"FES X NP(I-P),ID=3.813" 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 10289' / \ 10290' —14-1/2"WLEG,D=3.958" FISH LOST 2 KICK SPRINGS DH @ UtskNOWN —I ? 10285' —ELM)TT LOGGED 09/01/00 DEPTH(08/18/13) 7"MILLED WINDOW- 10372 to 10384' NOTE NO LNR N H-37L1 UPPER LATERAL RA TAG —1 10356' —S OFEV HOLE TD —I 11500' H-371:7 R \/ 10393' —14-1/2"X 7"BKR ML PKR,D=3.875" 4-1/2"XX PLUG w/FLL EXTENSION(01/03/16) —I 10403' /\ INER,--- 10403' --14-1/2*FES X NP,D=3.813" 4-1/2"TBG,12.6#,L-80 IBT,.0152 bpf,D=3.958" 10409' ' 10410° —I4-1/2"WLEG,D=4.00" 10410 H1 E LMD TT LOGGED 09(01/00 FISH:WFD TREATING PKR ELEMENT, —I 10480'ELM D10425 --I BKR TIEDACK SLV,13=5.25" .95'X.4"(08/21/12) `\\slJ 1 10433 —1r X 5"BKR ZXP PKR Wl HNC HGR,D=4.408" 7"CSG,26#,L-80,ID=6276" H I 10460' -A I I PERFORATION SUMMARY 11155' H4-1/2"WFD WRP PLUG-03/28/01 REF LOG:MWD GR ON 07/29/97 ANGLEAT TOP FE RF:64°@ 10565' % Note:Feer to Production DB for historical perf data 11440' —{4 1/2"BKR KB LNR PKRID=2.44" SIZE SPF INTERVAL Dpn/Sqz SHOT SQZ s_ 1*2-718" 6 10565-10614 C 01/25/03 '- 11459' 12-7/8"LIR TOP,D=2.372" 2-3/4" 4 10650-10900 C 08/01/97 4-1/2"LNR 12.6#,L-80 —{ 11565' ti / 2-3/4" 4 10950-11130 C 08/01/97 2-3/4" 4 11185-11230 C 03/28/01 .0152 bpf,D=3.958" TD H 11760' • 2-7/8" 4 11290-11370 C 03/28/01 2-7/8"SOLDLNR,6.16#,L-80, —1 11695' , "I +, 2-7/8" SLID 11695-11758 C 03/28/01 .0058 bpf,D=2.372" 2-7/8"SLID LNR,6.16#,L-80, H 11758' .0058 bpf,ID=2.372" DATE REV BY COMMENTS DATE _REV BY COMMENTS PRUDHOE BAY UNIT 08/16!97 CFH MULTI-LAT COM PL-RIG 2ES 01/06/16 GJB/JMD SFT XX PLUG(01/03/16) WELL: H-37A I L1 08/22/00 CTD-RUN 2-718"SLTD LP* 06/27/17 DEG/JMD GLV GO(06/22/17) PERMIT No: 2000970/1971030 01/25/03 TNrTP ELM)TT LOGGBJ/ADPERF 08/30/17 JNUJMD ADDED IEF&BF ELEV AR No: 50-029-22772-60/01 11/25/14 LEC/PJC PULL X LOCK w/SBR SEC 21,T11 N,R13E,2019'FNL&1264'FEL 01/19/15 PJC MN D CORRECTION 02/17/15 STF/PJC GLV 00 BP Exploration(Alaska) • �T • SAFET ES: HIGH DOG LEG SEVERITY(35+1100')10417'- ACTUATAD= FMGGENS P ROPO .. 10500'IN COMPLETED LATERAL.WELL>70°g ACTUATOR= URAL KB.F1 F 75.48' H-37 L 1 NOTE 1"OGLV LOST IN HOLE LOCATION UNKNOWN. APPEARS TO BE BELOW EOT(KSB-01-02-05) BF ELEV= 47.2' KOP= 238T T ES CEMENTER H 1757' —a Max Angle= lex}_ 2078' 1--{4-1/2"HES HXO SSSV NP,D=3.813" Datum MD= 0 Datum TVD = 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT BATE - 6 3310 3249 28 CA MCO DMY NT 0 06/22/17 9 5!8'CSG_40#,L-80,D=8.835" H 3775' 1-4 ' 5 5755 5250 36 KBG-2-LS DMI NT 0 06/22/17 Minimum ID = L 4 7160 6397 34 CAMCO DMY NT 0 06/22/17 3 8021 7109 35 KBG-2-LS MN NT 0 02/17/15 2 8881 7810 36 KBG-2-LS DMY PIT 0 08/15/97 1 9737 8494 46 CAMCO DMY NT 0 02/17/15 RA TAG H 10107' —■ ' 10181' H4-1/2"HES X NP,D=3.813" i 10191-{7'X 4-1/2"BAKER S-3 PKR,D=3.952' 3-1/2"X 3-1/4"TOUTOC -J 1 10220 H3 r -»DEPLOY MHVT SLEEVE.D=3.00 FES 3-1/2"FXNP 0=2.813" H 10240' [ 10260' H3-1/2"X 3-1/4"XO,D=2.786"_ I3-1/2"LNR, #,L-80 STL,.0087 bpf,D=2.992" H 10260' , 1 I 10267' H4-1/2'HES X fes?D=3.813" I I i_ 10278' J--14-1/2"FES X NP(F#),D=3.813", 4-1/2"TBG,126# L-80. 0152 bpf,D=3.958' H 10289' ! II 10290' 4-1/2"WLEG,D=3.958' 10285' -BMD TT LOGGED 09/01/00 7'MILLED WINDOW- 10372'to 10384' RA TAG H 10356' NOTE NO LNR N H-37L1 UPPER LATERAL OPEN HOLE TD H 11500' [i-371-1 j 10303' E-4-1/2"X 7"BKR ML FKR,D=3.875' ' ' 10403' H4-1/2"FES X NP,D=3 813" 4-112"TBG,12 6#,L-80 BT,.0152 bpf,D=3.958" -1 10409' t - s10410' H4-1/2"WLEG,D=4.00' 1 10410 -{ELMD TT LOGGED 09/01/00 l 1 10425 H BKR TRACK SLV,D=5.25" x 10433 H7"X 5"BKR ZXP PKR W/F-NC HGR,D=4.408" 1 L 7"CSG,26#,L-80,D=6.276' H 10460' J , 14-1/2-BKR Mt 1 n4;xE R M+Fii,»rcac K( t�r�} H 10630' FALLOUT WINDOW(H-37B)10,530'- ' I41/2'TBG,12.6#,L-80,.0152 bpf,D=3.958'J-1 --10630' PERFORATION SUIM RY ' REF LOG: ON ! r A M-1 E AT TOP PERE _'0 Note;Refer to Rod uction DB for historical pert data SCE SPE INTERVAL Dpn/Sqz SHOT SQZ 1.1 44 3-1/4'LNR,6.6#,13-CR TC11, .0076 bpf,D=2 r ' H 11539' Al DATE REV BY COM4ENTS DATE REV BY COMMENTS PRUDHOE BAY UP(T 08/16197 CHH MULT1-LAT COM PL-RIG2E5 WE..L. H-37A I L1/ i Li 08/22/00 CTD-RUN 2-7/8"SLID LNR PERMT No: 2000970/1971030/ _I__/ API No 50-029-22772-60/01/ 08/21/1 t MU t3LILI PROF SL 1 SEC 21,T11 r' R13E,2019'FNL&1264'FEL BP Exploration(Alaska) Well Blank •CDR2-AC BOP Schematic •Date • Quick Test Sub to Otis -1"1 ft -' Top of7"Otis 0.Oft 4 CDR2 Rig's Drip Pan Distances from top of riser Excluding quick-test sub � Top of Annular 0.0 ft 7-1/16"— 5k Flange X 7"Otis Box drl17 1/1 ( Top Annular Element 0.7 ft Annular Bottom Annular 2.0 ft soms Blind/Shear CL Blind/Shears I 3.3 ft I 2.318"Pipe/Slips CL 2-3/8"Combi's 4.1 ft 0-' B5 ,1 B . -7 FII :: B8 Prr Deployment Line M ow— I~ e: (I',� kr sk1Mud h:r44-4Iv !- MMIIMI IH - 10 I" Choke Line 3"Pipe/Slips . CL 3"Pipe/Slips 6.6 ft 14 2-3/8"x 3-1/2"VBR rel CL 2-3/8"x3-1/2"VBRs 7.4 ft B1 I B2 B3 .I„84 Choke Line Kill Line ° '.��,ae a ” "r Pr -'r` r.' n.a..i�:, "xk:f �"'ak 11►. , 'ii,a ;Iiiiii lIi 1I1U�Mir Ill III Blind/Shear CL Blind/Shears 10.0 ft 1.11 ..ralle 2-3'8"Pipe'Slips dirAtt.ak `\ CL 2-3/8"Combi's 10.7 ft 0 -..... • CL of Top Swab 13.3 ft � � .41----.Swab 2 Test Pump Hose ♦ dr,......"Swab 1 CL of Bottom Swab 14.8 ft /moo i T1 i T2 CL Flow Tee 16.2 ft �. - = BOP2 CL of SSV 17.5 ft N o Master 2 } Fusable CL of Master Valve 19.0 ft BOP1 l► ��F Master 1 LDS 20.5 ft -----..,_ .74 11 II II II II Gound Level 'a:* a* - 11 11 It i( It • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsibl 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then/ it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill"code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. • • 0 Thousand Cubic Feet of Gas ("MCF") per Day cn0 0 0 0 0 0 co o c o .1 .1 ri ri 4 O Oe 4'I. c sr°2 E slit, 03 82.°e = (I o > $ 0 0 .�' !j 'a -4 • ° a 4 o iI, * a 8B 2 OM iii II o �+ 4 3 92. 0 a w e c� t. o 1 { c , pp o O! 0 8 0 0 4 O'O . O. a N 0 i .2 8 4 00 80 0� . • �4P� E N z , . o w at u 4* 0 a 00 0 00 r °e ro * a as 0 "..1'.o Bu o 40 o d *0 O + +„+ m D m * 04 a00o0 �0 - f_ FrOe. Q a 0 f0 m y cri i r 0- _o M 0 N n .—ice♦ et m 2 J_ ,0 v N ° vt, w 7 H 0 I i LLJ .0 h `., 443 v c Z 0 ° 1 / ' E i � °' � _ Ol v E a °� 2 co O L 4P�. a p Qa a a Vo c > E E £ 8 ate, { u kJ C Oe W a , . :°°e O I 1 4PP m o in Io Q ♦ •• 4P o { sO° a oa li", c- a ii ad r z A00:1/ 0 c •-- —may °°�O F - • ..-.--o• �'O°� o L- . �_ 45 &•41,"2: 1--- 4Pr a, eo m l , r < tooeve II ° o 0 q q o o °°e, o 0 0 0 0 o o o .1 o" o .-i o .1 U Ilea Jad JaleM }o siaa.ie8 JO /lea aad Ha Jo wing0 a Ima~roject Well History File Cover{~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds BY: BEVERLY ROBIN VINCENT SHER~)WINDY Project Proofing BY; BEVERLY ROBIN VINCENT SHERY~WINDY [] Other Scanning Preparation I x 30 = 3C) + J ~ = TOTAL PAGES Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: .J~ d/') PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: /~ YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANC~RE FOUND: /-, YES DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) NO NO RESCANNED BY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE; /si General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpo P e)(t 1-1--'3 7 4- Prb. Ze-U097c Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelIIntegrityCoordinator @bp.com] Sent: Monday, April 29, 2013 4:04 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HU; Weiss, Troy D; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D&C DHD Well Integrity Engineer; Grey, Leighton (CH2M Hill); Arend, Jon Subject: UNDER EVALUATION: Producer H-37A(PTD#2000970) Exceeded MOASP Attachments: H-37A.pdf; H-27A TIO Plot 04-29-13.docx All, ✓ Producer H-37A(PTD#2000970)exceeded MOASP on 04/27/2013 with T/I/0=284/1700/1500. The well is reclassified as Under Evaluation and is to be kept online for further diagnostics. Proposed plan forward: 1. Cameron to PPPOT 2. WIE to evaluate for further diagnostics. Attached are copies of the wellsketch and TIO plot for reference. OA SO Please call with any questions. � - I5-00es; Miy= 51515; Regards, Laurie Climer IAlternate:Jack Disbrow) BP Alaska - Well Integrity Coordinator Gwv Ctoba,Wells Organtzaton WIC Office: 907.659.5102 SCANNED FEB 2 5 2014 WIC Email: AKDCWellIntegrityCoordinator @BP.com 1 Q $so88o i _M t� -o M M en 43 Ws 1 M a M o a ,,,i. 1 M a o M i Pi • M O i M a 0 M o ,w ' o E O co I- O .- N M O O H ' N N 112 = Q N 0. m F— 4 O x0- 0 H _._ IHEE= 41/8"GW H 37A SAFETY 1, S; HIGH DOG LEG SEVERITY(35+1100')10417'- W13LHEAD= .FMC-GEN 5 - 10500'IN COMPLETI3)LATERAL.WELL>70°@ 10587'. ACTUATOR= BAKER NOTE 1"OGLV LOST IN HOLE-LOCATION UNKNOWN. KB.ELEV= 75.48' H-37 L1 APPEARS TO BE BELOW BDT(KSB-01-02-05) BF.a.EV= 47.2' - - KOP— 2387' Max Angle= 94°Q 10746' ES CEMENThR 1757' "—— Datum MD= 10439' Datum ND = 'SS 2078' —4-1/2"HES HXO SSSV NP,D=3.813" Eel GAS LFT MANDRELS 9 5/8'CSG.40#,L-80,D=8.835' H 3775' }--, , ST M) ND DEV TYPE VLV LATCH PORT DATE . J I ME 6 3310 3248 24 CAMCO DO NT 16 08/26/04 14Syp 15o ' I 5 5755 5249 35 KBG-2-LS DMY NT 0 04/08/01 �— 4 7160 6397 35 CAMCO DOW NT 16 08/26/04 3 8021 7109 34 KBG-2-LS DMY NT 0 04/08/01 2 8881 7810 34 KBG-2-LS DMY NT 0 04/08/01 RA TAG — 10107' —11 1 973718495 35 CAMCO SO NT 20 11/13/07 I ' 10181' H4-1/2-HES X NP,D=3.813' Minimum ID =2.37" @ 11459' Z Z 10192' i 7'X 4-1/2"BAKERS-3 PKR,ID=3.952" 2-7/8" LINER TOP ' ' 10257' —4-112"HESX NP,D=3.813" ' ' 10278' H4-1/2'HES X NP(HP),D=3.813' I 4-1/2'TBG,12.6#,L-80_0152 bpi,ID=3.958" — 10289' \ 10290' 4-1/2"WLEG,D=3.958" 10285' —H ELMD TT LOGGED 09/01/00 7'KILLED WNDOW- 10372'to 10384' NOTE NO LNR N H-37L1 UPPER LATERAL RA TAG — 10356' ill . OPEN HOLE TD --I 11600' H 37L1 j ›< 10393' —14-1/2"X 7'BKR ML PKR,13=3.875' I I 10403' H4-1/2"HES X NP,D=3.813' 4-1/2"TBG,12.6#,L-80 13T,.0152 bpi,D=3.958" H 10409' / 10410' —4-1/2'WLEG,D=4.00" 10410 --I ELMD TT LOGGED 09/01/00 FISH:WFD TREATNG PKR ELEMENT, — 10480' ELMD 10425 H BKR TLBACK SLV,D=5.25' .95'X.4"(08/21/12) M. 10433 H7'X 5'BKR ZXP PKR W/I IMC HGR,D=4.408" I ■ 7"CSG,26#,L-80,0=6.276" — 10460' I _ R3RFORATION SUMMARY 11155' H 4-1/2"WFD WRP PLUG-03/28/01 REF LOG:MWD GR ON 07/29/97 ANGLE AT TOP FERE:64°(fp 10565' Note:Refer to Production DB for historical pert data 11440 I-147/2'BKR Kb LNR PKR D=2.44" SIZE SPF NTBRVAL Opn/Sgz DATE 2-7/8' 6 10565- 10614 0 01/25/03 h y, 11459' —12-7/8"LNR TOP,D=2.372" I 2-3/4" 4 10650- 10900 0 08/01/97 / 2-3/4' 4 10950- 11130 0 08/01/97 4-1/2"LNR 12.6#,L-80, H 11565' 2-3/4" 4 11185-11230 C 03/28/01 •0152 b1:11,D=3.958" TD —I 11760' I 2-7/8" 4 11290- 11370 C 03/28/01 2-7/8"SOLDLNR,6.16#,L-80, —I 11695' . 2-7/8" SLID 11695- 11758 C 03/28/01 .0058 bpt.D=2.372" ,‘,1, 2-7/8"SLID LNR,6.16#,L-80, 11758' ` .0058 bpf,ID=2.372' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/16/97 CHI MULTI-LAT COMPL-RIG 2 08/29/06 GJF/PAG GLV C/O WELL: H-37L1/H-37A 08/22/00 CTD-RL*I 2-7/8"SLTD LNR 11/19/07 JLJ/PJC GLV C/O PB3IT No: 197103/2000970 01/25/03 TN/TP ELM)TT LOGGED/ADPBRF 09/07/10 PP/JMD CORRECTIONS AR No: 50-029-22772-60/01 08/26/04 JLJ/TLP GLV C/O 08/24/12 SJW/JMD FIST k WFD PKR t_EMENT(08/21/12) SEC 21,711N,R13E,3260'NSL&1264'WEL 01/02/05 RUKB/TP GLV CO,OGLV LOST 05/29/06 CO/DTM PE RE CORRECTIONS(6/13/04) BP Exploration(Alaska) L 4-374 • • Rit Ze ootiO Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] a S``L (13 Sent: Thursday, May 09, 2013 10:39 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Bonatham, Manikantesh; AK, OPS Well Pad HU; Weiss, Troy D; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Holt, Ryan P; Walker, Greg (D &C) Subject: OPERABLE: Producer H -37A (PTD# 2000970) Passing OART and PPPOT -IC Attachments: H -37A (PTD #2000970) TIO Plot.docx All, Producer H -37A (PTD #2000970) passed an outer annulus repressurization test and a positive pressure packoff test on the inner casing seals. The tests were performed to evaluate an outer annulus over MOASP event on 04/27/2013. The passing tests confirm integrity. The well is reclassified as Operable. A copy of the TIO plot is included for reference. , Please call with any questions. Thank you, SCANNED NAY . 4 2013 Jack Disbrow BP Alaska - Well Integrity Coordinator SW slob& Walls Organization Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator Pbp.com From: AK, D &C Well Integrity Coordinator Sent: Monday, April 29, 2013 4:04 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, O'S Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Se • es Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad ; Weiss, Troy D; 'jim.regg @alaska.gov'; 'Schwartz, Guy L (DOA)' (guv.schwartz(aalaska.gov) Cc: AK, D &C DHD Well Integrity Engineer; Grey, Leighton (CH2M Hill); A - nd, Jon Subject: UNDER EVALUATION: Producer H -37A (PTD# 2000970) Ex --ded MOASP All, _ T/I/0=284/1700/1500. well i Producer H 37A (PTD# 2000970) exceeded MOASP on 04/27 013 with T /I /0- 284/1700/1500. The is reclassified as Under Evaluation and is to be kept online for further dia: ► •stics. Proposed plan forward: 1. Cameron to PPPOT 2. WIE to evaluate for further diagnostics Attached are copies of the wellsketch and 10 plot for reference. Please call with any questions. 1 PBU H -37A PTD #2000970 5/9/2013 TIO Pressures Plot Well: H -37 4,000 , • 3.000 - Tbg —E— IA 2.000 - -- -DA �— 0 00.E on 1.aar_ - 11,—.111° virerrommorstrommorsliVidi _ 02'09/13 :216d13 02'23/13 03/02'13 03/09913 03116/13 03/23/13 03/30/13 04/06/13 04/13/13 04/20/13 04/27/13 05 2. • RECEIVED STATE OF ALASKA AKA OIL AND GAS CONSERVATION COM ION SEP 18 2012 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations 11 Perforate U Other U Performed: Alter Casing ❑ Pull Tubing0 �Q Stimulate - Frac ❑ Waiver ❑ Time Extensio(J Change Approved Program ❑ Operat. Shutdown❑ f Li'timulate - Other El Re -enter Suspended Wee 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development El Exploratory ❑ 200 -097 -0 3. Address: P.O. Box 196612 Stratigraphid Service ❑ 6. API Number: p Anchorage, AK 99519 -6612 50- 029 - 22772 -01 -00 7. Property Designation (Lease Number): .., 8. Well Name and Number: ADL0028288 PBU H -37A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11760 feet Plugs measured 11155 feet true vertical 9155.78 feet Junk measured 10480 feet Effective Depth measured 11155 feet Packer measured See Attachment feet true vertical 8982.23 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H-40 31 - 111 31 - 111 1530 520 Surface 3744 9 -5/8" 40# L -80 31 - 3775 31 - 3634.82 5750 3090 Intermediate None None None None None None Production 10432 7" 26# L -80 28 - 10460 28 - 8885.51 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10372 - 10384 feet 10565 -10614 feet 10650 - 10900 feet 10950 - 11130 feet 11185 - 11230 feet 11290 - 11370 feet 11695 - 11758 feet 10372 - 11500 feet < -- Lateral Leg True Vertical depth 8842.44 - 8848.39 feet 8942.13 - 8958.42 feet 8963.98 - 8957.26 feet 8957.99 - 8978.5 feet 8986.82 - 8994.37 feet 9004.12 - 9016.95 feet 9107.86 - 9154.24 feet 8842.44 - 8849.13 feet < -- Lateral Leg Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 26 - 10290 26 - 8801.47 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10565' - 10614', 10650' - 10900', 10950' - 11130', 11185' - 11230', 11290' - 11370', 11695' - 11758' SCANNED JAN 2 8 2013, Treatment descriptions including volumes used and final pressure: 75 Bbls 12% HCL, 72 Bbls 9:1 Mud Acid 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 333 1288 184 1400 191 Subsequent to operation: 896 953 1232 1995 350 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Explorator)Q Development 151 + Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil .a is Gas ❑ WbSPUU GSTOR ❑ WINJ ❑ WAG GINJ ❑ sus ❑ SPLutO 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: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature ,i/i,r de/-v Phone 564 -4424 Date 9/18/2012 RBDMS SEP 2 0 201( ei - zs i Z- t O75 /jam Form 10-404 Revised 11/2011 i Submit Original Only • • Packers and SSV's Attachment ADL0028288 SW Name Type MD TVD Depscription H -37A PACKER 10192 8676.09 7" Baker S -3 Packer H -37A PACKER 10393 8777.35 4 -1/2" Baker ML Packer H -37A PACKER 10433 8796.88 5" Baker ZXP Top Packer H -37A PACKER 11440 8953.27 2 -7/8" Baker Liner Top Packer Casing / Tubing Attachment ADLOO28288 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 31 - 111 31 - 111 1530 520 LINER 17 4 -1/2" 12.6# L -80 10393 - 10410 8852.83 - 8861.16 8430 7500 LINER 1140 4 -1/2" 12.6# L -80 10425 - 11565 8868.47 - 9053.17 8430 7500 LINER 320 2 -7/8" 6.16# L -80 11440 - 11760 9028.75 - 9155.78 13450 13890 PRODUCTION 10432 7" 26# L -80 28 - 10460 28 - 8885.51 7240 5410 SURFACE 3744 9 -5/8" 40# L -80 31 - 3775 31 - 3634.82 5750 3090 TUBING 10264 4 -1/2" 12.6# L -80 26 - 10290 26 - 8801.47 8430 7500 • • Daily Report of Well Operations ADL0028288 ACTIVITYDATE ( SUMMARY • w . c . o • • • jec ive: ci • mu a ion MU drift BHA w/ 3.4" JSN. Tag at 10504'. Attempt to jet and make no additional footage. POOH and MU WFD milling BHA w /3.48" 5 bladed concave junk mill. Tagged at 10259'. appears to be a nipple. Able to mill through with ease. Shut down pump and continue in hole. Set down again at 10394' ctm. Start milling. Milled down to 10440' ctm. 8/11/2012 « <Job continued on 8/12/2012 »> CTU #9 1.75" Coil Tubing Job Scope = Acid treatment • Milling w/ WOT 3.5" five bladed junk mill. Milled down to 10463' ctm, slowly, POOH to check mill out due to slow milling. Mill shows wear on the outer edges of the concave face. MU milling BHA #2 w/ 3.47" three bladed convex mill. Slow milling to 10602' cmtd. POOH to check mill. Mill shows wear on the outer ring of the concave mill blades. MU BHAw /GR -CCL -JSN. 8/12/2012 « <Job in Progress »> CTU #9 1.75" Coil Tubing - Job Scope = Acid treatment « <Job continued from 8/12/2012 »> Tagged @ 10556' ctm. Pumped 38 bbls of 12% HCL without being able to make a deeper depth, over displaced with 100 bbls of NH4CL. Logged from 10555' ctm, to 10450' flagged pipe. Logged up to 10100' ctm. POOH. Good tool data at surface. Review log and confirm entry into the L1 lateral. Begin to MU BHA for logging string to simulate treament packer BHA. Gas leak observed from H -31 wellhouse. Notify operator, shut down equipment, secure well and move to edge of pad. Operations bled down and isolated leak return to wellsite. Pump 100 bbls of NH4CI for over displacement and freeze protect well. Rig down and leave location to assist CTU #3. 8/13/2012 « <Job complete - Attempt »> • ASRC Test Unit #4. * *Continued from WSR 8/13/12 ** CT Mud Acid Flowback and Well l est. H -37 8/14/2012 inlet & H -34. Continue rig down. ** Job Complete ** ASRC Test Unit #1 ** *Spotted unit, permit signed, rigged up, pt'd, S/B for CTU * ** Inlet H -37, Outlet H -34 8/17/2012 Job in progress continued on 8 -18 -12 WSR ASRC Test Unit #1 ** *Continued from 8 -17 -12 WSR * * *S /B for CTU * ** Inlet H -37, Outlet H -34 8/18/2012 Continued on 8 -19 -12 WSR, Drills complete for the week Daily Report of Well Operations ADL0028288 CTU #9 1.75" Coil Tubing. Job Scope: Dntt, Acidize w/ Inflatable Packer MIRU. RIH w/ WOT MHA drift with PDS memory gamma ray CCL w/ a 3.4" drift nozzle. Tag at 10,615'CTM. Log up to 10450'CTM and paint flag. Log up to 10,100'CTM. POOH. Download tool data and confirm that tools stayed in the main bore. Rig up WFD inflatable treatment packer and RIH. Correct depth to 10,479'ELM at flag. RIH to 10,515'ELM and PU to ball drop depth. Bullhead 200 bbis of 3 %NH4C1 down backside. Pump full CT volume of 3 %NH4C1 and launch 5/8" ball. 8/19/2012 Trouble shoot ball immobility. « <Job in Progress »> CTU #9 1.75" Coil Tubing. Job Scope: Drift, Acidize w/ Inflatable Packer «< Continued from • 08/19/12 »> Continue to troubleshoot ball immobility. Launch 5/8" ball #2. Ball on seat. Set WFD inflatable treating packer at 10,480'ELM. Verify set. Perform injectivity test down CT below inflatable packer into Ivishak: 0.6 bpm @ 571 psi. 0.7 bpm @ 900 psi. 0.9 bpm @ 1135 psi. 1.0 bpm @ 1135 psi. 1.1 bpm @ 1437 psi. Injectivity >0.5 bpm proceed w/ acid job. Pump 130 bbis of diesel down backside to underbalance, did not achieve positive WHP. Pump acid stim per schedule: 98 bbis 3% NH4CI, 25 bbis 12% HCI, 24 bbls 9:1 Mud Acid, 49 bbis 3% NH4CI, 12 bbls Oil Seeker + 500# wax beads, 25 bbls 12% HCI, 24 bbis 9:1 Mud, 49 bbls 3% NH4CI, 13 bbls Oil Seeker + 500# wax beads, 25 bbls 12% HCI, 24 bbls 9:1 Mud, 48 bbis 3% NH4CI overflushed into formation by CT volume. 8/20/2012 Shear treating packer and begin deflation procedure. « <Job in Progress »> CTU #9 1.75" Coil Tubing. Job Scope: Drift, Acidize w/ Inflatable Packer «< Continued from 08/20/12 »> Allow treating packer to deflate. POOH. Handover well to ASRC for flowback. RDMO « <Job Complete »> 8/21/2012 A portion of the treatment packer rubber was left in hole. .95' x .375" • ASRC Test Unit #1 ** *Continued from 8 -21 -12 WSR Inlet H -37, Outlet H -34 ** *Flow H -37 liquid to tanks, gas to production ** *Start 6 hour well test * ** 8/22/2012 Continued on 8 -23 -12 WSR ASRC Test Unit #1 ** *Continued from 8 -22 -12 WSR Inlet H -37, Outlet H -34 ** *Flow H -37 liquid to tanks, gas to production ** *Start 6 hour well test * * *R /D ** *End job move to DS -13 8/23/2012 r TRH= 41/8" CfW SA TES: HIGH DOG L SEVERITY (35+/100') 1041T- WELLFEAD = F MGGEN 5 • H 7 10500' IN 00 COMPLETED LATERAL. WELL > 70° 0 10587'. ACTUATOR= BAKER ri 3 A NOTE v OGLV LOST IN HOLE-LOCATION UNKNOWN. ` ELEV= .______ 75.48' H -37L1 APPEARS TO BE BELOW MT (KSB - 01- 02 -05) 8F. 8_EEV = 472 1 LL Max Angle _ 94° Q 10746' 1 Es CEMENTER H 1757 1— Datum IA) = 10439' Datum ND = 8800' SS 1 2078' H4-1/2" FES HCO SSSV NP, D = 3.813* 1 GAS LET MANDRELS 19 5/8' CSG. 40#, L-80, D= 8.835' —1 3775' 1 , ■ ST ND TVD DEV 1Y FE VLV LATCH PORT CATE I•J 6 3310 3248 24 CAM00 DOME NT 16 08/26/04 5 5755 5249 35 KBG -2 -LS DMY NT 0 04/08/01 4 7160 6397 35 CAMDD DOME NT 16 08/26/04 3 8021 7109 34 KBG -2 -LS DMY NT 0 04/08/01 2 8881 7810 34 KBG -2 -LS DMY NT 0 04/08/01 1 9737 8495 35 CAM00 SO NT 20 11/13/07 1 RA TAG H 10107' 1--• ' ' 1 10181' JH4-1/2" HES X14 D = 3.813" 1 Minimum ID = 2.37" @ 11459' Z Z 1 10192' H7' X 41/2" BAKER S-3 PKR, D= 3.952" 1 2 -7/8" LINER TOP ' ' 1 10257' H4-1/2" HES X NP, D = 3.813' 1 ' 1 1 10278' H4 -1/2" HES X NP (FP), D = 3.813" 1 14-1/2" TBG, 12.6#, L -80, .0152 bpf, 0 = 3.958" 1-1 10289' 1- 1 10280' H4-1/2' 1NLEG, 0 = 3.958" 1 I 10285' 1--1111,431T LOGGED 09/01/00 1 7" PALLED I DOW - 10377 to 10384' NOTE NO LNR N H-37L1 UPPB2 LATERAL RA TAG 10356' • 1 OPEN HOLE TD_ _I-1 11500' H 37L1 X \i 1 10393' H4 -1/2' X 7" BKR ML PKR, 0 = 3.875" 1 / \ 1 10403' H41/2" FM=SX NP, D= 3.813" 1 14 -1/2" MG, 12.6#, L -80 BT, .0152 bpf, D = 3.958" H 10409' 1 ' - 1 10410' — { -1/2" WLEG, D = 4.00" 1 10410 HELM IT LOGGED 09/01 /00 1 FISH: WFD TREATING PKR ELEMENT, 10480' ELM ( 10425 H BKR TIEBACK SLV, D = 5.25" 1 .95' X .4" (08/21/12) 10433 H7" X 5" BKR ZXP PKR W/ HMC HGR, D = 4.408' 1 17" CSG, 26#, L -80, D = 6.276' H 10460' 1 PERFORATION StAMNRY 11155' H4-1/2" WFD WRP PLUG - 03/28/01 1 REF LOG: MI/VD GR ON 07/29/97 ANGLE AT TOP PEW: 64° 0 10565' , Note: Refer to Production DB for historical pert data 1 11440' H4-1/2" BKR KB LNR PKR, D = 2.44" 1 SIZE SPF NTB2VAL Opn/Sqz DATE J 2 -7/8" 6 10565 - 10614 0 01/25/03 , 1 11459' H2 -7/8" LNR TOP, D = 2.372' 1 2 -314" 4 10650 - 10900 0 08101/97 4 -1/2' LNR, 12.58, L -80, 11565' " / 2 -3/4" 4 10950 - 11130 O 08/01/97 2 -3/4" 4 11185 - 11230 C 03/28/01 .0152 bpf, D = 3.958' 4 7D —J 11760' 1 2 -7/8' 4 11290 - 11370 C 03/28/01 2 -7/8" SOLDLNR, 6.16#, L -80, H 11695' 1 2 -7/8" SLID 11695 - 11758 C 03/28/01 .0058 bpf, D = 2.372' 2 -7/8' SLID LNR, 6.16#, L-80, 11758' .0058 bpf, 0 = 2.372" DATE REV BY COMENTS DATE REV BY COMMENTS PRIDI-DE BAY tNT 08/16197 CHH MULTI -LAT COMPL - RIG 2E 08/29/06 GJF/PAG GLV C/O WELL: H-37L1 / H-37A 08122/00 CTD - RUN 2 -7/8" SLTD LNR 11/19/07 JLJ/PJC GLV C/O PEWIT No: 197103 / 2000970 01/25/03 TNITP EJVD TT LOGGBYADFITIF 09/07 /10 FH'JMD CORRECTIONS AR No: 50- 029 - 22772 -60 / 01 08/26/04 JU/TLP GLV CdO 08/24/12 SW/ /J14.430 FISFt WFD PKR B_EME IT (08/21/12) SEC 21, T11N, R13E, 3260' NSL & 1264' VVB_ 01/02/05 RUKB/TP GLV CIO, OGLV LOST 05/29/06 CO/DIM PERF CORRECTIONS (6/13/04) BP T3cploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 S 1 O AUG 0 8 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission J 333 West 7 Avenue -- 7 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB H -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad H that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Date: 03/17/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft WAS ft na gal H -01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010 11-02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010 H-03 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010 11-04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010 H -05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010 H -06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010 11-07A 2001280 50029202420100 0.6 NA 0.6 NA 3.40 2/15/2010 H -08 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010 H -09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011 H -10A 1971900 50029204870100 0.3 NA 0.3 NA 1.70 2/19/2010 H -11 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010 11-12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010 H -13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18 /2010 H -14B 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18 /2010 H -15 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 H -16 2000650 50029205920200 0 NA NA NA NA NA H -17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011 H -18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 H -19B 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010 H -20 1830070 50029208960000 6.7 NA 6.7 NA 47.60 2/22/2010 H -21 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010 H -22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010 H -23A 1950850 50029217940100 5 NA 5 NA 32.30 2/17/2010 H -24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010 11-25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/26/2010 H -26 1852770 50029214870000 2.3 NA 2.3 NA 17.90 2/23/2010 H -27A 2030590 50029214560100 0.1 NA 0.1 NA 0.85 2/21/2010 11-28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010 H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 H -30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 H -31 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010 H -32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010 11-33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010 11-34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010 11-35 1951490 50029226000000 1.7 NA 1.7 NA 15.30 2/16/2010 H -36A 2000250 50029226050100 1.3 NA 1.3 NA 11.90 2/17/2010 H -37A 2000970 50029227720100 1.2 _ NA 1.2 NA 10.20 2/20/2010 11-38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012 • McMains, Stephen E (DOA) From: Stewman, Sondra D [Sondra.Stewman @bp.com] - ` -- ell_ Sent: Thursday, January 13, 2011 12:00 PM To: McMains, Stephen E (DOA) Cc: Phillips, Patti J Subject: FW: H -37 Status From: Warren, Mike (Orbis) Sent: Thursday, November 29, 2001 10:42 AM To: 'tom_maunder @admin.state.ak.us' Cc: Hubble, Terre L Subject: H -37 Status Yes, H -37 is producing. There may be some confusion because this is a "dump flood" well. The original well has both Ivishak (H -37) and Sag laterals (1- 37L1). However, the well had trouble staying online due to lack of pressure support. Later, we extended the Ivishak lateral below the OWC (H -37A), and set up the extension to dump flood the lower portion of the pay below a plug. The original Ivishak lateral is still open and producing above the plug. Hope this helps. Mike 564 -4306. JA 1 2 1 OPERABLE: H-37A (PTD #2000) Tubing integrity restored Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, November 16, 2007 9:16 AM ~~''-~~~ fl~Z~l~ To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Starck, Jennifer L Cc: Roschinger, Torin T. Subject: OPERABLE: H-37A (PTD #2000970) Tubing integrity restored Follow Up Flag: Follow up Flag Status: Green ~~~~ N~-,~ ~,. ZQ~~ Hi All, Fi-37A (PTD #2000970) has been classified as Under Evaluation due to a failed TIFL. The OGLV has been changed out and a second TIFL has been conducted. This subsequent TIFL passed confirming that tubing integrity has been restored The well has been reclassi€ied as Operable with normal MAASP and may be put on production when convenient. Thank you, ~~ 11 /26/2007 UNDER EVALUATION: H-37A~D #2000970) Sustained IAP Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ ~ 11'Zl~ct7 Sent: Friday, November 09, 2007 7:37 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Starck, Jennifer L Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: H-37A (PTD #2000970) Sustained IAP Attachments: H-37A.pdf; H-37 90-day TIO PIot.BMP All, Well H-37A (PTD #2000970) has been found to have sustained casing pressure on the IA. The TIOs were 2050/2050/10 psi on 11/09/07. At that time, the well failed a TIFL. The well has been reclassified as Under Evaluation and can be produced under a 28-day clock. The plan fonnrard is as follows: 1. D: TIFL -FAILED 2. S: C/O OGLV 3. D: Re-TIFL A wellbore schematic and TIO plot have been included for reference. «H-37A.pdf» «H-37 90-day TIO PIot.BMP» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 SC"P = Zti~ ~s ~] `~ c s~ N1~t P = ZZ~~~ Z ~~, ~.4h?~ ~-~ c~C J ~~r- C~ ~ v 11 /21 /2007 TREE= 4-118" CNV >~ WELLHEAD = FMC-GEN 5 ACTUATOR ~ BAKER KB: 1=iEV = a~.48' BF. cLEV - 47.2` KOP = "L387' Max Angle = 94 @ 10746` Dat~arn MD = 10439` DatumTVD = 8800' SS 9 518" CSG. 403f, L-80, ID = 8.835°' '--( 3775` RA TAG H 10107' ICt1illUi'i'I III = 2.37" 1+77 1'1459 2-718" LINER TOP 4-1/2" 7BG, 12.611, L-80, .0152 bpf, ID = 3.958" ~---~ 10289' sAFEI" ES. HIGH DOG LEG SEVERITY {s5+11 flfl ) 14417'-10500' IN COMPLETED LATERAL. WELL> 7®° @ 1 fl587' ~ > 90° @ 10700'. NOTE: 1" OGLV LOST IN HOLE-LOCATION UNI{NOWN, APPEARS TO BE BELOW ES CE,MENTER~ 1757' EOT {ICSB - 01-02-fly} I 4-1 i2" HES HXO SSSV NIP, ID = 3.813" I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3310 3248 24 CAMCO DOME INT 16 08126/04 5 5755 5249 35 KBG-2-LS DMY iNT 0 04108101 4 7160 6397 35 CAMCO DOME INT 16 08126104 3 $021 7109 34 KBG-2-LS DMY INT 0 04108(01 2 8881 7810 34 KBG-2-LS DMY INT 0 04108101 1 9737 8495 35 CAMCO SO INT 20 08J29t06 10181' 4-112" HES X NIP, ID = 3.813" 10192' 7' X 4-112" BAKER 5-3 PKR, ID = 3.952" 10257' 4-112" HES X NIP, ID = 3.813" 10278' 4-1 t2" HES X NIP (HP}, ID = 3.813" 10290' ~ 4-1r2" `/VLEG; ID = 3.95$" 102$5' ELMD TT LOGGED 09101100 7" MILLED WINDOW - 10372' to 10384' NOTE: NO LNR 1N H-37L1 UPPER LATERAL RA TAG I--I 10356' OPEN HOLE TD H ,11500° .......10393' -~ 4-112" X 7" BKR ML PKR, ID = 3.875" 10403° 4-112" HES X NIP, ID = 3.$13„ 4-112" TBG; 126#, L-80 IBT:.0152 bpf, ID = 3.958" 10409' 10410' 4-1 t2" WLEG, ID =.4.00" 1{}410 ELN1D TT LOGGED 09,'01!00 10425 BKR TIEBACK SLV, ID = 5.25" 10433 ~ 7" X 5" BKR ZXP PKR W,- HMC HGR, ED = 4,408" 7" CSG, 26#, L-80: ID = 6.276°' I~ 10460' PERFORATION SUtv1MARY REF LOG: MVtrD GR ON 07129.'97 ANGLE AT TOP PERF: 64 ~; 10565' Nate: Refer to Prodiicllon DB for historical peri data SIZE SPF INTERVAL Opn!Sgz DATE 2-718" 6 10565- 1()di14 O 01t25r'O:i 2-314" 4 10650 - 10900 O 08101197 2-3,"4" 4 10950- 11130 O 08;01f97 2-3r4" 4 11185 - 11230 C 03128101 2-7;$" 4 11290 - 11370 C 03128(01 2-7; 8" SLID 11605 - 11758 C 03!28!01 DATE REV BY COM~,IENTS DATE REV BY COMMENTS 0811fi197 GHH MULTI-LAT COMPL -RIG 2 01i02f05 RLrKBITP GLV CIO. OGLV LOST 08122(00 CTD -RUN 2-718" SLTD LNR 05/29108 CO/DTPJI PERF CORRECTIONS (611 01;25103 TNi~TP EL_P~IDTTLOGGED!ADPERF 08129106 GJFlPAG GLV CiC) 07r15i03 CMO!TLP MAX ANGLE CORRECTION -°---.._.._.._....__•-- 06;25;04 L4rti'BfKAK CORRECT MANDREL DEPTH 08,26;04 JLJ/TLP GLV C?O 11440' --~ 4-1/2" BKR KB LNR PKR, ID = 2.44" 11459' 2-7x8" LNR TOP, iD = 2.372„ PRUDHOE BAY UNIT WELL: H-37A MULTI-LAT PERMIT No: 2000970 AI~I No: 50-029-22772-01 SEC 21, T11N, R13E, 3260' NSL & 1264' VdEL BP Exploration {Alaska} 11155' {-I 4-1;2" ~VFD VL1RP PLUG - 03/28?01 ~'~ t-I -3 7 A a,oor, H-~7 TIO Plot -Y- Tbg 3,000 -~- IA IA MAA~P -~- OA OA MAASP OOA 1,000 0 ,,,,,,,,,,,,,, t OOOA 819!2007 8/2472007 9~t2007 912472007 10+'312007 1012x72007 11!972007 11I24t2007 • • Well Job# LOQ Description ate o or H-13 11676950 GAS ENTRY SURVEY 06/20/07 , C-41 11801077 LDL 06/19/07 1 A-30A 11661159 MEM PROD PROFILE 06/23/07 1 W-21A 11661140 MEM PROD PROFILE 04/21/07 1 E-21B 11661157 MEM PROD PROFILE 06/19/07 1 M-23 11626107 PRODUCTION PROFILE 06/23/07 1 01-21 11824330 PRODUCTION PROFILE 06/22/07 1 J-25A 11767130 MEM PROD PROFILE 06/18/07 1 Z-08A 11630483 GLS/PROD LOG 06/22/07 1 M-34 11824330 PRODUCTION PROFILE 06/22/07 1 02-30B 11594512 LDL 06/23/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 S-38 11801078 LDL 06/20/07 1 H-37A 11594506 PPROF/IPROF (REVISED) 06/05/07 1 N-15 11637129 PROD PROFILE (REVISED) 06/13/07 1 Z-13A 11649962 MEM PROD PROF (REVISED) 04/21/07 1 P2-15A 11594511 SCMT 06/15/07 1 12-05 11676951 USIT (CEMENT) 06/24/07 1 12-05 11676951 USIT (CORROSION) 06/24/07 1 B-15 11626097 US IT 06/14/07 1 G-24A 11628750 SCMT 02/05/07 1 Scblumberger Alaska Data & Consulting Services 2625 Gambell Street, Suite 400 Anchorage, AK 99603-2838 ATTN: Beth RECEIVED JUL 0 3 Z007 Alaska Oil & Gas Coos. CommIssion Anchorage 06/29/07 NO. 4324 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay D BL CI CD . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. SCANNED JULO 5 2007 Anchorage, Alaska 99508 Date Delivered: 9ro-tf1'? Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~- .' '\,.,.' ~'." - -..,. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X ADD PERFS Pull tubing _ Alter casing _ Repair well _ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 75 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchora~le, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2018' FNL, 1264' FEL, Sec. 21, T11 N, R13E, UM (asp's 643339, 5958770) H-37A At top of productive interval 9. Permit number / approval number 121' FNL, 4579' FEL, Sec. 28, T11 N, R13E, UM (asp's 640098, 5955326)"" ,,~ 200-097 At effective depth 10. APl number 597' FNL, 124' FEL, Sec. 29, T11 N, R13E, UM (asp's 639284, 5954835) 50-029-22772-01 At total depth 11. Field / Pool 659' FNL, 281' FEL, Sec. 29, T11 N, R13E, UM (asp's 639128, 5954770) Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11760 feet Plugs (measured) Tagged TD @ 11157' (01/25/2003) true vertical 9155 feet WRF (IBP) Set @ 11555' (03/28/2001) Effective depth: measured 11555 feet Junk (measured) Milled Window f/10372' - 10384' (well H-37L1). true vertical 9050 feet H-37L1 is an OH completion - TD @ 11500'. Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 260 sx Arctic Set (Aprox) 138' 138' Surface 3744' 9-5/8" 1800 sx CS III, 400 sx Class 'G' 3775' 3635' Intermediate 10432' 7" 493 sx Class 'G' 10460' 8885' Liner 1140' 4-1/2" 142 sx Class 'G' 10425' - 11565' 8868' - 9053' Uncemented Slotted Sidetrack Liner 320' 2-7/8" Liner 11440' - 11760' 9028' - 9155' Perforation depth: measured Open Perfs 10558'-10614', 10650'-10900', 10950'-11130', Open Perfs Below IBP 11185'-11230', 11290'-11370', Slotted Liner ~1~1...7~)(7~1 true vertical Open Perfs 8939'-8958', 8964'-8957', 8958'-8978', Open Perfs Below IBP 8978'-8995', 9004'-9017', Slotted Li.n.e_r$~,,lj~.,tS. ~ Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, TBG @ 10192' MD. 4-1/2" 12.6# Tubing Tail belOw ~'~)oT~' ~1~285'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 PKR @ 10918'. 4-1/2" x7" BKR ML PKR @ 10393' w/tbg to 10404'. 7" x 5" BKR ZXP PKR @ 10425'. 4-1/2" HES HXO SSSV Landing Nipple @ 2078' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 10/30/2002 436 660 411 187 Subsequent to operation 09/12/2002 366 4062 141 187 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil _X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Technical Assistant Date February 11,2003 DeWayne R. Schnorr Prepared by DeWayne R. Sc=hnorr 564-5174 Form 10-404 Rev 06/15/88 · ..~ ~ ....... SUBMIT IN DUPLICATE 10/05/2002 10/24/2002 10/25/2OO2 10/28/2OO2 10/30/2002 11/01/2002 11/02/2002 01/24/2003 01/25/2003 01/30/2003 10/05/02 10/24/O2 10/25/O2 1 O/28/O2 10/30/02 11/01/O2 11/02/02 H-37A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PERFORATING: DRIFT/TAG SBHP/FBHP SURVEY: DRIFT/TAG; STATIC BOI-FOM HOLE PRESSURE SURVEY SBHP/FBHP SURVEY: DRIFT/TAG; STATIC BOTTOM HOLE PRESSURE SURVEY SBHP/FBHP SURVEY: FISH TESTEVENT--- BOPD: 436, BWPD: 411, MCFPD: 3,690, AL Rate: 3,030 PERFORATING: PERFORATING PERFORATING: FISH; PERFORATING PERFORATING: JEWELRY LOG--DEPTH CONTROL; PERFORATING PERFORATING: JEWELRY LOG--DEPTH CONTROL; PERFORATING TESTEVENT--- BOPD: 366, BWPD: 141, MCFPD: 6.872, AL Rate: 2,810 EVENT SUMMARY D&T WITH 3" CENT, TTL AND S/BAILER TO 10,568' CORRECTED (82' OF FILL) --- RIH WITH S/BAILER AND GOT TRACE AMOUNTS OF FORMATION SAND --- RIH W/DD/BAILER AND STOPPED @ 10,597' CORRECTED (DUE TO DEVIATION.) <<< TURN WELL OVER TO PAD OPERATOR >>> DRIFT AND TAG W/3 3/8" X 10 ' DUMMY GUN, TEL, SB TO 10467' SLM, 10463' ELM. STOPPED DUE TO DEVATION,--( HAW ) --- (TARGET DEPTH IS 10,614). RE-DRIFT W/ROLLER STEM AND 2 7/8" X 10' DUMMY GUN SB TO 10610' SLM, ( HAW), TARGET 10614' ---. LOST TOOL STRING AT 10400'. WHILE POOH. RECOVERED ALL WIRE. ROPE SKT, QC, 5' OF 2 1/8 ROLLER STEM. QC, K J, OIL JARS, QC, LS SPANGS, QC, KJ, 10 1/2' DUMMY GUN, XO, SAMPLE BLR. TOTAL LENGTH IS 33.44' RECOVER LOST TOOLS FROM 10561' SLM. ( NOTE: GO EXTREMELY SLOW 35' PER MIN THROUGH LOWER TT @ 10410' MD WATCH FOR POSSIBLE CUTTING OF WIRE) .... TESTEVENT --- BOPD: 436, BWPD: 411, MCFPD: 3,690, AL Rate: 3,030 RIH W/10' 2-7/8" HSD GUN. GUN STUCK IN RESTRICTION @ 10403' MD. ATTEMPT TO FLOW & PUMP DOWNHOLE. UNABLE TO FREE TOOLS. PULL OUT OF WEAK POINT. POOH. ALL WIRE RETREIVED. TOOLS LEFT DN HOLE ARE ..... HEAD--AH-38--1 11/16 WEIGHT BAR---ROLLERS---10 FT 2 7/8 GUN-- STEM ROLLERS-- TOTAL LENGTH 25.5 FT-- MAX OD 3.5 "- WELL TURNED BACK TO PAD OP. WELL LEFT SHUT IN-- LATCH & PULL E-LINE TOOL STRING & PERF GUN FROM 10,418' AMS - RECOVER ALL TOOLS. <<< WELL TO REMAIN SHUT-IN >>> Page I H-37A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/24/03 MIRU CTU #9. RIH WITH PDS MEMORY GR/CCL. <<< JOB IN PROGRESS >>> 01/25/03 RIH WITH PDS MEMORY GR/CCL. TAGGED WRP @ 11157'. LOGGED MEMORY GR/CCL FROM 11155' TO 10150'. PAINTED FLAG @ 10500'. POOH. REVIEWED DATA (-8' CORRECTION TO BE ON DEPTH WITH PSP 09/01/2000). UNDERBALANCED PERFORATE 10558'-10607' (09/01/2000 PSP DEPTHS)IN TWO RUNS WITH 2-7/8" HSD PJ 2906, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION GUNS. NOTE: PERF DEPTHS CONVERTED TO REFERENCE LOG DEPTHS = 10565'-10614'. WELL TURNED OVER TO PCC FLOWING (REQUESTED TEST). 01/30/03 TESTEVENT --- BOPD: 366, BWPD: 141, MCFPD: 6,872, AL Rate: 2,810 Fluids Pumped BBLS 205 60/40 METHANOL WATER 205 TOTAL ADD PERFS 01/25/2003 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-7/8" HSD PJ2906, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 10565'-10614' Page 2 Permit to Drill 2000970 DATA SUBMITTAL COMPLIANCE REPORT 919/2002 Well Name/No. PRUDHOE BAY UNIT H-37A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22772-01-00 MD 11760 TVD 9156 Completion Dat 8/22/2000 Completion Statu 1WINJ Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Sample N_~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH I Dataset Name Scale Media No Start Stop CH Received Number Comments ED C Pdf ED C Pdf ED C Pdf ED C Pdf ED C Pdf ED C Pdf ED C Pdf D ED G~Pdf GR Gamma Ray ~ GR Ind Ind GR GR Ind L C D R D R Gamma Ray ~ Induction/Resistivity, Induction/Resistivity Gamma Ray ~ Gamma Ray -- Induction/Resistivity Ind Induction/Resistivity PROD-SPIN/TEM/ 10343 10351 LIS Verification '"-- 10352 LIS Verification final 11565 11760 11535 11717 final 11676 11656 final 11565 11760 final 11676 11656 final 11565 11760 final 11676 11656 final 11565 11760 FINAL 10280 11540 FINAL 10280 11540 FINAL 11528 11607 FINAL FINAL 11535 11717 FINAL final 11528 11607 11676 11656 10280 11540 O O 3en O ~en O 3en O ~en O ~en O ~en O 3en CH CH oh oh oh oh Open Open Case 3en 11/13/2001 10466 10/10/2001 10352- 11535-11717 11/13/2001 10467 - 11/13/2001 10466 -- 11/13/2001 10467 - 11/13/2001 10466 ~ 11/13/2001 10467 11/13/2001 10466 ~ 9~8/2000 PRES 10280-11540 9/28/2001 10343 ---~280-11540 Digital Data 10/10/2001 10351 --t1528-11607 LIS Verification 10/10/2001 LIS Verification Paper copy 10/10/2001 10352 --11535-11717 Digital data 10/10/2001 LIS Verification Paper Copy 10/10/2001 10351 '~11528-11607 11/13/2001 10467--- 9/28/2001 10343 --"1'0280-11540 Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Permit to Drill 2000970 MD 11760 TVD Well Cored? Y / Chips Received? Analysis Y / N DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. PRUDHOE BAY UNIT H-37A Operator BP EXPLORATION (ALASKA) INC 9156 Completion Dat 8/22/2000 Completion Statu 1WINJ Current Status Daily History Received? ~ N Formation Tops (~)/N 1-OIL APl No. $0-029-22772-01-00 UIC N Comments: Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska October 12, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: H-37A & H-37A PB 1, AK-MW-00153 H-37A & H-37A PBI: Digital Log Images: 2 CD Rom Discs PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska MWD Formation Evaluation Logs H-37A PB 1, October 4, 2001 AK-MW-00153 1 LDWG formatted Disc with verification listing. API#: 50-029-22772-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED ocr 1o ooI WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska MWD Formation Evaluation Logs H-37A, AK-MW-00153 October 4, 2001 02oo-09-7 1 LDWG formatted Disc with verification listing. API#: 50-029-22772-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: ECEIYED OCT 0 2001 A~chorage 09/13/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503,571t ATTN: Sherrie NO. 1454 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Color Log Description Date Blueline Sepia Prints CD D.S. 16-06A ,,-~(~l--OOt~· 21371 MGR (PDC) 02123101 H-37A. ~'~,(-~l') _(~c) ~ i 21368 MGR 09/01100 1 L-01 ~-I~/~'~:.~ 21375 FRAC ADVISOR TVD (KUPARUK SECTION) 06/t9101 2 L-01 L.,~.-~'.-":i I C:~., 21378 FRAC ADVISOR TVD (SCHRADER BLUFF) 06119101 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie f,~ Rece~,~'-~--~~----~' REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Acid & IBP (WRP) Pulltubing_ Alter casing _ Repair well _ Other_X IBP 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 , Anchorage, AK 99519-6612 5. Type of Well: Development Explorato~__ Stratigraphic._ Servic~ 4. Location of well at surface 2018' FNL, 1264' FEL, Sec. 21, T11N, R13E, UM At top of productive interval 121' FNL, 4579' FEL, Sec. 28, T11N, R13E, UM At effective depth 596' FNL, 123' FEL, Sec. 29, T11N, R13E, UM At total depth 658' FNL, 281' FEL, Sec. 29, T11N, R13E, UM (asp's 643339, 5958770) (asp's n/a) (asp's 639284, 594835) (asp's 639128, 5954770) 12. Present well condition summary Total depth: measured true vertical 11760 feet Plugs (measured) 9155 feet 6. Datum elevation (DF or KB feet) RKB 75 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number H-37A 9. Permit number / approval number 10. APl nu~ 50-029-22772-01 11. Field / Pool Prudhoe Bay Oil Pool WRF (IBP) SET @ 11555 (03/28/2001) Effective depth: measured 11555 feet true vertical 9050 feet Junk (measured) Milled Window.f/10372 - 10384' (well H-37L1) H-37L1 is an OH completion - TD @ 11500'. Casing Length Conductor 110' Surface 3744' Production 10432' Liner 1140' Sidetrack Liner 320' Size Cemented Measured Depth True Vertical Depth 20" x 30" 260 sx Arctic Set (Approx 138' 138' 9-5/8" 1800 sx CS Ill, 400 sx 3775' 3635' Class 'G' 7" 493 sx Class 'G' 10460' 8885' 4 sxo,ass, , 2-7/8" Uncemented Slotted Line 11440' - 1171 ~.~155' Perforation depth: AUG 1 6 2001 measured Open Peals 10650' - 10900', 10950' - 11130', Open Perfs Below IBP 11185' - 11230', 11290' - 11370'~i1~6eS true vertical Open Perfs 8964' - 8957', 8958' - 8978', Anchorage Open Perfs Below IBP 8987'- 8995', 9004'- 9017', Slotted Liner 9111'- 9156'. Tubing (size, grade, and measured depth) 4-1/2" 12.6#, L-80 TBG @ 10192'. 4-1/2" 12.6# Tubing Tail below PKR to 10285'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 PKR @ 10918'. 4-1/2" x 7" BKR ML PKR @ 10393' w/tbg to 10404'. 7" x 5" BKR ZXP PKR @ 10425'. 4-1/2" HES HXO SSSV Landing Nipple @ 2078'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well opera 03/28/2001 Subsequent to op~ 04/15/2001 OiI-Bbl 0 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 0 0 963 1639 436 Casing Pressure Tubing Pressure 0 o 1447 276 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations _ Oil _'~, Gas __ 17. I hereby certify that the foregoing is true and correct to the best of my knoWledge. Title: Technical Assistant DeWayne R. Sc norr ~ Suspended__ Service _ Date August 15. 2001 Prepared by DeWayne R. Schnorr 564-5174 ORIGINAL, Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE TREE = 4" ClW WELLHEAD = FMC-GEN 5 ACTUATOR = BAKER KB. ELEV = 75.48' BF. ELEV = 47.2' KOP = 2387' Max Angle = 94 @ 10745' Datum MD = 10439' Datum TVD = 8800' H-37A F~ROM,/NOTES: HIGH DOGLEG SEVERITY (35+/100') 10417'-10500' IN COMPLEI'ED LATERAL. 2078' I~ 4-1/2" HES HXO SSSV NIP, ID = 3.813" 19 5~8" CSG. 40#, L-80, ID = 8.835" Id 3775' ~--~ DAT~ IMinimum ID = 2.44" @ 11440'I 2-7/8" LINER TOP I RATAGI-J 10107' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID: 3.958" Id 10290' I P~ ~^G H ~ 0356' KBG-2-LS KBG-2-LS 10181' J-I 4-1/2" HES X NIP, ID: 3.813" J 10192' J~ 7'x4-1/2" BAKERS-3 PKR, ID= 3.952" J 10257' Id 4 1/2" HES X NIP, ID: 3.813" I 10278' Id' 4 1/2" HES X NIP (HP), ID: 3.813" I ~02~0' H 4-1/2" WLEG, ID = 3.958"I ~o28s' H ~_M~o~ o~o~oo I MILLED WINDOW - 10372 TO 10384'- H-37 L1 I I /W / 6' TIE BACK SLEEVE, ID: 5.25" 10403' J-'l 4-1/2" HES X NIP, ID: 3.813" J 14-1/2" LNP~ 12.6#, L-80 ,BT,.6392bpf, ID= 3.958" H ~04~0' ~04~0' i--t 4-1/2" WLEG, ID =4.00"I 10404' Jfl ELMD'IT LOGGED 09/01/00 J J TOP OF 4-1/2" LNR Jd 10425' 10425' J 7" CSG, 26#, L-80, iD = 6.276" Jfl 10460' I I 1~55'1-1 4-1/2"WFDWRPPLUG-03/28/01 J REF LOG: MWD GR ON 07/29/97 I '2'~ i . , . . , L. I Note: Refer to Production DB for historical perf data ~ATE ~ /.r/%."'~. \ 1/Ol/9; ~/01/9; __ 1.0152 bpf, ID = 3.958" I / '. ' ' ' !~o. o. ~-~,~"~N., ~.~#, ~_~o, .o~ I ~O~OMO. SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4" 4 10650' -10900' O 08/01/97 2-3/4" 4 10950' -11130' O 08/01/97 2-3/4" 4 11185'- 11230' O 08/01/97 2-3/4" 4 11290' -11370' O 08/01/97 2-7/8" 11695'-11758' SLOT 08/28/00 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/16/97 CHH Multi-lat Completion - RIG 2ES WELL: H-37A MULTI-LAT 08101100 CT 2ND EXTEN - 4-1/2" LNR PERMIT No: 200-097 12/08/00 SiS-QAA CANVAS- KKRIEGER REVIEW APl No: 50-029-22772-01 01/29/01 SIS-MD FINAL Sec. 21, T11N, R13E 08/08/01 RN/TP CORRECTIONS BP Exploration (Alas ka) H-37A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/26/2000 CTD-POST WORK: SBHPS, GLV INSTALLATION 08/27/2000 CTD-POST WORK: POST CTD SIDETRACK 09/01/2000 09/23/2000 02/21/2001 03/26/2001 03/27/2001 03/28/2001 DRILL-POST WORK: STATIC FSPL DRILL-POST WORK: SBHPS: AVG PRESS = 3408 PSI @ 8800' PSI DRILL-POST WORK: D&T {PRE CT ACID STIM } DRILL-POST WORK: VENTURI FCC / ACID STIM (3 ZONES) DRILL-POST WORK: VENTURI FCC / ACID STIM (3 ZONES) --DAY 2-- DRILL-POST WORK: ACID STIM (3 INTERVALS) --DAY 3-- EVENT SUMMARY O8/26/0O POST CTD. RAN 2.70" CENTRALIZER AND PDS GAUGES. OVERCOME BY DEVIATION AT 10604' WLM. PERFORM SBHP SURVEY. SET CATCHER AND PULLED DGLV FROM STA #3. 08/27/00 COMPLETED GAS LIFT INSTALLATION. PULLED DGLVS FROM STATIONS 5 & 6. RAN LGLVS IN STATIONS 5 & 6, ORIFICE IN STATION 3. PULL CATCHER. 09/01/00 O9/23/O0 02/21/01 03/26/01 03/27/01 CTE FSPL; NO FIELD PICK EVIDENCE OF CROSSFLOW. WELL WAS INITIALLY LOGGED SI AND THEN LOGGED FLOWING. NO CROSSFLOW WAS SEEN IN EITHER CONFIGURATION. FLOWING PASSES SHOWED ALL PRODUCTION COMING FROM 2-7/8" SLOTTED LINER PERFORMED STATIC SURVEY W/SPARTEK GAUGES. 8800' TVD = 3408 PSI, 229 DEG F. R.I.H. 3.50 DRITF WENT TO 10,612 {SLM} JAR DOWN A FEW TIMES MADE NO HOLE P.O.O.H. RIG DOWN. MIRU DOWELL-SLB CTU #8. LOAD AND KILL WELL W/2% KCL. SET DOWN W/ VENTURI JUNK BASKET @ 10,350'--COULD NOT PASS (SUSPECT WINDOW FOR UPPER LATERAL). RECOVER FORMATION (PIECES OF SHALE) AND METAL SHAVINGS. MADE SECOND TRIP WITH MODIFIED VENTURI BASKET WITH FISHING MOTOR. SAT DOWN AT10,379'. ROTATE THROUGH. SAT DOWN AGAIN AT 10,405' (TAILPIPE ASSY ?). ROTATE THROUGH. RAN BASKET TO 11,419'. SAT DOWN WITH NO FURTHER HEADWAY. POH. RECOVER LARGE STONE LODGED IN MOUTH OF BASKET. CONT' ON WSR 3/27/01 ... CONT' FROM WSR 3/26/01 ... RIH WITH BHA #3--VENTURI JB--SAME AS #2. SAT DOWN AT10,371' (8' HIGHER). ROTATE THROUGH. RAN BASKET TO 11,411' SAT DOWN (8' HIGHER). POH. RECOVERED FORMATION, SMALL ROCKS AND METAL FRAGMENTS. RIH W/BHA #4--SAME VENTURI JB. PASS Page I 03/27/01 BY UPPER LATERAL / PACKER. CLEAN OUT 4 1/2 LINER TO 11,435' (CTM). CONTINUED SMALL AMOUNT OF METAL SHAVINGS IN BAILER. RIH W/3 1/2" JET PACK STRADDLE PACKER. TAG TOP OF 2 7/8" LINER, CORRECT DEPTH. TEST TREATMENT PACKERS TO 3000 PSIG IN BLANK PIPE - GOOD. SET PACKERS AND TREAT LOWER INTERVAL AS PER PROGRAM, SAW GOOD PRESURE BREAKS. CONT' ON WSR 3/28/01 ... 03/28/01 CONT' FROM WSR 3/27/01 ... COMPLETE DAD/MUD ACID TREATMENT ON THREE INTERVALS:(11,320' - 11,340'), ( 11,210' - 11,230'), (11,185' - 11,205). ALL TREATMENTS AND PACKER SETS WENT AS PLANNED WITH DEFINITE INDICATION OF BREAKDOWN AS MUD ACID CONTACTED PERFS. ADDITIVE INJECTION INTO 3 ZONES: 3.2 BPM @ 2000 PSI. RIH W/WFD 4 1/2" WRP (IBP) PLUG. >>>WRP PLUG SET @ 11,155' (ELMD)<<< ***NOTIFY PCC TO LEAVE WELL SHUT IN FOR DUMP FLOOD INJECTION BELOW IBP.*** THIS WELL IS STILL AN OIL PRODUCING WELL. FLUIDS PUMPED BBLS I PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (1 TESTS) 56 METHANOL WATER 365 60/40 METHANOL WATER 400 NH4CL 390 iDS 2% KCL WATER 1212 TOTAL Page 2 ALASKA(~ . AND STATE OF ALASKA GAS CONSERVATION COMI~ iON WELL COMPLETION OR RECOMPLETION REPOR~AND LOG "i. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-097 300-170 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22772-01 'ii' Location of well at surface r ,, ,~. ~..,...,....-'~ ~ 9. Unit or Lease Name 3261' NSL, 1265' WEL, SEC. 21, T11N, R13E, UM ,~ ......... ~ .~.':, ;~ ~ .~ VI~,r~_; Prudhoe Bay Unit. At t,o,p of produ,,ctive interval i ;~,.,..¢,, l';2"~"-'::-g~'~~t,,~~. 121 SNL, 4579 WEL, SEC. 28, T11N, R13E, UM ~ ,'~';:;:: :;~ 10. Well Number At ~otal dept,h, 658 SNL, 281 WEL, SEC. 29, T11N, R13E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 75.48' ADL 028286 12. Date Spudded 8/19/2000 113' Date T'D' Reached 114' Date COmp'' Susp'' Or Aband' 8~20~2000 8/22/2000 115' Water depth' if OffshOre N/A MSL II 16' N°' °f C°mpleti°ns One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 11760 9156 FTI 11760 9156 FTI []Yes [] NoI (Nipple) 2078' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SiZE CEMENTING RECORD AMOUNT PULLED 20" 94# L-80 Surface 110' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 31' 3775' 12-1/4" 1800 sx CS III, 400 sx Class 'G' 7" 26# L-80 28' 10460' 8-1/2" ¢93 sx Class 'G' 4-1/2" 12.6# L-80 10425' 11565' 6" 142 sx C lass 'G' 2-7/8" 6.16# L-80 11440' 11760' 3-3/4" LJncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4spf 2-7/8" Slotted Liner 4-1/2", 12.6#, L-80 10290' 10192' MD TVD MD TVD 4-1/2", 12.6#, L-80 11393'- 11410' 10393' 11290' - 11370' 9004' - 9017' 11695' - 11758' 9108' - 9154' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. (Re-per[) DEPTH INTERVAL {MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 20 Bbls of MeOH 0 R I G INA L 27. PRODUCTION TEST ~N' '-- '-' ~'""~" ,,, Date First Production Method of Operation (Flowing, gas lift, etc.) AJas~8 0i~ & Gas Co~$. August 28, 2000 Water Injection AllChora~e 'Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL'BBL iGAs-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Top of Zone 3 11739' 9140' HOT 11585' 9058' COWC 11661' 9088' RECEIVED SEP 22 2O00 A~aske 0~ & Gas Cons. ~mmissior~ Anchorage 3.1" List of Attachments: Summary of Daily Drilling Reports, Surveys ...... , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~'~_ ~ Title TechnicalAssistant Date H-37A 200-097 300-170 Prepared By Narne/Nurnbec Terrie Hubble, 564-4628 'Well Number Permit No. / Approval No. 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28.' If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ·. O.Deration s_ Summary'-- :ReD°rt---.--- - i Legal Well Name: H-37a Common Well Name: H-37a Spud Date: 8/17/2000 Event Name: RE ENTER Start: 8/17/2000 End: 8/22/2000 Contractor Name: NORDIC CALISTA Rig Release: 8/22/2000 Group: RIG Rig Name: NORDIC 1 Rig Number: Date From !To HOUr~ ACtivi~ COde phase Des~;iPtiDn of OPe~.~EIVED 8/17/2000 19:00 - 21:00 2.00 RIGU PROD1 ACCEPT RIG AT 1900 HRS ON 8/17/00. Hook up lines to DOPE. SEP 2- 2 ?.000 21:00 - 21:15 0.25 RIGU PROD1 PJSM for stabbing coil. 21:15 23:15 2.00 RIGU PROD1 Stab coil. Spot cuffings tank and berm ~¢~a ~'J & Gas ~Jons. Commissh 23:15 - 00:00 0.75 RIGU PROD1 Change out packoff in injector. ~Ch0i-aD(~ 8/18/2000 00:00 - 02:00 2.00 BOPSUF PROD1 Test DOPE 250/4000 psi. Witnessing of test waived by J. Spaulding - ^OGCC. Unable to get satisfactory HP test. Call grease crew to come out and grease xmas tree valves. 02:00 - 02:30 0.50 BOPSUF OTHR PROD1 Wait on grease crew - greased all tree valves. 02:30 - 07:30 5.00 BOPSUF PROD1 Continue BOP test. Grease one valve on choke manifold - not holding pressure. 07:30 - 09:30 2.00 DRILL PROD1 Install CT Conn, pull test. Pump dart fill CT w. FIo-Pro. Pressure test CT Conn. 09:30- 10:30 1.00 DRILL PROD1 PU BHA 10:30- 12:30 2.00 DRILL PROD1 TIH 12:30 - 15:30 3.00 DRILL PROD1 Taking wt and stalling at top perf. Wash and ream thru perfs. Stalls at speed faster than 4 fpm. Short trip back across perfs. Losing up to 1.2 bpm, losses decreasing 15:30 - 16:30 1.00 DRILL PROD1 Tag up on cement. Drill cement and latch collar. Losing 0.5 bpm 16:30 - 17:30 1.00 DRILL PROD1 Pull above perfs and circulate across top of hole while wait on mud. Losing 0.5 bpm 17:30 - 19:15 1.75 DRILL PROD1 Drill cement and float eqpt. Broke thru and ROP picked up to 15 fph below 11476'. Losses still at 0.3-0.4 bpm. 19:15 - 23:30 4.25 DRILL PROD1 Cont drilling cement at 10-20 fph - losses still at 0.3 bpm (+/- 20 bph). Tag float collar? at 11517'. 23:30 - 00:00 0.50 DRILL PROD1 Drill through float collar. 8/19/2000 00:00 - 03:00 3.00 DRILL PROD1 Continue drilling cement in shoe track. Losses reduced to 0.2 bpm. 03:00 - 03:45 0.75 DRILL PROD1 Drill out float shoe. 03:45 - 04:15 0.50 DRILL PROD1 Drill to 11576' to confirm out of shoe - OK. 04:15 - 06:30 2.25 DRILL PROD1 POH for drilling package. 06:30 - 07:30 1.00 DRILL PROD1 LD Milling BHA. 07:30 - 09:00 1.50 DRILL PROD1 MU drilling BHA #2. 09:00 - 10:30 1.50 DRILL PROD1 TIH, shallow test Sperry tools-OK 10:30 - 11:00 0.50 DRILL PROD1 H25 and Rig Evacuation Drill. Stop pumps, shut in well and evacuate rig. (Notify BPX Emergency Services of drill) 11:00 - 11:30 0.50 DRILL PROD1 Continue TIH 11:30 - 13:30 2.00 DRILL PROD1 Tag up, correct depth (-6'). Orient to drop angle. Drill ahead. 13:30 - 15:30 2.00 DRILL COMM PROD1 Unable to follow proposed well path. POOH to check tools. Rig on zero rate starting at 13:30 hrs on 8/19/00. 15:30 - 17:30 2.00 DRILL COMM PROD1 OOH. Incorrect scribe line used to calculate offset for MWD orientation. 17:30 - 19:30 2.00 DRILL COMM PROD1 Adjust orientation to correct scribe line mark. Change out resistivity tool. MU bit #2 - Smith M09 and BHA #3. MU conn. Stab inj. 19:30 - 21:45 2.25 DRILL COMM PROD1 RIH with BHA #3. Tag up at 11582'. 21:45 - 22:00 0.25 DRILL COMM PROD1 Pump and orient thru and tag bottom at 11662'. Correct to 11656' (corr'n -6'). 22:00 - 22:15 0.25 DRILL COMM PROD1 Pull up hole and orient for 160-170 R. 22:15 - 23:00 0.75 DRILL COMM PROD1 Slowly ream 10' interval to start trough 2.5/2.2 bpm 2980 psi. 161R. 23:00 - 00:00 1.00 DRILL COMM PROD1 Pull up to 11575' and start time drilling at 0.1' every 3 min. 2.5/2.3 bpm. 2920 psi. 164R. 8/20/2000 00:00 - 02:45 2.75 DRILL COMM PROD1 Continue time drilling for Iow side open hole sidetrack. Increase drilling rate to 0.1 fpm. Start seeing motor work and WOB at 11587'. Incr ROP slowly up to 20 fph by 11590'. Printed: 8/30/2000 2:15:09 PM : : operations Repo : Legal Well Name: H-37a Common Well Name: H-37a Spud Date: 8/17/2000 Event Name: RE ENTER Start: 8/17/2000 End: 8~22~2000 Contractor Name: NORDIC CALISTA Rig Release: 8~22~2000 Group: RIG Rig Name: NORDIC 1 Rig Number: ~te : ~ro~ Acti~i~ ~ :. ph~ ~iipti~n of ~P~ti~h:~ 18/20/2000 02:45 - 03:30 0.75 DRILL COMM PROD1 Drill ahead at 20 fph. 2.6/2.5 bpm. 3210 psi. 164R. Get 1 click at 11600'. 03:30 - 04:15 0.75 DRILL COMM PROD1 Increase to full ROP at 50-80 fph. 2.5/2.4 bpm. 3200 psi. 178R. Rig back on dayrate at 04:15 hrs 8/20/00. 04:15 - 04:45 0.50 DRILL PROD1 Drill ahead dropping angle. ROP 120-140 fph. Est OWC at 11650' per wellsite geologist. 04:45 - 05:00 0.25 DRILL PROD1 Orient around 05:00 - 05:45 0.75 DRILL PROD1 Drill ahead dropping angle. 2.5/2.4 bpm. 3450 psi. 170L. ROP 100-140 fph but dropped rapidly at +/- 11750'. Zone 3? 05:45 - 06:30 0.75 DRILL PROD1 Short trip up to 11600' to clean up hole. RIH to bottom. 06:30 - 08:00 1.50 DRILL PROD1 Log MAD Pass from TD 11571', GR log for correlation from 11510'-11544', correct depth (+6') 08:00 - 09:45 1.751 DRILL PROD1 POOH 09:45 - 10:30 0.75: DRILL PROD1 OOH, LD BHA 10:30 - 11:30 1.00 DRILL PROD1 Download MWD tools and LD same 11:30 - 12:45 1.25 CASE PROD1 PU 2 7/8" Liner and CTLRT 12:45 - 14:30 1.75 CASE PROD1 TIH w/2 7/8" Liner 14:30 - 16:30 2.00 CASE PROD1 Liner hanging up, attempt to wash in hole. Got to 10925', could not work deeper. TOL at 10614'. Bridging off and high overpull coming uphole. 16:30 - 18:30 2.00 CASE FILL PROD1 POOH w/Liner. Did not have liner - released at deployment sleeve. Did not release hydraulically. Metal debris and cuttings/cmt found packed in tool when dis-assembled. 18:30 - 19:00 0.50 CASE FILL PROD1 Discuss with Anch engineer. 19:00 - 19:30 0.50 CASE FILL PROD1 Hold PJSM and plan forward with crew. 19:30 - 20:30 1.00 CASE FILL PROD1 Strap and MU nozzle, 2 jts 2 3/8" PH6, Dowell package. 20:30 - 22:15 1.75 CASE FILL PROD1 RIH. Tag up at 10447'. 22:15 - 22:30 0.25 CASE FILL PROD1 Got pressure increase as if at or in top of deployment sleeve. Obstruction will not move down hole with weight or circ. 22:30 - 23:30 1.00 CASE FILL PROD1 Circ at 3.6 bpm above deployment sleeve. Losing +/- 0.5 bpm. Circ 20 bbl hi-vis sweep around into annulus at 3.5 bpm. 23:30 - 00:00 0.50 CASE FILL PROD1 POH chasing pill out. Ditch magnets are accumulating quantity of fine metal filings? 8/21/2000 00:00 - 01:00 1.00 CASE : FILL PROD1 POH with nozzle after cleaning out to TOF at 10447'. 01:00 - 01:15 0.25 CASE FILL PROD1 Stand back injector. LD nozzle. 01:15 - 01:30 0.25 FISH i FILL PROD1 MU GS spear w/packoff, jars, 2 jts 2 3/8" PH6. Stab injector 01:30 - 03:15 1.75 FISH FILL PROD1 RIH with GS spear to engage and fish liner. Up = 40klbs. Dn = 20 klbs. 03:15 - 03:30 0.25 FISH FILL PROD1 Engage GS in deployment sleeve and pick up. Small overpull and weight increase (1500 lbs) coming up. Able to go down +/- 15' and then started stacking weight. Pull up and come out of hole with fish. 03:30 - 06:30 3.00 FISH i FILL PROD1 POH with liner. Fill across top of hole. 5 rain flow check at 3000' 06:30 - 07:30 1.00 FISH FILL PROD1 Stand back 2 7/8" Liner ~07:30 - 08:30 1.00 FISH FILL PROD1 PU Venturi Jet Basket BHA i08:30 - 10:30 2.00 FISH FILL PROD1 TIH i10:30 - 12:00 1.50 FISH FILL PROD1 Wash in hole w/Jet Basket from 10300' to 11760'. 12:00 - 14:15 2.25 FISH FILL PROD1 POOH 14:15 - 14:45 0.50 FISH FILL PROD1 OOH, Break off jet basket. Basket +/- 1/4 full of metal cuttings and formation cuttings. LD jet basket BHA 14:45 - 15:15 0.50 CASE I FILL PROD1 PU 2 7/8" Liner 15:15 - 17:30 2.25 CASE FILL PROD1 TIH w/Liner. Started taking weight at 10770'. Printed: 8/30/2000 2:15:09 PM Legal Well Name: H-37a Common Well Name: H-37a Spud Date: 8/17/2000 Event Name: RE ENTER Start: 8/17/2000 End: 8/22/2000 Contractor Name: NORDIC CALISTA Rig Release: 8/22/2000 Group: RIG Rig Name: NORDIC 1 Rig Number: 8/21/2000 17:30 - 18:45 1.25 CASE FILL PROD1 Work and intermittently circulate pipe down to 11000' shoe depth. Liner 'started going in hole OK. 18:45 - 19:00 0.25 CASE PROD1 Run liner ot bottom at 11760' - no further problems. Open hole in good condition. 19:00 - 19:15 0.25 CASE PROD1 Establish circulation thru guide shoe and slotted liner. 1.4 in 1.0 out. Release GS spear from deployment sleeve. 19:15 - 21:00 1.75 CASE PROD1 POH with GS spear. LD tools. 21:00 - 21:30 0.50 CASE PROD1 PJSM for LTP run. New crew on tour. 21:30 - 22:00 0.50 CASE PROD1 MU Baker KB liner top packer. 22:00 - 00:00 2.00 CASE PROD1 RIH with LTP. 8/22/2000 00:00 - 00:30 0.50 CASE PROD1 Continue RIH with Baker LTP. Stopped at 10457'. PU and work thru obstruction - OK. Continue RIH to TOL. Locate seals in deployment sleeve and set down 10 klbs. Pull to PU wt and pull up 2 feet to put top of LTP at 11441'. Establish circ at 1.6 bpm: 1600 psi. 00:30 - 00:45 0.25 CASE PROD1 PU and space out to load setting ball. Load 5/8" setting ball in reel manifold and pump to coil. 00:45 - 01:15 0.50 CASE PROD1 Displace ball to coil and pump down at 1.8 bpm/1750 psi. Only getting about 50% returns. SD pump and sting back in to deployment sleeve - space out 2' from fully inserted. Cont displacing ball. Returns improving 2.2 bpm in 1.9 bpm out 2000 psi. Ball on seat at 53.6 bbl away. 01:15 - 01:30 0.25 CASE PROD1 Pressure up to 3000 psi and bleed off to 1500 psi. PU to 5000 lbs above PU wt - no go, Slack off to set slips and PU again. Pressure back up to 3500 psi. PU to 5K over- slips are now set. Slack off weight to energise packer element. Bleed off and chk slips are set - OK. Top of LTP = 11440'. ~01:30 - 04:00 2.50 CASE PROD1 Pressure up to 4300 psi and release off LTP - OK. Pull up out of LTP with setting tool and displace well to 2% KCI at 3.5 bpm 3250 psi. i Pumped 450 bbl total - 2.5 wellbore vols for cleanup. 04:00 - 06:00 2.00 CASE PROD1 POH with LTP setting tool. 06:00 - 06:30 0.50 CASE PROD1 At surface. LD setting tool and BHA. 06:30 - 08:00 1.50 PERF COMP PJSM and PU Schlumberger perf guns 08:00 - 10:00 2.00 PERF COMP TIH w/perf guns 10:00 - 10:30 0.50 PERF COMP Tag up, correct depth (-2'). Position bottom shot at 11370'. Drop 5/8" Firing Ball and displace w/2% KCI. Ball on seat and sheared at 3300 psi. 10:30 - 12:30 2.00 PERF COMP POOH w/perfguns 12:30 - 13:30 1.00 PERF COMP PJSM and LD perf guns, all shots fired 13:30 - 15:00 1.50 CHEM COMP TIH to 2000', freeze protect tubing w/MeOH. Close swab valve. 15:00 - 16:00 1.00 GASN2 COMP Purge CT w/N2 and bleed down nitrogen. Clean pits. 16:00 - 18:00 2.00 GASN2 COMP Rig down cuttings tank. ND BOPE. Install and test tree cap. RELEASE RIG FROM WELL H-37A AT 18:00 HRS ON 08/22/2000. Total time on well was 4 days 23 hours. Printed: 8/30/2000 2:15:09 PM North Slope Alaska Alaska State Plane 4 PBU_ WOA H Pad H.37A Surveyed: 20 August, 2000 ORIGINAL SURVEY REPORT 08/30/2000 14:20:12 PM Your Ref: API.500292277'201 Surface Coordinates: 5958769.63 N, 643339.57 E (70° 17' 41.4625" N, 148° 50' 21.6327" W) Kelly Bushing: 75.48ft above Mean Sea Level I:),R I l.,b I N Iii' IIItVII::I= RECEIVED SEP 22 ~_000 Al~sk~ Oil & (~as Cons. C, omm'lssiO~ Anchorage Survey Reft svy9966 Sperry-Sun Drilling Services Survey Report for H-37A Your Ref: AP!.$00292277201 Surveyed: 20 August, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (fi) (ft) (fi) Global Coordinates Northings Eastings (ft) (ft) 11451.56 80.420 249.570 8955.19 9030.67 3822.01 S 4033.99 W 11575.05 76.300 248.500 8980.10 9055.58 3865.27 S 4146.91 W 11607.85 71.080 249.360 8989.31 9064.79 3876.59 S 4176.27 W 11639.85 63.260 249.000 9001.71 9077.19 3887.06 S 4203.82 W 11673.85 54.360 252.700 9019.31 9094.79 3896.63 $ 4231.24 W 11709.25 45.810 249.700 9042.01 9117.49 3905.33 S 4256.93 W 11733.45 39.470 244.410 9059.80 9135.28 3911.67 S 4272.03 W 11760.00 39.470 244.410 9080.30 9155.78 3918.96 S 4287.25 W 5954871.38 N 639379.20 E 5954825.98 N 639267.13 E 5954814.11 N 639237.99 E 5954803.11 N 639210.64 E 5954793.02 N 639183,40 E 5954783.83 N 639157.89 E 5954777.20 N 639142.92 E 5954769.63 N 639127.84 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Dogleg Rate (°ll00ff) 3.442 16.112 24.459 27.776 25.007 30.075 0.000 Alaska State Plane 4 PBU_WOA H Pad Vertical Section (ft) Comment 4958.2o 5o78.78 5110.15 5139.54 5168.56 5195.66 5211.94 5228.61 Tie-on Survey Window Point Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 253.390° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11760.00ft., The Bottom Hole Displacement is 5808.51ft., in the Direction of 227.570° (True). RECEIVED SE? 27 2000 0il & Gas Cons. C0mmissio~ Continued... 08730/2000 14:20:14 PM - 2 - DrillQuest 1.05.05 North Slope Alaska Sperry-Sun Drilling Services Survey Report for H-37A Your Ref: AP1.500292277201 Surveyed: 20 August, 2000 Alaska State Plane 4 PBU_WOA H Pad Comments Measured Depth (ft) 11451.56 11575.05 11760.00 Station Coordinates TVD Northings Esstings (tt) Ct) (~t) 9030.67 3822.01 S 4033.99 W 9055.58 3865.27 S 4146.91 ~W 9155.78 3918.96 S 4287.25 W Comment' Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth Ct) Ct) 0.00 0.00 To Measured Vertical Depth Depth (~t) (ft) 11760.00 9155.78 Survey Tool Description MWD Magnetic RECEIVED DrillQuest 1.05.05 08/30/2000 14:20:15 PM - 3 - North Slope Alaska Alaska State Plane 4 PBU_ WOA H Pad H-37A PB1 Surveyed: 19 August, 2000 ORIGINAL SURVEY REPORT 30 August, 2000 Your Ref: API-500292277270 Surface Coordinates: 5958769.63 N, 643339.57 E (70° 17' 41.4625" N, 148° 50' 21.6327" W) Kelly Bushing: 75.48ft above Mean Sea Level =par",m~-=ur"~ ~ R I L. L.'IN C!I S'ell Iqv I C: llei~ RECEIVED S ~; © 2000 ,~l~¢a Oi~ & Gas Cons. Commissio~ s, nchorarje Survey Reft svy9957 Sperry-Sun Drilling Services Survey Report for H-37A PB1 Your Ref: AP1.500292277270 Surveyed: 19 August, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (fi) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 11451.56 80.420 249.570 8955.19 9030.67 3822.01 S 4033.99 W 11565.00 78.000 243.720 8976.44 9051.92 3866.14 S 4136.24 W 11596.57 78.240 240.220 8982.94 9058.42 3880.66 S 4163.51 W 11621.57 81.150 234.230 8987.42 9062.90 3893.97 S 4184.18 W 11656.00 81.150 234.230 8992.72 9068.20 3913.86 S 4211.78 W 5954871.38 N 639379.20 E 5954825.31 N 639277.81 E 5954810.28 N 639250.82 E 5954796.57 N 639230.41 E 5954776.16 N 639203.20 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Dogleg Rate (°ll00ff) 5.496 lO.876 26.288 o.o0o Alaska State Plane 4 PBU_WOA H Pad Vertical Section (ft) Comment 5054.92 5165.96 5196.45 5220.32 5252.88 Tie-on Survey Window Point Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 251.090° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11656.00ft., The Bottom Hole Displacement is 5749.55ft., 'in the Direction of 227.100° (True). RECEIVED S c? 22 000 Oil a Gas Cons. c0mm]~o~ Anchora.oe Continued... DrillQuest 1,05.05 30 August, 2000 - 12:05 - 2 - Sperry-Sun Drilling Services Survey Report for H-37A PB1 Your Ref: API-500292277270 Surveyed: 19 August, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA H Pad Comments Measured Depth (ft) 11451.56 11565.00 11656.00 Station Coordinates TVD Northings Eastings (~) (~) (~) 9030.67 3822.01S 4033.99w 9051.92 3866.14 s 4136.24w 9068.20 3913.86 s 4211.78w Comment Tie-on Survey Window Point ProjeCted Survey Survey tool program From Measured Vertical Depth Depth (ft) 0.00 0.00 TO Measured Vertical Depth Depth (ft) (ft) 11656.00 9068.20 Survey Tool Description MWD Magnetic RECEIVED SEP 22 2000 Alas~ 0il & I~as Cons. C0mmJssien Anchorage DrillQuest 1.05.05 30 Augus~ 2000-12:05 -3- 9/6/00 _. _. ~o. os'"'/ Schh berger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AITN: Sherrie NO. 480 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date Blueline Sepia Color CD Prints H-37A PSP PROD PROFILE 000901 1 1 a-26B ~ q"/I'~ ~ 20228 MCNL 000512 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Naska 0il & [;as Cons. Commission Anchorage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 RECEIVED ATrN'. Sherrie ~~ 8EP 0 82000 Received _ ALASKA OIL AND GAS CONSERVA~FION CO~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 995014192 PHONE: (907) 279-1433 FAX: (907) 276~7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re~ Prudhoe Bay Unit H-37A BP Exploration (Alaska) Inc. Permit No: 200-097 Sur Loc: 3261'NSL, 1265'WEL, Sec. 21, T11N, R13E, UM Btmhole Loc. 729'SNL, 338'WEL, Sec. 29, T11N, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to deepen the above referenced well. The permit to deepen 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) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF TIlE COMMISSION DATED this ~ ~ day of July, 2000 dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK~ JIL AND GAS CONSERVATION COrv~" $SlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] D~II [] Redrill I lb. Type of well ,_,_ [] Exploratory [] Stratigraphic Test '~ DeveloPment Oil [] Re-Entry ~1 DeepenI ~,.~ s~ice [] Development Gas [] Single ZoneC! Multiple Zone 2. Name of Operator ~. Datum Elevation (DF or KB) 101 Field and Pool " BP Exploration (Alaska) Inc. KBE = 75.48' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation,e_~ Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 0~~~ 4. Location of well at surface ./ ,/ ~' 7. Unit or Property Name 11. Type Bond (See 20 AA(::; 25.025) 3261' NSL, 1265' WEL, SEC. 21, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 121' SNL, 4579' WEL, SEC. 28, T11N, R13E, UM H-37A Number 2S100302630-277 At total depth 9. Approximate spud date 729' SNL, 338' WEL, SEC. 29, T11N, R13E, UM 07/12/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD"~nd TVD) ADL 028287, 338' MDI No Ciose Approach 2560 11870' MD / 9134' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11507' Maximum Hole Angle 85 ° Maximum surface 2908 psig, At total depth (TVD) 9100' / 4000 psig - ._ 18. Casing Program Setting Depth Size Specifications T<',p Bottom Quantity of Cement Hole Casinq Weiqht . Grade Cc~uplinq Lenqth MD TVD MD 'I'VD (include staqe data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 450' 11420' 8950 11870' 9134' Uncemented Slotted Liner ,,,,,, , , 19. To be completed for Redrili, Re~entry, and Deepen Operations. ' it' ~, ~ ~.~ ?~ ....... ,~. Present well condition summary Total depth: measured 11565 feet Plugs (measured) JUN ~ 9 ~)000 true vertical 9052 feet Effective depth: measured 11475 feet Junk (measured) Ala~(a 0i~ & Gas C~s~ Commission true vertical 9035 feet A~c~of~e Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 260 sx Arctic Set (Approx.) 110' 110' Surface 3744' 9-5/8" 1800 sx CS III, 400 sx Class 'G' 3775' 3635' Intermediate 10432' 7" 493 sx Class 'G' 10460' 8886' Production Liner 1140' 4-1/2" 142 sx Class 'G' 10425' - 11565' 8868' - 9052' Perforation depth: measured 10650'- 10900', 10950'- 11130', 11185'- 11230', 11290'- 11370' ORIGIN^L true vertical 8964' - 8957', 8958' - 8979', 8987' - 8994', 9004' - 9017' '20. Attachments [] Filing Fee' [] Property 'Plat [] BOP Sketch ri Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements ='contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubblc, 564-4628 ~1. I hereby certify that the for~q~in~and correct to the best 'of my knowledge Signed TedStagg ~,~..~///~.~.~'~, Title CT Drilling Engineer Date ~;/,~,.~///'~ Permit Number d.~)c:a ~ I APl Number ~' Apm&a I)ati~ See cover letter '~-~-- / / 150-029-22772-01 '- t [~'~1 U {! for other requirements ~onditions of Approval: SamPles Required [] Yes ~[ No "Mud Log Re'qluir~[d" r-I Yes Hydrogen Sulfide Measures [~'Yes [] No Directional Survey Required ~r~'es [] No Required Working Pressure for BOPE [] 2K; [] 3K; r'l 4K; !~ 5K; [] 10K; [] 15K Other: ~OO~ ~, ~'>(;~3 ~> ~-~ ~"~v~ OI~,I~,NAL SIGNED BY by order of r:t [~pproved By D Tavlnr Rm~rnn,,n~ Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit Triplicate BPX H-37a Sidetrack Summary of Operations: H-37 is being extended to access the zOne 3 aquifer in order to create a water dump flood to lower Zone 4. This sidetrack will be conducted in two phases. Phase 1' Tubing Integrity Test, Tubing Drift, Liquid pack IA: Planned for July 5, 2000. · A Tubing Integrity Test and tubing drift will be pedormed. · The well will be killed and the Inner Annulus liquid packed. Phase 2: Mill float equipment, Drill and Complete sidetrack: Planned for July 12, 2000. Drilling coil will be used to mill existing 4 ½" float equipment then drill and complete the directional hole as per attached plan. The existing 4 ½" liner will be perforated in lower Zone 4 for the dump flood. Mud Program: · Phase 1' Seawater · Phase 2: Seawater and FIo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, ST-L slotted liner will be run from TD to approx. 11,420' MD. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log will be run over all of the open hole section. Hazards Milling the existing float equipment is a mechanical risk. No faults will be crossed. Res. pressure is normal. Reservoir Pressure Res. press, in Zone 3 aquifer is possible as high as 4000 psi @ 9100ss. Max. surface pressure with gas (0.12 psi/fi) to surface is 2908 psi. JUN 2 9 2000 Alaska & Gas Cons. Commissio / ch0rage TREE: 4" CIW WELLHEAD:FMC-GEN 5 (CONT. CONTROL LINE) ACTUATOR: BAKER ES CEMENTER [ 1757' a Proposed Multi-Lateral 4.5" HES HXO SSSVN ( 3.813" ID ) KBE = 75.48' BFE = 47.2' 2078' 9 5/8", 40 #/fi, L-80 I BUTT. SHOE I 3775' KOP# 1 (H-37L1) 10372' KOP# 2 (H-37) 10460' MAX ANG: (H-37L1) 98° MAX ANG: (H-37) 94° 4.5" 12.6#, L-80, BUTT. TBG. TUBING ID: 3.958" CAPACITY: .0152 BBL/FT GAS LIFT MANDRELS (CAMCO) #1-6; 4.5'~(1" KBG-2-LS -MOD W/DK-1 BTM LATCH f 3.909" ID NO. MD(BKB) TVDss. 3310' 5755' 716O' 8021' 8881' 3173' 5174' 6321' 7033' 7734' IDEV. 27 36 33 36 36 7" 26# L-80 BTC-M ID: 6.276" CAP: .0383 BBL/FT CSG RA TAG @ 10107' JUN 2 9 2000 Al~a Oil & Gas Cons. Oomm~ssior. Anchof~e RA TAG @ 10356' MILLED WINDOW IN 7" CSG FROM 10372' - 10384' 10393'I i I o. lo, I BAKER 4.5"X 7" ML PKR f3.875" ID1 4.5" HES X-NIPPLE ( 3.813" ID ) 4.5" WLEG ( 4.000" ID ) 4 1/2" 12.6~ L-80 IBT-M SOLID LINER - 10446' - 11565' 10425' I TOP OF 4 1/2" LINER 7"X 5" BAKER ZXP PKR W/6' TIEBACK SLEEVE ( 5.25" ID ) 4.5" HES X-NIPPLE (3.813" ID) ~ 7"X 4.5" BAKER S-3 PACKER (3.875" ID) 4.5" HES X-NIPPLE (3.813" ID) 4.5" HES X- NIPPLE (HP) (3.813" ID) 23/4" I 4 I 23/4" I 4 I 14 I I" I 4.5" WLEG H-37 L 1 OPEN HOLE TD NOTE: NO LINER IN UPPER LATERAL, RIG UNABLE TO SET SLOTTED LINER. SEE DRLG FOR MISC JUNK LEFT IN WELL. PERFORATION SUMMARY' INTERVAL 10650'-10900' 10950'-11130' 11185'-11230' 11290'-11370' 41/2"SHOE PBTD OPEN/SQZ'D OPEN OPEN OPEN OPEN 1565' 11474' H-37 H-37a 2 718" Slotted Existing perfs water flow I10181' I10290' I 11500 ' I Dump Flood Perfs I Bridge Plug -5,000 I -4,500 H-37 -4,000 H-37L1 Case 103 5/31/00 Toe Drill-out 363 ft open hole -3,500 i'~T -4,000 -4,500 X distance from Sfc Loc -5,000 30 IWell Name H-37 I CLOSURE Distance 5,898 ft I Az 226 deg NEW HOLE E/W (X) NIS {Y) Kick Off -4,011 -3,918 TD -4,269 -4,071 State Plane 639,072 5,954,698 Su~ace Loc 643,340 5,958,769 DLS deg/100 Tool Face Length Curve 1 6 0 69 Curve 2 20 -155 300 369 Drawn: 6/28~00 16:29 Plan Name: Case 103 JUN 2 9 2000 Alaska Oil & Gas Cons. Commission Anch0rege H-37 Vertical Section Path Distance (Feet) 8750 8800 8850 8900 .-..8950 9000 9050 9100 9150 9200 0 500 1,000 I I -TSAD - 1,500 I 2,000 2,500 Angle@K.O.= 79 MD:11507 3,000 I - HOT 11870 TD Marker Depths ~Ori~l Wellbore ~s^~I 01.~VD 9,i4219,1421ft TVD TS^~ ~ 8,86~J.~ IKick Off I 8,9651ft TVD 11,507 Iff MD IDeprtr ~}KO 5,622 ft rMD KO Pt 11,507 MD New Hole 363 Total MD 11,870 'I'VD TD 9,134 DLS de~l/lO0 Tool Face Length Curve t '6 0 ~9 Curve 2 20 -155 300 369 Drawn: 6/28/00 16:29 Plan Name: Case 103 JUN 29 2000 0~ & G~s Cons. Commission U) I.U 'r Z · 12' 36" 22.5" 18" 2 3/8" CT ~1 I I I 10,000 psi Pack-Off Lubricator t I H-37a CT Drilling & Completion BOP 7 1/16" Annular 7 1/16" 5000 psi 7 1/16" Pipe/Slip ~ 2 3/8" 7 1/16" x 5,000 psi Slips 7 1/16" Pipe I 718" 3/8" SWAB OR MASTER VALVE RECE!VED JUN 2 9 2000 Ala~a Oi~ & Gas Cons. Commissio~ STATE OF ALASKA ALASI[ alL AND GAS CONSERVATION COl(. ISSlON APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: I=1 Abandon r'l Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Operation Shutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface [] Plugging [] Time Extension [] Pull Tubing [] Variance [] Re-Enter Suspended Well [] Stimulate [] Pedorate [] Other Extend H-37 5. Type of well: [] Development i-I Exploratory [] Stratigraphic r"l service 6. Datum Elevation (DF or KB) KBE = 75.48' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number H-37 9. Permit Number 197-102 10. APl Number 50- 029-22772-00 12. 3261' NSL, 1265' WEL, SEC. 21, T11N, R13E, UM At top of productive interval 121' SNL, 4579' WEL, SEC. 28, T11N, R13E, UM At effective depth 570' SNL, 48' WEL, SEC. 29, T11 N, R13E, UM At total depth 600' SNL, 131' WEL, SEC. 29, T11N, R13E, UM RECEIVED J;JN 2 9 2000 Ala~a Oil & Gas Cons. Commissb~ Present well condition summary Total depth: measured 11565 feet Plugs (measured) true vertical 9052 feet Effective depth: measured 11475 feet Junk(measured) ORIGINAL true vertical 9035 feet Casing Length Size Cemented MD Structural Conductor 110' 20" 260 sx Arctic Set (Approx.) 110' Surface 3744' 9-5/8" 1800 sx CS III, 400 sx Class 'G' 3775' Intermediate 10432' 7" 493 sx Class 'G' 10460' Production Liner 1140' 4-1/2" 142 sx Class 'G' 10425' - 11565' 11. Field and Pool Prudhoe Bay Field / prudhoe Bay Pool TVD 110' 3635' 8886' 8868' - 9052' Perforation depth: measured true vertical 10650'-10900', 10950'-11130', 11185'-11230', 11290'-11370' 8964'-8957', 8958'-8979', 8987'-8994', 9004'-9017' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 10290'; 4-1/2", 12.6#, L-80 from 11393' - 11410' Packers and SSSV (type and measured depth) 7" x 4-1/2" Baker 'S-3' packer at 10192'; 7" x 4-1/2" Baker ML packer at 10393'; 4-1/2" HES 'HXO' SSSVN at 2078' 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program r-I BOP Sketch 4. Estimated date for commencing operation July 12, 2000 16. If proposal was verbally approved Date Approved 15. Status of well classifications as: [] Oil I-'1 Gas I-'1 Suspended Service Name of approver Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the Signed Ted Stagg is true and correct to the best of my knowledge Title CT Ddlling Engineer Date ~/~o Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- ..Approved by order of the Commission Approval Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate DATE CHECK NO. ::.~.::::.." .~]~iLIATE;O~ ::]:~::.." ?. .:. :.:".: ~.::.;: "':::':. .'....... ..::~:: ':.: :':.': .-.: :-.: ...... . ::;': .:. ::: :"'. 412 ---001 &.C1.426:-.: ANCHORAG~E AK c)c)501 ':' 1' 05/26/00 [ ..... FIELD & POOl' ~:~ ~-~/,~'~ INIT (~i.~ss ~ . ,, GEOL AREA ~;~?L--~,~ '" UNIT# ~"~//~'~) oN/OFF SHORE AD_MINISTRATION 1. Permit fee attached ........ . ...... ,~/J., ·; ...... · ~ :~ ........ ,~ J, - ,,~ 3. Unique well name and number .............. /.... N ?r'~,=~o_-/-z'.~;~_..,~-~,, -v'~., ~ ,'.u~ /--/Z::>4~,, ,F2.2-~__~,~, "/~-~,,.~ N J, ' 4. Well located in a defined pool .................. ' N 5. Well located proper distance from drilling unit boundary .... . 7. 8. 9. 10. 11. A~_TE. 12. 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 ........... lEERING II AI~P---~_ DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations ........ '.. 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~-~G~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. 31. 32. II AP. PR DATE 33. II - J~'~,NNULAR DISPOSAL35. APPR DATE Permit can be issued w/o hydrogen sulfide measures ..... Y ~')~._,Y ~'- Data presented on potential overpressure zones ....... ~ SeiSmic analysis of shallow gas zones ........... ,,,,~(- ~"'- Y N Seabed condition survey (if off-shore) ....... /.;,,,,.,~../."; Y N Contact name/phone for weekly progress repo~xploratory only] Y N With propercementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: . ENGINEERING: UIC/Annular CoMMISsION: .. ~~(';.,-, .. ~ .... . Comments/Instructions: rtl z c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify, finding information, information, of this nature is accumulated at the end of the file under APPE .NDIX. No Special'effort has been made to chronologically organize this category of information. H37APBl.txt Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Oct 01 12:43:07 2001 Reel Header Service name ............. LISTPE Date ..................... 01/10/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/10/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MW-00153 J. PANTER C. PARKER / H-37APB1 500292277270 BP Alaska, Inc. Sperry Sun 01-OCT-01 21 Tll R13 3261 1265 75.48 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 3.750 4.500 11565.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING Page 1 H37APBl.txt GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RESISTIVITY IS NOT PRESENTED OWNING TO TOOL FAILURE. DIGITAL MWD DATA ONLY IS SHIFTED TO THE PDCL GR LOG (SCHLUMBERGER PL OF 09/09/2000). LOG AND LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. MWD RUN 1 REPRESENTS WELL H-37A PB1 WITH API%: 50-029-22772-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11656'MD, 8993'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 11528.0 11607.0 ROP 11579.0 11658.5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPT~ BASELINE DEPTH GR 11528.0 11525.0 11536.0 11533.0 11555.0 11552.0 11658.5 11655.5 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 1 11525.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 11655.5 Name Service Order Units Size Nsam Rep Code Offset Channel Page 2 H37APBl.txt DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max DEPT FT 11528 11658.5 ROP MWD FT/H 1.15 197.99 GR MWD API 21.44 51.84 First Reading For Entire File .......... 11528 Last Reading For Entire File ........... 11658.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Mean 11593.3 109.144 33.493 Nsam 262 160 159 First Reading 11528 11579 11528 Last Reading 11658.5 11658.5 11607 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11525.0 11604.0 ROP 11576.0 11655.5 $ LOG HEADER DATA DATE LOGGED: 19-AUG-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0.41 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11656.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 78.0 MAXIMUM ANGLE: 81.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01475GR3 EWR4 ELECTROMAG. RESIS. 4 PB01475GR3 $ BOREHOLE AND CASING DATA Page 3 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): H37APBl.txt 3.750 11565.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.65 MUD VISCOSITY (S): .0 MUD PH: 10.0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 167.7 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 11525 11655.5 11590.3 262 ROP MWD010 FT/H 1.15 197.99 109.144 160 GR MWD010 API 21.44 51.84 33.493 159 First Reading For Entire File .......... 11525 Last Reading For Entire File ........... 11655.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 11525 11576 11525 Last Reading 11655.5 11655.5 11604 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/10/01 Origin ................... STS Page 4 H37APBl.txt Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/10/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... uNKNOwN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 5 H37A.txt Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Oct 01 14:40:48 2001 Reel Header Service name ............. LISTPE Date ..................... 01/10/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/10/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MW-00153 B. JAHN C. PARKER / H-37A 500292277201 BP Alaska, Inc. Sperry Sun 01-OCT-01 21 Tll R13 3261 1265 75.48 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 3.750 4.500 11565.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2¸. MWD RUN 1 COMPRISES WELL H-37A PB1 ENTIRELY, AND IS PRESENTED SEPARATELY. Page 1 H37A.txt 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. DIGITAL MWD DATA ONLY IS SHIFTED TO THE PDCL GR LOG (SCHLUMBERGER PL OF 09/09/2000). LOG AND LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUN 2 REPRESENTS WELL H-37A PB1 WITH API%: 50-029-22772-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF l1760'MD, 8993'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPX 11482.0 11728.5 RPS 11482.0 11728.5 RPM 11482.0 11728.5 RPD 11482.0 11728.5 FET 11482.0 11728.5 GR 11535.5 11717.0 ROP 11578.0 11763.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 11535.5 11534.5 11536.5 11535.5 11544.5 11542.0 11763.0 11760.5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 2 11481.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN MERGE BASE 11760.5 Page 2 H37A.txt Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 11482 11763 ROP MWD FT/H 1.92 399.59 GR MWD API 17.21 129.61 RPX MWD OHMM 0.19 1375.42 RPS MWD OHMM 0.11 2000 RPM MWD OHMM 0.4 2000 RPD MWD OHMM 0.09 2000 FET MWD HOUR 19.58 609.72 First Reading For Entire File .......... 11482 Last Reading For Entire File ........... 11763 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Mean 11622.5 90.036 32.8786 17.5411 274.325 488.146 442.74 276.139 Nsa~ 563 371 364 431 431 431 431 431 First Reading 11482 11578 11535.5 11482 11482 11482 11482 11482 Last Reading 11763 11763 11717 11728.5 11728.5 11728.5 11728.5 11728.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM RPD FET GR ROP $ 2 .5000 START DEPTH 11481.0 11481 0 11481 0 11481 0 11481 0 11534 5 11575 5 STOP DEPTH 11726.0 11726.0 11726.0 11726.0 11726.0 11714.5 11760.5 Page 3 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL {FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TypE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 H37A.txt 20-AUG-00 Insite 0.41 Memory 11760.0 39.5 71.1 TOOL NUMBER PB01613RF3 PB0t613RF3 3.750 11565.0 Flo Pro 8.65 .0 9.5 24000 6.0 .190 .083 .150 .200 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 70.0 179.5 70.0 70.0 Name Service Unit Min Max Mean Nsam Page 4 First Reading Last Reading DEPT FT 11481 11760.5 ROP MWD020 FT/H 1.92 399.59 GR MWD020 API 17.21 129.61 RPX MWD020 OHMM 0.19 1375.42 RPS MWD020 OHMM 0.11 2000 RPM MWD020 OHMM 0.4 2000 RPD MWD020 OHMM 0.09 2000 FET MWD020 HOUR 19.58 609.72 H37A.txt 11620.8 560 90.036 371 32.9269 361 17.5411 431 274.325 431 488.146 431 442.74 431 276.139 431 First Reading For Entire File .......... 11481 Last Reading For Entire File ........... 11760.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 11481 11760.5 11575.5 11760.5 11534.5 11714.5 11481 11726 11481 11726 11481 11726 11481 11726 11481 11726 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/10/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/10/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 5
