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Home My WebLink About200-009MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Saturday, January 25, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC N-08A PRUDHOE BAY UNIT N-08A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/25/2025 N-08A 50-029-20143-01-00 200-009-0 G SPT 7735 2000090 2800 1931 1941 1931 1933 451 455 462 464 REQVAR P Bob Noble 12/2/2024 2 Year MIT-IA to max injection pressure as per AA AIO 3.025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT N-08A Inspection Date: Tubing OA Packer Depth 0 3040 2973 2958IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN241202175043 BBL Pumped:3.5 BBL Returned:2.5 Saturday, January 25, 2025 Page 1 of 1 9 9 9 9 9 9 999 999 9 9 9 9 9 AIO 3.0252 Year MIT-IA James B. Regg Digitally signed by James B. Regg Date: 2025.01.25 23:20:36 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC N-08A PRUDHOE BAY UNIT N-08A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/26/2023 N-08A 50-029-20143-01-00 200-009-0 W SPT 7735 2000090 2500 1107 1107 1107 1107 550 550 550 550 REQVAR P Austin McLeod 12/12/2022 Two year to MAIP. AIO 3.025. 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: PRUDHOE BAY UNIT N-08A Inspection Date: Tubing OA Packer Depth 326 2680 2638 2630IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM221212185111 BBL Pumped:1 BBL Returned:1.7 Thursday, January 26, 2023 Page 1 of 1 Two year to MAIP. AIO 3.025. MEMORANDUM TO: Jim Regg I P.I. Supervisor I C_ 12 Z -q FROM: Matt Herrera Petroleum Inspector Well Name PRUDHOE BAY UNIT N -08A IInsp Num: mitMFH2O1208160831 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, December 10, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC N -08A PRUDHOE BAY UNIT N -08A Src: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-20143-01-00 Inspector Name: Matt Herrera Permit Number: 200-009-0 Inspection Date: 12/7/2020 Pretest Packer Depth Well N 08A Type Inj w✓' TVD 7735 " PTD 2000090 -" (Type Test SPT Test psi:1 2500 " BBL Pumped: 2 BBL Returned: 2.2 = InterVaII REQVAR P/F Notes: MIT -IA Performed to 2500 PSI Per AIO AA 3.025 486 Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 1074 'T 1075 1075 1074 ' IA 51 2673 -� 2631 2623 ' A 507 486 495 501 " Thursday, December 10, 2020 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,December 07,2016 P.I.Supervisor \ 1z"'71/tc SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. N-08A FROM: Bob Noble PRUDHOE BAY UNIT N-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT N-08A API Well Number 50-029-20143-01-00 Inspector Name: Bob Noble Permit Number: 200-009-0 Inspection Date: 12/4/2016 Insp Num: mitRCN161204155805 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well N-08A Type Inj W TVD 7735 - Tubing 530 . 529 528 - 527 - PTD 2000090 ,Type Test SPT Test psi 2500 - IA 34 2746 - 2694 - 2683 - REQVAR __ -- IntervallI P/F P r OA 513 - 494 _ 508 . 513 Notes: AA,Area Injection order 3.025.MIT-IA every 2 years to max anticipated injection pressure.,„ SCANNED APR 0 6 2017 Wednesday,December 07,2016 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Thursday,January 08,2015 P.I.Supervisor et' • /('Z /1b SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC N-08A FROM: Bob Noble PRUDHOE BAY UNIT N-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 1 NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT N-08A API Well Number 50-029-20143-01-00 Inspector Name: Bob Noble Permit Number: 200-009-0 Inspection Date: 12/18/2014 Insp Num: mitRCN141222162957 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well N-08A Type Inj w TVD 7735 ' Tubing 1122 1122 - 1123 - 1123 PTD 2000090 - Type Test SPT Test psi 1934 IA 125 2505 - 2467 - 2463- Interval REQVAR P/F P - OA 726 677 - 734 , 745 - Notes: 2300 psi is max mJ pressure Required to test to max mj psi - A-3-6 3,o z5- SCANNED ' 21 2_U i-; Thursday,January 08,2015 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday, December 21, 2012 Jim Regg P.I. Supervisor �` ri i '(i 'ji SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC N -08A FROM: Bob Noble PRUDHOE BAY UNIT N -08A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ,,r NON- CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT N -08A API Well Number 50- 029 - 20143 -01 -00 Inspector Name: Bob Noble Permit Number: 200 -009 -0 Inspection Date: 12/13/2012 Insp Num: mitRCNl21215080000 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well N -08A Type Inj W TVD 7735 , IA 287 2286 • 2264 2259 PTD 2000090 - Type Test SPT Test psi 1933 - OA 696 665 , 677 690 Interval RE P/F P - Tubing 1015 - 1012 1015 1010 - Notes: This well has a 2 year AA. TVD is 7735' , min test pressure is 1933 psi. Max anticipated injection pressure is 1650 psi L_> Aso 3 , 0 75- SCANNED APR 1 1 2013 Friday, December 21, 2012 Page 1 of 1 Injector N -08 (PTD #2000090) M•A to 4000 psi on 12 -17 -2010 Discuss. Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, January 24, 2011 9:23 AM �� 4 23 \ To: 'AK, D &C Well Integrity Coordinator' Cc: Phillips, Patti J Subject: RE: Injector N -08 (PTD #2000090) MIT -IA to 4000 psi on 12 -17 -2010 Discussion Jerry, Thanks for the MIT. The pressure requirement of the AA appears to be something that needs to be captured in your tracking database. I think there is work going on to make sure that compliance dates are not automatically reset when a diagnostic MIT is done. I am also curious about the different test pressure requirements. The minimum pressure required by the regulations is .25 psi /ft x TVD. There is nothing that says that this pressure cannot be exceeded and in this case it is prudent due to employing MI. That is the reason for the requirement to test to MASP in the AA. To eliminate confusion, I would think it appropriate to have one test pressure with that being what ever the maximum is. I'd appreciate your, Torin's and any others comments back on this. Tom Maunder, PE AOGCC From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, January 21, 2011 9:56 PM To: Maunder, Thomas E (DOA) Cc: Phillips, Patti 3 Subject: Injector N -08 (PTD #2000090) MIT -IA to 4000 psi on 12 -17 -2010 Discussion Tom, Per our discussion today regarding WAG injector N -08 (PTD #2000090), which is operating under Administrative Approval 3.025, the witnessed MITIA on 12/17/2010 that was done was insufficient in pressure for the expected maximum injection pressure that will occur with the well on gas injection (Condition 4 of the AA). An MITIA test to 4000 psi for BP's compliance, that was not witnessed was performed on 12/17/2010 that passed. This test was not sent in with the monthly MIT's at the first of the month. Per our discussion, we do not intend to retest to the expected injection pressure of 3300 psi, as a test in excess of that pressure has already been done that is included for refenece. Please call if you have additional questions or concerns. «MIT PBU N -08A 12 -17 -10 pre -state witnessed MITIA.xls» Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1/24/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, January 14, 2011 TO: Jim Regg rafq 11 v4'l i( P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC N -08A FROM: John Crisp PRUDHOE BAY UNIT N -08A Petroleum Inspector Src: Inspector Reviewed By� P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT N -08A API Well Number: 50- 029 - 20143 -01 -00 Inspector Name: John Crisp Insp Num: mitJCr101220074426 Permit Number: 200 -009 -0 Inspection Date: 12/17/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well N-08A - Type Inj. W 1 7735 IA 340 2500 " 2450 2440 P.T.Di 2000090 ITypeTest Test psi 1933 - OA 580 580 560 560 Interval REQVAR p/F P , Tubing 850 850 1 850 850 Notes: AA for OA re- pressurization. 2 year MIT. 1.8 bbls pumped for test. % AT-o . 3.0255 03;1 - d.tAE 12(Ze.�l 1c� Friday, January 14, 2011 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reao alaska.gov; doa.aoacc.prudhoe.bay(6 alaska.gov; phoebe.brooksealaska.aov; tom.maunderC alaska.aov OPERATOR: BP Exploration (Alaska), Inc. //A 1.106(1( FIELD / UNIT / PAD: Prudhoe Bay / PBU / N Pad / 1! DATE: 12/17/10 OPERATOR REP: Torin Roschinger AOGCC REP: N/A Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well N -08A Type Inj. W ' TVD ' 7,735' Tubing 750 - 750 750 750 Interval V P.T.D. 2000090 ' Type test P Test psi '1933.75 Casing 300, 4000 ' 3990 3990- P/F P Notes: Pre -state MIT -IA for WAG OA 580 550 550 550 OOA 120 120 120 120 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA - Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) FEES ' 1 '_7 Form 10 - 426 (Revised 06/2010) MIT PBU N -08A 12 -17 -10 pre -state witnessed MITIA.xls STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate 0 Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 200-0090 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ .API Number: Anchorage, AK 99519-6612 50-029-20143-01-00 8. Property Designation (Lease Number) : \, 9. Well Name and Number: ADLO-028282 ~ PBU N-08A 10. Field/Pool(s): ~ PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 11139 feet Plugs (measured) 10950' feet true vertical 9100.87 feet Junk (measured) None feet Effective Depth measured 11072 feet Packer (measured) 8665 8779 true vertical 9036.65 feet (true vertical) 7735 7850 Casing Length Size MD TVD Burst Collapse Structural Conductor 74 20" 94# H-40 26 - 100 26 - 100 1530 520 Surface 2575 13-3/8" 72# N-80 25 - 2600 25 - 2600 4930 2670 Intermediate 2015 10-3/4" 55.5# N-80 24 - 2039 24 - 8297 6450 4020 Production 7216 9-5/8" 47# N-80 2039 - 9255 2039 - 8297 6870 4760 Liner 789 7" 29# N-80 8781 - 9567 7845 - 8590 8160 7020 Liner 1895 2-7/8" 6.16# L-80 9244 - 11139 8287 - 9101 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 7" 26# NN=80 24 - 8779 24 - 7844 4-1/2" 12.6# L-80 ~~ 24 - 8784 24 - 7848 Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer .-~ 8665 7735 7" Liner Too Packer 8779 7850 12. Stimulation or cement squeeze summary: ~ ~~(~ E~~('1 Intervals treated (measured): ~ ~ ~ , ~~ ~ t~~~~! ~ .¢ ~ ti ~ ~1 ~ ~ 4~,D VV s a - ._ r_ °~ ~ N 2 ~ ~ ~ 1 G Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection D Oil-Bbl Gas-Mcf Water-Bbl Casing ressureA`^ Tubing pressure Prior to well operation: 2392 670 Subsequent to operation: 1134 1480 14. Attachments: Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service 0 Daily Report of Well Operations X Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^~ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 6/29/2010 ~''l ~ N-08A 200-009 DGR~ ATTA~_NMFNIT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base N-08A 3/16/00 PER 11,000. 11,050. 8,971.03 9,016.16 N-08A 12/16/00 APF 10,250. 10,270. 8,774.82 8,770.37 N-08A 5/14/01 BPS 10,950. 10,960. 8,928.73 8,936.97 N-08A 6/17/05 APF --~ kb ~ 8,628. 8,630. 7,700.55 7,702.43 N-08A 6/14/10 APF ~ v (' 10,475. 10,500. 8,739.1 8,737.62 N-08A 6/14/10 APF 10,500. 10,525. 8,737.62 8,737.37 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE N-08A 200-009 DRRF ATTArNMFNIT Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base N-08A 3/16/00 PER 11,000. 11,050. 8,971.03 9,016.16 N-08A 12/16/00 APF 10,250. 10,270. 8,774.82 8,770.37 N-08A 5/14/01 BPS 10,950. 10,960. 8,928.73 8,936.97 N-08A ,-~. 6/16/05 SPS 8,853. 11,000. 7,914.06 8,971.03 N-08A 6/17/05 APF F n- 8,628. 8,630. 7,700.55 7,702.43 N-08A --'i 6/17/05 SPS 8,812. 10,250. 7,874.93 8,774.82 N-08A 10/12/07 BPS 8,812. 10,250. 7,874.93 8,774.82 N-08A 6/14/10 APF 10,475. 10,500. 8,739.1 8,737.62 N-08A 6/14/10 APF 10,500. 10,525. 8,737.62 8,737.37 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 6/12/2010 CTU # 9 w/ 1.75" CT Scope; Perf Continued from WSR 06-11-10. «<InterAct is publishing»>continue RIH w/ SLB GR/CCL inside 2.2" carrier. Pass thru liner top @ 9243' without any problem, sat down @ 10286. Repeat and pickup clean several 'times. Came online down coil w/diesel and made several more attempts. On last attem t tools stuck ulled to 40k and ulle fr Tools appeared to drag debris, then pulled normal. RBIH w /motor & 2.30" mill tagging @ 9505' appears we are going on the out side of the liner POOH. Straighten pipe. RIH w/ motor, 2.2" to 1.90" tapered mill. Pass thru LNR top without any problems. tag restriction @ 10285' mill to 10288 w/ several stalls..; Pooh.Mill show min signs of wea~`to'T continued on WSR 06-13-10* ACTIVITYDATE SUMMARY 6/11/2010;CTU # 9 w/ 1.75" CT. Scope; Perf Perform weekly BOP test. Shut in well. RIH w/ sSLB GR, CCL inside 2.2" carrier. **job continued on WSR 06-12-10"" 6/1 N-08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY OCTU # 9 w/ 1.75" CT Scope; pert. ""Continued from WSR 06-12-10** Cont RIH w/ 1.69" motor and 2.3" diamond parabolic mill. Made several attempts to get inside LNR.Tools would set down at 9505. Pooh. Bottom 1.5' of coil had scar mar s indicating being on outside of LNR. Made it to CIBP (a~ 10960' w / 1.80" drift. RIH w/ 1.69" SLB memory GR/ CCL. pass thru LNR w/o problems, log 60 fpm from 10924. paint referance flag @ 10625 and cont log 60 fpm to 10100'. Pooh. Good data w/ -23' correction. RIH w/ 1.69" MHA w/ 25' x 1.56" HSD PJ1606 - 6 spf pert gun. **job continued on WSR 06-14-10** ._.~,.. 6/14/2010 CTU # 9 w/ 1.75" CT. Scope; pert **Continued from WSR 06-13-10*" continue i RIH w/ 25' PJ1606 - 6 SPF 1.56" pert gun. Shoot perf interval 10500-10525'. RIH iw/Gun run #2 - 25' PJ1606 - 6 SPF 1.56" pert gun Top shot 10475' bottom shot 10500'. Confirmed Auns fired. Recovered 1/2" ball. Freeze pro ec we w s 50/50 methanol «<Job complete»> FLUIDS PUMPED BBLS 83 DIESEL 277 1 % XS KCL 109 50/50 MEOH 469 Total WELLH -• MCEVOY ACTUATOR= BAKER KB. ELEV = 61.52' BF. ELEV = 41.86' KOP = 3200' Max Angle = 103 @ 10254' Datum MD = 10862' Datum TV D = 8804' SS 7" TIEBACK CSG, 26#, L-80 TCII, ID = 6.276" 10-3/4" CSG, 55.5#, N-80, ID = 9.953" SAFETY ES: WELL EXCEEDS 70 DEG. @ 9750' & N /0 8~i GOES HORIZONTAL @ 10112'. 148' 11-314" X 9-518" THERMOCASE II 500' ESTIMATED TOP OF CEMENT 2039' 10-3/4" X 9-518" XO 1248' 2039' 2082' 9-5/8" FOC 2096' 4-112" HES X NIP, ID = 3.813' 2105' 9-5/8" CSG SEAL ASSY 2513' 9-5i8" FOC 13-3/8" CSG, 72#, N-80, ID = 12.347" ~ 2600' Minimum ID = 2.372" @ 9258' TOP OF 2-7/8" LINER 7" TIEBACK CSG, 26#, L-80 BTC, ID = 6.276" ~~ 8761' ~ 4-1 /2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, N-80, ID = 8.681" PERFORATION SUMMARY REF LOG: SWS-BRCS 08119!74; PDS GR/DIL 03/15/00 ANGLE AT TOP PERF: 103 @ 10250' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2 4 10250 - 10270 O 12/16100 1.56 6 10475 - 10500 O 06!14!10 1.56 6 10500 - 10525 O 06114110 2 4 11000 - 11050 C 05/14!01 TOP OFWINDOW-1 y5(j4' 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" I-I 10038' I PBTD I $634' -j4-112" HES X NIP, ID = 3.813" $665' 7" X 4-1 /2" BKR S3 PKR, ID = 3.875" 8699' - 4-112" HES X NIP, ID = 3.813" _ -~ 8722' 7" ES CEMENTER ~ ~ 8739' -TOP OF 7" BTM TIEBACK SLV ~' $761 ` 7" SEAL ASSY, ID = ???? $773' 4-112" HES XN NIP, ID = 3.725" 8779' 9-518" x 7" LNR TOP PKRI 87$1' 7" LNR HGR 8786' 4-112" WLEG, ID = 3.958" ~- ELMD TT NOT LOGGED 9243' 4-1/2" BKR ENTRY GUIDE, ID = 3.63" 9244' 3-314" BKR DEPLOY SLV, ID = 3.00" 9250' TOP OF 2-7/8" LNR, ID = 2.372" 7" MILLOUT WINDOW 9567' - 9574' 10950' I-I 2-718" BKR CIBP (05114101 } (CTMD) 2-7/8" LNR, 6.16#, L-80 STL, .00579 bpf, ID = 2.372" I-i 11139' DATE REV BY COMMEMS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12113(76 ORIGINAL COMPLETION 07/19/08 RM/SV TREE C!O (07!16108} WELL: N-08A 03116!00 CTU SIDETRACK {N-08A} 06/18/10 RMHlSV ADD PERF (06114110} PERMff No: 200-0090 07102!05 D16 RWO API No: 50-029-20143-01 09/02/05 MW/PJC CMTANNULUS CORRECTION 4711' WEL, 3161' SNL, SEC. 8, T11N, R13E 01/30/06 BEJPJC MCEVOY TREE CORRECTION 08/29/06 /TLH DRLG DRAFT CORRECTIONS BP Exploration (Alaska} OPERABLE: N-08A (PTD #2000090) WAG Injector with stable OA pressure Page l~ • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, December 20, 2008 3:52 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD}; GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Starck, Jennifer L; GPB, Prod Controllers Cc: Holt, Ryan P (ASRC); Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: N-08A (PTD #2000090) WAG Injector with stable OA pressure Attachments: ATT4098916.txt; N-08A TIO and Injection plot.doc All, Well N-08A (PTD #200{090} has been reclassified as Operable. After swapping the infector to water on 12/19/08, the M{TIA passed confirming two barriers. Gas samples from the n,n arr~ rliccimilar frnm nnl ~s indicating past OA pressure is not from MI injection. The OA pressure has been stable since and MITOA was conducted on 12/03/08. The MITOA failed due to slow leak off, too small to measure a liquid leak rate. The well will remain on the AOGCC Monthly Injection Report for at least the next three months to continue to monitor the OA pressure. At this time no further action will be taken and the well may be normally operated. A recent TIO plot and injection profile have been included far reference. «N-08A TIO and Injection plot.doc» Please iet me know if ypu have any questions. Thank you, Anna ~u6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 `;4~'YL'WJ"r~v 9i~,t~:,~ tY: f""~i~. Lr ~2 4.. L!1.-~'~7 From: NSU, ADW Well Integrity Engineer Sent: Saturday, November 22, 2008 1:30 PM To: GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Starck, Jennifer L; GCE Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: N-08A (PTD #2000090) WAG Injector OA repressurization All, ~C~ z~~~ ~z~ ~~~~~~ i ~~~~ t ~.~~ r~~ ~~~ ~P2 aC(~e.~ ~J~z~.u~~ z~~~,q ~,~-a-. ~~~ 1 ~ssberg, R Steven; Engel, Harry R; NSU, ADW ~ ~ ~ G0~ Pad MN; GPB, Prod Controllers Well N-08A (PTD #2000090) is a WAG in~ for currently on MI injection with OA repressurization. The well was worked over in July '05 when new 7" duction casing was set and cemented over a leak in the 9-5/8" production casing at -7100' md. The well has een reclassified as Under Evaluation to determine the source of the OA repressurization. The well sh emain on MI for a short amount of time for gas samples to be obtained and then must be swapped to water shut-in. The plan forward f~this well is as follows: PBU N-08A (PTD #2000090) TIO Plot 4,nr.~r, ;; noo 2 n00 1 nnr~ 03120102 03/27/02 10104108 .10111102 10/12102 10/25109 11/01108 11/08102 11/15/02 11122108 11129109 12106102 12/13/02 ~ PBU N-08A (PTD #2000090) Injection Plot ' I _. ~, --- ------------ 1s,oot~ ' J " ', ' ` a 14,000 3,Ofii 12:000 ~, 2 ~Oi ~ 10,Mfi ~ } ~ 2,000 o 9:000 ~~- ~ 1,500 6,OOU 1,OOt~ 4.000 ° t 5010 2,OOU p31201Ca8 03127102 10104108 10111108 10119108 10/25109 11101/08 11108/08 1111510811122109 1112311)8 12106108 12113102 12120/02 i Z j ZG~uvo~ -*- Tbg -E- IA -~ OA -+ OOA -~ DOOA - ~- On WHIP SW PW MI GI 0 Cher --~- 0 n • • • ~' 'a~ N ° v ~ N ~ ~ N i o a O Q 0 z m a Sao rn 0 f N I° M_ ~~~ b ~~5 ~ ~00~~ ~~5 Z ~~~~Z 0~5 ~ 0~0 ~ ~~5 ~ ~ 6isd 'dIHM Page 1 of 1 • ~4- Regg, James B (DOA) ~ ~ ~ e~ ~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, December 06, 2008 9:52 AM ~~ l IZi~~Z,~~ To: Regg, James B (DOA) ~ l Cc: NSU, ADW Well Integrity Engineer Subject: RE: PBU N-08A (PTD 2000090) Jim, After the message was sent to the Commission the OA pressure was increasing to near MOASP. The OA pressure was bled on 11/26108. After the bleed the well showed signs of slowed OA re-pressurization. On 12/01/08 a gas sample was taken from the OA, but the sample was wet and could not be analyzed for composition. To evaluate the competency of the OA, an MIT-OA was conducted to 1500 psi on 12143108. The MIT-OA failed to 1500 psi but the wail passed a liquid No Flow Test. The wail was shut in at this time and IA and OA were bled to 0 psi to allow apack-off test to be done on 12/05/08. The IC.pack-offs were re-energized and the test gassed. We are currently bringing the well online to check far repressurization and to obtain a gas sample from the OA. !wilt make sure that the results are provided to you when it is / analyzed. Please contact me ifi you would like to discuss any point about this well. Thank yau, Taylor Wellman filling. in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, December 05, 2008 8:27 AM To: NSU, ADW Well Integrity Engineer Subject: PBU N-08A (PTD 2000090) Message sent to Commission on 11/24/08 indicated PBU N-08A (WAG injector; currently on MI) was exhibiting OA repressurization, and a gas sample was obtained from OA to determine if repressurization was from MI or some other source. Have you received the analysis and if so, what are the results? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 12~g~2~~g FW: UNDER EVALUATION: N-08A (PTD #2000090) WAG Injector with OA repressurization Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, November 24, 2008 1:17 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: FW: UNDER EVALUATION: N-08A (PTD #2000090) WAG Injector with OA repressurization Attachments: N-08A TIO Plot.doc; N-08A.pdf Jim and Tom, I realized I inadvertently missed on sending this to you. We should have the lab samples soon and will evaluate from there. Thank you, Anna ~u6e, ~? E. Well Integrity Coordinator GPB Wells Group Phone; {907) 659-5102 Pager: {907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Saturday, November 22, 2008 1:30 PM To: GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Starck, Jennifer L; GPB, Well Pad MN; GPB, Prod Controllers Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: N-O8A (PTD #2000090) WAG Injector with OA repressurization AI I, Well N-08A (PTD #2000090) is a WAG injector currently on MI injection with OA repressurization. The well was worked over in July '05 when new 7" production casing was set and cemented over a leak in the 9-5/8" production casing at -7100' md. The well has been reclassified as Under Evaluation to determine the source of the OA repressurization. The well shall remain on MI for a short amount of time for gas samples to be obtained and then must be swapped to water or shut-in. The plan forward for this well is as follows: 1. Lab: Obtain and analyze gas samples from the OA and injected MI for comparison of composition 2. Operations: Swap well to water injection or shut-in well 3. DHD: Bleed OA pressure, monitor BUR 4. Well Integrity Engineer: Evaluate lab sample results and pressure build-up information to determine path forward A Ti0 plot and wellbore schematic have been included for reference. «N-08A TIO Plot.doc» «N-08A.pdf» Please call with any questions or concerns. 11 /24/2008 FW: UNDER EVALUATION: N-08A (PTD #2000090) WAG Injector with OA repressurization Page 2 of 2 • Thank you, Anna ~u6e, ~? E. WeN Integrity Coordinator GPB Wells Group Phone: {907} 659=5102 Pager: {907} 659-5100 x1154 11 /24/2008 PBU N-08A PTD 200-009 1 I /22/2008 TIO Pressures 4.000 }~ p ~u~i icy 3:Oiau~ ,.f I ~ 5~ 1-~-----J-- ~: ouu 1.000 ~a (~ , 0$123,'0$ 0$13010$ 09/0E10$ 0911310$ 0912010$ 0912710$ 1010,'0$ 1011110$ 1011$!0$ 1012510$ 1110110^0 1110$10$ 1111510$ = 4-1(1 WELLHEAD= MCEVOY ACTUATOR= BAKE KB. ELEIi - ~61.52'~ BF ELEV. - 41.86'.. nvr - - 3200' Max Angle = 103 @ 10254'. Datum MD = 10862' Datum TV D = 8800' SS 7" TIEBACK CSG, 26#, L-80 TCII, fD = 6.276" 10-314" CSG, 55.5#, N-80, ID = 9.953" ~ 124$' r •~ $ .~ GO~ORIZONTAL @ 10112~S 70 DEG. @ 9750` & 14$' 11-3/4" X 9-518" THERMOCASE II 500' ESTIMATED TOP OF CEMENT ~ 2039' 10-3(4" X 9-5/8" XO 20$2' 9-518" FOC 2096' 4-1/2" HES X NIP, ID = 3.813" 2105' 9-518" CSG SEAL ASSY 2513' 9-5l8" FOC 13-318" CSG, 72#, N-8Q ID = 12.347" ~ 2600' Minimum ID = 2,372" @ 9250' TOP OF 2-71$" LINER (7" TIEBACK CSG, 26#, L-80 BTC, ID = 6.276" ~ 112" TBG, 12.6#: L-80 TCII, .0152 bpf, ID = 3.958'° ~-j $7$6' 9-5(8" CSG: 47#: N-80; ID = 8.681" ~ 9255' PERFORATION SUMMARY REF LOG: SWS-BHCS 08119/74; PDS GR/DIL 03!15100 ANGLE AT TOP PERF: 103 @ 10250' Note: Refer to Production DB for his#orical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2 4 10250 - 10270 O 12(16100 2 4 11000 - 11050 C 45!14(01 TOP OF WINDOW 9564' 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" '--~ 1003$' $634' -~4-1/2" HES X NIP, ~ = 3.813" $665' 7" X 4-1/2" BKR S3 PKR, ID = 3.875" $699' 4-112" HES X NIP, ID = 3.813" 8722' -( 7" Es CEMENTER $739' TOP OF 7" BTM TIEBACK SLV $761' °j 7" SEAL ASSY, ID = ???? $773' 4-1/2" HES XN NIP, ID = 3.725" $779` 9-518" x 7" LNR TOP PKR $7$1' 7" LNR HGR 87$6' 4-112" WLEG, ID = 3.958" C~ ELMD TT NOT LOGGED 9243' 4-112" BKR ENTRY GUIDE, ID = 3.63" 9244' 3-314" BKR DEPLOY SLV, ID = 3.00" 9250' TOP OF 2-7l8" LNR, ID = 2.372" 7" MILLOUT WINDOW 9567' - 9574' 10950' I-j2-7/8" BKRCIBP(05/14/fl1 PBTD I-I 11072' 2-7/8" LNR, 6.16#. L-80 STL, .00579 bpf, ID = 2.372" ~~ 111 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12113176 ORIGINAL COMPLETION 07/19!08 RIWSV TRE E CIO (07I16J08} WELL: N-08A 08/16/00 CTU SIDETRACK (N-08A} _ _ ~~ PERMff No: 200-0090 07!02/05 D16 RWO API Na: 50-029-20143-01 09/02105 MWIPJC CMT ANNULUS GORRECTION 4711' WEL, 3161' SNL, SEC. 8, T31 N, R13E 01/30!06 BE(PJG MGEVOY TREE CORRECTION 08/29/06 ITCH DRLG DRAFTCORRECTIONS BP Explora#ion (Alaska} MEMORANDUM Toy Jim Regg P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 14, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC N-08A PRUDHOE BAY UNIT N-OSA Src: Inspector NON-CnNFII)F.NTT s T Reviewed By: P.I. Suprv. ~ ~~ Well Name: PRUDHOE BAY UNIT N-08A API Well Number: 50-029-20143-01-00 Inspector Name: Chuck Scheve Insp Num: mitCS08041 l 185153 Permit Number• 200-009-o Inspection Date• 49/2008 Rel Insp Num: ~ • Monday, April 14, 2008 Page ! of ! STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Û/æ)o¡Ç ~ØfC{ I Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay 1 PBU 1 N Pad 12/24/05 Rob Mielke ::l..Ob~OOr Packer Depth Pretest Initial 15 Min. 30 Min. WellIN-08A I Type Inj. I W TVD 1 7,739' Tubing 2,060 2,060 2,0601 2,000 Intervall 4 P.T.D.12000090 I Typetest I P Test psi I 1934.75 Casing 1,0801 2,510 2,4801 2,475 P/FI P Notes: MIT-IA to 2500 for 4 year reg. compliance OA 0+ 10+ 0+ 10+ Pumped 1.1 bbls neat Meoh for test. Well' I Type Inj. I TVD I Tubing I I I I Interval I P.T.D.I I Type test I I Test psil I Casing I I I I P/FI Notes: I OA I I Weill I Type Inj.1 TVD I Tubing 1 Interval I p.T.D.1 I Type test 1 Test psil Casing I PIFI Notes: OA I Weill 1 Type Inj.1 TVD I Tubing Interval I P.T.D.I 1 Type testl Test psil Casing PIFT Notes: OA Weill I Type Inj.1 1 TVD I Tubing Interval 1 P.T.D.I I Type test 1 I Test psil Casing I PIFT Notes: OA AOGCC Rep. John Crisp declined to witness. TYPE INJ Codes D ~ Drilling Waist G ~ Gas I ~ Industrial Waistewater N ~ Not Injecting W ~ Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M:= Annulus Monitoring P ~ Standard Pressure Test R ~ Internal Radioactive Tracer Survey A ~ Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I ~ Initial Test 4 ~ Four Year Cycle V = Required by Variance T ~ Test during Workover o ~ Other (describe in notes) . \11;\\' .~.\'f;.\ ; ~'VC~~~~~~.... Cl 2005-1224_MIT _PBU_N-08Axls i"',-,' :¡"""'" -':I 'Æ-'" '1 "~fi_":1, '~,' 'I 'ç'J ".,'" 'j"'" 'ß" """ [¡""" , I . l :1; !' ¡, ,', \ I ij I! '~,' , );' f/ \ Ii ! ',\ I: i /l' '., I 'I i' @ u t,\ J l6 ) (11) !~F ,1;'1"\\ n¡ i, I WI ¡ 1 !;'::1 ..iJ \ I, il' ;\\ U.i !I' :) ,i !r~ ':\ II 1_", '-\ . ,jJ iJ-J ,u ~!~ ') ,~.//;~~ :rr\' i.~ \ U WI FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Warren Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 RE: Prudhoe Bay N-08A Sundry Number: 305-333 ~rJÆJ./f)@e¡ Dear Mr. Warren: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, sçANNEL ~~O'J 0 2. 2005 DATED this.zrday of October, 2005 Enc!. 1. Type of Request: (!¡l]- /0 -'2/7- ¿) S- , STATE OF ALASKA, ALl-. ~ OIL AND GAS CONSERVATION COMMk. ,bN APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Development 0 Stratigraphic 0 RE . EI OCT 2 6 Z005 Perforate U A'aWaiv~r:~", Other U r7l SKit u§ ¡ r;j\~~-" Co~·, Stimulate t.::J Time Extension ,I.;~ ^~,,' ,./II,I/¡¡:$, Re-enter Suspended Well DAnch~Jrag,~ 5. Permit to Drill Number: Exploratory 0 200-0090"'/ ./ r.:;¡ 6. API Number: ./ .' Service c!I Abandon U Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Suspend U Repair well D Pull Tubing D µGI\- to 2.1 { l.OOç Anchorage, AK 99519-6612 7. KB Elevation (ft): 9. Well Name and Number: 50-029-20143-01-00 / 61.52 KB N-08A /' 8. Property Designation: ADL-028282 11. Total Depth MD (ft): 11139 Total Depth TVD (ft): 9100.87 10. Field/Pools(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 11072 9036.65 10950 Casing Length Size MD TVD Burst Conductor 74 20" 94# H-40 26 100 26 100 1530 Surface 2575 13-3/8" 72# N-80 25 2600 25 2600 4930 Intermediate 2015 10-3/4" 55.5# N-80 24 2039 24 8297 6450 Production 7216 9-5/8" 47# N-80 2039 9255 2038.94 8297 6870 Liner 786 7" 29# N-80 8781 9567 7845.41 8590 8160 Liner 1895 2-7/8" 6.16# L-80 9244 11139 8286.83 9101 13450 Perforation Depth MD (ft): 10250 - 10270 Perforation Depth TVD (ft): 8774.82 - 8770.37 Tubing Size: 7" 26# 4-1/2" 12.6# Tubing Grade: N-80 L-80 Packers and SSSV Type: Packers and SSSV MD (ft): 4-1/2" Baker S-3 Perm Packer 7" Liner Top Packer 8665 8779 12. Attachments: Descriptive Sum m ary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for 13. Well Class after proposed work: Exploratory 0 Developm ent 0 ,,/ 15. Well Status after proposed work: Oil 0 Gas 0 Plugged D WAG ~ GINJ 0 WINJ 0 Commencing Operations: 16. Verbal Approval: Commission Representative: 11/9/2005 Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Contact Michael Warren Printed Name ~ ~ MitaJ1'f~rren Signature t¡/~~ p(fit tH/Q~1U¡ Production Engineer Date 10/26/2005 Phone 564-4306 COMMISSION USE ONLY Junk (measured): None Collapse 520 2670 4020 4760 7020 13890 Tubing MD (ft): 24 - 8779 24 - 8784 Service ~ Abandoned 0 WDSPL 0 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 306--33::;; Plug Integrity D Mechanical Integrity Test D Location Clearance D BOP Test D Other: f~ED~AS 8Ft Ory ;q :: 2005 APPROVED BY ()~',S~", r-l,E~' Al I THE COMMISSION ~,' r\ 'c] ~ j \1 L Date: 1::i:: ) ') Description Summary of Proposal: 1) Drift as deep as possible (high angle well), perform CT fill cleanout if required. 2) Add new perforations 10,475-10,525 MD. 3) Perform contingent mud acid stimulation if injectivity is less than 6 MBD. 25 bbls NH4CI 50 bbls 7.5% HCI / 50 bbls 9/1 Mud Acid 100 bbls NH4CI overflush 4) Return well to injection. Thanks, Mike Warren Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well 1-31/M-21 'c:.f) - ü'} ]... 07-34A ) oc ~ ð~.3 15-14A J.ûLt - .ÀJ. ~ Y-23B ). () J -. i f.s¡ \., N-08A ,. \¡~.. t crt K-08A '^ \:a -~ .... I L( ~ W-26A ,C\'\ - C~\ L5-09 \ q ~ ~ j J.. '-f OWDW-NW I ~c .. J... '1 i:::. C-34 J 98· CI Y 01-12A ';). ~).. - ¡ (l t DS 05-41A ).. {,¡ ~.- I -, ~ 02-26C ). G > - ü \ q Job# 10980540 11001051 10913003 10913024 10919802 10942219 11051066 11051037 10980537 10831309 10928620 10715377 10928619 Log Description RST (REVISED)* RST (REVISED)* PEX-DSI-AIT PDC-GR LDL MEM PPROF LDL RST RST RST MCNL MCNL MCNL *REVISED TO CORRECT API# ON DIGITAL DATA PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ,-, \ '-.(t / ~)..;(J ~.'^ ~., Á}~'-..(, \ SCÞNNEC Date 04/14/05 04/26/05 01/16/05 06109/05 09124/04 06124/05 06123/05 04127105 03126105 07/09/04 04103105 01121104 03120105 SEP fl ?- ('. 01 n !~ L '''.J 07/14/05 NO. 3433 .;{oo-vð1 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL Color CD 1 1 1 1 '- 1 I~ J. ~ 3 r3:A~Y i .~ J...) (~ I J J..J ~. 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 J 3 JJ 7 1"3 J.18 iJ J.JC¡ ).} ~"/ l\ jJ~'1f i) ,14 1 '-~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anch~rage. AK 9"°732838 ¡1 ATTN. Beth ;/j-f Ii U Received by: / '. I¡\~\,. .Ill ;' ÛJt~ STATE OF ALASKA ') ALASKAlL AND GAS CONSERVATION CO...,(¡IISSIONBfCEIVED REPORT OF SUNDRY WELL OPERATIONjðL 21 Z005 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: o Development 0 Exploratory o Stratigraphic 181 Service Alaska Oíl. & Gas GOIIS. ~_~~~~~~_~_1 o Other Anchorage o Re-Enter Suspended Well o Time Extension 5. Permit To Drill Number: 1. Operations Performed: o Aba ndon o Alter Casing o Change Approved Program o Suspend 0 Operation Shutdown 0 Perforate 181 Repair Well 0 Plug Perforations 0 Stimulate 181 Pull Tubing 0 Perforate New Pool 0 Waiver 99519-6612 200-009 6. API Number: 50-029-20143-01-00 61.52' 9. Well Name and Number: PBU N-08A 8. Property Designation: ADL 028282 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11139 feet true vertical 9101 feet Plugs (measured) 10950 Effective depth: measured 10950 feet Junk (measured) None true vertical 8929 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 20" 100' 100' 1530 520 Surface 2600' 13-3/8" 2600' 2600' 4930 2670 Intermediate 7149' 9-5/8" 2106' - 9255' 2106' - 8297' 6870 4760 Production Liner 786' 7" 8781' - 9567' 7845' - 8590' 8160 7020 Liner 1895' 2-7/8" 9244' - 11139' 8287' - 9101' 13450 13890 Tieback 2106' 11-3/4" x 10-3/4" x 9·5/8" 2106' 2106' Tieback 8781' 7" 85t!ÄNNED J(Jr52 ;) 2005 7240 5410 Perforation Depth MD (ft): 10250' - 10270' Perforation Depth TVD (ft): 8775' - 8770' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2", 12.6# L-80 8786' 7" x 4-1/2" Baker 'S-3' packer; 4-1/2" HES 'X' Nipple 8665'; 2096' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFL .JUL 2 5 2005 Treatment description including volumes used and final pressure: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl CasinQ Pressure TubinQ Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram 15. Well Class after proposed work: o Exploratory 0 Development 181 Service 16. Well Status after proposed work: o Oil 0 Gas 181 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Paul Chan, 564-5254 305-149 Printed Name Terrie Hubble Signature ---1Ô.N\Ì t de ~ Form 10-404 Revised 04/2004 Title Technical Assistant 0'1/.;u j Prepared By Name/Number: Phone 564-4628 Date 0..<) Terrie Hubble, 564-4628 U RIG ! N A L Submit Original Only ) ) Well: Field: API: Permit: N-08A Rig W orkover Prudhoe Bay Unit 50-029-20143-01-00 200-009 Accept: Spud: Release: Rig: 06/19/05 N/A 07/02/05 Doyon 16 PRE-RIG WORK 05/04/05 TAG SSSV NIPPLE AT 2025' SLM. 05/05/05 PULLED 7" INSERT AT 2025' SLM. DRIFT FOR CHEM CUT TO 9224' SLM. MADE 2 ATTEMPS TO PULL L TTP, NO LUCK. 05/06/05 ATTEMPT TO PULL L TTP, MADE SEVERAL ATTEMPTS WI 2.5" & 4" GS, RAN 2.5 PUMP BAILER (EMPTY). 05/07/05 RAN HYDROSTATIC BAILER SEVERAL TIMES (RECOVERED 1 CUP OF INJ SCHMOO), MADE ONE MORE ATTEMPT TO PULL L TTP BUT W AS UNABLE, APPEARS L TTP EQUALIZING PORTS MIGHT BE PLUGGED OFF. 05/11/05 MU BHA WI 3.5" GS. RIH. JET ACROSS LTTP FISH NECK WITH 10 BBLS METH. LATCH LTTP AND POOH. HDMO. 06/12/05 LOG CORRELATED TO JEWELRY LOG, DATED 1 MARCH 2000. ATTEMPTED TO SET 33/8" IBP AT 8841', (10' BELOW TOP OF SECOND FULL JOINT BELOW THE. 7," LINER). FIRST ATTEMPT FAILED DURING SETTING PROCESS, POOH WI IBP. SECOND ATTEMP-r'!THEIBP SET BUT FAILED TO SHEAR THE RUNNING TOOL. HAD TO USE BAKER'S EMERGENCY DISCONNECT!LEAYING IBP AND RUNNING TOOL IN THE HOLE. FISH SPECS: 1 3/8" F.N ON THE DISCONNECT, 1 3/4" F.N ON THE IBP, 2-EACH 6" COVER RUBBERS & 1 - 1" STIFFENING RING. OAL = 14' 06/14/05 PULLED IBP AT 8843' WLM. MIDDLE RUBBER ELEMENT WAS MISSING. DRIFT TBG W/ 5-1/2 WIRE GRAB. DRIFT WITH 7" WIRE BRUSH. 06/15/05 ATTEMPT TO FISH CENTER ELEMENT OFF OF 3 318 IBP (LEFT IN HOLE). DRIFTED LINER WI 2.25 GR. 06/16/05 SET IBP AT 8841' WITH LOG CORRELATED TO JEWELRY LOG DATED 3/1/2000 AND TUBING DETAIL. (PRE RWO) SET 10' INTO SECOND JOINT BELOW PACKER. 1.75" FN, OVERALL LENGTH 11.59', FROM CENTER ELEMENT TO TOP = 6.50'. DUMPED 1 BAG OF 24/40 RIVER SAND ON TOP OF IBP AT 8833' SLM + 20' = 8853' CORRECTED. BEGIN TO RIH WI 2ND DUMP BAILER. 06/17/05 DUMPED - 20' (10 BAGS) OF 24/40 RIVER SAND ON TOP OF IBP. STARTED AT 8833' SLM ENDED AT 8812' SLM. DRIFTED W/5.87" GAUGE RING TO 8812' SLM. SHOOT STRING SHOT, TUBING PUNCHER AND CHEMICAL CUTTER. CUT IN THE MIDDLE OF THE FIRST FULL JOINT ABOVE THE PBR WITH 5.75" CHEMICAL CUTTER. LOG CORRELATED TO JEWELRY LOG DATED 1- MARCH-2000. LEFT SEVERING HEAD IN HOLE AND TURNED OVER TO SL TO FISH. 06/18/05 TAGGED FISH AT 8812' SLM WI 5.5" LIB, PIC WAS CLEAN. RAN BAKER OVERSHOT TO 8812' SLM, RECOVERED FISH. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BPEXPLORA TION O:petati()n$SummaryReport Page 1 of 1 0 N-08A N-08A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/19/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 7/28/1974 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/19/2005 00:00 - 00:30 0.50 MOB P PRE PJSM on Moving Rig, Lowering Derrick and Installing Booster. 00:30 - 03:00 2.50 MOB P PRE Moved Off F-40 and Postioned Rig to Lay Down Derrick. 03:00 - 04:00 1.00 MOB P PRE Removed BOP's from Pedestal and Placed in Carriage. Set TD in Rotary Table and Serviced, L / D Derrick. 04:00 - 05:00 1.00 MOB P PRE Installed Boosters and Prepared Rig to Travel to N Pad. 05:00 - 09:30 4.50 MOB P PRE PJSM wi Security. Moved Rig from F-Pad to N-Pad. 09:30 - 10:30 1.00 MOB P PRE Removed Rear Boosters. 10:30 - 11 :00 0.50 MOB P PRE Removed BOP Stack from Carriage and Placed onto BOP Pedestal. 11 :00 - 11 :30 0.50 MOB P PRE Held PJSM. Raised and Pinned Derrick. 11 :30 - 12:00 0.50 MOB P PRE Rigged Up Drill Floor and Bridled Down Lines. 12:00 - 18:00 6.00 BOPSUP P DECOMP R / U Top Drive. Change Lower Rams to 7". Install 13-5/8" Drilling Spool on BOPE. Accept Rig at 12:00 Hrs 6/19/2005 18:00 - 22:00 4.00 PULL N WAIT DECOMP Clean and Service Rig. Wait On DSM to RID N-08ai Well House and Flow Line Removal, Move Up Rights, Grade and Level Pad. -- Wind Speed Greater than Maximum Speed Allowable for Safe Lift. Wind Speed Must be Lower Than 25 MPH. 22:00 - 00:00 2.00 PULL N WAIT DECOMP DSM on Location. Pull Well Houses and Flowlines. 6/20/2005 00:00 - 03:30 3.50 PULL N WAIT DECOMP Continued Removing Well Houses, Flowlines, and Scafolding. 03:30 - 07:30 4.00 PULL N WAIT DECOMP Tool Service Shot and Leveled Pad I Location Area. 07:30 - 08:30 1.00 PULL N WAIT DECaMP DSM Installed BPV in N - 08ai. 08:30 - 10:30 2.00 PULL P DECaMP Set Herculite and Mats. 10:30 - 12:00 1.50 PULL P DECOMP Spotted, Shimmed and Leveled Rig Over N - 08ai. 12:00 - 13:00 1.00 PULL P DECOMP R I U Over N - 08ai. N I U Secondary Annulus Valve. R I U to 9-5/8" x 7" Annulus. 13:00 - 14:00 1.00 PULL P DECOMP R / U Vacuum Trucks to Pits, Took on Seawater into Pits #3 and #4. Waited on DSM. 14:00 - 14:30 0.50 WHSUR P DECOMP Held PJSM. R I U DSM, Latched and Pulled BPV, RID DSM. Tubing and IA Pressure 100 psi. 14:30 - 15:00 0.50 KILL P DECOMP Held PJSM w/ Rig Crew, Vac Truck Drivers, Toolpusher and Drilling Supervisor. R / U 9-5/8" x 7" Annulus to Choke Line. 15:00 - 16:30 1.50 KILL P DECOMP Tested Lines to 3,000 psi, OK. Circulated Bottoms Up, ICR 10 bpm, 1,900 psi, FCR 10 bpm, 2,600 psi. Pumped 350 bbls, Took Returns to Slop Tank. 16:30 - 17:00 0.50 KILL P DECaMP Shut Down Pump and Monitored Well, Well Dead. 17:00 - 18:00 1.00 WHSUR P DECOMP R / U DSM Lubricator, Ran and Set TWC, RID DSM. Pressure Tested TWC from Below to 1,000 psi, OK. 18:00 - 20:30 2.50 WHSUR P DECaMP N I D Tree and Adapter Flange, Terminate Control Lines, Function LDS, Make Dummy Run w/7" IJ4S Test Joint. 20:30 - 00:00 3.50 BOPSUR P DECOMP N / U BOPE: 13-5/8" 5M GK Annular Preventer, 13-5/8" 5M Blind Shear Rams, Mud Cross w/ Kill Choke Lines, 13-5/8" Lower Pipe Rams with 7" Rams and Spacer Spool. N I U Riser. Installed Flow Line. 6/21/2005 00:00 - 01 :00 1.00 BOPSUF P DECOMP M I U Test Joint, RIH and Engage Tubing Hanger. R I U BOPE Test Equipment. 01 :00 - 05:30 4.50 BOPSUP P DECOMP Test BOPE, Test Annular Preventer 3500 psi Highl 250 psi Low, Blind Rams, Pipe Rams, Choke Manifold and Valves, HCR's, Kill Line, Choke Line, Floor Valves, and IBOP to 4000 psi high I 250 psi low. Test Accumulator Unit. All Test Held for 5 mins. All Test held wi no leaks or Pressure Losses. Test Witnessed by BP Drilling Supervisor. AOGCC Witness Waived by John Crisp. Printed: 7/11/2005 10:17:58 AM ) ) BP EXPLORATION Operations SµmmaryReport Page 2 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-08A N-08A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/19/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 7/28/1974 End: 7/2/2005 Date From -To Hours Task Code NPT Phase Description· of Operations 6/21/2005 05:30 - 06:30 1.00 BOPSUR P DECOMP RID BOPE Test Equipment. 06:30 - 07:30 1.00 WHSUR P DECOMP PJSM-R/U DSM Lubricator, Latch and Pull BPV, RID Lubricator, Well On Vacuum 07:30 - 08:30 1.00 PULL P DECOMP PJSM-M/U 7" Tubing Spear Assembly; Spear P/O Assy-5-3/4" Spear-5-3/4" Spear-Spear Ext.-Stop Sub-XO = 14.87' Total Length 08:30 - 09:00 0.50 PULL P DECOMP RIH, Engaged Tubing, P/U 10,000# to Ensure Grapples Engaged, BOLDS 09:00 - 12:00 3.00 PULL P DECOMP P/U t/ 300,000# on Spear-No Movement, Slacked off and Repulled to 31 O,OOO#-No Movement, Repeat Process t/ 325,000#-No Movement, Repeat t/ 350,000#-Slight Movement, Repeat t/ 375,OOO#-Hanger Came Off Seat, Repeat t/ 400,000#-16" Movement, Repeat t/ 425,000#-1.5' Movement, Worked String fl 150,000# - t/ 425,000# Trying to Pull Free w/o Success 12:00 - 13:00 1.00 PULL P DECOMP Released Spear from Hanger, B/O and LID Spear Assy. 13:00 - 14:00 1.00 PULL P DECOMP R/U 7" 350 ton Elevators and Slips, P/U and M/U 7" Ldg. Jt. to Hanger 14:00 - 14:30 0.50 PULL P DECOMP Spotted Schlumberger E-Line Truck, Brought E-Line Equipment to Rig Floor 14:30 - 16:00 1.50 PULL P DECOMP PJSM-R/U Schlumberger Equipment and String Shot I CCL 16:00 - 18:00 2.00 PULL P DECOMP RIH t/ 8,750' wI String Shot I CCL, Correlated to CCL Log 6-17-05. Set on Depth 8,702.4', Stand Off CCL to Top String Shot 3.6', Fired Shot fl 8,706' - t/ 8,721'. POH wi String Shot, Shot Successfully Fired 18:00 - 21 :30 3.50 PULL P DECOMP PJSM-RIH wi 5.75" Chemical Cutterl CCL. Correlate Depths wI 6-17 Log. Set on Depth at 8,702.4'. CCL to Cutter = 17.6'. Cutter Set On Depth at 8,720'. Fired Cutter-Lost 210,000# String Weight. 21 :30 - 23:00 1.50 PULL P DECOMP POH wi E-Line, Remove Pack-off, Break Down Tools and Remove from Rig Floor, Hang E-Line In Derrick 23:00 - 00:00 1.00 PULL P DECOMP Pull 7" Tubing, Break Over Weight 320,000#, Reset Slips and R/U to Circulate 6/22/2005 00:00 - 00:30 0.50 PULL P DECOMP Circulated Bottoms Up, Pump Rate 10 bpm, 1,100 psi. RID Schlumberger Equipment. 00:30 - 02:30 2.00 PULL P DECOMP Pulled Tubing Hanger to Rig Floor, B I 0 Landing Jt., Hanger and LID Same. Removed 350 Ton Elevators and Slips. Changed Out Bails and Installed 250 Ton Elevators. R I U Camco Spooler. 02:30 - 07:00 4.50 PULL P DECOMP POOH wi 7" 26# L-80 TC4S Tubing. Spooled Up Dual SSSV Control Lines on Camco Spooler. 07:00 - 07:30 0.50 PULL P DECOMP B I 0 and LID SSSV. RID and Cleared Rig Floor of Spooling Unit. 100% Recovery of Control Lines. Recovered 53 Clamps and 109 SS Bands, 100% Recovery. 07:30 - 16:30 9.00 PULL P DECOMP POOH wI 7" 26# L-80 TC4S Tubing. Total Tubing Recovered: 225 Joints, Cut Joint - 20.95'. Top of Fish 8,738.00'. 16:30 - 18:00 1.50 PULL P DECOMP RID 7" Handling Equipment. Cleared Rig Floor. Cleaned Rig. 18:00 - 18:30 0.50 BOPSUF P DECOMP PI U Test Joint and Test Plug, Installed Test Plug, RILDS. 18:30 - 19:30 1.00 BOPSUF P DECOMP Changed Out 7" Solid Rams for 3-1/2" x 6" Variable Rams. 19:30 - 20:00 0.50 BOPSUF: P DECOMP Tested Variable Rams t/ 250 psi Low I 4,000 psi High. Held Tests for 5 min. Each Test Held without Leaks or Pressure Loss. Test Witnessed by BP Drilling Supervisor Rodney C. Klepzig, Doyon Tool Pusher Pete Martinson. Printed: 7/11/2005 10:17:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP EXPLORATION OPE!ratlon~ Summary.·Report N-08A N-08A WORKOVER DOYON DRILLING INC. DOYON 16 Page 3 011 0 Start: 6/19/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 7/28/1974 End: 7/2/2005 Date From- To Hours Task Code NPT Phase Description of Operations 6/22/2005 20:00 ~ 20:30 0.50 BOPSUP P DECaMP Pulled Test Plug and RAnd and Installed Wear Bushing, lID TestJt. 20:30 ~ 23:00 2.50 FISH P DECOMP Held PJSM. M I U Spear Assy. BHA: Spear Packoff Assy.-5~3/4" Spear wi 6.220" Grapple-Spear Extension-Stop Sub-XO-Bumper Jar-Oil Jar-XO-12 x 6-1/4" DC's-Accelerator Jar-XO = 421.03' Total length. 23:00 ~ 00:00 1.00 FISH P DECaMP RIH wI Spear Assy BHA on 4" DP. PI U from Pipeshed 1 x 1. 6/23/2005 00:00 ~ 07:30 7.50 FISH P DECaMP RIH wi 5-3/4" Spear (wI 6.220" Grapple) Assy BHA on 4" DP to 8,660'. Picked Up DP from Pipe Shed 1 x 1. 07:30 ~ 15:30 8.00 FISH P DECOMP M I U Top Drive, Established Parameters: String Weight Up 195,000#, String Weight Down 155,000#, Pump Rate 5 bpm, 500 psi. Washed Down and Worked Grapples into Fish, Pump Rate 3 bpm, 190 psi, Observed Pump Pressure Increase to 400 psi as Packoff Enter Tubing Stub. Shut Down Pump. RIH and Stacked 10,000# on Fish, P I U wI 80,000# Overpull and Allowed Jars to Bleed Off. Applied Straight Pull wI 105,000# Overpull, No Movement. Attempted to Jar Seal Stem Free. Began Jarring wi 80,000# Overpull, Stepped Up Jarring Overpull Weight to 175,000# wI Straight Pull of 225,000# Overpull, without Success. Continued to Jar and Pull on Fish While Waiting on Schlumberger. 15:30 - 16:00 0.50 FISH P DECaMP Spotted Schlumberger E-Line Truck, Brought E-Line Equipment to Rig Floor. 16:00 ~ 17:30 1.50 FISH P DECaMP Held PJSM. R I U Schlumberger Equipment and String Shot I CCl. 17:30 - 19:00 1.50 FISH P DECOMP RIH wi 1-11/16" 3-Strand String Shot! CCl Tools on .023 E-Line 19:00 ~ 20:30 1.50 FISH P DECOMP String Shot Tools Tagged Obstruction at 8,768', Firing Head Depth 8,728', CCl at 8,723', Suspected 5-3/4" Spear Assy. wI 2" ID. Worked String Down to 8,732', Firing Head Depth, CCl at 8,728'. Encountered Restricted Tool Movement, Worked String Up Until Free Movement Observed at 8,728'. Set String Shot Across Interval fl 8,728' - t/ 8,768'. Fired Shot. Observed Slight Movement In E-Line. 20:30 - 21 :30 1.00 FISH P DECOMP POOH wi String Shot I CCl BHA on E-Line. Shot Successful. 21 :30 - 22:30 1.00 FISH P DECOMP M I U Top Drive, Began Jarring Process with 175,000# Overpull and Allowed Jars to Fire, Followed wi Straight Pull of 225,000# Overpull, Repeated Process Until Seal Stem Pulled Free. Picked Up Out of PBR wI 50,000 Overpull for 30'. 22:30 ~ 00:00 1.50 FISH P DECaMP Circulated Bottoms Up, 540 bbls I 5,400 stks at 7 bpm I 980 psi. RID Schlumberger E-Line Truck. 6/24/2005 00:00 - 01 :00 1.00 FISH P DECOMP Inspected Top Drive and Derrick, Serviced Top Drive 01 :00 ~ 01 :30 0.50 FISH P DECOMP POOH wi 5-3/4" Spear Assy on 4" DP. 01 :30 - 03:00 1.50 FISH P DECOMP Repaired Top Drive, Faulty Fitting on Bail Link Tilt. 03:00 - 05:00 2.00 FISH P DECOMP POOH wi 4" DP 05:00 ~ 06:00 1.00 FISH P DECOMP POOH wi Spear BHA, Stood Back 6-1/4" DC's. 06:00 - 07:00 1.00 FISH P DECOMP B I 0 Spear from Fish. POOH, B I 0 and lID Fish: 7" Cut Joint - 14.95', PBR Insert wlo Seals - 29.58', Seal Stem - 10.52'. 07:00 - 07:30 0.50 FISH P DECOMP B I 0 Spear Assy from BHA and liD Same. Cleared and Cleaned Rig Floor. 07:30 - 09:00 1.50 FISH P DECOMP Held PJSM. M I U Polish BHA: 7.40" Polish Mill wI Stop Collar, XO , 9-5/8" Casing Scraper, Bit Sub XO, Bumper Jars, Oil Jars, I Printed: 7/11/2005 10:17:58 AM ) BP EXPLORATION·. OperationsSul'I1maryReport . Page 4 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-08A N-08A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/19/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 7/28/1974 End: 7/2/2005 Date From -To Ho u rs Task Code NPT Phase Description of Operations 6/24/2005 07:30 - 09:00 1.50 FISH P DECOMP XO, 12 x 6-1/4" DC, XO, XO. BHA Total Length - 411.56'. 09:00 - 11 :30 2.50 FISH P DECOMP RIH w/ BHA on 4" DP to 5,200'. 11 :30 - 12:00 0.50 DHB P DECOMP Held PJSM. M / U 9-5/8" RTTS Packer w/ Storm Valve and XO to 4" DP String. RIH to 69'. String Weight Up 127,000#, String Weight Down 123,000#. Set RTTS Packer at 69'. Release from Packer and POOH. Closed Blind Rams and Tested Packer to 1,000 psi. OK. Bled Down Pressure. 12:00 - 15:00 3.00 WHSUR P DECOMP Held PJSM w/ Rig Crew, Cameron Rep, Tool Pusher and Drilling Supervisor. N I D Flowline, Riser and BOP Stack. N I D Spool. Pulled Old Packoff. 15:00 - 18:30 3.50 WHSUR P DECOMP Installed New 9-5/8" Primary Seal, N I U New Spool wi YB Packoff. Tested Packoff to 2,450 psi. Test Witnessed By Rodney C. Klepzig 18:30 - 20:00 1.50 WHSUR P DECOMP N/U Bop's, Install Riser and Flowline, Secure BOP's wi Turnbuckles 20:00 - 21 :00 1.00 WHSUR P DECOMP Install Test Plug, Test Full Body BOP and Top Flange of New 13-5/8" Wellhead to 250 psi Low and 4,000 psi High for 5 min. Each. No Visual Leaks or Pressure Loss. Test Witnessed by BP Drilling Supervisor Rodney C. Klepzig. Remove Test Plug and Install Wear Ring 21 :00 - 21 :30 0.50 WHSUR P DECOMP Retrieve Halliburton RTTS and LID Same 21 :30 - 22:30 1.00 WHSUR P DECOMP RIH wi 7.40" Polish Mill Assy. on 4" DP f/ 5200' - t/ 8752' 22:30 - 00:00 1.50 WHSUR P DECOMP M/U Top Drive and Establish Parameters; String Weight up 190,000#, String Weight Down 155,000#, Rotary String Weight 174,000#, Pump 210 gpm at 460 psi. Rotary Speed 80 rpm, Rotary Torque off Bottom 6,500 ft/lbs. Dress 7" Liner Tie-Back fl 8,756' - t/ 8,761'. Observed Presure Increase of 20 psi When Mill Entered Tie-Back and Torque Increase to 9,000 ft/lbs. Stop Collar Tagged Tie-Back at 8,756'. Pump Pressure Increased 70 psi t/ 530 psi, Torque Increased to 11,000 ft/lbs and Weight ceased to Drill Off. 6/25/2005 00:00 - 01 :00 1.00 CLEAN P DECOMP Held PJSM. Cleaned Pits #3 and #4, Mixed 40 bbl Safe-Surf / Flo-Vis Pill in Pill Pit, Filled Pits #3 and #4 w/ Clean 140 deg. Sea Water. R I U Hot Oil and Tested Lines t/ 3,000 psi. 01 :00 - 03:00 2.00 CLEAN P DECOMP Little Red Pumped 50 bbls 180 deg Diesel, 1.8 bpm, 240 psi. Switched to Rig Pump, Pumped 40 bbl 140 deg Hi-Vis Detergent Sweep. Displaced Well Bore w/ 140 deg Clean Seawater, 9 bpm, 1,550 psi. Took All Dirty Well Bore Fluid, Diesel, Hi-Vis Detergent Sweep and 50 bbls Seawater Interface to Slop Tank. Blew Down Lines. 03:00 - 07:00 4.00 CLEAN P DECOMP POOH w/ 4" DP. 07:00 - 09:00 2.00 CLEAN P DECOMP POOH, B I 0 and L / D All BHA Components. 09:00 - 09:30 0.50 WHSUR P TIEB1 M / U Retrieving Tool, Latched and Pulled Wear Bushing, Ran and Set Test Plug. 09:30 - 12:00 2.50 BOPSUP P TIEB1 Held PJSM. C I 0 3-1/2" X 6" Variable Rams fl 7" Solid Rams. R / U 7" Handling Equipment to Run 7" Casing. 12:00 - 13:00 1.00 BOPSUPP TIEB1 R / U Test Equipment. Performed Body Test on Stack and Bonnet Doors. 250 psi 14,000 psi Held Each Test for 5 minutes I wi No Leaks or Pressure Loss. Test Witnessed by BP Drilling Supervisor. Latched and Pulled Test Plug. 13:00 - 13:30 0.50 CASE P i TIEB 1 Held PJSM. M I U Seal Assy wi Orifice Insert and Baffle Sub. M I U Halliburton ES Cementer. Bakerlocked Connections. M I I U Torque 8,000 It llbs. Printed: 7/11/2005 10:17:58 AM ) ) BP EXPLORATION O¡perationsSui11maryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/25/2005 6/26/2005 N-08A N-08A WORKOVER DOYON DRILLING INC. DOYON 16 From - To Hours Task Code NPT Phase 13:30 - 22:30 9.00 CASE P TIEB1 22:30 - 00:00 1.50 CASE P TIEB1 00:00 - 02:30 2.50 CASE P TIEB1 02:30 - 03:00 0.50 CEMT P TIEB1 03:00 - 03:30 0.50 CEMT P TIEB1 03:30 - 05:00 1.50 CEMT P TIEB1 05:00 - 07:30 2.50 CEMT P TIEB1 Page 5 of 10 Start: 6/19/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 7/28/1974 End: 7/2/2005 Description of Operations M I U and RIH wi 180 Joints 7" 26# L-80 BTC Casing. Average M / U Torque 8,500 ft / Ibs. M / U TC II x BTC-M Crossover Jt. Held PJSM. Changed Bails, R / U Compensator and Torque Turn Equipment. RIH w/ 30 Jts. 7" 26# TC II L-80 Casing, Make Up Torque 10,100 ft/lbs, Ran a Total of 220 Joints and 1 Crossover Jt. String Up Weight 250,000#, String Weight Down 210,000#. Held PJSM. M / U XO Jt. RID Compensator, PI U and M / U Cement Head, R / U Cementing Lines. Broke Circulation at 8 bpm wi 820 psi. Shut Down Pumps, Slacked Off and Stung Into 7" PBR. Applied 500 psi to Test Seals, OK. Bled Down Pressure and Picked Up Out of PBR. Loaded Opening Plug and Pumped Down Same to ES Cementer, 8 bpm 1820 psi. Slowed Pump Rate to 2-1/2 bpm Prior to Bumping. Bumped Plug w/ 3,280 stks. Pressured Up to 300 psi to Ensure Plug Seated. Bled Down Pressure and Loaded Closing Plug into Cement Head. Pressured Up to 3,250 psi and Opened ES Cementer. Bled Down Pressure and Stung Back Into PBR. Broke Circulation with 8 bpm at 850 psi. Held PJSM With Rig Crew, Dowell, Hot Oil Crew, Halliburton Reps, Tool Pusher and Drilling Supervisor. Switched to Dowell, Pumped 5 bbls Water, 4 bpm, 500 psi. Shut in Cement Manifold, Tested Cement and Hot Oil Lines to 4,000 psi, OK, Bled Down Pressure. Switched to Little Red Hot Oil, Pumped 30 bbls Diesel, 3 bpm /250 psi. Shut Down, Switched Over to Dowell. Mixed and Pumped 233 bbls (1,128 sks) 15.8 ppg Premium Class G Cement wi 0.300 %bwoc Dispersant, 0.030 %bwoc Retarder, 0.200 gal / sk Antifoam. Pumped Cement at the Following Rates: Pumped Rate Pressure 25.0 bbls 6.00 bpm 1,100 psi 50.0 bbls 6.00 bpm 1,100 psi 100.0 bbls 5.00 bpm 825 psi 150.0 bbls 3.00 bpm 320 psi 200.0 bbls 5.00 bpm 780 psi 225.0 bbls 5.00 bpm 790 psi 233.0 bbls 2.50 bpm 320 psi Dropped and Pumped Closing I Wiper Plug wi 5.0 bbls Water 5 bpm, 200 psi Displaced Cement wi 328 bbls of Mud at the Following Rates: Pumped Rate Pressure 25.0 bbls 8.00 bpm 430 psi 50.0 bbls 8.00 bpm 430 psi 100.0 bbls 10.00 bpm 660 psi 150.0 bbls 10.00 bpm 660 psi Caught Cement wi 170 bbls Pumped 200.0 bbls 9.00 bpm 1,850 psi 250.0 bbls 8.00 bpm 2,700 psi 300.0 bbls 5.00 bpm 2,950 psi 325.0 bbls 1.50 bpm 2,850 psi 328.0 bbls 1.25 bpm 2,800 psi I Closing I Wiper Plug Bumped wi 333.0 bbls Total Displacement Pumped. Pressured up to 3,900 psi to Close Printed: 7/11/2005 10:17:58 AM ) ) BP EXPLORATION Operations Summary Report· Legal Well Name: N-08A Common Well Name: N-08A Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 From- To Hours Task Code NPT 6/26/2005 05:00 - 07:30 2.50 CEMT P 07:30 - 08:30 1.00 CEMT P 08:30 - 09:30 1.00 BOPSUP P 09:30 - 10:30 1.00 WHSUR P 10:30 - 11 :00 0.50 WHSUR P 11 :00 - 12:00 1.00 WHSUR P 12:00 - 12:30 0.50 WHSUR P 12:30 - 13:30 1.00 WHSUR P 13:30 - 16:00 2.50 BOPSUR P 16:00 - 17:00 1.00 BOPSUR P Phase TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 17:00 - 19:00 2.00 CLEAN P CLEAN 19:00 - 22:00 22:00 - 00:00 3.00 CLEAN P 2.00 CLEAN P CLEAN CLEAN 6/27/2005 00:00 - 00:30 0.50 CLEAN P CLEAN 00:30 - 01 :00 0.50 CLEAN P CLEAN 01 :00 - 02:00 1.00 CLEAN P CLEAN 02:00 - 03:00 1.00 CLEAN P CLEAN 03:00 - 03:30 0.50 CLEAN P CLEAN 03:30 - 06:30 3.00 CLEAN P CLEAN 06:30 - 07:30 1.00 CLEAN P CLEAN 07:30 - 08:00 0.50 CLEAN P CLEAN 08:00 - 08:30 0.50 CLEAN P CLEAN 08:30 - 11 :00 2.50 FISH P DECOMP 111 :00 - 13:30 I 2.50 FISH P I DECOMP i I Page 6 of 10 Start: 6/19/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 7/28/1974 End: 7/2/2005 Description of Operations Cementer. Bled Down Pressure and Checked Cementer, Cementer Closed. Cement in place at 0715 hrs. Blew Down and RID Lines and Cement Manifold. Flushed BOP Stack. Drained Stack. N I D Flowline and Riser. Removed Bolts and P I U BOP Stack. Set 7" Casing Slips, Slacked Off on Casing and Set 195,000# on Slips. R I U Wachs Cutter and Cut 7" Casing. Broke Out and LID Cut Joint and Landing Joint. Set BOP Stack onto Pedestal. Cleaned Wellhead, PI U and Set Tubing Spool onto Wellhead. M I U 13-5/8" 5M Tubing Spool to Wellhead. M I U Secondary Annulus Valve. Energized Packoff Seals and Tested to 4,350 psi f/30 Minutes. Bled Off Pressure and RID Wellhead Testing Equipment. Held PJSM. N I U BOP Stack, Riser and Flowline. cia 7" Solid Rams to 3-1/2" x 6" Variable Ran and Set Test Plug, Filled BOP Stack. Closed Blind Rams. Performed Body Test on Tubing Spool Flange, Stack and Bonnet Doors. 250 psi 14,000 psi Held Each Test for 5 minutes wi No Leaks or Pressure Loss. Test Witnessed by BP Drilling Supervisor. Latched and Pulled Test Plug. PJSM-P/U and M/U Clean Out BHA #2; 6-1/8" Bit-7" Casing Scraper-2 ea. Junks Baskets-Bit Sub XO-Bumper Jar-Oil Jar-XO-12 x 4-3/4" DC's = 404.02' Total Length RIH wi Clean Out BHA on 4" DP. Tag Cement at 8,706' M/U Top Drive and Establish Parameters; String Up Weight 200,000#, String Weight Down 140,000#, Rotary String Weight 157,000#,240 gpm at 1,060 psi, 40 rpm at 7,000 ft/lbs. WOB 5,000# to 15,000#. Drill Cement fl 8,706' - t/ 8,721'. Drill Out Closing Plug and ES Cementer fl 8,721' - t/ 8,724'. Clean Out t/ 8,744' Circulated Bottoms Up at 8,744',250 bbls, 10 bpm, 2,680 psi. Pressure Tested 7" Tie-back Casing to 4,000 psi. Test Charted and Witnessed By Drilling Supervisor. Drilled Halliburton Baffle Adaptor and Baker Float Collar fl 8,745' - t/ 8,747'. WOB 5,000# - 6,000#, rpm 70, Torque 8,500 ft I Ibs, Pump Rate 6 bpm, 1,040 psi. Washed Down t/ 8,812'. Circulated 40 bbl Hi-Vis Sweep Surface to Surface, 350 bbls, 10 bpm, 2,700 psi. Reciprocated and Rotated DP While Circulating. Blew Down Top Drive, Monitor Well-Static. Serviced Top Drive. POOH wi 4" DP. POOH wi BHA, B I 0 and LID Same. Cleared and Cleaned Rig Floor. Held PJSM. M I U IBP Retrieving BHA: Sure Catch 0 IS, XO, XO, Bumper Jars, Oil Jars, Pump Out Sub, XO, 12 x 4-3/4" DC. BHA Total Length: 396.59'. RIH wi IBP Retrieving BHA on 4" DP to 8,800'. M I U Top Drive, Established Parameters: String Weight Up 200,000#, String Weight Down 137,000#, Pump Rate 6 bpm, 1,000 psi. Washed Down to 8,834',6 bpm, 1,000 psi. Pumped I and Circulated Around 40 bbl Hi-Vis Sweep, 10 bpm, 2,650 psi. I Printed: 7/11/2005 10:17:58 AM ) ) BP EXPLORATION Operati()nsSu mmary·· Report Page 70f 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-08A N-08A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/19/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 7/28/1974 End: 7/2/2005 Date From ~ To Hours Task Code NPT Phase Description of Operations 6/27/2005 11 :00 - 13:30 2.50 FISH P DECOMP Slowed Pump Rate to 2 bpm, 100 psi, Washed Down, Attempted to Latch and Retrieve IBP, w/o Success. Blew Down Top Drive Monitored Well. Static. 13:30 - 16:30 3.00 FISH P DECOMP POOH wi 4" DP. 16:30 - 17:00 0.50 FISH P DECOMP POH wi Retrieving Assy. #2, Stand Back 4-3/4" DC's. UD 3-5/8" Surecatch Overshot 17:00 - 17:30 0.50 FISH P DECOMP Clear and Clean Rig Floor 17:30 - 18:00 0.50 FISH P DECOMP P/U and M/U BHA; Sure Catch Overshot (5-3/4" Guide)-XO-Bumper Jar-Oil Jar-Pump Out Sub-XO- 12 x 4-3/4" DC's = 397.04' Total Length 18:00 - 19:00 1.00 FISH P DECOMP Slip and Cut Drilling Line 19:00 - 22:00 3.00 FISH P DECOMP RIH w/ Sure Catch Overshot on 4" DP V 8,770' 22:00 - 00:00 2.00 FISH P DECOMP M/U Top Drive and Establish Parameters; String Weight Up 183,000#, String Weight Down 145,000#, Rotary String Weight 160,000#, Pump Rate; 5 bpm, 650 psi, Rotary; 10 rpm, 3,000 fVlbs Torque. Circulate Down f/ 8,770' - V 8,834'. Tag IBP and Set Down 10,000#. P/U V 8,820', No Overpull. Slack Off and Tag IBP, Apply 15,000# Down Weight, Shut Down Pumps, Observed Sudden 5,000# Weight Loss. P/U t 8,825', No Overpull, Slack Off Rotating, String Stalled Out, P/U No Overpull, Rotate Down, String Stalled, Continue to Slack Off, Regained Rotary, Slack Off Until String Stalled Again. Shut Down Pumps. Apply 25,000# Down Weight. P/U,Observed Overpull of 5,000#, Slack Off to Neutral Weight and Let IBP Relax for 15 min. P/U V 185,000#, Lost Overpull Weight, Attempt to Relatch w/o Success. 6/28/2005 00:00 - 01 :00 1.00 FISH P DECaMP Circulate 20 bbl Hi-Vis Sweep Surface to Surface at 10 bpm, 2,700 psi, Blew Down Top Drive, Monitor Well-Static 01 :00 - 04:30 3.50 FISH P DECaMP POH wi 4" DP 04:30 - 05:00 0.50 FISH P DECOMP POH w/ BHA #5; Stand Back 4-3/4" DC's, B/O and UD Sure Catch Overshot. Left 5-3/4" Guide and Extension Sleeve in Hole. Total Length 1.48', Fishing Neck 3" x .78" 05:00 - 06:00 1.00 FISH P DECOMP Wait on Fishing Tools 06:00 - 09:30 3.50 FISH P DECOMP M/U BHA #6: close-catch Overshot, Bumper sub, Oil Jars, Pump-Out sub, XO and 12 ea DC's. TIH wi same to 8,832'. 09:30 - 10:00 0.50 FISH P DECOMP Latch onto Fish, Blow-down Top Drive. P/U wt 187K, SIO wt 145K, 630 psi @ 50 SPM. 10:00 - 13:00 3.00 FISH P DECOMP POH and SIB DP and DCs in Derrick. 13:00 - 13:30 0.50 FISH P DECOMP B/O and UD Fish and M/U BHA #7: 5-3/4" O/S wi 1-7/8" G/R, Bumper sub, Oil Jars, Pump-Out sub, XO, and 12 ea 4-3/4" DCs. 13:30 - 16:00 2.50 FISH P DECOMP RIH wi BHA #7 to Latch onto IBP @ -8,832'. 16:00 - 18:00 2.00 FISH P DECOMP Get Parameters: P/U wt 188K, S/O wt 144K, Rot wt 162K. Tag @ 8,832' (3' in on DP Jt #265). P/U 10' then WID slowly @ 28 RPM, 52 SPM, 660 psi. Don't see change in wt, but WID to 19' in on #265, then wt slacks off. P/U to 220K and hold, wt slacks off to 180K. Repeat several times with same results. SID pump and P/U and see same results with a stack-out @ 19' in on #265,8,847'. Start pump and P/U, wt slacks off to 188K, continue POH for one jt. Pulls wet. Decide to continue POOH. 18:00 - 21 :30 3.50 FISH P DECOMP POH, Overpull of 22,000# wlo Bleed Off, Pump Out of Hole fl 8,825 - V 8,632'. Pull Dry, Steady Overpull of 5,000# V 7,000#, Continue to POH w/o Pumping. Printed: 7/11/2005 10:17:58 AM ) ') BP EXPLORATION Operations Summary Report Page 8 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-08A N-08A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/19/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 7/28/1974 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description·of Operations 6/28/2005 21 :30 - 22:30 1.00 FISH P DECaMP POH wI BHA: Stand Back 4-3/4" Dc's, No IBP, BIO and UD Overshot, Inspect Overshot and Grapple, NO Internal Markings. Some Scarring On Bottom of Cut Lip Guide 22:30 - 23:00 0.50 FISH P DECaMP P/U and M/U BHA #8; Reverse Circulating Jet Basket-Bumper Sub-Oil Jar-Pump Out Sub- XO-12 x 4-3/4" DC's = 402.07' Total Length 23:00 - 00:00 1.00 FISH P DECOMP RIH wI 4" DP 6/29/2005 00:00 - 01 :30 1.50 FISH P DECOMP RIH wI Clean Out BHA #8; Reverse Circulating Jet Basket-Bumper Jar-Oil Jar-Pump Out Sub-XO-12 x 4-3/4" DC's = 402.07' Total Length 01 :30 - 03:30 2.00 FISH P DECOMP M/U Top Drive and Establish Parameters; String Wt. Up 190K, String Wt. Dn. 135K, Rotary String Wt. 160K, Pump 9 bpm,3100 psi, Rotary 20 rpm at 4,000 ft/lbs Torque. Rotate Dn. fl 8,847' - tJ 8,850', Observe Sudden Loss of 5,000# WOM. P/U wI Initial Overpull of 40,000# Dropping Off Suddenly Back to Orginal Up Wt. Wash Back Dn tJ 8,850'. No Weight On Mill. Continue to Wash Down to tJ 8,875'. RIH Picking Up Singles Out of Pipeshed wlo Pumping. String Took Weight at 9,251'. Weight Would Not Drill Off. No Excess Pump Pressure. Monitor Well-Static. 03:30 - 04:00 0.50 FISH P DECaMP Circulate Bottoms Up at 10 bpm at 3000 psi. Didn't see any junk over shakers. 04:00 - 09:30 5.50 FISH P DECaMP POH and SIB DP and DC's. Breakout BHA and clean Junk Baskets. Found remains of the 7" Cement Shoe and the Fishing Neck section of the IBP, l' in length; 1/2 of the fishing neck had been cut away by the first Overshot Run. There is a 2-3/8" x 1.5' length of the IBP looking up and a Grapple will be sized for the next run. 09:30 - 10:00 0.50 FISH P DECaMP Clear and clean Rig Floor and Lubricate Rig. 10:00 - 15:00 5.00 BOPSUFP DECaMP R/U and PT BOPE 250 psi Low and 4,000 psi high. Chuck Scheve wi AOGCC waived witnessing tests. All tests witnessed by M. S. Rooney. 15:00 - 15:30 0.50 BOPSUP P DECaMP Rig down test lines and Clear and Clean Rig Floor. 15:30 - 16:00 0.50 FISH P DECaMP M/U BHA #9: 5-3/4" Overshot wi 2-3/8" Basket Grapple, Bumper Sub, Oil Jar, Pump Out Sub, XO sub, and 12 ea DC's. 16:00 - 18:30 2.50 FISH P DECaMP RIH wI BHA #9 to 9,251'. 18:30 - 20:00 1.50 FISH P DECOMP M/U Top Drive and Establish Parameters; String Wt. Up 208K, String Wt. Dn 142K, Rt. String Wt. 170K, Pump 10 bpm, 2700 psi. Rotary 50 rpm at 7,500 ft/lbs Torque. Wash Dn. fl 9,213' - tJ 9,251'. P/U wI No Overpull or Pressure Increase. Rotate Dn tJ 9,252'. Observe Pressure Increase of 200 psi. Shut Dn. Pumps and Stack 15K Dn on Fish. P/U wI No Overpull. Start Pumps and Checked Pressure, No Excess Pressure, Rotate Dn. and Try To Engage Fish w/o Success. No Fluid Losses, Monitor Well-Static 20:00 - 23:00 3.00 FISH P DECaMP POH w4" DP 23:00 - 23:30 0.50 FISH P DECaMP POH wI BHA; Stand Back 4-3/4" DC's, B/O and UD 2-3/8" Grapple Overshot. Markings on Inside of Overshot Suggest Junk Still In Hole. Grapple Did Not Make Contact. 23:30 - 00:00 0.50 FISH P DECOMP Clear and Clean Rig Floor 6/30/2005 00:00 - 00:30 0.50 FISH P I DECOMP RIH wi Clean Out BHA # 10; Reverse Circulating Jet I Basket-Bumper Jar-Oil Jar-Pump Out Sub-XO-12 x 4-3/4" DC's = 400.30' Total Length Printed: 7/11/2005 10:17:58AM ) ) BPEXPLORATION Operations.SÜmmary Report ·Page90f 10 Legal Well Name: Com man Well Name: Event Name: Contractor Name: Rig Name: N-08A N-08A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/19/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 7/28/1974 End: 7/2/2005 Date From- To Hours Task Code NPT . Phase Description of Operations 6/30/2005 00:30 - 04:00 3.50 FISH P DECOMP RIH w 4" DP t/ 9,220' 04:00 - 06:00 2.00 FISH P DECOMP M/U Top Drve and Establish Parameters; String Wt. Up 208K, String Wt. Dn. 140K, Rotary String Wt. 164K, Pump 9 bpm, 2,950 psi, Roatry 50 rpm at 7,500 ft/lbs Torque. Wash Dn. fl 9,220' - t/ 9,251' P/U, No Overpull, No Excess Pressure. Rotate Dn t/ 9,251'. P/U, Initial Overpull of 30,000#. Dropped back to Orginal Up Wt.. Rotate Back Dn. Encountering Fluctuating Torque between 7K and 12K. Observe Pressure Increase of 250 psi. Shut Down Pump and Apply 25,000# Dn. Wt. P/U and Check Pump Pressure. No Excess Pressure. Work Pipe and Junk Basket Down to 9,253'. 06:00 - 10:00 4.00 FISH P DECOMP POOH one stand and String wt increased to 240K. Work pipe free and continue POOH, SIB DP and DC's. 10:00 - 12:00 2.00 FISH P DECOMP Break-out and empty Reverse Circulating Junk Basket. Recovered 3.17' of the IBP, which is the remainder of the "hard pipe" attached to the top of the veined sealing element. Most of the element and all of the hard pipe and bull nose below the element remains on top of the 4-1/2" Entry Guide. Wait on re-dressed tools. 12:00 - 13:00 1.00 FISH P DECOMP M/U BHA #11: Reverse Circulating Jet Basket, Double Pin sub, 2-ea Boot Baskets, Bit sub, Bumper Sub, Oil Jar, Pump-out sub, XO and DC's. RIH on one stand of DP from Derick. 13:00 - 14:00 1.00 FISH P DECOMP Slip and Cut Drilling Line. 14:00 - 16:30 2.50 FISH P DECOMP RIH wi BHA #11 to 9,253' to recover remains of dead IBP. 16:30 - 17:30 1.00 FISH P DECOMP Get Parameters: Up wt 212K, Down wt 142K, Rot wt 170K, 40 RPM, Torque 8K ft-Ibs, 84 SPM @ 2700 psi. Tag @ 9,253' and begin to Wash Down. See Torque surge while rotating. P/U and slowly lower onto fish and see same Torque surges. Repeat several times. Make headway to 9,255' and Torque stays @ 10-11 K ft-Ibs. Make additional foot to 9,256'. Decide to POOH and check Reverse Circulating Junk Basket. 17:30 - 20:30 3.00 FISH P DECOMP POH and SIB DP and in Derrick. 20:30 - 21 :30 1.00 FISH P DECOMP POH wI BHA, Stand Back 4-3/4" DC's. Retrieved Remainder of IBP. B/O and UD Junk Baskets and Jet basket. Cleaned Junk Baskets, Small Amount of Metal. Jet Basket Full, Uable to Break Down Jet Basket, Jammed With Metal 21 :30 - 22:30 1.00 FISH P DECOMP M/U BHA #12; Reverse Circulating Jet Basket-Dbl. Pin Sub-2 x Boot Baskets-Bit Sub-Bumper Sub-Oil Jar-Pump Out Sub-XO-12 x 4-3/4" DC's = 411.53' Total Length 22:30 - 00:00 1.50 FISH P DECOMP RIH wi 4" DP 7/1/2005 00:00 - 01 :00 1.00 FISH P DECOMP RIH wi Clean Out BHA # 12 t/ 9,256' 01 :00 - 02:00 1.00 FISH P DECOMP M/U Top Drive and Establish Parameters: String Wt. Up 21 OK, String Wt Dn. 140K, Pump 8 bpm at 3,000 psi. Wash Dn. fl 9,220' - t/ 9,257'. Work Junk Baskets and Jet Basket. Circulate 40 bbls Hi-Vis Sweep Surface To Surface. Monitor Well-Static 02:00 - 04:30 2.50 FISH P DECOMP POH, Lay Down DP. While POH DP Tool Joint Hung Up On the Air Slips and Raised Them Up Coming Into Contact With Iron Roughneck Causing Roughneck To Tip Over. 04:30 - 10:00 5.50 FISH P DECOMP Contacted BP HSE and Doyon Field Superintendent to Initiate Investigation. Please see the Remarks Tab for further information. 10:00 - 13:00 3.00 FISH P DECOMP Repairs to Iron Roughneck and Inspection and service Air Slips. Printed: 7/11/2005 10:17:58 AM ') ) BPEXPLORATION Operations Summary Repo.rt DECOMP Resume POOH and LID DP, DC's & Junk Baskets. Junk Baskets had Minimal Fine Cuttings, Jet Basket was Clean. DECOMP Clear and Clean Rig Floor, Remove Wear Ring RUNCMP R/U Tubing Handling Equipment and Torque Turn Tools RUNCMP RIH wI 4-1/2" 12.6# L-80 TCII Tubing RUNCMP RIH wI 4-1/2" 12.6# L-80 TCII Tubing, torque all connections to 3,850 Ib-ft. RUNCMP P/U Landing Jt and M/U to tubing Hanger. P/U wt 137K, S/O wt 117K. Land Tubing Hanger; TD of tubing 8,762'. RILDS. R/U to circulate. RUNCMP PJSM. Establish circulation. Pres test lines to 4,000 psi. RUNCMP Reverse circulate130 Bbls of 140 F seawater @ 3 BPM and 220 psi. Reverse circ @ 3-BPM and 220 psi, 154 Bbls of 140 F seawater mixed wI 1-Bbl EC 1124 Correxit Corrosion Inhibitor. RUNCMP R/U Lil Red and test lines. RUNCMP Pump 75 Bbls Diesel Freeze Protect down Inner annulus @ 3 BPM, 350 psi. U-Tube Diesel to Tubing. RUNCMP Drop Ball/Rod to set Packer. Pressure upon Tubing to 4,000 psi and record on chart for 30 mins. 250 psi bleed-off in 30 mins, but not seen in IA. Bleed Tubing to 2,000 psi and test Annulus to 4,000 psi and chart for 30 mins. 250 psi bleed-off in 30 mins, but no pressure change in Tubing. P/U, install and test TWC. N/D BOPE. N/U Adaptor Flange and Production Tree, DSM Torqued all Adaptor Flange and Tree Nuts with Hydraulic Wrench Test Adaptor Flange and Tree V 5,000 psi. wI No Leaks or Pressure Loss. Test Witnessed by Cameron, BP Pad Operator, Doyon Tool Pusher and BP Well Site Leader R/U DSM Lubricator and Pull TWC. Install BPV and RID Lubricator Clean Cellar Area, Install All Hardware On Tree. Released Rig AT 2400 hrs 7/2/05 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-08A N-08A WORKOVER DOYON DRILLING INC. DOYON 16 Hours Task Code NPT Phase 7/1/2005 13:00 - 19:30 6.50 FISH P 19:30 - 20:00 0.50 FISH P 20:00 - 21 :30 1.50 RUNCOMP 21 :30 - 00:00 2.50 RUNCOMP 00:00 - 08:30 8.50 RUNCOMP 08:30 - 10:00 1.50 RUNCOMP 10:00 - 10:30 0.50 RUNCOrvP 10:30 - 12:00 1.50 RUNCOMP 12:00 - 12:30 0.50 RUNCOMP 12:30 - 14:00 1.50 RUNCOMP 14:00 - 15:30 1.50 RUNCOMP 7/2/2005 15:30 - 17:00 1.50 BOPSUP P RUNCMP 17:00 - 18:30 1.50 BOPSUF P RUNCMP 18:30 - 21 :00 2.50 WHSUR P RUNCMP 21 :00 - 22:00 1.00 WHSUR P RUNCMP 22:00 - 23:30 1.50 WHSUR P RUNCMP 23:30 - 00:00 0.50 WHSUR P RUNCMP Page 1 oöt 10 Start: 6/19/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 7/28/1974 End: 7/2/2005 Description of Operations Printed: 7/11/2005 10:17:58 AM N-J8A Completion u TREE = 6" CWV ~ WELU-IE'AD= MCEVOY ACTUA TOR= OTIS KB. ELEV = 61.52' BF. ELEV = 41.86' KOP = 3200' Max Angle = 103 @ 10254' Datum MD = 10862' Datum TVD = 8800' SS 110-3/4" CSG, 55.5#, N-80, ID = 9.953" I., 19-5/8" FOC I., 19-5/8" CSG SEAL ASSY I., 2039' 2082' 2105' ~ 113-3/8" CSG, 72#, N-80, ID = 12.347" I., 2600' µ Minimum ID = 2.372" @ 9250' TOP OF 2-7/8" LINER 141/2" TBG, 12.6#, L-80, TC-II, 0.0152 bpf, 10 = 3.958"1., 8786' 17" CSG, 26#, L-80, ID = 6.276" I., I TOP OF 7" BOT TIEBACK SL V I., 19-5/8" X 7" LNR TOP PKR 1-1 17" LNR HANGER I., 19-5/8" CSG, 47#, N-80, ID = 8.681" I., 8739' 1 8739' 1 8779' 1 8781' 1 9255' 1 ÆRFORA TION SUMMARY REF LOG: SWS-BHCS 08/19/74; PDS GR/DIL 03/15/00 ANGLE A T TOP ÆRF: 103 @ 10250' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2 4 11000-11050 C 05/14/01 2 4 10250-10270 0 12/16/00 I TOP OF WINDOW I., 9564' 1 17" LNR, 29#, N-80, .0371 bpf, ID=6.184" I., 10038' I OATE 12/13/76 03/16/00 02128/01 03/05/01 06/03/01 REV BY COI\tÆNTS ORIGINAL COMA..EllON CTU SIDETRACK SIS-SL T CONVERTED TO CANVAS SIS-MD FINAL CH/KAK CORRECTIONS ') IJ 148' I., 11-3/4" X 9-5/8" THERMOCASE II I I I 2039' I., 10-3/4" X 9-5/8" XO I 1 2096' 1"4-1/2" HES X NIPPLE, 10 = 3.813" ~ I 2513' I., 9-5/8" FOC 1 8635' 1"4-1/2" HES X NIPPLE, ID = 3.813" 8669' 1.,7" X 4-1/2" BAKER S-3 PKR, ID = 4.00" 8700' 1"4-1/2" HES X NIPPLE, 10 = 3.813" 8774' 1"4-1/2" HES XN NIPPLE, ID = 3.813" ~ ~ I .- 9243' 1"4-1/2" BKR ENTRY GUIDE, ID = 3.63" 1 9244' I., 3-3/4" BKR DEPLOY SL V, ID = 3.00" I 9250' I., TOP OF 2-7/8" LNR, ID = 2.372" I ~ - ---.. 7" MILLOUTWINDOW 9567' - 9574' I., 2-7/8" BKR CIBP (05/14/01) (CTMD) I 1 PBTD I., 11072' I / 12-7/8" LNR, 6.16#, L-80 sn., .00579 bpf, ID= 2.372" I., 11139' I PRUDHOE BAY UNIT WELL: N-08A ÆRMIT No: 200-0090 API No: 50-029-20143-01 4711'WEL,3161'SNL,SEC.8,T11N,R13E BP Exploration (Alas ka) ~r. ¡ ~.' !.~\. .Ii:f? ltrF, I , I r i /1.f ! II \ì Ill!. ~. I I'! 1.1 II . . I I ,I "'"' :(fù~.~ .,ì. i.I-.i.!IJ? .t:.·.·:.-u:\f;~ \, .' /./ " ili!( ! H \\. ,\, : ~\.. ! U I /¡ ,. 'II \ { ~! \ .' @J\\in~ / / I ALASKA OIL AND GAS iil CONSERVATION COMMISSION / l 1.'I~nu1 i'. I' 6 I I! I ~. I I ' I I .1 ~J U ) I.'Ã.\.\ r~1 p~~,\ II: LflJ L~ ) FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~ÐO-()o9 Paul Chan Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 SCANNED JUN 1 '7 2005 Re: Prudhoe Bay N-08A Sundry Number: 305-149 Dear Mr. Chan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd following the date of this letter, or the next working day if the 23rd day falls on a oli ay or weekend. A person may not appeal a Commission decision to Su erior unless rehearing has been requested. DATED this 15":ay of June, 2005 EncL ~,,~ CIlf ~- (I: /06 \¡J G/~ t; Ii c.; I Z.ð t?S ) STATE OF ALASKA M 'I .1;5 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL JUN 1 'á~ 2'005 20 MC 25.280 1. Type of Request: 0 Abandon 0 Suspend / 0 Operation Shutdown 0 Perforate 0 Other o Alter Casing II Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612. Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 4. Current Well Class: o Development 0 Exploratory o Stratigraphic iii s;rvice 5. Permit To D;lH Number 200-009 /' 6. API Number: 50- 029-20143-01-00,/ 61.52' 9. Well Name and Number: PBU N-08A / 10. Field / Pool(s): ADL 028282 Prudhoe Bay Field / Prudhoe Bay Pool r' . :.1" ' 1II'",:',·i ':,' ,I,'. (I' .·I',..Rc¡::,éE~I1r¡~^ill::l:., ..I"..I~IC\Nr:'t":~I·I'ÄNQllli"A¡\IIJi4C¥" II::I'..···'.·'·',:'I",I',',..I,! 1"'ill:,I:;I,II, :.:::.,1;,,' II:: i 11,,'1 'I'.' ':'1'. :,',"."1 :1 ,1:'1 'I"I!I, i;'IIII',I,.'",.·'I"I; T ota¡Di~~n¡D(~):l E;~;';;';.,"~o1~'~~(ft~~È~~~t;'~i~P~;~(~)r:""p:~I~~'\~iii~;;;;;;;'" . 'J~~k'~o~~~red) Length Size ' Mb rVD BUrst Collapse 8. Property Designation: ~,'~I' ' ., Total Depth MD (ft): 11139 Casing Structural Conductor Surface Intermediate Production Liner Liner Tieback 100' 20" 100' 100' 1530 520 2600' 13-3/8" 2600' 2600' 4930 2670 7149' 9-5/8" 2106'-~ 2106' - 8297' 6870 4760 786' 7" 8781' - 56 7845' - 8590' 8160 7020 1895' 2-7/8" 9244' - 11 39' 8287' - 9101' 13450 13890 2106' 11-3/4" x 10-3/4" x 9-5/8" 210€r 2106' Perforation Depth MD (ft): Perforation Depth TVD (ft): 10250' - 10270' 8775' - 8770' Packers and SSSV Type: 7" Otis 'RQ' SSSV Landing Nipple Tubing Size: 7". 26# Tubing Grade: N-80 Packers and SSSV MD (ft): 2051' Tubing MD (ft): 8779' ,./ 12. Attachments: !HI Description Summary of Proposal D Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: / o Exploratory 0 Development iii Service 16. Verbal Approval: Commission Representative: 17. I h~rebY certify that the foregojAg is true and correct to the best of ~y. knowle?ge. Printed Name . ~I Chan f Title Drilling Engineer s¡gnatuX",- QC~ Phone 564-5254 roc \G. Commission. Use Only June 18, 2005 Date: 15. Well Status after proposed work: DOil / o Gas iii WAG 0 GINJ o Plugged DWINJ o Abandoned D WDSPL Contact Paul Chan, 564-5254 Date (p(¡ if o~ Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 305--149 D Plug Integrity o BOP Test o Mechanical Integrity Test o Location Clearance Other: 1-e s +- p ç.~ . RBDMS BFL JUN 15 2005 COMMISSIOt;JER ('~ D ! r ~ ~\! L~ ~ '. ,.. ~l._ APPROVED BY THE COMMISSION Date S~z! ) ) N-08A proposed Ria Workover Procedure 1. MIRU. ND tree. NU and test BOPE tO~L pirculate out freeze protection fluid and circulate well to clean seawater through the cut. _---",:7 G) 2. Pull ~nd LD 7" tubing string ~o the cut at +/- 7~()'/MD. 3. Retneve 7" seal stem from tieback sleeve. '.--- 4. Dress off tieback sleeve and run 9-5/8" casing scraper. Circulate the hole clean. 5. Run 7" tieback string to surface. Cement 7" to -500' MD."/ //.--~---) 6. Cleanout 7" casing to ES cementer and pressure test. Continue cleaning out to bridge plug. 7. Retrieve bridge plug. ~ 8. Run 4-1/2" L-80 TC-II premium connection completion with 7" x 4-1/2" packer and tailpipe. 9. Displace the IA to packer fluid and set the packer. 10. Test tubing to 4000 psi, test annulus to 4000 psi. Freeze protect to 2200' MD. 11. Set BPV. NO BOPE. NU and test tree. RDMO. . TREE = 6" CIW W8.LHEAD= rvcEVOY ,..."..................................."........ .. A CrL.v\ TOR= OTIS \.............................................. KB. ELEV = 61.52' BF. ELEV = 41.86' k6Þ ;"" '" , "m ""m32ÖÖï 'Max'Än9'~';;'1'Ö3@fö25'~Ï' DatïJïïïMb; foa62' 'Öäiüï"fVÖ;"""æÖQi"'S'š '\ J ') N-08A uu SAFETY NOTES: WELL EXCŒDS 70 DEG. @ 9750' & GOES HORIZONTAL @ 10112'. 148' H11-3I4" X 9-5/8" THERMOCA.SE II 110-3/4" CSG, 55.5#, N-80, ID= 9.953" H 9-5/8" FOC - 19-5/8" CSG SEAL ASSY - ~ 2039' H 10-314" X 9-5/8" XO I 2039' 2082' 2105' . 2051' H 7" OTIS RQ SSSV LA NOIt\G NIP, ID = 5.962" J 113-3/8" CSG, 72#, N-80, ID= 12.347" l-i 2600' µ ~ 2513' 1"9-5/8" FOCi Minimum ID = 2.372" @ 9250' TOP OF 2-7/8" LINER ITOP OF 7" BOTTIEBAO< SLV 1--1 19-5/8" X 7" Lf\R TOP PKR 1-1 17" LNR HA t\GER H 8739' 8779' 8781' ,.......v- I ~ ~~-l~O J r ~IG~ 8781' 1-7" TBG, 26#, N-80 TCHS, .0383 bpf, ID = 6.276" Rgp \fJ6/t- 9243' - 4-1/2" BKRENTRY GUIDE,ID= 3.63" 1 9244' - 3-3/4" BKR DER..OY SL V, ID = 3.00" I 9250' HTOPOF2-7/8" LNR, ID= 2.372" 1 I 9-5/8" CSG, 47#, N-80, ID = 8.681" 1-1 9255' ~ ~, FERFORA TlON SUMMARY REF LOG: SWS-BHCS 08/19/74; PDS GRlDIL 03/15/00 ANGLE AT TOP FERF: 103 @ 10250' Note: Refer to Production DB for historical perf data SIZ E SPF IN1£R\/ AL OpnlSqz DA 1£ 2 4 11000-11050 C 05/14/01 2 4 10250-10270 0 12/16/00 I T' LNR, 29#, N-80, .0371 bpf, ID = 6.184" H 10038' I II~ 7" MILLOUT WINOOW 956T - 9574' ITOP OF WINOOW 1--1 9564' 1-12-7/8" BKRCIBP(05/14/01) (Cn/D) I PBTD H 11072' I / I 2-7/8" LNR, 6.16#, L-80 STL, .00579 bpf, 10 = 2.372" H 11139' I DATE 12/13/76 03/16/00 02/28/01 03/05/01 06/03/01 REV BY COMrvENTS ORIGINAL COtvPLEfION CTU SIDETRAO< SIS-SL T CONV ERrED TO CANVAS SIS-MD RNAL CHIKA K CORRECTIONS PRUDHOE BAY UNIT WELL: N-OBA PERMIT I\b: 200-0090 AA No: 50-029-20143-01 4711' WEL, 3161' SI\l., SEC. 8, T11N, R13E BP Exploration (Alas ka) , -) N-_8A Proposed Completion U U TREE = 6" crvv W~~L~~~~ ' MCEV OY +. CTUA TOR= OTIS ...""""""",.",,,,,,,,,,,,,,,,,,,,, KB. ELEV = 61.52' BF. ELEV = 41.86' 'Kbp; "à20Òi Max Angle; 1 Ò3@10254ï Datum IVÎD = ,'" '16862' ..."""" , , ''''"""""". . Datum 'TV D = 8800' SS 110-3/4" CSG, 55.5#, N-80, ID = 9.953" 1-1 19-5/8" FOC 1-1 19-5/8" CSG SEAL ASSY 1-1 113-3/8" CSG, 72#, N-80, ID = 12.347" 1-1 2039' 2082' 2105' 500 -- ;Y~ I 1 -7 1 ~/ µ/ / 2600' Minimum ID = 2.372" @ 9250' TOP OF 2-7/8" LINER 141/2" TBG, 12.6#, L-80, TC-II, 0.0152 bpf, ID = 3.958" 1-1 -8700 1 17" CSG, 26#, L-80, ID = 6.276" 1-1 1 TOP OF 7" BOT TIEBACK SL V 1-1 19-5/8" X 7" LNR TOP PKR 1-1 17" LNR HA NGER 1-1 19-5/8" CSG, 47#, N-80, ID = 8.681" 1-1 8739' 1 8739' 1 8779' 1 8781' 1 / ~ 9255' 1 ~ ÆRFORA TION SUMMARY REF LOG: SWS-BHCS 08/19/74; PDS GR/DIL 03/15/00 ANGLE AT TOP ÆRF: 103 @ 10250' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2 4 11000-11050 C 05/14/01 2 4 10250-10270 0 12/16/00 7 / I / ,~ /) ~ /~ ~ I' '" // vJ 9-1\" / ¡ (I'~.,/ ,/ .- -~ 148' 1-111-3/4" X 9-5/8" THERMOCASE II 2039' 1-110-3/4" X 9-5/8" XO 1 2100' 1-14-1/2" HES X NIPPLE, ID = 3.813" 2513' 1-19-5/8" FOC 1 1-14-1/2" HES X NIPPLE, ID = 3.813" -8650 1-17" X 4-1/2" BAKER S-3 PKR, ID = 4.00" 1-14-1/2" HES X NIPPLE, ID = 3.813" 1-14-1/2" HES XN NIPPLE, ID = 3.813" 9243' 1-14-1/2" BKR ENTRY GUIDE, ID = 3.63" 1 9244' 1-13-3/4" BKR DEPLOY SL V, ID = 3.00" 1 9250' I--{TOP OF2-7/8" LNR, ID =2.372" 1 7" MILLOUTWINDOW 9567' - 9574' I TOP OF WINDOW 1-1 9564' 1 . 17" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 1-1 10038' 1 DATE 12/13/76 03/16/00 02/28/01 03/05/01 06/03/01 REV BY COMMENTS ORIGINA L COMA-ETION cm SIDETRACK SIS-SLT CONVERTED TO CANVAS SIS-MD FINAL CHlKA K CORRECTIONS 1-12-7/8" BKR CIBP (05/14/01) (CTMD) I PBTD l-i 11072' 1 / I 2-7/8" LNR, 6.16#, L-80 STL, .00579 bpf, ID = 2.372" l-i 11139' 1 PRUDHOE BAY UNrT WELL: N-08A ÆRMrT No: 200-0090 API No: 50-029-20143-01 4711'WEL, 3161' SNL, SEC. 8, T11N, R13E BP Exploration (Alaska) MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc Re: ~-08A (PTD #2000090) Possible PC Leak t Subject: Re: N-08A (PTÐ#2000090)Possible PC Leak From: James Regg <jim_regg@admin.state.ak.us> Date: Tue, 23Dec 2003 14:31 :50 -0900 " , "" "" ..", T ' "r\ .... ,""'.A.nn", '"" " rp"'Ah:t... ,@"DD""'> .O:"pUlj€, ','. ", ,.,' " a.,.L~<:::.t\.Ðn~~;L.tUt)e,£>r~c()m. ' , , """" Cç, :..:WAtJ.t2P' .'.p,'.l\1.1b~rt.',> WitJ.~QÎl.'..~"lJ. D~rt@ådrniIi..'s ta tè ..a.J<}p§:?;' ',' ",'. ',' ",' , " , Anna - Timing for resolution of this seems inappropriate given the failed MITIA and established LLR. Why was there 45+/- days between failed MITIA and subsequent diagnostics (LNFT)? And when can we expect your sundry requesting approval to continue injecting with the PC leak? Jim Regg Dube, Anna T wrote: Hi Winton and Jim, This is an e-mail to update you on the status of well N-08A (PTD# 2000090). The tubing and .IA pressures do not track. Recent events: 10/30/03: MITIA Failed, LLR .3 bpm @ 2500 psi. Left VOlce message for Winton. 11/01/03: Email plans to Winton., MITOA Passed to 2000 psi. 12/18/03: LNFT-IA FAILED. Fluid was diesel FP. Plans forward for this well are as follows: 1. Slickline to set TTP. 2. Conduct MIT-T & MIT-OA to 1.2 times maximum injection pressure. 3. Submit application for sundry for PC leak. Please let me know if you have any questions, , Thanks, Anna Dube Well Integrity Engineer GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 xl154 S(,"'~~I.{'~~~E'.",W",JJ nCfti '} «ìI 2' On"JJ .# "i ~~"'I\\I " ... ~ IL~ Y 1.1 iJ UJ lof2 12/23/2003 2:32 PM Re: N-08A (PTD #2000090) Possible PC Leak . -----Original Message----- From: NSU, ADW Well Integrity Engineer Sent: Saturday, November 01, 2003 12:43 PM To: AOGCC Winton Aubert (E-mail); AOGCC Jim Regg (E-mail) Cc: Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Dube, Anna T; AOGCC Bob Fleckenstein (E-mail) Subject: N-08A (PTD #2000090) Failed MITIA Hi Winton and Jim, Well N-08A (PTD #2000090) failed an MITIA on 10/30/03. The tubing and IA pressures do not track, IAxOA communication is suspected. Recent events: 10/30/03: MITIA Failed, LLR .3 bpm @ 2500 psi. Notified Winton. Plans forward for this well are as follows: 1. Restrict to water only only while diagnostics are being , performed. 2. Conduct a CMIT IAxOA. 3. If the CMIT IAxOA fails, evaluate for a production caslng leak. 4. Include on the monthly injection report. Attached is the completed MIT form and a wellbore schematic. We'll keep you informed of progress. Please call if you have any questions. Thanks, Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943 -1154 Pager: (907) 659-5100, xl154 Email: NSUADWWel1IntegrityEngineer@bp.com « File: MIT PBU N-08 10-30-03.xls » « File: N-08A.pdf » 2 of2 12/23/2003 2:32 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / N Pad 10/30/03 Joe Anders None Packer Depth Pretest Initial 15 Min. 30 Min. WelIIN-08A I Typelni. I S TVD I Tubin~lI 5901 5901 5901 5901 IntervaI O P'T'D'12000090I ITypetest P Test psil Casin~ll 2501 2,5O01 1,7501 NAI P/FI F Notes: Test to evaluate high IA pressure. LLRT established, .3 BPM @ 2500 psi. WellI Type Ini. TVD I ,:,1 ITubin l Interval test Test Cas'n~, I I I I P/~I Notes: WellI Type ,nj.l ~D mubin~l IntewaI Notes: m,,I Type Inj.I TVD Tubin~l Type tes~ Test P/FI Notes: w:,iI Type lnj.l ~D Tubin~l I I J I I Type tes~ Test P/FI Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form MIT PBU N-08 10-30-03.xls Permit to Drill No. 2000090 MD 11139 TVD DATA SUBMITTAL COMPLIANCE REPORT 3/21/2002 Well Name/No. PRUDHOE BAY UNIT N-08A Operator BP EXPLORATION (ALASKA) INC 9109 Completion Date 3/16/2000 ~' Completion Status WAG1N AP1 No. 50-029-20143-01-00 Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format T D T T Name Injection Profil 'L// NGP-MD j NGP-TVD "/RST/S IL Log Log Run Scale Media No Interval Start Stop OH / CH Received 25 25 5 25 (data taken from Logs Portion of Master Well Data Maint) O FINAL 9600 11032 ch O FINAL 9526 11105 OH C C FINAL 8491 9006 OH FINAL 800 11017 CH FINAL 9300 11133 OH C 3/21/2000 2/2/2001 6/1/2000 6/1/2000 2/2/2001 1/3/2001 6/1/2000 5/12~2000 3/21/2000 Dataset Number Comments 09517'~ '/~' 9300-11133 BL, Sepia 09559 ,//' 9526-11107 j. 09967 9600-11032 10300 -'/' 9477-9776 UIC 5112/2000 09612 ''// 9450-11020 Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis Received? Daily History Received? Formation Tops Receuived? /N Comments: TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE · Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ' Joey Burton/Jerry Morgan ProActive Diagnostic Services, Inc. 310 K Street Suite 200 Anchorage, AK 99501 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM COLOR Open Hole I 1 1 N-O8ai 01-10-01 Res. Eval. CH I I 1 Mech. CH 1 Caliper Survey Signed · Print Name: Date · RECEI'VED Oil & Cons. CommissJor, ProActive Diagnostic Services, Phone:(907) 245-8951 Fax:(907) 245-8952 Inc., 310 K Street Suite 200, Anchorage, AK 99501 E-mail: pdsanchorage~memorylog, com Website: ,, ",.. '.,.: !~'--' ~ ~.','.~ ~:,.. H "L L LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Robert Richey ProActive Diagnostic Services, Inc. 310 K Street Suite 200 Anchorage, AK 99501 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LoG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM COLOR Open Hole I I 1 Res. EYai. CH I I 1 N-8 Mech. CH 1 Caliper Survey Signed' Print Name: .... -' 2001 A~as~a Oil & Gas Cons. Commissior; Anchorage 31o [ street suite 200, Anchorage, A[ 9950~ WebsJte: www. mcmon4o~.com ProActive Diagnostic Services, Phone:(907) 245-895 ! Fax:(907) 245-8952 Inc., E-maih pdsanchorage~memorylog.com WELL LOG TRANSMYITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 ~o° ' MWD Formation Evaluation Logs' N-08A, May 30, 2000 AK-MW-90264 N-08A: 2" x 5" MD Gamma Ray Logs' 50,029-20143-01 2" x 5" TVD Gamma Ray Logs' 50-029-20143-01 1 Blueline 1 Rolled Sepia l Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED DatSUN 01 t000 Alaska Oil & Gas Go'ns. Commission Anchorage BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton comDanv Cl R I L_I_ I N r'; c; E IR~./I CIE c; WELL LOG TRANSMITTAL To.' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs N-08A, AK-MW-90264 May30,2000 1 LDWG formatted Disc with verification listing. API#: 50-029-20143-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF TilE.TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: fun Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVED Date: JUN 0 1 2 000 Alaska Oil & Gas Cons. Commission Anchorago 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 a Halliburton company Scbhanberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 120 Company: Field: Alaska Oil & Gas Cons Corem Afln: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date Blueline Sepia Color CD Prints B-12A PROD PROFILE PSP)DEFT/GHOST 000506 1 1 D-21 PROD PROFILE 000507 1 1 G-13 PROD PROFILE 000501 1 1 Wo30 PRODUCTION LOG 000503 1 1 H-36A ~ O~fo ~ 20188 UCNL 000421 i 1 1 N-08A /.4 ~ C-..~ O~01 ~ 20187 RST 000421 1 1 1 , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 5/10/00 BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED 12 Alaska 0il & 6as Bo'ns. Commissto~ Anchorage Schlumberger GeoQuest 3940 Arctic BIvd, Suite 300 Anchorage, AKfi¢,~503-5711 AT[N: Sherr,~~ , /. STATE OF ALASKA ALASKA'OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water & Gas Injector 2. Name of Operator 17. Permit Number BP Exploration (Alaska) Inc. 200-009 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 . ~.?~~ 50- 029-20143-01 4. Location of well at surface ~ I .~'~'~;,..~,...,~.~ 19. Unit or Lease Name 3161' SNL, 4711' WEL, SEC. 08, T11N, R13E, UM .?~! :.~p¢~.~.~ Prudhoe Bay Unit At top of productive interval ',~.~ ~/~..~O i: ..~ !. 3458'SNL'2541'WEL'SEC'07'T11N'R13E'UM ' ~ ' !At total depth N-08Ai 2251' SNL, 2558' WEL, SEC. 07, T11N, R13E, UM 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 61.52' AMSL ADL 028282 12. Date Spudded3,11,2000 ! 13' Date T'D' Reached 114' Date c°mp'' Susp'' °r Aband'3,14,2000 3,16,2000 115' Water depth' if °"sh°reN/A MSL 116' N°' °, C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey1 20. Depth where SSSV setI 21. Thickness of Permafrost 11139 9101 FTI 11072 9037 FTI []Yes I-lEoI (Nipple) 2051'MDI 1900'(Approx.) 22. Type Electric or Other Logs Run MWD, GR, ReP, Memory DIL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 100' 24" 210 sx Permafrost 13-3/8" 72# N-80 Surface 2600' 18-1/2" 3800 sx Permafrost II 10-3/4"x9-5/8"55.5# / 47# N-80 Surface 2106' Tieback ~ / Top 3 Uts 11-3/4'x9-5/8' Thermocase II 9-5/8" 47# N-80 2106' 9255' 12-1/4" 900 SX Howcolite~ 200 sx Class 'G' 7" 29# N-80 8781' 9567' 8-1/2" 300 sx Class 'G' 2-7/8" 6.16# L-80 9244' 11139' 3-3/4" 113 sx Class 'G' 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" Gun Diameter, 4 spf 7", 26#, N-80 8779' MD TVD MD TVD 11000' - 11050' 8971' - 9016' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 50 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 20, 2000 Injection 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 GAS-MCF WATER'BBL OIL GRAVITY'API (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. R. :_CEI ED Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 9553' 8516' Shublik %' 9589' 8549' Shublik 'B' 9649' 8598' Shublik 'C' 9680' 8619' Ivishak / Zone 4B 9708' 8634' Zone 4A 10040' 8725' APR 20 ~31. List of AEachments: Summa~ of Daily Drilling Repo~s, Su~eys 32. I hereby ce~i~ that the foregoing is trueand correct to the best of my knowledge Signed TerrieHubb,e~~ ~ Title TechnicalAsoistantl,l Date N-08Ai 200-009 Prepared By Name/Number: 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 log 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. ITEU 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 Well: N-08A Accept: 03/11/00 Field: Prudhoe Bay Spud: 03/11/00 APl: 50-029-20143-01 Release: 03/16/00 Permit: 200-009 CTD Unit: Nordic #1 03/12/00 1 Accept Nordic Rig #1 on N-08ai at 13:00 hrs, 3-11-00. Cut off corroded bolts on tree cap. N/U BOP stack. Test BOPE. Fax test forms to AOGCC. M/U MWD drilling BHA #1 and RIH. Orient Tool face. Drill build section from 9574 - 9732 ft. Drilling in top of Zone 4. 03/13/00 :2 Drill build section in Zone 4 to 9,755 ft. POOH for smaller bend motor. M/U Bit #2 and 1.1 deg motor. RIH with MWD BHA #2. Correct CTD at flag. RIH to TD. Drill build section from 9,755 - 9,900 ft. Short trip to window. Hole in good condition. Drill build section from 9,900 - 10,050 ft. Short trip to window. Hole in good condition. Drilled build section from 10,050 - 10,120 ft. Landed well at 10,120 ft CTD at 8,733 ft TVDSS. Drilled inverted section from 10,120 - 10,195 ft. Short trip to window. Hole in good condition. Drilled inverted from 10,195 - 10,310 ft. Short trip to window. Drilled inverted hole from 10,310 - 10,460 ft. Short trip to window. Tied-in with BHCS/GR, Added 7 ft to CTD. RIH to TD. Hole in good condition. Drilled inverted from 10,460- 10,520 ft. Drilled final drop section of hole from 10,520 - 10,610 ft. Lost 1.0 BPM returns at 10,610 ft CTD [8686' TVDSS]. Short trip to window. RIH to TD. Drilled from 10,610 - 10,680 ft with losses of 1.2 BPM. Ordered materials for 25 BBLS Form-A-Set LCM pill from MI. Short trip to 7" liner. Circulate across top while waiting for LCM. 03/14~OO 3 Circ at min rate while mixing Form-a-Set plug. Safety meeting. RIH and displace pill to coil. RIH to 10660' and displace pill to bit. Close choke and establish injection rate 1 bpm at 150-200 psi back pressure. Squeeze 15 bbl pill to formation at 1 bpm - max back pressure 375 psi. POH laying in remaining 10 bbl at 1:1. Pull up above window and circ at min rate while waiting on pill to set up. RIH. Started losing returns below 10610' - 2.4/2.0. Drill ahead to 10700'. Getting poor wt transfer & trying to pack off. POH to window to clean up hole and move residual LCM pill up into liner. Tied-in with BHCS/GR, Added 7 ft to CTD. RIH and drill to 10,850 ft. Top of Zone 3 at 10,837 ft. Short trip to window. Hole in good condition. Mud losses of 0.2 BPM. Drilled in Zone 3 from 10,850 - 10,924 ft. POOH for new bit to finish Zone 3. RIH with MWD BHA #3 with 1.1 deg motor and DPI Bit #3. 03/15/00 4 RIH with MWD BHA #3. Correct CTD to flag at 9300 ft. RIH to TD. Drill Zone 3 from 10,924 - 10,960 ft.. Many stalls drilling conglomerate. Drill Zone 2 from 10,960 - 11080 ft. Short trip to window. Held Safety Stand down with day and night crews. Log Tie-in with BHCS/GR, added 12 ft to CTD. RIH to TD. Drill to final TD at 11135' at 9035' TVD. POOH for logs. LD drilling BHA. MU logging BHA. RIH with PDS memory GR/Induction. Log down from 9300' at 30'/min. APR 20 2.000 AJ~ka 0i~ & G~s C,:::~, s. C0~'r~mis~i0n ~cho~age N-08A, Coil Tubing Drilling Page 2 03/16/00 5 Log down with PDS Memory DIL/GR. Tag TD. Log up with DIL/GR to 9300 ft. POOH. Lay out logging BHA. Safety Meeting. Prepare rig floor to run 2 7/8" liner. Conduct BPX Noise Level audit on rig. MU 62 jts of 2 7/8" liner. M/U Baker CTLRT and CTC. RIH with liner on CT to corrected TD of 11139'. Release from liner. Displace FIo Pro mud to 2% KCI water losing 0.5 bpm. DS cementers load CT with 23 bbls 15.8 ppg Class G cement with latex. Load wiper dart and displace with 2% KCI water to latch collar. Unsting from liner. Jet TOL and POOH. LD CTLRT. MU 2.25" jet nozzle on 32 stands CSH workstring. RIH on CT to PBD at 11072' while jetting liner clean. Displace liner to Lithium Hypochlorite water. POOH for perf guns. 03/17/00 6 POOH with liner cleanout BHA. Standback CSH workstring. Held Safety Meeting. Pressure tested 2 7/8" Liner Lap with 2,200 psi. Good Test. RIH with SWS 2" Power Jet perforating, loaded at 4 SPF. Tag PBTD of 11,072 ft BKB. Pumped 8 BBL Lithium Hypochlorite. Drop 5/8" steel ball and displace with 2% KCL water. Position bottom perforating charge at 11,050 ft. Ball on seat at 56.4 bbls. Fired guns, saw a 2 bbl drop in pit level. POOH. Standback CSH workstring. Safety Meeting. Lay out SWS perforating guns. All shots fired. Perforated Interval: 11000' - 11050', 2" Power Jet, 4 spf, 60 Deg. Phasing. RIH and freeze protect 7" tubing to 2000' with MEOH. Blow down CT with Nitrogen. ND BOPE. NU tree cap and test. Rig released at 2200 hrs 3/16/00 (5 days 9 hrs). APR 20 2000 A!aska 0ii & Gas C~:~s. C0t~missiol~ Ancho~'~e North Slope Alaska Alaska State Plane 4 PBU_ WOA N Pad N-O8A Surveyed: 14 March, 2000 SURVEY REPORT 23 March, 2000 Your Ref: API-500292014301 Surface Coordinates: 5968023.00 N, 634414.00 E (70° 19' 14.0835" N, 148° 54' 36.9234" W) Kelly Bushing: 61.52ft above Mean Sea Level APR 20 ~000 §RILLINI~ Sl~ RVI r"E S SurveyRef:svy9702 A HALLIBURTON CO~PANY Sperry-Sun Drilling Services Survey Report for N-O8A · Your Ref: API-500292014301 Surveyed: 14 March, 2000 North Slope Alaska Measured Depth (ft) Incl. 9500.00 9564.00 9584.32 9598.09 9630.76 9648.37 9681.24 9707.77 9732.12 9760.89 9791.39 9832.46 9859.56 9893.32 9934.42 9963.42 10004.49 10057.21 10081.21 10111.99 10150.96 10189.06 10223.84 10253.67 10286.81 20.649 20.970 25.420 28.820 37.880 43.550 53.610 60.030 68.820 75.060 73.480 72.330 72.770 73.120 72.690 76.870 79.870 82.270 85.080 88.940 95.010 100.460 101.690 103.090 101.960 Azim. 314.987 318.850 320.900 321.890 323.550 324.20O 332.380 327.280 327.110 329.570 335.020 341.170 343.630 349.260 354.530 349,980 351,250 355.940 352.070 350.840 351,370 349.080 353.650 356.460 359.330 Sub-Sea Depth (ft) 8466.22 8526.04 8544.72 8556.97 8584.23 8597.58 8619.31 8633.83 8644,33 8653.25 8661.52 8673.61 8681,73 8691.64 8703.73 8711.35 8719.63 8727.81 8730.46 8732.06 8730.72 8725,60 8718.91 8712.51 8705.32 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 8527.74 8587.56 8606.24 8618.49 8645.75 8659.10 8680.83 8695.35 8705.85 8714.77 8723.04 8735.13 8743.25 8753.16 8765.25 8772.87 8781.15 8789.33 8791.98 8793.58 8792.24 8787.12 8780.43 8774.03 8766.84 388.19 S 3043.29W 371.59 S 3058.81W 365.46 S 3063.96W 360.56 S 3067.87W 346.26 S 3078.71W 336.99 S 3085.48W 316.01S 3098.28W 296.85 S 3109.46W 278.40 S 3121,35W 255.13 S 3135.69W 229.15 S 3149.34 W 192.76 S 3163.98 W 168.11 S 3171.79 W 136.75 S 3179.35 W 97.88 S 3184,89 W 70.17 S 3188.67W 30.48 S 3195.23W 21.25 N 3201.03W 44.97 N 3203.52W 75.36 N 3208.09W 113.82 N 3214.11W 151.01N 3220.51W 184.75 N 3225.64W 213.77 N 3228.15W 246.09 N 3229.34W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5967580.37 N 631378.15 E 5967596.69 N 631362.33 E 5967602.73 N 631357.08 E 5967607.56 N 631353.08 E 5967621.66 N 631341.98 E 5967630,81 N 631335.05 E 5967651.56 N 631321.87 E 5967670.52 N 631310.35 E 5967688.74 N 631298.14 E 5967711.76 N 631283.38 E 5967737.49 N 631269.27 E 5967773,61 N 631253.98 E 5967798.11 N 631245.72 E 5967829.33 N 631237.60 E 5967868.10 N 631231.37 E 5967895.74 N 631227.10 E 5967935.30 N 631219.83 E 5967986,93 N 631213.10 E 5968010,60 N 631210.19 E 5968040.90 N 631205.08 E 5968079.25 N 631198.37 E 5968116.31 N 631191.30 E 5968149.95 N 631185.57 E 5968178.92 N 631182.54 E 5968211,22 N 631180.77 E R; CE!VED APR 20 2000 2.202 22.254 24.907 27.870 32.287 35.801 29.048 36.104 23.161 17.962 14.583 8.811 15.976 12.300 20.900 7.907 9.897 19.847 13.160 15.635 15.494 13.371 10.328 9.116 Alaska State Plane 4 PBU_WOA N Pad Vertical Section (ft) Comment 37.53 56.12 62.90 68.30 83.96 94.09 116.64 137.16 157.07 182.11 209.73 247.81 273.29 305.40 344.67 372.64 412.84 464.89 488.72 519.45 558.37 596.09 630.21 659.30 691.48 Tie-on Survey Window Point MWD Magnetic Continued... 23 March, 2000 - 8:35 -2- DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for N-O8A Your Ref: API-500292014301 Surveyed: 14 March, 2000 North Slope Alaska Measured Depth (ft) Incl. 1 o327 ,o6 10394.06 10426.46 10479.56 10512.56 10546.06 10581.06 10613,34 10648.41 10675.24 107t2.29 10744.29 10777.49 10814.01 10847.89 10883.39 10910.16 10938.24 10972.66 11002,79 11044.31 11075.74 11113.46 11135.00 99.440 98.700 97.470 94.310 90.610 86.480 80.940 77.520 73.480 69.960 66.010 61.790 57.660 52.910 48.430 43.000 39.640 36.470 32,610 28.560 22,670 20.130 14.590 14.590 Azim. 4.230 10,350 10.880 15.800 13.870 11.410 15.000 11.410 9.470 8.940 9.470 9.650 7.190 6.480 4.200 2,340 359.980 0.680 5,080 5.430 5.960 6.840 5.600 5.600 Sub-Sea Depth (ft) 8697.84 8687.27 8682.72 8677.26 8675.85 8676.70 8680.53 8686.57 8695.35 8703.76 8717.65 8731.72 8748.46 8769.25 8790.72 8815.50 8835.60 8857.71 8886.06 8911.99 8949.42 8978.68 9014.66 9035.51 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 8759.36 8748.79 8744.24 8738.78 8737.37 8738.22 8742.05 8748.09 8756.87 8765,28 8779,17 8793.24 8809.98 8830.77 8852.24 8877.O2 8897.12 8919,23 8947.58 8973.51 9010.94 9040.20 9076.18 9097.03 285.61N 3228.10W 351.20 N 3219.71W 382.73 N 3213.80W 434.10 N 3201.61W 465.97 N 3193.17W 498.63 N 3185.84W 532.48 N 3177.91W 563.35 N 3170.66W 596.73 N 3164.50W 621.87 N 3160.43W 655.77 N 3154.94W 684,10 N 3150.17W 712.45 N 3145.96W 742,25 N 3142,38W 768.33 N 3139.92W 793.69 N 3138.46W 811.36 N 3138.09W 828.66 N 3137.99W 848.14 N 3137.05W 863.40 N 3135.65W 881.26 N 3133.87W 892.66 N 3132.60W 903.84 N 3131.36W 909.24 N 3130.83W Alaska State Plane 4 PBU_WOA N Pad Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/lOOft) Vertical Section (ft) Comment 5968250.75 N 631181.30 E 13.501 5968316.49 N 631188.52 E 9.087 5968348.12 N 631193.86 E 4.127 5968399.70 N 631205.13 E 10.970 5968431.71N 631213.00 E 12.643 5968464.50 N 631219.74 E 14.348 5968498.49 N 631227.07 E 18.826 5968529,48 N 631233.76 E 15.218 5968562.96 N 631239.32 E 12.703 5968588.17 N 631242,94 E 13.253 5968622.17 N 631247.83 E 10.743 5968650.58 N 631252.09 E 13.197 5968679.00 N 631255.79 E 13.988 5968708.86 N 631258.83 E 13.104 5968734.98 N 631260.82 E 14.209 5968760.36 N 631261.83 E 15.748 5968778.03 N 631261.89 E 13.834 5968795.34 N 631261.67 E 11.393 5968814.83 N 631262.27 E 13.347 5968830.11N 631263.39 E 13.455 5968848,00 N 631264.85 E 14.197 5968859,41 N 631265.92 E 8.146 5968870.62 N 631266.95 E 14.719 5968876.02 N 631267.38 E 0.000 RECEIVED 730.44 794.24 824.64 873.83 904.21 935.55 967.97 997.53 1029.74 1054.07 1086.88 1114.28 1141.77 1170.79 1196.28 1221.19 1238.63 1255.76 1274.92 1289.84 1307.27 1318.38 1329.28 1334,56 Projected Survey APR 2.0 2000, Continued... 23 March, 2000 - 8:35 DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for N-O8A Your Ref: API-500292014301 Surveyed: 14 March, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA N Pad All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 27.057° (10-Mar-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 352.030° (True). Based upon Minimum Curvature type calculations,' at a Measured Depth of 11135.00ft., The Bottom Hole Displacement is 3260.19ft., in the Direction of 286.194° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9500.00 8527.74 388.19 S 3043.29 W Tie-on Survey 9564.00 8587.56 371.59 S 3058.81 W Window Point 11135.00 9097.03 909,24 N 3130.83 W Projected Survey APR 2_0 2000 A~sska Oil & Gas Oo~s. Commissi~ Continued... 23 March, 2000 - 8:35 - 4 - DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for N-O8A Your Ref: AP1-$00292014301 Surveyed: 14 March, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA N Pad Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 9564.00 8587.56 To Measured Depth (ft) 9564.00 11135.00 Vertical Depth (ft) 8587.56 9097.03 Survey Tool Description AK-1 BP_HG MWD Magnetic 23 March, 2000 - 8:35 - 5 - DrillQuest 1.05.04e B.P. E×p o,ration (True) Structure : Pod N Field : Prudhoe Boy Well : N-08AI, 50-029-20143-01 Location : North Slope, Alaska West (feet) Created by potn;$ Dote plotteo : 5-Apr-2000 Plot Reft,once ia N-O&AL Coordinates ere in lee~ ra~erence N-08, 8rij Potn;s 267-6613 --- 8okar Huohlt INT[O --- 6200 5000 4800 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 [ I I I I I I I I I I I I I I I I I I I I I I I I I I I [ I I I I 8300 8400 8500 8600 8700 8800 8900 gooo 9100 Projected to TD J N-08^I Coae203b Plon L~ RL(,E :,, ..... IVED I .-o., co...o.~.,o. APR 20 2000 Projected to TDJ~,k,,J~ Oil & Gas C0nsr ~r~J'~ i i i i i -f-- I i - i t f i i t i i i' i--T"~ i i i i *~ i i i -- i i t i i i i I i i--'1-~"~-- i 1----~ 100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1~00 1500 1600 1700 1800 1900 2Q00 VerticalSection(feet)-> Azimuth 351.00 with reference 388.25 S, 3043.31 W from N-08 1400 1200 1OO0 8O0 60O 400 Z 200 0 -4- 2O0 400 6OO 8OO B.P. Exploration (True) Pad N N-08AI N-08 Prudhoe Bay North Slope, Alaska suRvEY LISTING by Baker Hughes INTEQ Your ref : N-08AI Our ref : svy320 License : 50-029-20143-01 Date printed : 3-Apr-2000 Date created : 3-Apr-2000 Last revised : 3-Apr-2000 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 633890.846,5965894.587,999.00000,N Slot location is n70 19 14.083,w148 54 36.923 Slot Grid coordinates are N 5968022.970, E 634414.000 Slot local coordinates are 2118.88 N 561.07 E Projection type: alaska- Zone 4, Spheroid: Clarke- 1866 Reference North is True North APR 20 2000 Oi~ & Gas Co~s. Commis~:,, AnchomcJe B.P. Exploration (True) Pad N,N-08AI Prudhoe Bay,North Slope, Alaska Measured Inclin Azimuth Subsea R E C T A N G Depth Degrees Degrees Depth C O O R D I N 9500.00 20.65 314.99 8466.20 388.25S 9564.00 20.97 318.85 8526.03 371.65S 9584.32 25.42 320.90 8544.70 365.52S 9598.09 28.82 321.89 8556.96 360.62S 9630.76 37.88 323.55 8584.22 346.32S 9648.37 43.55 324.20 8597.56 337.05S 9681.24 53.61 332.38 8619.30 316.07S 9707.77 60.03 327.28 8633.82 296.91S 9732.12 68.82 327.11 8644.32 278.46S 9760.89 75.06 329.57 8653.23 255.19S 9791.39 73.48 335.02 8661.51 229.21S 9832.46 72.33 341.17 8673.59 192.82S 9859.56 72.77 343.63 8681.72 168.18S 9893.32 73.12 349.26 8691.63 136.81S 9934.42 72.69 354.53 8703.72 97.94S 9963.42 76.87 349.98 8711.33 70.23S 10004.49 79.87 351.25 8719.61 30.54S 10057.21 82.27 355.94 8727.80 21.19N 10081.21 85.08 352.07 8730.44 44.91N 10111.99 88.94 350.84 8732.05 75.30N 10150.96 95.01 351.37 8730.71 113.76N 10189.06 100.46 349.08 8725.58 150.95N 10223.84 101.69 353.65 8718.90 184.69N 10253.67 103.09 356.46 8712.49 213.71N 10286.81 101.96 359.33 8705.31 246.03N 10327.06 99.44 4.23 8697.83 285.55N 10394.06 98.70 10.35 8687.26 351.14N 10426.46 97.47 10.88 8682.70 382.67N 10479.56 94.31 15.80 8677.25 434.04N 10512.56 90.61 13.87 8675.83 465.90N 10546.06 86.48 11.41 8676.68 498.57N 10581.06 80.94 15.00 8680.52 532.42N 10613.34 77.52 11.41 8686.55 563.29N 10648.41 73.48 9.47 8695.33 596.67N 10675.24 69.96 8.94 8703.74 621.81N SURVEY LISTING Page 1 Your ref : N-08AI Last revised : 3-Apr-2000 U L A R Dogleg Vert G R I D C O O R D S A T E S Deg/100ft Sect Easting Northing' 3043.31W 3.04 0.00 631378.34 5967580.55 3058.83W 2.20 18.83 631362.53 5967596.87 3063.97W 22.25 25.68 631357.28 5967602.90 3067.89W 24.91 31.14 631353.28 5967607.74 3078.73W 27.87 46.95 631342.18 5967621.83 3085.49W 32.29 57.17 631335.25 5967630.99 3098.30W 35.80 79.90 631322.08 5967651.73 3109.47W 29.05 100.57 631310.56 5967670.69 3121.36W 36.10 120.64 631298.35 5967688.91 3135.70W 23.16 145.88 631283.60 5967711.93 3149.35W 17.96 173.67 631269.49 5967737.65 3163.99W 14.58 211.91 631254.20 5967773.78 3171.81W 8.81 237.47 631245.95 5967798.28 3179.37W 15.98 269.63 631237.83 5967829.50 3184.91W 12.30 308.89 631231.60 5967868.26 3188.69W 20.90 336.85 631227.33 5967895.90 3195.24W 7.91 377.07 631220.06 5967935.46 3201.04W 9.90 429.08 631213.34 5967987.08 3203.54W 19.85 452.89 631210.43 5968010.75 3208.10W 13.16 483.62 631205.32 5968041.05 3214.12W 15.64 522.55 631198.61 5968079.39 3220.53W 15.49 560.29 631191.55 5968116.46 3225.65W 13.37 594.41 631185.82 5968150.09 3228.16W 10.33 623.47 631182.79 5968179.07 3229.35W 9.12 655.58 631181.03 5968211.36 3228.12W 13.50 694.41 631181.56 5968250.89 3219.72W 9.09 757.89 631188.79 5968316.62 3213.81W 4.13 788.10 631194.13 5968348.24 3201.62W 10.97 836.93 631205.40 5968399.82 3193.19W 12.64 867.09 631213.27 5968431.83 3185.86W 14.35 898.20 631220.01 5968464.62 3177.92W 18.83 930.40 631227.34 5968498.60 3170.67W 15.22 959.75 631234.04 5968529.58 3164.52W 12.70 991.75 631239.60 5968563.07 3160.44W 13.25 1015.95 631243.22 5968588.28 10712.29 66.01 9.47 8717.63 655.71N 3154.95W 10.74 1048.57 631248.11 5968622.27 10744.29 61.79 9.65 8731.71 684.04N 3150.18W 13.20 1075.81 631252.37 5968650.68 10777.49 57.66 7.19 8748.44 712.39N 3145.97W 13.99 1103.15 631256.08 5968679.10 10814.01 52.91 6.48 8769.23 742.19N 3142.39W 13.10 1132.02 631259.12 5968708.95 10847.89 48.43 4.20 8790.70 768.27N 3139.94W 14.21 1157.40 631261.11 5968735.07 10883.39 43.00 2.34 8815.48 793.63N 3138.47W 15.75 1182.22 631262.13 5968760.45 10910.16 39.64 359.98 8835.58 811.30N 3138.10W 13.83 1199.61 631262.18 5968778.12 10938.24 36.47 0.68 8857.69 828.60N 3138.01W 11.39 1216.69 631261.97 5968795.42 10972.66 32.61 5.08 8886.04 848.08N 3137.06W 13.35 1235.78 631262.56 5968814.91 11002.79 28.56 5.43 8911.98 863.34N 3135.66W 13.45 i250.63 631263.69 5968830.20 11044.31 22.67 5.96 8949.40 881.20N 3133.89W 14.20 1267.99 631265.15 5968848.08 11075.74 20.13 6.84 8978.66 892.59N 3132.62W 8.15 1279.05 631266.21 5968859.49 11113.46 14.59 5.60 9014.65 903.78N 3131.38W 14.72 1289.90 631267.25 5968870.69 11135.00 14.59 5.60 9035.49 909.18N 3130.85W 0.00 1295.15 631267.69 5968876.10 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from N-08 and SSTVD from RKB - MSL = 61.52 ft. Bottom hole distance is 3260.19 on azimuth 286.19 degrees from wellhead. Vertical section is from tie at S 388.25 W 3043.31 on azimuth 351.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed usingthe Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad N,N-08AI Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : N-08AI Last revised : 3-Apr-2000 MD SSTVD Rectangular Coords. 9500.00 8466.20 388.25S 3043.31W 11135.00 9035.49 909.18N 3130.85W Comments in wellpath Comment Tie-in Point Projected to TD NO Targets associated with this wellpath RkCEiVED APR 20 2000' Alaska Oil & Gas Cons. Commission Anchorage . ,._..,, STATE OF ALASKA ALASI~ 3IL AND GAS CONSERVATION CO, fISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepeni [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of'Operator ...... 5. Datum Elevation (DF or KB) 10. Field" and Pool BP Exploration (Alaska) Inc. KBE = 61.52' AMSL Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028282 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3161' SNL, 4711' WEL, SEC. 08, T11 N, R13E, UM Prudhoe Bay Unit ........ At top of productive interval 8. Well Number Number 2S100302630-277 3587' SNL, 2548' WEL, SEC. 07, T11N, R13E, UM N-08Ai At total depth 9. Approximate spud date Amount $200,000.00 2390' SNL, 2697' WEL, SEC. 07, T11 N, R13E, UM 02/16/00 12'.'"'[~istance to nearest properbj line113. Distan'~e to nearest well 14. Number of acres in property 15. PropOsed depth (MD and TVD) ' ADL 028260, 2217' MDI No Close Approach 2560 11105' MD / 8977' TVDss ,, 16. TO be completed fo~ deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9560' MD Maximum Hole Angle 98° Maximum surface 2234 psig, At total depth (TVD) 8800' / 3290 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Q, uantit¥ of Cement Hole Casing Weight ....... Grade COupling Length MD TVD MD TVD (include stage data) .... 3-3/4" 2-7/8" 6.16# L-80 ST-L 1840' 9265' 8262' 11105' 8977' 104 cuft Class 'G' 19. TO be completed'"i~'; Redrill,Re-entry, and Deepen Operations. ! ! E ..................... ~ :~...~ Present well condition summary Total depth: measured 10040 feet Plugs (measured) EZ Drill Bridge Plug at 10017' (9/96) true vertical 9053 feet Effective depth: measured 10017 feet Junk (measured) ,,,:::::,}:r~ 0ii & Gas Cons. Col~li', true vertical 9031 feet Anchorage Casing Length Size Cemented MD TVD Structural Conductor 100' 20" 210 sx Permafrost 100' 100' Surface 2600'. 13-3/8" 3800 sx Permafrost II 2600' 2600' Intermediate 7149' 9-5/8" 900 sx Howcolite, 200 sx Class 'G' 2106' - 9255' 2106' - 8314' Production Liner 1257' 7" 300 sx Class 'G' 8781' - 10038' 7862' - 9051' 9-5/8" Tieback to Surface 2106' 10-3/4" x 9-5/8" ( w/top 3 Jts 11-3/4" x 9-5/8" Thermocase) 2106' 2106' Perforation depth: measured. 9686'-9978' (five intervals) true vertical 8719' - 8994' (five intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Skeich [] 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 Hubble, 564-4628 Signed Ted Stagg Title CT Drilling Engineer Date Commission Use Only Permit Number I APl Number Approval Date I See cover letter ~--C.~) '-' (:::~::~r 50-029-20143-01 ~,~--~ ~/~ '" t~)(:~ for other requirements Conditions of Approval: Samples Required .[] Y/es ,~_No Mud Log Required [] Yes J~No Hydrogen Sulfide Measures .]~'Y'es [] No Directional Survey Required '~Yes 'l-"l'No Required Working Pressure fo~ BIDPE I-'12K; [-I 3K; [] 4K; 1-15K; I"110K;' I'-I 15K Other: ORIGINAL SIGNED' BY by order of Approved By Robert N. Christenson Commissioner the commission Date (--~--/O ---'~ Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX N-08ai Sidetrack Summary of Operations: N-08 is being sidetracked to improve injection conformance. Zone 4B is the targeted injection interval. This sidetrack will be conducted in two phases. Phase 1: Set Whipstock, squeeze perfs, Mill Window: Planned for week of Feb. 14, 2000. · A Mechanical Integrity Test was successfully performed on 1/26/00. · The whipstock drift and Kinley caliper were run on 12/9/99.. · A Schmoo-B-Gone treatment was pumped on 11/30/99.. · E-Line will be used to set the mechanical whipstock at 9,565'. · Service coil will cement squeeze existing perfs & mill the window. Phase 2: Drill & Complete sidetrack: Planned for Feb. 21, 2000. Directional drilling coiled tubing equipment will be rigged up to drill and complete the directional hole as per attached plan to planned TD of 11,105' MD (8,977' TVDss). Mud Program: RECEIVED · Phase 1' Seawater · Phase 2: Seawater and FIo-Pro (8.7-8.8 ppg) 0 t 2.000 Disposal: AJaskli 011 & Gas Cons. Commission · No annular injection on this well. Altch0rage · 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 liner will be run from TD to approx. 9,265' MD and cemented with approx. 18.5 bbls. cement to bring cement 200 fi above the window. The liner will be pressure tested to 2200 psi and perforated with coiled tubing conveyed guns. 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 · A Gamma Ray log will be run over all of the open hole section. · Open hole will be logged with Memory Induction log. · No Cement Evaluation Log is planned on the 2 7/8" liner as 7" liner cement quality above the planned window is excellent and will not be compromised by the sidetrack. Hazards Five small faults will be crossed with this sidetrack but all faults are small and lost circulation is not expected. Reservoir Pressure Res. pressure is 3290 @ 8800ss. Max. surface pressure with gas (0.12 psi/fi) to surface is 2234 psi. TREE: 6" ClW WELLHEAD: McEVOY ACTUATOR: OTIS 11-3/4" x 9-5/8" Thermocase Il I 1481 10-3/4" 55.5#/ft N-80 Seal-Lock Casin¢ 9-5/8" x 10-3/4" X- ow. I ,o ol 9-5/8" FCC [ 2,513 13-3/8" 72#/ft N-a0 I 2,600 BTRS N-08ai Proposed Complett~on KB. ELEV = 61.52' BF. ELEV = 41.86' 7" SSSV LANDING NIPPLE (OTIS"RQ") I 2,051 (5.962" ID w/o INSERT) (3.813" ID w/ INSERT) KOP: 2800' MAX ANGLE: 50°/6100' 7", 26 #/ft, N-80, AB TC-4S TUBING ID: 6.276" CAPACITY: 0.0382 BBL/FT Top of 7" Liner ] 8,739I 9-5/8", 47#/ft, [ 9,2551 N-80, BTRS Top of whipstock approx 9565' MD. Abandonment Cement to be downsquezed past whipstock PERFORATION SUMMARY REF. LOG: SWS - BHCS - 8-19-74 TIE IN LOG: Size SPF Interval Open/Sqzed 4" 4 9,686- 9,760 Open 7-22-85 4" 4 9,772- 9,830 Open 7-22-85 4" 4 9,868 - 9,898 Open 6-18-78 4" 8 9,914- 9,944 Open 5-17-77 4" 8 9,958 - 9,978 Open 5-17-77 I 0,017 7", 29 #/~, N-80, BTRS 110,038 TOP OF SEAL ASSY. I 8,747 BOTTOM OF SEAL ASSY. I 8,788 2 7/8" liner cemented to approx. 200 ft above window 7" WD PACKER ! 9,840 (OTIS)( 4.000"ID )I ' 4 1/2 ....XN" NIPPLE 0] (OTIS) (3.725" ID) I 9,85 Note: Plug set "XN" 1 9/19/96 J · N-08 Vertical Section 8500 8550 8600 8650 8700 8750 880O 885O 8900 8950 9000 5OO I Path Distance (Feet) 1,000 1,500 2,000 I I I Angle @ K.O.= 21 deg MD:9560 ,, , TgAC N-08a Case 103a 11/24/99 2,500 3,000 I I 8,700 .................................................... WD Pkr. J 8979ss J .~- 22 deg. Tot Drld: 1545 ft 11105 TD Marker Depths ~:~), ri~l Wellbore TSAG TSHU TSAD/8652 J 8,7501 J 8,531 Jft TVD 8,566Jfi.TVD 8,652 iff. TVD 8,750Jfi. TVD Kick Off J 8,539 Jft TVD 9,560Jft MD Deprtr @KO 3,097 fi' 9,56oj 1545I 11,105J 8,977J MD KO Pt MD New Hole Total MD TVD TD RECEIVED Alas_ka Oil & Gas Cons. ~imisslon DLS deq/100 Tool Face Length Curve 1 6 0 ~0 Curve 2 30 13 184 Curve 3 10 90 220 Curve 4 10 20 230 Curve 5 10 90 295 Curve 6 16 - 145 588 1,547 Drawn: 1/26/2000 11:07 Plan Name: Case 103a -4,000 N-08 N-08a Case 103a 11/24/99 700 I -3,500 -3,000 X distance from Sfc Loc 1,500 1,000 500 -500 -2,500 JWell Name N-08 I CLOSURE JDistance 3,358 ft Az 282 de~l NEW HOLE E/W (X) N/S (Y) Kick Off -3,036 -532 TD -3,282i 7 ! 3 State Plane 631,132 5.968.736 Surface Loc 634,414 5.968,023 DLS de~/100 Tool Face Lenc. lth Curve 1 " 6 0 ~0 Curve 2 30 13 184 i Curve 3 10 90 220 Curve 4 10 20 230 Curve 5 10 90 295 Curve 6 16 - 145 588 1,547 RECEIVED 01 A~aska Oil & Gas Cons. Commission Anchorage Drawn: 1/26/2000 11:07 Plan Name: Case 103a 12" 36" uJ '"r" _z 22.5" 2 3/8" CT ~'11 Pack-Off 7 1/16" Annular 7 1/16' 5000 psi Blind/Shear 71/16" Pipe/Slip 7 1/16" x 5,000 N-08ai CT Drilling & Completion BOP 2 3/8" 18" 38" 1/16" x 5,000 psi' Slips 71/16" Pipe 7 1/16" x 5,000 psi SWAB OR MASTER VALVE RECEIVED O A~aska 0ii & Cas Cons. Commies/on Ancho~e DATE H '1 5995:3 :t :::, ,' :t o ,' CHECK NO. O0159953 DATE INVOICE ! CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 120999 'CK 120999F 1 OO. OO 1 OO. OO HANDL]NO INST: S/H TERR! HUBBLE X4&::;'EI : '..., ",. ~'.:i:::',. ':.?,1 & Gas Col'G. 00[1 .mission T.,: ^'.^C.,:. C.,:C~ ,S ,..^.,.,:.T FO. rm.s .,:~.,.,:. ^.ov,:. ~ 100. OO :t 00, 00 PAY To'. ':Th,e 'DR:DER .' :. . , ', . ,, ~::,~!! 'ii ':i:i': i,~I': .... ?,,' ':/:'i;I::I' 'i:'.,.:i ":i::i:::::!:!''?~ DATE :ALASKA O IL AND :?OAS :~ :':,:~:~: ,:::,,,! ,:. ::!:!:: :ii:!::, NO~Fi':VALID AFTER ~20 flAYS ,::. ,::,,:' ~:::.,: :.~. .... ,: ,,.,, ~..,.:: , .... :..:'::, ',..~.: ,'I, 5qq53"' ':Oh~aO~,aqS~: OOP. hh WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ (---//(/~'), _ _/-~'~--'-~"%__ INIT CLASS ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name 'and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... DATE ENGINEERING ~/.-,M'/,~i GEOL AREA )N 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 ~t.~ 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 ................. dev __ redrll v" serv / wellbore seg ann. disposal para req __ ON/OFF SHORE ~_..~ YNl Y N,~ ~ N 'MN N Y N ~,~-~'~..~ N N N GEOLOGY A.~ DATE / J---~" 30. Permit can be issued w/o hydrogen sulfide measures. 31. Data presented on potential overpressure zones .... ' .' .',,~ Y N 32. Seismic analysis of shallow gas zones ............ ~ Y N 33. "f-/',~ Seabed condition survey (if off-shore) ............ - . /Y~ N 34. Contact name/phone for weekly progress reports [exploratory only](~) N ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause ddlling 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 GEOL%J;~ ENGINEERING: U.[C/Annular COMMISSION: RF'C_,/'~ ~ BEW / WM-'"'""'"",,~ DWJ SF,~~ JDH .-~,,~_ -"" RNC co Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 09/27/99) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ .. No 'special'effort has been made to chronologically organize this category of information. .o Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu May 25 12:50:18 2000 Reel Header Service name ............. LISTPE Date ..................... 00/05/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/05/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit 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 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING MWD RUN 1 AK-MW-90264 B. JAHN M_ASKELL, WHI N-08A 500292014301 BP Exploration (Alaska), Inc. Sperry Sun 25-FLAY-00 MWD RUN 2 AK-MW-90264 B. JAHN NLASKELL, WHI 8 liN 13E 3161 MWD RUN 3 AK-MW-90264 S. LATZ NLASKELL, WHI 4711 61.52 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 9564.0 3.750 3.750 RECEIVED JUN O l 000 Alaska Oil & Gas Cons. Commission Anchorage ~EMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 - 3 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC GR LOG OF 04/21/00 (SWS) . PEAK TO PEAK CORRELATION BETWEEN MWD AND PDC GR DISCONTINUED BELOW 10899.5 DUE TO FORMATION BEING ACTIVATED. KICKOFF POINT FOR THIS WELLBORE IS AT 9564' MD, 8526' SSTVD (TOP OF WHIPSTOCK). 4. MWD RUNS 1 - 3 REPRESENT WELL N-08A WITH API 50-029-20143-01. THIS WELL REACHED A TOTAL DEPTH OF ll135'MD, 9035' SSTVD. SGRD = SMOOTHED GAMMA RAY SROP = SMOOTHED RATE OF PENETRATION $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/25 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 9526.5 11107.5 ROP 9557.0 11138.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9526 5 9548 9549 9554 9558 9582 9589 9592 9596 9604 9606 9624 9630 9637 9645 9648 GR 9526 5 9548 0 9549 5 9555 0 9559 0 9583 5 9591 5 9595 0 9599 0 9606 5 9609 5 9627 0 9633 5 9640 0 9647 5 9650 5 EQUIVALENT UNSHIFTED DEPTH 9658 9669 9672 9678 9702 9714 9715 9719 9721 9722 9772 9776 9786 9801 9811 9824 9852 9891 9919 9935 9961 9985 10008 10013 10022 10033 10060 10088 10097 10100 10106 10107 10127 10131 10149 10159 10170 10203 10244 10262 10269 10290 10300 10305 10318 10340 10355 10434 10440 10443 10447 10453 10460 10508 10528 10574 10579 10599 10602 10620 10623 10635 10650 10658 10670 10683 10691 10703 5 5 0 0 0 5 5 0 5 5 5 0 5 5 5 0 5 5 5 0 0 0 0 0 5 5 5 0 0 0 5 5 0 0 0 5 5 0 0 5 0 0 5 0 .0 0 5 0 0 5 5 5 5 5 5 0 .5 5 0 5 0 0 0 5 0 5 0 5 9660 9672 9673 9679 9704 9716 9718 9722 9723 9725 9772 9777 9786 9802 9812 9825 9856 9894 9923 9938 9964 9989 10012 10019 10027 10037 10065 10093 10100 10104 10111 10112 10131 10135 10151 10163 10174 10207 10247 10266 10274 10292 10303 10308 10321 10342 10358 10438 10444 10447 10450 10455 10464 10511 10530 10576 10582 10600 10603 10622 10625 10636 10652 10659 10671 10684 10693 10705 10710 10718 10722 10729 10732 10737 10742 10753 10767 10773 10782 10793 10798 10802 10804 10807 10810 10812 10826 10830 10839 10847 10856 10859 10869 10894 10902 11138 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: 10711 0 10721 5 10725 5 10730 5 10733 0 10739 5 10744 5 10755 0 10769 5 10775 5 10783 5 10795 0 10798 5 10802 5 10804 5 10807 5 10810 5 10812 5 10827 5 10831 5 10836 0 10845 0 10854 0 10857 0 10866 0 10890 0 10899 5 11135 0 BIT RUN NO MERGE TOP MERGE BASE 1 9526.5 9755.0 2 9755.0 10923.0 3 10923.0 11135.0 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 ...................... -999.25 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 MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9526.5 11138 10332.3 3224 ROP MWD FT/H 0.02 387.82 82.204 3163 GR MWD API 16.66 1340.3 54.167 3163 First Reading 9526.5 9557 9526.5 Last Reading 11138 11138 11107.5 First Reading For Entire File .......... 9526.5 Last Reading For Entire File ........... 11138 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/25 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 SGRD 9526.5 ROP 9558.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9725.0 9755.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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) : 12 -MAR- 00 Insite 7.74 Memory 9755.0 25.4 68.8 TOOL NUMBER 003 3 .750 Flo Pro 8.70 65.0 8.5 29000 7.2 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .000 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 .0 120.6 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 9526.5 9755 9640.75 458 ROP MWD010 FT/H 1.81 387.82 73.8441 395 GR MWD010 API 38.62 1340.3 187.152 398 First Reading 9526.5 9558 9526.5 Last Reading 9755 9755 9725 First Reading For Entire File .......... 9526.5 Last Reading For Entire File ........... 9755 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9725.5 10892.5 ROP 9755.5 10923.0 $ LOG HEADER DATA DATE LOGGED: 14-MAR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWATHOLE SOFTWARE VERSION: 7.74 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 10923.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 43.0 MAXIMUM ANGLE: 103.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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 NUMBER 003 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): 3.750 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 Flo Pro 8.60 65.0 8.5 24500 4.6 .000 .000 .000 .000 .0 124.8 .0 .0 Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 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 MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9725.5 10923 10324.3 2396 ROP MWD020 FT/H 0.02 222.12 95.1052 2336 GR MWD020 API 17.62 176.99 35.7447 2335 First Reading 9725.5 9755.5 9725.5 Last Reading 10923 10923 10892.5 First Reading For Entire File .......... 9725.5 Last Reading For Entire File ........... 10923 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10893.0 11104.5 ROP 10923.5 11135.0 $ LOG HEADER DATA DATE LOGGED: 15-MAR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 11135.0 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 NGP NATURAL GAMMA PROBE $ 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 14.6 36.5 TOOL NUMBER 002 3.750 Flo Pro 8.65 65.0 9.8 24500 5.0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 .0 137.5 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 10893 11135 11014 485 ROP MWD030 FT/H 0.64 129.29 18.4808 424 GR MWD030 API 16.66 114.83 26.7709 424 First Reading 10893 10923.5 10893 Last Reading 11135 11135 11104.5 First Reading For Entire File .......... 10893 Last Reading For Entire File ........... 11135 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/05/25 Origin ................... STS Tape Name ................. UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 00/05/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File