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Home My WebLink About201-132MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, March 20, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC M-38A PRUDHOE BAY UNIT M-38A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/20/2025 M-38A 50-029-22519-01-00 201-132-0 W SPT 8453 2011320 2113 1662 1664 1660 1661 176 437 441 440 4YRTST P Sully Sullivan 2/11/2025 no issues 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 M-38A Inspection Date: Tubing OA Packer Depth 20 2423 2323 2310IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250211125141 BBL Pumped:2.2 BBL Returned:2.1 Thursday, March 20, 2025 Page 1 of 1 9 9 9 9 9 9 999 999 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.03.20 14:52:38 -08'00' New Plugback Esets 7/18/2024 Well Name API Number PTD Number ESet Number Date 09-44A PB1 50-029-22087-70-00 209-157 T39240 6-11-2010 15-27A PB1 50-029-22243-70-00 210-023 T39241 8-11-2010 17-09A PB1 50-029-20617-70-00 209-160 T39242 5-10-2010 18-10C PB1 50-029-20818-72-00 210-112 T39243 1-10-2011 G-30C PB1 50-029-21613-70-00 209-151 T39244 7-26-2010 K-10C PB1 50-029-21762-73-00 210-128 T39245 8-24-2011 M-17AL1 PB1 50-029-20627-70-00 211-086 T39246 3-30-2012 M-38A PB1 50-029-22519-70-00 201-132 T39247 2-22-2006 S-106 PB1 50-029-22999-70-00 201-012 T39248 2-22-2006 Z-113 PB1 50-029-23450-70-00 211-084 T39249 12-1-2011 M-38A PB1 50-029-22519-70-00 201-132 T39247 2-22-2006 MEMORANDUM TO: JintRegg R14?"(7(zrzi P.I. Supervisor "`� I FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska .Alaska Oil and Gas Conservation Commission DATE: Monday, March 15, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC M -38A PRUDHOE BAY UNIT M -38A Src: Inspector Reviewed By: P.I.Supry JS Comm Well Name PRUDHOE BAY UNIT M -38A API Well Number 50-029-22519-01-00 Inspector Name: Bob Noble Permit Number: 201-132-0 Inspection Date: 2713/2021" Insp Num: mitRCN2I0214163058 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well M -38A _Type _ — Inj G -''TVD 8453 - Tubing 2821 - 2823 - — 7 'I 2817 - 2817 " 2814 2807 " PTD 2011320 Type Test SPT "Test psi 1 2113 - IA 1 32 2319 - 2274- 2276 - 2286 - - 2285- BBL Pumped: 1.7 - BBL Returned: 2 A 267 O 532. 550 - 558 565 _ 569 Interval 4YRTST P/F I P ✓ Notes: Monday, March 15, 2021 - Page 1 of 1 STATE OF ALASKA Reviewed By - OIL OIL AND GAS CONSERVATION COMMISSION P.1. Suprv�P�_!6' 0 BOPE Test Report for: MILNE PT UNIT L-OIA i Comm Contractor/Rig No.: Doyon 14 Operator: Hilcorp Alaska, LLC Type Operation: WRKOV Sundry No: Type Test: [NIT 1 321-072 - PTD#: 2030640' DATE: 2/25/2021 " Inspector Guy Cook Operator Rep: S. Sutherland Rig Rep: F. Carlo Test Pressures: Rams: Annular: Valves: MASP: 250/4000 - 250/2500 - 250/4000' 3220 Insp Source Inspector Inspection No: bopGDC210225055741 Related Insp No: FLOOR SAFTY VALVES: Quantity TEST DATA Upper Kelly 1_ - _P - MISC. INSPECTIONS: _ _ 1____ MUD SYSTEM: Ball Type ACCUMULATOR SYSTEM: P - Inside BOP P/F P_• Visual Alarm 0 Time/Pressure P/F Location Gen.: P Trip Tank P P System Pressure 3100 P Housekeeping: P Pit Level Indicators P P Pressure After Closure — 1600__ P PTD On Location P Flow Indicator P P 200 PSI Attained 37 P " Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 191 _P Well Sign P H2S Gas Detector P P Blind Switch Covers: All StationsP Drl. Rig P MS Misc NA NA Nitgn. Bottles (avg): _ 6 @ 2079 - P Hazard Sec. P ACC Misc _ 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: Quantity Size P/F Stripper Quantity P/F Upper Kelly 1_ - _P - Lower Kelly _ _ 1____ P Ball Type 1 P - Inside BOP I _ P_• FSV Misc 0 NA BOP STACK: Quantity Size P/F Stripper —0—INA Annular Preventer _ 1 - 13 5/8" 5000 " P 41 Rams _1 - 2 7/8 x 5 VBR P " #2 Rams 1 - Blinds P. - #3 Rams 1 2 7/8" x 5" V" P . #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 - 3 1/8" 5000 P_ HCR Valves 2 - 3 1/8" 5000 F Kill Line Valves 2 -3 1/8" 5000 _ P ' Check Valve 0 NA BOP Misc 0 NA CHOKE MANIFOLD: Quantity P/F No. Valves 14 _ P" Manual Chokes 1'— P- Hydraulic Chokes 1 P " CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Number of Failures: 1 - Test Results Test Time 8 Remarks: 2 7/811 test joint used for testing. A couple of test fitting leaks and one test that the valves were improperly lined up. The HCR choke failed and was serviced. The retest was also a fail and the valve is to be than ed out and tested. I did not stay onsite for the c ange o t ou e va ve and its testing. Company rep. Sloan Sut er and made the decision to test the rams and valves to 4000 psi high. MEMORANDUM TO: Jim Regg '7 P.LSupervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, February 19, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC M -38A PRUDHOE BAY UNIT M38A Src: Inspector Reviewed By: P.I. Supry J bl--- Comm Well Name PRUDHOE BAY UNIT M -38A API Well Number 50-029-22519-01-00 Inspector Name: Bob Noble Permit Number: 201-132-0 Inspection Date: 2/14/2021 ' Insp Num: mitRCN21 oz 14163058 Rel Insp Num: Well M -38A Packer 'Type Inj U -'TVD Depth 8453 Tubing Pretest 2821 Initial 2823 - 15 Min 2811 30 Min 2817 45 Min 2814 - 60 Min 2807 . PTD 2011320 Type Test SPT Test psi, 2113 IA 32 2319 - 2274 - 2276 2286 - 2285 - BBL Pumped: Interval 1 7 - BBL Returned: 4YRTS7.... P/F 2 P OA 267 532. 550 558 - 565. 569 - Notes: Friday, February 19, 2021 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,February 27,2017 Jim Regg P.I.Supervisor } SUBJECT: Mechanical Integrity Tests k BP EXPLORATION(ALASKA)INC. M-38A FROM: Chuck Scheve y 1� PRUDHOE BAY UNIT M-38A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry' ga. NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT M-38A API Well Number 50-029-22519-01-00 Inspector Name: Chuck Scheve Permit Number: 201-132-0 Inspection Date: 2/21/2017 Insp Num: mitCS170221151020 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well M-38A Type Inj w TVD 8453.E Tubing 565 570 568 574 PTD 2011320 Type Test SPT Test psi 2113 IA 45 2347 2305 2292 BBL Pumped: 2 BBL Returned: 2 OA 184 428 426 481 Interval 4YRTST P/F P '/ Notes: SCANNED APR. 2 8 21117 Monday,February 27,2017 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, August 16, 2015 9:17 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale;AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Morrison, Spencer; Regg, James B (DOA) Subject: UNDER EVALUATION:Injector M-38A (PTD# 2011320) Possible Inner Annulus Communication All, Injector M-38A(PTD#2011320) is showing anomalous inner annulus pressure trends while on water injection. The well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Downhole Diagnostics: Perform MIT-IA 2. Wellhead: Obtain updated PPPOT-IC 3. Well Integrity Engineer: Additional diagnostics as needed Please call with any comments or concerns. Thank you, Whitney Pettus SCANNED AUG 2 4 2015 (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator Gt]Cjdnlat On WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital infonnation available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. d-~ / / 3¿r- Well History File # Digital Data Added to LaserFiche File CD's - # Yes No Yes No Yes No DVD's - # Diskettes - # Oversized Material Added to LaserFiche File Other # Yes No Yes No Yes No Maps # Mud Logs # General Notes or Conunents about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC - Librarian@admin.state.ak.us • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission SLR AUG 2 2012 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB M -Pad (4 3 R Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad M that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) M -pad Date: 04/14/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal M -01 1690780 50029200420000 Sealed NA NA NA NA NA M -03A 2011470 50029201020100 0.25 NA 0.25 NA 0.85 6/3/2009 M -04 1710230 50029201050000 0 NA 0 NA NA 4/14/2012 M-05A 1970810 50029201940100 0.5 NA 0.5 NA 2.6 6/3/2009 M -06A 1930930 50029203670100 0.25 NA 0.25 NA 0.85 6/3/2009 M -07 1790370 50029203730000 0.25 NA 0.25 NA 0.85 6/3/2009 M -08 1800860 50029204990000 1.75 NA 1.75 NA 10.2 6/24/2009 M -09B 2022200 50029205630200 6.25 NA 6.25 NA 44.2 6/3/2009 M -10 1810290 50029205670000 0.25 NA 0.25 NA 2.6 6/4/2009 M -11 1810570 50029205890000 0.25 NA 0.25 NA 1.7 6/4/2009 M -12A 2001510 50029205930100 0.25 NA 0.25 NA 1.7 6/4/2009 M -13A 2011650 50029205220100 2.75 NA 2.75 NA 17 6/4/2009 M -14 1801090 50029205120000 1 NA 1 NA 5.1 6/4/2009 M -15 1810850 50029206120000 6.75 NA 6.75 NA 55.3 6/4/2009 M -16 1810860 50029206130000 0.25 NA 0.25 NA 1.7 6/4/2009 M -17A 2000320 50029206280100 0.5 NA 0.5 NA 2.6 6/3/2009 M -18B 1930540 50029208550200 10 NA 10 NA 73.1 6/24/2009 M -19B 2081980 50029208970200 Sealed NA NA NA NA 4/13/2012 M -20A 1971990 50029209120100 8 NA 8 NA 52.7 6/24/2009 M -21A 1930750 50029209230100 0.5 NA 0.5 NA 3.4 6/24/2009 M -22 1830540 50029209360000 16 NA 16 NA 117.3 6/23/2009 M -23 1830550 50029209370000 0.25 NA 0.25 NA 1.7 6/4/2009 M -24A 2011260 50029209390100 0.25 NA 0.25 NA 0.85 6/24/2009 M -25 1860650 50029215700000 8 NA 8 NA 55.3 6/3/2009 M -26A 1920280 50029220040100 2.75 NA 2.75 NA 18.7 6/3/2009 M -27A 1930860 50029219920100 0.25 NA 0.25 NA 2.6 6/24/2009 M -28 1860740 50029215780000 1 NA 1 NA 4.3 6/3/2009 M -29A 2000990 50029219040100 1 NA 1 NA 4.3 6/3/2009 M -30 1920300 50029222550000 0.5 NA 0.5 NA 3.4 6/3/2009 M -31 1920320 50029222560000 0.5 NA 0.5 NA 3.4 6/4/2009 M -32 1920330 50029222570000 0.25 NA 0.25 NA 0.85 6/4/2009 M -33 1941160 50029225040000 20 NA 20 NA 133.45 6/24/2009 M -34 1941330 50029225140000 6.25 NA 6.25 NA 25.5 6/3/2009 --j M -38A 2011320 _50029225190100 21.3 NA 21.3 NA 210.8 11/26/2009 Page 1 of 1 • Maunder, Thomas E (DOA) From: Reem, David C [ReemDC@BP.com] Sent: Monday, January 26, 2009 1:00 PM To: Maunder, Thomas E (DOA) Subject: RE: M-38A (201-132) see below ~~~~ _~~4 ~~~ ~ ~aa From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, January 26, 2009 9:51 AM To: Reem, David C Subject: M-38A (201-132) Dave, I have reviewed the 404 for the recently completed workover on this well and noted the following: -- It is stated in the plan and through emails with Dave Bjork that the BOP would not be equipped with rams sized for the 5-1/2" liner since there would be a tested plug in the hole and KW fluid. -- The tailpipe plug was tested (MIT-T) to 1000 psi when it was set on 10/14. After the tubing is cut a pressure test is attempted (11/14) immediately prior to the rig arriving which fails (.4 bpm). This is not surprising since the well has a known production casing leak. -- When the BOP is NU, it is equipped with 3-1/2" x 6" rams however these are changed out as planned to 2-7/8" x 5". -- As the tubing is pulled, a fluid loss of 8 bph is noted. There are no further comments regarding fluid loss although it is likely they still existed since it was possible to squeeze cement into the casing leak. What bearing do fluid losses have on the validity of a KW fluid barrier? Losses do not reduce the validity of a KW fluid barrier as long as the fluid level constantly remains at surface and the brine remains homogeneous. With the small leak to the Cretaceous in this well, keeping the hole full with 9.8 ppg brine was operationally "easy" to do, thus maintaining a solid column of KW brine at all times. It appears that with the original ram set that both the liner and DP could have been covered. Tom, you are correct. The optimal time to have changed from the 3-112'° x 6'° VBRs to the 2-718" x 5" VBRs would have been AFTER we had run and cemented the 5-112" scab liner. The smaller VBRs would`ve covered the 2-718" x 3-1/2" drillout pipe sizes and the 4-112" x 3-112" completion that was run in the well. look forward to your comments. Tom Maunder, PE AOGCC 1 /26/2009 1. Operations Performed:. ~~ChOra„Q ^ Abandon ®Repair Well . ^ Plug Perforations ^ Stimulate ^ Re-Enter Susp nded Well ®Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 201-132 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22519-01-00 7. KB Elevation (ft): 56 1' 9. Well Name and Number: . PBU M-38Ai 8. Property Designation: 10. Field /Pool(s): ADL 028282 » Prudhoe Bay Field / Prudhoe Bay Pool » 11. Present well condition summary Total depth: measured 10270' ° feet true vertical 8726' » feet Plugs (measured) None Effective depth: measured 10235' feet Junk (measured) None true vertical 8720' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 110' 110' 1490 470 Surface 3110' 10-3/4" 3110' 3036' 5210 2480 Intermediate 8858' 7-5/8" 8858' 8571' 8180 5120 Production Liner 1572' 3-3/16" x 2-718" 8698' - 10270' 8413' - 8726' Scab Liner 4759' 5-1/2" 3851' - 8618' 3741' - 8334' 7740 6280 Perforation Depth MD (ft): 9968' - 10206' Perforation Depth TVD (ft): 8693' - 8715' 3-1/2" x 4-1/2", 9.2# x 12.6# L-80 8784' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 5-1/2" x 3-1/2" Baker SABL-3 Packer, 7-5/8" x 4-1/2" TIW 8472' -* 'HBBP' packer 8738' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut and pull tubing from 8606'. Run 5-1/2" (17#, L-80) scab liner from 3851' to 8618'. Cement w/ 120 bbls Class'G' (674 cu ft / 581 sx . Clean out and run new tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ®Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ^ Oil ^ Gas ®WAG ^ GINJ ^ WINJ ^ 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 David Biork, 564-5683 308-363 Printed Name David Reem Title Engineering Team Leader Prepared By Name/Number. S nature Phone 564-5743 Date o~"~~ Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 STATE OF ALASKA AL•CA OIL AND GAS CONSERVATION COf•6SION REPORT OF SUNDRY WELL OPERATIONS '~. ,iAN ~ ~ 1D~~ RECEIifE~ DEG 3 ~, x .~ Submit Original Only ~~ ~ TREE = 4-1 /6" CMJ WELLHEAD = 13-5/8" 5M FMC ACTUATOR= BAKER KB. ELEV...- _.56.5'. BF. ELEV _ 26.0' KOP = _ 1676' Max Angle - 98 @ 9188" Dat Dat um MD _ __ um TVD = 8800' SS 10-3/4" CSG, 45.5#, NT-80-LHE, ID = 9.953" 3110' 5-1/2" SCAB LNR, 17#, L-80, BTGM, ID=4.892"~ 3-~ 851'-8E 4-1/2" TUBING STUB (11/22/08) 8606' 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 8623' Minimum ID = 2.372" @ 8904' 3-3/16" X 2-7/8" LNR XO 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-r 8783' I TOP OF WHIPSTOCK RA TAG ~-{ $$65' 1945' I-j 3-1/2" HES 9Cr X-Nip, ID=2.813 3851' 7-5/8" x 5-1/2" ZXPand Flexlock Hanger 8452' - -I3-1/2" HES 9Cr X-Nip, ID=2.813 8472' 5-1/2" x 3-1/2" BKRSABL-3 PKR, ID=2.78°' 8496' 3-1f2" RHC PLUG {1212048) 8496' 3-1/2" HES 9Cr X-Nip, ID = 2.813' 8579' 3-1/2" HES 9Cr XN-Nip, ID=2.75 8591' 5-1 /2" x 4-1 /2" XO, ID = 3.958" 8603' 7-5/8" x 4-1/2" UNIQUE OVERSHOT, ID = 3.958" 8677' 4-1/2" OTIS X NIP, ID = 3.813" 8698' 4-1/2" BKR KB LNR TOP PKR, ID = 2.56" 8703' TOP OF BKR LOCATOR SUB, ID = 2.39" 8705' 3.75" BKR DEPLOY SLV, ID = 3.00" 8711' 3-1/2" BKR FL4S 3" PUP, ID = 2.88" 8714' 3-1/2" X 3-3/16" LNRXO, ID = 2.80" 8738' 7-5/8" X 4-1/2" TIW HBBP PKR, iD = 3.901" 8772' 4-1/2" OTIS X NIP, ID = 3.813" 8784' 4-1/2 WLEG 8783' ELMD TT LOGGED 01 /18/95 7-518" MILLOUT WINDOW (M-38Aj 8858' - 8863' 8902' 3-3/16" LNR, 6.2#, L-80 TC2, .0076 bpf, ID = 2.80" 8904' ~--~ 3-3116" x 2-7/8" LNR XO, ID = 2.372" ~ PERFORATION SUMMARY REF LOG: SPERRY-SUN MWD RESISTNtTY ON ANGLE AT TOP PERF: 87 @ 9968' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9968 - 9998 C 08/26/01 2" 6 10095 - 10132 C 08/26/01 2" 8 10175 - 10206 C 08/26/01 7-5/8" CSG, 29.7#, NT-95-HS, ID = 6.875" PBTD -j 10235' ~~ ~' \ 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.372" DATE REV BY COMMENTS DATE REV BY COMMENTS 11/17/94 KSB ORIGINAL COMPLETION 08/26/01 CTD SIDETRACK 12/02/08 N4ES RWO 12/26/08 /TLH RHC PLUG / PKR RESTRICTION PRUDHOE BAY UNff WELL: M-38A PERMfr No: 2011320 API No: 50-029-22519-01 SEC 1, T11 N, R12E, 2437' FSL & 605' FEL BP f=xploration (Alaska) BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: WORKOVER Start: 11/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/2/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task 'Code'. NPT .Phase Description of Operations _. _ - 11/15/2008 11:00 - 18:00 7.00 MOB X RREP PRE Held a 2.5 hr safety stand down with all hands. Reviewed 18:00 - 00:00 6.00 MOB X RREP PRE ,11/16/2008 ~ 00:00 - 06:00 ~ 6.00 ~ MOB ~ X ~ RREP ~ PRE 06:00 - 14:00 8.00 MOB X RREP PRE 14:00 - 18:00 4.00 MOB X RREP PRE 18:00 - 00:00 6.00 MOB X RREP PRE 11/17/2008 00:00 - 06:00 6.00 MOB X RREP PRE 06:00 - 18:00 12.00 MOB X RREP PRE 18:00 - 00:00 6.00 MOB X RREP PRE 11/18/2008 00:00 - 06:00 6.00 MOB X RREP PRE 06:00 - 18:00 12.00 MOB X RREP PRE 18:00 - 00:00 6.00 MOB X RREP PRE 11/19/2008 00:00 - 06:00 6.00 MOB X RREP PRE 06:00 - 10:30 4.50 MOB X RREP PRE 10:30 - 12:00 1.50 MOB X RREP PRE 12:00 - 14:00 2.00 MOB X RREP PRE 14:00 - 18:00 4.00 MOB X RREP PRE 18:00 - 21:00 3.00 MOB X RREP PRE 21:00 - 22:00 1.00 MOB X RREP PRE 22:00 - 23:00 1.00 MOB X RREP PRE 23:00 - 00:00 1.00 MOB P PRE latest incidents at 4-ES and 3-ES. Reviewed and edited the Man-Rider Procedure with input from all hands. Discussed hand safety interventions. Divided crew and rig leadership into three teams and performed a full rig hazard hunt. Convened meeting with all crew to compile lists of identified hazards for handover to Nabors management. Con't with the safety stand down. Split the crew into 3 teams, auditing entire rig for hazards and unsafe conditions. Correcting deficits whereever possible, recording all observations and corrections. Con't with the safety stand down. Split the crew into 3 teams, auditing entire rig for hazards and unsafe conditions. Correcting deficits where ever possible, recording all observations and corrections. Pre-tour meeting with day crew and crew Crew reviewing and editing work procedures. Crew making repairs on and correcting issues identified during hazard hunt. Line gaurd being designed and attached to manrider winch. pre-tour meeting and crew change. Continue making repairs and correcting issues identified during hazard hunt. Continue making repairs and correcting issues identified during hazard hunt. Pre-tour meeting & crew change. Continue making repairs and correcting issues identified during hazard hunt. Pre-tour meeting & crew change. Continue making repairs and correcting issues identified during hazard hunt. Continue making repairs and correcting issues identified during hazard hunt. Pre-tour meeting and crew change. Continue making repairs and correcting issues identified during hazard hunt. Pre-tour meeting and crew change. Continue making repairs and correcting issues identified during hazard hunt. Continue making repairs and correcting issues identified during hazard hunt. Pre-tour meeting and crew change. Continue making repairs and correcting issues identified during hazard hunt. Rig leadership meeting to discuss Nabors safe work and maintenance plan forward. Meeting with day crew to roll out Nabors safe work plan and maintenance forward and walk around rig to observe current repairs made by crews. Continue making repairs and correcting issues identified during hazard hunt. Crew change and continue making repairs and correcting issues identified during hazard hunt. gave AOGCC -Chuck Sheve - 24 hrs. notice of upcoming BOPE test. Rig leadership meeting to discuss Nabors safe work and maintenance plan forward. Meeting with night crew to roll out Nabors safe work plan and maintenance forward. PJSM with rig crew to scope down derrick. Printed: 12/18/2008 1:24:39 PM • BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: WORKOVER Start: 11/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/2/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code', NPT ' Phase 11/20/2008 00:00 - 03:00 3.00 MOB P PRE 03:00 - 06:30 3.50 MOB P PRE 06:30 - 13:00 6.50 MOB P PRE 13:00 - 18:00 5.00 RIGU P PRE 18:00 - 19:00 19:00 - 20:00 20:00 - 21:00 21:00 - 23:00 23:00 - 00:00 11 /21 /2008 100:00 - 00:30 00:30 - 02:00 02:00 - 03:00 03:00 - 04:30 1.00 RIGU P PRE 1.00 RIGU P PRE 1.00 RIGU P PRE Description of Operations Lay over derrick and secure rig for move. Hold Prejob with Peak for rig move and move rig from E-33 to M-38 Move rig components from E pad to M Pad. Spot sub over well. Spot pipe shed and pits. Raise and scope derrick, hook up electrical, steam, water, and mudlines between modules. Set stairs and walk ways. Pre tour checks, service rig. RIG ACCEPTED ~ 19:00-HRS,. Install secondary annulus valve, spot tiger tank, take on 110 degree 9.8 ppg brine into pits. Rig up DSM lubricator and test to 500 psi for 10 minutes (good tubing and IA on vac, OA at 150 psi. 2.00 RIGU P PRE Rig up circulating lines for killing well, run return line to tiger tank. 1.00 RIGU P PRE Hold PJSM with all personell involved. Pressure test return line to 250 psi, pressure test circulating lines to 3500 psi (good tests). 0.50 WHSUR P CLEAN Pumped 5.5 Barrels before returns. Pumped ~ 3 BPM 400 psi. Pumped 24 bbls before clean returns. 1.50 WHSUR P CLEAN Swap over and circulate down tubing @ 4.5 BPM 680 psi. Pumped a total of 155 bbls to tiger tank. Returns are 9.7+ fluid back and take returns to pits. OA reached 900 psi and bled off to tiger tank. I nsc rate at 24 BPH while circulating. Total losses while circulating was 50 bbls. 1.00 KILL P DECOMP Monitor well. IA and Tubing on vacuum. Level sub structure. 1.50 WHSUR P DECOMP FMC set TWC and test from below to 1000 psi by pumping 1/2 04:30 - 08:00 08:00 - 12:00 12:00 - 20:30 3.50 WHSUR P DECOMP R/D circulating lines. Hold PJSM with crew for N/D tree and adapter. Crew change. Check PVT's, daily derrick inspection and grease drawworks and blocks. Environmental walkaround. Install pressure gauge on IA and 2" line from pits that are filled with 9.8 kill wt. fluid. M/U 4 1/2" NSCT X-O to TIW valve and place in cellar. Dress bolts for BOPE nipple up. Open swab valve and monitor for leaks - no leaks. OAP = 0-psi and IAP = 0-psi. N/D tree and adapter. No leaks from TWC or tubin han er seals. Inspect tubing hanger lift threads and found three gouges and XO would not makeup correctly. Ordered out single grapple ITCO spear w/packoff from Baker Fishing. 4.00 BOPSU P DECOMP PJSM -Crew reviewed nippling up BOPE procedure with crew. Nippled up BOPE per procedure using Sweeney wrench to torque stud bolts to prescribed values. Motor man energized Koomey unit as soon as BOP stack set on tubing spool flange. PJSM -Crew reviewed changing out BOP ram blocks. Monitored TWC and tubing hanger seals for leaks -none noted. Crew removed 3-1/2" x 6" VBR blocks and installed 2-7/8" x 5" VBR blocks. Called AOGCC with 2.0-hrs. notice prior to starting BOPE testing per Chuck Sheve's request and direction that if we did not hear back from them within 2.0-hrs., we are cleared to proceed with testing and to consider AOGCC witnessing of the BOPE test to be waived. 8.50 BOPSU P DECOMP Pressure test BOP~er BP/AOGCC requirements - 250-psi Printed: 12/18/2008 1:24:39 PM • • BP EXPLORATION Page 3 of 10 Operations. Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To 11 /21 /2008 12:00 - 20:30 20:30 - 21:30 M-38 M-38A WORKOVER NABOBS ALASKA DRILLING NABOBS 4ES Hours Task Code j NPT I i 8.501 BOPSURP 1.001 WHSURIP Spud Date: 7/19/2001 Start: 11 /20/2008 End: I Rig Release: 12/2/2008 Rig Number: Phase Description of Operations DECOMP Lo/4000-psi hi for 2-7/8" x 5" VBR's, choke manifold, manual and HCR choke valves, manual and HCR kill valves, TIW floor valve, DP dart valve, upper and lower kelly cock valves. Tested VBR's with 2-7/8" and 4-1/2" test joints. Tested annular preventer to 250-psi Lo/3500-psi Hi with 2-7/8" test joint. Performed Koomey test. Chuck Sheve - AOGCC -waived states right to witness testing. No failures of any components or systems during ROPE testing. DECOMP PJSM - Make u lubricator and extension and close annular pryventer. P/T lubricator to 500 psi (good test). Pull TWC and R/D lubricator and extension. Filled hole with 19 bbls. to obtain returns. 21:30 - 22:00 0.50 PULL P DECOMP BHA #1 to s ear han er as follows: Bullnose, spear packoff assembly, "C" Dlm. Tubing spear, LBS. Ttl. length = 15.61'. 22:00 - 23:30 1.50 PULL P DECOMP Engaged spear into hanger and opened OA. No pressure, Back out LDS and pulled hanger. Hanger moved at 92k. 105K upweight to hoist hanger to floor. L/D spear BHA and tubin hanger. 23:30 - 00:00 0.50 PULL P DECOMP R/U circulating equipment and CBU at 90-spm 310 psi. 11/22/2008 00:00 - 00:30 0.50 CLEAN P DECOMP Continue CBU C~ 90-SPM @ 310 psi. Losses while CBU were 00:30 - 01:00 0.50 PULL P DECOMP Monitor well for 30-minutes and confirm dead and stable. 01:00 - 08:00 7.00 PULL P DECOMP POOH laying down 4.5" L-80 NSCT tubing from cut ~ 8610' to pipe shed 1x1. Pumping across top of flow nipple with charge pump while POH to keep hole full. Losses = 8.0-BPH. 181 jts. out ~ 06:00-hrs. Recovered Tubing hanger, 2' x 4-1 2" 12.6#, L-80 NSCT Tubing Pup, 2 x 4-1/2" "X" Nipples, 2 x 10' 4-1/2" 12.6#, L-80 NSCT Tubing Pups, 206 full jts. of 4-1/2" 12.6#, L-80 NSCT Tubing and 1 jet cut jt. of 4-1/2" 12.6#, L-80 NSCT Tubing. Tubing was in good condition with no internal or external corrosion or scale deposition present. Also recovered Cut jt. length = 20.74'. Remainder of cut jt. length = 18.10'. Jet Cut flare O.D. = 5.05". Cut was perfectly circular in shape and was a clean cut with no hangnails. Photos e-mailed to RWO engineer and also copied to RWO well file on town server. 08:00 - 09:30 1.50 PULL P DECOMP Clear and clean rig floor. Rig down tubing handling tools. 09:30 - 11:00 1.50 FISH P DECOMP Rig up drill pipe and BHA handling tools. 11:00 - 11:30 0.50 FISH DECOMP PJSM -Review Making Up BHA Procedure and Running In Hole With Drillpipe Procedure. 11:30 - 13:00 1.50 FISH P DECOMP Make up BHA #2 (Tubing Dress-Off) as follows: 6-3/4" x 4-9/16" Dress-Off hoe, xtension x 3, Tubing Dress-Off Mill (length = 2.18'), Boot Basket, Double Pin Sub, 7-5/8" Scraper, Bit Sub, LBS, 6 x 4-3/4" Drill Collars & Pump Out Sub. Ttl. Length = 223.07'. 13:00 - 21:30 8.50 FISH P DECOMP RIH w/BHA #2 on 3-1/2" 15.5# drill pipe 1 x 1 from pipe shed. 118 jts. RIH at 17:00-hrs. Reciprocated scraper across liner hanger/packer setting dept at 3800' 4 times. Continue RIH. agge op o u mg stub 21' in on jt. #270 at 8605'. 21:30 - 22:30 1.00 FISH P DECOMP PJSM -lay down 1) jt. 3 1/2" DP and pick up 10' pup and kelly. Establish parameters up wt.=138k do wt.=125 rt wt.=133k. Dress off 4 1/2" tubing stub from 8605' to 8606'. Reengaged to ing stu times no pro ems. Printed: 12/18/2008 1:24:39 PM i C~ BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: WORKOVER Start: 11/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/2/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To I Hours Task 'Code NPT Phase Description of Operations 11/22/2008 22:30 - 23:00 0.50 FISH P DECOMP Stand back kelly and blow down. Rig up circulating lines to reverse circulate 23:00 - 00:00 1.00 FISH P DECOMP Reverse circulate C~ 4 bpm with 1100 psi. Pumped 40 bbl hi-vis sweep. 11/23/2008 00:00 - 01:00 1.00 FISH P DECOMP Continue reverse circulating well clean. Drop 2-3/16" dart and shear open pump out sub and drift drill pipe in preparation for liner cement job. 01:00 - 06:00 5.00 FISH P DECOMP POOH laying down 3-1/2" 15.5# DP to pipe shed 1x1. Perform flow check after 10 stands. (No flow) Continue POOH laying down 151 joints of 3-1/2" DP to pipe shed 1x1. Stand back 41 stands of 3-1/2" DP in derrick. Maintain full hole. 06:00 - 06:30 0.50 FISH P DECOMP Crew change. Perform daily derrick inspection, check PVT's, grease blocks and drawworks and environmental walkaround. 06:30 - 06:45 0.25 FISH P DECOMP PJSM -All crew reviewed laying Down BHA procedure. 06:45 - 09:30 2.75 FISH P DECOMP Monitor well for flow at last stand of DP in hole before procedding with laying down BHA. POH and lay down BHA #2 including 6 x 4-3/4" drill collars. Tubing Dress-Off Shoe and Dress-Off Mill have good clear wear marks indicating tubing stub is dressed properly. 09:30 - 10:30 1.00 FISH P DECOMP Clear & clean rig floor. 10:30 - 13:30 3.00 CASE P TIEB1 Finish loading, drifting and strapping 5-1/2" 17#, L-80 BTC-M pipe and liner shoe track in pipe shed. Rig up pipe handling tools to run scab liner. 13:30 - 14:00 0.50 CASE P TIE61 PJSM -All crew to review "Running Scab Liner" procedure. 14:00 - 00:00 10.00 CASE P TIE61 Make u 5-1/2" scab liner shoe track with 7-5/8" x 4-1/2" Unique machine Guided Overshot, ported sub, HES 5-1/2" float collar and Baker insert landing collar and RIH. Baker-Lok'd all connections below landing collar. Made up BTC-M connection to the mark. RIH with 5-1/2" 17#, L-80 BTC-M scab liner 1 x 1 from pipe shed. Made up all connections to the mark and used Bes-O-Life 2000 thread compound. Also filled pipe every 5 jts. while RIH. 11/24/2008 00:00 - 01:00 1.00 CASE P TIEBi Continue RIH with 5-1/2" scab liner. Made up BTC-M connection to the mark. RIH with 5-1/2" 17#, L-80 BTC-M scab liner 1 x 1 from pipe shed. Made up all connections to the mark and used Bes-O-Life 2000 thread compound. Also filled pipe every 5 jts. while RIH. Fluid losses = 45-Bbls. 115 joints ran. 01:00 - 01:30 0.50 CASE P TIEB1 Make up 7-5/8" x 5-1/2" Baker Flexlock II liner hanger and 7-5/8" x 5-1/2" Baker C-2 ZXP liner top packer with hydraulic setting tool. 01:30 - 02:00 0.50 CASE P TIEB1 Circulate liner volume @ 4 BPM with 260 psi. 02:00 - 05:00 3.00 CASE P TIEB1 PJSM RIH with 41 stands of 3-1/2" 15.5# DP from derrick. Filling each 5 stands. P/U wt. 135k slack off wt. 120k. P/U single of DP from shed and RIH 11' and tagged first set of shears. Sheared at 12k continue down to 20' in and second sheared at 12k run m o an no goe an reconfirmed. No indication when shoe went over stump. UD single and P/U 24' 3-1/2" pup. 05:00 - 06:00 1.00 CASE P TIEB1 Rig up cement head and circulate 100 degree brine ~ 3.0-bpm 300-psi for cement job. 06:00 - 06:30 0.50 CASE P TIEB1 Crew change. pre-tour meeting, check PVT's and daily derrick inspection. Grease blocks and drawworks and environmental Printed: 12/18/2008 7:L4:3y F'M BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: M-38 Common W Event Nam Contractor Rig Name: Date ell Name: e: Name: From - To M-38A WORKO NABOBS NABOBS Hours VER Start ALASKA DRILLING I Rig 4ES Rig Task !, Code'i NPT I Phase Spud Date: 7/19/2001 : 11/20/2008 End: Release: 12/2/2008 Number: Description of Operations 11/24/2008 06:00 - 06:30 0.50 CASE P TIE61 walkaround. Continue circulating 9.8-ppg brine at 3.0-bpm 300-psi to warm hole. 06:30 - 07:30 1.00 CASE P TIEBi Continue circulating 9.8-ppg brine at 3.0-bpm C~? 300-psi to warm hole and wait for Schlumberger cementers to have crew change. 07:30 - 08:00 0.50 CASE P TIE61 PJSM -Rig crew, Schlumberger cement crew & CH2MHill vac truck drivers. Reviewed "Liner Running and Cementing Procedure". Identified hazards and tools to mitigate them. Assigned roles and responsibilities. 08:00 - 12:30 4.50 CASE P TIEBi Held PJSI~1 with all cementing personnel. Finished RU to cement scab liner. Tested cementing lines to 4500 psi. ~` Mixed and um ed 120 bbls Class "G" cement + additives at 15.8 ppg. Pumped cement slurry at 4-5 bpm with pressure varying from 1250 psi to 680 psi. Released DP wiper dart (~ 26-bbls. away, saw no indication of dart away. Cementing unit displaced cement with 9.8 ppg brine. Varied displacement rate from 5 bpm to 1.0-bpm. At 84-Bbls. away, choked back on return flow to hold 800-1000 psi backpressure and attempt to s ueeze away cement into hole in PC. In ications are at -20-Bbls. cements ueezed into casin leak. Bumped plug with 2900-psi at 134.92-bbls, about 0.08-bbls less than calculated displacement of 135-Bbls. CIP at 09:59-hrs. 11/24/2008. Increased pressure to 3300-psi and held for 2 slips set. Bled off pressure to 0-psi and confirmed float holding. Pressured u to 4435 si to set liner top packer. Bled pressure to 0-psi and had about 1.5 bbls luid return. Rotated running tool off liner top with 20 RH turns. Pressured up to 1000 psi and PU 7'; saw pressure bleed and circulated 20 bbls 9.8 ppg brine the long way. PU 25', closed annular, and RU to reverse circulate with rig. Reverse circulated at 4-5 bpm and 580-1600 psi. Had -20 bbls NEAT cement and 15-Bbls. diluted cement in fluid returns. Reverse circulated total of 87-Bbls. to clean up lines and mud manifold. RD cementing equipment. 12:30 - 14:00 1.50 CASE P TIEB1 POH with 41 stands DP and lay down liner running tools. 14:00 - 16:00 2.00 CASE P TIE61 Clear and clean rig floor. Rig up to run 2-7/8" HT PAC DP. 16:00 - 17:00 1.00 CASE P TIE61 Weekly safety meeting with day crew. Reviewed past weeks ADW HSE issues and IADC safety alerts and how they pertain to 4ES operations. Also read and discussed STOP cards submitted in the last week. 17:00 - 17:30 0.50 CASE P TIEB1 PJSM -reviewed 'BHA Picking Up" procedure and identified hazards associated with pinch points, line of fire, caught in between and working under suspended loads. 17:30 - 18:00 0.50 CASE P TIEB1 Pick up BHA #3 18:00 - 19:00 1.00 CASE P TIEB1 Crew change. pre-tour meeting, check PVT's and daily derrick inspection. Grease blocks and drawworks and environmental walkaround. 19:00 - 23:30 4.50 CASE P TIEB1 P/U BHA #3 for liner cleanout. 3-3/4" PDC, 2 boot baskets, bit sub, x-o, 2 pony collars, 1 drill collar, flex joint, string mill, x-o, oil jar, 8) 2-7/8" drill collars, pumpout sub, x-oi70) joints 2-7/8" HT PAC. 23:30 - 00:00 0.50 CASE P TIE61 an set 7-5/8" Halco storm packer 32' below surface for Printed: 12/18/2008 124:39 PM • BP EXPLORATION Operations Summary Report Legal Well Name: M-38 Page 6 of 10 ~ Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: WORKOVER Start: 11/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/2/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/24/2008 23:30 - 00:00 0.50 CASE P TIEB1 7-5/8" packoff change out. 11/25/2008 00:00 - 00:30 0.50 CASE P TIEB1 Pick up wear ring running tool and pull wear ring for packoff change out. 00:30 - 01:00 0.50 CASE P TIEB1 Pressure test 7-5/8" Halco storm packer to 3500 psi for 10 charted minutes oo es 01:00 - 02:00 1.00 WHSUR P TIEB1 P/U packoff running tool and engage 7-5/8" P/O. Open IA and bleed pressure.. Back out LDS and pull P/O, pulled at 35k. Install new FMC 7-5/8" P/O and test to 5000 psi for 30 minutes. (good test). Close IA. 02:00 - 03:00 1.00 DRILL P TIEB1 Hold Weekly safety meeting with rig crew. Discussed recent hand injuries, latest IADC incidents, ULS deisel, reviewed stop cards 03:00 - 03:30 0.50 DRILL P TIEB1 Install wear ring. 03:30 - 04:00' 0.50 DRILL P TIE61 P/U storm acker retreival tool and ull. 04:00 - 06:00 2.00 DRILL P TIE61 Continue RIH with 2-7/8" HT PAC 1x1 from pipe shed for 5-1/2" liner clean out. 06:00 - 06:30 0.50 DRILL P TIE61 Crew change. Pre-tour meeting -reviewed "Picking Up PAC DP" procedure, checked and tested PVT's, greased blocks and drawworks, performed daily derrick inspection and environmental walkaround. 06:30 - 09:00 2.50 DRILL P TIE61 Resumed picking up 2-7/8" HT PAC DP 1 x 1 from pipe shed. Circulated DP volume every 30 jts. ran in hole. Ran a total of 143-jts. of Weatherford owned 2-7/8" HT PAC , 1~ eta. x- 2-7/8" HT PAC x 2-7/8" PA BxP and 1 ea. XO 3-1/2" IF x 2-7/8" HT PAC BxP. 09:00 - 09:30 0.50 DRILL P TIE61 PJSM -reviewed "Running DP From Derrick" procedure. 09:30 - 10:30 1.00 DRILL P TIEB1 Rigged down 2-7/8" HT PAC DP running tools. Rigged up 3-1/2" DP running tools. 10:30 - 14:00 3.50 DRILL P TIEB1 Resumed RIH with 3-1/2" DP from derrick. Ran in hole w/ 38 stands. 14:00 - 15:00 1.00 CASE P TIEB1 R/U test equip. Close in well & pressure test 7 5/8" x 5 1/2" liner to 4000 psi. Pressure ee o psi in min, en flat lined remainder of test. Test, ee o pressure R/D test equip. 15:00 - 18:00 3.00 DRILL P TIEB1 P/U sin le & tagged up on stringer C~3 8386'. P/U kelly. Break circulation. 3 BPM ~ 1520 psi.Establish drilling parameters; drill & wash from 8386' to 8520'. Much green cement in returns. P/U Wt = 121 K. S/ Wt = 98K. Rot Wt = 107K WOB 2-3K. 60 RPMs, Torq = 2K ft-Ibs. 18:00 - 19:00 1.00 DRILL P TIEB1 Crew change. Pre-tour meeting -reviewed "Making Connection" procedure, checked and tested PVT's, greased blocks and drawworks, performed daily derrick inspection and environmental walkaround. 19:00 - 00:00 5.00 DRILL P TIE61 Establish parameters, P/U Wt = 121 K, S/O Wt = 98K, Rot Wt = 108K. WOB 2-5K, 70 rpm at 2,200 fUlbs of rotary torque. 3 bpm with 1,450 psi pump pressure. Drill cement and float equipment from 8,520' to 8,633'. Hard cement rom 8,450' 11/26/2008 00:00 - 00:30 0.50 DRILL P TIEB1 Drill cement from 8,633' to 8,651' P/U Wt = 121 K, S/O Wt = o = - ,~ 70 rpm at 2,200 ft/Ibs of rotary torque. 3 bpm with 1,450 psi pump pressure. 00:30 - 03:00 2.50 DRILL P TIEB1 Circulate 20 bbl High Vis sweep around at 4 bpm with 2,250 Printed: 12/18/2008 1:24:39 PM BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: WORKOVER Start: 11/20/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/2/2008 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code I NPT i Phase Description of Operations 11/26/2008 00:30 - 03:00 2.50 DRILL P TIE61 psi. Sweep brought up cement cuttings and some sluggits. 03:00 - 06:00 3.00 DRILL P TIEB1 Monitor well, Stand back Kelly, Shear open circulating sub, 3 06:00 - 06:30 0.50 DRILL P TIE61 06:30 - 09:30 3.00 DRILL P TIEB1 09:30 - 11:00 1.50 DRILL P TIE61 11:00 - 11:30 I 0.501 FISH I P I ITIEBI 11:30 - 12:30 1.00 FISH P TIE61 12:30 - 18:00 5.50 FISH P TIE61 18:00 - 18:30 0.50 FISH P TIEB1 18:30 - 20:30 2.00 FISH P TIEB1 20:30 - 21:30 1.00 FISH P TIEB1 21:30 - 23:00 1.50 FISH P TIEB1 23:00 - 00:00 1.00 FISH P TIEB1 11/27/2008 00:00 - 01:00 1.00 FISH P TIE61 01:00 - 04:00 3.00 FISH P TIEB1 04:00 - 05:30 1.50 FISH P TIE61 05:30 - 06:00 0.50 FISH P TIEB1 06:00 - 12:00 6.00 FISH P TIE61 12:00 - 12:30 0.50 FISH P TIEB1 12:30 - 14:00 1.50 FISH P TIEB1 14:00 - 17:30 3.50 FISH P T1EB1 17:30 - 19:00 1.50 FISH P TIEB1 19:00 - 21:00 2.00 FISH P TIE61 21:00 - 22:00 1.00 FISH P TIE61 bpm at 1,350 psi, sheared open, pump rate 3 bpm at 1,000 psi. POOH with BHA #3, Liner Clean Out Assembly, standing back 3-1/2" DP in the derrick. Stand back 38 stands of 3 1/2" DP. Change out handling tools for 2 7/8" PAC DP. Crew change. check PVT alarms. Inspect derrick. Service rig. UD 2 singles of 2 7/8" PAC DP.Con't to POOH & stand back 41 stands of 2 7/8" PAC DP. Break out & UD 8 jts of 3 1/8" PAC DCs. UD remaing BHA componets. Empty Boot baskets, inspect string mill & bit. Recovered cement, Brass & Aluminium. M/U BHA #4, RCJB assy to clean out to top of "XX" Plu as follows. RCJB, Boo- t basket, i~~ - ony s, 1 DC, XO, Jars, 8- 3 1/8" DCs, Pump Out Sub, XO. TL = 3036.36'. Set Back same. Clear & clean rig floor. RIH w/ RCJB & P/U 8 3 1/8" DCs. RIH on 48 stands of 2 7/8" PAC DP. Passed thru TOL ~ 3851' w/ no problem. Crew change. Service rig. Inspect derrick. Check PVT alarms. RIH w/ RCJB with 3-1/2" DP from derrick. Tagged up at 8,643'. P/U Kelly and establish parameters. P/U Wt = 122K, S/O Wt = 100K, Rotating Wt 112K. 30 RPM with 2,400 fUlbs of torque. 3 bpm with 2,160 psi. SPR = 35 SPM with 1,080 psi. Drop ball and pump down at 3 bpm. Ball on seat 2 bpm with 2,900 psi. Wash and work RCJB down to 8,646' while rotating at 20 rpm. Unable to work past 8,646', Acts like RCJB is packed with cuttin s. '-° Shear open circulating sub and circulate bottoms up at 4 bpm with 1,600 psi. Cement cuttings back at bottoms up. Monitor well, stand back kelly and POOH w/ RCJB standing back 3-1/2" DP in derrick while maintaining continous holefill• POOH w/ RCJB standing back 3-1/2" DP in derrick. Maintain continous holefill. C/O handling equipment and POOH standing back 2-7/8" HTPAC DP in derrick. Maintain continous holefill. UD 3-1/8" DC's, Break down RCJB. RCJB shoe was packed off with pieces of float equipment and cement. mpty boot basket. Recovered appx 1 quart of pot metal and cement. Redress circulating sub. Clear and clean rig floor. Secure well. Hold 6 hr crew holiday stand down for Thanksgiving. 3 hrs/ crew (crew on change out schedule) Crew change. Service rig. Check PVT alarms. Inspect derrick. M/U BHA 4 (re-run BHA #~ to clean out junk above top of XX Plug. RIH w/ BHA #4 to clean off above XX plug. on stands of 2 7/8" PAC DP. Did not see TOL at 3,851' Change handling equipment and RIH w/ BHA #4 on 3-1/2" DP from derrick. RIH to 8,591' Slip and cut 120' of drilling line. Inspect drawworks brakes and brake bands. P/U 10', 3-1/2" pup joint and 1 joint of 3-1/2" DP to 8,633'. P/U Printed: 12/18/2008 1:24:39 PM • BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: WORKOVER Start: 11/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/2/2008 Rig Name: NABOBS 4ES Rig Number: .pate From - To Hours ' Task Code ~!~ NPT Phase ' Description of Operations Y 103K, Rotating Wt = 112K. 20 RPM with 2,400 fUlbs of torque. Drop ball and pump to bottom at 3 bpm with 1,640 psi. With ball on seat 2-1/2 bpm with 2,700 psi. Wash down from 8,633' and tag at 8,646'. Wash and work RCJB from 8,646' to 8,655'. Wash and work RCJB with 20 - 40 RPM w/2,400 Wlbs of torque and 2-1/2 bpm with 2,700 psi. Unable to work ast 8,655'. Drop ball and open circulating sub and circulate bottoms up at 5 bpm with 2,500 psi. light cement cuttings at bottoms up. Crew change. Service rig. Check PVT alarms. Inspect derrick. Stand back Kelly, UD 1 joint of 3-1/2" DP and 10' pup joint. POOH w/ RCJB standing back 3-1/2" DP in derrick. C/O handling equipment, POOH w/ RCJB standing back 2-7/8" HTPAC DP. L/D 3-1/8" DC's and break down RCJB BHA. M/U running tool. Pull Wear Bushing. Install Test Plug. L/D running tool. R/U to test BOPE. Perform weekly BOPE test as per AOGCC/BP requirements. LP 250 psi. HP 4000 psi. ested annu ar to 3500 psi. Used 3 1/2" & 2 7/8" test jts. All tests passed. BOP test witnessing waived by Bob Noble w/ AOGCC 0730 hrs, 11-27-2008.. Crew change. Service rig. Check PVT alarms. Inspect derrick. Pull test plug. Install Wear Bushing. Slowdown lines. R/D test equip. M/U 3 1/2" notched collar on 2 7/8" PAC DP &RIH. handlin a ui ment and RIH w/ notched collar BHA o 3-1/2" DP from derrick. Tagged up at 8,657'. Stand back 1 stand o 3-1 2 an joints of 3-1/2" DP. M/U Kelly and establih parameters. Up Wt = 117K, S/O Wt = 97K, 3 bpm with 950 psi. Wash and work notched collar from 8,657' to 8,664'. Cuttings started washing wit out working pipe. Wash from 8,664 to 8,675' while reverse circulating. 4 bpm with 2,050 psi. Hard cement and sluggits in returns. everse circulate till clean returns. Monitor well, stand back Kelly and POOH w/ notched collar standing back 3-1/2" DP in derrick. POOH w/ notched collar standing back 3-1/2" DP in derrick. C/O handling equipment and POOH w/ notched collar, standing back 2-7/8" HTPAC DP. Break out and L/D notched collar BHA. Slight wear on notched collar. Clear and clean rig floor. M/U XX plug retrieval tool and P/U 3-1/8" DC's. Crew change. erwce rig. c ec alarms. Inspect derrick. R/U floor to RIH w/ 2 7/8" PAC DP. RIH w/ 50 stands of 2 7/8" HT-PAC DP to fish XX Plug.. Change out handling tool for 3 1/2" DP. RIH w/ 40 stands of 3 1/2" DP to fish XX plug. displace entire wellbore to 8.5 ppg seawater. Pump 4 BPM ~ 2240 psi. Pumped total of 275 bbls. P/U DP up jt & tag up 7' in ~ 8672'. Engage fish, work & jar 11/27/2008 21:00 - 22:00 1.00 FISH P TIE61 Kell and establish parameters. P/U Wt = 122K, S/O Wt = 23:00 - 00:00 1.00 FISH P TIEB1 11/28/2008 00:00 - 00:30 0.50 FISH P TIEB1 00:30 - 02:30 2.00 FISH P TIE61 02:30 - 05:00 2.50 FISH P TIE61 05:00 - 06:00 1.00 FISH P TIEB1 06:00 - 07:00 1.00 WHSUR P TIEB1 07:00 - 12:00 5.00 WHSUR P TIEB1 11/29/2008 00:00 - 01:30 1.50 FISH P TIEB1 01:30 - 03:30 2.00 FISH P TIEB1 03:30 - 04:00 0.50 FISH P TIEB1 04:00 - 05:00 1.00 FISH P TIEB1 05:00 - 06:00 1.00 FISH P TIEB1 06:00 - 06:30 0.50 FISH P TIEB1 06:30 - 07:00 0.50 FISH P TIEB1 07:00 - 09:30 2.50 FISH P TIEB1 09:30 - 10:00 0.50 FISH P TIEB1 10:00 - 11:30 1.50 FISH P TIE61 . 11:30 - 13:00 1.50 FISH P TIEB1 22:00 - 23:00 1.00 FISH P TIEB1 12:00 - 12:30 0.50 WHSUR P TIEB1 12:30 - 13:30 1.00 WHSUR P TIEB1 13:30 - 17:30 4.00 FISH P TIE61 17:30 - 19:30 2.00 FISH P TIEB1 19:30 - 20:30 1.00 FISH P TIEB1 20:30 - 23:00 2.50 FISH P TIEBi 23:00 - 00:00 1.00 FISH P TIE61 13:00 - 15:00 2.00 FISH P TIEB1 Printed: 12/18/2008 1:24:39 PM BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: WORKOVER Start: 11/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/2/2008 Rig Name: NABOBS 4ES Rig Number: Date ~'I From - To Hours Task Code NPT Phase 11/29/2008 13:00 - 15:00 15:00 - 17:30 17:30 - 18:00 18:00 - 18:30 18:30 - 21:30 21:30 - 00:00 11 /30/2008 00:00 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 06:00 06:00 - 06:30 06:30 - 07:30 07:30 - 08:30 08:30 - 09:00 09:00 - 10:00 10:00 - 00:00 2.00 FISH P 2.50 FISH P 0.50 FISH P 0.50 FISH P 3.00 FISH P 2.50 FISH P 2.00 FISH P 1.00 FISH P TIEB1 TIEB1 TIEB1 TIEBi TIE61 TIEB1 TIEB1 TIEB1 12/1 /2008 100:00 - 03:30 Description of Operations "XX" Plug free. Had 30K overpull when pulling up thru 4 1/2" tubing & out tie top of cut off stub. Verify plug engaged by RIH thru "X" Nipple & stack out on top of 3 1/2" liner ~ 8696'. P/U work & pull "XX" Plug back thru nipple & out top of tubing. did not notice any losses after pulling plug. P/U Wt - 120K, S/O Wt = 97K. Drop rod/ Ball, allow to fall & open Pump out sub. Circulate bottoms up. Pump 4 BPM. Pumped total of 290 bbls of seawater to fluid came back 8.5 ppg & clean. No losses noted ~.. during circulation. POOH with XX plug, laying down 3-1/2" DP. Maintain continous holefill with seawater. Hole is taking proper hole fill. Crew change. Service rig. check PVT alarms. Inspect derrick. POOH with XX plug, laying down 3-1/2" DP. Maintain continous holefill with seawater. Hole is taking proper hole fill. Change out handling equipment and POOH with XX plug, laying down 2-7/8" HTPAC DP. Maintain continous holefill with seawater. POOH with XX plug, laying down 2-7/8" HTPAC DP. Maintain continous holefill with seawater. L/D 3-1/8" DC's and XX -plug retrieval tool. Recovered XX - plug. 1.00 FISH P TIE61 ea rig floor and pull wear bushing. 1.00 BUNCO RUNCMP Hold weekly safety meeting with rig crew. 1.00 BUNCO RUNCMP R/U handling equipment for 3-1/2" tubing completion. 0.50 BUNCO RUNCMP Service rig. Crew Change. Check PVT alarms. Inspect derrick. 1.00 BUNCO RUNCMP Finish R/U handling tools & torque Turn equip to run 3 1/2" completion. 1.00 BUNCO RUNCMP Hold Weekly safety meeting. Reviewed this weeks incidents, BP & Nabors HSE Policy statements, Stop Cards, Weekly/YTD statistics & hand safety. 0.50 BUNCO RUNCMP Hold PJSM & review completion running order. Assign tasks to specific personnel. 1.00 BUNCO RUNCMP P/U & M/U completion tail pipe assy. Baker-Loc all connections below packer. Torque turn connections to 2300 ft-Ibs. 14.00 BUNCO RUNCMP P/U &RIH w/ 3 1/2" 9.2#, L-80, TCII tubing completion. Used Jet Lube Seal Guard thread compound. Torque Turn all connections to 2300 ft-Ibs. 3.50 BUNCO RUNCMP RIH w/ 3 1/2" 9.2#, L-80, TCII tubing completion. Used Jet Lube Seal Guard thread compound. Torque Turn all connections to 2300 ft-Ibs. Tagged up at 8,626'. 4' in on jt #283. Attempt to work through, set 5K down, Overpull of 10-20K coming out. R/U to circulated down at 2 bpm with 240 psi. Pressure started rising as set down. P/U and R/D circulating head. Collar on muleshoe spaces out to be landing 03:30 - 05:00 1.50 BUNCO RUNCMP L/D jts.#283, #282, and #281. P/U 5.78" pup jt. M/U Jt #281 and FMC tubing hanger. P/U Wt 80K, S/O Wt 70K. 05:00 - 06:00 1.00 BUNCO RUNCMP M/U landing jt and land hanger. RILDS and torque to 450 ft/Ibs as per FMC procedure. Muleshoe landed at 8,623', 17' inside of 4-1/2" tubing stub. 06:00 - 06:30 0.50 BUNCO RUNCMP Crew Change. Service rig. Check PVT alarms. Inspect derrick. 06:30 - 08:30 2.00 BUNCO RUNCMP R/U & reverse circulate hot seawater down annulus. Pumped Printed: 12/18/2008 1:24:39 PM • BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: WORKOVER Start: 11/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/2/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task. '~, Code NPT 12/1/2008 ~ 06:30 - 08:30 ~ 2.00 08:30 - 11:30 I 3.00 11:30 - 13:00 1.50 13:00 - 18:00 5.00 Phase Description of Operations RUNCMP 75 bbls of 120 degree seawater, 2 BPM C~ 330 psi. Follow w/ 185 bbls of 120 degree Inhibited Seawater, 2 BPM ~ 290 psi. RUNCMP R/U Hot Oilers & pressure test lines to 2000 psi. Pumped 95 bbls of 80 degrees diesel to freeze protect. Pumped 2 BPM ~ 575 psi. OAP increased from 80 psi to 560 psi. bleed OAP to 200 psi. RUNCMP R/U lines & allow well to U-tube from IA to tubing. RUNCMP Drop Ball/Rod & allow to fall. R/U Hot Oilers on tubing to set Packer. Attempt to pressure test lines, Pop off valve tripped ~ 4200 psi. Re-dress P/O valve & pressure test lines to 4500 psi, OK. Attempt to pressure up & set packer w/ 4500 psi. Pop off valve tripped again C~ 4400 psi.. R/U Rig test pump to tubing. pressure up to 4500 psi & set packer. Hold pressure for 30 min & test tubing, OR- ee to ing pressure to 1500 psi & SI. Swap Test Pump lines to IA & pressure up to 4000 psi. & test 18:00 - 19:00 19:00 - 21:00 1.00 2.00 BUNCO BUNCO RUNCMP RUNCMP Charted entire test. Bleed pressure off of IA and tubing. R/D test assemblies. Install TWC with FMC wellhead tech. Test TWC from above to 3 500 si for 10 minutes on the chart. Good test. 21:00 - 22:30 1.50 BOPSU P RUNCMP Drain BOPE and N/D BOP stack an set ac on pedestal. Barriers are tested TWC and Ball on RHC with kill weight fluid. 22:30 - 00:00 1.50 WHSUR P RUNCMP N/U FMC 13-5/8" X 4-1/16" 5K adaptor flange and 4-1/16" Tree. Test adaptor flange to 5,000 psi for 30 minutes. Good test. 12/2/2008 00:00 - 00:30 0.50 WHSUR P RUNCMP Fill 4-1/16" tree with diesel and test to 5000 psi. Good test 00:30 - 01:30 1.00 WHSUR P RUNCMP Wait on DSM to pull TWC. DSM is currently on Doyon 16. 01:30 - 03:00 1.50 WHSUR P RUNCMP R/U DSM lubricator Attempt to test to 500 psi. I up in lubricator. Thaw ice plug and test lubricator to 500 psi. Pull TWC and instal 03:00 - 04:00 1.00 WHSUR P RUNCMP Remove. secondary annulus valve and secure well and cellar. Rica released at 04:00 hours on 12/2/2008. Printed: 12/18/2008 1:24:39 PM • Well History • Well Date Summary M-38A 10/13/2008 **' WELL S/I ON ARRNAL.*** (pre rw o) RAN 3.80" CENT,4 1/2" EO PRONG. TAG & EQUALIZE 4 1/2" XX PLUG aC~. 8657 SLM LL 4 1/2" XX PL b6Y"FRa31~1'8'i;T7' M SET 4 1/2" BODY W/23" FILL EXT t~ 8657' ~' PERFORMED SUCCESSFUL MIT-T TO 1000# GETS AT 8640' SLM 2ND DUMP BAILER RUN SAT DOWN HIGH @ 8591' SLM, UNABLE TO WORK PAST BROKE THROUGH OBSTRUCTION @ 8591' SLM W/ 2.45" CENT. & 2.0" GAUGE RING, TAG @ 8657' SLM TOOK IMPRESSION W/ 3.75" LIB @ 8609' SLM, POOH ON 10/14/08 ***JOB CONT. ON 10/14/08*** M-38A 10/14/2008 ***JOB CONT. FROM 10/13/08*** (pre rw o) RAN 3.65" CENT., 2' x1-7/8" STEM, 3.75" LIB TO 8609' SLM. PICTURE OF SLUGGTTS. RAN 3.00" LIB TO 8607' SLM, TAP THRU, SD @ 8661' SLM. PICTURE OF SLUGGTTS. RAN 3.75" LIB TO 8658' SLM, TAP DOWN TWICE UNABLE TO COME FREE DROP 3.25" GO-DEVIL AND CUT WIRE @ 8655' SLM. RECOVER ALL WIRE FISHED OUT GO-DEVIL FRO G'~0 RIH W/ B.GUIDE & JDC TO FISH TOOLS. JARRED 5 HRS BEFORE FULLING LOST/STUG< TOOLS OOH. PICTURE OF SLUGGITS. REPEAT MIT-T TO 10 OOpsi (~ UG STILL HOLDING). ***CONT RIG DOWN ON 10-15-08 WSR, WELL TURNED OVER TO DSO*** M-38A 10/15/2008 ***CONT FROM 10-14-2008" (pre rw o) RIG DOWN SLICKLINE UNIT#4516 AFTER FISHING TOOL STRING. ***RDMO, S/IN UPON DEPARTURE, NOTIFY DSO'** M-38A 10/15/2008 T/IA/OA= SSV/0/0 Temp= cold PPPOT-T (PASS) PPPOT-IC (PASS) (PRE RWO) PPPOT-T RU 2 HP BT onto THA test void, 50 psi to 0 psi, flushed void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 rrinutes, 5000/ 30 minutes. Bled void to 0 psi, RD test equipment, cycled LDS out 1.0" ran in torqued "ET style" all w ere in good working condition. PPPOT-IC RU 2 HP BT onto IC test void, 1200 psi to 0 psi, flushed void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 34001 15 minutes, 3400/ 30 minutes. Bled void to 0 psi, RD test equipment, cycled LDS out 1.0" ran in torqued "Ef style" all w ere in good w orking condition. M-38A 10/17/2008 T/V0=400/50/160 Terrp=S/I MIT OA PASSED to 2000 psi (RWO prep,) Pumped 1.2 bbls of crude into the OA to reach test pressure. MIT A lost 60 psi in the 1st 15 min and 20 psi in the 2nd 15 min for a total loss of 80 psi in the 30 min test. Bleed OAP back down. Final WHPs = 400/60/0 Valve positions at the time of departure =Swab, Wing, SSV = Gosed /Master, IA, OA =Open M-38A 10/29/2008 ***WELL SHUT-IN ON ARRNAL*** INITIAL T/VO = 400/25/100. RIG UP E-LINE TO DRIFT AND JET CUT TUBING. ***JOB CONTINUED ON 30-OCT-2008*** M-38A 10/30/2008 ***JOB CONTINUED FROM 29-OCT-2008*** DRIFT 4.5" TUBING WITH 3.65" GAUGE RING ALONG WITH JUNK BASKET FROM SURFACE TO 8666'. RETRIEVED APPROXIMATELY 1.5 FEET OF SHMOO IN JUNK BASKET BUT 4.5" TUBING AT 8610' MID 2ND FULL JOINT ABOVE X NIPPLE WITH 3.65" POWER JET CUTTER. WELL SHUT-IN ON DEPARTURE INA T/V~ O = 925/20/100. ***JOB COMPLETE'** M-38A 11/2/2008 T/V0=950/40/100 Grc-out Well (RWO Prep) Pumped 5 bbls methanol, 530 bbls 9.8 NaG Brine dow n Tbg taking returns up Va to M-26 flow line. Freeze Protected TxVa w ith 25 bbls diesel, U-Tubed the FP into the Va. Flushed hardline jumper w ith 5 bbls diesel, bled all pressures to 0 psi. FWHP=O/0/0. Tags hung, casing valves open to gauges. M-38A 11/9/2008 T/V0=Vac/0/0; Set 4-1/16" CNV "H" BPV #145 thru tree for 4ES Pre-rig; 1-2' ext. used, tagged @ 98"; ***Complete*** (Best/Fraker) M-38A 11/14/2008 T/VO=BPVIO/0 temp=Sl MIT Failed to 1000 psV LLR of .4 bpm @ 1000 psi (Pre RWO) Pumped 11 bbls diesel to 1000 psi, slowed rate to establish LLR of .4 bpm at 1000 psi. Pumped at rate for 15 minutes. FWHPs=6FV/0/50 AT DEPARTURE VALVES in following positions -and operator notified of positions and result of job. Wing closed, Swab closed, SSV open, Master open, IA open, OA open -Well SI M-38A 11/20/2008 Tear down BPV #527 and have inspected for annual inspection. M-38A 11/20/2008 T/V0=0/0/150. Pull 4" CM/ H BPS/. Nabors 4ES move on well. Print Date: 12/29/2008 Page 1 oft Weli Date Summary M-38A 11/21/2008 T/V0=0/0/0. Pull 4" CNV H TWC thru BOPS after testing. Nabors 4ES N'-38A 12/2/2008 T/VO=Vac/0/0. Pull 4 1/16" CNV H TWC #283 thru tree, post tree test. 1-2' ext used, tagged @ 102". Dry Rod in 4 1/16" CNV H BPV thru tree for rig to move off well. No problerns. N'-38A 12/6/2008 T/V0=0/0/0. PUII 4 1/16" CNV H BPV thru tree, post rip. 1-2' ext used, tagged @ 102". No problerm. Print Date: 12/29/2008 Page 2 oft • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Anchorage, AK 99519-6612 b~- Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU M-38Ai Sundry Number: 308-363 David Reem Engineering Team Leader BP Exploration Alaska Inc. ~'~~ ~~ ` ~ ~~ ~ `~ ~' ~` PO Box 196612 ~~'"~ Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this~day of October, 2008 Encl. _ - /D/,~Dd' STATE OF ALASKA `' i~''~ ^~ ALASKA OIL AND GAS CONSERVATION COM~ION --RE~ E 19/ E '`' ~4 00 APPLICATION FOR SUNDRY APPROVAL 't~OCT 0 9 2 8 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ime ension ' Anch~ra e ~ ® Alter Casing - ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended ell ^ Change Approved Program _® Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 201-132 3. Address: ~® Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22519-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU M-38Ai Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (tt): 11. Field /.Pool(s): ADL 028282 ~ 56.1' - Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (tt): Effective Depth MD (tt): Effective Depth TVD (tt): Plugs (measured): Junk (measured): 10270' ~ 8726' - 10235' 8720' None None C in nth Size MD TVD B rst II se ct ral ' " 1 1 rf 311 1- /4" 11 S 1 4 In rmediate 7- / " 8' 71' 1 1 Pr n Liner 1 72' 3- /16" x 2-7/8" ' - 1 27 ' 413' - 7 6' Perforation Depth MD (tt): Perforation Depth TVD (tt): Tubing Size: Tubing Grade: Tubing MD (tt): 9968' - 10206' 8693' - 8715' 4-1/2", 12.6# L-80 8784' Packers and SSSV Type: 7-5l8" x 4-1/2" TIW 'HBBP' packer Packers and SSSV MD (tt): 8738' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: November 15, 2008 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ®WAG ~ ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Biork, 564-5683 Printed Nam avid Reem Title Engineering Team Leader Prepared By Name/Number Signature ~ Phone 564-5743 Date /o19~p8 Terris Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ ~ ~ ~ ^ Plug Integrity 'BOP Test ~Vlechanical Integrity Test ^ Location Clearance ~ ~' ~ ~~ /''~ L~ Other: ~d~ ~ e~1 ~O Q {'~-5•~ GS `C:~ h.~C` C Subsequent Form Required: ~4 APPROVED BY / (~ l 'Z (~ l A roved B COMMISSIONER THE COMMISSION Date l Form 10-403 Revised Ofi/2006 ' ;~~ ,<,,~,$r ~ ~,; Submit In Duplicate ~M-`1r-.~~~ ~` C~~~ ~ s 1008 • by C'~Trlrrdri M-38ai Expense Rig Workover Scope of Work: Pull 4-1/2" completion, change out 7-5/8" pack-offs, run and cement 5-1/2" scab liner, re- complete with 3-1/2" L-80 tubing and SABL-3 packer at 8430' MD. MASP: 2285psi Well Type: Water and Gas Injector Estimated Start Date: Nov. 15, 2008 Production Engineer: Don Brown Intervention Engineer: David Bjork Pre-Rip Prep Work: S 1 Drift tubing for 4-1/2" jet cutter. Set 4-1/2" XX Plug in the X nipple at 8677'. Dump 30' of Slug-Its on top of the XX Plug. Reference tubing tally dated 11/16/94 and CT liner tall dated 8/25/01 F 2 MIT-T to 1000 si, MIT-OA to 1000 si, attem t CMIT-TxIA to 1000 si and record LLR. E 3 Power Jet cut 4-1/2" L-80 tubing near the middle of the 2 full joint (8610') above the X nipple at 8677' (Tubing tally dated 11/16/94 indicates one pup, a full joint and pup below an X ni le above the aaker, CT liner to is in the first full ~oint. F 4 Circulate well with kill weight fluid (seawater) and 95bb1 diesel thru the cut, Freeze rotect tubin and IA to 2,200'MD W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. Check the IC for lastic ack ~ob. W 6 Set a BPV in the tubin han er. O 7 Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU Nabors 4ES. ND tree. NU and test BOPE pipe rams, with 2-7/8" x 5" VBR, to 4000 psi. Test annular preventer to 3500 psi. Circulate out freeze protection fluid and circulate well to kill weight fluid through the cut. 2. Retrieve 4-1/2" tubing string down to the tubing cut. 3. Dress off tubing stub. 4. Fully cement 5-1/2" L-80 BTC scab liner from 3800' to 8610'. The 2-7/8" x 5" VBR will NOT be changed to 5-1/2" as the barrier to the reservoir will be a tested XX plug at 8677' MD. 5. Change out 7-5/8" pack-offs, clean out shoe tract and pressure test liner and casing to 4000psi. 6. Retrieve 4-1/2" RBP. 7. Run 3-%" L-80 TC-II tubing with Baker SABL-3 packer and set at 8,430' MD. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 4000 psi. Freeze protect to 2200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. M-38ai Scope of Work Revisio~ • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 15, 2008 11:29 AM To: 'Bjork, David (Northern Solutions)' Cc: Reem, David C; Hubble, Terrie L Subject: RE: M-38ai (201-132) Scope of Work Revision Page 1 of 1 David, Changing the plug type is not an issue. Key requirement is that there is a plug. Coupled with the KW fluid, there should be 2 barriers in place while running the liner. I will place a copy of this message in the file. Please note, it is appreciated if you would include the permit number in the subject line of messages. Call or message with any questions. Tom Maunder, PE AOGGC From: Bjork, David (Northern Solutions) [mailto:David.Bjork@bp.com] Sent: Wednesday, October 15, 2008 11:14 AM To: Maunder, Thomas E (DOA) Cc: Reem, David C; Hubble, Terrie L Subject: M-38ai Scope of Work Revision Mr. Maunder, Please accept this revision for the Scope of Work on well M-38ai. Several changes were made including; XX Plug barrier, 2-7/8" x 5" VBR, and a statement of barrier during 5-112" liner run. Please accept my apologies for changes. Regards, Dave «M-38ai AOGCC Scope of Work rev1.doc» 10/1 S/200$ • by ~,r~iry- M-38ai Expen Rig Workover Scope of Work: Pull 4-1/ completion, change out 7-5/8" pack-offs, run and ment 5-1/2" scab liner, re- complete with 3-1/2" L-80 t ing and SABL-3 packer at 8430' MD. MASP: 2285psi Well Type: Water and Gas Injec Estimated Start Date: Nov. 15, 2 Production Engineer: Don Brown Intervention Engineer: David Bjork Pre-Rip Prep Work: S 1 Drift tubing for 4-1/2" RBP and 4 2" jet cutter. et 4-1/2" RBP at 8664' in the bottom of the 1st full joint above the X ni le at 8677 (9.68' pup on top of X nipple). Dump 30' of Slug-Its on top of the RBP. ferenc tubing tally dated 11/16/94 and CT liner tall dated 8/25/01 F 2 MIT-T to 1000 si, MIT-OA to 1000 si, a t CMIT-TxIA to 1000 si and record LLR. E 3 Power Jet cut 4-1/2" L-80 tubing near t fiddle of the 2" full joint (8610') above the X nipple at 8677' (Tubing tally dated /16 4 indicates one pup, a full joint and pup below an X ni le above the acker T line o is in the first full ~oint. F 4 Circulate well with kill weight fluff (seawater and 95bb1 diesel thru the cut, Freeze rotect tubin and IA to 2,200'M W 5 Check the tubing hanger lock own screws for f e movement. Completely back out and check each lock downs ew for breakage (ch k one at a time). PPPOT-T & IC. Check the IC for lastic ac 'ob. W 6 Set a BPV in the tubin h er. O 7 Remove the well house flow line. Level the ad as ne ed for the ri . Proposed Procedure 1. MIRU Nabors 4ES. ND t e. NU and test BOPE pipe rams (with 2- 8" x 5-1/2" VBR) to 4000 psi. Test annular preventer 3500 psi. Circulate out freeze protection flu and circulate well to kill weight fluid through t cut. 2. Retrieve 4-1/2" tubi string down to the tubing cut. 3. Dress off tubing st 4. Fully cement 5-1 ' L-80 BTC scab liner from 3800' to 8610'. 5. Change out 7- "pack-offs, clean out shoe tract and pressure test liner and sing to 4000psi. 6. Retrieve 4-1/ RBP. 7. Run 3-'/z" 0 TC-II tubing with Baker SABL-3 packer and set at 8,430' MD. 8. Displace a IA to packer fluid and set the packer. 9. Test to g and IA to 4000 psi. Freeze protect to 2200' MD. 10. Set B ND BOPE. NU and test tree. RDMO. • Attachment 1 - Wellbore Schematic C] t1~E= a-t,ra rev IYlinimum ID = 2372" ~ &904' 3-3110" X 2.710" LNR XO s D =z€ir 3(ii~fl 7MI IMBP 1iCR D= I;-111'078 XN? D=3~1~- 1 7-SIE' Ui1.0Uf iM1~DOYV M-MA) 89M'-9883` D = 2EOr (fRA7i3NSikYlRif IiEf Lots SP~{Y.~N SIYVD I~SBTil11Y ON ANGLEAT TY]PP' 87 ~ 9988' Wa,e= iiriee io Rnd-~an DH itr limfioml ptri dada SSE ~ Al OpU6gx DALE 2' 8 1095.10132 O 0828(01. 2' 8 1017b .10208 O 0828'01 17-~,6° tests. ~9.TA. NT-g~. D ~ fl875• 1 ~~/ ~~ +'4A€ETY ~~; ~"PR~M. iDia'CJI~i(~I.E/d{. O~A79M/bL1AitT5: MAX IAP~ 50B P81,MI1;}COAI' ^ ~ ~~ ~ 8904" 33Hi: x DATE liD/ BY 017S DALE fitV BY L7CtTS '11H7191 1i98 OM9fi1NAlC0MltEt10N 88P19~1 G3L9~E~'IWCK OllO8C15 itQAf#~IG YIC1A/E32 SAFii1f ND7E 09d08q$ ipHP.~ VWW~SF7YN01ElFDA7E 11f10R18 {:RdP.tC ty1TSTAl~IfiVALVE1~8898' f2H308 CINYTW CA7STAt~iGVAWE PR1O[7E BAY !M WELL' i~39A PWAfTPkt 20113211 APiNa 60A34-?251Sti1 SE111,1't'Itt, R12E 213T FSt3 ~1? FE1. ~ L~itpbtsflan {Alrulcij TREE= , 4-1/6" CNV WELLHEAD = 13-5/8" 5M FMC ACTUATOR= BAK KB. ELEV = 56.5' BF. ELEV = ~ 26.0' KOP = ' 1676' Max Angle = 98 Q 9188" Datum MD = Datum TVD = 8800' SS -3 8A SNOTES: ***PRODUCTION CASING LEAK O NG LIMITS: MAX IAP = 500 PSI, MAX OAP PfOpOS@d =1000 PSI (03/08/06 WAIVER)*** WELLANGLE> 70° @ 9040'. 2000' 3-1/2" HES 9Cr X-hip, X2.813 10-3/4" CSG, 45.5#, NT 80-LHE, ID = 9.953" H 311 3-1/2" TBG, 9.3#, L-80, .0087 bpf, O = 2.992" -$550' ~ 5-1/2" CSG, 17#, L-80, BTGM, ID = 4.892" ~ - 3800' 7-5/8" x 5-1/2" ZXP and Flexlock Hanger 8530' 3-1/2" HES 9G X-hip, ~=2.813 - 8550' 5-1/2" x 3-1/2" Baker SABL-3 Packer w/ E - 8580' 3-1/2" HES 9Cr X-Nip, ID=2.75 - 8640' 3-1/2" HES 9Cr XN-hip, ID=2.635 8677' 4-1/2" OTIS X NIP, ID = 3.813" Minimum ID = 2.372" @ 8904' 8698' 4-1/2" BKR KB LNR TOPPKR ID=2.56" 3-3/16" X 2-7/8" LN R XO 8703' TOP OF BKR LOCATOR SUB, ~ = 2.39" 8705' 3.75" BKR DEPLOY SLV, ID = 3.00" 8711' 3-1/2" BKR FL4S 3" PUP, ID = 2.88" 1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 8783' 8714' 3-1/2" X 3-3/16" LNR XO, ID = 2.80" 8738' 7-5/8" X 4-1 /2" TNV HBBP PKR, O = 3.901" 8772' 4-1/2" OTIS X NIP, ~ = 3.813" 8784' 4-1/2 TBG TAIL 8783' ELMD TT LOGGED 01/18/95 TOP OF WHIPSTOCK $$55' 7-5l8" MILLOUT WINDOW (M-38A) 8858'- 8863' ;; M1 8902' ~ 3-3/16" LNR 6.2#, L-80 TC2, .0076 bpf, ID = 2.80" i RA TAG 8865' q ~'; $904' 3-3/16" x 2-7/8" LNR XO, ID = 2.372" PERFORATION SUMMARY REF LOG: SPERRY-SUN MWD RESISTNIIY ON ANGLE AT TOP PERF: 87 @ 9968' Note: Refer to Production ~ for historical pert data S¢E SPF INTERVAL Opn/Sqz DATE 2" 6 9968 - 9998 C 08/26/01 2" 6 10095 - 10132 C 08/26/01 2" 6 10175 - 10206 C 08/26/01 7-5/8" CSG, 29.7#, NT-95-HS, ID = 6.875" H 9518' I PBTD I ~2-718" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.372" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 11/17/94 KSB ORIGINAL COMPLETION 12/15/07 KDC/PJC SETXX PLUG (12/06/07) 08/26/01 CTD SIDETRACK 10/02/08 DRB Proposed RWO 01/06/05 RDJ/PAG WANERSAFETY NOTE 03/08/06 RPWPJC WANER SFTY NOTE UPDATE 11/20/06 CJWPJC CAT STANDING VALVE @ 8698' 12/13/06 CJNITLH CAT STANDING VALVE PULL PRUDHOE BAY UNIT WELL: M-38A PERMfT No: 82011320 API No: 50-029-22519-01 SEC 1, T11 N, R12E, 2437' FSL i3< 605' FEL BP Exploration (Alaska) M-38A (PTD #2011320) Interna aver Cancellation -Not Operable Well Page 1 of 1 Re James B DOA • J9s ~ ) From: NSU, ADW Well Integrity Engineer[NSUADWWeIIlntegrityEngineer@BP.com] ~ 1~ ~ I~ 7 Sent: Thursday, November 15, 2007 3:38 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); GPB, FS2/COTU OTL; GPB, Wells Opt Eng; GPB, Prod Controllers Cc: Brown, Don L.; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: M-38A (PTD #2011320) Internal Waiver Cancellation -Not Operable Well All, An internal waiver was issued for a PC Leak on well M-38A (PTD #2011320) on 03/08/06. Corresponding AOGCC ~ Administrative Approval 3.004 was approved on 11!18/04. Although this well is allowed to inject under dispensation from the Well Integrity Policy until 12/31/07 if all compliance testing remains current, the produced water line at M Pad is down indefinitely. Therefore both the waiver and AA are being cance-led until both the line and well are repaired. The well has been reclassified as Not Operable and will be secured:` Please remove all Waivered well signs and the laminated copies of the waiver and AA from the wellhouse. The corresponding AA cancellation will be sent to the AOGCC. Please call if you have any questions. ~;~~~ NOV ~ 8 20D7 11 /26/2047 /~ TO: Jim Regg ~~~;.. hI ~~~ 1 P.1. Supervisor f FROM: Chuck Scheve Petroleum Inspector Alaska Oil and Gas Conservation Commi~ DATE: Monday. October 01, 2007 SliBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC M-38A PRL'DHOE BAY UNIT M-38A Srr. Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv-rJ~T iu `~j~i ~ Comm Well Name: PRUDHOE BAY UNIT M-38A ' Insp Num: mitCS070928172824 Rel Insp Num: API Well Number: 50-029-225 1 9-0 1-00 Permit Number: 201-132-0 Inspector Name: Chuck Scheve Inspection Date: 9%27/2007 Packer Depth ~ Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~ ~ M-38A ~ p ~. ~ N ~ well iTy eIn i TVD 8453 ~ ~ IA ~ ~ 0 40 ~~ -~~~~~~~ 40 40 I P.T. ~ 20] 1320 TypeTest SPT Test pSl ~ 2113 25 I QA ~, 30 2000 1910 j 1900 ' j Interval REQvAR p~F P ~~ Tubing = o ~ o ii o ~o -- NoteS' MITOA only. Annual test required by varience. _ - - y h ' ,~k.~~"1 ~~~ ~ ~ ~~~~ Monday, October 01, 2007 Page 1 of 1 Re: M-pad temperature logs . . Subject: Re: M-pad temperature logs From: Tom Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 20 Nov 2001 09:43:56 -0900 To: "McLellan, Bryan J" <McLellBJ@BP.com> Brian, Thanks for the info. I'd like to get together as well. When is the key?? Performing the same procedure on M-13Ai is appropriate. For the present time, on the other wells, I suggest you send us the log copies and include a letter describing the why and then the what was determined. How does that sound? Also, is the reporting by Joe just until we have a chance to pass approval on the temperature logs?? Tom "McLellan, Bryan J" wrote: Tom, I would like to set up a time to get together to discuss the M-03Ai and M-38Ai temperature logs. Both logs would suggest that we have cement isolation uphole from the perfs. I can either come to your office when you have time, or send copies of the logs to you, whichever you prefer. I have also asked Joe Anders (BP Well Integrity Engineer) to add these wells to his monthly monitoring list and he should begin reporting injection rate and pressure to you each month. ~ ~O \ _ \ Sl~ Also, we just finished drilling well M-13Ai and would like to\use the same method to confirm cement integrity as we did with M-03Ai and M-38Ai. If you agree, we will run a baseline temperature log and follow up with a temp warmback after 1 month of injection in M-13Ai. Thank you, Bryan McLellan Bryan McLellan BP Exploration, Alaska Production Engineer (907) 564-5516 5CANNED JUN 2 5 2007 ... ""-.~ ......-.* --:,-.."...:~.; , \,~",~'J~ç ~CP~ 10f1 6/25/2007 12:07 PM Re: M-38Ai Temp wannback. . Subject: Re: M-38Ai Temp warmback. From: Tom Maunder <tom _ maunder@admin.state.ak.us> Date: Wed, 03 Oct 2001 09:08:34 -0800 To: "McLellan, Bryan J" <McLelffiJ@BP.com> Sounds good Bryan. I will look forward to your update. Tom "McLellan, Bryan J" wrote: . Tom, FYI All the injectors at M-pad were shut in for the GC-2 shutdown for 9 days in September, so I am going to delay the Temp warmback on M-38Ai until mid October. M-38Ai started injecting on 9/5/01. .~ M-03Ai has still not come on line yet. I plan to get the SRT on M-03Ai 1 month after first injection. I'll keep you updated. Thanks, Bryan McLellan Bryan McLellan BP Exploration, Alaska Production Engineer (907) 564-5516 ~CANNED JUN 2 5 2007 10fl 6/25/2007 12:07 PM · _1 /rfJ~;¡ WELL LOG TRAt'\¡"SMITT AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13,2006 RE: MWD Formation Evaluation Logs: M-38A_PB1, N-01A, P-18 L1, S-18A, W-16A_PB1, W-32A PBl. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 ~ M-38A PB1: U'IC- 'dül-\"3'd- l'-/'--/lO Digital Log Images: 50-029-22519-01, 70 1 CD Rom N-OIA: g Cf./ - t 13 Å14'-11I Digital Log Images: 50-029-20079-01 SCANNED FE8 10 J 2007 1 CD Rom P-18 L1: QO'd. - 030 ~ ILILIO?! Digital Log Images: 50-029- 22097 -60 1 CD Rom S-18A: ¿)Od-/(P3 #;¿./L//d. Digital Log Images: 50-029-21156-01 1 CD Rom W-16A_PBl:Q0'3-IOO ¢ ¡L/4b9 Digital Log Images: 50-029- 22045-01, 70 1 CD Rom W-32A _PBl: dOd - dO'1 tt /4L/l3 Digital Log Images: 50-029-21790-01,70 1 CD Rom 1- e e WELL LOG TRANSMITTAL :;01,. 13~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 lðLç5C1 RE: MWD Formation Evaluation Logs M-38A + PBl, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 M-38A + PBl: LAS Data & Digital Log Images: 50-029-22519-01, 70 1 CD Rom .;,~ ~~ ~ e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc · as a Oil Jè. ~~. " 1. Operations Abandon D Repair Well D Plug Perforations [] Stimulate D Other Er4 'V "'UIl~. I..Umiìllt1SìOh Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension ndwrage Change Approved Program D Opera!. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 201-1320 3. Address: P.O. Box 196612 Stratigraphic fJ Service PI 6. API Number: Anchorage, AK 99519-6612 50-029-22519-01-00 7. KB Elevation (ft): 9. Well Name and Number: 56.1 KB M-38A 8. Property Designation: 10. Field/Pool(s): ADL-028282 Prudhoe Bay Field/ Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 10270 feet Plugs (measured) None true vertical 8725.56 feet Junk (measured) None Effective Depth measured 10235 feet true vertical 8720.07 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surface 3081 10-3/4" 45.5# NT-80LH 29 - 3110 29 - 3035.9 5210 2480 Production 8831 7-5/8" 29.7# NT-95HS 27 - 8858 27 - 8571.36 8180 5120 Liner 187 3-3/16" 6.2# L-80 8715 - 8902 8429.84 - 8613.57 Liner 1368 2-7/8" 6.16# L-80 8902 - 10270 8613.57 - 8725.56 13450 13890 Liner 12 3-1/2" 9.3# L-80 8703 - 8715 8417.98 - 8429.84 10160 10530 Perforation depth: Measured depth: 9968 - 9998 10095 - 10132 10175 - 10206 True Vertical depth: 8692.58 - 8694.3 8697.47 - 8701.68 8709.22 - 8715.06 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 25 - 8784 Packers and SSSV (type and measured depth) 4-1/2" Baker KB Top Packer 8698 4-1/2" Baker HB pa~~t~\~~!i~¡¡;: I" c; 2.L~8 u· u""\)';;'· '.~ t ~ (; 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8Ft. DEC 22' 2005 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 6364 0 790 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development 0 Service PI Daily Report of Well Operations X 16. Well Status after proposed work: Oil fJ! Gas 0 WAG GINJ fJ WINJ PI WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal / Title Data Mgmt Engr Signatur~'~~~¡ 1\ ! Phone 564-4424 Date 12/20/2005 Form 10-404 Revised 04/2004 ( I: : .. f "\ i__ Submit Ori inal Onl . STATE OF ALASKA _ ALA Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS AI k RECEI\I1=n ..,¥ DEe 2 2 2005 g y e e to' .. M-38A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 11/25/2005 ***WELL ON INJECTION ON ARRIVAL *** (reg campi) IN PROCESS OF RIGGING UP SLlCKLlNE UNIT ***CONTINUED ON WSR 11-26-05*** 11/26/2005 ***CONTINUED FROM WSR 11-25-05*** ( reg campi) RUN 41/2" BRUSH AND 3.80 GR TO 8705' MD, BRUSH 3.813 X- NIPPLE AT 8677' WHILE ON INJECTION, LITTLE RED FREEZE PROTECTED TBG & FLOW-LINE, A TTEMPING TO SET PX PLUG AT 8663' SLM ***JOB CONTINUED ON WSR 11-27-05*** 11/26/2005 T/I/O== 1500/60/160 Freeze Protect FL & TBG for SSL (Waiver Compliance) (On Injection upon arrival) Freeze Protect Flowline w/ 38 bbls of 60/40 meth/water. Freeze Protect Tbg w/ 38 bblsof 60/40 meth/water. RDMO Final WHP's 300/40/40 11/27/2005 ***JOB CONTINUED FROM 11-26-05*** SET 41/2" PX PLUG AT 8663' SLM (4 -1/4" HOLES IN EO-SUB, P- PRONG IS 96" OAL W/ 1 3/4" F.N W/ 2.75 CENTRALIZER 3" BELOW FISH NECK,1 3/4" BODY) GOOD TEST TO 3000 PSI, SEE DATA TAB # 6, LEFT PLUG IN HOLE FOR STATE TEST, NO-FLOW, PLUG SET TAG HUNG ON THE WING VALVE, PAD OP.NOTIFIED OF WELL STATUS ***LEFT WELL SHUT-IN, NOTIFY PAD OPERATOR*** 11/29/2005 T/I/O==60/50/60. Temp==SI. MIT-T to 3000 psi PASSED. (AOGCC Witnessed by Chuck Scheve). (WC). Used 1.7 bbls to pressure TBG from 60 psi to 3000 psi. TBG pressure decreased 30 psi in the 1st 15 min, and 10 psi in the 2nd 15 min for a total toss of 40 psi in 30 min. Bled TBG pressure from 2960 psi to 50 psi in 15 min. Final WHP's == 50/50/60 11/29/2005 T/1/0==60/50/60 MIT TBG passed @ 3000 psi. (Shut in)( AOGCC Witnessed LJY Chuck Sheve) TBG pressured up w/ 1.7 bbls Inhibited 60/40 meth pumped. TBG lost 30 psi in 15 min. w/ total loss of 40 psi in 30 min. Final WHP's==50/50/GO 11/30/2005 T/1/0== 0/30/30 MITOA to 3000 PASSED. Lost 120psi 1st 15 min. Lost 60psi 2nd 15 min. Bled pressures down. FWHP's== 0/30/30 12/1/2005 **** WCLL SHUT IN **** (reg campi) PULLED 4 1/2" PX PLUG FROM 8664' SLM *** WELL LEf; SHUT-IN NOTIFY OPERATOR READY TO POP AND DEPARTURE*** FLUIDS PUMPED BBLS 87 1 88 I ~~;~L MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission ....--. DATE: Wednesday, November 30,2005 TO: JIill Regg k/ . 7 j {D'S" ~___~_~I.supen'isoL_~}!9q3~~~--~-!E~I'lÆ~Ch!lI1.!C~ l¡¡tegrLty Te~tL.._u__ _.__~ _______..____ . BP EXPLORATION (ALASKA) INC t") ~ M~ \3r PRUDHOE BAY UNIT M-38A ~ 0\'" FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT M-38A API Well Number 50-029-225 I 9-0 1-00 Inspector Name: Chuck Scheve Insp Num: mitCS051129153639 Permit Number: 20 I -132-0 Inspection Date: 11/29/2005 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well M-38A ¡Type Inj.1 N I TVD I 8392 I IA I 50 I 50 I 50 ! 50 i ! I P.T. 2011320 ¡TypeTest I I Test psi I 2098 lOA ! 60 , 60 I 60 60 I I , Interval REQVAR P/F P Tubing I 60 I 3000 I 2970 2960 I ¡ Notes This Well has IA x formation communication. A plug had been set in the 4 1/2" X nipple at 8677'. The liner top packer is at 8698. This MIT T verifies tubing integrity above the X nipple. ~(('&Ulr<if~~:' . ~ ~Ú~; ~<:...,,", ~~ .'-'~ Wednesday, November 30, 2005 Page I of 1 ) ~J/A\~~ :~ /A\:/A\~~/A\ AI/ASKA OIL AlVD GAS CONSERVATION COJDIISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 18,2004 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage,AJ( 99519-6612 RE: PBU M-38A (PTD 201-132) Request for Administrative Approval Dear Mr. Rossberg: Per Rule.9 of Area Injection Order ("AIO") 003.000, the Alaska Oil and Gas Conserva- tion Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU M-38A. The Commission further finds that, based upon reported results of BPXA's di- agnostic procedures, PBU M-38A exhibits two competent barriers to release of well pres- sure. Accordingly, the Commission believes that the well's condition does not compro- mise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in PBU M-38A iscondi- tioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 3. BPXA shall perform a yearly MIT-OA to 1.2 times the maximum anticipated well pressure; 4. BPXA shall perform an MIT-T every two years to 1.2 times the maximum antici- pated well pressure; 5. BPXA shall limit the well's IA pressure to 500 psi; if. "r.'I"N.' N!E-f""., r¡\!lr"¡ \1 l (¡ 2004 ;:)vM .. .~,"- ~.I ,.. '!..S ) , Mr. Steve Rossberg November 18,2004 Page 2 of2 6. BPXA shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure; and . 7. after well shut in, AOGCC approval shall be required to restart injection. 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 consid- ered 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. aniel T. Seamount Jr. Commissioner SCANNED NO\! 1 ~ 2004 BP Exploration (Alaska) Inc. Steve Rossberg, Wells Manager Post Office Box 19661 2 Anchorage, Alaska 99519-6612 November 3,2004 Mr. John Norman, Chairman Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 NOV 1 () 2004 Subject: Prudhoe Bay Unit M-38A (PTD 2011320) Request for Administrative Approval to Continue Water Injection Operations Dear Mr. Norman, BP Exploration (Alaska) Inc. requests approval to continue water injection operations into well M-38A. Well M-38A has a production casing leak. Based upon sound engineering practice, two competent barriers have been established and thus the well can be safely operated. The barriers have passed pressure tests to 1.2 times the maximum anticipated injection pressure and observed annulus operating pressures do not exceed 45% of the casing's rated burst pressure. The attached proposed operating and monitoring plan includes frequent monitoring of the competency of the barriers by recording daily pressure and injection data, increasing the frequency of mechanical integrity tests and increased reporting to the AOGCC. These measures will ensure continued safe water injection operations. Considering the presence of two competent barriers, physical repairs in this well are not necessary for safe operation. If one of the competent barriers should become compromised, the well will be shut in, the Commission notified and physical corrective options will be evaluated. This request is consistent with Area Injection Order 3, Rule 9, in that sound engineering practices have established two competent barriers and an operating and monitoring plan has been developed to ensure continued safe operations. There is no underground source of drinking water and thus no USDW is endangered. If you require any additional information, please contact me at 564-5637 or Joe Anders / Anna Dube at 659-5102. Sincerely, ý} ./ 2(-£~~ Wells Manager SCANNED NO\f 1 ~ 2004 '. ') ) Attachments Technical Justification for Administrative Relief Request Wellbore Schematic TIO Plot SCANNE[', NOV 1 9 2004 , . {/' ") ') Prudhoe Bay Unit M-38A Technical Justification for Administrative Relief Request November 3, 2004 Well History and Status Prudhoe Bay Unit well M-38A (PTD 2011320) has a slow production casing leak. An MIT-IA failed on 09/20/03, leak rate is 8.4 gpm @ 2850 psi. An MIT-T passed to 3000 psi on 12/09/03 and an MIT -OA passed to 2500 psi on 10/18/04. These passing MITs demonstrate competent tubing and surface casing. Recent Well Events: - 12/07/03: Set standing valve - MIT-T pass to 3000 psi. Pull standing valve. - 12/26/03: LDL ID'ed PC leak @ 4780' md. - 10/18/04: MITOA Passed to 2500 psi. Barrier and Hazard Evaluation The well has two competent well barrier systems to prevent the atmospheric release of fluids and to safely operate the well. The primary barrier is the tubing/packer. In the event of a leak, the secondary well barrier system composed of the surface casing will contain any pressure. Both of these systems have been pressure tested to at least 1.2 times the maximum anticipated injection pressure to ensure competency. Barrier competency is monitored using wellhead pressure plots (TIO plot), Pressure / Rate plots and periodic pressure tests to 1.2 times the maximum anticipated injection pressure. Primary Well Barrier System: Tubing competency is demonstrated by the passing MIT - T to 3000 psi on 12/07/03. Primary well barrier system competency will be monitored by daily annulus pressure observations, by frequent review of a TIO plot to monitor pressure trends and by conducting a 2 year MIT-T. Also, maximum allowable IA pressure will be limited to 500 psi. In the event of a tubing or packer leak, IA pressure would increase to the injection pressure, providing notification of a compromised primary well barrier and initiating a well review. Secondary Well Barrier System: Surface casing competency is demonstrated by the passing MIT -OA to 2500 psi on 10/18/04. Competency will be monitored by daily annulus pressure observations, by frequent review of a TIO plot to monitor trends and by conducting an annual MIT-OA. Thermal Overpressure of the OA: Maximum allowable OA pressure will remain at 1000 psi. In the event of a shallow production casing leak, an OA pressure increase would be observed by the Operators conducting daily well inspections and the well would be shut-in. Any pressure in the OA would relieve into the formation through the production casing and tubing, mitigating the potential of OA overpressure. Injection fluid temperatures are warmer than the wellbore temperatures to the depth of the surface casing shoe. This results in the well cooling off when shut-in, preventing thermal overpressure. SCANNEIJ NO\! 1 9 2004 ) ') Mechanical Condition: The production casing is not considered a component in the well barrier systems. The tubing/packer and surface casing are the 2 competent well barrier systems and have been confirmed. The well will be shut-in at any indication of barrier competency loss. Proposed Operating and Monitoring Plan 1. Continue water injection. 2. Record wellhead pressures and injection rate daily. 3. Submit a report monthly of well pressures and injection rates to the AOGCC. 4. Perform an annual MIT-OA to 1.2 times maximum anticipated well pressure. 5. Perform a MIT - T every 2 years to 1.2 times maximum anticipated well pressure. 6. Notify the AOGCC if there is any indication of a change in well mechanical condition. SCANNED NO\! 1. 9 2004 '.... ) TREE = 4-1/6" CIW WI3...LHEAD = 13-5/8" 5M FtvC 'Acï'UÃfõR";"""m"m,,,,_,,,,,mmmm,,mmSAKER' "KIr'ECE\T;;mm_"m_""m_mm""_'m,w_m"m56~5'" "s'F:mËCBl"";m"""_"_---",__""m",,,,-,,,,m"-2f3':i5;' 'KÕp-;m_~_""""__m"m_m"_",,m"m"m"m""'''''''167iF Max"Ãñglë~;"-'-m--"m""98'm"@"m'9T8íF' '5ã1Î::tmmfíífÕ";,,,-,,,__,,,,,,,,,m,,_m,,,,,__m,,___,,,,,,,__mm,, --HH__"'H'H"""'HH,--_''''''N''m'''''''''''_'NHH''''H_H'''HH,H__'nH'''H~HHH''_'- Datum TV 0 = 8800' SS 110-3/4" CSG, 45.5#, NT-80-LHE, 10 = 9.953" 1-4 3110' r-JI Minimum ID = 2.372" @ 8904' 3-3/16" X 2-7/8" LN R XO 13.75" BKR LNR OER...OY SLEEVE, 10 = 3.00" H 8705' 13-1/2" BKR FL4S 3' PUP, 10 = 2.88" I~ 8711' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10=3.958" 1-4 8783' PERFORATION SUMMARY REF LOG: SÆRRY-SUNMWORESISllVl1Y ON ANGLEA TTOP ÆRF: 87 @ 9968' !\bte: Refer to A'oduction DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DATE 2" 6 9968 - 9998 0 08/26/01 2" 6 10095 - 10132 0 08/26/01 2" 6 10175 - 10206 0 08/26/01 SCANNED NO\ll 92004 17-5/8" CSG, 29.7#, NT-95-HS, 10= 6.875" H 9518' DATE 11/17/94 08126101 04111/01 1 0/0210 1 02104/04 REV BY COMrvENTS KSB ORIGINAL COMPLETION CTD SIDErRACK CH/KA K CORRECllONS CHffP CORRECllONS GRCffLP CSG - GRACE CORRECTIONS ) M-38A SAFETY NOTES: WELL AN<?LE > 700 @ 9040' & > 900 @ 9070'. I 2097' 1-14-1/2" OTIS X NIp, 10 = 3.813" 1 I ~ I 8677' 1-14-1/2" OTIS X NIP, 10 = 3.813" 1 8 2S 8698' 1-\4-1/2" BKRKB LNR TOPPKR, 10= 2.56" 8703' I-iTOPOFBKR LOC'ATORSUB, ID= 2.39" I ... 8714' 1--13-1/2" X 3-3/16" LNRXO, 10= 2.80" I :8: )S 8738' 1--17-5/8" X 4-1/2" TIW HBBPPKR, 10 = 3.901" 1 ! , 8772' 1-14-1/2" OTIS X NIP, 10 = 3.813" 1 8784' 1--14-1/2 TBG TAIL I 8783' HEUVD TT LOGGED 01/18/95 I 7-5/8" MlLOUTWINOOW 8858' - 8863' ~ 8855' 1-4 TOP OF WHIPSTOCK 1 8865' I-iRA TAG I 1-43-3/16" LNR, 6.2#, L-80 TC2, .0076 bpf, 10 = 2.80" 1 8904' 1-13-3/16" x 2-7/8" LNR XO, 10 = 2.372" 1 FETD H 10235' 12-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, 10= 2.372" DATE REV BY COrvtv1ENTS PRUŒ10E BAY UNIT WI3...L: M-38A ÆRMIT !\b: 2011320 API !\b: 50-029-22519-01 SEC 1, T11N, R12E, 2437' FSL& 605'FEL BP Exploration (Alaska) , \-..-' > ::'1 M-38 TIO Plot 4,000 3,000 CI> '- ::s t/) t/) CI> '- c.. 2,000." \ 0 . '~MP --Lf"~~~1 11/4/2003 1/4/2004 3/4/2004 5/4/2004 SCA,NNED NOV 1 9 2004 ù I Ii ~....-. - ..-.. II -~-LI '"II; 7/4/2004 9/4/2004 11/4/2004 '. Tbg -.- IA *OA OOA -111- OOOA ¡j -) ) BP Exploration (Alaska) Inc. Steve Rossberg, Wells Manager Post Office Box 196612 Anchorage, Alaska 99519-6612 D OCT 2 ry 2004 AI~lkl October 20, 2004 Mr. John Norman, Chairman Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit M-38A (PTD 2011320) Request for Administrative Approval to Continue Water Injection Operations Dear Mr. Norman, BP Exploration (Alaska) Inc. requests approval to continue water injection operations into well M-38A. Well M-38A has a production casing leak. Based upon sound engineering practice, two competent barriers have been established and thus the well can be safely operated. The barriers have passed pressure tests to 1.2 times the maximum anticipated injection pressure and observed annulus operating pressures do not exceed 45% of the casing's rated burst pressure. The attached proposed operating and monitoring plan includes frequent monitoring of the competency of the barriers by recording daily pressure and injection data, increasing the frequency of mechanical integrity tests and increased reporting to the AOGCC. These measures will ensure continued safe gas injection operations. Considering the presence of two competent barriers, physical repairs in this well are not necessary for safe operation. If one of the competent barriers should become compromised, the well will be shut in, the Commission notified and physical corrective options will be evaluated. This request is consistent with Area Injection Order 3, Rule 9, in that sound engineering practices have established two competent barriers and an operating and monitoring plan has been developed to ensure continued safe operations. There is no underground source of drinking water and thus no USDW is endangered. If you require any additional information, please contact me at 564-5637 or Joe Anders / Anna Dube at 659-5102. Sincerely, ;1"£4 Steve Rossberg Wells Manager ~ SCANNEC, NOV 1 9 2004 -) Attachments Technical Justification for Administrative Relief Request Wellbore Schematic TIO Plot SCANNED NOV 1. 9 2004, -) ) Prudhoe Bay Unit M-38A Technical Justification for Administrative Relief Request October 20, 2004 Well History and Status Prudhoe Bay Unit well M-38A (PTD 2011320) has a slow production casing leak. An MIT-IA failed on 09/20/03, leak rate is 8.4 gpm @ 2850 psi. An MIT-T passed to 3000 psi on 12/09/03 and an MIT-OA passed to 2500 psi on 10/18/04. These passing MITs demonstrate competent tubing and surface casing. Recent Well Events: - 12/07/03: Set standing valve - MIT - T pass to 3000 psi. Pull standing valve. - 12/26/03: LDL IDled PC leak @ 47801 md. - 10/18/04: MITOA Passed to 2500 psi. Barrier and Hazard Evaluation The well has two competent well barrier systems to prevent the atmospheric release of fluids and to safely operate the well. The primary barrier is the tubing/packer. In the event of a leak, the secondary well barrier system composed of the surface casing will contain any pressure. Both of these systems have been pressure tested to at least 1.2 times the maximum anticipated injection pressure to ensure competency. Barrier competency is monitored using wellhead pressure plots (TIO plot), Pressure / Rate plots and periodic pressure tests to 1.2 times the maximum anticipated injection pressure. Primary Well Barrier System: Tubing competency is demonstrated by the passing MIT - T to 3000 psi on 12/07/03. Primary well barrier system competency will be monitored by daily annulus pressure observations, by frequent review of a TIO plot to monitor pressure trends and by conducting a 2 year MIT-T. Also, maximum allowable IA pressure will be limited to 500 psi. In the event of a tubing or packer leak, IA pressure would increase to the injection pressure, providing notification of a compromised primary well barrier and initiating a well review. ~ 0 c.:;:) ~ ~ ~ -- - 0 z Secondary Well Barrier System: Surface casing competency is demonstrated by the passing MIT -OA to 2500 psi on 10/18/04. Competency will be monitored by daily annulus pressure observations, by frequent review of a TIO plot to monitor trends and by conducting an annual MIT-OA. (~\ Lû Z Z <C. U to Thermal Overpressure of the OA: Maximum allowable OA pressure will remain at 1000 psi. In the event of a shallow production casing leak, an OA pressure increase would be observed by the Operators conducting daily well inspections and the well would be shut-in. Any pressure in the OA would relieve into the formation through the production casing and tubing, mitigating the potential of OA overpressure. Injection fluid temperatures are warmer than the wellbore temperatures to the depth of the surface casing shoe. This results in the well cooling off when shut-in, preventing thermal overpressure. Mechanical Condition: The production casing is not considered a component in the well barrier systems. The tubing/packer and surface casing are the 2 competent well ') ) barrier systems and have been confirmed. The well will be shut-in at any indication of barrier competency loss. Proposed Operating and Monitoring Plan 1. Continue water injection. 2. Record wellhead pressures and injection rate daily. 3. Submit a report monthly of well pressures and injection rates to the AOGCC. 4. Perform an annual MIT-OA to 1.2 times maximum anticipated well pressure. 5. Perform a MIT - T every 2 years to 1.2 times maximum anticipated well pressure. 6. Notify the AOGCC if there is any indication of a change in well mechanical cond ition. SCANNED NOV 1 9 2004 M-38 TIO Plot 4,000 3,000' ~ :;, tn tn () ~ 0.. 2,000'" 1 Ooo'~M , r - \/ I II : ~ Ii! f 0 10/21/2003 12/21/2003 2/21/2004 4/21/2004 SCANNEC, NO\J 1 9 2.004 6/21/2004 ) , " II II I, " ,1 :1 ! I ",MU- ... t:Þ- ~-- u. " " 8/21/2004 10/21/2004 .- Tbg -111- IA -,.- OA OOA &I- OOOA TREE = WB..LI-EAD = A CTUA TOR = KB.ELEV = ., BF. ELBI = KOP= Max Angle = Datum MD = DatumTVD = 4-1/6" CIW 13-5/8" 5M F~ BAKffi , 56.5; 26.0' 1676' 98 @ 9188" 8800' SS 110-3/4" CSG, 45.5#, NT-80-LHE, ID = 9.953" 1-1 3110' ~ Minimu m ID = 2.372" @ 8904' 3-3/16" X 2-7/8" LN R XO 13.75" BKR LNR DEROY SLEEVE, ID = 3.00" 1-1 8705' 13-1/2" BKR R..4S 3' PUp, ID = 2.88" H 8711' 14-112" 18G, 12.6#, L-80, .0152 bpf, ID =3.958" 1-1 8783' PffiFORA TION SUMrv1ARY REF LOG: SÆRRY -SUN MWD RESISllV IlY ON ANGLEA TTOP ÆRF: 87 @ 9968' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DATE 2" 6 9968 - 9998 0 08/26/01 2" 6 10095 - 10132 0 08/26/01 2" 6 10175 - 10206 0 08/26/01 SCANNE,[; NO\! 1 9 2004 17-5/8" CSG, 29.7#, NT-95-HS, ID= 6.875" H 9518' DATE 11/17/94 08126101 04111/01 10/02/01 02/04104 REV BY COMI\ÆNTS KSB ORIGINAL COMPLETION CTD SIDETRACK a-J/KA K CORRECllONS CHffP CORRECllONS GRCffLP CSG - GRADE CORRECTIONS DATE REV BY M-38A I I I 8 ~ 8: '~ ! , ~ ~ SAFETY NOTES: WELL ANGLE> 70° @ 9040' & > 90° @ 9070'. 2097' H4-1/2" OTIS X NIp, ID = 3.813" 1 8677' 1-14-1/2" OTIS X NIp, ID = 3.813" 1 8698' 8703' 8714' 8738' 8772' 8784' 8783' H4-1/2" BKR KB LNR TOP PKR, ID = 2.56" I..,TOPOFBKR LOCATOR SUB, ID= 2.39" I H3-1/2"X 3-3/16" LNRXO, ID= 2.80" 1 1-17-5/8" X 4-1/2" TIW H3BPPKR, ID = 3.901" 1 1-14-1/2" OTIS X NIP, ID = 3.813" 1 1-i4-1/2 18G TAIL 1 I-1ELMD IT LOGGED 01/18/95 1 7-5/8" MLLOUTWINDOW 8858' - 8863' 8855' HTOPOFWHIPSTOO< 1 8865' I-iRA TAG I 1-13-3/16" LNR, 6.2#, L-80 TC2, .0076 bpf, ID = 2.80" I 8904' 1-13-3/16" x 2-7/8" LNR XO, ID = 2.372" 1 FBlD H 10235' 12-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.372" COfvfv1ENTS PRU[)-OE BAY UNIT WB..L: M-38A ÆRMT f\b: 2011320 API f\b: 50-029-22519-01 SEe 1, T11 N, R12E, 2437' FSL & 605' FEL BP Exploration (Alaska) (' ( ò BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 March 17, 2004 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Subject: M-38A (PTD 2011320) Application for Sundry Approval for PWI with Slow Production Casing Leak Dear Mr. Aubert: Attached is Application for Sundry Approval form 10-403 for well M-38A requesting approval to continue water injection with a slow production casing leak. If you require any additional information or clarification, please contact Anna Dube or Joe Anders at (907) 659-5102. Sincerely, ¡~.~ v Joe Anders, P .E. Well Integrity Coordinator Attachments Application for Sundry Approval form 10-403 Description Summary of Proposal Well bore Schematic 1 0),'. ")["\u" 1 o}l Ld ( O'?'Gt~\!A[- ( STATE OF ALASKA ( , ALASKA OIL AND GAS CONSERVATION COMMISSION,: APPLICATION FOR SUNDRY APPROVAl.¡ t) '200 20 AAC 25.280 . ,~ J 1. Type of Request: Abandon D Alter Casing D Change Approved Program 0 2. Operator Name: Suspend D Repair Well D Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: " PerforateD "Waiver!]/ Annular Disposal 0 StimulateD Time ExtensionD OtherD Re-enter Suspended We II 0 Permit to Drill Nurpber: 201-1320 /' . ~ .. .~ BP Exploration (Alaska), Inc. Development D StratigraphicD 9. Well Name and Num7ber', M -38A 10. Field/Pool(s): Prudhoe Bay Fie PRESENT WELL CONDITION SUMMARY I Total Depth TVD (ft): I Effective Depth MD (ft): I Effective D 8725.6 10234 Length Size MD 3. API Number /' 50-029-22519-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.10 KB 8. Property Designation: ADL-0028282 11. Total Depth MD (ft): 10270 Casing P'tIgs (md): None Burst Junk (md): None Collapse 17. I hereby certify that the foregoing is true and cqfrect to the best of my knowledge. 20" 91.5# H-40 3-1/2" 9.3# L-80 3-3/16" 6.2# L-80 2-7/8" 6.16# L-80 7 -5/8" 29.7# NT .95HS 10-3/4" 45.5# Nk80LHE Perforation Depth TVD ~: 8693 - 829 , 8697 - 870 . Þ\ 8709 - 8 5.~ top bott top bottom /'3Q - 10 30.0 - 110.0 (~ 8703\ 8715 8418.0 - 8429.8 . 8715 8902 8429.8 . 8613.6 8902 1 027~ 8613.6 - 8725.6 13450 r - 885f 2~0 - 8571.4 8180 .:: . 311 2 . - 3035.9 5210 T. ubinç Size.' ~ Tubing Grade: Tubing MD (ft): ..)¡.5 ~ ~ 2. # L-80 25 ,,~ 'e\~ ~ackers a~~~ssv MD (ft): 1490 10160 470 10530 Conductor 80 Liner 12 Liner 187 Liner 1368 Production 8831 Surface 3081 Perforation Depth MD (ft): 9968 - 9998 10095 - 10132 10175 - 10206 Packers and SSSV Type: 4-1/2" Baker HB Packer 4-1/2" Baker KB Liner Top Packer 12. Attachments: ~ Description Summary of Propos ~ Detailed Operations Program D BOP Ske hr¡. 14. Estimated Date for F Commencing Operatic 16. Verbal Approval: Commission Representative: 13890 5120 2480 8785 8738 8698 13. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ Date: 15. Well Status after proposed work: Oil D GasD PluggedD AbandonedD WAG D GINJD WINJŒ WDSPLD Prepared by Garry Catron 564-4657. Printed Name Signature Contact Joe Anders I Anna Cube Title Phone Well Integrity Coordinator 659-5102 3/9/04 Commission Use Only Conditions of approval: Notify Commissio'\í so that a representative may witness I Sundry Number: . '3o~'" tJ /16\../ Plug Integrity D BOP TestD Mechanciallntegrity Test D Location Clearance 0 Other: Subsequent Form Required: Approved by: BY ORDER OF THE COMMISSION Date: Form 10-403 Revised 12/2003 ORIGINAL RBDMS BFL JUM 2 9 100~ SUBMIT IN DUPLICATE ( \, M-38A Description Summary of Proposal 03/09/04 Problem: Produced Water Injector with slow production casing leak / Wen History and Status: Well M-38A (PTD 2011320) has a slow production casing leak. An MITIA failed on 9/20/03, and a subsequent LDL located a production casing leak at 4780'. /' Mechanical integrity tests indicate competent tubing and surface casing, Recent Wel\ Events: ~ 09/20/03: M'T'A Failed, LLR 8.4 gpm @ 2850# ~ 11/06/03: M'T -OA Passed to 2500 psi ~ 12/07/03: Set standing valve - MIT-T pass to 3000 psi. Pull standing ~ ~~1~~103: LDL ID'ed PC leak ~d, This Sundry request is to allow for continued water injection in this well. The foHowing supports the request: . An MIT-Tubing passed to 3000 psi on 12/07/03, indicating competent ./ tubing.' . An MIT-OA passed to 2500 psi on 11/06/03, indicating competent / surface casing. . Pressure and injection rates will be monitored and recorded daily and checked for indications of a tubing or surface casing leak. Proposed action plan: 1. Allow well to continue Water injection. / 2. Record wellhead pressures and injection rates daily. / 3. Perform annua' MIT -OA. /' *' 4. Perform 4-year MIT -Tubing. 5. Stop injection and notify the AOGCC if there is an indication of a loss of tubing or casing integrity. { TREE = WELU-EAO = A CfUA TOR = KB. ElEV = BF. ELEV = KOP= Max Angle = Datum MO= Datum TV 0 = 4-1/6" CIW 13-5/8" 5M FWC BAKER 56.5' 26.0' 1676' 98 @ 9188" 8800' SS 110-3/4" CSG, 45.5#, NT-80-Ll-E, 10 = 9.953" 1-1 311 0' ~ Minimum ID = 2.372" @ 8904' 3-3/16" X 2-7/8" LN R XO 1 3.75" BKR LNR OEA..OY SLEEV E, 10 = 3.00" l-i 8705' 13-1/2" BKR FL4S 3' PUP, 10 = 2.88" 1-1 8711' 14-112" lEG, 12.6#, L-80, .0152 bpf, 10 =3.958" 1-1 8783' PERFORATION SUMMARY RS= LOG: SÆRRY -SUN MWO RESISllV 11Y ON ANGLEA TTOP ÆRF: 87 @ 9968' I\bte: Refer to A-oduction DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DATE 2" 6 9968 - 9998 0 08/26/01 2" 6 10095 - 10132 0 08/26/01 2" 6 10175 - 10206 0 08/26/01 17-5/8" CSG, 29.7#, NT-95-HS, 10 = 6.875" 1-1 9518' DATE 11/17/94 08/26/01 04/11/01 10/02101 02104/04 REV BY COMMENTS KSB ORIGINAL COMPLETION CTD SIDETRACK CH/KA K CORRECllONS CHffP CORRECllONS GRCffLP CSG - GRADE CORRECfIONS M-38A I I ~ /cf7~O 1 8677' I g )Í :8: z:;: ! , ~ 8698' 8703' 8714' 8738' 8772' 8784' 8783' ( SAFETY NOTES: WELL ANGLE> 70° @ 9040' & > 90° @ 9070'. 2097 H4-1/2" OTIS X NIP, 10 = 3.813" 1 1--14-1/2" OTIS X NIP, 10 = 3,813" 1 1--14-1/2" BKR KB LNR TOP PKR, 10 = 2.56" I-iTOP OF BKR LOO\ TOR SUB, 10 = 2.39" I 1-i3-1/2" X 3-3/16" LNRXO, 10 = 2.80" I 1-\7-5/8" X 4-1/2" TIW I-13BPPKR,IO = 3.901" 1 1-14-1/2" OTIS X NIP, 10 = 3.813" I 1-14-1/2 lEG TAIL I I-iELMD TT LOGGED 01/18/95 I 7-5/8" MLLOUTWINOOW 8858' - 8863' 8855' I-1TOPOFWHIPSTOO< 1 8865' I-iRA TAG 1 l-i 3-3/16" LNR, 6.2#, L-80 TC2, .0076 bpf, 10 = 2.80" I 8904' 1-i3-3/16"X 2-7/8" LNRXO,ID =2.372" I FEW 1-1 10235' \2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, 10 = 2.372" DATE REV BY COMMENTS PRUDHOEBAY UNIT WELL: M-38A ÆRMIT I\b: 2011320 APII\b: 50-029-22519-01 SEe 1, T11 N, R12E, 2437' FSL & 605' FEL BP Exploration (Alaska) 01/22/04 Schlumberger NO. 3095 Alaska Data & Consulting Services Company: State of Alaska 3940 Arctic Blvd, Suite 300 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color (' Well Job # Log Description Date Blueline Prints CD D.S. 06-02\ ':::¡--=(. ,rYi-9( 10874399 PROD PROFILE 11/22/03 1 E-35A ;Ð[j' ~. \ \ q 10715373 MEM PROD PROFILE 12/27/03 1 P1-06 \ q (J'- \ ~-:>; v=¡.. 10703984 PPROFILE/DEFT/GHOST 12/24/03 1 D.S.15-49A 1~fí'.V')-. J ~' 10679043 LDL 12/23/03 1 M-38A ,t¿1("') I ... I ~~ 10709678 LDL 12/25/03 1 D.S.09-15 ) '-::¡..., -c "'-{T íJ 10709680 STATIC SURVEY 12/27/03 1 X-27 ,'~ q --t)l r;q 10679046 LDL 01/08/04 1 'Y I t \. ."" ",,',,""," <'J, ,,'.. ,,,",'I:',',, "..:~,,' :' ,'"(,,'j:':',,.,,,,,~\, ,,:"",': PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Schlumberger GeoQuest Petrotechnical Data Center LR2-1 RECEIV D 3940 Arctic Blvd, Suite 300 900 E. Benson Blvd. ' , E Anchorage, AK 99503-5711 Anchorage, Alaska 99508 ' ATTN: Beth I ^ ~;I '7 C "004 -"~._,,. """". , D t D I" d ~¡ \Il .J .' L. . ..~ \ \ '\ ' a e e Ivere : Received by: "'; (~1 \...( AI" '¡~ C:d~'\_~.t'>V:\ AJa,ka OU & Gas Cons. Commiliufi Andøage @Q/;~ij~~~Jftl:; F £13 0 3 2004- " \ ( M-38A (PTD #2011320) Leak Detect Results Subject: M - 38A (PTl) #20 11320) Leak Detect Results F",'"r,om""":"",",D"',,,,,u,"""b"e"'".",,A nn"a""""T"','"'",,,,',<,,An,,'" n,a""".",D""U""b,."",e""@""""",B,P""."",.",C""o, m"""..>", "',,. ,'.""~""."".""'."""".. ....1, "".,."G".,'",ò3,"","", Date: Fri, 26 Dec 2003 17:40:30 -0900 ' " l/l'Vt '" '" , , ' " , ~ ,., ' , To: "AOGCC Jitn Regg{E~mai1)"'<JiIÎ1~Regg@admin.state~ak.us>, "Aodcc Winton Aubert (E-mail)" <Winton_Aubert@admin.state.ak.us>, "AOGCC Bob Fleckenstein (E-mail)" <Bob ýleckenstein@admin.state.ak.us> ' CC: "NSU, ADW'Well Operations Supervisor'" . <NSUADWWellOperationsSupervisor@BP.com>, "Engel, Harry R" <EngeIHR@BP .c.om> Hi Jim, Winton, & Bob, A leak detection log was completed on M-38A (PTD #2011320) indicating a possible production casing leak at 4780' md. Work will continue to complete an Application for Sundry for a PC leak. Please let me know if you have any questions. Thanks, Anna Dube Well Integrity Engine~r ,GPB Wells Group. " Phone: ( 907 ) 659 -5102 Pager: (907) 659-5100 xl154 SCANNED DEC ~,l2003 1 of 1 12/29/2003 8:41 AM Permit to Drill 2011320 MD 10270 ""'"' TVD DATA SUBMITTAL COMPLIANCE REPORT 8~25~2003 Well Name/No. PRUDHOE BAY UNIT M-38A Operator BP EXPLORATION (ALASKA) INC 8726 ''?/' Completion Dat 8/27/2001 ~ Completion Statu WAGIN Current Status WAGIN APl No. 50-029-22519-01-00 REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Mud Log N__9 Sample N._9 Directional Survey N._~o ................................. ' ~-~-~'~-~--'~'~-~'~---~ .... .~--------~_~'--~'~---_ ~-~ ' ~_'~'-~'~ -_-'" i~_'~_~T- ~ ~-~ _L' -~'- - 2~ ~'- ~'~ ~-¥~- ~__ .~-~. _~-_~- -_~' _-~ (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number Comments -E"I~' D D Rpt Rpt Te Temperature Pre Pressure Ver LIS Verification Ver LIS Verification Ver LIS Verification Ver LIS Verification Pdf Cn See Notes ,EI~ C Pdf Cn See Notes ~ C Asc Ver LIS Verification ~/ C Pdf GR Gamma Ray Directional Survey PB1 TEMPURATURE / PRESSURE Directional Survey PB1 Directional Survey Directional Survey FINAL oh 9/27/2001 Directional Survey digital data FINAL 8992 10222 CH 9/17/2001 ~.~'0272 8992-10222 DIGITAL DATA 8992 10222 Open 9/17/2001 /-~272 8992-10222 FINAL 8992 10222 CH 9/17/2001 8992-10222 BL, SEPIA FINAL oh 9/27/2001 Directional Survey paper copy FINAL oh 9/27/2001 Directional Survey Paper copy FINAL oh 9/27/2001 Directional Survey digital data final 8700 10225 Case 11/20/2001 ~13"446 final 8700 10225 Case 11/20/2001 /-'1~446 1 8840 9291 Open 12/18/2002 c.~rfl'383 PB1 1 8840 10224 Open 12/18/2002 ~,,t1384 1 8840 10224 Open 12/18/2002 1 8840 9291 Open 12/18/2002 PB 1 8869 9326 Open 5/13/2003 ¥~r738 ROP log / Gamma Ray: MD/TVD images in .emf, .tif, and .pdf with .emf viewer ROP log pbl ROP log / Gamma Ray pbl 8869 9326 Open 8840 10235 Open 8869 9326 Open 5/13/2003 ~-'¢'1739 5/13/2003 C-1~738 5/13/2003 ~,'1~1739 Well Cores/Samples Information: Permit to Drill 2011320 MD 10270 TVD 8726 Name DATA SUBMITTAL COMPLIANCE REPORT 812512003 Well Name/No. PRUDHOE BAY UNIT M-38A Operator BP EXPLORATION (ALASKA)INC Completion Dat 8/27/2001 Completion Statu WAGIN Current Status WAGIN Interval Dataset Start Stop Sent Received Number Comments APl No. 50-029-22519-01-00 UIC Y ADDITIONAL INFORMATION Well Cored? Y/~ Chips Received? ~' 1 N Analysis ~ R ~.r.~.ive. d'~ Daily History Received? ~ N Formation Tops ~ Comments: Compliance Reviewed By: ................ _~._~_ WELL LOG TRANSMITTAL To: State of Alaqka Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs M-38A & M-38A PB 1 January 15, 2003 AK-MW-11124 M'38A: Digital Log Images: 50-029-22519-01 ,,,,M-38A PBI: Digital Log Images: 50-029-22519-70 1 CD Rom 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT By' SIGNING, AND RET~G ~ AT~ACHED COPIES OF THE TRANSMITTAL LETTER TO THE ,ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed~. -~/~(~5~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 74 Avenue, Suite 100 Anchorage, Alaska December 16, 2002 RE: MWD Formation Evaluation Logs M-38A, AK-MW- 11124 1 LDWG formatted Disc with verification listing. API#: 50-029-22519-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Cemer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 16, 2002 RE: MWD Formation Evaluation Logs M-38A PB1, AK-MW- 11124 1 LDWG formatted Disc 'with verification listing. API#: 50-029-22519-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING. AND RETURNING, A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 iBP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 iE. Benson Blvd. Anchorage, Alaska 99508 Date: .. r,""'" !:ì'~'" [Jt" ¡ " J' . . '. .......'~' fJ"""i ,',' ":r,t..:,~"".-~\"""",, "',,',', ":;':,,",:~;:,, ,t', ,,' "ii'" ø~~ ':,,: \;~,'2\, ..'~~~", BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Tom Maunder, P. E. Petroleum Engineer State of Alaska Oil & Gas Conservation Commision Date: Dec 5, 2001 From: Bryan McLellan Petroleum Engineer BP Exploration, Alaska l""'i '"" ,,'o.':" ::., ...fI''''~ ~ ;= \ F' t ¡,,: ¡ ~ I ¡: L,,, "", " 1, ~, ' ~"\ ... i"',,of ¡} l ,t, ~ " It4.u ~\. Subject: M-03Ai and M-38Ai Cement Intearitv ~ . ~ ift)\-\.~:;} Tom, d.~( - \'--\'\ -:' ¡ :,,,.,. . , ";i__'~¡ 0 20 1 llJJ~!(':¡ (. -. O! 'w, <2 Uii G( (j;¡,-, " "'.I \..-Go,> '. ,AfJCborag~ LommíSSiO¡1 Please find enclosed the following 4 logs confirming cement integrity in wells M-03Ai and M- 38Ai. 1) M-38Ai Temperature Pressure Run 2-Sep-01 2) M-38Ai Temperature Pressure Run 10-0ct-01 3) M-03Ai Temp. Log & Jewelry Log Run 10-Sep-01 4) M-03Ai Temperature Pressure Log Run 07-Nov-01 The purpose of running these logs was 1) to confirm cement isolation to the perforated interval and 2) for reservoir surveillance, to observe what portions of the reservoir have already experienced cooling and to observe which perforation intervals are taking fluid. The plan, agreed to by the AOGCC, was to first run a baseline temperature log prior to injection (see enclosed e-mail correspondence). After injecting for approximately 1 month, a temperature warmback log would be run and compared to the baseline temperature log. If fluids are injecting uphole of the perforations via a cement channel, the temp warmback log should clearly indicate this. The baseline temperature log will indicate any temperature anomalies that were caused by other injectors in the area, prior to drilling M-03Ai or M-38Ai. Deviation from the normal procedure of running a wireline conveyed cement bond log through the window was done for the following reasons: 1 ) A lost circulation zone was experienced while drilling the new injector, uphole of the perforation interval. Therefore, cement integrity in the vertical section above this LC zone is qUE3stionable. Good cement is anticipated between the LC zone and the perf intervals, however, a wireline conveyed cement bond log would not be able to reach beyond the lost circulation zone due to the high angle of the wellbore. 2) A coil tubing E-line unit was not in operation on the slope, and obtaining a CTE-line bond log could not be done without considerable expenditure and time. 3) A temperature warmback would be more conclusive about the point of injection than the cement bond log. These logs will also provide valuable information about injector conformance and previously swept zones in the reservoir. The results of the logs suggest that the wells are injecting into the appropriate intervals in the reservoir. There is no cooling uphole of the perfs that can not be explained by the pre- -' injection temperature baseline. This evidence shows that with some degree of certainty, the perforation intervals are isolated from uphole. These wells have, at the request of the AOGCC, been put on a monthly monitoring list so that the pressure and rate will be reported to the commission on a monthly basis. The purpose of reporting this data is to establish a normal operating envelope, where any deviation from the normal injection conditions could warrant further investigation. This reporting will continue indefinitely until the AOGCC is satisfied that there is no need to continue. If you would like to discuss the results of these logs in person, I would be happy to come to your office at your convenience. Please do not hesitate to call at 564-5516. Sincerely, Bryan McLellan ~~ McLellan, Bryan J From: Sent: To: Subject: Tom Maunder (tom_maunder@admin.state.ak.us) Wednesday, October 03, 2001 9:09 AM McLellan, Bryan J Re: M-38Ai Temp warm back. ~ Card for Tom Maunder ;!~JZ'~'2:/(::f Sounds good Bryan. I will look forward to your update. - Torn "McLellan, Bryan J" wrote: t) r- '\~ .t:~~ ß:~ ,~ fI¡ ,.'~' po., I~"". ~~ ~ -/~' I:, ~ I .il'"" . - . - '~ iJ cù > Torn, > FYI > All the injectors at M-pad were shut in for the GC-2 shutdown for 9 days in > September, so I am going to delay the Temp warmback on M-38Ai until mid > October. M-38Ai started injecting on 9/5/01. > > M-03Ai has still not corne on line yet. I plan to get the SRT on M-03Ai 1 > month after first injection. > > I'll keep you updated. > > Thanks, > Bryan McLellan > > > > > Bryan McLellan BP Exploration, Alaska Production Engineer (907) 564-5516 1 McLellan, Bryan J From: Sent: To: Subject: Tom Maunder [tom_maunder@admin.state.ak.us) Friday, September 07,2001 11 :41 AM McLellan, Bryan J Re: M-38Ai cement integrity ~ Card for Tom Maunder Bryan, Thanks for bringing the information over on M-38Ai. is similar to the diagnostics planned for M-03Ai. I acceptable and you have approval to proceed. I look in early October to review the results. Tom Maunder, PE Sr. Petroleum Engineer AOGCC As you note, the proposal concur that your plan is forward to getting with you "McLellan, Bryan J" wrote: > Tom, > BP recently drilled a new coil tubing sidetrack (M-38Ai) from well M-38i in > Prudhoe Bay. There was no cement bond log run in the original well, and we > can not conclusively confirm or deny the presence of good cement above the > sidetrack window. > > This well is in a very similar situation as M-03Ai, which you and I > discussed in person a few weeks ago (our correspondence is attached below) . > > I would be happy to bring the logs and drilling reports over to discuss this > well in person if you would like, but here is what we are proposing to do: > > In order to confirm cement isolation in M-38Ai, BP would like to follow the > same procedure that you and I agreed to in M-03Ai. We will run a baseline > temperature log in the well prior to establishing injection (we have already > run this log). This log will identify any cooling that may already have > occurred in the reservoir from other injectors in the area. BP will then > establish produced water injection for a period of approximately 1 month, > and then run a temperature warm-back log from the window down to TD. > > > > > > If there is no sign of cooling above the perf intervals, we can conclude > that there is no injection above the window. > > > > > > > > > > > Please let me know if this proposal is acceptable to you. If you would like > to see the open hole logs and temperature baseline log before making a > decision, I will be happy to bring those to your office. Feel free to call > me with any questions at 564-5516. Once injection is established, the well will be placed on a monthly monitoring list to ensure that the pressure and rate are monitored and reported. Note: We are deviating from the normal procedure of running a wireline conveyed cement bond log through the window for the following reason: A lost circulation zone was encountered in the new sidetrack at about 400 feet outside the window, and no cement is expected above that point (the shallowest perf interval is 1100 feet outside the window). Wireline can not reach the loss zone with a CBL because the deviation is too great. There are no memory CBL logs that could be run on coil tubing on the slope yet and we do not have a coil tubing e-line unit running right now. > 1 > Thank you, > Bryan McLellan > Production Engineer > BP Exploration > (907) 564-5516 > > -----Original Message----- > From: Tom Maunder [mailto:tom_maunder@admin.state.ak.us] > Sent: Wednesday, September 05, 2001 3:43 PM > To: McLellan, Bryan J > Subject: Re: Cement integrity in M-03Ai > > Brian, > My apologies for not getting this note back sooner. Your proposal is an > acceptable method to determine the isolation. I only have 2 recommended > changes. > 1--I would prefer that the temperature log be run as near 1 month as > practical. > 2--Contact Joe Anders and Kevin Yeager to place this well on the monthly > monitoring list. This will assure that the rate and injection pressure is > monitored and then reported. A graph of the pressure versus rate can be > used to > develop an operating envelope for the well which can be used as a diagnostic > tool to confirm injection performance. > > Good luck with the testing operation. Please call with any questions. > > Tom Maunder, PE > AOGCC > > "McLellan, Bryan J" wrote: > > > Tom, > > As we discussed yesterday, BP recently drilled a coil tubing sidetrack > > (M-03Ai) from well M-03i in Prudhoe Bay. The results of the cement bond > log > > in the original well bore are inconclusive, and can not definitively > confirm > > or deny the presence of good cement above the sidetrack window. > > > > > > > > > > > > > > > > > > > > > > > > > > Note: We are deviating from the normal procedure of running a wireline > > conveyed cement bond log through the window for two reasons: 1) A lost > > circulation zone was encountered in the new sidetrack at about 100 feet > > outside the window, and no cement is expected above that point. Wireline > > can not go beyond the LCZ because the deviation is too great. 2) We do > not > > currently have a coil tubing e-line unit running, and there are no memory > > cement bond logging tools on the slope. We therefore can not log past the > > lost circulation zone with coil tubing. > > > > Does the AOGCC approve of the above method for demonstrating cement > > isolation in Prudhoe Bay well M-03Ai? > > > > Thank you, > > Bryan McLellan > > To confirm cement integrity above the window, we plan to run a baseline temperature log prior to injecting any fluid in the well. We will then establish produced water injection for a period of 1 - 2 months before running a temperature warmback log. If any fluid is injecting above the window, the warmback log will clearly show cooling in the reservoir at the depth of injection. If no cooling is observed uphole of the window, cement integrity will be confirmed and injection will continue. If uphole cooling is observed, remedial action will be taken prior to comencing injection. 2 M-38 resume operations Subject: M-38 resume operations Date: Tue, 21 Aug 2001 19:59:27 -0500 From: "Endacott, Mary SII <EndacoMS@BP.com> To: "Tom Maunder (E-mailt<tom_maunder@admin.state.ak.us> CC: IIHubble, Terrie L" <HubbleTL@BP.com> Tom Nordic 1 has returned to M-38 to resume sidetrack operations. Ref: Operation shut down Sundry No. 301-222 (requesting emait notice when operations resume). Original Sundry No. 301-180 API No. 50-029-22519-01 Mary S. Endacott BP Coil Tubing Drl9 Engr 907 -564-4388 endacoms@bp.com 1 of 1 d()\-\~~ 8/23/01 8:38 AM M-38A sundry and permit ;¡ dOJ-13~ Subject: M-38A sundry and permit Date: Mon, 2 Ju12001 20:20:56 -0500 From: "Cubbon, John R" <CubbonJR@BP.com> To: "'j ulie _heusser@admin.state.ak.us'" <julie - heusser@admin.state.ak.us> CC: "Cubbon, John R" <CubbonJR@BP.com>, "Kara, Danny T" <KaraDT@BP.com> Julie, I respectfully request, on behalf of BP, that the sundry and permit for the M-38A sidetrack be expedited so that work can begin on July 3, 2001. The reason for this request is due to logistical problems with obtaining necessary equipment to start work on wells that have already been approved by the AOGCC. If you have any further questions, please don't hesitate to call me. Best Regards, John R. Cubbon BP - Coil Tubing (907) 564-4158 (907) 240-8040 cubbonjr@bp.com Drilling Engineer " VCLN t I.a" Prep UJG'rlG- for c,-- $1, d1\ttt 1/3)0) 1 of 1 7/3/01 1:56 PM WELL TFIA $MITTAL 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. P, O. Box 1369 Stafford, TX 77497 BP Exploration [Alaska), Inc. Petr. otechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LoG DIGITAL MYt~R / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S ) OR CD-ROM F~LM COLOR __ Open Hole I I 1 M-38Ai 10/30/01 Res. Eval. CH I I 1 Mech. CH 1 Caliper Survey Signed · Print Name: Date · RECEIVED NOV 2O 2001 AJaSka Oil & Gas Cons, Commis~bn Ancl~rage ProActive DiagnosTic SErViCES, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-'mail: pdsanchorage~memorylog.com Website: ._.W....W_W..J..n.~!.~.Lo._r.y.!.o_g,...c_9.!.n.. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor Chair ~y~o~. BJECT: THRU: Tom Maunder'J~ P.I. Supervisor DATE: November 10, 2001 FROM: Jeff Jones Petroleum Inspector NON- CONFIDENTIAL Mechanical Integrity Tests BPX M Pad M-03A, M-38A PBU , PBF Packer Depth Pretest Initial 15 Min. 30 Min. WellI M-03A I Typelni. I S I T.¥.D. 17807 I Tubin~ll 1675 I 1675 I 1675 I~ I lntervall O P.T.D.I 2011470 ITypetestl P ITestpsil 1952 I CasingI 1000I 2500I 2490I 24901 P/F I _P Notes: Post coil tubing workover MIT. WellI M-38A 'lTypelni. I S I T.V.D. I~ I Tubin~l 750 I 800 I 8'00 I 800 I lntervall O P.T.D.I 2011320 ITypetestl P I,Testpsil 2113 ICasin~lI 40I 25oo1 24501 24501 P/F Notes: Post coil tubing workover MIT. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Saturday~ November 10, 2001: I traveled to BPX's M Pad in the Prudhoe Bay Field to witness post' coil tubing workover MIT's on wells M-03A and M'38A. The pretest pressures were monitored for 30 minutes and found to be stable. The standard annulus pressure test was then performed with both wells passing the MIT's, M.I.T.'s performed: 2 Number of Failures: Attachments: wellbore schematics ( 2 ) Total Time during tests: 2.5 hfs cc: MIT report form 5/12/00 L.G. MIT PBU M-03A, M-38A 11-10-01 JJ.xls 12/2/01 i 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 7. Permit Number BP Exploration (Alaska) Inc. 201-132 301-222 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~,~:,~. 50-029-22519-01 4. Location of well at surface 9. Unit or Lease Name 2438' NSL, 605' WEL, SEC. 01, T11N, R12E, UM Prudhoe Bay Unit At top of productive interval .,.~ 1359, NSL, 1136, EWL, SEC. 06, T11N, R13E, UM At total depth ....................... ~;:. ~~. 10. Well Number 1462' NSL, 346' EWL, SEC. 06, T11 N, R13E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 56.10' ADL 028282 I I'"' °r~,~,,~001 8,27,2001 115' water depth' if °fish°re N/A, SL 116' N°' °f C°mpleti°ns One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 10270 8726 FTI 10235 8726 FTI [] Yes [] NoI (Nipple) 2097' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, ROP, GR, RES, CNL 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 30' 110' 30" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# NT80LHE 30' 3110' 13-1/2" 1231 sx CS iii, 375 sx Class 'G' 7-5/8" 29.7# NT95HS 27' 8858' 9-7/8" 1038 sx Class 'G' 3-3/16,,x 2-7/8,, 6.2# / 6.16# L-80 8698' 10270' 3-3/4" 98 sx Class 'G' 24. Perforations open to Production' (MD+TVD of'Top and 25. ' '' TUBING RECORD Bottom and interval, size and number) ....... S~'E ' DEPTH SET (MD)' PACKER SET(MD) 2" Gun Diameter, 4 spf ........ 4~1/2", 12.6#, L-80 .... 8784' '8738' MD TVD MD TVD 9968' - 9998' 8693' - 8694' 10095' - 10132' 8697' - 8702' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 10175' - 10206' 8709' - 8715' DEPTH INTERVAL (MD) AMOUNT & K~ND OF MATERIAL USED 2000' Freeze Protect with 23 Bbls of MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 5, 2001 Water 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. RECEIVED OCT 1 0 ZOO1 Alaska 0il & Gas Cons, Commissior~ .... Anchorage 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. Shublik 'A' 8858' 8571' Shublik 'B' 8905' 8616' Shublik 'C' 8930' 8639' Sadlerochit 8950' 8656' 45N 8994' 8688' 45P 9007' 8695' RECEIVED OCT 1 0 2001 Alaska Oil & Gas Cons. Commission Anchorage 3-1. List 6i'~ttac'l~'m~nts: .... Sum'mary"of Daily' Drilling Reports, Surveys ....................... 3~. I I~ereby certifY"thai th"e'fore, g0ing is true and correct to the best of my knowledge Signed TerrieHubbl .e~~/~ ~ Title TechnicalAssistant , ,.Date M-38Ai 201-132 301-222 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. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 BP EXPLORATION Page i of 14 Operations Summa Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: REENTER+COMPLETE Start: 7/18/2001 End: 8/27/2001 Contractor Name: NORDIC CALISTA Rig Release: 8/27/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours !Activity Code NPT Phase Description of Operations 7/18/2001 !00:00 - 00:45 0.75 MOB P PRE Continue move from price pad to M pad in the WOA. Arrive at M-pad. 00:45 - 01:15 0.50 MOB P PRE Pad inspection with pad operator. 01:15 - 02:30 1.25 MOB i P PRE Safety meeting with rig hands prior to moving on well. 02:30 - 03:15 0.75 MOB P PRE MIRU, begin nippling up at 02:30. Accept rig. 03:15 - 05:00 1.75 BOPSUF P DECOMP Tree nippled down and BOP stack 1/2 nippled up. Just recieved notice that we are on a field wide stand down due to incident on rig 7. Finish nippling up tree first. 05:00- 08:45 3.75 BOPSUF N WAIT DECOMP Standby. 08:45 - 09:00 0.25 BOPSUR P DECOMP Safety mtg re: hi press test 09:00 - 16:30 7.50 BOPSUR P DECOMP Test BOPE. Witness waived by AOGCC 16:30- 18:00 1.50 RIGU P DECOMP PU injector. Install DS CTC 18:00 - 19:30 1.50 RIGU P DECOMP Pull test CTC. 19:30- 00:00 4.50 RIGU N SFAL DECOMP Fix computer problems. Needed to get parts and personnel from Deadhorse. Problem appears to be in computers/cards/wiring that was changed out during summer shutdown. 7/19/2001 00:00- 02:30 2.50 RIGU N SFAL DECOMP Continue working on Schlumberger computer system. No depth, flowrate, micromotion data, etc. 02:30 - 03:00 0.50 RIGU P DECOMP DS computer system repaired. Pump dart to fill coil and get coil vol. 59.3 bbls vol. 03:00 - 03:10 0.17 S'I'WHIP P WEXIT Pressure test hard line 03:10 - 03:30 0.33 STWHIP P WEXIT Safety meeting prior to making up BHA. 03:30 - 04:15 0.75 STWHIP P WEXIT Make up memory logging BHA. 04:15 - 06:45 2.50 STWHIP P WEXlT RIH with memory logging BHA (80.9' OA) 06:45 - 08:30 1.75 STWHIP N SFAL WEXIT Park at 8590' to fix wt cell after a few wt chks indicated inconsistency. Set upper slips. Adj gooseneck forward. Test, ok. PUH to 8100', swap to gen #2 after rig saver was found ,on~ 08:30 - 09:00 0.50 STWHIP P WEXIT Log down from 8100' @ 30'/rain 09:00 - 09:30 0.50 STWHIP P WEXIT Tag at 8772' CTD. PUH logging at 30'/min, 40K. Flag at 8600' EOP 09:30 - 10:30 1.00 STVVHIP P WEXIT POOH 10:30 - 12:00 1.50 STWHIP N RREP WEXIT Park at 3134' to repair blown injector hose (big one). All fluid contained. 12:00- 12:30 0.50 STWHIP P WEXIT POOH 12:30 - 12:45 0.25 STWHIP P WEXIT LD GR/CCL. Download data. Flag is at 8595' EOP ELMD based on PFC GR/CCL of 1/18/95. PBD tag was at 8766' ELMD 12:45 - 13:30 0.75 STWHIP N SFAL WEXIT Level up rig on drillers side. Fine tune wt indicator(s), but can't sync 13:30 - 14:10 0.67 STWHIP P WEXIT MU milling BHA (3.80" used D331 dia pilot mill w/1~3 deg motor) , 14:10 - 16:35 2.42 STWHIP P WEXIT RIH w/window milling BHA#1 (130.77 OA). SHT 16:35-17:00 0.42 STWHIP P WEXIT Correct to flag -l.7' at 8725.8'. CheckTF@31R. Orientto Iow side 17:00 - 17:10 0.17 STWHIP P WEXIT RIH at 178R reaming from 8725' and see stringers from 8762' 2.6/2400. Stall at 8782'. TF moved to 61L 17:10 - 17:50 0.67 STWHIP P WEXIT Orient around 17:50 - 18:05 0.25 STWHIP P WEXIT Mill firm cement to 8790' 2.6/2400/149R and TF reactive was 50 deg ' 18:05 - 18:30 0.42 STWHIP P WEXIT Orient to Iow side. Drill to 8800' 18:30 - 18:55 0.42 STWHIP P WEXIT Re check flag at 8595' EOP. Should be 8726' bit depth ELM. Printed: 10/5/2001 2:50:49PM BP EXPLORATION Page 2 of 14 Operations Summa Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: REENTER+COMPLETE Start: 7/18/2001 End: 8/27/2001 Contractor Name: NORDIC CALISTA Rig Release: 8/27/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity;Code NPT Phase Description of Operations 7/19/2001 18:30 - 18:55 0.42 STWHIPIP WEXIT Double checked, and it was on depth. Double checked length of BHA's. All checked ok. RIH to flag pipe. Put new flag on pipe at 8660' EOP, should be 8790.8' bit depth ELM. RIH to resume drilling. 18:55 - 19:00 0.08 STWHIP P WEXIT Tag at 8800', resume milling. Orientation 180 deg. started walking around. 19:00 - 19:40 0.67 STVVHIP P WEXIT Orient to 165L and try it again. 19:40 - 20:10 0.50 STWHIP P WEXIT Resume milling. 2.8/2.8, 2700 free spin, 3000 milling, ReP about 65 fph. Does not seem to be very hard cement. 20:10 - 20:20 0.17 S'I'WHIP P WEXIT Milled fairly easily to 8830', last ReP was down to 50 fph from 65 at top of cement. Not real hard cement. Will continue with program regardless. Orient around to 02L. 20:20 - 21:00 0.67: S'I'WHIP P WEXIT Mill cement at 0deg. Start ramp at 8830', mill to 8836.7', started getting erratic tool faces. Suspect we are against liner on bottom of ramp. Pump sweep of 2# biozan. 21:00 - 21:20 0.33 S'I'WHIP P WEXIT Circulate sweep around to clean hole prior to POOH. 21:20 - 23:00 1.67 STVVHIP P WEXIT POOH. Chasing sweep with 1/2# bio water. 23:00 - 23:30 0.50. STVVHIP P WEXIT Tag up at surface, lay down pilot hole BHA. 23:30- 00:00 0.50 STWHIP N WAIT WEXlT Standby on motor. 7/20/2001 00:00 - 00:20 0.33 STWHIP N WAIT WEXIT Wait on 2.5 deg Weatherford motor. 00:20 - 00:50 0.50 STWHIP P WEXIT MU BHA #3, 2.5 deg WF motor, HC 1 step window mill. 00:50 - 03:10 2.33 STWHIP P WEXIT RIH with BHA #3 to time mill window. 03:10 - 03:35 0.42 STWHIP P WEXIT Check flag at 8660' EOP, make -4.1' correction. PUH to above pilot hole. Orient to 10R. 03:35 - 03:45 0.17 S'I'WHIP P WEXIT RIH, tag up at 8834'. Left at 8837'. Tag a 2nd time at 8834'. PU 10', kick on pumps. 2.7 bpm, 2930 psi. RIH tag at 8833.2' with pumps on. 03:45 - 06:45 3.00 STVVHIP P !WEXIT Remove 1' from tag as per proceedure. Begin time milling window. Window top started at 8833', CTP=3150 psi. 06:45 - 10:50 4.08 STWHIP P WEXIT .Back to flag at 8833'. Mill by schedule 10:50-11:15 0.42 STWHIP P WEXIT - 8836'. Begin adding wt. Get to 8837.1' and TF was15L. 11:15 - 12:00 0.75 STWHIP P :WEXIT Orient around twice to get TF high right side, but flops to 901:{. Had minor overpulls when back at TD checking TF. 12:00 - 13:00 1.00 STWHIP P WEXIT Mill from 8837.5' at 15L Get a click and TF moved to 64R. Stick with it and no reactive to 8839'. Continue milling w/5K WeB and 200-400 diff and acts like formation. TF moving up to 35R. Looks like complete exit from liner occurred at 8837.3'. Getting lots of metal at shaker 13:00 - 13:40 0.67 STWHIP P WEXIT Mill to 8850' at 2.5/3000/2R at end. GR shows we are about 6' deeper than planned (probably some stretch due to new pipe). PUH 36K slow thru window, clean. Found flag at 8833' still on depth 13:40 - 15:10 1.50 STVVHIP P :WEXIT POOH slowthru sheath, clean. POOH 15:10- 16:30 1.33 STWHIP P WEXIT Standback 2 jts PH6. LD motor and mill. Mill had center wear and was 3.80" and in good shape. MU 1.75 deg adj motor and 3.78" tapered mill on MWD assy. Replace O-ring on injector hose 16:30- 18:10 1.67 STWHIP P WEXIT RIHw/BH^#4, SHT 18:10 - 18:30 0.33 S'I'WHIP P WEXIT Correct at flag to 8768.02'. Chk TF 2.5/2850/18R. RIH at min rate w/a few bobbles and set down at 8838'. Start motor and chk TF @ 106R 18:30 - 18:45 0.25 STVVHIP P WEXIT PUH and orient above ramp to high side 18:45 - 19:00 0.25 STWHIP P WEXIT Pre mill window safety meeting. Discuss proper way to dress Printed: 10/5/2001 2:50:49 PM BP EXPLORATION Page, 3 of 14 Operations Summa Report 'Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: REENTER+COMPLETE Start: 7/18/2001 End: 8/27/2001 Contractor Name: NORDIC CALISTA Rig Release: 8/27/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours ActivityCode NPT Phase Description of Operations ..... 7/20/2001 18:45 - 19:00 0.25 S'I'WHIP P WEXIT window w/o damaging cement ramp. 19:00 - 19:40 0.67 S'I'WHIP 3 WEXlT Dress window with crayola mill (3.78" OD). RIH at 2 fpm, hang up at bottom of window, 8837' CTM. Dress same. Holding tool face at 6 to 12 R. Originally milled at 13R. Cleaned up lip at bottom of window ok. Made it to 8851', same depth as on last run. Back ream up 4 times, no work or stalls. RIH dry through window 2 times, no problems. Pump 10 bbls of 2# biozan sweep. 19:40 - 22:10 2.50 STWHIP P WEXIT POOH with wiindow dressing BHA. 22:10 - 23:00 0.83 S'I'WHIP P WEXlT Tag up with BHA #4, swap out to build section BHA 2.83 deg motor, MO9 bit. 23:00 - 00:00 1.00 STWHIP'N SFAL WEXIT Schlumberger electronic weight indicator still not working properly. Source of down time on each of last 2 morning reports. A temporary repair was made that evidently has fixed the problem. (After 3 days!) 7/21/2001 00:00 - 01:50 1.83 STWHIP P WEXIT RIH with BHA #5, first build section BHA. Baker 2.83 deg motor, Smith M09 3.75" bit. 01:50 - 02:10 0.33 STWHIP P WEXIT Catch flag make -6.5 correction. Orient to high side. RIH 02:10 - 02:50 0.67 STWHIP P WEXIT RIH with TF=0 deg. Set down gently at the bottom ofthe window 3 times. Picked up, got 1 click, and were able to run through window smooth. Swap to mud, and circ in. 02:50 - 04:00 1.17 STVVHIP P WEXIT Begin drilling build section from 8851', 2.6 in, 2.2 out, 3200 psi free spin. Losing 0.4 bpm. 04:00 - 05:00 1.00 STWHIP P WEXIT 8869', getting lots of solids back. Plugged the micromotion with a handful of walnut sized chunks of cement. 05:00 - 06:00 1.00 STWHIP P WEXIT 8884', 05:00 update, Difficult holding tool face. Having to orient frequently after drilling only a 1 or 2', it flops around. 06:00 - 06:20 0.33 S'I'WHIP P WEXIT Log tie in pass. Add 6' to depth. Window now at 8839'-8843.7' 06:20 - 07:00 0.67 STWHIP P WEXIT Drill to 8913' at 2.6/3500/60R and had a number of stalls to 8915'. Cruise w/no diff to 8918'. 3 hard stalls at 8920'. MWD shows angle simlilar to prior wellbore, no az. Lots of cement chunks over shaker. Out MM is bypassed due to trash 07:00 - 07:15 0.25 STWHIP N DPRB WEXIT Cuss 'n discuss w/Mary. Not sure if we're inside or outside 7-5/8" casing, but definitely tracking based on angle. No mechanical WS available so will cement and start over 07:15 - 08:45 1.50 STVVHIP N DPRB WEXIT POOH. Flag at 8700' EOP 08:45 - 09:30 0.75 s'rWHIP N DPRB WEXIT LD drilling BHA. Bit was 1-3-1. All MWD offsets checked ok 09:30- 09:50 0.33 STVVHIP N DPRB WEXIT MU cement nozzle BHA 09:50 - 11:30 1.67 STWHIP N DPRB WEXlT RIH w/BHA #6 11:30 - 12:00 0.50 STWHIP N DPRB WEXIT Tag at 8921' CTD. Incr pump rate to jet any remaining solids OOH while PUH to flag. Corr -3.0' Safety mtg re: cmt 12:00 - 12:45 0.75 STWHIP N DPRB WEXIT Cuss n' discuss w/D Hearn 12:45 - 13:50 1.08 STWHIP N DPRB :WEXIT DS pump 2 bbls FW. PT 3500 psi after replace failed O- ring. DS load CT w/10 bbls 17 ppg G cement. Displace w! 2 bbls FW followed by FIo Pro mud. RIH. Plugged 'out' MM again. Found two cement chunks with rounded outsides stained with MI mung indicating they came from inside the liner 13:50 - 14:05 0.25 STWHIP N DPRB IWEXIT Noz @ 8915'. POOH after 2 bbls out noz at 1.0 bpm @ 20'/min and lay in cement. Over pull at 8866'. Check flag and on depth. WCTOC @ 8262' 14:05 - 14:40 0.58 STVVHIP N DPRB WEXIT Park at 8000'. Circ, WOC and discuss w/DH and ME 14:40 - 14:55 0.25 s'rWHIP N DPRB WEXIT RIH jetting out cement at 50'/min. Flag is on depth. Jet to Printed: 10/5/2001 2:50:49 PM --, BP EXPLORATION Page 4 of 14 Operations Summa Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: REENTER+COMPLETE Start: 7/18/2001 End: 8/27/2001 :Contractor Name: NORDIC CALISTA Rig Release: 8/27/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/21/2001 14:40- 14:55 0.25 STWHIP N DPRB WEXlT 8750' 14:55 - 16:45 1.83 STWHIP N DPRB WEXlT POOH jetting to surface. Reflag at 8600' EOP. Dump 50 bbls contam w/8 bbls cmt 16:45 - 17:00 0.25 STWHIP N DPRB WEXlT LD cementing BHA (#6) 17:00 - 18:30 1.50 STWHIP N DPRB WEXlT WOC. Safety mtg re: hi press test. PT new manifold lines to 7500 psi 18:30-21:00 2.50 S'FVVHIP N DPRB WEXlT Wait on cement. Cut off l00' CT 21:00 - 22:00 1.00 STWHIP N DPRB WEXlT Make up pilot mill BHA. BHA 22:00 - 00:00 2.00 STWHIP N DPRB WEXlT RIH with pilot mill BHA. 7/2212001 00:00 - 02:30 2.50 STVVHIP N DPRB WEXlT Stop at flag, make -5.2' correction, wait on cement. 02:30 - 02:45 0.25 STWHIP N DPRB WEXlT Dowell confirmed that the compressive strength of the cement sample was 2800 psi. Continue to RIH and orient tool face to 174 degrees right. 02:45 - 03:00 0.25 STWHIP N ~)PRB WEXlT Free Spin 2920 psi and 2.4 BPM. Tag cement top at 8750' CTM. PU weight 30, 500 lbs. Begin drilling with an initial ROP of 57 FPH. At 8752' the ROP dropped to 40 FPH. 03:00-03:15 0.25 STWHIP N ~)PRB WEXlT Orient tool face to 151 right. 03:15 - 06:15 3.00 STVVHIP N :DPRB WEXlT Begin drilling with an initial rate of 8 FPH. After reaching 8760' the ROP stabilized at about 18 FPH. Drilled to 8820' CTM. 06:15 - 06:45 0.50 STWHIP N DPRB WEXlT Orient tool face to the high side of the hole. 06:45 - 07:40 0.92 STVVHIP N DPRB WEXlT Mill ramp at 18R 07:40 - 09:00 1.33 STWHIP N DPRB WEXlT Mill to 8829.0' CTD (GR shows we may be 3' deep so window start will be at 8826'-did not correct). PUH clean. Had overpull at EOT. Flag pipe at 8600' EOP. POOH for one step mill 09:00 - 10:00 1.00 STWHIP N DPRB WEXlT LD motor and mill. MU 3.80" one step and 2.5 deg fixed WF motor 10:00- 11:40 1.67 STVVHIP N DPRB WEXlT RIH 11:40 - 12:20 0.67 STWHIP N DPRB WEXlT Correct -12.1' at flag. RIH. Set down at 8780' and pop thru. Start motor and orient 1 click at 8800' to 3R. RIH at rain to set down at 8827' three times. Start motor, PUH 14L. RIH and had first motor work at 8826.4'. Flag CT. PUH 1.0', one click. 12:20 - 15:20 3.00 STVVHIP N DPRB WEXlT Begin time milling at 8825.4' by schedule 8825.4' 2.5/3130/20R 22.3K 15:20 - 17:30 2.17 STWHIP N DPRB WEXlT 8826.4' 2.5/3200/20R 21.2K Back at flag. Still plugging 'out' MM occasionally w/cmt chunks from inside liner 17:30- 18:35 1.08 STWHIP N DPRB WEXlT 8827.4' 2.6/3200/9R 19.5K 18:35 - 20:18 1.72 STWHIP N DPRB WEXlT 8828.4' 2.6/3300/3L 17.2K 20:18-20:29 0.18 STWHIP N DPRB WEXlT 8829.6', 2.6/3100/19L 16.1K 20:29 - 20:32 0.05 STWHIP N DPRB WEXlT 8829.7', 2.6/3100/19L 16.4K 20:32-20:45 0.22 STVVHIP N DPRB WEXlT 8829.8', 2.6/3100/14L 16.1K 20:45 - 21:14 0.48 STWHIP N DPRB WEXlT 8829.9, 2.6/3050/14L 16.0K 21:14 -21:21 0.12 STWHIP N DPRB !WEXlT 8830.3, 2.6/3100/8L 14.4K 21:21 -21:40 0.32 STWHIP N DPRB WEXlT 8830.4, 2.5/3300/48L 14.1K 21:40 - 21:45 0.08 STWHIP N DPRB WEXlT Pick up and orient tool face from 48L one setting. 21:45 - 21:51 0.10 STWHIP N DPRB WEXlT Back on bottom with mill. 8830.4', 2.5/3300/8L 16.9K 21:51 - 21:55 0.07 STWHIP N DPRB WEXlT 8830.5', 2.5/3240/3L 16.7 21:55 - 22:25 0.50 STVVHIP N DPRB ~WEXlT 8830.6', 2.6/3350/3L 18K Appears that we have dropped through the window. '22:25 - 22:31 0.10 STWHIP N DPRB WEXlT 8831.6', 2.6/3615/8L 18K 22:31 - 22:32 0.02 STWHIP N DPRB WEXlT 8831.7', 2.6/3350/3L 16.7K 122:32 - 22:38 0.10 STWHIP N DPRB WEXIT 8831.8', 2.6/3380/3L 16.9K 22:38- 22:50 0.20 STWHIP N DPRB WEXlT 8831.9', 2.6/3560/25L 17K 22:50 - 22:52 0.03 STVVHIP N DPRB WEXlT 8832', 2.5/3320/19L 17.3K. Cutting returns have high steel Printed: 10/5/2001 2:50:49PM BP EXPLORATION Page 5 of 14 Operations Summa Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: REENTER+COMPLETE Start: 7/18/2001 End: 8/27/2001 Contractor Name: NORDIC CALISTA Rig Release: 8/27/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/22/2001 22:50- 22:52 0.03 STVVHIP N DPRB WEXIT content. 22:52-22:59 0.12 STWHIP N DPRB WEXIT 8832.1', 2.6/3340/19L 17.4K 22:59 - 23:08 0.15 STWHIP N DPRB WEXIT 8832.2', 2.6, 3270/14L 17K 23:08- 23:23 0.25 S'I'WHIP N DPRB WEXIT 8833', 2.5/3150/3L 14.5K 23:23- 23:30 0.12 STWHIP N I DPRB WEXIT 8834', 2.6/3400/36L 13.5K 23:30-23:33 0.05 STWHIP N ;DPRB WEXIT 8835', 2.6/3400/42L 12.1K 23:33 - 23:37 0.07 STVVHIP N DPRB WEXIT Pick up and cycle pump to index tool face. 23:37 - 23:43 0.10 STWHIP N DPRB WEXIT Drill to 8835.8 and tool face was back at 42L. Probably did not get an index on last try. 23:43 - 23:58 0.25 STWHIP N DPRB WEXIT Pick up and cycle pump to index tool face twice. Hung up at 8831' on the way back to bottom. Worked through what we assumed is the window several times and then successfully made it to bottom. 23:58 - 00:00 0.03 S'I'WHIP N DPRB WEXIT Tool face still at 45L. Pick up and cycle pump three times. (stayed below the window this time when we cycled) Drop back to bottom to finish drilling the 10' of hole past the window. 7/23/2001 00:00 - 00:12 0.20 STVVHIP N DPRB WEXIT Tool face still not indexed correctly. Pick up and cycle pumps three times. Drop back to bottom and start drilling at 8835.5'. Tool face at 3R. 00:12 -00:21 0.15 STWHIP N DPRB WEXIT 8838', 2.6/3470/9R, 10.3K 00:21 -00:25 0.07 STWHIP N DPRB WEXIT 8839', 2.6/3550/3L, 9.9K 00:25- 00:31 0.10 STWHIP N DPRB WEXIT 8840', 2.3/3680/26R, 10 K 00:31 - 00:50 0.32 S'I'WHIP N DPRB WEXIT Stalled motor twice at 8840.1'. Drill to 8840.5' 00:50 - 02:30 1.67 STWHIP N DPRB WEXIT Pulled out of hole with coil. Kick drill ~02:30 - 03:30 1.00 STWHIP N DPRB WEXIT Lay down window mill and pick up Baker 3.77" Go / 3.78" No-go carbide "crayola" mill with metal muncher buttons. 03:30 - 05:15 1.75 S'I'WHIP N DPRB WEXIT RIH with crayola mill. 05:15 ~ 05:25 0.17 STVVHIP N DPRB WEXIT Correlate depth with the flag at 8650' EOC. Made a -2' WEXIT correction. Continue in the hole to the window. 05:25 - 06:00 0.58 STWHIP N DPRB , Tag the window at 8826' at minimum pump rate. Could not pass through. Pick up 10' and bring up pumps to 2.3 BPM and lower mill. Could not pass below about 8823' with the pumps at 2.3 BPM. Made two tries with the tool face at 0 degrees. Pick 'up hole and orient tooface to the left to better replicate that position it was in when drilling the majority of the window. 06:00 - 06:10 0.17 STVVHIP~ N DPRB WEXlT Orient tool face to 15L and drop down with pumps at 2.3 BPM. ~ Stack out at 8823'. 06:10 - 06:40 0.50 STWHIP N DPRB WEXlT Orient in various positions and tried with pump at 0.2 BPM without getting through window. 06:40 - 08:10 1.50 S'FWHIP! N DPRB WEXlT POOH for different mill/motor adj 08:10 - 08:30 0.33 STWHIP N DPRB WEXlT LD BHA. Chk offsets, ok 08:30 - 09:45 1.25 STWHIP N DPRB WEXlT Wait on Baker to prep a 3.78" tapered cutrite mill w/bald nose to 2" OD 09:45 - 10:20 0.58 STWHIP N DPRB WEXlT MU BHA (3.78" crayola w/bald nose on 2.3 deg adj motor) 10:20-11:50 1.50 STWHIP N DPRB WEXlT RIHw/BHA#9 11:50 - 13:00 1.17 STWHIP N DPRB WEXlT Corr to flag. Get TF at 8800' 2.6/3200/61L. Orient high side at 2R. RIH at rain and tag at 8823.5' twice, muse, muse. PUH and chk TF at 2R. RIH w/pump and stall at 8822.5'. Begin milling at 8822' and had stalls at 8823.2'. Work back down to 8823.2' and had incr in diff w/wt loss, but no reactive. TF @ 36R 13:00 - 13:45 0.75 STWHIP N DPRB WEXlT PUH above ramp and orient back to high side at 14L. RIH at min and set down at 8802'. Orient to Iow side at 178R and try Printed: 10/5/2001 2:50:49PM BP EXPLORATION Page 6 of 14 Operations Summa Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: REENTER+COMPLETE Start: 7/18/2001 End: 8/27/2001 Contractor Name: NORDIC CALISTA Rig Release: 8/27/2001 Rig Name: NORDIC 1 Rig Number: Date From- To Hours Activity Code NPT Phase Description of Operations 7/23/2001 13:00 - 13:45 0.75 STWHIP N DPRB WEXIT to drill Iow side from 8802'-no progress with bald mill. Discuss w/DH and ME-will do leakoff test. Appears cement in 7-5/8" is falling apart. Have continued to plug 'out' MM with cement chunks every 1-2 hrs pumping 13:45 - 14:25 0.67 STWHIP N DPRB WEXIT Pump 20 bbls FW followed by mud and lay in hole from 8802'. MM plugged while displacing and pressured well up to 900 psi. Performed leakoff test anyway with FW at 8802' and held rite at 1230 psi 14:25- 16:00 1.58 S TWHIP'N DPRB WEXIT POOH 16:00- 17:00 1.00 STVVHIP N :DPRB WEXIT LD drilling BHA 17:00- 17:15 0.25 STWHIP N DPRB WEXIT Safety mtg re: cut CT 17:15 - 18:30 1.25 STWHIP N DPRB WEXIT RU and cut off 250' CT. RD tools 18:30 - 00:00 5.50 S'I'WHIP N DPRB WEXIT Wait on Weatherford tools (had to build blades for Reeves UR) 7/24/2001 00:00 - 02:15 2.25 S'I'WHIP N DPRB WEXIT Wait on Weatherford under reamer tools. 02:15 - 03:45 1.50 S'I'WHIP N DPRB WEXIT MU under reamer BHA 03:45 - 05:45 2.00 STVVHIP N DPRB WEXIT RIH with BHA #10. Tie in with flag to correlate depth. Tag at 8802'. Pick-up weight 31K. 05:45 - 08:30 2.75 STVVHIP N DPRB WEXIT Start under reaming liner 'up' at 8796' at a pump rate of 2.3 BPM and 2600 psi. 08:30 - 09:00 0.50 STWHIP N DPRB WEXIT Fin UR up to what acts like the tailpipe at 8786'. UR down from 8786' 2.4/2850. Flag at 8700' EOP (8790.1' this BHA). Getting chunks of cement over shaker 09:00 - 09:45 0.75 STWHIP N DPRB WEXIT Stall at 8799'. Begin UR down 2.4/2850 21K 09:45 - 11:20 1.58 STWHIP N DFAL WEXIT UR to 8804' and chunked stator. POOH for motor, filling from BS 11:20 - 12:00 0.67 STWHIP N DFAL WEXIT Change out motor. UR in good shape. Had chipped metal munchers on outside of upper blades probably indicating work on TT 12:00 - 12:50 0.83 STWHIP N RREP WEXIT DS mechanic adjust injector cage 12:50- 14:25 1.58 S'I'WHIP N DFAL WEXIT RIH w/BHA#11 14:25 - 14:35 0.17 STWHIP N DF^L WEXIT : Corr to flag -22.6' at 8399' EOP, RI H. Check flag at 8786.3' on depth 14:35 - 14:50 0.25 STWHIP N DPRB WEXIT Ream down from 8788' at 3'/min 2.4/2640 20.5K 14:50 - 16:20 1.50 STVVHIP N DPRB WEXIT Resume UR'ing cement from stall at 8804.3' 16:20 - 20:00 3.67 S'I'WHIP N DPRB WEXIT 8814' 2.3/2500 19K Kick while drilling drill. UR to 8830'. Slow but few stalls. 20:00 - 22:30 2.50 STWHIP N DPRB WEXIT UR AT 8830'. 2.4/2500 PSI. UR to 8842'. SHOULD BE BELOW DEEPER WINDOW. MILLING AHEAD SMOOTHLY AT 8842'. 22:30 - 00:00 1.50 STWHIP N DPRB WEXIT UR TO 8850'. 7/25/2001 00:00 - 01:45 1.75 STVVHIP N DPRB WEXIT CONTINUE TO UR CEMENT IN 7-5/8" CSG. MILL TO 8865'. 01:45 - 02:30 0.75 STWHIP~N DPRB WEXIT BACK REAM TO 8820'. 02:30 - 04:15 1.75 STWHIP N DPRB WEXIT POOH WITH UNDEREAMER. 04:15 - 05:00 0.75 STWHIP N DPRB WEXIT LD MOTOR & UR ASSEMBLY. MU NOZZLE. 05:00 - 07:00 2.00 STWHIP N DPRB WEXIT RIH with nozzle to 8865 ft. Circ. well to KCL water. 07:00 - 09:00 2.00 STWHIP N DPRB WEXIT POOH while circ at 3.5 bpm, 3400 psi. 09:00 - 09:30 0.50 STWHIP N DPRB WEXIT Freeze protect 4 1/2" tubing with MEOH from 2000' to surface. 09:30 - 11:30 2.00 STWHIP N DPRB WEXIT Closed Swab and Master valves. N/D BOP stack. Clean rig pits. 11:30 - 12:00 0.50 STWHIP N DPRB WEXIT N/U tree cap and press test with 4000 psi. RELEASED RIG FROM M-38AI AT 12:00 HRS, 07-25-01 TOTAL TIME ON WELL WAS 7 DAYS, 9 1/2 HOURS, _ Printed: 10/5/2001 2:50:49PM BP EXPLORATION Page 7 of 14 Operations Summa Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: REENTER+COMPLETE Start: 7/18/2001 End: 8/27/2001 Contractor Name: NORDIC CALISTA Rig Release: 8/27/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations .... 7/25/2001 11:30 - 12:00 0.50 STWHIP N DPRB WEXlT Well has MEOH to 2000 ft and 2% KCL water from 2000' - 8865 ft. 8/18/2001 13:00 - 16:00 3.00 MOB N DPRB PRE Standby waiting for supersucker to clean cuttings tank so rig can move. 16:00 - 17:00 1.00 MOB N DPRB PRE Move rig from M-03 to M-38. 17:00 - 18:00 1.00 RIGU N DPRB PRE Accept rig at 1700, begin nippling down tree, moving in green tank, diking, hard line to tiger tank, etc. 18:00 - 19:00 1.00 BOPSUF N DPRB DECOMP NU BOPE 19:00 - 00:00 5.00 BOPSUB N DPRB DECOMP Test BOPE. Witness waived by AOGCC 8/19/2001 00:00- 00:30 0.50 BOPSUB N DPRB DECOMP Fin test BOPE 00:30 - 01:30 1.00 STWHIP N DPRB WEXlT Cut off Baker CTC, install DS CTC. PT 35k, 3500 psi 01:30 - 02:00 0.50 STWHIP N DPRB WEXlT Prespud mtg while chk well for press, none 02:00 - 02:30 0.50 STWHIP N SFAL WEXlT Install fusible. MU milling BHA and can't get by SSV (not fully open) 02:30 - 03:40 1.17 STWHIP N SFAL WEXlT we grease crew to open 03:40 - 04:00 0.33 STWHIP N DPRB WEXlT MU milling BHA 04:00 - 05:50 1.83 STWHIP N DPRB WEXlT RIH w/BHA #1 (3.80" window mill and 3.80" SR) 05:50 - 06:00 0.17 STWHIP N DPRB WEXlT Tag WS top at 8868' at min rate and set down at pinch pt at 8870' CTD. PUH 32K, start motor 06:00 - 06:20 0.33 STWHIP N DPRB ,WEXlT Retag at 8868.8' w/motor diff. Corr to 8858' and flag. 2.5/1600. Got a little premature. Corr another -1.8' at 8859.8' and paint another flag 06:20 - 07:00 0.67 STWHIP N DPRB WEXlT Milling 2.7 bpm 100% returns, 1950 CTP. 07:00 - 08:00 1.00 STWHIP N DPRB WEXlT 07:00 update. Milling window at 8860.3', 2.3' into window. 2.7 in, 2.7 out, 100% returns, 2000 psi CTP, 2900 lbs weight on bit. 08:00 - 09:00 1.00 STWHIP N DPRB WEXlT 08:00 update. Milling window at 8861.6', 3.6' into window. 2.7 ~n, 2.7 out, 100% returns, 1800 psi CTP (Addidng bio to mud system), 3200 lbs weight on bit. 09:00 - 10:00 1.00 STWHIP N DPRB WEXlT 09:00 update. Milling window at 8862.6', 4.6' into window. 2.7 in, 2.7 out, 100% returns, 1750 psi CTP, 4000 lbs weight on bit. 10:00 - 10:30 0.50 STWHIP N DPRB WEXlT 10:00 update. Milling window at 8863.6', 5.6' into window. 2.7 l iin, 2.7 out, 100% returns, 2000 psi CTP, 2000 lbs weight on bit. Apparent bottom of window at 8862.8', for a 4.8' window. Observed stalls at 8863.6' indicating probably string reamer I exiting window. 10:30 - 11:00 0.50 STWHIP N DPRB WEXlT Drill open hole, getting 25 fph ReP, pump 15 bbls 2#/bbl biozan sweep. Drill to 8869'. 11:00 - 12:00 1.00 STWHIP N DPRB WEXlT Drilled to 8869', backream up and down through window 4 times at 30 fpm. Little work on motor. 12:00 - 12:30 0.50 STWHIP N DPRB WEXIT Dry drift up and down through window. No problems, no drag. Pump another sweep to clean up hole. 12:30 - 14:00 1.50 STWHIP N DPRB WEXlT Sweep around, chase out of hole with KCL. Stop and put EOP flag at 8500', EOP. 14:00 - 14:30 0.50 STWHIP N DPRB WEXlT Tag up at surface, lay down BHA #12, Milling BHA. Mill and string reamer both in gauge (3.79"+) 14:30 - 15:30 1.00 DRILL !N DPRB PROD1 Make up Build section BHA. Using Smth M-09 bit, 3.2 deg motor (43 deg DL). 15:30- 17:00 1.50 DRILL N DPRB PROD1 RIH with BHA#13 17:00 - 17:05 0.08 DRILL !N DPRB PROD1 Stop at 8500' EOP flag. Flag found at 8585'. (Last BHA was 87' log) So, very consistent on depth. Re set depth to 8570.5'. (8500' + this BHA length of 70.5'). RIH try to get through window we orienting. 17:05 - 17:10 0.08 DRILL N DPRB PROD1 Tag up at bottom of window. Attempt to work pipe to get Printed: 10/5/2001 2:50:49PM BP EXPLORATION Page 8 of 14 Operations Summa Report Legal Well Name: M-38 'Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: REENTER+COMPLETE Start: 7/18/2001 End: 8/27/2001 Contractor Name: NORDIC CALISTA Rig Release: 8/27/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/19/2001 17:05 - 17:10 0.08 DRILL N DPRB PROD1 through. Up weight clean at 34klbs. Can't make it through. Pick up to orient. 17:10 - 17:30 0.33 DRILL P PROD1 Orient to 33L, RIH through window easily. Small bobble on wt at 8862', bottom of window. Tag up at 8867', left bottom at 8869' on last run. Orient around to 30R. 17:30 - 20:00 2.50 DRILL P PROD1 Begin drilling build section. 2.4 in, 2.4 out, 2050 psi, pumping mud, chasing KCL OOH. 20:00 - 21:10 1.17 DRILL P PROD1 8916' 2.5/3500/5R 21:10 - 21:45 0.58: DRILL P PROD1 8935' 2.5/3500/15R Orient around (twice) 21:45 - 23:30 1.75 DRILL P PROD1 Drilling 2.5/3500/5R to 8957'. Orientor TF's wandering around the clock. Frequent MWD toggles to get signals 23:30 - 00:00 0.50 DRILL P PROD1 Orienting 8/20/2001 00:00 - 02:35 2.58 DRILL P PROD1 Orient, ream and try to get TF to stay in one high side spot, but flops to 90R on btm. Orient around twice in casing. Ream down slow from 8920' trying to scribe a HS TF twice wo success 02:35 - 03:50 1.25 DRILL P PROD1 Orient around on btm and flops to 90L (yes, left). Orient and slow ream to get to high side. These big motors are difficult to hold HS TF-Iooks like we found our 'technical limit' 03:50 - 04:25 0.58 DRILL P PROD1 Get it locked in at 5-17L and resume drilling from 8960' 2.5/3500/11 L 04:25 - 05:10 0.75 DRILL P PROD1 Began losing 0.5 bpm at 8980' (8614' 'rVD) 2.7/2.2 3600/11L 05:10 - 05:45 0.58 DRILL N DFAL PROD1 Attempt to orient from 11L to 10R at 9007' 2.6/2.0 3500 and can't get clicks. Pull into casing and can't get back down (w/ TF needed to drill) 05:45 - 07:10 1.42 DRILL N DFAL PROD1 POOH for orientor filling from BS 07:10 - 08:30 1.33 DRILL N DFAL PROD1 Change out orienter, Adjust motor to lower AKO setting. Plan to go with a 2.9 deg AKO to reduce the difficulty orienting. Should be able to get 39 deg build rate to land well. Current calculations show we need 36 deg rate to land. 08:30 - 10:10 1.67 DRILL N DFAL PROD1 RIH with BHA #14, Build section BHA #2. 10:10 - 10:15 0.08 DRILL P PROD1 Can't get down through window with pumps off. Hung up at bottom of window. Kick on pumps found tool face at 117L. Orient around to 28R, RIH. 10:15 - 11:10 0.92 DRILL P PROD1 Tag up at 8978', should be 9009'. Appear to be off depth 31'. Make tie in pass up. Make -9' correction. 11:10 - 11:40 0.50 DRILL P PROD1 Orient around. In build section, only getting 50% on clicks, BHA still in a bind. 11:40 - 12:15 0.58 DRILL P PROD1 Ream hole, trying to get back to bottom. Tool face keeps flopping around. Having to re orient. 12:15 - 13:00 0.75 DRILL P PROD1 Back on bottom, drilling at 0 TF, 2.7 in, 2.1 out, 80% returns, drilling at 3700 psi CTP, Free spin=3500 psi. ROP=60 fph. 13:00 - 13:30 0.50 DRILL P PROD1 9069', Build section completed. Orient to 90 R to make turn. i During orienting losses went to 1.0 bpm. 13:30 - 15:15 1.75 DRILL P PROD1 Drilling ahead, losses remain at 1 bpm. Will continue and see if they heal back up. 15:15 - 15:25 0.17 DRILL P PROD1 9150', short trip to shoe. In 2.5, out 1.4. 15:25 - 15:45 0.33 DRILL P PROD1 Orienting, 15:45 - 17:15 1.50 DRILL P PROD1 Resume drilling. 2.6 in, 1.3 out, 50% losses. 3700 psi CTP. 17:15 - 17:35 0.33 DRILL P PROD1 9241', Wiper trip to shoe. 17:35 - 18:00 0.42 DRILL P PROD1 Back on bottom. Attempt to get motor to drill. 18:00 - 19:40 1.67 DRILL N DFAL PROD1 Can't get motor to drill. Can't get any work when on bottom. POOH to see if motor is damaged. Fill across the backside Printed: '10/5/2001 2:50:,49 PM BP EXPLORATION Page 9 of 14 Operations Summa Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: REENTER+COMPLETE Start: 7/18/2001 End: 8/27/2001 Contractor Name: NORDIC CALISTA Rig Release: 8/27/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/20/2001 18:00- 19:40 1.67 DRILL N DFAL PROD1 when POOH. 19:40 - 20:30 0.83 DRILL N DF^L PROD1 LD drilling BHA. Motor drive sub turned freely indicating a transmission problem 20:30-20:50 0.33 DRILL N DPRB PROD1 MU cementing BHA 20:50 - 22:25 1.58 DRILL N DPRB ~PROD1 RIH to fix losses before resuming drilling 22:25 - 22:45 0.33 DRILL N DPRB PROD1 'RIH to 9050' 20k, PUH 30.2k 0.6/0.3. Start 30 bbls LCM (10 ppb nutplug, 10 ppb mica, 10 ppb Mixll) 1.6/0.6 1570 22:45 - 23:40 0.92 DRILL N DPRB PROD1 Displace w/rig mud 2.2/0.9 2000. SI at choke just prior to LCM @ noz @ 9000'. 12k overpull at 8990'. Inject at 1.5 bpm @ 11700 psi pulling 5'/min-no press incr on WHP or CT. Open choke as last of pill cleared nozzle. Got excessive returns like swabbing in or breathing. PUH 23:40 - 00:00 0.33 DRILL N DPRB PROD1 Park at 8600', check return rate 1/1. SI BS. Try to bullhead and pressured up to 200 psi. Manifold valves not lined up correctly to read WHP... 8/21/2001 00:00 - 01:10 1.17 DRILL N DPRB PROD1 RIH jetting LCM OOH to 8990'. PUH jetting 2.4/2.2 2050 to 8500'. Recovered a very minor amount of LCM 01:10 - 01:30 0.33 DRILL N DPRB PROD1 Safety mtg re: Forma Plug II 01:30-02:10 0.67 DRILL N DPRB PROD1 PT DS @ 4000 psi. Load CT w/15 bbls FIo Vis preflush 1.7/1.4 1630 02:10 - 02:25 0.25 DRILL N DPRB PROD1 Mix 30 sx accelerator. RIH 02:25- 02:55 0.50 DRILL N DPRB PROD1 Load CT w/30 bbls 1.7/1.2 1820. Pumping rough 1.4/1.1 2480 11.24 ppg, 87.6 deg F after 20 bbls. Displace w/15 bbl post flush FIo Vis pill 1.5/1.2 3100. After 30 min sample in HWB is hard 02:55 - 03:40 0.75 DRILL N DPRB PROD1 Displace w/fresh mud 1.6/1.3 2910. With FP II @ noz close choke, PUH from 8980' at 1.0'/min. 1.4/2400/300, 32.8k At 16 bbls out WHP was 730 psi. Red rate to 1.0 bpm and WHP pressure continued to increase. At 22 bbls out began laying 5 bbls in OH and casing. Open choke at 27 bbls out w/noz at 8750' and WHP max of 1070 psi. Bleed to zero while PUH and fin displ flush. Park and check returns 1/1 03:40 - 04:55 1.25 DRILL N DPRB PROD1 POOH maintaining 100 psi WHP 04:55 - 05:30 0.56 DRILL N DPRB PROD1 OOH. Standback BHA. Stab back on and circ out chunks of FIo Vis post flush from CT 05:30- 06:05 0.58 DRILL N DFAL PROD1 MU drilling BHA 06:05 - 07:40 1.58 DRILL N DFAL PROD1 RIH w/BHA # 16 (2.75 deg motor) 07:40 - 07:50 0.17 DRILL N DPRB PROD1 Kick on Pumps to 1 bbl/min to prevent plugging off jets as we RIH through formaplug gel. 07:50 - 08:00 0.17 DRILL N DPRB PROD1 Tag top of gel at 8523', continue RIH. Drop below tubing tail, bring rate up to 2.7 bpm to check orientation. 08:00 - 08:30 0.50 DRILL N 'DPRB PROD1 Orient to high side to get through window. MWD looking errattic, Keeps dropping out. Working well enough to get tool faces. Will try to RIH to get gel drilled up. Getting 1 for 1 returns at 1.5 bpm while RIH in casing. In open hole increase rate to 2.5 bpm, had 1 for 1 returns below window. Tagged up at 8970'. 08:30 - 09:20 0.83 DRILL P PROD1 Orienting to get through 9030'. Tool face 155L, having to orient around to high side. Can't get any clicks. Made it to 9030', and set down. Don't want to sidetrack. Pull up into window to attempt to orient. 09:20 - 09:30 0.17 DRILL P PROD1 RIH, continue to clean out gel. Tag TD at 9249', make -6' Printed: 10/5/2001 2:50:,49PM BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 !Event Name: REENTER+COMPLETE Start: 7/18/2001 End: 8/27/2001 Contractor Name: NORDIC CALISTA Rig Release: 8/27/2001 Rig Name: NORDIC 1 Rig Number: Date From-To Hours Activity i Code NPT Phase Description of Operations 8/21/2001 09:20 o 09:30 0.17 DRILL P PROD1 correction, set depth at 9243'. 09:30 o 09:40 0.17 DRILL P PROD1 Begin drilling. Tool face 90R, need 65R. Can't get it with reactive. Need to pick up and orient. 09:40 - 09:50 0.17 DRILL P PROD1 Orienting. Got tool face to 65R. After orienting, we got losses back. In 2.7, out 2.4. CTP 3600 psi free spin, 09:50 o 10:30 0.67 DRILL P PROD1 Resume drilling, 2.7 in, 2.4 out, 3650 psi drilling, TF 76R, ROP=65 fph. 10:30 - 11:00 0.50 DRILL N DPRB PROD1 9281', near predicted fault. Had several stalls, possibly crossing fault. Returns dropped off. Went to 0.5 bpm returns, then to 0 returns. Called for more mud. Called for 70 bbls LCM pill. 11:00 - 11:30 0.50 DRILL N DPRB PROD1 9326', 50 bbls left in pits. Pull up to casing shoe to hang out until new mud gets here. Pulled heavy up to window. 11:30 - 11:40 0.17 DRILL N DPRB PROD1 Pits dry. No mud on location. Waiting on vac trucks. 11:40 - 12:05 0.42 DRILL N DPRB PROD1 New mud on location. Blow into pits, circulate down the kill line, trying to get to fill well. 12:05 - 13:30 1.42 DRILL N DPRB PROD1 POOH to pick up nozzle to cement loss zone. Build/turn section completed. 13:30 - 14:30 1.00 DRILL N DPRB PROD1 Tag up at surface, stand back injector, lay down BHA, Make up cementing nozzle. 14:30 - 15:50 1.33 DRILL N DPRB PROD1 RIH with cementing nozzle. Loosing 3 bpm while making up BHA. 15:50 - 16:10 0.33 DRILL N i DPRB PROD1 Safety meeting prior to pumping cement. 16:10 - 17:30 1.33 DRILL N DPRB PROD1 Wait for dirty vac truck. All dirty vacs tied up at Pad 3. Decide to take our last clean mud truck and use him for a dirty after he unloads into the pits. Standby on vac truck to load pits. 17:30 - 19:00 1.50 DRILL N DPRB PROD1 Pump 2 bbls water. PT cementers lines to 4000 psi. Passed ok. Pump cement as follows; 5 bbls neat bentonite cement 13.8 ppg, 20 bbls + 20#/bbl Aggregate, 20 bbls 20#/bbl Ag + 1/4 ppb cello-flake, 5 bbls neat tail. Chase cement with 2 bbls water then displace with flow pro drilling mud. Position nozzle at 9281', SI pumping down the backside, si choke. Bullhead 3 bbls of cement into fault, open choke lay in cement to shoe holding 500 psi. Pull to shoe, si choke, BH cement well taking cement at 1000 psi. Put another 3 bbls away. Pressure up to 1200 and holding continue to bullhead cement. Put additional 16.4 bbls away. Got 500 psi bump on both WHP and CTP. Open choke, drop WHP to 0, lay in remaining 25 bbls of cement. PUH to safety depth. Circulate min rate with chokes open. ClP at 19:00. 22.4 bbls into fault. 19:00 - 20:00 1.00 DRILL N DPRB PROD1 Stop at safety depth - 7000'. Circulate at minimum rate. Wait for 1 hour on cement. 20:00 - 21:30 1.50 DRILL N DPRB PROD1 RIH and clean out CMT to 8835 ft. Unable to clean out any further with nozzle. Stacking wt while jetting. 21:30 - 23:30 2.00 DRILL N DPRB PROD1 POOH for drilling BHA. 23:30 - 00:00 0.50 DRILL N DPRB PROD1 Jet BOP stack with jetting nozzle. 8/22/2001 00:00 - 00:30 0.50 DRILL N DPRB PROD1 Surface test Sperry Resistivity tool. 00:30 - 00:45 0.25 DRILL N DPRB PROD1 M/U BHI 1.4 deg motor and used DS49 Bit #5. 00:45 - 02:30 1.75 DRILL N DPRB PROD1 RIH with MWD BHA #18, Shallow test Sperry tools. RIH. 02:30 - 02:45 0.25 DRILL N DPRB PROD1 Orient TF to 17L at 8810 ft. 02:45 - 03:40 0.92 DRILL N DPRB PROD1 Tag CMT at 8830 ft CTD. Drill CMT at 5 FPM, Stall four times at 8870 ft. TF = 20L. to 9R. 03:40 - 04:10 0.50 DRILL N DPRB PROD1 Orient around to exit window. Printed: 10/5/2001 2:50:49PM BP EXPLORATION Page 11 of 14 Operations Summa Report Legal Well Name: M-38 ICommon Well Name: M-38A Spud Date: 7/19/2001 Event Name: REENTER+COMPLETE Start: 7/18/2001 End: 8/27/2001 Contractor Name: NORDIC CALISTA Rig Release: 8/27/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/22/2001 04:10 - 05:30 1.33 DRILL N DPRB PROD1 Stall at 8870 ft. with 60L, 40L, 20L TF. Several stalls. Spud at 8870 ft. Still unable to exit window. 05:30 - 07:00 1.50 DRILL N DPRB PROD1 POOH for mill and string reamer. Flag CT at 8600' EOP. 07:00 - 08:15 1.25 DRILL N DPRB PROD1 LD motor, bit & resistivity tool. Bit had several broken cutters on taper. 08:15- 10:00 1.75 DRILL N DPRB PROD1 RIH. MWD test good. Continue in hole. 10:00- 10:30 0.50 DRILL N DPRB PROD1 Tie into EOP flag at 8600'. RIH. Tag at 8871'. Log gr up 3ass. Subtract 10'. 10:30 - 11:00 0.50 DRILL N DPRB PROD1 Orient to 20L. 11:00-12:00 1.00 DRILL N DPRB PROD1 Time mill through window. 2.5 / 3000 psi fs. Stall at 8860'. PU and get click. Repeat this several times. Keep stacking weight and getting too much reactive torque. 12:00 - 14:30 2.50 DRILL N DPRB PROD1 PU and time drill ahead 30 seconds per 0.1' from 8855'. TF holding steady between 30-20L. Mill to 8870'. 14:30 - 15:00 0.50 DRILL N DPRB PROD1 Orient to 90R. Ream down through window. Some reactive but otherwise smooth. 15:00 - 15:45 0.75 DRILL N DPRB PROD1 Orient to 90L. Ream down through window. Some motor work, but fairly smooth. 15:45- 16:45 1.00 DRILL N DPRB PROD1 POOH for drilling assy 16:45- 17:15 0.50 DRILL N DPRB PROD1 LD milling BHA. 17:15 - 19:30 2.25 DRILL N DPRB PROD1 Cut 300' of coil off reel for CT fatigue maint. 19:30 - 20:10 0.67 DRILL N DPRB PROD1 M/U MWD BHA with 1.4 deg motor and new DS49 Bit #6. 20:10 - 21:50 1.67 DRILL N DPRB PROD1 RIH with MWD BHA. Shallow test OK. RIH. 21:50 - 22:20 0.50 DRILL N DPRB PROD1 Orient TF to go thru window. 22:20 - 00:00 1.67 DRILL N DPRB PROD1 Ran thru window to 8875.5 ft. Correct depth to 8870 ft. Drill cement. TF not steady at 20R. Several stalls. Orient TF several times. ' Drill cement to 8896 ft. DS lab UCA cmt sample at 1100 psi at 23:30 hrs. Should be easy to drill. Drilling BHA inside window appears to be dragging causing several stalls. 8/23/2001 00:00 - 01:50 1.83 DRILL N DPRB PROD1 Drill cement with 1.4 deg motor and DS49 bit. Several stalls. Stacking wt. TF = 16R. ROP = 40-80 fph. drill to 8926 ft. 01:50 - 02:30 0.67 DRILL 'N DPRB PROD1 Drill to 8930 ft. MWD survey indicated original hole was sidetracked at 8895 ft. 02:30 - 03:00 0.50 DRILL N DPRB PROD1 Log Tie-in with RA tag. On depth, no correction. Flag CT at 8700' EOP. 03:00 - 04:30 1.50 DRILL N DPRB PROD1 POOH for higher bend motor to re-drill build section. 04:30 - 05:00 0.50 DRILL N DPRB PROD1 Change out BHA. M/U 3.2 deg short radius motor and M09 used bit. 05:00 - 06:30 1.50 DRILL N DPRB PROD1 RIH with MWD BHA #20, 3.2 deg short radius motor. Stop at flag at 8700' EOP. Correct -13 ft CTD. RIH. 06:30 - 07:00 0.50 DRILL N DPRB PROD1 Orient TF to exit window. 07:00 - 10:00 3.00 DRILL N DPRB PROD1 Tag TD. Correct to 8930' (-5') Drill ahead at 13R Drill slowly to 9000' to maintain smooth TF etc. 2.6/3200FS 10:00 - 12:00 2.00 DRILL N DPRB PROD1 Drilling ahead. 2.5/3000 fs / TF:15R Drill to 9063' 12:00 - 12:30 0.50 DRILL N DPRB PROD1 Short trip to window. Hole smooth 12:30- 13:15 0.75 DRILL N DPRB PROD1 Drill to 9097'. Land build. 13:15 - 13:45 0.50 DRILL N DPRB PROD1 Orient to increase turn rate TF:70-80r 13:45 - 15:00 1.25 DRILL N DPRB PROD1 Drill ahead to 9240'. TF rolling slowly to 130R. 15:00 - 15:30 0.50 DRILL N DPRB PROD1 Short trip to window. Hole smooth. Full mud returns. 15:30 - 15:45 0.25 DRILL N DPRB PROD1 Orient around to maintain angle. TF:80R 15:45-16:45 1.00 DRILL N DPRB PROD1 Drillahead. 2.6/3200fs/TF:85R. Drillto9317'. Fullrtns. Printed: 10/5/2001 2:50:49PM BP EXPLORATION Page 12 of 14 Operations Summary Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: REENTER+COMPLETE Start: 7/18/2001 End: 8/27/2001 Contractor Name: NORDIC CALISTA Rig Release: 8/27/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/23/2001 15:45 - 16:45 1.00 DRILL N DPRB PROD1 TF slowly rolling to right. 150 fph 16:45 - 17:15 0.50 DRILL N DPRB PROD1 !PU to orient. Getting about 50% clicks. TF:75R 17:15 - 18:00 0.75 DRILL P PROD1 Drilling ahead. TF:75R 75-100 fph. Losing about 20 bph. Complete turn/build at 9375'. 18:00 - 20:00 2.00 DRILL P PROD1 POOH for lateral assembly. 20:00 - 20:15 0.25 DRILL P PROD1 SAFETY MEETING, Review steps to M/U and test Sperry Resistivity tool. 20:15 - 21:45 1.50 DRILL P PROD1 M/U 1.0 deg motor and new DS49 Bit #8. Held kick drill. 21:45 - 23:30 1.75 DRILL P PROD1 RIH with BHA # 21. 23:30 - 00:00 0.50 DRILL P PROD1 Log Tie-in with RA tag. [-11 ft CTD]. 8/24/2001 00:00 - 00:20 0.33 DRILL P PROD1 Log tie-in with RA tag, [-11 ft CTD] 00:20 - 01:00 0.67 DRILL P PROD1 Log resistivity / GR MAD pass to TD at 600 fph. 1.3 / 0.8 bpm. 1/2 BPM losses. Sat down at 9255 ft. 01:00 - 02:15 1.25. DRILL P PROD1 Orient TF from 30R to 90R. Unable to orient in high DLS build section. Pull back to window. Unable to orient. Pull to 8600 ft. Unable to orient. 02:15 - 04:00 1.75 DRILL N DFAL PROD1 POOH for orientor. Fill across top. 04:00 - 04:30 0.50 DRILL N DFAL PROD1 Change out orientor and reduce choke to 12132". 04:30 - 05:00 0.50 DRILL N DFAL PROD1 RIH with MWD Res. BHA. Shallow test orientor. RIH. 05:00 - 06:15 1.25 DRILL N DFAL PROD1 Continue in hole. 06:15-06:30 0.25 DRILL P PROD1 Correct -11ft CTD at window. RIH. TF=67R. 2.1 bpm, 1.9 bpm returns. 06:30 - 06:45 0.25 DRILL P PROD1 RIH. Orient and pass through bridge with no trouble. 06:45 - 07:15 0.50 DRILL P PROD1 Drill ahead. 2.5/3200 fsi TF:50r 2.6 in/0.9 out. 33k# up, 15k# dn wt. 07:15 - 07:30 0.25 DRILL P PROD1 PU to orient. 07:30 - 08:30 1.00 DRILL P PROD1 Drilling ahead with 2.6 in/0.5 out. TF:140R. Trying to knock down angle to avoid Shublik. 08:30- 10:00 1.50 DRILL P PROD1 Drill to 9560'. 2.6 in/0.5 out rate. TF:135R. Dropping angle towards 90 deg. 10:00 - 11:00 1.00 DRILL P PROD1 Short trip to window. Some trouble getting back through window. Hole smooth. 11:00- 11:15 0.25 DRILL P PROD1 Orient to 85L 11:15 - 12:30 1.25 DRILL P PROD1 Drilling ahead. 2.5~3240 fs/TF:85R Drill to 9683'. 12:30 - 13:30 1.00 DRILL P PROD1 Drilling ahead. Losses improving slighly to 2.5 in/0.9 out. TF:100R. Drill to 9735'. 13:30 - 14:00 0.50 DRILL P PROD1 Short trip to window. Hole very smooth. 14:00 - 15:00 1.00 DRILL P PROD1 Drill ahead. 2.5 / 3200 fs / TF:110R 2.5 in/1.2 out rate. Switch to 2% kcl water. Drill to 9750'. 15:00 - 16:30 1.50 DRILL N STUC PROD1 Drill ahead to 9900'. Switch back to mud from pits. 2.5 in/1.6 out. Diff stuck. Rest hole & work free at 80K# up wt. 16:30 - 17:15 0.75 DRILL P PROD1 Wiper trip to window. Some slight rough spots 9600-9800'. Otherwise very smooth. 17:15 - 17:30 0.25 DRILL P PROD1 Orient to begin final turn & drop. 17:30 - 19:10 1.67 DRILL P PROD1 Drill ahead. 2.6~3300 fs / TF:125L 2.5 in/1.1 out. 100 fph. Drill to 9982 ft. Stacking wt. Not getting wt to bit, no motor work. 19:10 - 20:10 1.00 DRILL P PROD1 Wiper trip to window. Hole clean. RIH. 20:10-21:10 1.00 DRILL P PROD1 Drilling, 2.5 in /1.3 out, 3100psi, TF=80L. 100fph. Drillto 10,051ft. 21:10 - 21:40 0.50 DRILL P PROD1 Orient around to drop incl. 21:40 - 23:30 1.83 DRILL P PROD1 Drilling, TF = 130L, 2.6 ! 1.2 bpm, 3200 psi, 100 fph. Drill to Printed: 10/5/2001 2:50:49 PM BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: REENTER+COMPLETE Start: 7/18/2001 End: 8/27/2001 Contractor Name: NORDIC CALISTA Rig Release: 8/27/2001 Rig Name: NORDIC 1 Rig Number: Date From -To Hours Activity:Code NPT Phase Description of Operations 8/24/2001 21:40 - 23:30 1.83 DRILL P PROD1 10,150 ft. 23:30 - 00:00 0.50 DRILL P PROD1 Wiper trip to window. Hole clean. RIH. 8/25/2001 00:00 - 00:45 0.75 DRILL P PROD1 Wiper trip to window, Hole Clean, RIH. 00:45 - 02:30 1.75 DRILL P PROD1 Drilling, TF = 80L, 2.5 / 1.2 bpm, 3200 psi, ROP = 100 fph, In¢l - 80 Deg. Drill to 10260 ft. At TD. 02:30 - 02:50 0.33 DRILL P PROD1 Wiper trip to 9400 ft. Hole clean. 02:50 - 04:30 1.67 DRILL P PROD1 Log Resistivity / GR MAD pass from 9400 - 8860 ft at 300 FPH. 1.1 / 0.3 BPM 04:30 - 05:00 0.50 DRILL P PROD1 Log Tie-in with RA tag. Add 11 ft to CTD. 05:00 - 05:45 0.75 DRILL P PROD1 RIH to TD. Clean hole. Tag Final TD at 10,270 ft. 05:45 - 07:45 2.00 DRILL P PROD1 POOH. Flag CT at 7200 ft EOP. 07:45- 10:00 2.25 DRILL P PROD1 At surface. LD BHA. Download MWD. 10:00 - 10:30 0.50 CASE 3 COMP RU floor to run liner. 10:30 - 10:45 0.25 CASE ~ COMP Hold pre job safety mtg. Discuss falling ice hazard on rig floor. 10:45 - 13:15 2.50 CASE 3 COMP MU 42 jts 2-7/8" stl & 6 jts TCll liner. MU & test Baker CC & CTLRT. Check hole fill while running pipe. 13:15 - 13:30 0.25 CASE 3 COMP MU BHA & stab on liner. Get on well. 13:30 - 15:30 2.00 CASE ~ COMP RIH. 16k# dh, 35k# up wt at window. Continue in hole. Run to TD at 10270'. 38k#up, 18k# dn wt. TOL at 8705'. 15:30 - 16:15 0.75 CASE 3 COMP Drop 5~8" ball. Circ to CTLRT. On seat at 44.4 bbls. Pressure up to 3600 psi. PU to check release at 31k#. OK. 16:15 - 17:00 0.75 CASE 3 COMP Displace well to KCL water. Batch mix 20 bbls G, 15.8# latex. Up to wt at 1700 hrs. 17:00 - 17:15 0.25 CASE ~ COMP Hold pre job safety mtg. Discuss pump schedule & clean up. 17:15 - 18:30 1.25 CASE 3 COMP Pump 5 bls water. PT lines to 4000 psi. OK. Pump 20 bbls cement, drop dart. Blow back line to cementers. Bump dart 0.1 bbl, then check for launch. Displace dart with KCL using rig pump. Slow rate to 2.0 bpm at 55 away. 2.0 in / 1.3 out rate. Dart landed at 57 bbls (57.5 calc'd) Wiper plug bumped at '66.3. Pressure to 1000psi. Check floats. OK. CIPat 1815 hrs. Unsting 18:30 - 18:50 0.33 CASE P COMP Circulate at TOL. 2.4 in / 2.2 out rate. 18:50 - 20:10 1.33 CASE ~ COMP POOH while chasing out contaminated cement with KCL water. 20:10 - 21:00 0.83 CASE P COMP Lay out Baker CTLRT. M/U jet nozzle and jet BOP stack. 21:00 - 22:00 1.00 CASE P COMP RIH with 26 stds CSH and DS tools. 22:00 - 23:15 1.25 CASE P COMP RIH with CT. Circ 2% KCL water to clean well. 2.3 bpm, 2870 psi. 23:15 - 00:00 0.75 CASE P COMP WOC. Circ with nozzle at 8600 ft. 2.2 / 2.2 bpm, Full returns. 8/26/2001 00:00 - 00:45 0.75 CASE P COMP WOC. 00:45 - 01:00 0.25 CASE P COMP SAFETY MEETING. Review procedure and hazards for pumping Bleach. 01:00 - 01:45 0.75 CASE 'P COMP Clean out liner with nozzle to PBTD of 10,234 ft BKB. 2.3/2.3 bpm, 3000 psi. No sign of cement. Went to PBTD with no wt loss. 01:45 - 02:30 0.75 CASE P COMP Circ. in 20 BBLS Bleach. 2.1 bpm / 3060 psi. Lay in 20 bbls bleach. 02:30 - 04:10 1.67 CASE P COMP POOH while circulating in new 2% KCL water to clean tubing. Clean rig pits. 04:10 - 05:00 0.83 CASE 'P COMP Stand back 26 stds, CSH workstring. 05:00 - 05:20 0.33 CASE P COMP Pressure test liner lap to 500 psi WHP. Press dropped to 50 psi in 4 min. Failed test. 05:20 - 06:00 0.67 CASE N CEMT COMP M/U Baker 4.5" KB Liner top Packer with running tools, 2 its PH6, Hyd disconnect, swivel and CTC. BHA = 84.2 ft. Printed: 10/5/2001 2:50:49PM BP EXPLORATION Page 14 of 14 Operations Summary Report Legal Well Name: M-38 Common Well Name: M-38A Spud Date: 7/19/2001 Event Name: REENTER+COMPLETE Start: 7/18/2001 End: 8/27/2001 Contractor Name: NORDIC CALISTA Rig Release: 8/27/2001 Rig Name: NORDIC I Rig Number: Date From - To Hours :Activity Code NPT Phase Description of Operations 8/26/2001 06:00 - 08:00 2.00 CASE N CEMT I COMP RIH with Baker KB Liner Top Packer. 80 FPM. 30k# up, 20k# dn wt at 8600'. 08:00 - 09:15 1.25 CASE N CEMT COMP Tag TOL at 8705'. Test seals to 1000 psi. Bleed off. Drop 5~8" ball. On seat. Btm out packer. PU to up wt, then 1.5" additional. Pressure up to 2500 psi to set packer. Get off same. Test to 2000 psi. Holding steady. 09:15- 10:30 1.25 CASE N CEMT COMP POOH. 10:30 - 10:45 0.25 CASE N CEMT COMP LD BHA / packer setting tool. 10:45 - 11:00 0.25 CASE N CEMT COMP Hold pre job safety mtg w/crew & HB&R regarding liner lap test. 11:00 - 12:00 1.00 CASE N CEMT COMP Test lines to 1000 psi. Pressure 9-5~8" x tbg ann to 1000 psi. Pressure tubing to 3000 psi for 30 min. Record on chart. Bled down tbg, then ann. 12:00 - 12:15 0.25 PERF P COMP Hold pre job safety mtg for picking up & running guns. 12:15 - 13:45 1.50 PERF P COMP PU SWS 2" HSD guns. Intervals are 9968-9998, 10095-10132, 10175-10206. 12 guns & spacers total. Run on 48jts CSH pipe with MHA & CC. BHA:1764' 13:45 - 15:45 2.00 PERF P COMP RIH w/perf guns. 15:45 - 16:00 0.25 PERF P COMP Hold pre job to discuss pumping bleach. 16:00 - 17:00 1.00 PERF P COMP Drop 5/8" ball On seat at calc'd volume of 58 b. Pressure up, fluid by-passing ball seat (?) Pressure up several times. No good shot indications. Pressure well, injecting at 1.0 bpm @ 1200 psi. Holes some where. 17:00 - 18:15 1.25 PERF P COMP POOH. At surface. 18:15 - 19:15 1.00 PERF P COMP Stand back CSH. 19:15 - 19:30 0.25 PERF P COMP SAFETY MEETING. Review procedures and hazards of handling shot guns. 19:30 - 20:30 1.00 PERF P COMP Lay out perf guns, all shots fired. PERFORATED INTERVALS: 9,968 - 9,998 FT BKB 10,095 - 10,132 FT BKB 10,175 - 10,206 FT BKB 20:30 - 21:45 1.25 RIGD P COMP RIH to 2000 ft and freeze protect 4 1/2" tubing with 23 bbls MEOH. Close Swab valve. 21:45 - 23:30 1.75 RIGD P COMP Clean rig pits. Blow down reel with N2. R/D hardline to tanks. 23:30 - 00:00 0.50 RIGD P COMP Move green tank and vac tanks. 8/27/2001 00:00 - 01:00 1.00 PERF P COMP N/D BOPE. N/U Tree cap and pressure test. RELEASED RIG AT 01:00 HRS, 08-27-01. MOVE RIG TO J-14A. Well secured. Master, Swab and Wing valves shut. WHP = 0 psi. Tubing freeze protected to 2000 ft with MEOH. Printed: 10/5/2001 2:50:49 PM DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU_ WOA M Pad, Slot M-38 M-38A PB1 Job No. AKMW11124, Surveyed: 21 August, 2001 SURVEY REPORT 26 September, 2001 Your Reft APl 500292251970 Surface Coordinates: 5973514.16 N, 628226.59 E (70° 20' 09.1499" N, 148° 57' 34.7341" W) Kelly Bushing: 56. lOft above Mean Sea Level I) RII-'LI NB SERVICE~ A Halliburton Company Survey Ref: svy10957 Sperry-Sun Drilling Services Survey Report for M-38A PB1 Your Ref: AP1500292251970 Job No. AKMW11124, Surveyed: 21 August, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (fi) Local Coordinates Global Coordinates Northings Eastlngs Northings Eastings (ft) (ft) (fi) (ft) 8809.00 8.200 130.500 8466.73 8522.83 1045.57 S 1716.05 E 8855.00 7.750 129.120 8512.29 8568.39 1049.66 S 1720.95 E 8894.17 20.680 141.260 8550.19 8606.29 1056.75 S 1727.35 E 8925.57 35.950 147.580 8577.75 8633.85 1068.93 S 1735.82 E 8955.37 45.090 160.240 8600.42 8656.52 1086.31 S 1744.11 E 8990.27 58.540 159.090 8621.95 8678.05 1111.97 S 1753.64 E 9026.67 74.180 158.300 8636.50 8692.60 1142.93 S 1765.73 E 9058.47 82.700 164.980 8642.87 8698.97 1172.47 $ 1775.50 E 9090.07 84.990 172.890 8646.27 8702.37 1203.27 S 1781.52 E 9129.07 88.070 183.790 8648.63 8704.73 1242.12 S 1782.64 E 5972498.08 N 629960.26 E 5972494.08 N 629965.23 E 5972487.10 N 629971.76 E 5972475.06 N 629980.43 E 5972457.83 N 629989.02 E 5972432.34 N 629998.99 E 5972401.59 N 630011.61 E 5972372.22 N 630021.88 E 5972341.52 N 630028.43 E 5972302.70 N 630030.21 E 9159.67 95.800 192.400 8647.60 8703.70 1272.35 S 1778.35 E 5972272.40 N 9199.67 93.160 201.190 8644.47 8700.57 1310.48 $ 1766.83 E 5972234.08 N 9232.51 93.780 212.090 8642.47 8698.57 1339.74 $ 1752.16 E 5972204.58 N 9265.91 95.890 221.940 8639.65 8695.75 1366.28 $ 1732.15 E 5972177.70 N 9299.31 99.320 232.130 8635.22 8691.32 1388.82 $ 1707.97 E 5972154.75 N 9326.00 99.320 232.130 8630.90 8687.00 1404.99 S 1687.18 E 5972138.23 N All data is in Feet (US) 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 26.485° (18-Jul-01) 630026.43 E 630015.57 E 630001.40 E 629981.85 E 629958.06 E 629937.55 E The Dogleg Severity is in Degrees per 100 feet (US), Vertical Section is from Well Reference and calculated along an Azimuth of 140.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9326.00ft., The Bottom Hole Displacement is 2195.58ft., in the Direction of 129.786° (True). Dogleg Rate (°/100fi) 1.063 33.699 49.496 41.140 38.624 43.013 33.771 25.919 28.990 37.785 22.878 33.184 30.056 31.932 0.000 Alaska Drilling & Wells PBU_WOA M Pad Vertical Section Comment 1904.01 1910.29 1919.84 1934.61 1953.26 1979.04 2010.53 2039.43 2066.90 2O97.38 2117.78 2139.59 2152.57 2160.04 2161.76 2160.78 Tie On Point MWD Magnetic Window Point Projected Survey 26 September, 2001 - 12:30 Page 2 of 3 DrillQues t 2. 00. 08. 005 Sperry-Sun Drilling Services Survey Report for M-38A PB1 Your Ref: AP1500292251970 Job No. AKMW11124, Surveyed: 21 August, 2001 North Slope Alaska Alaska Drilling & Wells PBU_WOA M Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8809.00 8522.83 1045.57 S 1716.05 E 8855.00 8568.39 1049.66 S 1720.95 E 9326.00 8687.00 1404.99S 1687.18 E Comment Tie On Point Window Point Projected Survey Survey tool program for M-38A PB1 From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 8809.00 8522.83 8809.00 8522.83 9326.00 8687.00 Survey Tool Description AK-3 BP_HM - BP High Accuracy Magnetic (M-38) MWD Magnetic (M-38A PB1) 26 September, 2001 - 12:30 Page 3 of 3 DrillQ~est 2. 00.08. 005 North Slope Alaska Alaska Drilling & Wells PBU_ WOA M Pad, Slot M-38 M-38A Job No. AKMW11124, Surveyed: 25 August, 2001 DEFINITIVE SURVEY REPORT 26 September, 2001 Your Ref: AP1500292251901 Surface Coordinates: 5973514.16 N, 628226.59 E (70° 20' 09.1499" N, 148° 57' 34.7341" W) Kelly Bushing: 56. lOft above Mean Sea Level OIq I !, L~ I'N (S' A Halliburton Company Survey Ref: svy10958 Sperry-Sun Drilling Services Survey Report for M-38A Your Ref: APl 500292251901 Job No. AKMW11124, Surveyed:25 August, 2001 North Slope Alaska Measured Depth (ft) Incl. Az|m. Sub-Sea Depth (ft) Vertical Depth (ft) 8894.17 20.680 141.260 8550.19 8606.29 8895.00 20.720 141.440 8550.96 8607.06 8926.09 25.750 144.980 8579.52 8635.62 8951.89 35.430 147.980 8601.71 8657.81 8964.89 40.250 148.990 8611.97 8668.07 8997.29 54.230 150.920 8633.92 8690.02 9031.49 68.200 152.150 8650.34 8706.44 9058.29 79.450 156.190 8657.80 8713.90 9095.29 94.660 160.060 8659.70 8715.80 9126.29 98.260 172.540 8656.19 8712.29 8652.17 8647.56 8644.58 8644.16 8644.52 9155.29 97.650 182.210 9188.29 98.350 195.390 9218.89 92.810 205.940 9251.09 88.680 214.900 9280.29 89.910 226.330 8708.27 8703.66 8700.68 8700.26 8700.62 9314.09 87.890 237.230 8645.17 8701.27 9344.29 89.820 246.550 8645.77 8701.87 9378.48 93.740 256.780 8644.71 8700.81 9416.88 98.060 262.770 8640.76 8696.86 9454.68 98.330 268.410 8635.37 8691.47 9493.48 95.330 273.870 8630.75 8686.85 9530.48 91.370 276.330 8628.59 8684.69 9561.48 88.370 278.800 8628.66 8684.76 9593.08 89.160 284.790 8629.34 8685.44 9628.48 88.990 288.320 8629.91 8686.01 9661.48 88.720 294.130 8630.57 8686,67 9691.48 88.810 298.540 8631.22 8687.32 9725.08 89.430 302.940 8631.73 8687.83 9757.48 89.430 306.820 8632.06 8688.16 9795.28 88.370 311.750 8632.78 8688.88 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1056.75 S 1727.35 E 5972487.10 N 629971.76 E 1056.98 S 1727.54 E 5972486.87 N 629971.95 E 1066.82 $ 1734.85 E 5972477.16 N 629979.42 E 1077.78 S 1742.05 E 5972466.33 N 629986.81 E 1084.58 S 1746.21 E 5972459.60 N 629991.09 E 1105.14 S 1758.05 E 5972439.24 N 630003.28 E 1131.43S 1772.28 E 5972413.20 N' 630017.96 E 1154.57 S 1783.45 E 5972390.25 N 630029.52 E 1188.75S 1797.17 E 5972356.31 N 630043.82 E 1218.61S 1804.46 E 5972326.58 N 630051.62 E 1247.27 S 1805.77 E 5972297.95 N 630053.42 E 1279.49 S 1800.79 E 5972265.65 N 630048.99 E 1307.93 S 1790.05 E 5972237.03 N 630038.74 E 1335.66 S 1773.76 E 5972209.03 N 630022.93 E 1357.78 S 1754.79 E 5972186.58 N 630004.34 E 1378.66 S 1728.28 E 5972165.25 N 629978,19 E 1392.87 S 1701.68E 5972150.59 N 629951.83 E 1403.61 S 1669.29 E 5972139.30 N 629919.63 E 1410.39 S 1631.73E 5972131.88 N 629882.19 E 1413.27 S 1594.44E 5972128.36 N 629844.96 E 1412.49 S 1555.94E 5972128.48 N 629806.46 E 1409.21 S 1519.16 E 5972131.13 N 629769.62 E 1405.13 S 1488.44E 5972134.69 N 629738.84 E 1398.67 S 1457.53 E 5972140.61 N 629707.82 E 1388.59 S 1423.60E 5972150.11 N 629673.73 E 1376.65 S 1392.86 E 5972161.53 N 629642.79 E 1363.35 S 1365.99E 5972174,37 N 629615.69 E 1346.18 S 1337.12 E 5972191.04 N 629586.53 E 1327.66 S 1310.55 E 5972209.11 N 629559.65 E 1303.73S 1281.30 E 5972232.52 N 629530.00 E Dogleg Rate (°/100ft) 9.055 16,784 37.973 37.381 43.365 40.968 44.395 42.407 41.646 33.090 39.606 38.784 30.632 39.366 32.790 31.508 32.024 19.162 14.785 15.967 12.593 12.535 19.115 9.982 17.622 14.700 13.223 11.975 13.338 Alaska Drilling & Wells PBU_WOA M Pad Vertical Section Comment 1963.40 Tie On Point 1963.69 Window Point 1975.84 1988.70 1996.47 2019.45 2O48.2O 2072.55 2106.57 2133.01 2154.41 2173.96 2186.77 2195,20 2197.75 2194.13 2185.68 2170.70 2149.28 2125.25 2097.78 2069.71 2045.30 2019.07 1988.14 1958.10 1929.80 1897.34 1865.51 1827.96 26 September, 2001 - 12:34 Page 2 of 4 DrillQuest 2. 00. 08. 005 SPerry-Sun Drilling ServiceS Survey Report for M-38A Your Ref: APl 500292251901 Job No. AKMW11124, Surveyed: 25 August, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (fi) Local Coordinates Global Coordinates Northings Eastlngs Northings Eastings (ft) (ft) (fi) (ft) 9854.08 88.990 322.150 8634.14 8690.24 1260.84 S 1241.23 E 5972274.73 N 629489.20 E 9888.68 90.310 329.020 8634.35 8690.45 1232.31 S 1221.69 E 5972302.92 N 629469.17 E 9917.88 89.250 329.370 8634.46 8690.56 1207.23 S 1206.74 E 5972327.74 N 629453.79 E 9946.48 87.140 325.670 8635.37 8691.47 1183.12 S 1191.39 E 5972351.58 N 629438.03 E 9982.48 86.430 320.390 8637.39 8693.49 1154.42 S 1169.78 E 5972379.91 N 629415.94 E 10008.48 87.840 317.220 8638.69 8694.79 1134.88 S 1152.68 E 5972399.16 N 629398.51 E 10040.08 89.600 312.810 8639.39 8695.49 1112.54 $ 1130.35 E 5972421.11 N 629375.80 E 10074.28 87.750 311.750 8640.18 8696.28 1089.54 $ 1105.06 E 5972443.67 N 629350.12 E 10109.48 83.880 314.040 8642.75 8698.85 1065.65 $ 1079.34 E 5972467.12 N 629324.00 E 10143.28 80.350 312.110 8647.39 8703.49 1042.79 S 1054.90 E 5972489.56 N 629299.16 E 10171.88 78.850 309.110 8652.55 8708.65 1024.48 S 1033.54 E 5972507.50 N 629277.50 E 10209.88 79.470 302.770 8659.71 8715.81 1002.59 S 1003.34 E 5972528.87 N 629246.93 E 10237.48 80.970 299.240 8664.40 8720.50 988.58 S 980.03 E 5972542.48 N 629223.38 E 10270.00 80.970 299.240 8669.50 8725.60 972.89 S 952.01 E 5972557.69 N 629195.09 E All data is in Feet (US) 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 26.485° (18-Jul-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 135.622° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10270.00ft., The Bottom Hole Displacement is 1361.19ft., in the Direction of 135.622° (True). Dogleg Rate (°/100ft) 17.714 20.218 3.823 14.887 14.776 13.330 15.022 6.234 12.765 11.877 11.573 16.467 13.725 0.000 Alaska Drilling & Wells PBU_WOA M Pad Vertical Section Comment 1769.28 1735.22 1706.84 1678.87 1643.24 1617.32 1585.74 1551.60 1516.55 1483.11 1455.09 1418.32 1392.01 1361.19 Projected Survey 26 September, 2001 - 12:34 Page 3 of 4 Dr#/Quest 2. 00. 08. 005 Sperry-Sun Drilling Services Survey Report for M-38A Your Ref: APl 500292251901 Job No. AKMW11124, Surveyed: 25 August, 2001 North Slope Alaska Alaska Drilling & Wells PBU_WOA M Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8894.17 8606.29 1056.75 S 1727.35 E 8895.00 8607.06 1056.98 S 1727.54 E 10270.00 8725.60 972.89 S 952.01 E Comment Tie On Point Window Point Projected Survey Survey tool program for M-38A From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 8809.00 8522.83 8809.00 8522.83 10270.00 8725.60 Survey Tool Description AK-3 BP_HM - BP High Accuracy Magnetic (M-38) MWD Magnetic (M-38A PB1) 26 September, 2001 - 12:34 Page 4 of 4 DrillQuest 2. 00. 08.005 26-Sep-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well M-38A Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,894.17' MD 8,895.00' MD 10,270.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) SEp 2 7 2001 26-Sep-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well M-38A PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and,1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,809.00' MD 8,855.00' MD 9,326.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED S£P 2 7 2001 Alas~,a ~i ,~ Gas Cons, Co~]~ission An~rage WELL LOG 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. P. O. Box 1369 Stafford, TX 77497 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 -- M-38Ai 9/2/01 Res. Eval, CH I I 1 Mech. CH I . , Caliper Survey Print Name: Date · Ata~, 011 & G~ Cons. Con~n~n PRoA¢fiv£ Di^q~o~fi¢ $£RviC~, I~¢., ~10 K SmE~ Suh~ ;200, AN¢~OR^qE, Al( 99~O1 STATE OF ALASKA ~'~' ALASKA OIL AND GAS CONSERVATION COMM~o~ION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2438' NSL, 605' WEL, SEC. 01, T11N, R12E, UM At top of productive interval 1380' NSL, 1124' EWL, SEC. 06, T11N, R13E, UM At effective depth At total depth 1326' NSL, 340' EWL, SEC. 06, T11 N, R13E, UM (As Planned) 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE: 56.10' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number M-38Ai 9. Permit Number 201-132 10. APl Number 50- 029-22519-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured Effective depth: Casing 9525 feet true vertical 9235 feet measured 8756 feet true vertical 8470 feet Length Structural Conductor 110' Surface 3079' Intermediate Production 9487' Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) Plugs (measured) Junk (measured) Set Cement Retainer at 8910' (07/01) Abandon M-38 Perfs, TOC at 8756' (07/01) Size Cemented MD TVD 20" 260 sx Arcticset 110' 110' 10-3/4" 1231 sx CS III, 375 sx Class 'G' 3110' 3036' 7-5/8" 1038 sx Class 'G' 9518' 9228' RECEIVED JUL 2 7 2001 Alaska 0il & Gas Cons. Commis$1.0n /~chorage 4-1/2", 12.6#, L-SO to 8785'; 4-1/2", 12.6#, L-80 9090' to 9101' Packers and SSSV (type and measured depth) 7-5/8" x 4-1/2" Baker 'FB-I' packer at 9090'; 7-5/8" x 4-1/2" TIW 'HBBP packer at 8738'; 4-1/2" SSSV Landing Nipple at 2096' 13. Attachments [] Description Summary of Proposal 4. Estimated date for commencing operation July 25, 2001 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Mary Endacott, 564-4388 [] Detailed Operations Program [] BOP Sketch Status of well classifications as: [] Oil [] Gas [] Suspended Service Water & Gas Injector Prepared By Name/Numbec Terrie Hubble, 564-4628 17. I hereby certify that the f_oregoing is true and correct to the best of my knowledge Signed MSEndac0tt~~ ~ ~ Title CT Drilling Engineer Date ~'")?,'2~'-0/ J ..:':: .:. ,."~'.:::'.' ':". ~,':."': :'!':.. :: :.., .i'..:," :.'.'~"!.'.', :!. '::::, :: ':.!.'.::'.:,' i;::.:':,;.!..:,.i .; ,::'; i.':":'.:'.'i,:..~:;:i.'i' ::,,i,!:::::i;':~...: i'i'?'."?:':?,',"~ii'' ~i':..,,?:"! :.iic0:~i~;fs~i~!n,,: ,.u~e,...:i0,,:aly;'. . :!,~" ....;,.?: Conditions of Approval: Notify Commission so representative may witness I Approva Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test ~'~[l~,~q~[~ru~qYuired 10- O J. ~. ~eusser Approved by order of the Commission Commissioner Date ~*c~[--~- (~ ev. 0 i i A[ Submit In T-riplicate ' Hubble, Terrie L From: Sent: To: Subject: Endacott, Mary S Wednesday, July 25, 2001 5:19 PM Hubble, Terrie L M-38 halt of drlg operations Terrie Nordic 1 has moved from M-38 to M-24. After two attempted windows off cement whipstocks, we gave up. In the mean time of waiting the arrival and installation of a mechanical whipstock, we have moved to M-24 and may go to M-03 before returning to M-38. Please prepare a halt of operations on M-38a thanks, Mary S. Endacott Coil Tubing Drlg Engr 907-564-4388 737c endacoms@bp.com ALASKA OIL AND GAS CONSERYA~ION CO~TISSION John Cubbon CR Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 TONY KNOWLES, GOVERNOR 333 W. Tm AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re; Prudhoe Bay Unit M-38A BP Exploration (Alaska) Inc. Permit No: 201-132 Sur. Loc. 2438; NSL, 605' WEL, SEC. 01, T1 IN, R12E, UM Btmhole Loc. 1326' NSL, 340' EWL, SEC. 06, T1 IN, R13E, UM Dear Mr. Cubbon: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and dOes not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit M-38A. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Commissioner BY ORDER OF ~HE COMMISSION DATED this/~T~lay of.Mom~, 2001 jjc/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . STATE OF ALASKA CO~{''' .,,,: .-'11~ ~ ALASi,~'' OIL AND GAS CONSERVATION .... ,SSION .~.~,,,¢( [ PERMIT TO DRILL 20 AAC 25.005 1a. Type of work I-I Drill [] Redrill 11 b. 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 = 56.10' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028282 ~.¢zCz~ ~, 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 A~,C 25.025) 2438' NSL, 605' WEL, SEC. 01, T11N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1380' NSL, 1124' EWL, SEC. 06, T11N, R13E, UM M-38A Number 2S100302630-277 At total depth 9. Approximate spud date 1326' NSL, 340' EWL, SEC. 06, T11 N, R13E, UM 07/10/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028260, 340' MDI No Close Approach 2560 10341' MD / 8980' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)) Kick Off Depth 8840' MD Maximum Hole An~lle 92 ° Maximum surface 2237 psig, At total depth (TVD) 8800' / 3300 psig 18. Casing Program Specifications Setting Depth Rize T¢ D Dot om Quantity of Cement Hole Casina Weiaht Grade CouDlina ~.ength MD TVD MD TVD (include ~taqe d~;a) 3-3/4" 3-3/16"x2-7/8"4.6# L-80 ST-L 1586' 8755' 8413' 10341' 8980' 64 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. J U L 0 ?~ Z 0 01 Present well condition summary Total depth: measured 9525 feet Plugs (measured) Alaska 0il & Gas Cons. Commission true vertical 9235 feet Anchorage Effective depth: measured 9432 feet Junk (measured) true vertical 9142 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 260 sx Arcticset 110' 110' Surface 3079' 10-3/4" 1231 sx CS III, 375 sx Class 'G' 3110' 3036' Intermediate Production 9487' 7-5/8" 1038 sx Class 'G' 9518' 9228' Liner Perforation depth: measured 8950' - 9020', 9245'- 9285' true vertical 8663' - 8732', 8956' - 8996' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 2§.050 Requirements Contact Engineer Name/Number: John Cubbon,~5r6[¢-4158 Prepared By Name/Number: Terrie Hubble, 564-4628 21.1 hereby certify that the f~j~' iCa/e/and correct to the best of my knowledge / / Signed John Cubbon f~/ ' --'~/!~, ~ Title CT Drilling Engineer Date , .... '.. ...... '~'~'~/ .... ,-.. : . ...., f :.~',..... ;~; ..... .: ~ . . .,.. ; ... ,, ...:~.. ,. ',..~,,: , i., ;.; ':...:.;. ,.;, , ; .,., ........ : . :. /. ~.. . .... . .,. ~ ,.. ,.'. ,...:; .,:,' :::'.....,'...~. "::...:.':." ;...:~' ;':,',.:'.i.'"' ':.:'..": .... ,.. :,;'..'.'~,., ........ : "..:,' '.,'.::,.'~Om:mls~'.O,"n, Use~::Onl¥ '..:.' ..',.: ' ::" :::'::'.:',:"~."::~.. .;:.. :.',:, .'..::" '.,.:;'::.';;L.':.",.~:.: .:' .,.':'::. ,'.:.,, ".:'.,,...:.":'.';:: ..."., ',..:.,:.,:" · ""' '"~/,I"i'"'""Api'NU'mb;';'"' "".'.' ". "..' ~ ..... ,.,.'.' ...................... "'"""'" '"' i'"'" '""'";':'-~L'-"-'-:l/~pprova 'D~te ' '"' I' See"~o"v'~'le~te; ' '' "'" .;2_O{"' /~'~-~ IJ 150.029.22519.01 ] '"'7'1' '"-(") ! I f°r°therrequirements Conditions of Approval: Samples Required I'"]' Ye~" ~No' Mud Log Required [] .Yes I~No Hydrogen Sulfide Measures I~rYes r--i No Directional Survey Required .l~es [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ,~[I,,3.5K psi for CTU Other: ORIGINAL SIGNED BY by order of Approved By D Taylor Seamount Commissioner the commission Date Form 10-401 Rev. 12-01-85 ORIGINAl S Triplicate BPX M-38Ai Sidetrack Summary of Operations: A CTD sidetrack of well M-38A will be drilled. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Isolate & integrity test inner annulus, (IA). Drift/caliper liner and set whipstock. Mill window if service coil is available. Planned for July 3, 2001 · Drift well with dummy whipstock and caliper liner near setting depth. · Integrity test IA after displacing to seawater. · Set a mechanical plug in the tubing at approximately 9,098' MD to abandon the perforations 9,245'- 9,285' · Set through tubing whipstock using E-line at approximately 8,840'. (A cement whipstock may be substituted) · Service coil will use approximately 15 barrels of cement to abandon the remaining perforations located between the mechanical plug and the whipstock. (This step may be eliminated if a cement whipstock is utilized.) · Mill window with service coil if available. Phase 2: Drill and Complete CTD sidetrack: Planned for July 10, 2001 2-3/8" coil will be used to drill a ,-,1500 foot, 3-~,4'' open hole sidetrack, (as per attached plan) and run a solid, cemented & perforated 3-3/16" x 2-7/8" liner completion. Mud Program: · Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 3-3/16" x 2-7/8", L-80, solid liner will be run from approximately 8,755'md (8,413' TVDss) to TD at approx 10,340'md. Liner will be cemented in place with approximately 13 bbls (annular volume plus 25% excess in OH) of 15.8ppg class G cement. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2200 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log will be run over the open hole section. · A memory CNL will be run inside the liner. Hazards The H2S concentration for M-38 has not been recently recorded. However, the maximum concentration of H2S on "M" pad is 120 ppm at M-04. The well-path will cross I mapped fault. The risk of lost circulation at this fault is moderate due to the fact that the fault's strike is parallel to the maximum stress direction. Reservoir Pressure Res. pressure is estimated to be 3300 psi at 8800ss. Maximum surface pressure with gas (0.12 psi/fi) to surface is 2237 psi. TREE = 4-1/6" CIVV WELLHEAD= 13-5/8" - 5M FMC UN~/ERSAL ACTUATOR= SLIMHOLE KB. ELEV = 56.5 BF. ELEV = 26 KOP = 1350 Max Angle = 19 @ 2413' Datum MD = 9,145' I Datum TVDss= 8800' SS M-38Ai~' PROPOSED CTD SIDETRAC'I~ 10-3/4" CSG, 45.5#, L-80, 113=9.953 ~ 3110' 2096' 4-1/2" sssv LAND NIP, OTIS X, ID=3.813 J JMinimum ID = 3.725" @ 9099' 4-1/2" OTIS XN NIPPLE 8676' J-~ 4-1/2" OTIS X NIP, ID=3.813 J J 4 -1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID=3.958 JMill Window off Mechanical Whipstock 8739' I-I 7-5/8" x 4-1/2" TIW HBBP Pt(R, ID=4.0 I 8773' I-~ 4-1/2" OTIS X NIP, ID=3.813 I 8783' I--~ 4-1/2 TBG TAIL 8783' I-I JP&A'd w/Cement J I TOPOF4'I/2"TBG Id 9090' 1 N ·" ·~ . I ANGL~"X¥¥b'~'~ ......... 16 ~ 8950' I ~te: Refer to ~oduction DB for historical pe~ data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8 6 8950-9020 O 1/18/95 3-3/8 6 9245-9285 O 10/11/95 I-i 9432' I I 7-5/8" CSG, 29.7#,L-80, ID=6.875 Id 9518' 8900' I--'"~ 3-3/16" to 2-7/8" XO I I 3-3/4" Open Hole I 2-7/8" 4.6# L-80 LINER, Cemented & Perforated Id 10: ---{ 9090' I--[7-5/8" x 4-1/2" BAKER ISOLATION PKR ] 9098' I~ 4-1/2" OTIS XN NIP, ID=3.725 I 9099' I--~ 4-1/2 'I'BG TAIL 9099' I--i DATE REV BY COMMENTS 11/17/94 ORIGINAL COMPLETION 2/27/01 SIS-lsl CONVERTED TO CANVAS 3/14/01 SIS-MD FINAL 04/10/01 pcr Proposed CT Sidetrack PRUDHOE BAY UNIT WELL: M-38Ai Proposed ST PERMIT No: 94-1410 AF~ No: 50-029-22519-00 Sec. 6, T11N, R13E BP Exploration (Alas ka) O bP BP Amoco Baker Hughes INTEQ Planning Report INTEQ' Company: 'BP,~,6 · · . Field: . Prudhoe Bay ':Site: PB M Pad · Well: M-38 Wellpath: Plar~4 M-38A , ..:. ,Veilical (TVD)'Ref~i'~e:=.": .,.,:',, ;' S~st~m:' M~_~n Sea Level :' , ',.'::S~'¢ii.~&'(~,S)Refer;efi'.~(';~. :': ;::.:.'.!;.Well (0:00N.0..00E,140.00Azi) ' . '" '" ' Survey"CalCu~tioa'Mahod: '5,9. 'Minimum Curvature '.-..Db: Oracle .. __ Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Ceo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: PB M Pad TR-11-12 UNITED STATES: North Slope Site Position: Northing: From: Map Lasting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5971246.37 ft 626262.80 ft Latitude: 70 19 47.175 N Longitude: 148 58 33.196 W North Reference: True GHd Convergence: 0.96 deg Well: M-38 M-38 Well Position: +N/-S 2234.05 ft Northing: 5973513.61 ft +E/-W 2001.95 ft Easting: 628226.71 ft Position Uncertainty: 0.00 ft Slot Name: 38 Latitude: 70 20 9.144 N Longitude: 148 57 34.731 W Wellpath: Plan~4 M-38A Drilled From: M-38 500292251901 Tie-on Depth: 8840.00 ft Current Datum: 53: 38 11/5/1994 00:00 Height 56.10 ft Al)eve System Datum: Mean Sea Level Magnetic Data: 4/11/2001 Declination: 26.56 dog Field Strength: 57465 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ' 0.00 0.00 0.00 140.00 Plan: Plan fi4 Date Composed: 4/11/2001 Lamar's Plan #4 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets Name TvD:: :: M-38A T4.2 8627.00 -1442.91 1749.78 M-38A T4.3 8627.00 -1284.63 1252.29 M-38A T4.1 8640.00 -1194.58 1853.92 M-38A T4.4 8775.00 -1131.32 1054.79 M-38A T4.5@TD 8980,00 -1105.17 985.21 :'.: :.'~ ]:: <--'] Latitudel "'> , <--: Longitude -'>. !:::,,,, ,':: Deg i:M:in? ,sec: ::']: Deg Mia ':' Sec ' 5972100.94 630000.76 5972250.68 629500.68 5972351.00 630100.62 5972400.58 629300.60 5972425.54 629230.58 70 19 54,952 N 70 19 56.509 N 70 19 57,394 N 7O 19 58,017 N 70 19 58.275 N 148 56 43.640W 148 56 58.165W 148 56 40.598W 148 57 3.931W 148 57 5.963W Annotation 8809.00 8466.73 8840.00 8497.43 9077.03 8640.79 9377.03 8633.60 9398.04 8633.25 9723.04 8633.25 10340.53 8979.90 TIP KOP 1 2 3 4 TD O bP BP Amoco Baker Hughes INTEQ Planning Report Field:':.!"..~:;??..'Pmdh'0e Bay':.... : Sit~:?:~:'~ ::: ".::.'PB M pad "..':,"" , · :W:ai:'~'!: "~.::'.::M-,.~ ':'. :' '., :':' ~"., .We!lp~th:.':::.?la .~..: M-38A::' Date: .:.:411.'1../2001:'.-: 'i .... .Time: i4:00:42 . '" 'Page: 3' ... · Co-ordinate(NE) Reference: ' '.. Well: M.-38,..True North . Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Re'fer~6ce: , Well (0.00N,0.00E,140.00Azi) Survey Calculation Method: Minimum Curvature . ' Db: Oracle Plan Section Information '" ": MD, .':: ,",.. ': [ncl. TYD .: ,..,:+N/.-S !i.::}:';':.:;','~;W,, :i, ;,,.::',-:..::,..',:DLS':?::?BUild :;':?,.'!..i~,~lira,:...::!.i:).: f::~: 3'[~ :.!','!.~ :!l-arg~ ,..:: ,': .,.'-...... ': ,' i':' ",' .... ..,~:.'.:fl ,::.,:,' '.::.,:: deg. :deg ' '.fl. :.". "..?.:?:.:i?:~:?':ft:'.,:i?:..:,.,?'deg/~0.0ft'::deg/!C~..ffd~i00fft :. :.:i.deg.:!,...,-.."..:.:.:..:?..':,.".'.'-":i '.; :: :.: ' 8809.00 8.20 130.50 8466.73 -1045.49 1716.08 0.00 0.00 0.00 0.00 8840.00 7.89 129.65 8497.43 -1048.28 1719.40 1.07 -1.00 -2.74 200.57 9077.03 90.00 156.43 8640.79 -1193.61 1792.57 35.00 34.64 11.30 27.00 9377.03 91.93 261.44 8633.60 -1420.90 1667.04 35.00 0.64 35.00 88.00 9398.04 90.00 263.06 8633.25 °1423.73 1646.22 12.00 -9.19 7.71 140.00 9723.04 90.00 302.06 8633.25 -1354.42 1335.09 12.00 0.00 12.00 90.00 10340.64 15.90 302.06 8979.90 -1110.68 945.92 12.00 -12.00 0.00 180.00 Survey ,':::::,'.'.'.MD' ":":' :' :" Incl ':' : .AZtm :,:",:.':::: ':,: :SSTyD .::,.: ,::' ,:":' '..' ,'=i"fl .,?. "deg ,: , ," deg..,;::' ~; ,, ... fl,.:,; .: ,:'"'!:':.': ','., 8809.00 8.20 130.50 8466.73 -1045.49 1716.08 5972497.70 629960.27 0.00 1903.97 0.00 TI P 8825.00 8.04 130.07 8482.57 -1046.95 1717.80 5972496.26 629962.02 1.07 1906.19 200.57 MWD 8840.00 7.89 129.65 8497.43 -1048.28 1719.40 5972494.96 629963.64 1.07 1908.24 201.00 KOP 8850.00 11.12 137.91 8507.29 -1049.43 1720.58 5972493.83 629964.83 35.00 1909.88 27.00 MWD 8875.00 19.60 146.33 8531.38 -1054.72 1724.52 5972488.61 629968.87 35.00 1916.47 18.85 MWD 8900.00 28.25 149.76 8554.21 -1063.34 1729.84 5972480.08 629974.33 35.00 1926.49 10.70 MWD 8925.00 36.94 151.67 8575.25 -1075.09 1736.40 5972468.45 629981.09 35.00 1939.70 7.57 MWD 8950.00 45.65 152.93 8594.02 -1089.69 1744.04 5972453.99 629988.98 35.00 1955.80 5.95 MWD 8975.00 54.37 153.87 8610.07 -1106.80 1752.60 5972437.02 629997.83 35.00 1974.41 5.00 MWD 9000.00 63.10 154.61 8623.03 -1126.03 1761.88 5972417.96 630007.43 35.00 1995.10 4.40 MWD 9009.29~ 66.34 154.86 8627.00 -1133.62 1765.46 5972410.43 630011.14 35.00 2003.22 4.01 M-38A 9025.00 71.83 155.26 8632.61 -1146.93 1771.65 5972397.23 630017.56 35.00 2017.39 3.90 MWD 9050.00 80.56 155.84 8638.57 -1169.01 1781.68 5972375.33 630027.97 35.00 2040.76 3.76 MWD 9075.00 89.29 156.39 8640.78 -1191.75 1791.76 5972352.76 630038.43 35.00 2064.66 3.62 MWD 9077.03 90.00 156.43 8640.79 -1193.61 1792.57 5972350.92 630039.27 35.00 2066.60 3.57 1 9100.00 90.28 164.46 8640.73 -1215.24 1800.25 5972329.43 630047.32 35.00 2088.11 88.00 MWD 9125.00 90.58 173.21 8640.55 -1239.74 1805.09 5972305.01 630052.58 35.00 2109.98 88.02 MWD 9150.00 90.86 181.96 8640.23 -1264.69 1806.14 5972280.08 630054.06 35.00 2129.77 88.09 MWD 9175.00 91.13 190.70 8639.80 -1289.51 1803.39 5972255.22 630051.73 35.00 2147.02 88.20 MWD 9200.00 91.36 199.45 8639.25 -1313.62 1796.89 5972231.01 630045.65 35.00 2161.31 88.35 MWD 9225.00 91.57 208.20 8638.61 -1336.46 1786.80 5972208.00 630035.95 35.00 2172.32 88.54 MWD 9250.00 91.74 216.95 8637.89 -1357.50 1773.36 5972186.74 630022.87 35.00 2179.80 88.76 MWD 9275.00 91.87 225.71 8637.10 -1376.24 1756.88 5972167.72 630006.71 35.00 2183.56 89.02 MWD 9300.00 91.96 234.46 8636.26 -1392.26 1737.73 5972151.38 629987.84 35.00 2183.52 89.29 MWD 9325.00 92.00 243.22 8635.40 -1405.18 1716.37 5972138.10 629966.71 35.00 2179.69 89.59 MWD 9350.00 91.99 251.97 8634.53 -1414.69 1693.29 5972128.19 629943.80 35.00 2172.14 89.89 MWD 9375.00 91.94 260.73 8633.67 -1420.58 1669.04 5972121.89 629919.65 35.00 2161.06 90.20 MWD 9377.03 91.93 261.44 8633.60 -1420.90 1667.04 5972121.53 629917.66 35.02 2160.03 90.54 2 9398.04 90.00 263.06 8633.25 -1423.73 1646.22 5972118.35 629896.89 11.99 2148.81 139.98 3 9400.00 90.00 263.30 8633.25 -1423.96 1644.27 5972118.08 629894.95 12.00 2147.74 90.00 MWD 9425.00 90.00 266.30 8633.25 -1426.23 1619.38 5972115.39 629870.10 12.00 2133.47 90.00 MWD 9450.00 90.00 269.30 8633.25 -1427.19 1594.40 5972114.00 629845.14 12.00 2118.15 90.00 MWD 9475.00 90.00 272.30 8633.25 -1426.85 1569.41 5972113.92 629820.15 12.00 2101.82 90.00 MWD 9500.00 90.00 275.30 8633.25 -1425.19 1544.46 5972115.15 629795.18 12.00 2084.52 90.00 MWD 9525.00 90.00 278.30 8633.25 -1422.23 1519.64 5972117.68 629770.32 12.00 2066.30 90.00 MWD 9550.00 90.00 281.30 8633.25 -1417.98 1495.01 5972121.51 629745.62 12.00 2047.21 90.00 MWD 9575.00 90.00 284.30 8633.25 -1412.44 1470.63 5972126.63 629721.15 12.00 2027.30 90.00 MWD 9600.00 90.00 287.30 8633.25 -1405.64 1446.58 5972133.02 629696.99 12.00 2006.63 90.00 MWD 9625.00 90.00 290.30 8633.25 -1397.59 1422.92 5972140.67 629673.19 12.00 1985.25 90.00 MWD 9650.00 90.00 293.30 8633.25 -1388.31 1399.71 5972149.55 629649.83 12.00 1963.22 90.00 MWD 9675.00 90.00 296.30 8633.25 - 1377.82 1377.01 5972159.64 629626.96 12.00 1940.60 90.00 MWD 9700.00 90.00 299.30 8633.25 -1366.17 1354.90 5972170.92 629604.65 12.00 1917.46 90.00 MWD 9723.04 90.00 302.06 8633.25 - 1354.42 1335.09 5972182.32 629564.65 12.00 1895.73 90.00 4 BP Amoco Baker Hughes INTEQ Planning Report ENT£Q' -Field: .' ~: .. :'Prudl~0e'Bay ::' :'." ~" :-';-:::/,'. Ce-ordina{~(N'£) Reference: ...'WelI:.M:38,.Tmo North ': ".. ,Sitg: ' -PB M Pad - ... ' :, "-:"':,i '.":'i ~:, Vertical O'VD) Reference:' System: Mean Sea Level "Well: '. :M,38'::'i i '::.' "~.. '. -.: : ...:. ~.' · .~ction (VS) Reference: . , "Well (0.00N,0.OOE,140.00Azi) :Weilpath: .:.. Plang4.M~38A '.'.~, ,' Survey Calculation Me~hod: Minimum Curvature · , Db: ' Oracle Survey 9725.00 89.76 302.06 8633.25 -1353.38 1333.43 5972183.33 629582.97 12.00 1893.86 180.00 MWD 9750.00 86.76 302.06 8634.01 -1340.12 1312.25 5972196.23 629561.57 12.00 1870.09 180.00 MWD 9775.00 83.76 302.06 8636.07 -1326.89 1291.14 5972209.09 629540.24 12.00 1846:39 180.00 MWD 9800,00 80.76 302.06 8639.44 -1313.75 1270.15 5972221.88 629519.03 12.00 1822.82 180.00 MWD 9825.00 77.76 302.06 8644.10 -1300.71 1249.33 5972234.56 629497.99 12.00 1799.46 180.00 MWD 9850.00 74.76 302.06 8650.03 -1287.82 1228.76 5972247.09 629477.20 12.00 1776.36 180.00 MWD 9875.00 71.76 302.06 8657.23 -1275.11 1208.47 5972259.45 629456.70 12.00 1753.58 180.00 MWD 9900.00 68.76 302.06 8665.67 -1262.62 1188.53 5972271.59 629436.55 12.00 1731.20 180.00 MWD 9925.00 65.76 302.06 8675.33 -1250.39 1168.99 5972283.49 629416.81 12.00 1709.26 180.00 MWD 9950.00 62.76 302.06 8686.18 -1238.43 1149.91 5972295.12 629397.52 12.00 1687.84 180.00 MWD 9975.00 59.76 302.06 8698.20 -1226.80 1131.33 5972306.43 629378.75 12.00 1666.99 180.00 MWD 10000.00 56.76 302.06 8711.35 -1215.51 1113.31 5972317.41 629360.55 12.00 1646.76 180.00 MWD 10025.00 53.76 302.06 8725.59 -1204.61 1095.90 5972328.01 629342.95 12.00 1627.22 180.00 MWD 10050.00 50.76 302.06 8740.89 -1194.12 1079.15 5972338.21 629326.02 12.00 1608.41 180.00 MWD 10075.00 47.76 302.06 8757.20 - 1184.06 1063.10 5972347.99 629309.80 12.00 1590.39 180.00 MWD 10100.00 44.76 302.06 8774.48 -1174.48 1047.79 5972357.31 629294.34 12.00 1573.21 180.00 MWD 10100.72 44.68 302.06 8775.00 - 1174.20 1047.36 5972357.58 629293.90 12.00 1572.72 180.00 M-38A 10125.00 41.76 302.06 8792.69 -1165.38 1033.27 5972366.16 629279.66 12.00 1556.91 180.00 MWD 10150.00 38.76 302.06 8811.76 -1156.81 1019.58 5972374.50 629265.83 12.00 1541.54 180.00 MWD 10175.00 35.76 302.06 8831.66 -1148.77 1006.75 5972382.31 629252.87 12.00 1527.14 180.00 MWD 10200.00, 32.76 302.06 8852.31 -1141.30 994.82 5972389.58 629240.81 12.00 1513.75 180.00 MWD 10225.00 29.76 302.06 8873.68 -1134.41 983.83 5972396.27 629229.70 12.00 1501.40 180.00 MWD 10250.00 26.76 302.06 8895.70 -1128.13 973.79 5972402.38 629219.57 12.00 1490.14 180.00 MWD 10275.00 23.76 302.06 8918.30 -1122.47 964.75 5972407.89 629210.43 12.00 1479.99 180.00 MWD 10300.00 20.76 302.06 8941.44 -1117.44 956.73 5972412.78 629202.32 12.00 1470.98 180.00 MWD 10325.00 17.76 302.06 8965.04 -1113.06 949.74 5972417.04 629195.26 12.00 1463.13 180.00 MWD 10340.53 15.90 302.06 8979.90 -1110.68 945.93 5972419.36 629191.41 12.00 1458.86 180.00 TD 10340.54 15.90 302.06 8979.90 -1110.68 945.92 5972419.35 629191.40 12.00 1458.86 180.00 MWD BP Amoco REFERENCE INFORMATION ~e (NE) Relemnce Wel Ce~: M,38. Tree ~ velcal (TVD) RC, em*'x~: System Mean Sea Level Seclo~ (VS) Rdereno~: S~ot - 38(0.00N.0 0OE) Meest~md Depth Patentee: 53: 38 116'1994 O0:00 58.10 ANNOTAI'ION~ TY~ mD ObP !NTEQ LEGEND -- F~,an ~4 Azimuths to True Norl~ Magnetic Norlh: 26.56' Magnetic Field Slmnglh: 57465nT Dip, Angte: 80.77' Date: 4/11/2001 Model: BGGM2000 P~rc P~ M ~ M4e~ Contact Information: Dkect: (907) 267-6613 E-mail; brii. pot~l$C}inteq.com Baker Hughes INTEQ: (907) 267-~00 . -800' ' · ! . ..' .:.: . .i' '. .'i .' ..... West(-)/East(+) [lOOft/in] 1400 1450 l~.~JO 1550 1600 16~ 1700 17~ 1800 1850 1900 1~0 2000 2050 2100 2150 2200 22~ 2300 2350 2400 2450 2500 2550 2600 2650 2700 2750 2800 2850 2900 2950 3000 3050 3100 3150 3200 3250 3300 Vertical Section at t40,00° [SOft/in] 4/11/2001 2:02 PM 7 1/16" Annular 1/16" 5000 psi 7 1/16 ~;,~ ~ ~,J ;~ - ; il ,, 2 3/8" Pipe/Slips 7 1/16" Pipe 1 2 7/8" VBR' 2 3/8" to 3.5" SWAB OR MASTER VALVE I.I191154 ODATE I IDCHECK NO. 6104101 0191154 VENDOR ALASKAOILA O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 0&010i CKObOIOIJ 100. O0 100. O0 PYMT COMMENTS: PERt~IT TO DRILL FEE HANDLING INST: S/H - TERRIE HUBBLE X4628 HE ATTACHED CHECK I$ IN PAYMENT FOR ITEMS DESCRIBED ABOVE. i ~I] ~_~ I ~ 100_ O0 100_ O0 BP EXPLORATION, (A ,LAS~)./NC, RO. BOX' 196612, ? i' ANCHORAGE,'A~S~ CLEVELAND,. OHIO PAY U~, ANCHORA( Sm-' TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER - ~ CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULARD~Y~OSAL ( t~"~ NO ANNULAR DISPOSAL ( ) YEs ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS ( ) YES+ SPACING EXCEPTION "CLUE" The permit is for a new wellbore segment of existing well , Permit No, APl No. ~. Production should continue to be reported as a function of the original AP1 number stated above. In accordance with 20 AAC 25.005(0, ali records, data and logs acquired for the' pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). '. Annular disposal has not been requested... Annular Disposa! of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved... Please note that an disposal of fluids generated... Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name} will assume the liability of any protest t'o the spacing exception that may occur. Templates are located m drive\jody\templates ADMINISTRATION AIrieR DATE ENGINEERING DATE GEOLOGY ANNULAR DISPOSAL35. COMPANY INIT CLASS WELL NAME PROGRAM: exp APPR DATE GEOLAREA 1. Permit fee attached .................... 2. Lease number appropdate~ ,¢¢--~ ,4~¢_~/,'~-,~.) /C~ ~ ~ '/' 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling 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 ........... dev reddl serv UNIT# 14. 15. 16. 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive hodzons ..... ' ..... 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 ~_~L.~ osig, 27. Choke manifold complies w/APl RP-53 (May 84) ......... 28, Work will occur without operation shutdown ........... 29, Is presence of H2S gas probable ................. N. Conductor stdng provided ................... Y N Surface casing protects all known USDWs ........... Y N CMT vol adequate to circulate on conductor & surf csg ..... Y N Y N >/' wellbore seg ann. disposal para req 4~//~.-~_~-'-~ ON/OFF SHORE (")/3 _ _ -- 30. P~rmit can be issued wlo hydrogen sulfide measures ..... Y~_ 31. Data presented on potential overpressure zones . . ..... Y 32. Seismic analysis of shallow gas zones ........ , .... . ~.~/Y~ N 33. Seabed condition survey (if off-shore) ............. ~ ~ ~ Y N Contact name/phone for weekly progress reports [explo~y only] Y N 4. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... 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 ENGINEERING:. ' UICIAnnular ,,7. -~ ti. ~,,, , Commentsllnstructions: COMMISSION: ccc JMH, ~-~.. 4 ~ "Tj~lo ~ GEO~-~.OGY: c:~msoffice\wordian~diana\checklist (rev. 11101//00) 0 Z 0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the histo .fy 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. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Dec 11 17:17:57 2002 Reel Header Service name ............. LISTPE Date ..................... 02/12/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/12/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Cormments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD M-38A PB1 500292251970 BP Exploration (Alaska) Inc. Sperry Sun il-DEC-02 MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MW-ii124 AK-MW-Ii124 AK-MW-iI124 S. LATZ S. LATZ S. LATZ SARBER/SEVCI SARBER/SEVCI SARBER/SEVCI 6 liN 13E 2438 6O5 56.10 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (ET) 1ST STRING 3.750 4.500 8783.0 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (TVDSS). 3. IN JULY OF 2002, EIGHT RUNS WERE MADE IN AN UNSUCCESSFUL ATTEMPT TO KICK OFF THE WELL. NO DATA FROM THIS ATTEMPT IS PRESENTED HERE. SAME RIG RETURNED TO THE WELL IN AUGUST OF 2002 AND SUCCESSFULLY COMPLETED DRILLING. 4. MWD RUNS 1-3 WERE DIRECTIONAL WITH NATURAL GAMNLA PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. WELL KICKED OFF FROM M-38 AT TOP OF WHIPSTOCK SET AT 8895' MD, 8551' TVDSS. 5. MWD RUNS 4 AND 5 MADE NO FOOTAGE. WELL M-38A KICKED OFF FROM M-38A PB1 IN AN INADVERTENT SIDETRACK AT 8895' MD, 8550' TVDSS DURING MWD RUN 6. MWD DATA FROM M-38A ARE PRESENTED ELSEWHERE. 6. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER 2/11/2002 E-MAIL FROM D. SCHNORR (BP EXPLORATION). 7. MWD RUNS 1-3 REPRESENT WELL M-38A PB1 WITH API 50-029-22519-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9326' MD / 8631' TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY COMBINED (SCINTILLATION DETECTORS) $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 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 8840.0 9291.0 ROP 8861.0 9325.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record Data Record Type .................. 0 MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 1 8840.0 9009.0 2 9009.5 9243.0 3 9243.5 9325.5 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP 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 8840 9325.5 9082.75 972 ROP MWD FT/H 0.39 1094.89 88.6515 930 GR MWD API 20.33 1210.66 81.5814 901 First Reading For Entire File .......... 8840 Last Reading For Entire File ........... 9325.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Reading 884O 8861 8840 Last Reading 9325.5 9325.5 9291 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8840.0 8980.0 ROP 8861.0 9015.0 $ LOG HEADER DATA DATE LOGGED: 20-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9009.0 TOP LOG INTERVAL (FT) : 8869.0 BOTTOM LOG INTERVAL (FT) : 9009.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 20.7 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): 58.5 TOOL NUMBER TLG002 3.750 8783.0 BOREHOLE CONDITIONS MUD TYPE: FloPro MUD DENSITY (LB/G): 8.62 MUD VISCOSITY (S): 60.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 14400 FLUID LOSS (C3): 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 133.0 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 8840 9015 8927.5 351 ROP MWD010 FT/H 0.39 1094.89 94.6843 309 GR MWD010 API 26.39 1210.66 155.375 279 First Reading For Entire File .......... 8840 Last Reading For Entire File ........... 9015 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 8840 8861 8840 Last Reading 9015 9015 8980 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 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 8980.5 9208.0 ROP 9015.5 9243.0 $ LOG HEADER DATA DATE LOGGED: 20-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9243.0 TOP LOG INTERVAL (FT): 9009.0 BOTTOM LOG INTERVAL (FT): 9243.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 58.5 MAXIMUM ANGLE: 95.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE TLG033 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT) : 8783.0 # BOREHOLE CONDITIONS MUD TYPE: FloPro MUD DENSITY (LB/G): 8.62 MUD VISCOSITY (S): 60.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 14400 FLUID LOSS (C3): 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 129.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP 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 8980.5 9243 9111.75 526 ROP MWD020 FT/H 0.56 176.72 82.6726 456 GR MWD020 API 22.75 154.08 51.522 456 First Reading For Entire File .......... 8980.5 Last Reading For Entire File ........... 9243 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 First Reading 8980.5 9015.5 8980.5 Last Reading 9243 9243 9208 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 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 9208.5 9291.0 ROP 9243.5 9325.5 $ # LOG HEADER DATA DATE LOGGED: 21-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9326.0 TOP LOG INTERVAL (FT): 9243.0 BOTTOM LOG INTERVAL (FT): 9326.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 95.0 MAXIMUM ANGLE: 99.0 # 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): TOOL NUMBER TLG033 3.750 8783.0 BOREHOLE CONDITIONS MUD TYPE: FloPro MUD DENSITY (LB/G): 8.62 MUD VISCOSITY (S): 60.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 14400 FLUID LOSS (C3): 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 .0 129.0 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 9208.5 9325.5 9267 235 ROP MWD030 FT/H 2.22 226.43 93.877 165 GR MWD030 API 20.33 139.55 40.1278 166 First Reading For Entire File .......... 9208.5 Last Reading For Entire File ........... 9325.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 First Reading 9208.5 9243.5 9208.5 Last Reading 9325.5 9325.5 9291 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/12/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/12/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Dec 11 16:51:11 2002 Reel Header Service name ............. LISTPE Date ..................... 02/12/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/12/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: M-38Ai 500292251901 BP Exploration (Alaska) Inc. Sperry Sun Il-DEC-02 MWD RUN 1 MWD RUN 6 MWD RUN 7 AK-MW-iI124 AK-MW-Ii124 AK-MW-ii124 S. LATZ S. LATZ S. LATZ SARBER/SEVCI GOODRICH/WHI GOODRICH/WHI JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD MWD RUN 9 AK-MW-Ii124 S. LATZ GOODRICH/WHI 6 lin 13E 2438 605 56.10 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 3.750 4.500 8783.0 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (TVDSS). 3. IN JULY OF 2002, EIGHT RUNS WERE MADE IN AN UNSUCCESSFUL ATTEMPT TO KICK OFF THE WELL. NO DATA FROM THIS ATTEMPT IS PRESENTED HERE. SAME RIG RETURNED TO THE WELL IN AUGUST OF 2002 AND SUCCESSFULLY COMPLETED DRILLING. 4. MWD RUN 1 WAS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. WELL KICKED OFF FROM M-38 AT TOP OF WHIPSTOCK SET AT 8895' MD, 8551' TVDSS. 5. WELL KICKED OFF FROM M-38A PB1 IN AN INADVERTENT SIDETRACK AT 8895' MD, 8550' TVDSS DURING MWD RUN 6. MWD DATA FROM M-38A PB1 ARE PRESENTED ELSEWHERE. MWD RUNS 6 AND 7 WERE DIRECTIONAL WITH NGP. MWD RUN 8 MADE NO FOOTAGE. 6. MWD RUN 9 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). RESISTIVITY DATA IN THE INTERVAL FROM 8861' MD, 8519' TVDSS TO 9340' MD, 8646' TVDSS WERE COLLECTED IN A WIPE PASS FOLLOWING MWD RUN 9 WHILE PULLING OUT OF HOLE. 7. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER 2/11/2002 E-MAIL FROM D. SCHNORR (BP EXPLORATION). 8. MWD RUNS 1, 6, 7, AND 9 REPRESENT WELL M-38A WITH API# 50-029-22519-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10270' MD / 8669' TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED (GEIGER-MUELLER TUBE DETECTORS) SGRD = SMOOTHED GAMMA RAY COMBINED (SCINTILLATION DETECTORS) SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 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 8840 0 10224 0 ROP 8861 0 10270 0 FET 8861 5 10235 5 RPD 8861 5 10235 5 RPM 8861 5 10235 5 RPS 8861 5 10235 5 RPX 8861 5 10235 5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 8840.0 8895.0 6 8895.5 8932.0 7 8932.5 9375.0 9 9375.5 10270.0 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 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 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HR Min 8840 0 44 19 11 0 42 0 55 0 57 0 71 0.185333 Max 10270 1094.89 1210.66 2000 2000 2000 1775.47 131.661 First Reading For Entire File .......... 8840 Last Reading For Entire File ........... 10270 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Mean 9555 114.854 51 7932 23 3018 18 9553 16 8911 14 5584 16 8309 Nsam 2861 2819 2769 2748 2748 2748 2748 2749 First Reading 8840 8861 8840 8861.5 8861.5 8861.5 8861.5 8861.5 Last Reading 10270 10270 10224 10235.5 10235.5 10235.5 10235.5 10235.5 Date of Generation ....... 02/12/11 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 ....... 02/12/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8840.0 8895.0 ROP 8861.0 8895.0 $ LOG HEADER DATA DATE LOGGED: 20-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 8895.0 TOP LOG INTERVAL (FT): 8869.0 BOTTOM LOG INTERVAL (FT): 8895.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 20.7 MAXIMUM ANGLE: 58.5 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG002 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): 8783.0 # BOREHOLE CONDITIONS MUD TYPE: FloPro MUD DENSITY (LB/G): 8.62 MUD VISCOSITY S): 60.0 MUD PH: 9.0 MUD CHLORIDES PPM): 14400 FLUID LOSS (C3 : 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 133.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 8840 8895 8867.5 111 ROP MWD010 FT/H 0.44 1094.89 286.548 69 GR MWD010 API 32.43 1210.66 102.797 111 First Reading For Entire File .......... 8840 Last Reading For Entire File ........... 8895 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 8840 8861 8840 Last Reading 8895 8895 8895 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 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: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 8895.5 8932.0 GR 8895.5 8901.0 $ # LOG HEADER DATA DATE LOGGED: 23-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8932.0 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 PCG Natural gamma ray $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8895.0 8932.0 .0 .0 TOOL NUMBER TLG033 3.750 8783.0 BOREHOLE CONDITIONS MUD TYPE: FloPro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 61.0 MUD PH: 10.0 MUD CHLORIDES (PPM) : 14400 FLUID LOSS (C3): 9.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 .0 133.0 .0 .0 Name Service Unit Min Max Mean Nsam DEFT FT 8895.5 8932 8913.75 74 ROP MWD060 FT/H 1.38 322.34 37.5446 74 GR MWD060 API 90.37 238.17 140.254' 12 First Reading For Entire File .......... 8895.5 Last Reading For Entire File ........... 8932 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 Maximum Physical Record..65535 First Reading 8895.5 8895.5 8895.5 Last Reading 8932 8932 8901 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 ....... 02/12/11 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: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8901.5 ROP 8932.5 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ 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: $ STOP DEPTH 9340.5 9375.5 23-AUG-01 Insite 7.75 Memory 9375.0 8932.0 9375.0 26.0 98.0 TOOL NUMBER TLG033 3.750 8783.0 FloPro 8.60 62.0 10.0 14400 10.0 .000 ..0 .000 133.0 .000 .0 .000 .0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 8901.5 9375.5 9138.5 949 ROP MWD070 FT/H 4.77 453.85 112.585 887 GR MWD070 API 20.76 1080.32 65.6875 879 First Reading For Entire File .......... 8901.5 Last Reading For Entire File ........... 9375.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 First Reading 8901.5 8932.5 8901.5 Last Reading 9375.5 9375.5 9340.5 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 8861.5 10235 5 RPM 8861.5 10235 5 RPS 8861.5 10235 5 RPX 8861.5 10235 5 FET 8861.5 10235 5 GR 9341.0 10224 0 ROP 9376.0 10270 0 $ LOG HEADER DATA DATE LOGGED: 25-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL {FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD090 FT/H 4 1 68 GR MWD090 API 4 1 68 RPX MWD090 OHMM 4 1 68 RPS MWD090 OHMM 4 1 68 RPM MWD090 OHMM 4 1 68 RPD MWD090 OHMM 4 1 68 FET MWD090 HR 4 1 68 4.3 Memory 10270.0 9375.0 10270.0 78.9 98.3 TOOL NUMBER 69706 3.750 8783.0 FloPro 8.60 62.0 9.5 14400 10.4 .150 .086 .170 .160 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 63.0 115.0 63.0 63.0 Name Service Unit DEPT FT ROP MWD090 FT/H GR MWD090 API RPX MWD090 OHMM RPS MWD090 OHMM RPM MWD090 OHMM RPD MWD090 OHMM Min 8861.5 0 98 19 11 0 42 0 55 0 57 0 71 Max 10270 296.85 149.06 2000 2000 2000 1775.47 Mean Nsam 9565.75 2818 112.555. 1789 41.0767 1767 23.3018 2748 18.9553 2748 16.8911 2748 14.5584 2748 First Reading 8861.5 9376 9341 8861.5 8861.5 8861.5 8861.5 Last Reading 10270 10270 10224 10235.5 10235.5 10235.5 10235.5 FET MWD090 HR 0.185333 131.661 16.8309 First Reading For Entire File .......... 8861.5 Last Reading For Entire File ........... 10270 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/12/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 2749 8861.5 10235.5 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/12/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/12/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File