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Home My WebLink About200-185CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPJ-20 (PTD# 200-185) Missed AOGCC Witnessed MIT-IA Date:Wednesday, May 31, 2023 2:56:32 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, May 31, 2023 2:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: MPJ-20 (PTD# 200-185) Missed AOGCC Witnessed MIT-IA Mr. Wallace – PWI well MPJ-20 (PTD# 200-185) is currently shut in and will not be brought online for its scheduled 4 year MIT-IA. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT- IA will be scheduled once the well is returned to injection. Please respond with any comments or concerns. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, May 31, 2019 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC J -20A MILNE PT UNIT 1-20A Src: Inspector Reviewed By; P.I. Supry J f NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT J -20A API Well Number 50-029-22832-01-00 Inspector Name: Jeff Jones Insp Num: mit1J190531104537 Permit Number: 200-185-0 Inspection Date: 5/13/2019 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well — — — �i - — — - BBL 1-20A —f YP w :TVD � zz6s Tubing sv6 - ssa - 877 - sza - — "Type Inj PTD 2001850 !Type Test' s��est psi 1500 - IA 880 1622 sal { 1571 Pumped: i on�BBL Returned: 0.9 OA Interval 4vRTST P(F P K Notes: Pre-injection MIT -IA after long term S/I. Monobore injector, no OA. I well inspected, no exceptions noted. ✓ Friday, May 31, 2019 Page I of 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 �,�� 5�E FEB 2, g s - a 00- Mr. Tom Maunder Alaska Oil and Gas Conservation Commission � ' 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPJ -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPJ -Pad 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 . S BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) MPJ -Pad 9/5/2011 Corrosion I Vol. of cement Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped Final top of cement date inhibitor sealant date ft bbls ft gal MPJ -01A 1991110 50029220700100 Sealed Conductor NA NA NA NA NA MPJ - 1900960 50029220710000 Sealed Conductor NA NA NA NA NA MPJ -03 1900970 50029220720000 Sealed Conductor NA NA NA NA NA MPJ-04 1900980 50029220730000 _ Sealed Conductor NA NA NA NA NA MPJ -05 1910950 50029221960000 Dust Cover NA NA NA 3.4 9/5/2011 MPJ -06 1940950 50029224930000 4 NA 4 NA 8.5 8/21/2011 MPJ -07 1910970 50029221980000 3.8 NA 3.8 NA 3.4 8/21/2011 MPJ -08A 1991170 50029224970100 18 NA Need top job MPJ -09A 1990114 50029224950100 Sealed Conductor NA NA NA NA NA MPJ -10 1941100 50029225000000 Sealed Conductor NA NA NA NA NA MPJ -11 1941140 50029225020000 Sealed Conductor NA NA NA NA NA MPJ -12 1941180 50029225060000 Sealed Conductor NA NA NA NA NA MPJ -13 1941260 50029225080000 1 NA 1 NA 3.4 8/21/2011 MPJ -15 1991070 50029229520000 Dust Cover NA NA NA 5.1 9/5/2011 MPJ -16 1951690 50029226150000 1.8 NA 1.8 NA 11.1 8/20/2011 MPJ -17 1972080 50029228280000 0.8 NA 0.8 NA 8.5 9/5/2011 MPJ -18 1972200 50029228340000 1.3 NA 1.3 NA 17.0 9/5/2011 MPJ -19A 1951700 50029226070100 2.2 NA 22 NA 15.3 8/20/2011 --,•• MPJ -20A 2001850 50029228320100 5.8 NA 5.8 NA 65.5 9/5/2011 MPJ -21 1972000 50029228250000 3.5 NA 3.5 NA 28.1 8/20/2011 MPJ -23 2001200 50029229700000 0.8 NA 0.8 NA 10.2 11/1/2009 MPJ -24 2001490 50029229760000 Open Flutes - Treated MPJ -25 2040730 50029232070000 1 NA 1 NA 8.5 8/21/2011 MPJ -26 2040640 50029232050000 1.2 NA 1.2 NA 11.9 8/20/2011 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor .--, - - ' ~e1;' blC{ ftG I( DA TE: Wednesday, June 07, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC J-20A MILNE PT ~UNIT SB J-20A h-'lCÖS"" aOV FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv íf$']2- Comm NON-CONFIDENTIAL Well Name: MILNE PT UNIT SB J-2OA API Well Number 50-029-22832-01-00 Inspector Name: Chuck Scheve Insp Num: mitCS060603203255 Permit Number: 200-185-0 Inspection Date: 6/312006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. IType Inj. i W - ~~~ i Well I J-20A TVD 2960 ! IA I 360 2000 I 1880 ! 1880 ! ! I P.T. i 2001850 iTypeTest i SPT Test psi 1500 I OA I i ! I ! I i i Interval 4YRTST P/F P Tubing! 600 I 600 I 600 i 600 ! I Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. This well is a single casing design with no OA to monitor. ¿,/' aCANNEi0 JUN .¡ p r)pr1!,i OJ '-'h" U Wednesday, June 07, 2006 Page I of I MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc ids C!\J II. ~ ~) L") . - I 'S' S WELL LOG TRANSMITTAL t:JI,/zse.tf ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE: Distribution - Final Print[s] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration(Alaska), Inc. Petro-Technical Data Center LR2-1 900 East Benson Blvd. Anchorage, Alaska 99508 WELL DATE LOG TVPE DIGITAL OR CD-ROM 1 MVLAR / SEPIA FILM 1 BLUE LINE PRINT[S) REPORT OR BLUELINE Open Hole 1 MP J-20a 3-26-04 Res. Eva!. CH 1 1 t,...t;) 1 Mech. CH 1 Caliper Survey / Print Name: ,.. / ,., / ,/ I/'/~'~ ,:~.b.~ /'1' /1 "[,"{¿/~~'/,('i, '- '--_--I , . 1k./~7:J ~-T(;' {{.iLI/ H o--rJ Date: / / .. .// ('-{/ [) 4 I Signed: PRoAnivE DiAC¡NŒIk SERViCES, INe, PO Box I ~69 SIAHoRd IX 77477 Phone:(281 ) 565-9085 Fax:(28l) 565-1369 E-mail: pds.g.memorylog.com Website: www.memol}.log.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~>I 3?~ ëý; ~ ,. 1. Type of Request: 0 Suspend 0 Abandon Alter CasinQ D RepairWell D Change Approved Program 0 Pull Tubing 0 Operation Shutdown D PluQ Perforations D Perforate New Pool D 4. Current Well Class: 2. Operator Name: BP Exploration (Alaska), Inc. Development D PerforateD WaiverD StimulateŒ Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 200-1850 ../ Annular DisposalD OtherD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.22 KB 8. Property Designation: ADL-025517 Exploratory D 3. Address: 11. Total Depth MD (ft): ~ 11176 Casing StratigraphicD Service Œ] 9. Well Name and Number: MPJ-20A 10. Field/Pool(s): Kuparuk River Field 1 Schrader Bluff Oil Pool, Milne Point Unit PRESENT WELL CONDITION SUMMARY I Total Depth TVD (ft): Effective Depth MD (ft): IEffective Depth TVD (ft): 3984.7 / 11088 3857.1 Length Size MD TVD 6. API Number / 50-029-22832-01-00 Plugs (md): None Burst Junk (md): None Collapse Conductor 80 Liner 5133 Production 6190 Perforation Depth MD (ft): I 10900 - 10940 10996 - 11016 Packers and SSSV Type: 2-7/8" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 12. Attachments: Description Summary of Proposal 0 20" 91.5# H-40 4-1/2" 12.6# L-80 7" 26# N-80 Perforation Depth TVD (ft): 3788 3814.9 3855 3869.4 top bottom top bottom 32 112 32,0 112.0 1490 470 6043 11176 2960.2 3984.7 8430 7500 29 6219 29.0 2988.8 7240 5410 Tubing Size: Tubing Grade: Tubing MD (ft): 2.875" 6.5 # L-80 28 6117 Packers and SSSV MD (ft): 6030 6050 13. Well Class after proposed work: Detailed Operations Program Œ BOP Sketch 0 Exploratory 0 DevelopmentD ServiceŒ 14. Estimated Date for March 24, 2004 Commencing Operation: 16. Verbal Approval: Date: Commission Representative: 15. Well Status after proposed work: Oil D GasO PluggedO AbandonedO WAG D GINJD WINJŒ WDSPLD Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean Petersen Printed Name Signature Sean Petersen !"-O.- ~ Title Phone Petroleum Engineer 564-5392 3/24/04 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ...3 0 ~ ~ t)? .;;J-. Plug Integrity 0 BOP Tes~ Mechanciallntegrity Test D Location Clearance D Approved b : \ M.~ I)J\. ~<J ~ ~~\-- ~O,-\ RECEIVE~Cl BY ORDER OF .;f<L¿~ THE COMMISSION \4Ai: 2 4 200: fro¡ df " ,I. n'," ro" ", ;h1'!(t .,' :<' nac; vOP~ 1';'-:";;':":'1;11 An~I"(w;{';' OR\G\NAL .. BfL .8,08 Form 10-403 Revised 12/2003 SUBMIT IN DUPLICATE " '- To: From: Subject: BP Exploration Alaska Milne Point Jerry Bixby and Clint Spence MPU Well Operations Supervisor Date: 03/0112004 Sean Petersen Schrader Bluff Production Engineer lOR: COST: 75 bopd $60,000 MPJ-20Ai Tag TD, FCO, Memory IPROF w. Warmbacks OBJECTIVES: 1. Determine injection split between OA and OB sands a. Depending on results, an expensive RWO may be required for OB injection Note: Last year MPj-20A's CTU FCO and IPROF did not provide the desired results due to fouling of the spinner with schmoo. A CTU FCO is assumed to be required as part of this procedure, and takes into account learnings from a number of last year's CTU FCOs at MPU. Please call with any questions or comments. Category Step CTU 1 CTU 1A CTU CTU CTU CTU 2 Description Tag TD If TD Tag is < 11016 MD: FCO to PBTD (11,087' MD) with 2" JSN Circulate at maximum rate allowable Returns down production line or to a tank Note: Previous PBTD were reached between 11,040 - 11047 CTMD Spot 100 bbls 20% SBG from TD to WLEG, Let soak for 1 hour & displace with KCL Spot 100 bb1s 15% DAD from TD to WLEG, Let soak for 1 hour & displace with KCL Memory IPROF - DO NOT EXCEED 1500psi WHP!! a. 700 psi - note stable flow rate (current operating conditions) b. 1300 psi - note stable flow rate Please log up at 40,80, 120 and 160 fpm, and down at 80 fpm Perform warmback passes at 1 hour, 3 hours, 9 hours From TD to 10,400' MD Poor cement job - want to see if injecting above OA sands 3 4 5 HISTORY & DISCUSSION: MPJ-20Ai is a Schrader Bluff OA and OB sand injector that supports MPJ-23 and MPJ-24. In October 2002, MPJ-20Ai was in direct injector/producer communication with MPJ-23. As a result, MPJ-20Ai was shut in for 11 days prior to being brought back on injection at significantly reduced rates and pressures. Based on a similar well design in MPE-29i, it was suspected that 100% of the injection was going into the OA sands, but there was no hard evidence to support this. There have not been any additional incidents of direct communication between these wells since the MPJ-20A injection rates were reduced. In July 2003, aCTO FCO and IPROF was performed to determine if 100% of the injection was going into the OA. During the FCO, a hard tag was made at -10,925 ctmd and no progress was able to be made with a JSN, (Note: Bottom 15' of OA, and all of OB perforations covered) Next, the CTU spotted 7.5% HCL on top of the obstruction at 10,925' MD and let it soak for 30 minutes, but was still unable to pass through the obstruction. Finally, a motor and mill were then installed, and this assembly was able to break through the obstruction and continue RIH with little motor work. A JSN was used again to verify TD was reached, and to spot 7.5% HCL across the perforations. Memory IPROF logging passes were then made at several different injection rates, but the spinner data was not usable due to schmoo fouling the spinners. Temperature data may indicate that injected water was making it to the DB, but was not quantifiable. MPJ-23 and MPJ-24's performance has been respectable despite the continued lack of injection support. (However this pattern is always among the worst offenders in the Milne Point's monthly injection choke model.) A decision to convert this injector from a single commingled injector to a dual string injector has been delayed in part to the indeterminate results of the July '03 IPROF. Prior to making such a major investment, another FCO & IPROF attempt is being requested to verify the current level of fill, and what the splits between the OA and OB will be after the CTU FCO. Several CTU FCOs were performed at MPU last year. After reviewing these jobs, and based on conversations with the MPU Wells Operations Coordinator, the best results were achieved when schmoo-be-gone (SBG) was spotted over the interval of interest prior to logging or acid being spotted over the interval. The thought is that the SBG breaks down the hydrocarbons, allowing the acid to cleanly react to any additional build-up on the tubing. The proposed procedure takes these learning into account and will hopefully allow for useful IPROF results to be obtained. . ' POINTS OF CONTACT: Production Engineer: Sean Petersen Office: 564-5025 Home: 349-3098 MPU Wells Operation Supervisor: Jerry Bixby, Mike Hefley & Clint Spence Office: 659-6333 Fax: 659-6390 DISTRIBUTION: MPJ-20Ai Anchorage Well File MPU Admin, Assistant North Slope MPJ-20Ai Well File MPU Ops Supervisors MPU Ops Coord CURRENT WELL STATUS: GENERAL WELL INFORMATION: API Number: 50-029-22832-01 Well Type: Schrader Bluff OA, and OB Injector Original KB E1ev: 64.22' (Nordic 22E) Original GL Elevation: 35.1' Minimum ID: 2.205" @ 6065' MD (XN Profile) Current Injection Rate: -1000 bwpd @ -700 psi BHP and BHT INFORMATION: IUNfiT..- -- _l1li81 - J-20Ai 2/22/2001 1082 2527 SBHP J-23 10/1612000 1590 3569 SBHP Initial Static. Unable to get down to perfs. Dual Starburst gauges Initial Static; Pressure from Baker Sentry nol!o ".._.1...... p~P.s.t~!uppr~~s~~..._... H J-24 1/2312001 1675 3834 PP DIRECTIONAL INFORMATION: Max Angle: 750_840 from -3175' MD to -10,600' MD Max DLS: 13.00 at 6292' MD 13.10 at 7204' MD Angle through perfs: -440 PERFORATION INFORMATION: ( WELL LOG TRANSMITTAL ,ðcXJ-.185 ProActive Diagnostic SelVices, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE: Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. o. Box 1369 Stafford, TX 77497 BP Exploration(Alaska), Inc. Petro-Technical Data Center LR2-1 900 East Benson Blvd. Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CO-ROM FILM BLUELINE Open Hole 1 1 1 MPJ-20Ai 7-7-2003 Res. Eva!. CH 1 1 1 jt) .L..J 0 or Mech. CH 1 Caliper Survey RECE'VED Date:~04 AlukaOU & Gas Cons.CommisiOo AncbOf8ge Signed: ~ç,\;: ~~ ~~N1 Print Name: SGA\MNE\i) FEf3 ~~ 0 2004. .- PI~oACTivE DiAGNOSTic SERVicES, INC., PO Box 1 }69 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com (- STATE OF ALASKA ( ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator SuspendD Repair Well 0 Pull TubingD Operation Shutdown D Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Perforate 0 VarianceD Annular Disposal 0 Stimulate ŒJ Time ExtensionO OtherD Re-enter Suspended WeliO 5. Permit to Drill Number: 200-1850 Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.22 8. Property Designation: ADL-025517 11. Present Well Condition Summary: Total Depth Development 0 Stratigraphic 0 9. Well Name and Number: MPJ-20A 10. Field/Pool(s): Kuparuk River Field / Schrader Bluff Oil Pool, Milne Point Unit Exploratory 0 ServiceŒJ 6. API Number 50-029-22832-01-00 true vertical measured 11176 None Effective Depth measured true vertical Casing Conductor Liner Production Length 80 5133 6190 Perforation deDth: feet 3984.7 feet Plugs (measured) Junk (measured) 11088 feet 3921.3 feet None Size 20" 91.5# H-40 4-1/2" 12.6# L-80 7" 26# N-80 TVD MD Burst Collapse 470 7500 5410 32 112 32.0 - 112.0 6043 - 11176 2960.2 - 3984.7 29 - 6219 29.0 - 2988.8 1490 8430 7240 Measured depth: 10900 -10940,10996 -11016 2-7/8" 6.5# L-80 @ RECEIVED DEC I 72003 ~J~gka Oil & Gas Cons. Commission 6050 Anchorage True vertical depth: 3787.63 - 3814.88,3854.97 - 3869.39 Tubing ( size, grade, and measured depth): 28 - 6117 Packers & SSSV (type & measured depth): 2-7/8" Baker 5-3 Perm Packer 4-1/2" Baker ZXP Packer @ @ 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10900 - 10940, 10996 - 11016 Treatment descriptions including volumes used and final pressure: 17 bbls 7.5% HCL with additives @ 2950 psig. ReDresentative Dailv Average Production or Iniection Data Daily Report of Well Operations - ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature I j (~ ,.. Form 10-404 Revised /2003 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure 1068 0 817 938 0 607 15. Well Class after proposed work: ExploratoryD Development D Service Œ] 16. Well Status after proposed work: Operational Shutdown D Oil 0 GasD WAG:] GINJD WINJ Œ:I WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 8CA~Title Production Technical Assistant Phone 564-4657 Date 12/15/03 ~¡ f MPJ-20A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/05/03 MRIU unit #9. RIH with 1.75in JS nozzle. Circ. out filllmung using flo-pro and XSKCL to a hard tag at 10925 CTMO. Unable to break through. Prep for acid. Job in progress. 07/06/03 Continued from WSR of 715/03. Perform injectivity test: 0.75 b/m at 650 psi 1 b/m at 713 psi. Spot 5 bbls 7.5% HCL on obstruction and across open perfs. Let acid soak 30 minutes. RIH pumping 1.5 b/m. Unable to break thru obstruction. Injectivity after acid is 1.5 b/m at 735 psi. POH. RIH wI WFO 1 11/1611 motor & 2" junk mill. Tag fill at 109321 ctmd, clean out to 110471 ctmd, POOH. RIH wI 2" JSN, jet to 110451 with 10 bbls flo-pro and circulate out bottoms up. Jet across perfs with 17 bbls 7.5 bbls & let soak for 30 minutes. Overdisplace acid with 70 bbls KCL. POH. RIH with memory logging tools. Begin spinner passes while injecting C-H20 at 0.75 b/m. Initial injectivity is 0.75 b/m at 880 psi. 07/07/03 Continue making spinner passes at injection rate of 0.75 b/m rate. Final injectivity is 0.75 b/m at 900 psi. Perform spinner passes at 40 80 120 and 160 fpm with a WHP of 1035 at 0.9 b/m. Increase rate to 1.1 b/m with 1232 initial WHP. Perform spinner passes. Final injectivity is 1.2 b/m at 1326. POH and freeze protect well with 20 bbls 50/50 MEOH. Semi-good data. ROMO. FLUIDS PUMPED BBLS 800 XSLK 1 % KCL 35 Flo-pro 22 7.5% HCL with additives 286 Sea Water 20 50/50 Methonal/H20 1163 TOTAL Page 1 ( Orig. OF t::lev. = 64.22' (N 22E) Orig. GL Elev. = 35.10' OF to 7" csg. hng. = 30.13' (N 22E) Tree: 2 9/16" - 5M Wellhead: 11" 5M FMC Gen 6 Tbo. Hng: 27/8" x 11" FMC wi 27/8" NSCT T&B and 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 I 115' I KOP @ 400' Max. hole angle = 79 to 84 deg. fl 3,300' to 10,512' Hole angle thru' perfs = 43 deg. Tubing 27/8" 6.5 ppf, L-80, EUE 8rd. tbg. (drift = 2.441" ,cap = ( .0058 bpf) Casing 7" 26 ppf, L-80, Mod. Btrc. prod. casing (drift 10 = 6.151", cap. = 0.0383 bpf) .Li.wu: 4.5" 12.6 ppf, L-80 IBT drift = 3.958" id (cap = .0152 bpf) Min. id = 2.205" Window cut 6,202' - 6,216' Baker 6' tie back sleeve I 6,043' I Baker ZXP compo liner top packer I 6,050' I Baker 5 x 7" flex lock liner hanger I 6,060' I Perforation Summary Ref log: geL 02/17/01 Sizf SPF Interval lTVm 2" 4 10,900'-10,920' 3,782'- 3,796' 2" 4 10,920'-10,940' 3,796'- 3,809' 2" 4 10,996'-11,0"16' 3,856'- 3,870' 2" Powerjet guns, 40 sp'f, 90 degree phasing MPU J-20 HES 7" EZSV pkr. @ 6,213' HES X-Nipple 2.313" id I 2041' I 7" Howco "ES" Cementer I 2194' I 2-7/8" HES X-Nipple 2.313" id I 5,997' I I 6,039' I I 6,065' I I 6,077' I 7"x2-7/8" Baker Pkr. S-3 Perm pkr. 27/8" HES XN-Nipple 2.204" id WLEG 4.5" Baker landing collar 11,087' 4.5" hes float collar 11,132' .. ... 4.5" hes float shoe 11,176' "."""".w """ '.' .,,' ",' ',' ,.'." Liner 4.5" 12.6 #/ft L-80 IBT 3.958" id ( .0152 bp DATE 01/20101 02/18/01 REV. BY MOO MOO COMMENTS Sidetrack injector completion Nabors 22 Initial perforations wI ctu e-line MILNE POINT UNIT WELL J-20A API NO: 50-029-22832-01 Permit to Drill 2001850 DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. MILNE PT UNIT SB J-20A Operator BP EXPLORATION (ALASKA) INC MD 11176 ~/ TVD 3985 / Completion Dat 2/18/2001 / Completion Statu WAGIN Current Status 1WINJ UIC Y APl No. 50-029-22832-0'1-00 REQUIRED INFORMATION Mud Log No Sample No Directional Survey .~__._o._~ -~ -..--__ _~ ~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fret ED D ~Verification ED ~ ~ef~LIS Verification R (data taken from Logs Portion of Master Well Data Maint) -L--- L Interval Log Log Run OH I Name Scale Media No Start Stop CH Received I 6182 11127 Open 3~4/2002 I 6182 11127 Open 10697 11036 Open Dataset Number C~omments 106~'"'"" Directional Survey Directional Survey Directional Survey MWD Directional Survey MWD . - Slim Cement Mapping 5 Injection Profile 2/5 10169 FINAL FINAL FINAL FINAL 5/9/2002 10807'"'""~ 6/26/2001 q~9 10697-11036 2/22/2001 Dir Survey Paper Copy 2/2212001 Dir Survey Digital Data 2/22/2001 MWD Dir Survey Paper Copy 2/22/2001 MWD Dir Survey Digital Data ' FtNAL~---~-935~-~0~L .... 3116120D.1..~- ....... 92~g-14~)4~l~oler-Print-- .... FINAL 9250 11040 ch 3/16/2001 9250-11040 Color Print FINAL 10700 11030 CH 6/26/2001 10700-11030 BL, Sepia FINAL 10697 11036 OH 6/26/2001 r~169 10697-11036, Digital Data Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Analysis ~ Rec~.ive. d '~ Daily History Received? ~ N- Formation Tops ~_~/N Permit to Drill 2001850 MD 11176 Comments: TVD DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. MILNE PT UNIT SB J-20A Operator BP EXPLORATION (ALASKA) INC 3985 Completion Dat 2/18/2001 Completion Statu WAGIN Currant Status 1WINJ APl No. 50-029-22832-01-00 UIC Y Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _ CHG INJ STATUS FI WAG to H20 Pa, tubing _ Alter casing _ Repair well _ Other_X CHG Inject Status 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 3072' FNL, 3288' FEL, Sec. 28, T13N, R10E, UM At top of productive interval 1263' FNL, 1231' FEL, Sec. 30, T13N, R10E, UM At effective depth 1209' FNL, 1402' FEL, Sec. 30, T13N, R10E, UM At total depth 1191' FNL, 1461' FEL, Sec. 30, T13N, R10E, UM 5. Type of Well: Development __ Exploratory__ Stratigraphic._ ServiceBX (asp°s 552033, 6014605) (asp's 543514, 6016359) (asp°s 543343, 6016413) (asp's 543284, 6016430) 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Milne Point Unit 8. Well number MPJ-20A 9. Permit number / approval number 200-185 10. APl number 50-029-22832-01 11. Field / Pool Milne Point Unit / Schrader Bluff Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 112' Surface 6172' Production 5133' 11176 feet Plugs (measured) 3985 feet 11088 feet Junk (measured) 3921 feet Size Cemented 20" 260 sx Arcticset (Approx) 1476 sx PF 'E', 132 sx 7" Class 'G' 4-1/2" 250 sx Class 'G' Measured Depth True Ve~ical Depth 144' 144' 6202' 2985' 6043'-11176' 2960'-3985' Perforation depth: measured Open Perfs 10900'-10940', 10996'-11016' true vertical Open Perfs 3788'-3815', 3855'-3869' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 2-7/8", 6.5#, L-80 to 6077'. 7" x 2-7/8" Baker S-3 Perm Packer @ 6039'. No SSSV in well. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 02/24/2001 Subsequent to operation 06/23/2002 OiI-Bbl Representative Daily Avera.qe Production or Iniection Data Gas-Mcf Water-Bbl 2580 2022 Casing Pressure Tubing Pressure 1527 1614 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil _ Gas _ Suspended Service WATER INJECTOR 17. I hereby certify that the foregoing is tj~e and correct to the best of my knowledge. ~w.~a~e R~Schno~l~~~~. Title: Technical Assistant Form 10-404 Rev 06/15/88 · Date June 24, 2002 Prepared by DeWayne R. Schnorr 564-5174~ 2 2OO2 SUBMIT IN DUPLICATE MPJ-20A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/23/2001 STARTED WATER INJECTION 06/20/2002 CHANGED WELL CLASSIFICATION FROM WAG TO H20 INJECTION WELL. EVENT SUMMARY 02/23/01 STARTED WATER INJECTION 06/20/02 CHANGED WELL CLASSIFICATION FROM WAG WELL TO WATER INJECTION ONLY. FLUIDS PUMPED BBLS 0 NO FLUIDS PUMPED. 0 TOTAL Page I .._...__" Tree: 2 9/16" - 5M ~' ~l~;~U J-~O orig. DF~r_,,~v. = 64.22' (N 22E) Wellhead: 11" 5M FMC Gen 6 / Orig. GL Elev. = 35.10' Tbg. Hng: 2 7/8" x 11" FMC w/2 7/8" ! DF to 7" csg. hng. = 30.13' (N 22E) NSCTT&B and 2.5" ClW H BPV profile 20" 91.1ppf, H-40 I 115' I KOP @ 400' Max. hole angle = 79 to 84 deg. f/ 3,300' to 10,512' Hole angle thru' perfs = 43 deg. HES X-Nipple 2.313" id 7" Howco "ES" Cementer 2041'1 2194' Tubina 2 7/8" 6.5 ppf, L-80, EUE 8rd. tbg. ( drift = 2.441", cap = ( .0058 bpf ) Casina -- 7" 26 ppf, L-80, Mod. Btm. prod. casing ( drift ID -- 6.151", cap. = 0.0383 bpf ) 4.5" 12.6 ppf, L-80 IBT drift = 3.958" id ( cap = .0152 bpf ) Min. id = 2.205" 2-7/8" HES X-Nipple 2.313" id 7"x2-7/8" Baker Pkr. S-3 Perm pkr. I 5,997' J I 6,039' J Windowcut 6,202'- 6,216' Baker 6' tie back sleeve J 6,043' Baker ZXP comp. liner top packer J 6,050' Baker 5 x 7" flex lock liner hanger I 6,060' Perforation Summary Ref lo,q: SBL 02117101 Sizt SPI Interval (q'VD) /10,900'-10,920' 3,782'-3,796' / /10,920','10,940', 3,796'-3,809' 2" Powerjet guns, 40 spf, 90 degree phasing 2 7/8" HES XN-Nipple 2.204" id I 6,065' J WLEG I 6'077'1 4.5" Baker landing collar I 11,087' I 4.5" hesfloat collar I 11'132'1 4.5" hes float shoe I 11,176'I ~ 4.5" 12.6 #/ft L-80 IBT 3.958" id ( .0152 bpt pkr. 6,213' DATE 01/20/01 REV. BY MDO COMMENTS Sidetrack injector completion Nabors 22E 02/18/01 MDO Initial perforations w/ctu e-line MILNE POINT UNIT WELL J-20A APl NO: 50-029-22832-01 BP EXPLORATION {AK! MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor{'n'~ Chairman DATE: June 17, 2002 THRU: Tom Maunder ~~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests BPX MPU E & J Pads E-13B, J-20A MPU Milne Point Packer Depth Pretest Initial 15 Min. 30 Min. Well] E-13B ]Typelnj.I S ] T.V.D. I 4134 ]Tubing[ 1900 ] 1900 I 1900 ] 1900 ]IntervalI I P.T.D.] 202-044 ]Type testI P ]Test psi] 1034 I Casingl 1250 I 2500 I 2450 I 2425] P/FI -~ Notes: w~,,I J-20A I mype,nj.I S I T.V.D. 12959 I mubingl~SS0 [~S0 I lSS0 I lS50 I,nterva, I I P.T.D.I 200-185 ITypetestl P ITestpsiI 740 I Casingl 1000I 2000I ~925I ~925I P/F I --P Notes: Well P.T.D. Notes: Well P.T.D. Notes: P.T.D. Notes: IType Inj. Type test IType Inj. Type test Type Inj. Type test 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 I traveled to BPXs MPU and witnessed the initial MIT on wells E-13B And J-20A. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was the performed with both wells demonstrating good mechanical integrity. M.I.T.'s performed: 2 Attachments: Number'of Failures: 0 Total Time during tests: 2 hour cc: MIT report form 5/12/00 L.G. MIT MPU E-13B & J-20A 6-17-02 CS.xls 6/20/2002 To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7m Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPJ-20A, AK-MM-00311 March 04, 2002 MPJ-20A: Digital Log Images: 50-029-22832-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIFF BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTEN .TION OF: Sperry-Sun Drilling Services Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED 0 9 Alaska Oil & Gas Cons. Commission Anchorage WELL LOG TRANSMITTAL To: State of Alaska February 26, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPJ-20A, AK-MM-00311 1 LIS formatted Disc with verification listing. API#: 50-029-22832-01. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. iPetro-technical Data Center LR2-1 900 E. Benson Blvd. An.chorage, Alaska 99649-6612 Date: RECEIVED 2002 LOG ,,. TRANSMITTAL ProActive Diagnostic Services, Inc. To-' State of Alaska A~ 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE' Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmitSal letter to the attention of' Joey Burton/Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box '1369 Stafford, TX 77497 BP Exploration(Alaska), Inc. Petro-Technical Data Center LR2-1 900 East Benson Blvd. Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S] OR C[~ROM FILM BLUELINE · Open Hole I I 1 ,, Res,' Eval. CH, I I 1 Mech. CH. I ,. , Caliper Survey ,. Signed' ~ Print Name: ProActive Diagnostic Services, Phone:(90,7) 245-8951 Fax:(907) 245-8952 .Date' Inc., E-mail: pdsanchorage~memorylog.com RECEIVED JUN 2 6 310 K Street 8olte 200~ ~nc~o~age~ ~ 99501 Wcbsite: ~.memo~log.~m STATE OF ALASKA ALASKa," iL AND GAS CONSERVATION COIV~.' ;SION .EPO.T OF wE,, OPE.^T,ONS I Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Drill-Post Work: CBL / IPERF 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 64.22' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service .4. Location of well at surface 8. Well Number 2207' NSL, 3288' WEL, SEC. 28, T13N, R10E, UM MPJ-20A At top of productive interval 9. Permit Number / Approval No. 200-185 4016' NSL, 1231' WEL, SEC. 30, T13N, R10E, UM 10. APl Number At effective depth 50-029-22832-01 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 4088' NSL, 1460' WEL, SEC. 30, T13N, R10E, UM 12. Present well condition summary Total depth: measured 11176 feet Plugs (measured) true vertical 3985 feet Effective depth: measured 11088 feet Junk (measured) true vertical 3921 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 260 sx Amtic Set (Approx.) 112' 112' Surface Intermediate Production 6172' 7" 1476 sx PF 'E', 132 sx Class 'G' 30'-6202' 30-2985 Liner 5133' 4-1/2" 250 sx Class 'G' 6043'-11176' 2960-3985 '., ,, Perforation depth: measured 10900'- 10920', 10920'- 10940', 10996'- 11016' RECEIVED true vertical 3788' - 3801', 3801' - 3815', 3855' - 3869' JUN O5 2001 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 6077' Alaska 0il & Gas Cons. Commission Packers and SSSV (type and measured depth) Packer 6030' Anchorage 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. "Representative Daily Average Production or Iniecti0n Data " OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service Water & Gas Injector , 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Michael Williams ~,~ ~1¢~ Title Technical Assistant Date ~t~'/f/'~/' ?i~:!:~!~'_:.i::]II: ;?i': ;'.i.~"?;i::];?::?~':~,':!:~.:'. ':: :.!;.?-_ ............. '...'. ..... . ....:: ::... ':. :.:.:... '.:.....' :::: ;.'::":':" ;. '.': '." .'..'" '.':'..' :'. :'~,";~,,~~': !~~:~;~,~/~',~=:~ Form 10-404 Rev. 06/15/88 ('i DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/18/2001 DRILL-POST WORK: CBL / IPERF SUMMARY RIGGED UP AND COMPLETED BOP TEST COMPLETED CBL, UNABLE TO PERF DUE TO BAD WIRE REQUIRING REHEADING COMPLETED IPERF OF TWO INTERVALS ( 10900' - 10940'= 40' / 10996' - 11016'= 20' ). MADE THREE GUN RUNS W/20' 2" PJ 4 SPF 60 DEGREE PHASED GUNS. THE PROGRAM REQUESTED 22' BOTTOM INTERVAL ( 10994' - 11016' ) BUT THREE 20' GUNS WERE BROUGHT OUT TO THE JOB; ONE OF WHICH WAS USED FOR THE.BOTTOM INTERVSAL WITH MARK O'MALLEY'S APPROVAL. THE PROGRAM ALSO REQUESTED 90 DEGREE PHASED GUNS WHICH ARE NOT AVAILABLE IN 2" GUNS THEREFORE 60 DEGREE PHASED GUNS WERE USED, WELL WAS LEFT SHUT-IN AND FREEZE PROTECTED Fluids Pumped BBLS. Description MEOH 211 211 Total .. IPERF 02/18/2001 SUMMARY The following two intervals were perforated using 2" PJ 4 SPF 60 degree phased guns. Three gun runs. 10900' - 10940' MD 10996' - 11016' MD K~ STATE OF ALASKA ~i ALAS ,JIL AND GAS CONSERVATION COM ~SION 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. 200-185 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ....,..~.,,,,,,.~, 50-029-22832-01 4. Location of well at surface ~....:...:.; ..-.: ..,. ,..~ ~.:~;~,~I;;T~' 9. Unit or Lease Name 2207' NSL, 3288' WEL, SEC. 28, T13N, R10E, UM .... yr~ Milne Point Unit At top of productive interval 4016' NSL, 1231' WEL, SEC. 30, T13N, R10E, UM At total depth ., ....~:. .... MPJ-20A 4088' NSL, 1460' WEL, SEC. 30, T13N, R10E, UM .'. · , .~ .[ 10. WellNumber 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Milne Point Unit / Schrader Bluff KBE = 64.22' ADL 025517 12. Date Spudded 113. DateT. D. Reached114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 116. ND. of Completions 12/22/2000 12/26/2000 2/18/2001 N/A MSL I One 17. Total Depth (MD+TVD) ~ 18. Plug Back Depth (MD+TVD) 119. Directional Survey ~ 20. Depth where SSSV set121. Thickness of Permafrost 11176 3985 FTI 11088 3921 FTI []Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, and CBL (Post Rig) 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 260 SX Arctic Set (Approx.) 7" 26# L-80 30' 6202' 8-1/2" 1476 sx PF 'E', 132 sx Class 'G' 4-1/2" 12.6# L-80 6043' 11176' 6-1/8" 250 sx Class 'G' 24. Perforations pp. en to. P.roductipn (M,D+.TVD of Top and 25. TUBING RECORD Bottom and ~merva~, raze and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 6077' 6030' MD TVD MD TVD 10900' - 10920' 3788' - 3801' 10920' - 10940' 3801' - 3815' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 10996' - 11016' 3855' - 3869' DEPTH INTERVAL IMD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 210 Bbls of Diesel , , '27. ' , , PRODUCTION TEST .... '~)ate First Production Method of Operation (Flowing, gas lift, etc.) February 24, 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 GRAWTY-API (CORR) Press. .24-HOUR RATE 28. CORE DATA Brief descripti°n °' lith°l°gy' P°r°sity' fractures' apparent dips and presence °' °il' gas °r water' Subm~c~°~h~i' V ED ~AR 22 2001 Alaska 0il & Gas Cons. C0mmissio~ Anchorage __ Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. NA 10468' 3613' N B 10602' 3645' NC 10694' 3677' N E 10740' 3697' N F 10839' 3749' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~,~~ _~~_. Title Technical Assistant Date ~)~," ~,~o~/ MPJ-20A 200-185 Prepared By Name/Number: Terrie Hubble, 564-4628 Well I{lumber 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'. I:CFIVI D Form 10-407 Rev. 07-01-80 BP AMOCO Page I of 3 Operations Summary Report Legal Well Name: MPJ-20 Common Well Name: MPJ-20 Spud Date: Event Name: PLUG+ABANDON Start: 11/10/2000 End: Contractor Name: Rig Release: Group: RIG I Rig Name: Rig Number: .. .... Sub. .. Date From-To H°urs Task Code Phase Description,of Operations ,, 1111012000 12:00 - 23:59 11.98 CONS POST wait on weather (phase 3) , 11111/2000 00:00 - 23:59 23.98 CONS POST wait on weather (phase 3 down to phase 1 ) Held safety stand down with both crews and reviewed all recent incidents to see what we could do to avoid future incidents. 18:30 hrs to 23:59 hrs clear snow on pad and prepare for rig move. 1111212000 00:00 - 06:00 6.00 CONS POST Standby weather conditions. Clear snow on pad and prepare for rig move. 06:00 - 09:00 3.00 MOB PRE Scope down Derrick, Move rig from MPU J-10 to MPU J-20 09:00 - 14:00 5.00 RIGU PRE Spot Modules And camp. Raise and Scope out Derrick> Hook Up all Modules. Rig accepted at14:00 Hrs 11-12-00. 14:00 - 18:00 4.00 KILL DECOMP Hook up Lines to kill well. Picked up Lubricator and pulled BPV. 18:00 - 21:30 3.50 KILL DECOMP Heat Up and take on 410 bbls of 10.2 fluid. Heated to 150 degrees. 121:30 - 23:30 2.00 KILL DECOMP Burro and spot Tiger tank & rig up hard lines. 23:30 - 23:59 0.48 KILL DECOMP Pressure test lines to 3,500 psi 11113/2000 00:00 - 05:00 5.00 KILL DECOMP Kill well with 10.2 ppg. brine 05:00 - 07:30 2.50 WHSUR DECOMP Set twc & test same to 1000 & nipple down tree. 07:30 - 10:30 3.00 BOPSUI; DECOMP Nipple up bop 10:30 - 11:30 1.00 BOPSUI; DECOMP test bop's to 250~3500 psi. Test waived by John Crisp with AOGC 11:30 - 12:30 1.00 WHSUR DECOMP rig lubricator & pull twc. 12:30 - 13:30 1.00 WHSUR DECOMP mu landing jt. & check for pressure under hanger & back out rilds & pull hanger & lay dn same. 13:30 - 23:59 10.48 PULL DECOMP pull esp completion, laying dn tbg. & removing heat trace tape & lay dn same. at pump. 11114/2000 00:00 - 01:30 1.50 PULL DECOMP finish laying dn tbg. & esp completion, lost 5-bands in hole found 3-on surface equipment. 01:30 - 02:00 0.50 PULL DECOMP Clean floor & rig up to run 5.95" reverse basket. 02:00 - 02:30 0.50 WHSUR DECOMP Make Up Baker String Mill with 6.151" OD gauge RIH 31'. 11' below hanger and into 7" casing 02:30 - 10:30 8.00 CLEAN DECOMP Picked up Baker Scoop and and Trip in the hole while picking up single ~ 3 112" drill pipe. TIH to 6517' and picked up to 6,425' 10:30 - 12:00 1.50 CLEAN DECOMP 'Circulate hole clean 12:00 - 14:30 2.50 CLEAN DECOMP laid down 3 1/2" drill Pipe to 6,206'. POH and stand back in stands. 66 stds and double. Lay down Baker Scoop. Recovered 1 fiat band. 14:30 - 15:30 1.00 PXA DECOMP Pick up Halliburton 7" EZSV Squeeze Packer and EZ Drill SV drag Block Setting tool 15:30 - 19:00 3.50 PYA DECOMP I Run in the hole with Halliburton 7" EZSV Squeeze Packer to 6,213'. Broke circulation at 3 BPM at 600 psi. ! 19:00 - 20:00 1.00 PYA DECOMP 'Set Halliburton 7" EZSV Squeeze Packer at 6,213' (4ES RT-GL corrected back to Nabors 27E at 6,224' ). Pulled 50 k over to set. Stung back into Halliburton 7" EZSV Squeeze Packer and tested annulus to 2,500 psi. tested OK. Established and injection rate of 1100 psi at 2.5 bpm. Pumped a total of 7.7 bbls. 20:00 - 22:30 2.50 PYA DECOMP Held PJSM with Schlumberger, Halliburton, Peak, and Rig crews. Un Stung from Halliburton 7" EZSV Squeeze Packer. Pumped 10 bbls of freshwater ahead and shut in and tested surface lines to 3,500 psi. Released pressure and pumped 10 bbls of Fresh water followed by 20 bbls of 15.8 ppg, 1.17 ff3/sk yield Class G cement. Held 400 psi on annulus. Stung into Halliburton 7" EZSV Squeeze Packer and REcEIVEI) continued to pump an additional 44 bbls of 15.8 ppg, 1.17 ft3/sk yield Class G cement. Pumped a total of 65 bbls of slurry at 2.1 bpm at 1447 psi at end of job. Pumped 4 bbls of freshwater followed by 36 ~IAR 2 ;'. ~00~ bbls. of 10.1 ppg brine. Shut down and stung out of Halliburton 7" EZSV Squeeze Packer at 6,213'. ,~I~=QI~, 13i& Gas C~r~. ~,o~'l'l llissJor~ Arlchorage, Printed: 11/28/2000 8:54:00 AM BP AMOCO Page 2 of 3 Operations Summary Report Legal Well Name: MPJ-20 Common Well Name: MPJ-20 Spud Date: Event Name: PLUG+ABANDON Start: 11/10/2000 End: Contractor Name: Rig Release: Group: RIG Rig Name: Rig Number: .... Sub " ' ....... Date From - To Hours Task Code Phase Description of Operations 11114120o0 22:30 - 23:00 0.50 PXA DECOMP Reverse circulated well with 10.1 brine at 6,212'. Recovered show of cement after reverse circulating 40 bbls. Continued to reverse circulate and returns quickly cleaned up. Reverse circulated a total of 2 pipe volumes 80 bbls. Returns clean. 23:00 - 23:30 0.50 PYA DECOMP SWI and tested casing to 3,500 psi. recoreded on chart for 30 minutes. Lost 200 psi after 30 minutes. Released pressure 23:30 - 23:59 0.48 PYA DECOMP Filled pits with 8.5 ppg seawater and reverse circulated well at 5 bpm at 1,200 psi. 1111512000 00:00 - 02:00 2.00 PYA DECOMP Reverse circulated well at 5 bpm at 1,200 psi. 8.5 ppg seawater all the way around 02:00 - 07:00 5.00 PYA DECOMP Laid down 3 112" drill pipe to 2,115' 07:00 - 08:00 1.00 PXA DECOMP Rigged Up HB & R and Displace hole with diesel for freeze protect, at 2115'. 08:00 - 09:30 1.50 PYA DECOMP Continued to lay down 3 112" drill pipe. Break out and lay down Halliburton setting tool. 09:30 - 10:00 0.50 PYA DECOMP Top off casing with diesel. Rigged down and released HB & R. 10:00 - 10:30 0.50 PYA DECOMP Land hanger and locked down same. Set TWCV and tested to 2,500 3si. 10:30 - 12:30 2.00 PXA DECOMP Drain Stack, blow down lines, and Nipple down BOPE. 12:30 - 13:30 1.00 PXA DECOMP Nipple up tree and test hanger seals and body to 5000 psi 13:30 - 14:00 0.50 PYA DECOMP Set BPV and secure well. . , 001 Printed: 11/28/2000 8:54:00 AM BP AMOCO Page 1 of 4 Operations Summa Report Legal Well Name: MPJ-20A Common Well Name: MPJ-20A Spud Date: 12/22/2000 Event Name: REENTER+COMPLETE Start: 12/22/2000 End: 1/1/2001 Contractor Name: NABORS Rig Release: 1/1/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Date From-To Hours .Task Code Phase Description of Operations 12/19/2000 00:00 - 18:00 18.00 RIGU PRE Repair top drive and repair #4 Gen, commison #2 pump and 1 & 4 Gen. rig total commison @ 1800 hrs. rig was accepted @ 1800 hrs 12/19/2000 ( time was back up 8 hrs for the bop test so it would be 10:00 hrs 12/19/2000) 18:00 - 19:00 1.00 CLEAN DECOMP Prejob safety and spud meeting with crew on well 19:00 - 20:30 1.50 CLEAN DECOMP prep rig floor 20:30 - 23:30 3.00 CLEAN DECOMP Picking up mule shoe and 6 1/8 watermelon mill and drlg pipe pushing ice plug from 104-170ff, pull out for 6 1/8 bit 23:30 - 00:00 0.50 CLEAN DECOMP Pick up 6 1/8 bit and watermelon mill and trip in 12/20/2000 00:00 - 01:30 1.50 CLEAN DECOMP Trip in w/bit to 170 ft. pressure up, bit plug 01:30 - 02:30 1.00 CLEAN DECOMP Pulled out, bit plug w/scale from hw pipe, knock out jets trip into 170 ft. 02:30 - 05:00 2.50 CLEAN DECOMP Wash and drlg ice plugs from 170 ft to 525 ft 05:00 - 06:00 1.00 CLEAN DECOMP Picking up 3.5 13.3~ G drill pipe 06:00 - 07:00 1.00 CLEAN DECOMP Pre job and spud meeting with new crews 07:00 - 11:00 4.00 CLEAN DECOMP Picking up 3.5 13.3~ drill pipe to 2200 11:00 - 12:00 1.00 CLEAN DECOMP Circ diesel out of hole 12:00 - 17:00 5.00 CLEAN DECOMP Picking up 3.5 13.3~ G pipe to 5747 17:00 - 19:00 2.00! CLEAN DECOMP circ hole to clear scale and rust out of pipe 19:00 - 19:30 0.50 CLEAN DECOMP Pulled one stand of pipe 19:30-21:00 1.50; CLEAN DERK DECOMP Repaircrown-a-matic 21:00 - 00:00 3.00i CLEAN DECOMP Trip out and clear floor 12/21/2000 00:00 - 01:30 1.50 CLEAN DECOMP trip in w/bit and dc, hw pipe 01:30-06:00 4.50 CLEAN DECOMP picking up 3.5 pipe13.3~ G to 6218 06:00 - 06:30 0.50 CLEAN DECOMP Circ to clear pipe 06:30 - 09:30 3.00 CLEAN DECOMP Pull 12 sds and stand back in derrick, pick up 3.5 pipe to 6218 09:30 - 12:30 3.00 CLEAN DECOMP Circ, and displace hole with mud 12:30 - 17:00 4.50 CLEAN DECOMP Tripping out SLM, no correction 17:00 - 17:30 0.50 CLEAN DECOMP Clear floor and pre job safety meeting 17:30 - 20:30 3.00 STWHIP WEXIT Pick up whipstock and orient tools, test MWD 20:30 - 00:00 3.50 STWHIP WEXlT Trip in ,set whipstock w120,000~ ~ 60 L, 6218 '~ . 12/2212000 00:00 - 05:30 5.50 STWHIP WEXIT Shear off of Whipstock wi 35K - Mill window in 7" 26~ casing 6,202 to ",J 6,216' with Baker Window Master system - 3-5K wob, 80 rpm, 5,000 fi/# torque, Pumping at 251 gpm at 1600 psi 05:30 - 06:30 1.00 STWHIP WEXIT Pump high vis sweep and Circulate hole clean at 272 gpm 2000 psi 06:30 - 09:00 2.50 STWHIP WEXlT Monitor well - Pump slug - Pooh - stand back drill pipe 09:00 - 11:00 2.00' STWHIP WEXIT Lay down BHA - Top mill full gauge at 6.151" 11:00 - 12:00 1.00 STWHIP WEXIT Prejob safety meeting. Wash out BOP stack with wash tool - Clear rig floor - Service Top Drive 12:00 - 16:00 4.00 DRILL PROD1 Make up BHA #2: Pick up Sperry 5" Mud motor, adjust motor to 1.5 deg bent housing, Make up Sperry MWD/GR/ReslPWD - Make up Security 6 1/8" PDC bit - difficulty getting 5" motor with 1.5 deg BH down casing, Pooh adjust motor to 1.25 deg BH - Orient & Program logging tools 16:00 - 18:30 2.50 DRILL PROD1 Trip into 6216, fill pipe every 25 sd. 18:30 - 19:30 1.00 DRILL PROD1 Orient motor and slide tru window @ 6216 19:30 - 20:00 0.50 DRILL PROD1 Side drill from 6216 to 6235 20:00- 20:30 0.50 DRILL PROD1 Circ 20:30 - 21:00 0.50 DRILL PROD1 Preform FIT: test formation to 325 PSI with 8.9 ppg mud in hole at 2990 R£Ci';I~-[~ TVD:11.0EMW- Nobledoff : 3.00 DRILL PROD1 Drill and slide from 6,235 to 6,290'- Art 1.0 hrs, Ast 1.0 hrs, Average Rop 27.5 ftJhr with 5-10,000 wt. 254 gpm at 2000 psi - rotate at 70 rpm MAR 2 2 2001 Torque 5,000 ft/Ib Pdnted: 1/26/2001 4:33:02PM BP AMOCO Page 2 of 4 Operations Summa Report Legal Well Name: MPJ-20A Common Well Name: MPJ-20A Spud Date: 12/22/2000 Event Name: REENTER+COMPLETE Start: 12/22/2000 End: 1/1/2001 Contractor Name: NABORS Rig Release: 1/1/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Date From - To Hours Task Code Phase Description of Operations 12/23/2000 00:00 - 13:30 13.50 DRILL PROD1 Drill and slide from 6,290 to 7674'- Art 4.5 hrs, Ast 4.5 hrs, Average Rop 100 fi/hr with 5-10,000 wt. 254 gpm at 2000 psi - rotate at 70 rpm Torque 5,000 fi/lb 13:30- 14:30 1.00 DRILL PROD1 Circ. and pumps sweeps 14:30 - 16:30 2.00 DRILL PROD1 Pump out to 6000--no problems 16:30 - 18:00 1.50 DRILL PROD1 Service top drive, prejob safety meeting, change the swing of kelly hose 18:00 - 20:30 2.50 DRILL PROD1 Trip in hole, wash bridges @ 7300 and 7584, wash the last 60 ft. to bottom 20:30 - 00:00 3.50 DRILL PROD1 Drill and slide from 7674 to 8077'- Art 2 hrs, Ast 1.25 hrs, Average Rop 110 fi/hr with 5-10,000 wt. 271 gpm at 2700 psi - rotate at 80 rpm Torque 5,000 fi/lb 12/24/2000 00:00 - 16:00 16.00 DRILL PROD1 Drill and slide from 8077 to 9444'- Art 13.5 hrs, Ast 1.5 hrs, Average Rop 91 fi/hr with 5-10,000 wt. 271 gpm at 2800 psi - rotate at 80 rpm Torque 5,000 fi/lb 16:00 - 17:00 1.00 DRILL PROD1 Circ and pump sweeps 17:00 - 22:00 5.00 DRILL PROD1 Pump out to 7000 and trip back in. wash 150 ft. to bottom. (no problems) 22:00 - 00:00 2.00 DRILL PROD1 Drill and slide from 9444 to 9565'- Art 1 hrs, Ast .5 hrs, Average Rop 80 fi/hr with 5-10,000 wt. 271 gpm at 2800 psi - rotate at 80 rpm Torque 5,000 fi/lb 12/25/2000 00:00 - 00:00 24.00 DRILL PROD1 Drill and slide from 9565 to 10,866'- Art 8.75 hrs, Ast 9 hrs, Average Rop 75 fi/hr with 10-15,000 wt. 260 gpm at 3200 psi - rotate at 80 rpm Torque 5,000 fi/lb 12/26/2000 00:00 - 05:00 5.00 DRILL PROD1 Directional drill 10,866 to TD @ 11,176' - 160' below base of 'OB' sand - Art 2.25 hrs, Ast 1.5 hrs, Average Rop 82.6 fi/hr - Pumping at 251 gpm 3200 psi, 80 rpm with 5,000 fi/lb torque - Start angle drop section at 10490' - drop angle from 82 deg to 43 deg at TD- average 8 deg / 100' angle drop 05:00 - 10:00 5.00 DRILL PROD1 Circulate hole clean by pumping high vis sweep, Low vis sweep, and i High vis sweeps - Pump 3 hole volumes suface to surface - Pump 251 gpm at 3300 psi, Rotating at 80 rpm - Final ECD 11.8 ppg 10:00 - 14:30 4.50 DRILL PROD1 Monitor well - Pump slug - Pooh to 7" window at 6,202' - P/U wt. 170k - S/O wt. 80K - Top drive wt. 70K - work though spot that appeared to drag more than normal - Did not pump out 14:30 - 17:00 2.50 DRILL PROD1 Monitor well - Drop Sperry ESS survey and pump down slowly - TIH with with survey tool and take check shot survey at 7,181' 17:00 - 21:00 4.00 DRILL PROD1 Pooh to casing shoe - Pump slug & blow down mud lines - Continue pooh 21:00 - 00:00 3.00 DRILL PROD1 Down load MWD data - Lay down BHA - Bit cutters worn down to body of bit 12/27/2000 00:00 - 01:00 1.00 DRILL PROD1 Clean rig, service top drive 01:00 - 07:00 6.00 DRILL PROD1 Test BOP and all related equipment to 250 psi Iow for 5 rain 3500 psi high for 10 min. Choke manifold valves #9 & #14 failed to test. Witness of test waived by Jeff Jones AOGCC. 07:00 - 08:00 1.00 DRILL PROD1 PJSM, pull test plug, install wear bushing 08:00 - 10:00 2.00 DRILL BARR . PROD1 Repair manifold valves #9 & #14 and test same 250 psi Iow for 5 min, 3500 psi high for 10 min. Recorded on chart · '~0 - 14:00 4.00 DRILL PROD1 MU BHA #3:6 1/8" porcupine hole opener and 3 x 6" string stabilizers. cE~VT11~.0 TIH to 6100'. fill pipe every 25 stands 0 15:00 1.00 DRILL PROD1 Circulate and condition mud - 9.1ppg 55 viscosity 15:00 - 00:00 9.00 DRILL PROD1 TIh to 6300' with all stabilizers below whipstock -Wash & ream with hole 22 20(1 MI Printed: 1/26/2001 4:33:02 PM BP AMOCO Page 3 of 4 Operations Summa Report Legal Well Name: MPJ-20A Common Well Name: MPJ-20A Spud Date: 12/22/2000 Event Name: REENTER+COMPLETE Start: 12/22/2000 End: 1/1/2001 ~Contractor Name: NABORS Rig Release: 1/1/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Date From-To Hours Task Code Phase Description of Operations 12127/2000 15:00 - 00:00 9.00 DRILL PROD1 opener f/6360' to 9595' at 2400 hs - Reaming at 400-500fph, 295gpm, tq 4000-5000fi-lbs - Start adding lubricants to mud system at 8,000' 12/28/2000 00:00 - 05:30 5.50 DRILL PROD1 Wash & ream w/hole opener f/9595' to 11176'. 400-500fph, 295gpm, 4500-5500ft-lbs. Adding lubricants to mud system. 05:30 - 08:00 2.50 DRILL PROD1 Circulate and condition mud for liner. 08:00 - 11:00 3.00 DRILL PROD1 POOH to 6100', no problems. 11:00 - 12:30 1.50 DRILL PROD1 'Circulate and condition mud. Sweep w/EP mud lube and spot EP mud lube at shoe. 12:30 - 16:00 3.50 DRILL PROD1 POOH, LD BHA. 16:00 - 17:00 1.00 DRILL PROD1 Clear rig floor. 17:00 - 17:30 0.50 CASE COMP Make up cement head and stand back in derrick. 17:30 - 18:00 0.50 CASE COMP RU casing tools. 18:00- 18:30 0.50 CASE COMP PJSM on running liner. 18:30 - 00:00 5.50 CASE COMP Run 123 joints of 4 1/2", 12.6#, L80, IBT liner. 12/29/2000 00:00 - 01:00 1.00 CASE COMP Pick up Baker 5 x7" liner hanger with ZXP liner top packer - Change handling tools 01:00 - 01:30 0.50 CASE COMP TIH 8 stand of 3 1/2" 13.30 'G' drill pipe to 5800' 01:30 - 02:30 1.00 CASE COMP Circulate & Condition mud - reduce yield point - Circulate at 5 bbl / rain 800 psi 02:30 - 04:30 2.00 CASE FLOR COMP Repair Iron Roughneck 04:30 - 09:00 4.50 CASE COMP Continue TIH with 4 1/2" liner on 3 1/2" drill pipe - No problem - Pick up Baker top drive cement head 09:00 - 13:30 4.50 CASE COMP Break circulation & attempt to tag bottom - did not tag at calculated pipe depth - Increase circulation rate slowly to 5 bbl/min 1400 psi - Circulate & reciprocate pipe until bottom up - p/u 130k, s/o 90k - Pick up drill pipe and wash down, tag bottom 56' deep - Continue circulating until three annular vol. - Rig up Cement lines to Baker top drive head 13:30 - 16:00 2.50 CEMT COMP Pump 5 bbls water, Test lines to 4500 psi, pump 50 bbls CW-IO0 + 50 bbls mudpush spacer mixed at 10.0 ppg Followed by 250 sx Class 'G' Litecrete w/48.0% D-124 + 1.5% S001 + .5 gal/ex D300 + .12 gal/sk XE916 dispersant L - Mixed at 11.0 ppg, 126 bbl slurry, Yield 2.86 cfc - Wash cement out of lines - Drop wiper dart and displace with fresh water at 5 bpm 1800 psi - bump plug to 3600 psi to set liner hanger - Reciprocated pipe until 20 bbls before bumping plug - full returns - Check float -ok - Pressure up to 4100 psi and release setting tool - Set down with 30K and set liner top packer - ClP @ 1530 hrs 12/29/00 16:00 - 17:00 1.00 CEMT COMP Pressure up 1000 psi down drill pipe - Pull seal out of hanger assembly and Continue circulating long way with 9.2 ppg mud - Circulate out CW-100 + Mud push spacer & 32 bbls of 11.0 ppg cement - Circulate two bottoms up - Close Hydrill and verify liner top packer set with 2000 psi - ok 17:00 - 19:00 2.00 CLEAN COMP Displace 9.2 ppg mud with 8.4 ppg seawater Pumping at 8 bbl minute 1200 psi 19:00 - 20:00 1.00 CASE COMP Break down Baker top drive plug dropping head 20:00 - 00:00 4.00 CASE COMP Stand back 14 stands 3 1/2" drill pipe - Lay down excess drill pipe 12/30/2000 00:00 - 03:00 3.00 CLEAN COMP Pre-Job safety meeting - Strap & re-arrange tubing in pipe shed -some tubing AB-modified, Some not - Put all AB-Mod tubing together in Pipe shed. ~ (' [~ ~ V ~3:~!~- 11:30 8.50 CLEAN COMP Make up Mule shoe - Pick up 4900' 2 7/8" 6.5~ L-80 tubing - drift to 2.347" - difficultly getting rabbit though due to ice ~1.~:30 - 16:00 4.50 CLEAN COMP Change handling tools- make up 7" 26# Casing scraper- TIh with 3 2( iAR 2 2 U! 1/2" drill pipe- SLM - Tag liner top at 6053' Drill pipe measurement. 149' of lap from dpm. Printed: 1/26/2001 4:33:02 PM BP AMOCO Page 4 of 4 Operations Summary Report Legal Well Name: MPJ-20A Common Well Name: MPJ-20A Spud Date: 12/22/2000 Event Name: REENTER+COMPLETE Start: 12/22/2000 End: 1/1/2001 Contractor Name: NABORS Rig Release: 1/1/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Date From-To Hours Task Code Phase Description of Operations 12/30/2000 16:00 - 22:00 6.00 CLEAN COMP Pre-Job Safety meeting - Displace to Clean seawater by pumping 25 bbls Caustic wash + Two 25 bbl dirt Magnet pills followed by 700 bbl clean seawater - Pump at 5? bpm 3000 psi - reciprocate pipe - Final NTU on return fluid 101 .22:00 - 23:00 1.00 CLEAN COMP Rig up - Pressure test Casing to 3500 psi for 30 minutes on Chart -Lost 100 psi in 30 minutes - ok 23:00 - 00:00 1.00 CLEAN COMP Pooh lay down 3?" drill pipe - SLM 12/31/2000 00:00 - 06:00 6.00 CLEAN COMP Continue Pooh lay down 3 1/2" 13.30 'G' drill pipe - Change handling tools - Pooh & stand back in derrick 52 stand 2 7/8" 6.5~ L-80 Eue tubing 06:00 - 07:00 1.00 RUNCOI~I COMP Pull wear bushing - Clear rig floor 07:00 - 09:00 2.00 RUNCOI~I COMP Slip & Cut Drill line 09:00 - 09:30 0.50 RUNCOI~I COMP Rig up Tubing handling equipment 09:30 - 10:00 0.50 RUNCOI~! COMP Safety meeting with drill crew on running tubing 10:00 - 20:30 10.50 RUNCOI~ COMP Pick up Tail pipe assembly & Baker 7" S-3 permanent Packer - Inspect ~ packer - TIh w/ 52 stands 2 7/8" 6.5# L-80 Eue used tubing from derrick, Continue running tubing by picking up singles - tag up inside i liner - Space out - Make up FMC 11 x 2 7/8" tubing hanger w/eue , landing thread - Install two way check - !land tubing & Run in lock down pins - Ran total 190 jts 5970.24' 2 7/8" 6.5# L-80 Eue used tubing 20:30 - 21:30 1.00 RUNCOI~ ~ COMP Test Two way check valve to 1000 psi from above by pumping below blind rams ok- pump down annulus and test below to 1000 psi 21:30 - 22:30 1.00 RUNCOI~ COMP ~Blow down all lines & Pump suctions 22:30 - 00:00 1.50 WHSUR COMP : Nipple down & set back 13 5/8" 5000~ bop stack 1/1/2001 00:00 - 03:00 3.00 WHSUR COMP Nipple up FMC 11" x 2 9/16" 5000~ ESP adapter spool, Nipple up ClW 2 9/16 5000# Tree 03:00 - 06:30 3.50 WHSUR COMP Rig up HB&R pump truck - Test tree to 5000 psi for 10 minutes - Difficulty testing due leaking test line valves 06:30 - 09:30 3.00 RUNCOI~ COMP Freeze protect well by pumping diesel down annulus taking returns up tubing until diesel surface to surface - Pump 210 bbls diesel 09:30 - 12:00 2.50 RUNCOI~ COMP Drop 1" steel ball - rig up HES .105 slick line - Rill with 2.19" blind box on rollers - wireline stopped at 3500' - Pump wireline tool string down at 1 bpm with diesel - ball on seat with wireline tools at 5500' - Pooh with slickline 12:00 - 12:30 0.50 RUNCOI~ COMP Pressure up down tubing with annulus open to 3800 psi, set Baker S-3 Packer at 6039' - test tubing for 30 minutes - ok 12:30 - 14:00 1.50 RUNCOI~ COMP Pressure up down annulus with tubing open to 3700 psi - test Packer For 30 minutes on chart fOr MIT - bled to 3500 psi in 30 minutes - MIT witness by Mr. Jeff Jones of AOGCC 14:00 - 15:00 1.00 RUNCOI~I COMP Rig down HB&R pump truck, Rig down HES slickline unit 15:00 - 17:00 2.00 RUNCOI~I COMP Lay down 3 1/2" drill pipe from derrick 17:00 - 18:00 1.00 RUNCOI~I COMP Set BPV - Clean pit - Clear cellar area & rig floor Rig Released 1800 hrs 01/01/2001 R[:C[IVED /AR 22 2001 Anchorage Printed: 1/26/2001 4:33:02 PM Well: M PJ-20A Accept: 12/19/00 Field: Milne Point Spud: 12/22/00 APl: 50-029-22832-01 Release: 01/01/01 Permit: 200-185 Rig: Nabors 22E Date POST-RIG WORK 02/17/01 Ran CBL, data looks good. 02/18/01 Completed initial perf of two intervals; 10900' - 10940' = 40' and 10996' - 11016' = 20'. Made three gun runs with 20', 2" PJ 4 spf 60 degree phased guns. The well was left shut in and freeze protected. RECEIVED MAR 22 2001 29-Jan-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well MPJ-20A Dear Dear SidMadam' Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,175.58' MD 6,215.00' MD 11,176.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) DEFiNiTiVE Milne Point Unit Alaska Drilling & Wells Miine Point MPJ, S10t MPJ-20 MPJ-20A Surveyed: 26 December, 2000 $ UR VEY REPORT 26 January, 2001 Your Ref: APl 500292283201 Surface Coordinates: 6014605.30 N, 552033.21 E (70° 27' 02.1930" N, Kelly Bushing: 64.22ft above Mean Sea Level f49° 34' 31.7298" W) DRILLING SERVICES Survey Reft svy9789 A Halliburton Company Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for MPJ-20A Your Ref: AP1 500292283201 Surveyed: 26 December, 2000 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 6175.19 79.440 272.690 2915.81 2980.03 6202.00 78.730 272.590 2920.89 2985.11 6292.05 85.850 265.860 2932.98 2997.20 6322.40 87.290 263.310 2934.79 2999.01 6357.04 87.070 262.220 2936.50 3000.72 6387.97 86.670 263.000 2938.19 3002.41 6420.45 84.380 260.710 2940.72 3004.94 6513.26 82.360 260.720 2951.44 3015.66 6602.54 82.640 260.290 2963.09 3027.31 6701.36 82.290 259.700 2976.05 3040.27 6794.37 82.110 260.700 2988.67 3052.89 6891.24 82.200 259.990 3001.89 3066.11 6985.31 82.370 260.040 3014.52 3078.74 7074.44 82.690 260.220 3026.11 3090.33 7169.68 81.230 264.250 3039.43 3103.65 7203.67 80.530 268.710 3044.82 3109.04 7235.87 80.670 271.140 3050.08 3114.30 7262.89 81.740 273.670 3054.22 3118.44 7297.31 83.060 277.480 3058.77 3122.99 7328.78 83.040 280.350 3062.58 3126.80 7354.64 82.790 282.480 3065.77 3129.99 7388.21 82.130 286.640 3070.18 3134.40 7420.41 81.450 289.820 3074.78 3139.00 7447.98 81.420 292.160 3078.88 3143.10 7546.16 78.810 297.000 3095.74 3159.96 7634.75 79.860 299.180 3112.14 3176.36 7734.29 80.940 301.890 3128.74 3192.96 7829.13 80.950 301.310 3143.67 3207.89 7923.04 80.270 300.670 3158.99 3223.21 8016.02 79.440 302.270 3175.37 3239.59 Global Coordinates Northings Eastings (ft) (ft) 164.06 N 4441.18W 6014738.34 N 547590.99 E 165.27 N 4467.48W 6014739.37 N 547564.68 E 164.02 N 4556.60W 6014737.50 N 547475.58 E 161.16 N 4586.76W 6014734.43 N 547445.44E 156.80 N 4621.08W 6014729.83 N 547411.15 E 152.83 N 4651.70W 6014725.65 N 547380.55 E 148.24 N 4683.75W 6014720.84 N 547348.53 E 133.37 N 4774.73W 6014705.33 N 547257.66 E 118.77 N 4862.03W 6014690.12 N 54.7170.46 E 101.75 N 4958.51W 6014672.42 N 547074.11E 86.06 N 5049.31W 6014656.11 N 546983.42 E 69.97 N 5143.92W 6014639.35 N 546888.93 E 53.81 N 5235.72W 6014622.55 N 546797.24 E 38.66 N 5322.79W 6014606.79 N 546710.28 E 25.91 N 5416.21W 6014593.40 N 546616.96 E 23.85 N 5449.69W 6014591.10 N 546583.48 E 23.81N 5481.46W 6014590.84 N 546551.72 E 24.93 N 5508.13W 6014591.77 N 546525.04 E 28.25 N 5542.08W 6014594.85 N 546491.06 E 33.09 N 5572.94W 6014599.48 N 546460.17 E 38.17 N 5598.09W 6014604.38 N 546434.99 E 46.53 N 5630.30W 6014612.52 N 546402.72 E 56.50 N 5660.56W 6014622.27 N 546372.39 E 66.26 N 5686.02W 6014631.86 N 546346.87 E 106.46 N 5773.95W 6014671.45 N 546258.66 E 147.46 N 5850.74W 6014711.90 N 546181.58 E 197.32 N 5935.27W 6014761.17 N 546096.71E 246.39 N 6015.04W 6014809.69 N 546016.60 E 294.10 N 6094.46W 6014856.84 N 545936.84 E 341.88 N 6172.52W 6014904.07 N 545858.45 E Alaska Drilling & Wells Milne Point MPJ Dogleg Vertical Rate Section (°/100ft) 4377.44 2.67 4403.41 10.83 4490.30 9.64 4519.19 3.21 4551.85 2.83 4580.97 9.96 4611.35 2.18 4697.22 0.57 4779.54 O.69 487O.33 1.08 4955.85 0.73 5045.01 0.19 5131.41 0.41 5213.39 4.46 5302.08 13.12 5334.40 7.46 5365.45 10.06 5391.78 11.62 5425.67 9.05 5456.86 8.23 5482.52 12.44 5515.76 10.00 5547.44 8.39 5574.37 5.54 5668.75 2.69 5752.42 2.90 5845.50 0.60 5933.76 0.99 6021.40 1.91 6107.72 Comment TIE ON POINT AK-6 BP_IFR-AK Window Point 26 January, 200f - f6:00 Page 2 of 5 DriliQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPJ-20A Your Ref: APl 500292283201 Surveyed: 26 December, 2000 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Easfings (ft) (ft) (ft) (ft) (ft) 8107.90 79.700 302.660 3192.00 3256.22 8203.54 78.500 302.660 3210.09 3274.31 8295.71 77.270 302.460 3229.43 3293.65 8388.20 80.450 302.000 3247.30 3311.52 8483.55 81.320 303.110 3262.41 3326.63 8579.06 80.610 301.790 3277.41 3341.63 8671.58 84.330 303.010 3289.53 3353.75 8765.08 84.490 303.570 3298.64 3362.86 8859.66 84.070 303.590 3308.06 3372.28 8950.57 82.070 304.170 3319.03 3383.25 9043.28 77.150 306.270 3335.75 3399.97 9135.95 80.020 306.130 3354.09 3418.31 9226.66 82.150 306.090 3368.14 3432.36 9315.79 82.070 306.380 3380.38 3~4.60 9411.45 79.570 306.620 3395.64 3459.86 9500.99 80.060 306.850 3411.47 3475.69 9594.08 81.740 302.930 3426.20 3490.42 9687.01 82.210 300.700 3439.17 3503.39 9779.43 82.110 300.730 3451.78 3516.00 9871.67 81.890 300.450 3464.62 3528.84 9963.67 82.170 300.770 3477.37 3541.59 10054.90 82.240 301.760 3489.75 3553.97 10144.32 82.180 301.970 3501.87 3566.09 10237.29 82.070 301.280 3514.61 3578.83 10325.68 81.800 301.330 3527.01 3591.23 10419.80 81.360 301.040 3540.79 3605.01 10512.92 78.300 300.090 3557.23 3621.45 10599.92 72.150 297.590 3579.41 3643.63 10693.05 66.410 295.720 3612.35 3676.57 10785.95 58.800 291.490 3655.08 3719.30 390.38 N 6248.76W 6014952.04 N 545781.87 E 441.06 N 6327.83W 6015002.17 N 545702.46 E 489.56 N 6403.78W 6015050.14 N 545626.17 E 537.95 N 6480.53W 6015097.99 N 545549.08 E 588.61 N 6559.89W 6015148.09 N 545469.37 E 639.22 N 6639.48W 6015198.15 N 545389.43 E 688.36 N 6716.91W 6015246.75 N 545311.66 E 739.44 N 6794.69W 6015297.28 N 545233.52 E 791.49 N 6873.09W 6015348.78 N 545154.76 E 841.79 N 6948.01W 6015398.56 N 545079.49 E 894.36 N 7022.49W 6015450.60 N 545004.65 E 948.00 N 7095.78W 6015503.73 N 544930.98 E 1000.81 N 7168.18W 6015556.03 N 544858.22 E 1052.99 N 7239.39W 6015607.72N 544786.64 E 1109.16 N 7315.30W .6015663.36 N 544710.35 E 1161.87 N 7385.92W 6015715.57 N 544639.35 E 1214.43 N 7461.31W 6015767.61N 544563.61E 1262.94N 7539.50W 6015815.57 N 544485.08 E 1309.70 N 7618.21W 6015861.78 N 544406.04 E 1356.18 N 7696.84W 6015907.71N 544327.09 E 1402.58 N 7775.25W 6015953.56 N 544248.35 E 1449.49 N 7852.51W 6015999.93 N 544170.77 E 1496.26 N 7927.76W 6016046.17 N 544095.20 E 1544.55 N 8006.17W 6016093.91N 544016.45 E 1590.02 N 8080.95W 6016138.86 N 543941.36 E 1638.23 N 8160.60W 6016186.51N 543861.37 E 1684.84N 8239.51W 6016232.57 N 543782.14 E 1725.41 N 8313.14W 6016272.63 N 543708.22 E 1764.50 N 8390.94W 6016311.17 N 543630.15 E 1797.59 N 8466.40W 6016343.73 N 543554.46 E Dogleg Rate (°/'lOOff) 0.50 1.25 1.35 3.47 1.47 1.55 4.23 0.62 0.44 2.29 5.76 3.10 2.35 0.33 2.63 0.60 4.53 2.43 0.11 0.38 0.46 1.08 0.24 0.74 0.31 0.56 3.44 7.59 6.44 9.13 Alaska Drilling & Wells Milne Point MPJ Vertical Section Comment 6192.41 6280.32 6364.73 6449.90 6538.09 6626.50 6712.48 6799.22 6886.77 6970.55 7054.36 7137.25 7219.08 7299.62 7385.59 7465.67 7550.37 7636.97 7723.71 7810.32 7896.70 7982.05 8065.41 8152.18 8234.81 8322.77 84O9.68 8490.17 8574.42 8655.12 26 January, 2001 - f6:00 Page 3 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPJ-20A Your Ref: AP1500292283201 Surveyed: 26 December, 2000 Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Northings Easfings Rate (ft) (ft) (°/100ft) 10876.30 50.010 289.900 3707.62 3771.84 1823.58 N 8535.04W 10968.36 43.790 287.000 3770.49 3834.71 1844.92 N 8598.73W 11059.17 43.930 286.500 3835.97 3900.19 1863.05 N 8658.98W 11113.82 43.840 286.270 3875.36 3939.58 1873.74N 8695.33W 11176.00 43.840 286.270 3920.21 3984.43 1885.80 N 8736.67W 6016369.24 N 543485.65 E 6016390.13 N 543421.81E 6016407.85 N 543361.43 E 6016418.28 N 543325.01E 6016430.06 N 543283.58 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.398° (16-Dec-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 282.060° (True). Based upon Minimum Curvature type calculations, at a MeaSured Depth of 11176.00ft., The Bottom Hole Displacement is 8937.88ft., in the Direction of 282.180° (True). 9.83 7.14 0.41 0.34 0.00 Alaska Drilling & Wells Milne Point MPJ Vertical Section Comment 8727.67 8794.42 8857.13 8894.91 8937.86 PROJECTED SURVEY 26 January, 2001 - ~6:00 Page 4 of 5 DrillQuest 2.00.06 Sperry. Sun Drilling Services Survey Report for MPJ-20A Your Ref: AP1500292283201 Surveyed: 26 December, 2000 Milne Point Unit Alaska Drilling & Wells Milne Point MPJ Comments Measured Depth (rt) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6175.19 2980.03 164.06 N 4441.18 W 6202.00 2985.11 165.27 N 4467.48 W 11176.00 3984.43 1885.80 N 8736.67 W Comment TIE ON POINT Window Point PROJECTED SURVEY Survey tool program for MPJ-20A From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 6175.19 2980.03 6175.19 2980.03 11176.00 3984.43 Survey Tool Description MWD Magnetic (MPJ-20) AK-6 BP_IFR-AK (MPJ-20A) 26 January, 200f - 16:00 Page 5 of 5 DrillQuest ZOO.06 29-Jan-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPJ-20A MWD Dear Dear SidMadam' Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,175.19' MD 6,215.00' MD 11,176.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) DE F NJT VE Milne Point Unit Alaska Drilling & Wells Milne Point MPJ, Slot MPJ-20 MPJ-20A MWD Surveyed: 26 December, 2000 S UR VEY REPORT 26 January, 2001 Your Ref: AP150029228320f Surface Coordinates: 60f4605.30 N, 552033.21 E (70° 27' 02.~930" N, ~49° 34'3~.7298" VV) Kelly Bushing: 64.22ft above Mean Sea Level ri RI I-..- !-- ! N Oi SE FIVI C~ES Survey Ref: svy9788 A Halliburton Company Sperry-Sun Drilling Services Survey Report for MPJ-20A MWD Your Reft AP1 500292283201 Surveyed: 26 December, 2000 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 6175.19 79.440 272.690 2915.81 2980.03 6202.00 78.730 272.540 2920.89 2985.11 6292.05 85.850 265.860 2932.98 2997.20 6322.40 87.290 263.280 2934.79 2999.01 6357.04 87.070 261.950 2936.50 3000.72 6387.97 86.670 262.120 2938.19 3002.41 6420.45 84.380 260.960 2940.72 3004.94 6513.26 82.360 260.840 2951.44 3015.66 6602.54 82.640 260.060 2963.09 3027.31 6701.36 82.290 258.920 2976.05 3040.27 6794.37 82.110 259.990 2988.67 3052.89 6891.24 82.200 259.330 3001.89 3066.11 6985.31 82.360 259.320 3014.53 3078.75 7074.44 82.690 259.580 3026.12 3090.34 7169.68 81.230 263.310 3039.45 3103.67 7203.67 80.520 267.630 3044.84 3109.06 7235.87 80.670 269.960 3050.11 3114.33 7262.89 81.740 272.510 3054.24 3118.46 7297.31 83.060 277.120 3058.79 3123.01 7328.78 83.040 279.970 3062.60 3126.82 7354.64 82.790 282.490 3065.79 3130.01 7388.21 82.130 286.270 3070.20 3134.42 7420.41 81.450 289.410 3074.80 3139.02 7447.98 81.430 291.730 3078.90 3143.12 7546.16 78.810 296.600 3095.76 3159.98 7634.75 79.860 298.770 3112.15 3176.37 7734.29 80.950 301.640 3128.75 3192.97 7829.13 80.950 301.080 3143.66 3207.88 7923.04 80.270 300.410 3158.99 3223.21 8016.02 79.440 301.900 3175.36 3239.58 164.06 N 4441.18W 6014738.34 N 547590.99 E 165.26 N 4467.48W 6014739.36 N 547564.68 E 163.97 N 4556.60W 6014737.45 N 547475.58 E 161.10 N 4586.76W 6014734.37 N 547445.44 E 156.65 N 4621.07W 6014729.69 N 547411.16 E 152.37 N 4651.65W 6014725.19 N 547380.61 E 147.61N 4683.68W 6014720.21N 547348.62 E 133.03 N 4774.70W 6014704.99 N 547257.70 E 118.35 N 4861.99W 6014689.70 N 547170.51E. 100.48 N 4958.31W 6014671.16 N 547074.32 E 83.61N 5048.90W 6014653.66 N 546983.85 E 66.39 N 5143.31W 6014635.78 N 546889.56 E 49.12 N 5234.91W 6014617.87 N 546798.08 E 32.94 N 5321.79W 6014601.08 N 546711.32 E 18.91N 5415.02W 6014586.40 N 546618.19 E 16.26 N 5448.47W 6014583.52 N 546584.76 E 15.59 N 5480.23W 6014582.63 N 546553.01E 16.17 N 5506.92W 6014583.02 N 546526.31 E 19.03 N 5540.91W 6014585.65 N 546492.30 E 23.67 N 5571.80W 6014590.07 N 546461.38 E 28.67 N 5596.97W 6014594.89 N 546436.18 E 36.93 N 5629.20W 6014602.93 N 546403.89 E 46.70 N 5659.53W 6014612.48 N 546373.49 E 56.27 N 5685.05W 6014621.88 N 546347.90 E 95.84 N 5773.27W 6014660.83 N 546259.41E 136.29 N 5850.36W 6014700.74N 546182.04 E 185.66 N 5935.17W 6014749.52 N 546096.89 E 234.40 N 6015.14W 6014797.70 N 546016.58 E 281.77 N 6094.77W 6014844.51N 545936.62 E 329.12 N 6173.10W 6014891.31N 545857.97 E Alaska Drilling & Wells Milne Point MPJ Dogleg Vertical Rate Section Comment (°/'lOOft) 4377.44 TIE ON POINT 2.70 4403.41 Window Point 10.79 4490.29 9.72 4519.18 3.89 4551.81 1.40 4580.82 7.90 4611.15 2.18 4697.12 0.92 4779.41 1.20 4869.87 1.16 4954.94 0.68 5043.66 0.17 5129.64 0.47 5211.22 4.17 5299.46 12.72 5331.62 7.15 5362.53 10.13 5388.76 13.82 5422.59 8.99 5453.77 9.72 5479.43 11.33 5512.67 9.88 5544.38 8.32 5571.34 5.57 5665.88 2.68 5749.71 3.05 5842.97 0.58 5931.36 1.01 6019.13 1.81 6105.62 26 January, 200f - f6:00 Page 2 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPJ-20A MWD Your Ref: AP1 500292283201 Surveyed: 26 December, 2000 Milne Point Unit Measured Depth (ft) Incl. Azim. 8107.90 79.710 302.340 8203.54 78.500 302.380 8295.71 77.280 302.150 8388.20 80.460 301.660 8483.55 81.320 302.770 Sub-Sea Depth (ft) 3191.99 3210.07 3229.40 3247.25 3262.35 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Easfings (ft) (ft) (ft) (ft) (ft) 3256.21 3274.29 3293.62 3311.47 3326.57 8579.06 80.610 301.480 3277.35 3341.57 8671.58 84.330 302.630 3289.47 3353.69 8765.08 84.490 303.180 3298.58 3362.80 8859.66 84.070 303.220 3308.01 3372.23 8950.57 82.070 303.800 3318.98 3383.20 9043.28 77.160 305.950 3335.69 3399.91 9135.95 80.020 305.820 3354.02 3418.24 9226.66 82.150 305.730 3368.07 3432.29 9315.79 82.070 306.010 3380.31 3444.53 9411.45 79.570 306.290 3395.57 3459.79 9500.99 80.060 306.530 3411.40 3475.62 9594.08 81.740 302.610 3426.13 3490.35 9687.01 82.210 300.360 3439.10 3503.32 9779.43 82.110 300.400 3451.71 3515.93 9871.67 81.890 300.180 3464.55 3528.77 9963.67 82.170 299.930 3477.30 3541.52 10054.90 82.240 300.980 3489.68 3553.90 10144.32 82.180 301.500 3501.80 3566.02 10237.29 82.070 300.910 3514.54 3578.76 10325.68 81.790 301.000 3526.94 3591.16 10419.80 81.360 300.710 3540.73 10512.92 78.300 299.780 3557.18 10599.92 72.150 297.240 3579.36 10693.05 66.410 295.350 3612.29 10785.95 58.800 291.200 3655.02 377.16 N 6249.63W 6014938.82 N 545781.10 E 427.43 N 6328.96W 6014988.53 N 545701.42 E 475.54 N 6405.16W 6015036.10 N 545624.89 E 523.49 N 6482.19VV 6015083.52 N 545547.52 E 573.68 N 6561.84W 6015133.15 N 545467.52 E 623.84 N 6641.72W 6015182.75 N 545387.29 E 672.51 N 6719.44W 6015230.88 N 545309.24 E 723.06 N 6797.57W 6015280.89 N 545230.76 E 774.59 N 6876.32W 6015331.86 N 545151.65 E 824.41 N 6951.56W 6015381.16 N 545076.06 E 876.53 N 7026.35W 6015432.75 N 545000.91 E 929.77 N 7099.94W 6015485.47 N 544926.95 E 982.15 N 7172.64W 6015537.35 N 544853.88 E 1033.88 N 7244.19W 6015588.58 N 544781.98 E 1089.58 N 7320.43W 6015643.75 N 544705.35 E 1141.89 N 7391.36W 6015695.56 N 544634.06 E 1194.03 N 7467.03W 6015747.17 N 544558.02 E 1242.09 N 7545.50W 6015794.67 N 544479.22 E 1288.39 N 7624.49W 6015840.42 N 544399.91 E 1334.46 N 7703.36W 6015885.94 N 544320.72 E 1380.09 N 7782.22W 6015931.02 N 544241.54 E 1425.91 N 7860.13W 6015976.29 N 544163.31 E 1471.85 N 7935.88W 6016021.71N 544087.24 E 1519.57 N 8014.65W 6016068.87 N 544008.14 E 1564.58 N 8089.70W 6016113.36 N 543932.78 E 3604.95 1612.33 N 8169.63W 6016160.55 N 543852.52 E 3621.40 1658.50 N 8248.80W 6016206.16 N 543773.03 E 3643.58 1698.65 N 8322.66W 6016245.80 N 543698.89 E 3676.51 1737.24 N 8400.71W 6016283.85 N 543620.58 E 3719.24 1769.89 N 8476.36W 6016315.97 N 543544.70 E Dogleg Rate (°/100ft) 0.56 1.27 1.35 3.48 1.46 1.53 4.21 0.61 0.45 2.29 5.77 3.09 2.35 0.32 2.63 0.61 4.53 2.45 0.12 0.34 0.41 1.14 0.58 0.64 0.33 0.55 3.43 7.61 6.45 9.10 Alaska Drilling & Wells Milne Point MPJ Vertical Section Comment 6190.5o 6278.58 6363.15 6448.50 6536.88 6625,48 6711.65 6798.62 6886.39 6970.38 7054.41 7137.50 7219.55 73OO.32 7386.52 7466.81 7551.71 7638.48 7725.40 7812.16 7898.81 7984.58 8068.26 8155.25 8238.05 8326.19 8413.26 8493.89 8578.27 8659.07 26 January, 200t - f6:00 Page 3 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPJ-20A MWD Your Ref: AP150029228320f Surveyed: 26 December, 2000 Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 10876.30 50.010 290.040 3707.56 3771.78 1795.78 N 8545.03W 10968.36 43.790 286.620 3770.44 3834.66 1817.00 N 8608.76W 11059.17 43.930 286.130 3835.92 3900.14 1834.74N 8669.13W 11113.82 43.840 285.850 3875.31 3939.53 1845.17 N 8705.55W 11176.00 43.840 285.850 3920.16 3984.38 1856.94N 8746.98W 6016341.37 N 543475.85 E 6016362.15 N 543411.97 E 6016379.47 N 543351.48 E 6016389.65 N 543314.99 E 6016401.12 N 543273.48 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.398° (16-Dec-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 282.060° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11176.00ft., The Bottom Hole Displacement is 8941.92ft., in the Direction of 281.986° (True). Dogleg Rate (o/loort) 9.78 7.28 0.40 0.39 0.00 Alaska Drilling & Wells Milne Point MPJ Vertical Section Comment 8731.64 8798.40 8861.14 8898.93 8941.91 PROJECTED SURVEY 26 January, 200f - f6:00 Page 4 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPJ-20A MWD Your Ref: APl 500292283201 Surveyed: 26 December, 2000 Milne Point Unit Alaska Drilling & Wells Milne Point MPJ Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 6175.19 2980.03 164.06 N 4441.18 W 6202.00 2985.11 165.26 N 4467.48 W 11176.00 3984.38 1856.94 N 8746.98 W Comment TIE ON POINT Window Point PROJECTED SURVEY Survey tool program for MPJ-20A MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 11176.00 3984.38 Survey Tool Description MWD Magnetic (MPJ-20) 26 January, 200~ . f6:00 Page 5 of 5 DrillQuest 2.00.06 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI"rN: Sherrie NO. 1057 Company Field: Alaska Oil & Gas Cons Comm Attn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Milne Point (Cased Hole) 3/13/01 Well Job # Lo~l Description Date Color Sepia CD tvIPU J-20A 21105 SCMT 02/17/01 ) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Ancharage, Alaska 99519-6612 Date Delivered: RECEIVED 1 62O01 AlnkaOii&GasCons.~ Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AITN: Sherrie Received ALASI~A OIL AND GAS CONSERVATION CO~I~llSSION Steve Schultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK '99519-6612 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3 ! 92 PHONE: (907) 279-1433 FAX: (907) 276-7542 Milne Point Unit MPJ-20A BP Exploration (Alaska) Inc. Permit No: 200-185 Sur Loc: 2207'NSL, 3288'WEL, Sec. 28, T13N, R10E, UM Btmhole Loc. 4055'NSL, 1402'WEL, Sec. 30, T13N, RIOE, UM Dear Mr. Schultz: 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 a!i...0~¢r ..... required permitting determinations are made. ' .... .. 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. Sincerely, J. M. Heusser Commissioner · BY ORDER OF THE COMMISSION DATED this ~--'"' day of November, 2000 dlf/Enclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of Enviromnenlal Conservation w/o encl. STATE OF ALASKA , ALASK/[ ,L AND GAS CONSERVATION COMI[ .,SION PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la' Type of work B Drill [] Redrill lb. Type of well Re-Entry [] Deepen 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. Plan KBE= 64.22' Milne Point Unit / Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 =o~z.~/~L 025517 4. Location of well at surface 7. Unit or Pr6perty Name 11. Type Bond (See 20 AAC 25.025) 2207' NSL, 3288' WEL, SEC. 28, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 4026' NSL, 1245' WEL, SEC. 30, T13N, R10E, UM MPJ-20A Number 2S100302630-277 At total depth 9. Approximate spud date 4055' NSL, 1402' WEL, SEC. 30, T13N, R10E, UM 11/27/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025515, 1223' MDI 376' from MPJ-23 at 8223' 2560 11135' MD / 3985' TVD 16. To be completed for deviated wells ' '- 17. AnticiPated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 6200' MD Maximum Hole Angle 81.7 ° Maximum surface 1265 psig, At total depth (TVD) 3800' / 1700 psig 18. Casing Program Specifications Setting Depth Size To 3 Bottom Quantity of Cement Hole Casin,q Wei,qht Grade Couplin,q Len,qth MD TVD MD TVD (include sta,qe data) 6-1/8" 4-1/2" 12.6# L-80 IBT 4907' 6050' 2995' 11135' 3985' _~52 sx Class 'G' [:[~: ~fl n~, ~,n.~ l~r,[, . ,,, .,, 19. To be completed for Redrill, Re-entry, and Deepen Operations. - ............... "~'~ L,~.... ~ Present well condition summary Total depth: measured 8085 feet Plugs (measured) ':""-'~' '~ ] ~ 2000 true vertical 4196 feet Effective depth: measured 7982 feet Junk (measured) AidS}Ia 0ii &~-'..~"~ ....... Cons, u0mm~sston true vertical 4109 feet Anchor~e Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface Intermediate Production 8036' 7" 1476 sx PF 'E' 132 sx Class 'G' 8066' 4.180' Liner Perforation depth: measured 7616' - 7651', 7778' - 7798', 7850' - 7870' true vertical 3800' - 3829', 3936' - 3953', 3997' - 4014' 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 25.050 Requirements Contact Engineer Name/Number: Pat Archey, 564-5803 Prepared By Name/Number: Sondra Stewman, 564-4750 21.1 hereby certify that the foreg,,./_~;~s true an~o~ct/~z.,,...7 ~/~, the best of my knowledge ~ / Signed Steve Shultz ~/. ~7~., ~ ~//~~'~'13tle Senior Drilling Engineer Date J~/~/,~'/'"'~ ~.~' '"~-:~ (~ !;~'.,p,'Ii ~'~';~' ........ ,¥,r ~; ;: '~ ........ 'r!" Yr~'~i~!:l!~'" ..... ~' ..... ii" ~:ii '~'~!~,~ ......... ..... ' l~i'l~i { "~;';~t~'. ~'''5'~' ~" "" 'q:~'~ ...... .~ '''[~;)u~. ,~',, ~..~ '~ ~'~. ~ ~. '"~ ~ ~ ~;' ........ ,~,~P K .~:'~!!~$' ''~E'~'t~,~t~i~!? 'r!~ ~,'> ..... .., ~;!=4, ~ ~~'~', ~~ ~,~. ~m'~!~Y .... ~!";',~., r; .... ~:u',,' ~ ~ ......... r# ~. ,,. ,, ~ 'm:~, ~!~',~ ,~. ~;i~!~ ,~ ~l !)~ '"I" ~'v~;~t]";" ~'''~ ', ! !¢~'iii''~'''~'rJ~ ~c'i~ '~'~'I 3 .l, r~, [.~. I~, ~1~1. ~ '~l~'fi ......... '.~.~ ~'~ ii'~M r~i~h' .~',~ ;~i~.'~,~,,i~ '!~ ,a" '~' {;' ~ ~ I.~ ;~ 'R' "~'~ ~Iz~=!~:": t ~I~ ~o~c.t ~,n ........ '~ ;ii ~' ~ ~i~'=i ~ ' '~"~'"'' ...... ..... '"'"'*~ ~e I 'q~ ~=~ ~51,*~q'" ...... I'i= ..... ~ IAPl Number /~7~°~;~ ~at~e~)Isee c°ver letter Permit Nu '"/~:)~-- 50- 029-22832-01 ~ for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log Required [] Yes i~ No Hydrogen Sulfide Measures [] Yes [] No Directional Survey Required [] Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K 1~3.5K psi Other: [~-'~\'~ C.a:.w'~(X~u~,,..~c.~.'~,-~.[ ~-~ by order of Approved By Commissioner the commission Date //'"~:~i~ Form 10-401 Rev. 12-01-85 ORIGINAL Submit In Triplicate Schrader Bluff Tract 14 2000 Pro~lram MPJ-20A Well Plan MPJ-20A Sidetrack Procedure --Conversion to Injector-- Nabors 22E AFE Number: Est. Days: 337204 14 (mean, no trainwreck) Est. Amount: $ 1,700M (mean, no trainwreck) Estimated Spud: December 1, 2000 Prepared By: Pat Archey FOUR OBJECTIVES FOR WELL: 1. NO ACCIDENTS 2. NO SPILLS OR ENVIRONMENTAL VIOLATIONS 3. NO POLICY OR REGULATORY VIOLATIONS 4. MEET OR EXCEED COST AND QUALITY OBJECTIVES No portion of this work is so urgent that the time cannot be taken to do it without injuring yourself or others Approved By: Sr. Drilling Engineer Date Distribution: Mike Miller - MB 8-1 Steve Shultz - MB 4-4 Larry Wolfson - MB 8-1 Mik Triolo - MB 4-4 Dave Jenkins - MB 4-4 Daniel Bourne - MB 4-4 BPX Drilling Stores - N/S J-1 Rig Nabors 22E Sperry Sun - Mail Slot Baker- Mail Slot Baroid - Mail Slot Dowell- Mail Slot Nabors - Mail Slot MPU - Well Ops Coordinator Ops Drilling Engineer Date 19 Copies, 1 original I Copy I Copy 1 Copy I Copy I Copy I Copy I Copy 8 Copies 1 Copy I Copy I Copy 1 Copy 1 Copy Original for well file Senior Drilling Engineer Date Project Team Leader Date Drilling Superintendent Date BP Alaska Drilling and Wells Contact List (a complete project phone list can be found in the Appendix) Contacts Drilling Superintendent Senior Drilling. Engineer Senior Drilling Engineer Project Drilling Engineer Name Work Cell Home Mike Miller 564-5066 240-8066 348-0595 Steve Shultz 564-5491 240-8071 746-2507 Pat Archey 564-5803 240-8059 696-7570 Larry Wolfson 564-5969 240-8077 345-6624 Version #1, 10104/2000 Schrader Bluff Tract 14 2000 Program MPJ-20A Well Plan I · Well Plan Summary I Well Name: I MPJ-20 I Type of Well (producer or injector): I Injector Surface Location: 2207' NSL, 3288' WEL, Sec. 28, T13N, R10E X = 552,033.21 Y = 6,014,605.30 Top of CA 1824.24 N, 8520.68 W from well centerline 6,016,370 N, 543,500 E ASP4 TD 1853.34 N, 8678.48 W from well centerline 6,016,398 N, 543,342 E ASP4 I AFE Number: 1337204 I I Rig= I Nabors 22E Estimated Start Date: I Dec 1,2000 I I Operating days to complete: I 14 I MD 1~0,956 I ]TVDrkb: 13,~84 I IEEE= 164.22 Well Design (conventional, slim hole, etc.): I Sidetrack existing well & convert to injector. Objective: I Set a whipstock and sidetrack holding angle to TD at the base of the OB. ICompletion: I Injector will be a single packer 2-7/8" completion with the packer set above the top I of the liner. RECEIVED NOV 1,~ 2000 AJas,~a Oi~ & Gas Cons. Commission Anchorage Current Well Information Schrader Bluff Tract 14 2000 Program MPJ-20A Well Plan Well Name: APl Number: Well Type: Current Status: BHP: BHT: MPJ-20 50-029-22832 Development - Schrader Bluff Injector Shut in since 8/98 1,700 psi Schader Bluff 'OB' sand. Normal pressure gradient (8.7 ppg) 80°F@ 4,020' ss Estimated Mechanical Condition MPJ-20: Nabors 22E: Conductor: Tubing Heat String Bands & guards Tree Tubing Head Tubing Head Adpt. Tubing Hanger BPV Profile Open perfs Tubing Fluids Annulus Fluids Shut in pressures 7" by 2 7/8" MIT 2 7/8" Tbg hanger tst Hanger Cellar Box MSL = 35.10' KB / MSL = 64.22' 20", 921b/ft, H-40 Welded set at 115' RKB 2-7/8" 6.5#, L-80, EUE 8rd Raychem heat trace to 2300' Retrieved by 4ES (pulled by 4ES) (pulled by 4ES) CIW 2 9/16"- 5M FMC 11" 5M Gen 6 FMC 11" 5M X 2 9/16" 5M FMC 2 7/8" 8rd pin BTM x 2 7/8 8rd box TOP ClW H profile 3 sets from 7616' to 7878' MD - Squeezed off Produced gas & oil Produced gas and oil See Handover Sheet from Production Can't do pre-rig - No packer in well - 4ES to PT was removed and reinstalled by 4ES !,i."."JV 15 2000 Anchorage, Schrader Bluff Tract 14 2000 Program MPJ-20A Well Plan Drillin.q Hazards and Contin.qencies Well Control MANDATORY WELL CONTROL DRILLS: Drill Type Frequency Comments D1 Tripping (1) per week, per crew Conducted only inside casing. D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diverter N/A D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, Prior to milling the window. per crew Lost Circulation · Lost circulation has not been encountered while drilling this interval on previous J-Pad wells. · Possible small faults could be encountered throught the Ugnu and the Schrader Bluff. · Clean hole ECD in the 6-1/8" horizontal holes is estimated to be 11.7 lb/gal. Maintain minimum ECD thru use of proper hole cleaning procedures, PWD monitoring, and control drilling. · Follow the LOST CIRCULATION DECISION TREE RP if fluid losses occur while drilling. Unexpected Hiqh Pressures It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. This well is in an undrained fault block with no offtake or injection support. Stuck Pipe · The J-20 directional plan has a +/- 5,000' interval of high angle (81degrees) Ugnu and Schrader Bluff formation. All these hole intervals have massive permeable sand intervals. Good drilling practices to avoid differential sticking are required in all hole sections. · Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! · There is a risk of differentially sticking the 4-1/2" liner. The 9.1 lb/gal mud will be 0.4 lb/gal overbalanced to the 8.7 lb/gal CA/OB sand reservoir pressure (80 psi differential pressure @ 3,800' TVD). The liner should be kept moving as much as possible while running in the open hole. Breathing No breathing problems are expected drilling the Schrader Bluff formations. Hydrocarbons Hydrocarbons will be encountered in the Schrader Bluff intervals. Hydrogen Sulfide · MPJ Pad is not designated as an H2S Pad. · If encountered, AOGCC must be notified within 24 hours 4 Schrader Bluff Tract 14 2000 Program MPJ-20A Well Plan Drillin Program Overview Surface and Anti-Collision Issues Surface Shut-in Wells: MPJ-19 may need to be shut-in for the rig move on and off MPJ-20. Review the Pre- Rig Move Checklist to determine. Close Approach Wells: J-223 is the only close approach well and will be risked based. Well Name I Current Status MP J-23 ] Producing Production Priority High IPrecautions Well is on line. Well Control Expected BHP 1,700 psi, 3,800' TVD (estimated) Max Exp Surface Pressure 1,265 psi (0.115 psi/ft gas gradient) Mud Proqram BOPE Rating Planned BOPE Test Pres. 5,000 psi WP 2,000/250 psi Rams and Valves (entire stack & valves) 2,000/250 psi Annular 6-118" Production Hole Mud Properties: LSND Fluid I Above 10,300 I Density (ppg) Funnel vis YP pH APl Filtrate 8.7 - 9.2 40 - 60 17 - 35 8.0 - 8.5 6 - 12 Below 10,300 9.2 - 9.4 40 - 55 17 - 25 8.0 - 8.5 <6 According to recent modeling, we will be expecting high torque values at TD of this hole section in the range of 8 - 10,000 ft-lbs. The use of Lubtex for the open hole and EP mud lube for the casing may be required to help reduce torque. NOTE: See attached Baroid mud recommendation LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or ARCO KRU 1R. Formation Markers Formation Tops MD TVDss Pore Psi EMW (ppg) Base Permafrost 1884 1800 Top Ugnu 7319 3088 1390 8.66 Top Ugnu M 8899 3318 1493 8.66 NA 10552 3559 1602 8.66 NB 10652 3591 1616 8.66 NC 10717 3621 1629 8.66 NE 10757 3644 1640 8.66 NF 10836 3694 1662 8.66 Top OA 10888 3732 1679 8.66 Base OA 10930 3764 1694 8.66 Top OB 10974 3798 1709 8.66 Base OB 11003 3820 1719 8.66 Schrader Bluff Tract 14 2000 Program MPJ-20A Well Plan Casina/Tubinq Proqram Hole Size Liner OD Wt/R Grade Conn Length Top Btm MDrrVD MDrrVD 6-1/8" 4-1/2" 12.6# L-80 IBT 4,907' 6,050/2,995' 11,135/3,985 Cement Calculations ICasin~l Size I 4-1/2", 12.6#, L-80, IBT Basisl 50% excess over gauge hole I ITotal Cement Volume: CW-lO0 50 bbl at 8.32 ppg Spacer 50 bbls of Dowell Mudpush Spacer Weighted to 10.0 ppg Cmt Temp 252 sx 128 bbl 11.0 lb/gal LiteCRETE BHST -80° F from SOR, BHCT 80° F estimated by Dowell Survey and Loa~in~ Pro_~ram 6-1/8" Hole Sections: I MWD / GRIRes I PWD Cased Hole:I CBL Post Ri~l Bit Recommendations Alaska C~i & G~s Cons. ~mr~ission BHA Hole Size Depths (MD) Bit Type Nozzle I Flow Jets Number and Section Rate 1 6-1/8" 6,200' - TD Security FM2643 PDC 250 gpm 3 X 16's ~ Motors and Required Do.qleas Drilling Motor Size and Motor Required Flow Rate RPM's Required Doglegs BHA No. 1 4 3~,, Sperrydrill 4/5, 6.3 stg FTC 250 gpm 80 Build out of window at 10- Performance, 1.5° adj w/5.9" sleeve 12°/100 to horizontal. Materials Needed Production Liner: 5000' I each 1 each 110 each 50 each 1 assembly 4-1/2" 12.6#, L-80, IBT liner 4 Y2" IBT Halliburton Float Shoe and Float Collar 4 Y2" IBT Baker Landing Collar 4-5/8" x 5 3~" rigid straight blade centralizer 4-5/8" Stop Rings FMC 11" 5m x 2-7/8Wellhead/Tree (re-used) L-80 Completion: 6000' (3) 2-7/8"Landing nipples 7" x 2-7/8" Packer 6 2-7/8", 6.5#, L-80 EUE tubing (re-use) X and XN nipples Baker S3 2 -7/8" I lot Schrader Bluff Tract 14 2000 Program MPJ-20A Well Plan CIW tree & FMC wellhead equip - (reuse) 2-7/8" tubing pup joints Schrader Bluff Tract 14 2000 Program MPJ-20A Well Plan MPJ-20A Operations Summary Pre-Riq Operations 1. MIRU Nabors 4ES, ND CIW 2-9/16" 5m tree. 2. NU 5M BOPE. Test BOP to 2000/250 psi 3. Pull 2-7/8 .... tubing and ESP per decompletion procedure. 4. TIH with EZSV on DP. P & A perforations. 5. Make 6-1/8" mill run trip to 6,200' MD 6. Freeze protect well. RDMO. General Procedure 1. MIRU Nabors 22E, ND CIW 2-9/16" 5m tree. 2. NU 13-5/8" 5m BOP. Test BOP to 2000/250 psi 3. Circulate freeze protect out of well with completion fluid. 4. Pull hanger and tubing 5. Make 6-1/8" mill run trip to 6,200' MD. Verify depth of EZSV. 6. Circ well to LSND mud. POH 7. Make up Baker Window Master milling assembly with whipstock and MWD. 8. RIH and set packer to start milling at 6,200' MD. Mill window. POH. 9. MU BHA with 6-1/8" PDC bit, 4-3/4" MWD/LWD (GR-Res)/PWD, 3-1/2" drill pipe 10. Drill 20' and perform FIT to 11.0 ppg EMW. 11. Drill to TD per directional plan. 12. Wiper trip or reamer trip with Hole Opener to TD. 13. Run 4-1/2" liner w/liner top packer 14. Cement liner in place. Set liner top packer. 15. Make casing scraper run on 3-1/2" DP to packer depth w/2-7/8" tubing stinger and motor to TD. Test casing & LT pkr to 3500 psi f/30 min. 16. POH & L/D 3-1/2" drill pipe, stand back tubing. 17. Run 2-7/8" tubing and packer completion. Space out packer with the tailpipe stung into liner lap 18. Set BPV. ND BOPE. NU ClW tree 19. Pull BPV. Freeze protect tubing and annulus. 20. Drop ball and set packer 21. Set BPV. 22. RDMO Post rig work 1. 2. RU CTE. Pull RHC plug and run CBL from PBTD to top liner lap Perforate OA and OB with CTE. J-20A Proposed Compl. 11" FMC - 5M Gen 6 ~11 20" 91.1 PPF, H-40 2-7/8" 6.5# L-80 HUE tubing BAKER 7" X 4-112" Liner Hanger I +/-6,050' I Window Milled from Whipstock Top of Window at +/- 6,200' MD +/- 3,000' TVD Cement retainer set at +/-' TBD. SPF In te n/al (TVD) Sz 4.5 12 N 7616'-7651' 4.5 4 OA 7778'-7798' 3936-3954 4.5 4 OB 7850'-7870' 3999-4015 7"", 26 #/ft, L80, BTCM I 8,066' L 2-7/8" X Nipple (2.313") @ 2000' MD GL Elevation = 35.1 Nabors 22E RKB = 64.22' 2-7/8" X Nipple (2.313") 1 jt. above packer BAKER 7" X 2-718" Production Packer 2-7/8" XN (2.205 no-go) Tubing Tail @ +/- 6.050' 4-1/2" 12.6~ L-80 IBT I11,a3s,I Liner MILNE PT. UNIT WELL: J-20A Date Revised by Comments 10/11/00 PJA Proposed Completion O__~ II. I. I N I~ 5EFIVICE!B Shared Services Drilling MPJ-20A Wp-06 I DrillQuest' Proposal Data for MPJ-20A Wp6 Vertical Origin: Well Reference Horizontal Origin: Well Reference Measurement Units: ft North Reference: True North Dogleg severity: Degrees per 100ft Vertical Section Azimuth: 282.055° Vertical Section Descriptiotg/ell Reference Vertical Section Origin: 0.00 N,0.00 E Measured Incl. Azim. Vertical Nerthings Eastings Vertical Dogleg Depth Depth Section Rate 6200.00 78.777 272.604 2984.72 165.18 N 4465.52 W 4401.55 6260.00 81.819 267.357 2994.84 165.15 N 4524.63 W 4459.35 10.000 6332.86 81.500 260.000 3005.42 157.22 N 4596.23 W 4527.71 10.000 7151.37 81.500 260.000 3126.40 16.65 N 5393.46 W 5278.00 0.000 7503.82 81.682 302.776 3180.42 83.86 N 5726.99 W 5618.22 12.000 10509.64 81.682 302.776 3615.26 1693.94 N 8227.70 W 8400.04 0.000 10887.63 40.331 280.449 3796.22 1824.24 N 8520.68 W 8713.77 12.000 I 1135.56 40.331 280.449 3985.22 1853.34 N 8678.48 W 8874.17 0.000 Scale: linch = 1500ft Eastings -7500 -6000 -4500 ~[~.~:~, lEnd Dir: 10887.63ft MD, 3796.22ft TVD · .~a.J .-./Begin Dir @ 12.000°/100ft: 10509.64ft MD, 3615.26ft TVD 1500 Single Well Target Data for MPJ-20A Measurement Units: ft Coordinate Target Point TVD TVDss Northings Eastings Northings Eaatings Target Name Type Shape MPJ-20A BHL Enlxy Point 3985.22 3921.00 1853.34 N 8678.48 W 6016398.00 N 543342.00 E Point MPJ-20A T1 Entry Poim 3796.22 3732.00 1824.24 N 8520.68 W 6016370.00 N 543500.00 E Circle ~,_ 3000 - I! /ST Exit @ 10.000°/100ft, 300.000° TF: 6200.00ft MD 2984.72ft TVD ~ //Continu.e. Dir @ 10.000°/10Oft: 6260.00ft MD, 2994.[J4ft TVD ..~ End Dir 32 8 0 ,~ _VD ~ln , 1~?~0~~ 7 3 126 4oft TVD ....... -,~,~,~~ .................................................... ,1~.-~].,;~.-~.,7~.,[)- .......... ~ ............ J..~ ..................... ~Begin. Dir, .~.~.x!~.~. ~/~l.0.~t.; 10509.64ff MD 3615.26ft TVD -~ ~ ,~ / .~.,,..~../ .... ~.~.~_.~_'-rvl) ' ! \ --""------.7~,,, ,;:/End Dir: 10887.63ft MD 3~.~79~.., _2.~D , , · ti, .... ~ ~ ~:L~Sc~R. ADER NB- 3655.22' '0~ ...... 4'i12' liner 70~: ..~ -': -' ':; \\x.N~~' $CH~.'.Ai)ER A~. . . ~ ...... \~'][.3J'.:~./',.'t.~£ 0:. - .) ...... z_ . ~'D ngas.~,-rvo ' -'.' ............ ~',~o~. --'?~2~'~;D SB:i~/fl/£YE OB- 5~:b¥.22' 4500 6000 7500 9000 10500 Scale: linch = 1500ft Section Azimuth: 282.055° (True North) Vertical Section Current Well Properties Well: MPJ-20A Horizontal Coordinates: Ref. Global Coordinates: 6014605.30 N, 552033.21 E Ref. Structure Reference: 1185.86 N, 606.40 E Ref. Geographical Coordinates: 70° 27' 02.3112' N, 149° 34' 31.6949" W RKB Elevation: 64.22ft above Mean Sea Level 64.22ft above Structure Reference North Reference: True North Units: Feet North Slope Alaska Alaska State Plane 4 Milne Point.MPJ PROPOSAL 7 Surface Coordinates: 6014605.30 N~.;..5520~.21 E (70 27 02.3112" N, Kelly Bushtng::,,:,~2fl above Mea Sea Level 149° 34' 31.6949" W) proposal Reft pro9677 Sperry-Sun Drilling Services % ~'~. '~/~..~. Proposal Report for MPJ-20A Wp6 Nodh Slope Alas~ Measured "~Sub-Sea Vedical Local Coordinates Global Coordinates ~pth Inol. ~im. ~pth ~pth ~odhin~ ~tin~ ~oflhin~ ~tin~ 6260.00 81.819 267.~7 2930.62 2994.84 165.15 N ~24.63 W 60 · 547507.53 E 3~5.42 4596.23 W 3015.~ 4661.63 ~ ," :': ~, ,,,,,60147:~ 8:44 N :[~,~':,,,,~,,, 6300.00 81.627 263.319 2936.38 161.93 N 547468.11 E 6332.86 81.500 260.000 2941.20 157.22 N 547435.99 E 6400.00 81.500 260.000 2951.12 145.69 N 547370.68 E 6500.00 81.500 260.000 2965.91 3030.13 128.51 N 547273.40 E 6600.00 81.500 260.000 2980.69 3044.91 111.34 N 547176.12 E 6700.00 81.500 260.000 2995.47 3059.69 94.17 N 547078.85 E 6800.00 81.500 260.000 3010.25 3074.47 76.99 N 6014647.02 N 546981.57 E 6900.00 81.500 260.000 3025.03 3089.25 59.82 W 6014629.17 N 546884.29 E 7000.00 81.500 . 260.000 3039.81 3104.03 42.1 W 6014611.31 N 546787.02 E 7100.00 81.500 260.000 3054.59 3118.81 W 6014593.46 N 546689.74 E 7151.37 81.500 260.000 3062.18 3126.40 16.65 N W 6014684.29 N 546639.77 E 7200.00 81.235 265.896 3069.49 3133.71 10.75 N 5441.15 W 6014678.05 N 546592.12 E 7300.00 80.980 278.040 3065.01 3149.23 14.13 N 5539.69 W 6014580.75 N 546493.55 E 7319.10 80.976 280.360 3088.00 3152.22 17.14 N 5558.31 W 6014683.63 N 546474.92 E 7400.00 81.122 290.188 3100.62 3164.84 38.17 N 5635.31 W 6014604.12 N 546397.77 E 7500.00 81.654 302.313 3115.65 3179.87 81.82 N 5723.81 W 6014647.16 N 546308.97 E 7503.82 81.682 302.776 3116.20 3180.42 83.86 N 5726.99 W 6014649.17 N 546305.77 E 7600.00 81.682 302.776 3130.11 3194.33 135.38 N 5807.01 W 6014700.13 N 546225.40 E 7700.00 81.682 302.776 3144.58 3208.80 188.94 N 5890.20 W 6014753.11 N 546141.83 E 7800.00 81.682 302.776 3159.05 3223.27 242.51 N 5973.40 W 6014606.09 N 546058.26 E 7900.00 81.682 302.776 3173.51 3237.73 296.07 N 6056.60 W 6014659.08 N 545974.70 E 8000.00 81.682 302.776 3187.98 3252.20 349.64 N 6139.79 W 6014912.06 N 545891.13 E 8100.00 81.682 302.776 3202.45 3266.67 403.20 N 6222.99 W 6014965.04 N 545807.56 E Dogleg Rate (°/lOOft) 10.000 10.000 10.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 12.000 12.000 12.000 12.000 12.000 12.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 4401.55 4459.35 4497.25 4527.71 4589.26 4680.92 4772.59 4864.25 4955.92 5047.58 5139.25 5230.91 5278.00 5323.41 5420.49 5439.32 5519.01 5614.68 5618.22 5707.23 5799.78 5892.32 5984.87 6077.42 6169.97 Comment ST Exit @ 10.000°/100ft. 300.000° TF: 6200.00ft MD 2984.72ft TVD ' Continue Dir @ 10.000°/100ft: 6260.00ft MD, 2994.84ft TVD End Dir: 6332.86ft MD, 3005.42ft TVD Be~_ in Dir @ 12.000°/100ft: 7151.37ft MD, 3126.40ft TVD TUGNU End Dir: 7503.82ft MD, 3180.42ft TVD Continued... 7 November, 2000-14:54 - 2- DrillQuest 1.05.05a Sperry-Sun Drilling Services '~~~~.~~.C~.~~Proposal Report for MPJ-20A Wp6 North Slope Ala.~ a Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (fi) (ft) 8200.00 81.682 302.776 3216.91 3281.13 456.77 N 6306.18 W 601,5018.~ 545723.99 I= 8300.00 81.682 302.776 3231.38 3295.60 510.34 N 6389.38 W 601~ 545640.43 E 8400.00 81.682 302.776 3245.85 3310.07 563.90 N 6472.57 W 601 545556.86 E 8500.00 81.682 302.776 3260.31 3324.53 617.47 N 6555.77 W 545473.29 E 8600.00 81.682 302.776 3274.78 3339.00 671.03 N 6638.96 W N 545389.72 E 8700.00 81.682 302.776 3289.25 3353.47 724.60 N 6722.16 -~.94 N 545306.16 E 8800.00 81.682 302.776 3303.71 3367.93 778.16 N 6805.35 N 545222.59 E 3318.00 '3382.22 831.07 N 6887.52 5~8~.26 N 545140.05 E 8898.76 81.682 302.776 8900.00 81.682 302.776 3318.18 3382.40 831.73 N '~'6015388.91 N 545139.02 E 9000.00 81.682 302.776 3332.65 3396.87 885.29 N 6015441.89 N 545055.45 E 9100.00 81.682 302.776 3347.11 3411.33 938.86 N 6015494.88 N 544971.89 E 9200.00 81.682 302.776 3361.58 3425.80 992.43 3 W 6015547.86 N 544888.32 E 9300.00 81.682 302.776 3376.04 3440.26 1045.,~ W 6015600.84 N 544804.75 E 9400.00 81.682 302.776 3390.51 3454.73 W 6015653.83 N 544721.19 E 9500.00 81.682 302.776 3404.98 3469.20 1153.1-~ 6015706.81 N 544637.62 E 9600.00 81.682 302.776 3419.44 3483.66 1206.69 N 7470.92 W 6015759.79 N 544554.05 E 9700.00 81.682 302.776 3433.91 3498.13 1260.25 N 7554.11 W 6015612.78 N 544470.45 E 9800.00 81.682 302.776 3448.38 3512.60 1313.82 N 7637.31 W 6015865.76 N 544386.92 E 9900.00 81.682 302.776 3462.84 3527.06 1367.38 N 7720.50 W 6015918.74 N 544303.35 E 10000.00 81.682 302.776 3477.31 3541.53 1420.95 N 7803.70 W 6015971.73 N 544219.78 E 10100.00 81.682 302.776 3491.78 3556.00 1474.51 N 7886.89 W 6016024.71 N 544136.21 E 10200.00 81.682 302.776 3506.24 3570.46 1528.08 N 7970.09 W 6016077.69 N 544052.65 E 10300.00 81.682 302.776 3520.71 3584.93 1581.65 N 8053.28 W 6016130.68 N 543969.08 E 10400.00 81.682 302.776 3535.18 3599.40 1635.21 N 8136.48 W 6016183.66 N 543885.51 E 10500.00 81.682 302.776 3549.64 3613.86 1688.78 N 8219.67 W 6016236.64 N 543801.95 E 10509.64 81.682 302.776 3551.04 3615.26 1693.94 N 8227.70 W 6016241.75 N 543793.89 E 10552.44 76.867 300.955 3559.00 3623.22 1716.14 N 8263.39 W 6016263.70 N 543758.03 E 10600.00 71.533 298.846 3571.95 3636.17 1738.95 N 8303.04 W 6016286.23 N 543718.23 E 10652.27 65.699 296.369 3591.00 3655.22 1761.51 N 8346.14 W 6016308.50 N 543674.97 E 10700.00 60.411 293.902 3612.62 3676.84 1779.60 N 8384.63 W 6016326.31 N 543636.36 E Dogleg Rate (°/lOOft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 12.000 12.000 12.000 12.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 6262.51 6355.06 6447.61 6540.16 6632.71 6725.25 6817.80 6909.21 6910.35 7002.90 7095.44 7187.99 7280.54 7373.09 7465.63 7558.18 7650.73 7743.28 7835.83 7928.37 8020.92 8113.47 8206.02 8298.56 8391.11 8400.04 8439.58 8483.12 8529.98 8571.40 Comment TUGNU M Be;in Dir @ 12.000°/100ft: 10509.64ft MD, 3615.26ft TVD SCHRADER NA SCHRADER NB Continued... 7 November, 2000 - 14:54 - 3 - DrillQuest 1.05.05a Sperry-Sun Dnlhng Serwces ~~ ~-~.~ ~Proposal Report for MPJ-20A Wp6 North Slope Alaska ~ Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 10716.51 58.592 292,989 3621.00 3685.22 1785.26 N 8397.68 W 10757.99 54.054 290.528 3644.00 3708.22 1798.07 N 8429.73 W 10800.00 49.517 287.732 3669.98 3734.20 1808.90 N 8460.88 W 10835.64 45.727 285.048 3694.00 3758.22 1816.35 N 8466.13 W 10887.63 40.331 280,449 3732.00 3796.22 1824.24 N 8520.68 W 10900.00 40.331 280.449 3741.43 3805.65 1825.69 N 10929.60 40.331 280.449 3764.00 3828.22 1829.17 N 10956.88 40.331 280.449 3784.79 3849.01 1832.37 N 10974.21 40.331 280.449 3798.00 3862.22 1834.40N 11000.00 40.331 280.449 3817.66 3881.88 1837.43 11003.07 40.331 280.449 3820.00 3884.22 W 11100.00 40.331 280.449 3893.89 3958.11 1849.17 W 11135.56 40.331 280.449 3921.00 3985.22 1853.34 W Global Coordinates Northings Eastings (ft) (ft) 6016331..~ 543623,27 E 60163~ 543591.14 E 60~.0~ 5~9.~0 E ~62.~;35 N'~ 543534,61 E 0N '~ 543500.00 E N 543492,12 E )16374.74 N 543473,25 E N 543455,87 E 6016379,78 N 543444.83 E 6016382,69 N 543428,39 E 6016383.04 N 543426.43E 6016393.98 N 543364.66E 6016398.00 N 543342.00E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Dogleg Rate (°/lOOft) 12.000 12.000 12.000 12.000 12.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 8585.34 8619.36 8652.09 8678.33 8713.77 8721.78 8740.93 8758.57 8769.78 8786.47 8788.45 8851.17 8874.17 Comment SCHRADER NC SCHRADER NE SCHRADER NF End Dir: 10887.63ft MD, 3796.22ft TVD OA Taraet - MPJ-20A T1,200.00 Radius. TSBC/BASE OA 4 1/2" Liner OB SBA5/BASE OB Total Deoth: 11135.56ft MD, 3985 22ft TVD T_.arg~ .-_MPJ-.20A BHL, ~urrem large; The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 282.055° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11135.56ft., The Bottom Hole Displacement is 8874.17ft., in the Direction of 282.055° (True). Continued... 7 November, 2000 - 14:54 - 4 - DrillQuest 1.05.05a North Sperry-Sun Drilling Services ~_~ ~J '-.~.~ Proposal Report for MPJ-20A Wp6 ~.. ~ ' Slope Ala~a~ ~ Comments Measured Station Coordinates Depth TVD Northings Eastings (fi) (ft) (ft) (ft) 6200.00 2984.72 165.18 N 4465.52 W 6260.00 2994.84 165.15 N 4524.63 W 6332.86 3005.42 157.22 N 4596.23 W 7151.37 3126.40 16.65 N 5393.46 W 7503.82 3180.42 83.86 N 5726.99 W 10509.64 3615.26 1693.94 N 10887.63 3796.22 1824.24 N 11135.56 3985.22 1853.34 N Formation Tops Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) 7319.10 3152.22 3088.00 8898.76 3382.22 3318.00 10552.44 3623.22 3559.00 10652.27 3655.22 3591.00 10716.51 3685.22 3621.00 10757.99 3708.22 3644.00 10835.64 3758.22 3694.00 10887.63 3796.22 3732.00 10929.60 3828.22 3764.00 10974.21 3862.22 3798.00 ST Exit @ 10.000°/10~0~o~, 300'000°"'TE;:"'6200'00ft' MD'~~"'~'- - ~' ~'~ 2994184ft2984'72ft TVD Continue Dir @ 10.000/100ft: 621~u:u~Jf~?iMu, TVD End Dir: 6332.86ft MD, Begin Dir @ TVD End Dir- 7503.82ft MD, 8227.70 W Begin Dir @ 3615.26ft TVD 8520.68 W End Dir: TVD 8678.48 W Total Depth: ~3985.22ft TVD Northings Easting~ation Name (ft) (ft) 17.14 N 5558.31 W TUGNU 831.07 N 6887.52 W TUGNU M 1716.14 N 8263.39 W SCHRADER NA 1761.51 N 8346.14 W SCHRADER NB 1785.26 N 8397.68 W SCHRADER NC 1798.07 N 8429.73 W SCHRADER NE 1816.35 N 8486.13 W SCHRADER NF 1824.24 N 8520.68 W OA 1829.17 N 8547.40 W TSBC/BASE OA 1834.40 N 8575.79 W OB Alaska State Plane 4 Milne Point MPJ Continued... 7 November, 2000 - 14:54 - 5 - DrillQuest 1.05.05a I I 13 5/8" .~O00i~ HYDR!L ANNULAR ................ f .......... ~ ............ 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[! ................. i'~'~ BOP STACK ELEVATION ............................................................. ; ........................ il DI~SlGt4 IS ~BI..E ONLY F AU'II'IORIZI~D IN WErI1NO BY ~ AIASI,C). · ' I I ,',..~ ............ ~ ..... Nclbor8 NQBka DrillimJ Inc. ................... i ................................................ , ........................ , ~ i.~,ii%;i~;. '~i.".i~:,¢;ii::;~.::,::~i;:~:'i~!; ~i!~i!¢i ~:~ii~:~[.~ 1,300 B S'creet ' · ..................... I I ;~:[~ ilj-'i'.: .~i.::'i~;i..~i:i';:'r~)~':i~ :.i',¢;'i.~..[:.!¢.!'.i:!;::.;i:i; ;:':,::~:;..:~:~ Anchorage. Ncmko 9950,.1 ......... ~ '". .................................... II ' ' ........ ,...~ .............................. ~ ............. I1~~ .......... ~,o ==E ............. '.,. ' '11TM" BOP STACK II --~aT~ ' ~..:' ~. aP/~j.Pr I!~ ............. '.'~ ................... ?We,.' ~; ....................... sHY," ' : .,.-: ~- o~c.~.. II nTS n'.o,.,~¢,,, ~oo,o: '~ o~ VE.~O. ALASKASTAT 10 o^'re ,.VOCE / C.EDrr ,dedO oeSC.,m~N ~S D,scou.*r .~ 101200 CKlO1200B 100. O0 100. O0 PY~T (:O~ENTS: PERI liT TO DR~LL I'EE HANDL] NO INST: S/H SONDRA X4750 ~ A~AC~O ~ · m pAv~m ~ ~ ~n~ ~ ~ 100. O0 100_ O0 W;I · PERMIT CHECKLIST FIELD & POOL COMPANY ADMINISTRATION APPR DATE. ~ 11,/5/,~) WELL NAME ~/'-,~),/~ PROGRAM: exp INIT CLASS ~.~~--~¢z~-~ //4J/~J 1. Permit fee attached ......................... 2. Lease number appropriate~. ~ ~_,=~..,~/-z,.-~ /C~-~,ui 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 27. 28. 29. GEOLOGY A/~ DATE. /l',./¢.,-~ 30. 31. 32. 33. 34. Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to '~'i~i~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S' gas probable ............ . ..... dev redrll serv V~ wellbore seg ann. disposal para req GEOL AREA ~c:~) UNIT# ~)////~_~Z.~~) ON/OFF SHORE <:~N ~.~N Permit can be issued w/o hydrogen sulfide measures ..... ,Y,, Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones.' ............ / ~,,"W N Seabed condition survey (if off-shore) .......... .~,,~./~"' Y N Contact name/phone for weekly progress reports [explOratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater;; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UlClAnnular /~..,~ COMMISSIgN: JMH _~ Comments/Instructions: 1:3 0 Z 0 c:\msoffice\wordian~diana\checklist (rev. 11/01fl00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history' file. To improve :the readability of the Well History file and to simp!ify finding information, informati;3n of this '. nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information.. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Feb 21 08:55:19 2002 Reel Header Service name ............. LISTPE Date ..................... 02/02/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 02/02/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point 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: FAIL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPJ-20A 500292283201 B.P. Exploration (Alaska), Inc Sperry-Sun Drilling Services 21-FEB-02 MWD RUN 2 AK-MM-00311 J. FOLEY C. DIXON 28 13N 10E 2207 3288 64.22 35.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 6215.0 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER E-MAIL FROM D.SCHNORR (GEOQUEST/BP) TO R.KALISH (SSDS), DATED 3/29/01. MWD DATA ARE CONSIDERED PDC. 6. MWD RUN 2 REPRESENTS WELL MPJ-20A WITH API#: 50-029-22832-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF ll176'MD/3986'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. 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) i SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/21 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 6182.0 11127.5 RPX 6188.5 11134.5 RPS 6188.5 RPM 6188.5 RPD 6188.5 FET 6188.5 ROP 6230.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 11134.5 11134.5 11134.5 11134.5 11176.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 6182.0 11176.0 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 Spa~ing ..................... 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 HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 6182 11176 8679 9989 ROP MWD FT/H 0.47 635.4 181.893 9893 GR MWD API 17.'59 141.48 71.8311 9892 RPX MWD OHMM 0.31 1312.45 1~.7804 9893 RPS MWD OHMM 0.62 1868.87 19.0115 9893 RPM MWD OHMM 0.19 2000 22.6136 9893 RPD MWD OHMM 0.07 2000 19.4851 9893 FET MWD HOUR 0.08 7.47 0.873194 9893 First Reading 6182 6230 6182 6188.5 6188.5 6188.5 6188.5 6188.5 Last Reading 11176 11176 11127.5 11134.5 11134.5 11134.5 11134.5 11134.5 First Reading For Entire File .......... 6182 Last Reading For Entire File ........... 11176 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/21 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 ....... 02/02/21 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: 2 DEPTH INCREMENT: .5000 FILE S LSvSW_ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6182.0 11127.5 RPX 6188.5 11134.5 RPS 6188.5 11134.5 RPM 6188.5 11134.5 RPD 6188.5 11134.5 FET 6188.5 11134.5 ROP 6230.0 11176.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMI/MANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTRON_AG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 26-DEC-00 INSITE 4.30 Memory 11176.0 6230.0 11176.0 79.4 87.3 TOOL N731~BER 01758gr4 01758gr4 6.125 6215.0 LSND 8.90 52.0 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 9.5 850 6.2 3.000 3.640 3.500 3.500 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 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 67.0 54.0 67.0 67.0 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR Min Max Mean Nsam 6182 11176 8679 9989 0.47 635.4 181.893 9893 17.59 141.48 71.8311 9892 0.31 1312.45 17.7804 9893 0.62 1868.87 19.0115 9893 0.19 2000 22.6136 9893 0.07 2000 19.4851 9893 0.08 7.47 0.873194 9893 First Reading 6182 6230 6182 6188.5 6188.5 6188.5 6188.5 6188.5 Last Reading 11176 11176 11127.5 11134.5 11134.5 11134.5 11134.5 11134.5 First Reading For Entire File .......... 6182 Last Reading For Entire File ........... 11176 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/02/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 02/02/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File