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Home My WebLink About204-219 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q...O lJ - ;;1J ç¡ Well History File Identifier Page Count from Scanned File: ,.., Lf (Count does include cover sheet) Page Count Matches Number in Scannin1 Preparation: v"" YES ~_ Date: I/SJD7 If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) o Two-sided 1111111111111111111 R~AN '¢ Color Items: o Greyscale Items: DIGITAL DATA 'Ø"6iskettes, No. ~ o Other, Norrype: o Poor Quality Originals: o Other: NOTES: BY: ~ Dale 1/5/07 Project Proofing Dale 1/407 ~ x 30 = to () Date: 1/5 /07 BY: ~ Scanning Preparation BY: ~ Production Scanning Stage 1 BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed 1111111111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: mP 151 1111111111111111111 151 111 P + 13 = TOTAL PAGES 73 (Count does not include cover sheet) , A Å 0 Isl V vH 111111/111111111111 NO 151 M P NO Isl 1111111111111111111 1111111111111111111 151 Quality Checked 1IIIIII111111111111 10/6/2005 Well History File Cover Page.doc 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, January 10, 2013 TO: Jim R egg P.I. Supervisor I i ( i 3 ( 'f SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC G-03A FROM: Chuck Scheve MILNE PT UNIT SB G-03A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB G-03A API Well Number 50-029-21942-01-00 Inspector Name: Chuck Scheve Permit Number: 204-219-0 Inspection Date: 12/29/2012 Insp Num: mitCS121229144947 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min , W G-03A ' Type Inj w FTVD 1 4128 IA I Imo ; 2140 2080 .1 2070 ,--' 1 1 1 1 PTD1 2042190 Type Test l SPT Test psi! 1500 OA °H 580 . 580 1 550 - 1 _L Interval ;4YRTST P/F P - 1Tubing ;' 2550 , i 2550 i 2550 2550 - 1 , I Notes: pretest pressures observed and and found stable. - SCANNED APR 11 n13 Thursday, January 10, 2013 Page 1 of 1 STATE OF ALASKA • • A SKA OIL AND GAS CONSERVATION COMMISSION s REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other L MBE Treatment Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdowr0 Stimulate - Other ❑ Re -enter Suspended WeiU 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 204 -219 -0 3. Address: P.O. Box 196612 StratigraphiC Service El 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21942 -01 -00 7. Property Designation (Lease Number): _ J')l 8. Well Name and Number: _ ADL0025518 A.5901. la f 1 7 SBL MPG -03A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): t f 10. Field /Pool(s): _ To Be Submitted MILNE POINT, SCHRADER BLFF OIL 11. Present Well Condition Summary: Total Depth measured 6536 feet Plugs measured 6164 feet RECEIVED true vertical 4525.1 feet Junk measured None feet OCT 172012 Effective Depth measured 6164 feet Packer measured See Attachment feet true vertical 4307.51 feet true vertical See Attachment feet A G C C Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 13 -3/8" 48# H-40 32 - 112 32 -112 0 0 Surface 2902 9 -5/8" 47# L -80 31 - 2933 31 - 2544.76 6870 4760 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None Perforation depth Measured depth 5942 - 5977 feet 6010 - 6050 feet 6157 - 6164 feet 6164 - 6217 feet 6275 - 6317 feet True Vertical depth 4182.55 - 4201.99 feet 4220.42 - 4242.88 feet 4303.54 - 4307.51 feet 4307.51 - 4337.61 feet 4370.96 - 4395.41 feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2# L -80 29 - 6385 29 - 4435.33 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SCANNED JAN 2 8 2013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 746 0 1445 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 151 Stratigraphic 0 Daily Report of Well Operations X 16. Well Status after work: -. Oil ❑ Gas ❑ WDSPII1 GSTOR ❑ WINJ El WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -263 Contact Nita Summerhays Email Nita.Summer bp Printed Name Nita Summerhays Title Petrotechnical Data Technician AIWAINIWIN =maw Signs - =�� A _,,,, ,, �� Phone 564 -4035 Date 10/15/2012 Ji )' OCT 192012 , -2 -1.,z. A /0/,- Form 10-404 Revised 10/2012 Submit Original Only 1 1 Daily Report of Well Operations ADL0025518 HES H2 Zero Treatment; Move equipment from MPS -Pad to MPG -Pad. MIRU HES and spot support equipment. Perform low / high PT to 3800 psig - passed. Open well. SIWHP = 0. Pump 10 bbl - 50/50 spear. Catch fluid at 9 bbls away. Pump 15 bbls produced fluid at 1/2 bpm © 645 psig WHP. Swap to H2 Zero and increase rate to 3/4 bpm.@ 670 psig WHP. After 12 bbls of H2 Zero into formation, incresed rate to 1.0 bpm. 9/23/2012 Continue pumping H2 Zero. Cont' on WSR 9/24/12 ... HES H2 Zero Polymer Treatment; Continued from 9/23/12 ... Continue pumping H2 Zero Polymer treatment at 1.0 bpm @ 780 psig WHP. Pumped a total of 407 bbls of H2 Zero Polymer at a final rate of 1.0 bpm @ 770 psig WHP. Displace H2 Zero Polymer to formation with 59 bbls produced water followed by 10 bbls of 50/50 meth - water. Final injection at 1.0 bpm @ 750 psig WHP. Shut -in and secure well. RD HES..... Job Complete 9/24/2012 FLUIDS PUMPED BBLS 20 50/50 METH 756 H2 ZERO 74 PRODUCED WATER 850 TOTAL • I Packers and SSV's Attachment ADL0025518 SW Name Type MD TVD Depscription MPG -03A PACKER 5853 4070.29 3 -1/2" Baker Premier Ret. Pkr MPG -03A PACKER 5996 4149.49 3 -1/2" Baker Premier Ret. Pkr MPG -03A PACKER 6011 4157.87 3 -1/2" Baker Premier Ret. Pkr MPG -03A PACKER 6250 4293.42 3 -1/2" Baker S -3 Packer I Casing / Tubing Attachment ADL0025518 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 13 -3/8" 48# H-40 32 - 112 32 - 112 PRODUCTION 1951 7" 29# L -80 30 - 1981 30 - 1866.58 8160 7020 PRODUCTION 4555 7" 26# L -80 1981 - 6536 1866.58 - 4525.1 7240 5410 SURFACE 2902 9 -5/8" 47# L -80 31 - 2933 31 - 2544.76 6870 4760 TUBING 6356 3 -1/2" 9.2# L -80 29 - 6385 29 - 4435.33 10160 10530 0 • 1 Tree:Cameron 3 1/8`5M MPG 03ai Orig. KB Elev. = 32.45 (Doyon-14) Wellhead: WKM 11 "X 3 1/2" Inj 1 hanger w/ NSCT T & B thread Orig. RT-LDS Elev. = — 31.60' (Doyon -14 and 3.5" 'H' BPV profile J 13 3/8" 48#, H -40 110' 3.5" HES X- Nipple (2.813" pkg.) 511' NOTE: 7" casing is hung off on emergency slips. Valves in the SPM / XN: Arrangement as of 5/7/11 9 5/8" 47 #, L -80 BTC 2931' I , NOT Well was side tracked out of the D 3.5" x 1.5" Camco MMG GLM 2,118' 9 5/8" casing with a whipstock set (1964' - 1981') on top of a cement retainer set at I 3.5" HES X- Nipple (2.813" pkg.) 5,824' 1981'. Window is cut from 1965' - 1981'. 1 7" x 3.5" Baker Premier Packer I 5,$44' KOP @ 800' D 3.5" x 1.5" Camco MMG -W GLM I 5,870' Max. hole angle = 65° @ 5526' ._ ill Hole angle thru' perfs = 61° D 3.5" x 1.5" Camco MMG GLM 5,927' Short Joint w/ RA Tag 1 5853' - 5873'1 7" x 3.5" Baker Premier Packer 5,987' D 3.5" x 1.5" Camco MMG -W GLM 6,013' 3.5 ", 9.2 ppf, L -80 TC -II Tbg. D 3.5" x 1.5" Camco MMG GLM 6,042' (cap. = 0.0087 bpf, drift = 2.867 ") ■ 7" 26 #, L -80, BTC -MOD Casing ullill 7" x 3.5" Baker Premier Packer 6,102' (drift ID = 6.151, cap.= .0383 bpf) IDD 3.5" x 1.5" Camco MMG-W GLM 6,128' SBHP Data NC & NB - 2582# Calculated pressure 07 - 29 - 10 Top of Sluggits at 6139' MD NE sands 2.69" WRP Set at 6164' MD OA sands -1600# Calculated pressure 09 -13 -11 D 3.5" x 1.5" Camco MMG GLM 6,188' OB sands -3048# Calculated pressure 09 -13 -11 Perforation Summary 7" x 3.5" Baker S -3 Packer 6,250' 1 Size Spf Interval (TVD) 0 D 3.5" x 1.5" Camco MMG -W GLM 6,275' NC & NB Sands 4.5 5 5,942' - 5,977' D 3.5" x 1.5" Camco MMG GLM 6,336' NE Sands 4.5 5 6,010' - 6,050' I 3.5" HES XN- Nipple (2.813" pkg.) 6,364' OA Sands 2.750" No -Go ID 4.5 5 6,157' - 6217' 3.5" WLEG 1 6,376' OB Sands 4.5 5 6,275' - 6,317' 4.5" 4505 Powerjet, HSD 5spf chg. 7" Halliburton Float Collar 6450' A ■ 7" Halliburton float shoe 6536' DATE REV. BY COMMENTS MILNE POINT UNIT 11/16/04 Lee Hulme Side Tracked and Cased by Doyon 14 WELL No.: MPG -03ai 12/05/04 MDO Completion 4 -ES API : 50 -029- 21942 -01 -00 BP EXPLORATION (AK) • :17-77-1 r71 r [LA SEAN PARNELL, GOVERNOR ( =1) ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alecia Wood MPU Schrader Pad Engineer BP Exploration (Alaska), Inc. O LOLI P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPG-03A Sundry Number: 312-263 Dear Ms. Wood: 5LANNED AUG 0 202 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, , a 1 4 Cathy . Foerster Chair DATED this 6-> day of July, 2012. Encl. RECEIVED • STATE OF ALASKA ,ILJL 1 7 2012. ALASKA OIL AND GAS CONSERVATION COMMISSION 0 /..S' 7[ . 71/& APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ca Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 204 -219-0 • 3. Address: Stratigraphic ❑ Service 0 • 6. API Number. P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 21942 -01 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No IS MPG -03A ' 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025518 % 25906' MILNE POINT, SCHRADER BLFF OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6536 - 4525 6164 4308 6164 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 13 -3/8" 48# H-40 32 - 112 32 - 112 Surface 2902 9 -5/8" 47# L -80 31 - 2933 4760 - L -80 31 2545 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 3 -1/2" 9.2# L -80 10160 29 - 6385 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSV Installed No SSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch IS Exploratory ❑ Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ El , GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Prepared by Garry Catron 564 -4424 Printed Name Alecia Wood Title MPU Schrader Pad Engineer Signature Phone Date leXidOetCP COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3' Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: /t 4 i 1 APPROVED BY Approved by: ` ` .4. G,, A_..--- COMMISSIONER THE COMMISSION Date: 7 - 2-5 — / 2' N g c v Submit in Duplicate 1 . � VI ed JVt� 19 N V a .\ For Q� �� ,� ORIGINAL „ ��' L • • Packers and SSV's Attachment ADL0025518 / 25906 Well Jewelry Jewelry Type MD TVD MPG -03A PACKER 3 -1/2" Baker Premier Ret. Pkr 5853 4133 MPG -03A PACKER 3 -1/2" Baker Premier Ret. Pkr 5996 4213 MPG -03A PACKER 3 -1/2" Baker Premier Ret. Pkr 6011 4221 MPG -03A PACKER 3 -1/2" Baker S -3 Packer 6250 4357 1 • • Perforation Attachment ADL0025518 / 25906 Well Date Operation MD Top MD Base TVD Top TVD Base MPG -03A 7/29/2010 STC 5942 5977 4183 4202 MPG -03A 12/6/2004 STC 6010 6050 4220 4243 MPG -03A 9/14/2011 STO 6157 6164 4304 4308 MPG -03A 9/14/2011 STO 6164 6217 4308 4338 MPG -03A 9/13/2011 BPS 6275 6317 4371 4395 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE PLUG BPS SET 01-1 OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Completion Attachment ADL0025518 / 25906 Casing Type Size MD Top MD Base TVD Top TVD Base Burst Collapse CONDUCTOR 13 -3/8" 48# H-40 32 112 32 112 PRODUCTION 7" 29# L -80 30 1981 30 1867 8160 7020 PRODUCTION 7" 26# L -80 1981 6536 1867 4525 7240 5410 SURFACE 9 -5/8" 47# L -80 31 2933 31 2545 6870 4760 TUBING 3 -1/2" 9.2# L -80 29 6385 29 4435 10160 10530 • • Tree:Cameron 3 1/8" 0 MPG -03ai Wellhead: WKM 11" X 3 1/2" Inj Orig.Elev. = 32.45 (Doyon - 1a) hanger w/ NSCT T & B thread Orig. RT -LDS Elev. = 31.60' (Doyon - 14 and 3.5" 'H' BPV profile 13 3/8" 48 #, H -40 110' - . 3.5" HES X- Nipple (2.813" pkg.) 511' NOTE: 7" casing is hung off on emergency slips. ; , le / ';:: - F is “ pr i 9 5/8" 47 #, L -80 BTC 1 2931' , 1 NOTF: Well was side tracked out of the 3.5" x 1.5" Camco MMG GLM 2,118' 9 5/8" casing with a whipstock set (1964' - 5,824' 1981') on top of a cement retainer set at - 3.5" HES X- Nipple (2.813" pkg.) 1981'. Window is cut from 1965' - 1981'. 7" x 3.5" Baker Premier Packer I 5,844' KOP @ 800' � r 3.5" x 1.5" Camco MMG -W GLM I 5,870' I Max. hole angle = 65° @ 5526' Hole angle thru' perfs = 61° 3.5" x 1.5" Cameo MMG GLM 1 5,927 ilkor.; Short Joint w/ RA Tag 1 5853' - 5873' I _... 9 7" x 3.5" Baker Premier Packer 5,987' j ' �) 3.5" x 1.5" Camco MMG -W GLM 6,013' 1 3.5 ", 9.2 ppf, L - TC -II Tbg. '1'. f 3.5" x 1.5" Camco MMG GLM 6,042' (cap. = 0.0087 bpf, drift = 2.867 ") P 7" 26 #, L - 80, BTC -MOD Casing „ 7" x 3.5" Baker Premier Packer I 6,102` (drift ID = 6.151, cap.= .0383 bpf) < -r _ f7 r ... 3.5"xl.S"CamcoMMG-WGLM 6,128' .- Top of Sluggits at 6139' MD , ( ; _ 2.69" WRP Set at 6164' MD a e ? 3.5" x 1.5" Camco MMG GLM I 6,188` rt Perforation Summary 7" x 3.5" Baker S -3 Packer 6,250' NM Size Spf Interval (TVD) ' 3.5" x 1.5" Camco MMG -W GLM I 6,275' I NC & NB Sands 3.5" x 1.5" Camco MMG GLM 6,336` 4.5 5 5,942' - 5,977' )., NE Sands 4.5 5 6,010' - 6,050' 3.5" HES XN- Nipple (2.813" pkg.) I 6,364' I OA Sands 2.750" No -Go ID 4.5 5 6,157' - 6217' 3.5" WLEG 1 6,376' I OB Sands 4.5 5 6,275' - 6,317' F --�/://,,<1;4 7" Halliburton Float Collar 6450' 4.5" 4505 Powerjet, HSD 5spf chg. �� /� -s#D !f f 7" Halliburton float shoe 6536' DATE REV. BY COMMENTS MILNE POINT UNIT 11/16/04 Lee Hulme Side Tracked and Cased by Doyon 14 WELL No.: MPG -03ai 12/05/04 MDO Completion 4 -ES API : 50- 029 - 21942 -01 -00 BP EXPLORATION (AK) 0 To: Mark O'Malley /Rob Handy Date: July 2, 2012 MPU Well Operations Supervisor From: Alecia Wood, MPU Schrader Pad Engineer 907 - 564 -5492 Subject: MPG -03A Coil Cleanout, Acidize Step Unit Operation 1 C Conduct coil cleanout of wellbore 2 C Acidize as necessary OBJECTIVE 1. Cleanout wellbore with coil tubing post MBE treatment. Acidize as necessary to regain v injectivity. PROCEDURE Cleanout 1. RU, hold pre -job safety meeting, PT 2. RIH and cleanout wellbore with coil tubing to top of plug (6139'MD) 3. Perform injectivity test with produced water. Contingency if injectivity is not regained 4. Spot 5 bbls of 7% HCI and soak perfs. 5. Perform injectivity test with produced water raising injection pressure to a max of 4000 psig if necessary. MITE OF ALASKA ALASKA OIL AND CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other p MBE TREATMENT Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ " 204 -2190 3. Address: P.O. Box 196612 Stratigraphic Service El 6. API Number: Anchorage, AK 99519 -6612 • 50- 029 - 21942 -01 -00 8. Property Designation (Lease Number) : _ _ 9. Well Name and Number: ADLO- 025518 / 025906 , MPG -03A 10. Field /Pool(s): , MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 6536 feet Plugs (measured) 6164 feet true vertical 4525.1 feet Junk (measured) None feet Effective Depth measured 6450 feet Packer (measured) 5853. 5996 6011 6250 feet true vertical 4473.82 feet (true vertical) 4133.4213 4221 4357 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13 -3/8" 48# H-40 32 - 112 32 - 112 1740 750 Surface 2902' 9 -5/8" 47# L -80 31 - 2933 31 - 2545 6870 4760 Production 1951' 7" 29# L -80 30 - 1981 30 - 1867 8160 7020 Production 4555' 7" 26# L -80 1981 - 6536 1867 - 4525 7240 5410 Liner Liner t Perforation depth: Measured depth: SEE ATTACHED - I } : - F L „' C (t'� True Vertical depth: _ Tubing: (size, grade, measured and true vertical depth) 3 -1/2” 9.2# L -80 29 - 6385 29 - 4435 Packers and SSSV (type, measured and true vertical depth) 3 -1/2" Baker Premier Ret. Pkr 5853 4133 3 -1/2" Baker Premier Ret. Pkr 5996 4213 3 -1/2" Baker Premier Ret. Pkr 6011 4221 3 -1/2" Baker S -3 Packer 4357 12. Stimulation or cement squeeze summary: �� Intervals treated (measured): I I ' ' ` i ; Treatment descriptions including volumes used and final pressure: Oktos a i)yt & : a r Cons. Commissio 13. Representative Daily Average t roacrction or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 746 1,445 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ❑ Service 151 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ ,. WINJ 0 WAGE] GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -293 Contact Joe Lastufka Printed Name Joe Lastuf a Title Petrotechnical Data Technologist ■ Signal , Phone 564 -4091 Date 11/18/2011 R BDMS NOV 2 2 / -Z-2i Form 10 -404 Revised 10/2010 101 / J Submit Original Only MPG -03A 204 -219 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPG -03A 12/4/04 PER 5,942. 5,977. 4,182.55 4,201.99 MPG -03A 12/4/04 PER 6,010. 6,050. 4,220.42 4,242.88 MPG -03A 12/4/04 PER 6,157. 6,217. 4,303.54 4,337.61 MPG -03A 12/4/04 PER 6,275. 6,317. 4,370.96 4,395.41 MPG -03A 1/16/05 BPS 6,250. 6,450. 4,356.52 4,473.82 MPG -03A 1/24/05 BPP 6,250. 6,450. 4,356.52 4,473.82 MPG -03A 1/25/05 BPS 6,364. 6,450. 4,422.96 4,473.82 MPG -03A 8/12/10 BPP 6,364. 6,450. 4,422.96 4,473.82 MPG -03A 8/15/10 BPS 6,166. 6,450. 4,308.65 4,473.82 MPG -03A 8/16/10 SPS 6,152. 6,166. 4,300.7 4,308.65 MPG -03A 12/11/10 BPP 6,166. 6,450. 4,308.65 4,473.82 MPG -03A 12/11/10 SPR 6,152. 6,166. 4,300.7 4,308.65 MPG -03A 12/12/10 BPS 6,364. 6,450. 4,422.96 4,473.82 MPG -03A 9/12/11 BPP 6,364. 6,450. 4,422.96 4,473.82 MPG -03A 9/13/11 BPS 6,164. 6,157. 4,307.51 4,303.54 • MPG -03A 9/14/11 SPS 6,140. 6,164. 4,293.89 4,307.51 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • MPG -03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 1 0/28/201 1 3 ** *Thermatek / H2Zero Treatment * ** Pre Thermatek injection test - -Pump 5 bbl's 'diesel, 24 bbl's produced water, 9.2 bbl's K -max gel, chased gel to open injection mandral at 6128' and with PW. At 20 bbl's away something plugging off the injection mandrel, bleed 1 bbl back and worked free. 50 bbl's away started bilding pressure ;again, (tbg vol to inj mandrel 53 bbl's). The K -max gel appears to have pushed schmoo/sluuggets? ahead which plugged off the inj mandrel, able to work the gel pill ;through but unable to properly diagnose the MBE. Freeze protect tbg to 2200' with 'diesel and will return in the AM to re- attempt the Pre Thermatek injection test. 1 ** *Secure location for night * ** 10/29/2011; ** *Thermatek / H2Zero Treatment * ** Pre Thermatek injection test - -Pump 5 bbl's :60/40 meth, 20 bbl's PW, 8.7 bbl's K -max gel, chased gel to open injection mandrel at 6128' and with PW. Saw gel hit inj mandrel at 53 bbl's, continue pumping 95 bbl's of PW, freeze protect surface lines with 1 bbl's meth. ** *Thermatek treatment * ** Pump 2 bbl's pw, 3 bbl's x -link k -max gel, 6 bbl's Thermatek, 3 bbl's x- linked k -max gel, 6 bbl's Thermatek, 2 bbl's linear k -max gel, 25 bbl's PW, 28.3 bbl's diesel. Over ;flush thermatek by 1 bbl gel leaving 1 bbl gel in tbg & 3.5" x 7" lnr. Secure location. ** *Thermatek Treatment complete * ** 10/30/2011; ** *Thermatek / H2Zero Treatment * ** Post Thermatek injection test -- worked pressure pup to 4000 psi, unable to establish injection. Will require CTU cleanout before pumping H2Zero treatment. ** *Job complete * ** FLUIDS PUMPED BBLS 55 DIESEL 11 60/40 METH 134 PW 12 THERMATEK 6 K -MAX GEL X- LINKED 2 K -MAX GEL LINEAR 220 TOTAL Tree:Cameron 3 1/8" 5M MPG -03ai Wellhead: WKM 11 "X 3 1/2" Inj Orig. KB Elev. = 32.45 (Doyon-14) hanger w/ NSCT T & B thread Orig. RT -LDS Bev. = 31.60' (Doyon -14 and 3.5 " 'H' BPV profile J 13 3/8" 48#, H-40 I 110' 3.5" HES X- Nipple (2.813" pkg.) I 511' NOTE: 7" casing is hung off on emergency slips. 407n7777i710711 9 5/8" 47 #, L -80 BTC 1 2931' I A ' NOTE: Well was side tracked out of the 3.5" x 1.5" Camco MMG GLM I 2,118' 9 5/8" casing with a whipstock set (1964' - 1981') on top of a cement retainer set at - 3.5" HES X- Nipple (2.813" pkg.) I 5,824' 1981'. Window is cut from 1965' - 1981'. 7" x 3.5" Baker Premier Packer I 5,844` I IIIMM KOP @ 800' 3.5" x 1.5" Camco MMG -W GLM 5,870' I Max. hole angle = 65° @ 5526' Hole angle thru' perfs = 61° I . 3.5" x 1.5" Camco MMG GLM I 5,9 I Short Joint w/ RA Tag 1 5853` - 5873'1 - 7" x 3.5" Baker Premier Packer I 5,987' I Imo 3.5" x 1.5" Camco MMG -W GLM 6,013' 3.5 ", 9.2 ppf, L -80 TC -II Tbg. i 3.5" x 1.5" Camco MMG GLM I 6,042' I (cap. = 0.0087 bpf, drift = 2.867 ") �' 7" 26 #, L-80, BTC -MOD Casing - - - 7" x 3.5" Baker Premier Packer I 6,102' (drift ID = 6.151, cap.= .0383 bpf) _ 3.5" x 1.5" Camco MMG -W GLM 6,128' Top of Sluggits at 6139' MD 2.69" WRP Set at 6164' MD ;l 1 f 3.5" x 1.5" Camco MMG GLM I 6,188' Perforation Summary �•., u r - . -.k -- 7" x 3.5" Baker S -3 Packer 6,250' Size Spf Interval (TVD) 3.5" x 1.5" Camco MMG -W GLM ( 6,275' NC & NB Sands 3.5" x 1.5" Camco MMG GLM I 6,336' 4.5 5 5,942` - 5,977' NE Sands 4.5 5 6,010' - 6,050' ,.-? 3.5" HES XN- Nipple (2.813" pkg.) I 6,364' OA Sands 2.750" No-Go ID 4.5 5 6,157' - 6217' 3.5" WLEG 6,376' OB Sands 4.5 5 6,275' - 6,317' 4.5" 4505 Powerjet, HSD 5spf chg. 7" Halliburton Float Collar 6450' , 7" Halliburton float shoe 6536' DATE REV. BY COMMENTS MILNE POINT UNIT 11/16/04 Lee Hulme Side Tracked and Cased by Doyon 14 WELL No.: MPG -03ai 12/05/04 MDO Completion 4 -ES API : 50 -029- 21942 -01 -00 BP EXPLORATION (AK) + • • SIIAINE p� SEAN PARNELL, GOVERNOR J ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Keith Lopez Petroleum Engineer BP Exploration (Alaska), Inc. r . r,. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPG -03A Sundry Number: 311 -293 Dear Mr. Lopez: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4410 Daniel T. Seamount, Jr. Chair DATED this 2 day of September, 2011. Encl. STATE OF ALASKA C '/ t —/G ALASKAIIP G � AND GAS CONSERVATION COMMISSIO. ft. ? ?// APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: MBE TREATMENT El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 204 -2190 " 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 _ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21942- 01 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ MPG -03A 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 02551X2S9O6 MILNE POINT Field / SCHRADER BLUFF Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6536 - 4525.1 - 6450 - 4473.82 - 6164 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13 -3/8" 48# H -40 32 112 32 112 1740 750 Surface 2902' 9 -5/8" 47# L -80 31 2933 31 2545 6870 4760 Production 1951' 7" 29# L -80 30 1981 30 1867 8160 7020 Production 4555' 7" 26# L -80 1981 6536 1867 4525 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 3 -1/2" 9.2# L -80 29 6385 Packers and SSSV Tvoe: 3 -1/2" Baker Premier Ret. Pkr Packers and SSSV MD and TVD (ft): 5853 4133 3 -1/2" Baker Premier Ret. Pkr 5996 4213 3 -1/2" Baker Premier Ret. Pkr 6011 4221 3 -1/2" Baker S -3 Packer 6250 4357 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/5/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ El - GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact KEITH LOPEZ Printed Name KEITH LOPEZ Title PE Signature r� hone Date �� 564 -5718 9/21/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 I i • J RE ENE + ) Plug Integrity ❑ BOP Test p Mechanical Integrity Test ❑ Location Clearance ❑ 6 rffy1l ;EP ZO Other: Msgka 04 & Gas C ons. C �/ 1�ncir�ga Subsequent Form Required: /()' yd [ / APPROVED BY Approved by � COMMISSIONER THE COMMISSION Date: 712,1 RB I SEP 3 0' .9.z7/1 Q A "" Form 10 -403 Revised 1/2010 , Submit in Duplicate MPG -03A . . 204 -219 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPG -03A 12/4/04 PER 5,942. 5,977. 4,182.55 4,201.99 MPG -03A 12/4/04 PER 6,010. 6,050. 4,220.42 4,242.88 MPG -03A 12/4/04 PER 6,157. 6,217. 4,303.54 4,337.61 MPG -03A 12/4/04 PER 6,275. 6,317. 4,370.96 4,395.41 MPG -03A 1/16/05 BPS 6,250. 6,450. 4,356.52 4,473.82 MPG -03A 1/24/05 BPP 6,250. 6,450. 4,356.52 4,473.82 MPG -03A 1/25/05 BPS 6,364. 6,450. 4,422.96 4,473.82 MPG -03A 8/12/10 BPP 6,364. 6,450. 4,422.96 4,473.82 MPG -03A 8/15/10 BPS 6,166. 6,450. 4,308.65 4,473.82 MPG -03A 8/16/10 SPS 6,152. 6,166. 4,300.7 4,308.65 MPG -03A 12/11/10 BPP 6,166. 6,450. 4,308.65 4,473.82 MPG -03A 12/11/10 SPR 6,152. 6,166. 4,300.7 4,308.65 • MPG -03A 12/12/10 BPS 6,364. 6,450. 4,422.96 4,473.82 MPG -03A 9/12/11 BPP 6,364. 6,450. 4,422.96 4,473.82 MPG -03A 9/13/11 BPS 6,164. 6,157. 4,307.51 4,303.54 MPG -03A 9/14/11 SPS 6,140. 6,164. 4,293.89 4,307.51 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • bP To: Mark O'Malley /Rob Handy Date: September 20, 2011 MPU Well Operations Supervisor From: Keith Lopez, MPU Schrader Pad Engineer 907 - 564 -5718 Subject: MPG -03A MBE Treatment Step Unit Operation 1 S Set dummy valves in tubing mandrels to isolate zone for treatment 2 S Set retrievable plug in tubing to protect lower mandrels 3 0 Shut in all offset producers. Bullhead water into MPG -03A. 4 0 Bullhead treatment down MPG -03A (OA zone). Keep well and offset producers and injectors shut in for minimum of 2 days and flow producers to a tank before returning to production. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Measure of success 1. Treatments are fully displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is seen. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPG -03A is a regulated injector in the N, OA, and OB sands supporting MPG -16 and MPE- 28. The OA zone has an MBE with MPG -16 which was treated in 2010. The purpose of this treatment is to block the preferential path in the OA zone to decrease injectivity and re- establish matrix water flooding. PROCEDURE Stage 1. Prep Well 1. Dummy off GLM's and leave GLM across from treatment interval empty. 2. Set retrievable plug below treatment GLM to protect lower mandrels. . • • Stage 2. Injection Test 3. RU, hold pre -job safety meeting, PT surface lines 4. Ensure offset producers are SI. 5. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 6. Contact Engineering to discuss the injection pressure /rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate /pressure continue with remainder of program. Stage 3. Treatment 7. Ensure offset producers are offline 8. Pump produced water pre -flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 9. Pump produced water pre -flush followed by high volume gel treatment and diesel over flush. 10. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 11. Rig down all equipment and hold post -job assessment meeting to capture learnings to be incorporated into future jobs. 12. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. • • Tree:Can veren 3 1 AP 5M MPG -Q 3 a i ,_r ri KB Elev. = 5' .45 'or-1 Wellhead: WKM 11' X 3 1/2" irj g / hanger Ail t4SCT T & B thread 0.-g RT -LDS Elev. = 31.60 'ocverr's and 3.594' BPV pr°61e 13 SG' 4ef. H-44 I i ta. I - " ^tEC X- Ntipie 12.513' pc; I ' 1 A016; 7 easing Is llur =g of or errer ency sins. __ 1^ the ri DIV :X4 Arrar - :. - .in , . - _ , - - . as : _. - .' 1 9 5,9- 474, _ -60 ETC 1 25.31` ,:. E , Well 'inas sly :ranted or of /re 3.5' x 1.5` Caked 3NAG f;LM I 2.1 1:9 3 5,3' casing with a wmlpstect set (1964 - 19E1'1 on top oTa cement retainer set at 3.5' HESX- 14ipie(2a13'pia}.} I 5,824' 1 9111'. Vi hdtra' Is exit from 1465' - 1581' ' r x 35' Baker Premier Packer I '' 34* NOR '` 3.5- x1.5- Came MMG -W I E.-7 I Max_ hole angle = 85' fa 55215 Hale angle thru' pert = 81 3.5'x1 "Car,rnWA:�GLA1 I ''. Snell 15553'-5573'1 • r. 7'x3- 5'Bate^ „, erPacke^ I E,de7 MI 35'x1.5" canna MMG -WGLM L n, I 3.5 ", 6.2 ppf, L-80 TC -II The. ■ 3.5 x 1.5' Came° MMG G_M I 6,042 I (e .w. = 0.0087 bpf, drift = 1.387 Ell 7" 26#• L -90, BTC -MCC Casing 7• x 3.5' Baker Premier Rader I 8,132' fdrift ID = 6.151, cap = .0393 bpfi _ 3.5'1 1.5'Car1rb -1V G_M 6.125 I 0 HP Data - NC . L *E , ECX Oaoatlefl pesiot C7 .2.S - Top OT ,mv IJ ^ :5 at t 135 \i 'E sal= ME - 269' MAP ;e: at 51 E= ki CA sand: .160CPL Ntd iressze - I OS sant .30440 Cacaald znezwe 11-1 3.5' x 1.5' Carnca M' IJ G GLM I ' :2 _' Perforation Summary ■ r x 3.5• Baker S - 3 Packer I 6.25C I ■ Size SRf Internal (T't'D;+ 3.5' x 1.5' Ca r ;AUG GL#f I r 275 I NC & NB Sands . 41 5 5;542' - 5.977' 3.5'x1.5" earned MUG GL. 6•33e NE Sanas 4.5 5 6.810' - 6.OSG' I 3.5' HES XN- NIpple 12. @13' pkg.I 5.3'5 I OA ;ands I 2.758' Nos -G:1 ID 4-5 5 6,157' -6217' '•-'_-,1 3.5' e.-,75 I 08 Sands 4.5 5 6,275' -6,317' 4.5' 4 . .5 norrerlet, HST E [hg. 7' Hailklurtor Float Colar 64E0' 4 r allturton feat sloe 5535' C: -E REV. BY COMMENTS MILNE POINT UNIT Lee Hulrr. E. 7lce Traced and Cased by Doyon 14 WELL No.: MPG -03ai 1_ MOO romp e:or 4 - ES API : 50-029-21942-01-00 BP EXPLORATION (AK) • • ~~Q~~ 0~ Q~G~~~Q /,~.m.,E..~~~. Keith Lopez Wells 8v Surface Engineer ~~~~,.~. ti~~~ ~ ~ ~ ` ~ ~ ~ ~, BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Pool, MPG-03A Sundry Number: 310-216 Dear Mr. Lopez: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of July, 2010. Encl. ~tEC~tV~D j~ STATE OF ALASKA V' ~~I'~ ALAS~IL AND GAS CONSERVATION COMMISSI JUL 1 9 201Q '- APPLICATION FOR SUNDRY APPROVAL 20 AAC 2s.2so f>~ska AID' $I Ga: C~-!s. CutrMmssian 1. Type of Request: Abandon ^ Plug for Redrill ^ Pertorate New Pool ^ Repair Well ^ Ch~~d Program ^ Suspend ^ Plug Pertorations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ ~ • Other: MBE TREATMENT 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 204-2190 . 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21942-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ MPG-03A , 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-025518 ~ Ai>t,. ct2~ ~,'O~~ ~ MILNE POINT Field / SCHRADER BLUFF Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 6536 4525.1 6450 4473.82 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 110 13-3/8" 48# H-40 SURFACE 112 SURFACE 112 1740 750 Surface 1965 9-5/8" 47# L-80 SURFACE 1965 SURFACE 1854 6870 4760 Intermediate 6536 7" 26# L-80 SURFACE 6536 SURFACE 4525 7240 5410 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5942 - 5977 4182.55 - 4201.99 3-1/2" 9.2# L-80/TCII URFACI 6376 6010 - 6050 4220.42 - 4242.88 6157 - 6217 4303.54 - 4337.61 Packers and SSSV Tvoe: 7"X3.5" BAKER PREMIER PKR Packers and SSSV MD and TVD (ft): 5844 4128 7"X3.5" BAKER PREMIER PKR 5987 4208 7"X3.5" BAKER PREMIER PKR 6102 4272 7"X3.5" BAKER PREMIER PKR 6250 4357 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/27/2010 Oil ^ Gas ^ WDSPL ^ Suspended ^ 16. Verbal Approval: Date: WINJ ^~ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact KEITH LOPEZ Printed Name ITH LOPEZ Title WELLS & SURFACE ENGINEER KE Phone Date Signature ~- ~ ~1~'0 ~, 564-5718 7/16/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY witness Sund Number: ~ ~ ~ "~Q~~~ diti ns of a roval: Notif Commission so that a re resentative ma C ry y y on o pp p Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: APPROVED BY Approved by: OMMISSIONER THE COMMISSION Date: ~r~ i~ -. ~._.. :~ D ~ l ~ j1y RBDMS 2 n (~ n' Form 10-403 Revised 1/2010 O K' V ~'\1 ~ ~ Submit in Duplicate • by • To: Mark O'Malley/Nathan Leonard Date: July 13, 2010 MPU Well Operations Supervisor From: Keith Lopez, MPU Schrader Pad Engineer 907-564-5718 Subject: MPG-03A MBE Treatment Step Unit Operation 1 S Set dumm valves in tubin mandrels to isolate zone for treatment 2 S Set retrievable lu in tubin to rotect lower mandrels 3 O Shut in all offset roducers. Bullhead water into MPG-03. 4 O Bullhead treatment down MPG-03A. Keep well and offset producers and injectors shut in for minimum of 2 days and flow producers to a tank before returnin to roduction. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid . gel. Measure of success 1. Treatments are fully displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is seen. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. PROCEDURE Stage 1. Prep Well 1. Dummy off GLM's and put flow sleeve in GLM across from treatment interval. 2. Set retrievable plug below treatment GLM to protect lower mandrels. Stage 2. Injection Test 3. RU, hold pre-job safety meeting, PT surface lines 4. Ensure offset producers are SI. 5. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 6. Contact Engineering to discuss the injection pressure/rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate/pressure continue with remainder of program. • Stage 3. Treatment 7. Ensure offset producers are offline 8. Pump produced water pre-flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 9. Pump produced water pre-flush followed by high volume gel treatment and diesel over flush. 10. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 11. Rig down all equipment and hold post job assessment meeting to capture learnings to be incorporated into future jobs. 12. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. • 9 °,~"' d7?~. -50 B~~ 20.31 :.M~1t ~ FdA Tag Sd°3' - `~73' 11r1tx,Ld LE2 Ff:JI~12 =!'dGlOi~U 8i°d ~ ~ 1~' 12'~[~+3A ND~ 9~tt 1-E 3.~ HES }c-t«ippdie ;2.81!3' Fkg.# v 11' ' 3.5' x 1.5' C,31t~a h16AG Gltll t.1 $' 3~a' HEti 3C-hit~le ~ 813' ~kg j ~.~~'~~ r ~xn ~.~ 3~r ~Ye~mg~y~saPa~ys.d ~ u, ~J x j.~ zL.r lf+lii'T~~~ VL9 ~.~?i~a; T' x 3.4' Bier der Fucker 5,€~B t' $.5' x f.R3 C31P1C[b iwlAd~ti"~ GL1.1 $i.l`! ~~• ~:$° 7C 1. ~' C.~1PY?y7 NFa~ Ilk' ~.~"~~ I 7' x 3.~' 3.31t~ ; t i~rces 6,1 ~~' 3.5'x1~~ C3R7LtiG1u1FJfC~i."~GLttii .1~k3° 3, 4' x 1.5 v~TtCa-11f'-.4~ GL.h1 ~, ~ ~ 4` ~' x 3.~' Bier ~-3 FtY B,~~D' 3."x 1.4' fl~t't~Ra 8.;~i5' 3 m' x 1" C~1-C,: ~lR.tG iGLM f~,;33~6' 3.S HEM }~ ~~:A~3' P"T9.? 8r~$r+#' 2.75' °iC~ id 3.v°1rVLErta ~5~~~''', r' F181itAP4oI'1 F4Q3! ~ ~~~• 7' ~i~it~tul filk'~ bit Egg' SP EJ4PLC~RATI~7!IV Page 1 of 1 Schwartz, Guy L (DOA) From: Lopez, Keith [lopek3@BP.com] Sent: Monday, July 19, 2010 5:33 PM To: Schwartz, Guy L (DOA) Subject: RE: MPG-03a MBE Treatment (PTD 204-219) Sorry about that Guy. The MBE is in the OA zone so we will be pumping the treatment thru the mandrel at 6128'. We plan to set the retrievable plug at 6164' to protect the lower mandrels. This plug is intended to be temporary and pulled post treatment and after an evaluation period. Let me know if you need further info. Keith Lopez Wells & Subsurface Engineer Milne Point -Alaska BP Exploration Alaska, Inc. Office (907)-564-5718 Cell (907)-903-5432 _ ,. From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, July 19, 2010 4:02 PM To: Lopez, Keith Subject: MPG-03a MBE Treatment (PTD 204-219) Keith, Can you fill me in a bit more on what you are doing on this well. Which zone are you targeting for the MBE treatment? Where is the Bridge plug being set? I know this is may be proprietary technology but more detail is needed. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 7/20/2010 1VIEli~1®RANI®UIVi • TO: Jim Regg ,~ P.I. Supervisor I~ ~~/`~ i~i ZI ~~~ ,\ f FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, .lanuary 07, 2009 StiBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC G-03 A MILNE PT L'NIT SB G-03A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.L Suprv y ~~ Comm Well Name: MILNE PT UNIT SB G-03A API Well Number: 5 0-029-2 1 942-0 1-00 Inspector Name: Chuck Scheve Insp Num: mitCS090 1 0 70648 30 Permit Number: 2o4-2I9-o ~~ Inspection Date: 1/6/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ G-o3A Type Inj. ~ W TVD 41?8 IAA o ~ aooo ~ I9zo ~ i9oo 4 I9~ ~--- SPT - 1500 ~ --- - _ --- P.T. ~ - ;TypeTest Test psi j OA ~ zzo ~ aao _,' aso aso ----- ~ --- r - - - - ---- Interval aYRTST p~F P ~ Tubmg! Isoo ~soo isoo >>oo ---- -- --- ------ --- L- NOtes: Pretest pressures observed and found stable. Wednesday, January 07, 2009' Page 1 of 1 • • MICROFILMED 03101 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1l.aserFiche~CWrPgs_InseitslMicrofilm Marker.doc '> J~ ~7 DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Permit to Drill 2042190 Well Name/No. MILNE PT UNIT SB G-03A Operator BP EXPLORATION (ALASKA) INC 1p~J.. 1'1 INevl L~'I API No. 50-029-21942-01-00 MD 6536 TVD 4525 Completion Date 12/5/2004 Completion Status 1WINJ Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Data Type þD ~/ tJÉD D ~ ~.. Electr Digital Dataset Med/Frmt Number D Asc Name Interval Start Stop Log Log Run Interval OH/ . Scale Media No Start Stop CH Received Comments 1903 6536 12/21/2004 IIFR 1903 6536 12/21/2004 IIFR 1903 6536 12/21/2004 MWD 1903 6536 12/21/2004 MWD 5 Blu 2000 6440 Case CEMENT MAP & IMAGE LOG, SLIM CEMENT MAPPING TOOL 5 Blu 5900 6340 6/21/2005 Injection profi le/press/tem p/ ccl/g rli Is 1960 6499 Open 6/10/2005 MWD/GR/EWR4/ROP 1960 6499 Open 6/10/2005 MWD/GRlEWR4/ROP 1964 6536 Open 2/22/2006 ROP DGR EWR plus Graphics 5 Blu 5770 6300 Case 10/10/2006 Injection Profile, Pres, GR, . CCL, TEMP, ILS, SPIN, 9- Aug-2006 w/graphics Sample Set Sent Received Number Comments Asc Name Directional Survey Directional Survey Directional Survey Directional Survey Cement Evaluation ~g Injection Profile /ÊÔ D Tap 13165 I nd u ction/Resistivity .4 13165 LIS Verification .......eD C Lis 13519 I nd uction/Resistivity ~ 14168 Injection Profile Well Cores/Samples Information: Permit to Drill 2042190 MD 6536 TVD 4525 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Analysis Received? "'¥-f.N- Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Well Name/No. MILNE PT UNIT 5B G-03A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21942-01-00 Completion Date 12/5/2004 Completion Status 1WINJ Daily History Received? Formation Tops p-O Current Status 1WINJ &N (J/N Date: UIC Y >J~ ~? . . (~i~~ 6 --'..-.-_..--.-~.---.-~-. ._----, ,¡ . . , . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 1 00 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/ Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowtedge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907] 245-8951 1) 2) 3) 4) 5) 6) 7) 1 BL / EDE Disk MPU G - 03ai Injection Profile 9-Aug-06 Signed: , I ¡1 Þ II t _.~{\_--- fJh íl~&:) H U ,~ ;1/7 Cl,fÆ (1/ I( ~ Print Name: PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 w. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : "').S,,\:' :;', ::'èè.2:="'7:¿;'n~'¡;CR''.,: 2.:' :;0:: WEBSITE: _-.'0,,' ). (J" -- ;U Cf UIê :Jo 4 - i SD +t ¡:-//(o7S C'''OO _ ?DSA.i'\iC-2006'Z _ Vvord\Distnbutlon\Transmlttal_ She~ts\Transrrut_ Original.doc · . WELL LOG TRANSMITTAL rQ04.., ~ 1°1 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7'h Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 I 35/q RE: MWD Fonnation Evaluation Logs MPG-03A The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPG-03A LAS Data & Digital Log Images: 50-029-21942-01 1 CD Rom ~ (~19'~/00 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg V. 0 {o . P.I. Supervisor f....eft Z 2'410'£' DATE: Monday, February 07, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC G-03A MILNE PT UNIT SB G-03A FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv,,-rBf--- Comm NON-CONFIDENTIAL Well Name: MILNE PT UNIT SB G-03A Insp Num: mitJJ050206203922 Rei Insp Num: API Well Number: 50-029-21942-01-00 Permit Number: 204-219-0 Inspector Name: Jeff Jones Inspection Date: 1/3112005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. i i I I IA Well ! G-03A !Type Inj. i S TVD 4128 1240 2500 2430 2420 P.T. i 2042190 !TypeTest I SPT Test psi 1032 i OA 100 190 140 140 I Interval !NIT AL P/F P Tubing 1650 1650 1650 1650 Notes: 1.1 BBL diesel pumped. 1 well house inspected; no exceptions noted. Monday, February 07, 2005 Page 1 of 1 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Milne Point Unit I G-Pad 01/31/05 John Cubbon Jeff Jones Packer Depth Pretest weIlIMPG-03A J Type Inj. Is TVD 1 4,128' TUbing 1,6501 P .T.D. 2042190 . Type test P Test psi 1,500 Casing 1,240 Notes: Initial 4-year AOGCC witnessed MITIA. Witnessed by Jeff Jones of the AOGCC. Initial 15 Min. 30 Min. 1,6501 1,6501 1,650lnterval 2,500 2,430 2,440 PIF I P weill I Type Inj. I I TVD I I TUbingl Ilnterval P.T.D. Type test Test psi Casing PIF Notes: weill Type ,nj'l I TVD I TUbing II nterval P.T.D. Type test Test psi Casing PIF Notes: weill Type Inj. I TVD 1 I TUbing Ilntervall P.T.D. Type test Test psi Casing PIF Notes: weill Type Inj. I TVD I I TUb~ng I II ntervall P.T.D. Type test Test psi Casing PIF Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 MIT MPU G-03A MITIA 01-31-05.xls I, 'I. _ STATE OF ALASKA __ ALAS~L AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Aevi.ion:; 02lO9lS:stårt.ffijèdtðtf' 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ !HI WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1754' NSL, 3361' WEL, SEC, 27, T13N, R1OE, UM Top of Productive Horizon: 3495' NSL, 148' WEL, SEC. 27, T13N, R1OE, UM Total Depth: 3736' NSL, 4999' WEL, SEC. 26, T13N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 557244 y- 6014190 Zone- ASP4 TPI: x- 560440 y- 6015956 Zone- ASP4 Total Depth: x- 560S67 y- 6016200 Zone- ASP4 -------------- 18. Directional Survey 0 Yes !HI No 21. Logs Run: MWD , GR , RES, IFRlCASANDRA , SCMT 22. One Other 5. Date Camp., Susp., or Aband. 12/5/2004 6. Date Spudded 11114/2004 7. Date T.D. Reached 11/15/2004 8. KB Elevation (ft): 63.10' 9. Plug Back Depth (MD+ TVD) 6450' + 4474' 10. Total Depth (MD+TVD) 6536' + 4525' 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/ A MSL WT. PER FT. 48# 47# 26# CASING, LINER AND CEMENTING RECORD SETrlNGÐEP11HAO SEmNG DEPTHTVO BoTTOM lOP BoTToM 110' Surface 110' 1965' Surface 1854' 6536' Surface 4525' CASING SIZE 13-3/8" 9-5/S" 7" H-40 L-SO L-SO Surface Surface Surface 23. Perforations oRen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Gun Diameter, 5 SPF MD TVD MD TVD 5942' - 5977' 4183' - 4202' 6010' - 6050' 4220' - 4243' 6157' - 6217' 4304' - 4338' 6275' - 6317' 4371' -4395' 26. Date First Production: 01/25/05 Date of Test Hours Tested PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 24-HoUR RATE 1b. Well Class: o Development 0 Exploratory o Stratigraphic !HI Service 12. Permit to Drill Number 204-219 13. API Number 50- 029-21942-01-00 14. Well Name and Number: MPG-03Ai 15. Field / Pool(s): Milne Point Unit / Schrader Bluff Ft Ft 16. Property Designation: ADL 025518 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) 30" Arctic Set to Surface (Approx.) 12-1/4" 181 Bbls Perm 'E', 138 Bbls Class 'G' 8-112" 68 Bbls Class 'G' 24. PACKER SET (MD) 5844',5987'.6102',6250' SIZE 3-1/2",9.2#, L-80fTCII 25. DEPTH SET (MD) 6376' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection OIL-BBL GAs-McF WATER-BBL CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas o~ª,~~L(ª1tªçt!separate sheet, if necessary). Submit core chips; if none, state "none". ~ COMPLm~j ¡ RBDMS BFL F EB 1 7 2005 ~ Dif!'fí t L ,\ .~.' Ul:"..· ¡·F'CD ¡ w= ¡" ¡ ,~ !. \!..<-~~~, ~;~,,,~J OIL -BBL 27. None Form 10-407 Revised 12/2003 GAs-McF WATER-BBL CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) ~F · "'\ 28. GEOLOGIC MARKER. 29. .ORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD SBF2-NA SBF21 SBF24-MF SBF1-NB SBF12 SBE4-NC SBE41 SBE3-ND SBE2-NE SBE1-NF TSBD-OA TSBC TSBB-OB SBA5 5870' 5890' 5922' 5935' 5969' 5989' 5996' 6003' 6013' 6090' 6145' 6210' 6267' 6315' 4143' 4154' 4171' 4179' 4198' 4209' 4213' 4217' 4222' 4265' 4297' 4334' 4366' 4394' None 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~ ~ Sondr~man JZ)V'ç~ À p~ MPG-03Ai 204-219 Well Number Title Technical Assistant Date 02 -(jf-o t) Permit No. I Approval No. INSTRUCTIONS Prepared By NameINumber: Drilling Engineer: Sondra Stewman, 564-4750 Walter Quay, 564-4178 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only - .. STATE OF ALASKA __ ALAS~L AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEI\/ED JAN 0 G 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 181 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1754' NSL, 3361' WEL, SEC, 27, T13N, R10E, UM Top of Productive Horizon: 3495' NSL, 148' WEL, SEC. 27, T13N, R10E, UM Total Depth: 3736' NSL, 4999' WEL, SEC. 26, T13N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 557244 y- 6014190 Zone- ASP4 TPI: x- 560440 y- 6015956 Zone- ASP4 Total Depth: x- 560867 y- 6016200 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD , GR , RES, IFRlCASANDRA , SCMT 22. One Other 5. Date Comp., Susp., or Aband. 12/5/2004 6. Date Spudded 11/14/2004 7. Date T.D. Reached 11/15/2004 .; 8. KB Elevation (ft): 63.10' 9. Plug Back Depth (MD+ TVD) 6450' + 4474' 10. Total Depth (MD+TVD) 6536' + 4525' 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL CASING SIZE 13-3/8" 9-5/8" 7" GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTINGDI':PTH MD SET1"lNG DeÞTHTVD HO!.E lOP BOTTOM Top BOTTOM SIZE Surface 110' Surface 110' 30" Surface 1965' Surface 1854' 12-1/4" Surface 6536' Surface 4525' 8-1/2" WT. PER FT. 48# 47# 26# 23. Perforations op'en to Production (MD + TVD of Top- and Bottom Interval, Size and Number; if none, state 'none"): 4-1/2" Gun Diameter, 5 SPF MD TVD MD TVD 5942' - 5977' 4183' - 4202' 6010' - 6050' 4220' - 4243' 6157' - 6217' 4304' - 4338' 6275' - 6317' 4371' -4395' 24. SIZE 3-1/2", 9.2#, L-801TCII 1b.W~¡~I~~ Ga~ C;'¡HlWlš:.¡í( n o DevelopmerÎlm:Dqðratory o Stratigraphic 181 Service 12. Permit to Drill Number 204-219 13. API Number 50-029-21942-01-00 14. Well Name and Number: MPG-03A 15. Field I pool(s): Milne Point Unit / Schrader Bluff Ft 16. Property Designation: Ft ADL 025518 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) "7"h;".d~ 196<1' #/1> ~ / <95:</1 TV Þ /, "'J,'ðS;- Arctic Set to Surface (Approx.) 181 Bbls Perm 'E', 138 Bbls Class 'G' 68 Bbls Class 'G' TUBING · Re:cQF{O DEPTH SET (MD) 6376' PACKER SET (MD) 5844', 5987", 6102', 6250' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-BBl GAs-McF WATER-BBl 26. Date First Production: Not On Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Oll-Bsl GAs-McF WATER-BBl None RBDMS 8Fl JAN 0 7 2005 ORIGINAl CONTINUED ON REVERSE SIDE Form 10-407 Revised 12/2003 CHOKE SIZE I GAs-all RATIO all GRAVITY-API (CORR) &-;. I 28. .. GEOLOGIC MARKER. 29. .ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". SBF2-NA SBF21 SBF24-MF SBF1-NB SBF12 SBE4-NC SBE41 SBE3-ND SBE2-NE SBE1-NF TSBD-OA TSBC TSBB-OB SBA5 5870' 5890' 5922' 5935' 5969' 5989' 5996' 6003' 6013' 6090' 6145' 6210' 6267' 6315' 4143' 4154' 4171' 4179' 4198' 4209' 4213' 4217' 4222' 4265' 4297' 4334' 4366' 4394' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and a Leak-Off Test Summary. 31. I hereby certify that the fore Signed Sondr( Stewman MPG-03A Well Number Title Technical Assistant Date ~ {J ( -CY5-C~ 204-219 Permit No. I 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. Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Walter Quay, 564-4178 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only .. Tree:Cameron 3 1/8" .. Wellhead: WKM 11" X ~ Ini hanger wI NSCT T & B thread and 3.5" 'H' BPV profile 133/8" 48#, H-40 ~' ..tiQI.E.: 1" casing is hung off on emergency slips. 95/8" 47#, L-80 BTC I 2931' I .. ..tiQI.E.: Well was side tracked out of the 95/8" casing with a whipstock set (1964'- 1981 ') on top of a cement retainer set at 1981 '. Window is cut from 1965' - 1981'. KOP @ 800' Max. hole angle = 65° @ 5526' X Hole angle thru' perfs = 61° MPG-03i Short Joint wI RA Tag I 5853' - 5873' I _11.::,,11!:J::. 3.5", 9.2 ppf, L-80 TC-II Tbg. (cap. = 0.0087 bpf, drift = 2.867") 7" 26#, L-80, BTC-MOD Casing (drift ID = 6.151, cap.= .0383 bpf) Peñoration Summary Size Spf Interval (TVD) NC & NB Sands 4.5 5 5,942' - 5,977' NE Sands 4.5 5 6,010' - 6,050' OA Sands 4.5 5 6,151' - 6217' OB Sands 4.5 5 6,275' - 6,317' 4.5" 4505 Powerjet, HSO 5spf chg. DATE 11/16/04 12/05/04 REV. BY COMMENTS Lee Hulme Side Tracked and Cased by Doyon 14 MOO Completion 4-ES ori. Elev. = 32.45 (Doyon-14) Orig. RT-LDS Elev. = 31.60' (Doyon-14 3.5" HES X-Nipple (2.813" pkg.) 511' 3.5" x 1.5" Camco MMG GLM I 2,118' I 3.5" HES X-Nipple (2.813" pkg.) I 5,824' I 7" x 3.5" Baker Premier Packer I 5,844' I 3.5" x 1.5" Camco MMG-W GLM I 5,870' I 3.5" x 1.5" Cameo MMG GLM 5,927' 7" x 3.5" Baker Premier Packer 5,987' 3.5" x 1.5" Camco MMG-W GLM 6,013' 3.5" x 1.5" Camco MMG GLM 6,042' 7" x 3.5" Baker Premier Packer I 6,102' 3.5" x 1.5" Cameo MMG-W GLM I 6,128' 3.5" x 1.5" Camco MMG GLM 6,188' 7" x 3.5" Baker S-3 Packer 6,250' 3.5" x 1.5" Camco MMG-W GLM 6,275' 3.5" x 1.5" Camco MMG GLM 6,336' 3.5" HES XN-Nipple (2.813" pkg.) I 2.750" No-Go ID I 3.5" WLEG 6,364' 6,376' 7" Halliburton Float Collar 7" Halliburton float shoe 6450' 6536' MILNE POINT UNIT WELL No.: MPG-03i API: 50-029-21942-01-00 BP EXPLORATION (AK) · legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 ¿ PlUG+ABANDON NABORS ALASKA DRilLING I NABORS 4ES Start: 9/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 8/29/1989 End: 9/26/2004 9/17/2004 01 :00 - 07:00 6.00 MOB P PRE Move rig & rig components from MP H-07 to MP G-03. Raise and scope Derrick. Rig up lines. Accept rig at 07:00 hrs, 9/17/2004. 07:00 - 08:00 1.00 KILL P DECOMP PJSM. Rig up lines to wellhead & tiger tank. Take on 9.3 ppg 120 deg brine to pits. Pull BPV. Tubing & IIA = 0 psi. OIA = 0 psi. 08:00 - 08:30 I 0.50 KILL P DECOMP Pre kill safety meeting wI overview of well plan scope. I Emphasis on fluid & pressure monitoring. i 08:30 - 10:30 2.00 KILL P DECOMP Bring on pump @ 2 bpm 1200 psi, pumping 9.3 ppg heated brine down tubing, taking returns thru choke to tiger tank. Bring rate up to 4 bpm /1100 psi. No gas. Pump 200 bbls & monitor well, well stable. 10:30 - 11 :30 1.00 I WHSUR P DECOMP PJSM. Set 2 way check & test from below @ 1500 psi, OK. Rig I down & blow down lines. 11 :30 - 13:00 1.50 WHSUR P DECOMP Bleed void & nipple down tree. Wire brush & inspect threads on tubing hanger. Threads not in real good shape. Opt to spear hanger & order out double spear assembly. 13:00 - 14:30 1.50 BOPSUF P DECOMP PJSM. NIU 135/8" x 5M BOPE. 14:30 - 16:00 1.50· BOPSUPP DECOMP PJSM. Commence wI full test on BOPE. AOGCC rep John Crisp witnessing test. Gland nuts on lock down screws leaking, call out wellhead man & continue testing choke valves. 16:00 - 17:30 1.50 BOPSUP P DECOMP Suck out stack. Change packings on Lock-Down Screws. 17:30 - 21 :00 3.50 BOPSUPP DECOMP Resume testing BOPE; RIU to test Kelly, set back down. All tests OK. 21 :00 - 21 :30 0.50 PULL P DECOMP PJSM. RID test lines. 21 :30 - 22:00 0.50 PULL P DECOMP PIU landing joint, XO and MIU to BOT 2-7/8" spear, RIH to hanger and set it. 22:00 - 22:30 0.50 PULL P DECOMP Pull slowly to 46K and hanger came free, wI 4-5 "bobbles" on weight indicator as the hanger came to the floor with 32 to 35K. 22:30 - 23:00 0.50 PULL P DECOMP Breakout and UD landing joint, BOT spear, and XOs. 23:00 - 00:00 1.00 PULL P DECOMP POH wI and UD 2-7/8" tubing. 9/18/2004 00:00 - 03:30 3.50 PULL P DECOMP POH and UD 2-7/8" tubing. Recovered hanger wI 2' pup; 155 joints of 2-7/8", EUE, 8rd tubing; 3-pups: 12.12', 10.11',2.13'; and the Locator Seal assy wI 6 seals intact. 03:30 - 05:00 1.50 CLEAN P DECOMP Clear and clean rig floor. RIU 3-1/2" DP handling equipment. 05:00 - 06:00 1.00 CLEAN P ABAN MIU BHA #2: 6-1/8" Bit, 7" Casing Scraper, 2ea Boot Baskets, Bit Sub, Bumper Sub, Oil Jar, 9 ea 4-3/4" DCs. 06:00 - 06:30 0.50 CLEAN P ABAN Service rig. 06:30 - 07:00 0.50 CLEAN P ABAN Finish making up clean out BHA. 07:00 - 09:00 2.00 CLEAN P ABAN RIH wI clean out BHA on 3 1/2" DP, 1 x 1. 09:00 - 10:00 1.00· CLEAN P ABAN PJSM. Slip & Cut drilling line. 10:00 - 12:30 2.50 CLEAN P ABAN Continue to pick up 31/2" DP & RIH wI clean out BHA. Tag Baker SC-1 L Pkr @ 4939' DPM, l' in on jt #147. 82K up wt, 56K down. 12:30 - 14:00 1 .50 CLEAN P ABAN PJSM. Line up & circulate 40 bbls Hi Vis sweep around @ 5 bpm I 900 psi. No significant amount of solids or sand recovered when sweep came back. Well stable. 14:00 - 16:00 2.00 CLEAN P ABAN PJSM. POOH wI clean out BHA. 16:00 - 16:30 0.50 CLEAN P ABAN UD clean out BHA. 16:30 - 17:00 0.50 CLEAN P ABAN PJSM. Fill hole & close blind rams. Establish injection rate of 1/2 bpm @ 130 psi. 17:00 - 18:00 1.00 PXA P ABAN PJSM. Pick up Halliburton 7" x 26-29# EZSV Cement Retainer. Printed: 11/22/2004 10:18:54 AM . Ope . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 8/29/1989 End: 9/26/2004 9/18/2004 18:00 - 21 :30 3.50 PXA P ABAN RIH wI EZSV to set at -4900'. 21 :30 - 22:30 1.00 PXA P ABAN Set EZSV @ 4899'. Pump into formation 3 BPM @ 1000 psi. Unsting from EZSV and establish circulation up annulus--good. Sting back into EZSV. RIU Schlumberger equip, Vac and fresh water trucks. Pump Pit 1 to TT. 22:30 - 23:00 0.50 PXA P ABAN PJSM with Schlumberger, Peak, Halliburton, Nabors Crew, Tour Pusher and Co Man, to discuss safety performance and job procedures. 23:00 - 00:00 1.00 PXA P ABAN Pump 5 Bbls and pressure test line to 4000 psi. Check all connections. Pump 48 Bbls class G cement, displace wI 24 Bbls seawater to get 38 Bbls under EZSV. Unsting from EZSV, displace remaining cement on top of EZSV, (10 bbls). 9/19/2004 00:00 - 02:00 2.00 PXA P ABAN POH and UD DP to 4700', reverse circulate DP clean and swap 9.3 ppg brine with 9.8 ppg brine. 02:00 - 04:00 2.00 PXA P ABAN POH and UD 1500', SIB 34 stands. 04:00 - 04:30 0.50 PXA P ABAN PT cement plug to 1500 psi and record for 30 minutes. Bled 100 psi in 1st 15 min, 50 psi in 2nd. Will retest prior to setting bridge plug. 04:30 - 05:00 0.50 PXA P ABAN M/U EZSV Bridge Plug on 3-1/2" DP. 05:00 - 07:30 2.50 PXA P ABAN RIH wI EZSV B/P. 101 jts total. P/U 10' pup & M/U head pin. 07:30 - 08:30 1.00 PXA P ABAN Close pipe rams & pressure test 7" from surface to estimated top of cement @ 4700' (+ -) @ 1500 psi 130 minutes, charted. Good test. Witnessing of setting cement plugs & subsequent pressure tests waived by AOGCC rep John Crisp. 08:30 - 09:30 1.00 PXA P ABAN PJSM. Up wt = 46K, Down wt = 41 K. Circulate 15 bbls @ 3 bpm 1275 psi. Shut down pump. Pick up to up wt. WI Bridge PLug @ 3201' DPM, rotate to the right (40) turns. Pick up to 65K, wait a few minutes, up to 80K, wait a few more & pull to 93K, sheared OK. Rotate to the right (30) turns. RBIH & tag bridge plug @ 3201'. 09:30 - 10:30 1.00 PXA P ABAN PJSM. Close pipe rams & test 7" from surface to top of bridge plug @ 3201' @ 1500 psi 130 minutes, charted. Good test. O/A monitored during test, no indication of flow or pressure. 10:30 - 12:00 1.50 PXA P ABAN PJSM. POOH w/3 1/2" DP & Halliburton running tool. 12:00 - 13:00 1.00 PXA P ABAN PJSM. UD Halliburton Running Tool, pull wear bushing & M/U Baker Multi-String Cutter & (9) 4 3/4" DCs. 13:00 - 14:00 1.00 PXA P ABAN RIH wI cutter BHA on 31/2" DP. (90 jts DP). 52K up wt, 43K down wt, 50K rotating wt. P/U kelly. 14:00 - 15:00 1.00 PXA P ABAN PJSM. Bring on pump @ 3 bpm, 550 psi. Gradually slack off & locate casing collar approximately 26' in on kelly @ 3160'. Shut down pump & pick up to 3150'. Kick in rotary table @ 80 rpm I 2200 Nibs torque. Bring on pump @ 3 bpm I 525 psi & commence cutting 7" casing. Torque oscillating between 2000 Nibs & 3000 Nibs, gradually increase pump rate & pressure during cutting operation to final rate of 6.1 bpm 11025 psi. Total cutting time = 50 minutes. Monitor O/A for pressure increase throughout operation, no increase. Shut down pump & rotary table & pick up 5'. Bring on pump @ 3114 bpm 1675 psi & slack off to cutting depth. See 200 psi decrease in pump pressure @ 3150', indicating cutting blades extending. Repeat. Good indication of successful cut. 15:00 - 16:30 1.50 PXA P ABAN Stand back kelly & POOH wI cutter assembly. Noted fluid loss rate increase when POOH. When OOH loss rate increased to Printed: 11/22/2004 10: 18:54 AM . . Oper Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 8/29/1989 End: 9/26/2004 9/19/2004 15:00 - 16:30 1.50 PXA P ABAN the point unable to keep hole full. Ordered out (2) loads seawater. 16:30 - 18:00 1.50 PXA P ABAN Break out and UD BHA #3. Clear and clean rig floor. R/U lines to circulate annulus and RIU lines to Tiger Tank. 18:00 - 19:00 1.00 PXA P ABAN Hook up HB&R to annulus to pump heated diesel. Try 3 times pressuring to 2000 psi, for total of 2.2 Bbls; stop pump, hold pressure, but no leak off. 19:00 - 21 :30 2.50 BOPSUP P ABAN Change out 3-1/2" x 5" rams to 7" rams and test. 21 :30 - 23:00 1.50 PXA P ABAN Fill 7" with 19 Bbls seawater. M/U 7" casing spear BHA #4: Spear Packoff Bullnose, Spear Packoff Packer Cup, 2 ea 5-3/4" Itco Spears wI 6.095" grapple, Extension Sub, Spear Stop Sub, Lubricated Bumper Sub. 23:00 - 00:00 1.00 PXA P ABAN RIH and engage 7" casing, Pull slowly to 170K, relax and pull to 180K. Repeat cycles up to 225K with no gains. observed stretch ... (21 ")... when overpulling to 225K. 9/20/2004 00:00 - 00:30 0.50 PXA P ABAN Set hanger back down, RILDS. Hook up HB&R and attempt to pump into annulus. No Joy. 00:30 - 02:00 1.50 PXA P ABAN Release, POH wI spear, add jars and accelerator. RBIH and engage spear in 7". 02:00 - 02:30 0.50 PXA N DPRB ABAN Work pipe and set off jars @ 175K several times with no positive results. Call engineer and discuss option to install retrievable BIP in order to circulate hot seawater to free pipe. 02:30 - 03:30 1.00 PXA N DPRB ABAN Break out and UD BHA #5. Order packer and running tool from Halliburton. 03:30 - 04:30 1.00 PXA N DPRB ABAN Clear and clean rig floor, wait on tools from Halliburton. H/U HB&R to heat seawater in pits for downhole circulation. 04:30 - 06:00 1.50 BOPSUF N DPRB ABAN PJSM. CIO P/Rams to 2 7/8" x 5" variables. Test same, OK. Pull test plug. 06:00 - 07:00 1.00 PXA N DPRB ABAN PJSM. PIU Halliburton 7" RTTS & M/U above (9) 4 3/4" DCs. 07:00 - 08:30 1.50 PXA N DPRB ABAN PJSM. Change of plan, opt to recut casing above 9 5/8" shoe. 08:30 - 09:30 1.00 PXA N DPRB ABAN PJSM. POOH w/3 1/2" DP & RTTS. 09:30 - 11 :00 1.50 PXA N DPRB ABAN PJSM. UD Halliburton RTTS. Pick up Baker Multi-String Cutter Assembly. 11 :00 - 12:00 1.00 PXA N DPRB ABAN RIH wI Baker Cutting Assembly, 77 jts 31/2" DP. Kelly Up. Establish parameters: 51 K Up wt, 42K down wt, 48K rotating wt. Rotating torque = 90 amps in 2nd gear or 1900 ftIlbs. Search for collar in vicinity of projected cutting area by picking up to 2740' & bringing on pump @ 3 bpm I 600 psi & gently slacking off, looking for blades to catch a connection & take weight. Slack off to 2755', no connection located. 12:00 - 13:00 1.00 PXA N DPRB ABAN PJSM. Pick up to 2750'. Engage rotary table & rotate @ 80 rpm. Bring on pump & gradually work rate up to 4112 bpm @ 1000 psi. See pressure drop off to 700 psi in just a few minutes, indicating cut made. Continue with cutting ops, bringing pump rate up to 6112 bpm @ 1000 psi to ensure a good cut. Total cutting time 45 minutes. Shut down pump & rotary table. Pick up a few feet & bring on pump @ 3112 bpm I 600 psi. Slowly slack off & observe pressure decrease of 250 psi @ 2750' DPM. Continue to slack off & observe 2-3K weight drop on indicator. Good indication of cut. 13:00 - 14:00 1.00 PXA N DPRB ABAN POOH w/3 1/2" DP & cutting assembly. 14:00 - 15:30 1.50 PXA P ABAN PJSM. Line up to pump & pump hot seawater down 7", taking returns to tiger tank. Pumping 4 bpm, seeing good returns Printed: 11/22/2004 10:18:54 AM · Ope Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 8/29/1989 End: 9/26/2004 9/20/2004 14:00 - 15:30 1.50 PXA P ABAN initially, but returns gradually trail off to less than 1 bpm. Line up & pump hot seawater down 9 5/8" x 7", taking returns up 7" to tiger tank @ 4 bpm 11100 psi. Note arctic pack coming back. Circulate 200 bbls total. 15:30 - 17:30 2.00 BOPSUF: P ABAN PJSM. Set test plug, RILDs. Change out pipe rams to 7" & test same, OK. Pull test plug. 17:30 -18:00 0.50 BOPSU1P ABAN PIU running tool and pull test plug. 18:00 - 19:30 1.50 BOPSU P ABAN M/U casing spear and engage casing, pull to 150K, then 175K. Make decision to POH and replace 4-3/4" DC wI 3-1/2" DP to be able to circulate and pull at the same time. 19:30 - 20:00 0.50 BOPSUP P ABAN POH, UD 1 jt 4-3/4" DC, P/U 1 jt 3-1/2" DP. Engage 7" wI spear, PIU to 175K, begin circ 150 F seawater, 3 M @ 500 psi and set brake. Wt dropped to 150K, pres dropped to 100 psi. PIU to 175K, circ and hold, for three times. Each time the wt fell off to 150K while pumping. Made no gain. Calculate free point wI 9" stretch and 84K overpull = -2050'. 20:00 - 23:30 3.50 BOPSUP N DPRB ABAN Re-align for rev circ for 2 ann vols of 70 Bbls ea. Discuss options with engineer. Conntinue rev circ for 4 additional volumes. Start at 5 BPM, but losses are 1 BPM, reduce to 3 BPM and losses average 2.8 Bbls/10 mins. 23:30 - 00:00 0.50 BOPSUP N DPRB ABAN Bleed down lines. Pull and work pipe to 175K and hold, 3 times, then to 225K and hold, 2 times. No gains. Stretch is 11.25" w/1 07K overpull, free pipe - 2220'. 9/21/2004 00:00 - 01 :00 1.00 BOPSUF N DPRB ABAN Make decision to cut pipe - 2000'. Breakout and UD Spear. I Wait on new Multi-string cutter from Baker. 01 :00 - 02:00 I 1.00 BOPSUP N DPRB ABAN Change out rams to 2-7/8" x 5". Take on 150 F C/wtr thru 02:00 - 02:30 I HB&R hot oiler. 0.50 BOPSUPN DPRB ABAN MIU new 7" BOT Multi-String casing cutter. 02:30 - 03:30 1.00 FISH N DPRB ABAN RIH wI new csg cutter BHA #8. 03:30 - 04:30 1.00 FISH N DPRB ABAN Locate lower collar and P/U to start cut. Start cut @ 90 RPM, bring pump up 90 SPM @ 600 psi to 103 SPM @ 1000 psi. See good pressure drop in 10 minutes and torque increase steadily to constant rate. Continue rotating for 20 minutes. SID pump, P/U slowly, then lower slowly to relocate cut twice. Cut made @ 1686'. 04:30 - 06:00 1.50 FISH N DPRB ABAN POH and SIB DP and DCs. 06:00 - 06:30 0.50 FISH N DPRB ABAN Lubricate & service rig. 06:30 - 08:30 2.00 BOPSUF N DPRB ABAN PJSM. Set test plug. CIO rams from 2 7/8" x 5" to 7". pt same @ 250/3500 psi, OK. Pull test plug. 08:30 - 09:30 1.00 FISH N DPRB ABAN PJSM. M/U double spear assembly, complete wI jars. M/U circulating head. 09:30 - 10:00 0.50 FISH N DPRB ABAN PJSM. RIH & latch fish. Verify able to pull free wI 50K up wt. 10:00 - 11 :00 1.00 FISH N DPRB ABAN PJSM. Line up & circulate @ 5 bpm I 350 psi once around to clear hole of residual oil I arctic pack. 100 bbls pumped. Rig up floor to pull 7" casing. 11 :00 - 12:00 1.00 FISH N DPRB ABAN PJSM. Pull 7" & packoff, mandrel hanger to floor. UD fishing assembly, pack off & mandrel hanger. 12:00 - 15:00 3.00 FISH N DPRB ABAN PJSM. POOH & UD (42) full jts & (1) 36.80" cut off jt. 15:00 - 18:00 3.00 BOPSUP N DPRB ABAN PJSM. Set test plug. CIO P/Rams from 7" to 2 7/8" x 5". Test same @ 250 I 3500 psi, OK. Drain stack. UD test plug. RID test equip. 18:00 - 19:30 1.50 FISH N DPRB ABAN MIU BHA to spear 7" csg as follows: Spear Bullnose, Spear Pack Off, XO, Spear wI 6.095" Grapple, Spear wI 6.095" Printed: 11/22/2004 10:18:54 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 8/29/1989 End: 9/26/2004 9/21/2004 18:00 - 19:30 1.50 FISH N DPRB ABAN Grapple, Extensiobn, Stop Sub, XO, Bumper Sub, Oil Jar, XO, 6 - 6 1/4" DCs, XO, Jar intensifier, XO. TL = 238.58' 19:30 - 20:30 1.00 FISH N DPRB ABAN RIH wI Spear Assy on 31/2" DP to 1886'. PIU kelly. Engauge fish wI spear. Top of stub @ 1687'. 20:30 - 22:00 1.50 FISH N DPRB ABAN P/U wt = 41 K, SIO wt = 41 K. Attempt to fish 7" casing. Jar on fish from 125k to 200 K. Attempt to circulate 3 BPM 600 to 1000 psi. No returns. 22:00 - 22:30 0.50 FISH N DPRB ABAN PIU to wI 125K & reverse circulate & heat well bore fluids to 95 deg. Pumped 115 bbls.. 3.4 BPM @ 300 psi. 22:30 - 00:00 1.50 FISH N DPRB ABAN Con't to to jar on fish.w/200K. Pump 1/2 BPM @ 120 psi. 9/22/2004 00:00 - 02:00 2.00 FISH N DPRB ABAN Con't to jar & work pipe. Fish not coming free. P/U wt = 41 K, SIO Wt = 41 K. Jarred wI 200K. no movement. 02:00 - 03:00 1.00 FISH iN DPRB ABAN POOH w/3 1/2" DP & Spearing Assy. Inspect derrick. Release I spear. Circulate oil out of BOP stack. Set back kelly. 03:00 - 03:30 0.50 FISH N DPRB ABAN POOH w/3 1/2" DP & spearring assy. 03:30 - 05:00 1.50 FISH N DPRB ABAN UD spear assy & 61/4" Dcs. 05:00 - 06:00 1.00 EVAL N DPRB ABAN PIU RTTS & drill collars. 06:00 - 06:30 0.50 EV AL N DPRB ABAN Lubricate & service rig. 06:30 - 07:30 1.00 EVAL N DPRB ABAN PJSM. RIH wI RTTS on 31/2" DP. 18 stands & (1) single. 41K down wt, 43K up wt. 07:30 - 08:00 0.50 EVAL N DPRB ABAN PJSM. Set RTTS in 7" casing @ 1732'. Verify by pass valve is closed. 08:00 - 08:30 0.50 EVAL N DPRB ABAN PJSM. Close annular preventor. Pump down 9 5/8" attempting to break circulation around 7" to cut @ 2750' & back up DP. Pressure up gradually to 3200 psi. Very little bleed off in 15 minutes, approximaterly 50 psi. Call Schlumberger to run USIT log. Bleed all pressure, open annular preventor, well stable. 08:30 - 09:30 1.00 EVAL N DPRB ABAN POOH w/31/2" DP. 09:30 - 10:30 1.00 EVAL N DPRB ABAN UD Halliburton RTTS & 4 3/4" DCs. 10:30 - 13:30 3.00 EVAL N DPRB ABAN Wait on Schlumberger & change out liners in mud pump to 5 1/2" in preparation for milling 7" casing. 13:30 - 15:00 1.50 EVAL N DPRB ABAN PJSM. Rig up Schlumberger E-Line. 15:00 - 18:00 3.00 EVAL N DPRB ABAN Run US IT log on E-Line. Log from 3150' to top of 7" @ 1687'. Log indicates top of cement @ 2294' . pipe appears to be free from 2200' up. plan to cut 3' below collar @ 2186'. (ELM) Logged from 3165' to 1687'. 18:00 - 19:00 1.00 EVAL N DPRB ABAN RID loggers & equip. 19:00 - 20:30 1.50 EVAL N DPRB ABAN Change out cutters & redress cutting tools. M/U BHA to cut 7" csg as follows: Multi-string Cutter, XO, String Stabilizer & 9 - 4 3/4" DCs. TL = 288.28'. 20:30 - 21 :30 1.00 EVAL N DPRB ABAN RIH wI cutting assy on 20 stds. of 31/2" DP. 21 :30 - 23:00 1.50 FISH N DPRB ABAN P/U kelly. Break circulation & locate collar @ 2191' (DPM). Space out cutter 3' below collar @ 2194' (DPM) Cut 7" casing. PIU Wt = 45K, SIO Wt = 41 K, Rot Wt = 45K. 90 RPMs, 3 1/2 BPM @ 1000 psi. Torq. 2K. lost 250 psi after 4 min. Con't to rotate & insure complete cut for 30 min. SID P/U 2'. Break circ & RIH 2' & verify cut. Positive indication. Set back kelly & blow down lines. 23:00 - 23:30 0.50 FISH N DPRB ABAN POOH wI drill string. 23:30 - 00:00 0.50 FISH N DPRB ABAN UD BHA & 4 3/4" DCs. 9/23/2004 00:00 - 00:30 0.50 FISH N DPRB ABAN Finish UD BHA & 4 3/4" DCs. 00:30 - 01 :30 1.00 FISH N DPRB ABAN Clear & clean rig floor. Printed: 11/22/2004 10:18:54AM · Legal Well Name: MPG-03 Common Well Name: MPG-03 Spud Date: 8/29/1989 Event Name: PLUG+ABANDON Start: 9/17/2004 End: 9/26/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/26/2004 Rig Name: NABORS 4ES Rig Number: NPT 9/23/2004 01 :30 - 02:30 1.00 FISH N DPRB ABAN M/U spear assy & P/U 6 - 6 1/4" DCs. 02:30 - 03:00 0.50 FISH N DPRB ABAN RIH wI spear assy on 31/2" DP 1687'. P/U 44K SIO 40K. 03:00 - 06:00 3.00 FISH N DPRB ABAN P/U kelly & engage spear into csg stub. Attempt to circ & pull csg. Having to jar. After 3rd lick casing started to move. Pump @ 2 BPM, 750 psi. No returns. SID pump & can't to jar. Casing moving 3-4" per lick. Jarring @ 200K. Pulled fish up hole approximately 15' - 16'. 06:00 - 17:00 11.00 FISH N DPRB ABAN Continue jarring. 300 -400 jar licks @ 200K total. Tried I bullheading I circulating past around outside of 7", no indication of much success. Pulled fish up hole total of 24' - 25' since latching up. believe turbulator(s) are giving us grief. Opt to recut @ 2005' (+ -). 17:00 - 18:30 1.50 FISH N DPRB ABAN Release spear from 7" casing. Inspect derrick. POOH wI Spear Assy. 18:30 - 19:30 1.00 FISH N DPRB ABAN UD Spear Assy & DCs. 19:30 - 20:30 1.00 FISH N DPRB ABAN Clear & clean rig floor. Adjust brakes. 20:30 - 22:00 1.50 FISH N DPRB ABAN M/U BHA to cut 7" casing. 22:00 - 22:30 0.50 FISH N DPRB ABAN RIH wI Cutting Assy. Top of 7" stub now @ 1665'. (22' high from jarring) 22:30 - 23:30 1.00 FISH N DPRB ABAN P/U kelly. Locate collar @ 1974'. Space out cutter to 1987'. P/U Wt = 40K, SIO Wt = 40K. Rot Wt = 40K. Cut 7" casing as follows: 90 RPMs, 3 1/2 BPM @ 1000 psi, Torq = 2K. Cut thru casing & pressure dropped 250 psi. Con't to rotate for I additional 30 min. PIU & SID pump. lower back down wI pump I on & verify casing cut. Ok. 23:30 - 00:00 0.50 FISH N DPRB IABAN Set back kelly & POOH wI cutting assy. 9/24/2004 00:00 - 00:30 0.50 FISH N DPRB ABAN Con't to POOH wI BHA & DP. 00:30 - 01 :30 1.00 FISH N DPRB ABAN UD 4 3/4" DCs & cutting BHA. 01 :30 - 02:00 0.50 FISH N DPRB ABAN M/U BHA & PIU 6 1/4" DCs to Fish cut casing. 02:00 - 02:30 0.50 FISH N DPRB ABAN RIH wI BHA to Spear casing. 02:30 - 03:00 0.50 FISH N DPRB ABAN Engage spear into casing & PIU w/15K over pull. Casing free. P/U 46K, SIO 44K. 03:00 - 05:00 2.00 FISH N DPRB ABAN Set back kelly & blow down lines. POOH wI fish. Have up to 30K overpull in spots. 05:00 - 07:00 2.00 FISH N DPRB ABAN PJSM. UD fishing assembly. Rig up to UD 7" casing. 07:00 - 09:00 2.00 FISH N DPRB ABAN PJSM. UD 7" casing & turbulators. Recovered total of 325.11' of 7" casing. Total recovered since onset of fishing ops = 2012'. 09:00 - 13:00 4.00 BOPSUPN DPRB ABAN PJSM. Conduct weekly BOPE test. Witnessing of test waived by AOGCC rep John Spalding. 13:00 - 14:00 1.00 FISH N DPRB ABAN PJSM. P/U 7" Multi-String Cutter Assembly & RIH on (20) stands DP. 14:00 - 16:00 2.00 FISH N DPRB ABAN PJSM. P/U kelly. 40K down wt, 43K up wt. Bring on pump @ 3 bpm 1600 psi & slack off slowly. Locate collar @ 2093'. Shut down pump & PIU 5'. Slack off to cutting depth of 2110', (25') in on kelly. Kick in rotary table @ 90 RPM & bring on pump @ 5 bpm 11000 psi. See indication of cut 3 1/2 minutes into operation. Continue to rotate for an extra 20 minutes @ 6 bpm I 650 psi to ensure good cut. 16:00 - 17:00 1.00 FISH N DPRB ABAN PJSM. POOH wI cutter assembly. 17:00 - 18:00 1.00 FISH N DPRB ABAN Clear & clean rig floor. Adjust brakes. 18:00 - 19:30 1.50 FISH N DPRB ABAN P/U 6 1/4" DCs & Spear Assy. 19:30 - 20:00 0.50 FISH N DPRB ABAN RIH wI fishing assy. Printed: 11/22/2004 10:18:54AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 PLUG+ABANDON NABORS ALASKA DRilLING I NABORS 4ES Start: 9/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 8/29/1989 End: 9/26/2004 9/24/2004 20:00 - 21 :00 1.00 FISH N DPRB ABAN P/U kelly. Attempt to engauge spear & work pipe. Spear bottoming out 12' high. Appears not to be entering 7" stub. Did see pressure increase. 21 :00 - 22:00 1.00 FISH N DPRB ABAN POOH wI Spear Assy. 22:00 - 23:30 1.50 FISH N DPRB ABAN No recovery. Cup above bull nose on spear is mushroomed out. Wire re-enforcement prevented spear from entering 7" stub. Remove cup & re-dress spear. Clean threads on DCs. 23:30 - 00:00 0.50 FISH N DPRB ABAN RIH wI re-dressed Spear Assy. 9/25/2004 00:00 - 01 :00 1.00 FISH N DPRB ABAN Finish RIH wI Spear Assy. PIU kelly. 01 :00 - 01 :30 0.50 FISH N DPRB ABAN Engauge casing stub @ 1978'. PIU & attempt to pull casing. Casing stuck. Jar on fish wI 200k. Fish moved up approx. 1'. Each jar lick moved less. Would not pull free. 01 :30 - 02:00 0.50 FISH N DPRB ABAN POOH wI spear Assy. 02:00 - 04:00 2.00 FISH N DPRB ABAN BIO & UD spear Assy. 04:00 - 05:00 1.00 PXA P ABAN MIU Scraper Assy. 05:00 - 06:00 1.00 PXA P ABAN RIH & scraper casing to top of casing stub. Tag top of 7" casing @ 1985'. 06:00 - 07:00 1.00 PXA P ABAN Reverse circulate bottoms up, returns clean. Service rig. 07:00 - 08:30 1.50 PXA P ABAN PJSM. POOH wI clean out assembly. 08:30 - 09:00 0.50 PXA P ABAN PJSM. MIU Halliburton 95/8" EZSV cemaent retainer & inspect same. 09:00 - 10:30 1.50 PXA P ABAN RIH wI EZSV on 31/2" DP. 62 jts total. 37K up wt, 35K down. 10:30 - 11 :30 1.00 PXA P ABAN PJSM. MIU 24' pup wI headpin & lightly tag 7" casing stub @ 1985'. P/U 3' & circulate @ 3 bpm 1250 psi, 15 bbls. WI top of retainer @ 1978' DPM, rotate to the right 35 turns. Pick up 20K over up wt to 57K, wait a minute, pick up another 15K to 72K, wait a minute & shear @ 92K. Rotate to the right 40 turns. Pressure test 9 5/8" casing to top of retainer, 2500 psi 110 minutes, OK. Stab into retainer & establish injection rate of 3 bpm /1100 psi. 11 :30 - 12:00 0.50 PXA P ABAN Held safety meeting wI cementers & truck drivers. 12:00 - 13:00 1.00 PXA P ABAN Rig up cement lines & test @ 3500 psi, OK. Pump 5 bbls water followed by 53 bbls 15.7 ppg Arctic Set 1 @ 2.5 bpm 1400- 500 psi average pressure. Displace wI seawater, (10 bbls). WI 2-3 bbls cement left in DP, unsting from retainer. 13:00 - 14:00 1.00 PXA P ABAN PJSM. Line up & reverse circulate @ 4 bpm 1400 psi, (2) DP volumes. 14:00 - 15:00 1.00 PXA P ABAN Clean pits, take on 9.8 ppg brine & reverse circulate hole to 9.8 ppg brine to 9.8 ppg returns, 160 bbls. 15:00 - 16:30 1.50 PXA P ABAN PJSM. Close pipe rams & rig up on lower annulus valve. Pressure test 9 5/8" from surface to top of retainer @ 1978' DPM @ 2000 psi I 30 minutes, charted. Good test. 16:30 - 20:00 3.50 PXA P ABAN POOH & LDDP. UD EZSV stinger. RIH wI remaining 9 stands & UD same. 20:00 - 21 :00 1.00 WHSUR P ABAN Install Pack off. RILDS. UD running tool. 21 :00 - 21 :30 0.50 PXA P ABAN RID DP tools & RIU tbg tools. Clear floor. 21 :30 - 23:00 1.50 WHSUR P ABAN P/U & RIH w/5 jts of 2 7/8" tbg. TL = 155'. M/U tbg hanger. Land hanger. RILDS. J/D landing jt. RID tbg tools. Install TWC. 23:00 - 00:00 1.00 BOPSUP P ABAN N/D BOPE. 9/26/2004 00:00 - 01 :00 1.00 BOPSUP P ABAN Finish N/D BOPE. 01 :00 - 02:30 1.50 WHSUR P ABAN NIU tree. Test to 5000 psi, OK. 02:30 - 03:00 0.50 WHSUR P ABAN Pull TWC. Install BPV. 03:00 - 03:30 0.50 WHSUR P ABAN R/U hot oilers. Test lines & pump 10 Bbls for diesel cap. 3/4 Printed: 11/22/2004 10:18:54 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/26/2004 MPG-03 MPG-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 8/29/1989 End: 9/26/2004 03:00 - 03:30 03:30 - 04:00 0.50 WHSUR P 0.50 WHSUR P BPM @ 100 psi. Secure well. Clean cellar. RELEASE RIG @ 0400 hrs. 9/26/2004 ABAN ABAN Printed: 11/22/2004 10:18:54 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 ~ MPG-03 DRILL+COMPLETE Start: 11/9/2004 Rig Release: Rig Number: Spud Date: 8/29/1989 End: 2/1/2004 11111/2004 20:30 - 00:00 3.50 MOB P PRE PJSM,Skid rig floor, Pulling off MPG-19i 11/12/2004 00:00 - 05:00 5.00 MOB P PRE PJSM - Move rig from well MPG-19 to MPG-03 - Spot over well 05:00 - 06:30 1.50 MOB P PRE PJSM - Skid rig foor from move position to drlg position - Build berm for rockwasher - spot rockwasher 06:30 - 08:00 1.50 MOB P ¡PRE PJSM, Rig up rig floor, Rig accept @ 00:30 hrs 11/12/2004, I Due to small pad and pad condition 08:00 - 09:30 1.50 MOB P PRE PJSM, Nipple down CIW tree 09:30 - 14:30 5.00 MOB P PRE PJSM,Nipple up BOPS, change out Choke spool to longer 'spool 14:30 - 15:30 1.00 MOB P PRE PJSM, Pickup landing jt, Verify no pressure on annulus, pull hanger to floor, lay down 5 jts 2 7/8 tubing 15:30 - 16:00 0.50 MOB P PRE Pull Tubing hanger to floor and lay down 5 jts 2 7/8 tubing 16:00 - 17:00 1.00 MOB P PRE Pull 7" csg hanger and lay down same 17:00 - 17:30 0.50 STWHIP P WEXIT Pick up Circ sub. Rih to 180', circ out diesel 17:30 - 19:30 2.00 STWHIP P WEXIT Rig up to test BOPS 19:30 - 23:30 4.00 STWHIP P WEXIT Test BOPS and manifold to 250-3500 psi 5 min. per test, Annulur 250-2500 psi 5 min. per test, The right to witness test was wavier by Chuck Scheve AOGCC 23:30 - 00:00 0.50 STWHIP P WEXIT Rig up to pick up pipe in mouse hole, standing in derrick 11/13/2004 00:00 - 00:30 0.50 STWHIP P WEXIT Pick up pipe in mouse hole, standing in derrick 00:30 - 01 :00 0.50 STWHIP P WEXIT Install wear ring 01 :00 - 01 :30 0.50 STWHIP P WEXIT Pickup BHA #1 8.5 mill assem. 01 :30 - 03:00 1.50 STWHIP P WEXIT Rih, picking up pipe from pipe shed to 1989' 03:00 - 04:00 1.00 STWHIP P WEXIT Circ and displace well with 9.0 LSND mud 04:00 - 04:30 0.50 STWHIP P WEXIT POH, lay down mills 04:30 - 09:30 5.00 STWHIP P WEXIT Picking up Whipstock BHA # 2, surface test MWD 09:30 - 10:00 0.50 STWHIP P WEXIT RIH to 1937' 10:00 - 10:30 0.50 STWHIP P WEXIT Orient and set whipstock 65 degrees to left of high side, top of stock 1964', shear off 10:30 - 16:30 6.00 STWHIP P WEXIT Milling window 1965 to to 1995' with 120 rpms, 450 gpm, 1000 psi,( top of window 1965' bottom window 1981') 16:30 - 18:00 1.50 STWHIP P WEXIT Circ, pump pill, work window 18:00 - 18:30 0.50 STWHIP P WEXIT FIT with 9.0 MW, 240 psi, 1854 TVD= 11.5 EMW 18:30 -19:00 0.50 DRILL P INT1 POH 19:00 - 21 :30 2.50 DRILL P INT1 Lay down 6" dc and mills 21 :30 - 22:30 1.00 DRILL P INT1 Clear floor, Flush out BOP stack 22:30 - 00:00 1.50 DRILL P INT1 i Picking up BHA # 3 11/14/2004 00:00 - 01 :00 1.00 DRILL P INT1 Finish picking up BHA #3, surface test MWD 01 :00 - 01 :30 0.50 DRILL P INT1 Service top drive 01 :30 - 02:00 0.50 DRILL P INT1 Trip in to 1950', orient to high side, slide thru window with out pump, no problem 02:00 - 18:00 16.00 DRILL P INT1 Drilling 1995' to 4533' with 500 gals min, 2720 psi, 90 rpms .~ 18:00 - 19:30 1.50 DRILL P INn Circ, Three bottoms up, with 90 rpms,500 gpm.,2700 psi 19:30 - 22:00 2.50 DRILL P INT1 Pumping out to window @ 1981', with full drilling rate., pull thru window with out pumping 22:00 - 23:00 1.00 DRILL P INT1 Circ bottoms up from @ 1854 23:00 - 00:00 1.00 DRILL P INT1 RIH to 4439', wash to bottom @ 4533' 11/15/2004 00:00 - 19:00 19.00 DRILL P INT1 Drilling 4533' to 6536'TD with 500 gals min, 2800 psi, 90 rpms, AST .73, ART 12.65, TQ 5K 19:00 - 21 :00 2.00 CASE P INT1 Circ three bottoms up with 90 rpms, 500 gpm, 2700 psi 21 :00 - 23:30 2.50 CASE P INT1 Pump out to 4000' with full drilling rate 23:30 - 00:00 0.50 CASE P INT1 Trip back to bottom, wash last stand to bottom 11/16/2004 00:00 - 02:00 2.00 CASE P INT1 Circ three bottoms up with 90 rpms, 500 gpm, 2700 psi Printed: 11/22/2004 10: 19: 15 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 DRILL+COMPLETE Start: 11/9/2004 Rig Release: Rig Number: Spud Date: 8/29/1989 End: 2/1/2004 11/16/2004 02:00 - 05:00 3.00 CASE P INT1 Pump out to 2047' with full drilling rate, pull thru window with out pumping to 1950' 05:00 - 06:00 1.00 CASE P INT1 Circ bottoms up from 1950' 06:00 - 06:30 0.50 CASE P INT1 Poh to BHA 06:30 - 08:30 2.00 CASE P INT1 Laying down HWDP and MWD, Motor 08:30 - 09:00 0.50 CASE P INT1 Service rig 09:00 - 10:00 1.00 CASE P INT1 Pull wear ring, change out top rams to 7", test door seals to 1500 psi 10:00 - 11 :00 1.00 CASE P INT1 PJSM, Rig up to run Csg 11 :00 - 14:00 3.00 CASE P INT1 Picking up 7" 26# L-80 But Csg to 1955' 14:00 - 15:00 1.00 CASE P INT1 Circ one csg volume @ 1955',170 gpm 300 psi 15:00 - 18:00 3.00 CASE P INT1 Picking up 7" 26# L-80 But Csg to 6500', total its run 158, shoe @ 6536, float 6449, maker jt 5853' 18:00 - 19:00 1.00 CASE P INT1 Pickup landing jt circ down with Franks to 6536', circ. one bottoms up, 212 gpm, 600 psi, P/U 210K, SIO 110 worked 20 ft. 19:00 - 19:30 0.50 CASE P INT1 Rig down franks tooll and rig up cement head 19:30 - 21 :30 2.00 CASE P INT1 Circ and reciprocate Csg with 212 gpm, 600 psi, working csg 20 ft., PJSM on cementing 21 :30 - 23:00 1.50 CEMT P INT1 Cement with Schlumberger, with 5 bbls water, test lines to 4,000 psi, 15 bbls CW-100, 30 bbls mud push 10.6, drop bottom plug, pump 68:IiBItJ"Cf8s8G, 328sx., 1.17 yield, 15.8#, Flush lines,Kicked out top plug with 20 bbls water, Displace with rig pump 5 bbls min., 227 bbls 9.7 mud, bump plug with 2000 psi, floats held,.,-_:,..~te csgthru outj()b., cement and displacment was pumped @ 5 bbls min. final pickup wt on Csg 185K, final S/O 85K 23:00 - 00:00 1.00 CASE P INT1 Pickup on Csg to 205K with no movement, slack back off to 85K, test csg for 30 min. to 3000 psi 11/17/2004 00:00 - 01 :00 1.00 CASE P INT1 Monitor well, Pull out #2 motor and replace, lay down cement head 01 :00 - 02:00 1.00 CASE P INT1 Flush stack, Nipple down 02:00 - 03:00 1.00 CASE P INT1 Pick up to 205K string wt. and set slips with 150K 03:00 - 04:30 1.50 CASE P INT1 Blow down Csg it. , cut off csg with csg cutter, install packoff, test to 4,300 psi 04:30 - 08:30 4.00 CASE P INT1 Nipple up, change top rams to 2 7/8 X 5, test rams and door seals 250-3500 psi 5 min. per test, install wear ring 08:30 - 09:00 0.50 CASE P INT1 Clear floor 09:00 - 12:00 3.00 CASE P INT1 Pickup 6 1/8 bit, boot basket, csg scraper, pick up 16 its drill pipe, trip in to 6449', float collar 6450' 12:00 - 14:30 2.50 CASE P INT1 Displace well with 200 bbls sea water, 35 bbl hi-vis pill, 355 bbls sea water, 215 bbls 9.6 brine 14:30 - 16:00 1.50 CASE P INT1 Cut and slip drilling line, service top drive 16:00 - 22:00 6.00 CASE P INT1 Laying down drill pipe, clear floor 22:00 - 22:30 0.50 CASE P INT1 Pull wear ring 22:30 - 23:00 0.50 RUNCOMP RUNCMP Rig up to pick up 3.5 tubing, PJSM 23:00 - 00:00 1.00 RUNCOMP RUNCMP Picking up, 3.5, 9.3# L-80, TCII, kill string 11/18/2004 00:00 - 02:00 2.00 RUNCOMP RUNCMP Picking up 3.5 9.3# L-80, TCII, kill string, total 63 its, WLEG 2064', Xnipple 2051', land tubing with P/U 67K, SIO 67K, Blocks 50K 02:00 - 02:30 0.50 RUNCOMP RUNCMP Test two way check to 1000 psi 02:30 - 03:30 1.00 RUNCOMP RUNCMP Nipple down Bops, change out saver sub on top drive 03:30 - 06:30 3.00 RUNCOMP RUNCMP Nipple up tubing adapter, and CIW 3 1/8 X 5,000 # tree, test Printed: 11/22/2004 10: 19: 15 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 DRILL+COMPLETE Start: 11/9/2004 Rig Release: Rig Number: 11/18/2004 03:30 - 06:30 06:30 - 11 :00 11 :00 - 12:00 Spud Date: 8/29/1989 End: 2/1/2004 RUNCMP adapter and shell test tree to 5,000 psi/ 10 min. RUNCMP Pull TWC, freeze protect 3.5 tubing and annulus with 61 bbls diesel, rig up on 7 X 9 5/8 annulus and freeze protect it with 60 bbls diesel, Install BPV RUNCMP Secure well and release rig @ 12:00 hrs 11/18/2004 3.00 RUNCOMP 4.50 RUNCOMP 1.00 RUNCOMP Printed: 11/22/2004 10:19:15 AM · port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 Þ. MPG-03 COMPLETION NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/3/2004 12/6/2004 Spud Date: 8/29/1989 End: 12/6/2004 12/312004 12:00 - 14:00 2.00 RIGU P RUNCMP Move Rig and Equipment from MPE-Pad to MPG-Pad. 14:00 - 15:30 1.50 RIGU P RUNCMP Lay Herculite and Rig Mats. Spot Sub Base over MPG-03Ai Well. Spot Rig Pits. 15:30 - 16:30 1.00 RIGU P RUNCMP Raise Derrick 16:30 - 17:00 0.50 RIGU P RUNCMP Spot Pipe Shed and Camp. 17:00 - 17:30 0.50 RIGU P RUNCMP Scope Derrick. 17:30 - 18:00 0.50 RIGU P RUNCMP Lay lines. Ready to take on Brine in Pits. Accept Rig at 18:00 hrs. 18:00 - 18:30 0.50 RIGU P RUNCMP Rig up Lines to Tree and Tiger Tank. Take on 9.6 Iblgal Brine in Pits. 18:30 - 19:00 0.50 WHSUR P RUNCMP Pick-up Lubricator and pull BPV. Lay down same. Tbg = 0 psi. Csg = 0 psi. 19:00 - 19:30 0.50 RUNCOMP RUNCMP Operations and PJSM with all. Test Lines to 3,500 psi. 19:30 - 20:30 1.00 RUNCOMP RUNCMP Circulate out Diesel Freeze Protect from -2,075' with 9.6 Iblgal Brine at 5 bpm. Monitor Well. 20:30 - 21 :30 1.00 WHSUR P RUNCMP Set and test TWC. Blow down Lines. 21 :30 - 22:30 1.00 WHSUR P RUNCMP Nipple down Tree. 22:30 - 00:00 1.50 BOPSUP P RUNCMP Nipple BOPE. 12/4/2004 00:00 - 03:30 3.50 BOPSUF P RUNCMP Test BOPE per BP/AOGCC requirements at 250/4,00 psi. Tested Annular at 250/3,500 psi. State's right to witness test waived by C. Sheve. 03:30 - 04:30 1.00 BOPSUF P RUNCMP Blow down Lines. Rig down Test Equipment. Pick-up Lubricator and pull TWC. Lay down same. 04:30 - 05:00 0.50 WHSUR P RUNCMP Pick-up Landing Joint. BOLDS. Pull Tubing Hanger to Floor. Lay down same. 05:00 - 06:00 1.00 RUNCOMP RUNCMP POOH with 3 1/2" TCII Kill String. 06:00 - 06:30 0.50 RUNCOMP RUNCMP Lube & service rig. 06:30 - 09:00 2.50 RUNCOMP RUNCMP Con't to POOH & UD 3 1/2" TCII tubing. 09:00 . 10:00 1.00 PERFOB P OTHCMP Set Wear Bushing. Clear & clean rig floor. RIU To RIH TCP guns on 3 1/2" DP. 10:00 - 10:30 0.50 PERFOB P OTHCMP Hold PJSM wI all hands for TCP gun handling. 10:30 - 12:00 1.50 PERFOB P OTHCMP MIU TCP guns & RIH. 12:00 - 16:30 4.50 PERFOB P OTHCMP PIU 31/2" DP 1x1 & RIH wI TCP guns to 5909'.186 jts + 10' DP pup jt. 16:30 - 20:00 3.50 PERFOB P OTHCMP Wait on E-line equip. RIU E-line equip. 20:00 - 23:00 3.00 PERFOB P OTHCMP MIU GRlCCL tools & RIH. Correlate tubing guns to depth. POOH. 23:00 - 23:30 0.50 PERFOB P OTHCMP UD sheave. Pull 1 jt of DP. RIU sheave. 23:30 - 00:00 0.50 PERFOB P OTHCMP RIH wI GR/CCL logs. 12/5/2004 00:00 - 01 :30 1.50 PERFOB P OTHCMP RIH & tie in TCP guns to correct depth. P/U DP 3' & correlate depth. POOH wI logging tools. 01 :30 - 02:00 0.50 PERFOB P OTHCMP RID logging equip. 02:00 - 02:30 0.50 PERFOB P OTHCMP Hold PJSM. pressure up to 3000 psi & hold for 2 min. Bleed off pressure & open rams. Monitor Guns. Guns fired wI good surface indication in approx 10 min. Monitor well. Fluid level dropping. 02:30 - 04:00 1.50 PERFOB P OTHCMP Circulate bottoms up. 4.5 BPM @ 675 psi. Had gas to surface. Pumped 2 bottoms up. SID & monitor well. Fluid level dropping. Total losses while circulating = 27 Bbls. Pumped total of 335 Bbls. 04:00 - 11 :00 7.00 PERFOB P OTHCMP POOH wI expended TCP guns. Stand back DP. Lay down TCP Guns. All shots fired (see remarks section). Clear and Clean Floor. Printed: 12/14/2004 8:22:03 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 COMPLETION NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/3/2004 12/6/2004 Spud Date: 8/29/1989 End: 12/6/2004 12/512004 11:00 -11:30 0.50 CONDHL P OTHCMP Make-up 6 1/8" Bit and 7" Casing Scraper. 11 :30 - 13:00 1.50 CONDHL P OTHCMP TIH with BHA and 203 Jts 31/2" Drill Pipe. Tag PBTD at 6,447' 113:00 - 14:30 1.50 CONDHL P OTHCMP Reverse circulated Well clean at 4.5 bpm/800 psi. Fluid loss at ! 1 bpm. Dirty Brine and some "Shot Junk" across Shaker after first DPV up. Reversed a total of 160 bbls. 14:30 - 19:00 4.50 CONDHL P OTHCMP POOH & LDDP. UD bit,scaper & junk basket. Junk basket had small amount of black carbon-like material. '19:00 - 23:00 4.00 RUNCOMP RUNCMP Pull wear bushing. Clear & clean rig floor. RIU torq turn & tubing tools. Load& strap completion tubing. 23:00 - 23:30 0.50 RUNCOMP RUNCMP Hold PJSM & review running order for completion string. 23:30 - 00:00 0.50 RUNCOMP RUNCMP MIU tailpipe & packer assys & RIH wI same. Torque-turn all connection to 2300 ft-Ibs. Baker-Loc all connections below bottom Packer. 12/6/2004 00:00 - 01 :00 1.00 RUNCOMP RUNCMP Con'rt to MIU & RIH wI packer & GLM assys. 01 :00 - 09:00 8.00 RUNCOMP RUNCMP Finish running 3 1/2" 9.2 Ib/ft L-80 TCII Completion. Total Jts = 187 ea,. 1 S-3 Packer, 3 Premier Retrievable Packers, 1 XN-Nipple, 2 X-Nipples, 9 GLMs, and WLEGIMule Shoe. 09:00 - 10:00 1.00 RUNCOMP RUNCMP Pick-up Landing Jt. Make-up Tubing Hanger. Land Hanger. RILDS. 10:00 - 11 :00 1.00 BOPSUF P RUNCMP Set and test TWC. 11 :00 - 12:30 1.50 BOPSUP P RUNCMP Nipple down BOP Stack. 12:30 - 14:00 1.50 WHSUR P RUNCMP Nipple up Tree. Test at 5,000 psi. Good. 14:00 - 15:00 1.00 WHSUR P RUNCMP MIU lubricator & pull TWC. UD lubricator. 15:00 - 16:00 1.00 WHSUR P RUNCMP RIU lines to tree. Pressure test lines to 3500 psi, OK. 16:00 - 19:00 3.00 RUNCOMP RUNCMP Displace well annulus w/1 00 bbls of heated seawater. Follow wI 175 bbls of heated inhibited seawater. 2.5 BPM @ 375 psi. 19:00 - 22:00 3.00 RUNCOMP RUNCMP Drop ball/rod. Pressure up tubing to 4000 psi & set packers. Hold pressure & test for 45 min. Had 450 psi leak off. Re-pressure up & repeat test. Leaked off 150 psi in 30 min. Bled off tbg to 2000 psi & SI. Pressured up annulus to 4000 psi & tested for 30 min. Bled off tubing to 1100 psi & DCR-SV sheared. Bled off tbg & ann to 0 psi. Charted entire test. 22:00 - 23:00 1.00 RUNCOM RUNCMP Circulate down annulus & up tubing. Freeze protect well wI 80 Bbls of diesel. 2 1/2 BPM @ 350 psi. 23:00 - 23:30 0.50 WHSUR P RUNCMP P/U lubricator & Installed BPV. UD lubricator. 23:30 - 00:00 0.50 WHSUR P RUNCMP Secure well & cellar. RELEASE RIG @ 2400 hrs. Printed: 12/14/2004 8:22:03 AM Legal Name: Common Name: MPG-03 MPG-03 11/13/2004 LOT 1,995.0 (ft) 1,854.0 (ft) 9.00 (ppg) 240 (psi) 1,107 (psi) EMW 11.49 (ppg) . . Printed: 11/22/2004 10:19:07 AM . . 06-Dec-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPG-03A Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 1,903.83' MD 1,964.13' MD 6,536.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK99518 Date;) I ¡)J.A :LL~~ . /I Ú i/J / ... ,1 Signed ~..vJ( 01 .~ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) . DEFINITIVE Halliburton Sperry-Sun Milne Point Unit BPXA MPG-03A .. Job No. AKZZ3389345, Surveyed: 15 November, 2004 Survey Report 2004 2 December, Your Ref: API 5002922194201 Surface Coordinates: 6014190.03 N, 557243.78 E (70026' 57.8511" N, 149031 Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Survey Ref: svy1504 W) 58.7513" 63. 10ft above Mean Sea Level SpE!I"""ï')J-SUI'1 CRILLING seRVIt:es A Halliburton Company Kelly Bushing Elevation: Halliburton Sperry-Sun Survey Report for MPG-03A Your Ref: API 5002922194201 Job No. AKZZ3389345, Surveyed: 15 November, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 1903.83 39.250 61.100 1744.07 1807.17 204.39 N 386.99 E 6014397.39 N 557629.19 E 43763 Tie On Point MWD+IIFR+MS 1964.13 39.850 61.540 1790.56 1853.66 222.82 N 420.68 E 6014416.07 N 557662.73 E 1.098 476.02 Window Point 2031.26 41.320 57.440 1841.55 1904.65 245.00 N 458.27 E 6014438.54 N 557700.16 E 4.536 51965 ~~ 2078.05 40.170 54.580 1877.00 1940.10 262.06 N 483.59 E 6014455.80 N 557725.34 E 4.685 550.03 . 2174.05 38.710 48.740 1951.17 2014.27 299.82 N 531 .4 1 E 6014493.92 N 557772.87 E 4.152 610.05 2218.49 38.760 45.990 1985.84 2048.94 318.65N 551.86 E 6014512.91 N 557793.18 E 3.873 636.99 2268.20 38.470 45.460 2024.68 2087.78 340.30 N 574.07 E 6014534.73 N 557815.22 E 0.885 666.83 2364.39 38.410 44.450 2100.02 2163.12 382.62 N 616.33 E 6014577.37 N 557857.15 E 0.656 724.12 2408.76 38.4 70 45.840 2134.77 2197.87 402.07 N 635.88 E 6014596.98 N 557876.55 E 1.952 750.57 2460.68 41 .480 48.290 2174.56 2237.66 424.77 N 660.31 E 6014619.86 N 557900.81 E 6.541 782.85 2556.90 44.630 49.780 2244.86 2307.96 467.81 N 709.92 E 6014663.28 N 557950.08 E 3.440 846.96 2652.96 47.430 53.030 2311.55 2374.65 510.89 N 763.96 E 6014706.77 N 558003.80 E 3.797 914.98 2748.81 51.270 56.700 2374.00 2437.10 552.66 N 823.44 E 6014749.00 N 558062.95 E 4.948 987.17 2845.64 54.390 59.140 2432.50 2495.60 593.60 N 888.82 E 6014790.44 N 558128.02 E 3.796 1064.15 2941 .58 57.390 62.770 2486.30 2549.40 632.11 N 958.26 E 6014829.49 N 558197.16 E 4.426 1143.55 3038.02 57.870 64.540 2537.94 2601.04 668.26 N 1031.25 E 6014866.19 N 558269.87 E 1.628 1224.94 3131.74 57.750 64.260 2587.87 2650.97 702.53 N 1102.78E 6014901.01 N 558341.13 E 0.283 1304.16 3227.22 57.380 64.130 2639.08 2702.18 737.61 N 1175.33 E 6014936.64 N 558413.41 E 0.404 1384.67 3324.11 57.070 63.990 2691.53 2754.63 773.24 N 1248.59 E 6014972.84 N 558486.39 E 0.342 1466.06 3418.66 57.060 63.850 2742.93 2806.03 808.13 N 1319.86 E 6015008.27 N 558557.39 E 0.125 1545.35 3514.71 57.020 63.720 2795.19 2858.29 843.73 N 1392.16 E 6015044.43 N 558629.42 E 0.121 1625.88 . 3611.28 56.900 65.220 2847.84 2910.94 878.62 N 1465.21 E 6015079.87 N 558702.20 E 1.308 1706.73 3706.76 56.540 65.240 2900.24 2963.34 912.06 N 1537.69 E 6015113.87 N 558774.41 E 0.377 1786.40 3802.67 56.220 64.510 2953.34 3016.44 945.97 N 1610.00E 6015148.34 N 558846.46 E 0.716 1866.13 3898.46 56.070 65.020 3006.71 3069.81 979.88 N 1681.95 E 6015182.80 N 558918.16 E 0.469 1945.56 3994.58 56.180 65.010 3060.28 3123.38 1013.59 N 1754.29 E 6015217.07 N 558990.23 E 0.115 2025.23 4090.75 55.440 64.770 3114.32 3177.42 1047.35 N 1826.32 E 6015251.37 N 559062.00 E 0.797 2104.64 4185.32 56.790 62.240 3167.05 3230.15 1082.38 N 1896.56 E 6015286.94 N 559131.98 E 2.640 2183.10 4280.41 57.290 64.170 3218.79 3281.89 1118.34N 1967.78 E 6015323.45 N 559202.91 E 1.782 2262.85 4374.18 57.520 64.890 3269.30 3332.40 1152.31 N 2039.10 E 6015357.97 N 559273.97 E 0.692 2341.75 2 December, 2004 - 14:50 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for MPG-03A Your Ref: API 5002922194201 Job No. AKZZ3389345, Surveyed: 15 November, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 446957 56.630 65.040 3321 .15 338,J .25 1186.20 N 2111.65 E 6015392.41 N 55934625 E 0.942 2421.68 4566.78 56.560 64.840 3374.67 3437 77 1220.57 N 2185.16E 6015427.35 N 559419.50 E 0.186 2502.69 4662.56 55910 63.920 3427.90 3491.00 1254.99 N 2256.95 E 6015462.32 N 559491.03 E 1.048 2582.22 4759.13 57.450 63.580 3480.95 3544.05 1290.69 N 2329.32 E 6015498.57 N 55956312 E 1.622 2662.86 4855.30 58180 63.070 3532.18 3595.28 1327.23 N 2402.05 E 6015535.67 N 55963557 E 0.882 2744.21 . 4951.66 58.280 62.840 3582.91 3646.01 1364.48 N 2475.02 E 6015573.48 N 559708.24 E 0.228 2826.11 5047.04 57.480 63.070 3633.62 3696.72 1401.21 N 2546.96 E 6015610.76 N 559779.90 E 0.863 2906.87 5143.40 57.440 63.060 3685.45 3748.55 1438.00 N 2619.38E 6015648.11 N 559852.04 E 0.042 2988.08 5238.46 57.350 62.870 3736.68 3799.78 1474.40 N 2690.71 E 6015685.06 N 559923.09 E 0.193 3068.14 5334.50 56.930 64.050 3788.79 3851.89 1510.45 N 2762.88 E 6015721.66 N 559994.98 E 1.121 3148.77 5430.82 57.130 62.590 3841 .21 3904.31 1546.73 N 2835.08 E 6015758.49 N 560066.90 E 1.289 3229.53 5525.57 58.120 65.400 3891.95 3955.05 1581.80 N 2906.99 E 6015794.11 N 560138.54 E 2.714 3309.47 5622.01 57.270 64.330 3943.49 4006.59 1616.42 N 2980.79 E 6015829.30 N 560212.06 E 1.287 3390.85 5718.47 56.680 61.700 3996.07 4059.17 1653.11 N 3052.85 E 6015866.54 N 560283.84 E 2.366 3471.69 5814.37 56.410 60.730 4048.94 4112.04 1691.63 N 3122.97E 6015905.60 N 560353.67 E 0.890 3551.70 5911.10 56.530 60.490 4102.37 4165.47 1731.20 N 3193.23E 6015945.71 N 560423.62 E 0.241 3632.32 6005.90 55.990 61 .400 4155.02 4218.12 1769.49 N 3262.14 E 6015984.52 N 560492.23 E 0.981 3711.15 6102.61 55.370 61.060 4209.55 4272.65 1807.93 N 3332.15 E 6016023.50 N 560561.95 E 0.704 3791.02 6198.57 55.440 61.080 4264.03 4327.13 1846.14 N 3401.29 E 6016062.24 N 560630.79 E 0.075 3870.01 6294.33 54.370 60.300 4319.09 4382.19 1884.49 N 3469.61 E 6016101.12 N 560698.81 E 1.301 3948.34 6390.57 53.840 60.290 4375.51 4438.61 1923.13 N 3537.33 E 6016140.27 N 560766.23 E 0.551 4026.29 6471.87 53.380 59.450 4423.75 4486.85 1955.98 N 3593.93 E 6016173.55 N 560822.58 E 1.006 4091.70 . 6536.00 53.380 59.450 4462.00 4525.10 1982.14 N 3638.26 E 6016200.06 N 560866.70 E 0.000 4143.14 Projected Survey All data is in Feet (US Survey) 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. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 61.620° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6536.00ft., The Bottom Hole Displacement is 4143.16ft., in the Direction of 61.418° (True). 2 December, 2004 - 14:50 Page 3 of4 Dril/Quest 3.03.06.006 .'" . Milne Point Unit Comments Measured Depth (ft) 1903.83 1964.13 6536.00 Halliburton Sperry-Sun Survey Report for MPG-03A Your Ref: AP/5002922194201 Job No. AKZZ3389345, Surveyed: 15 November, 2004 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 1807.17 1853.66 4525.10 Comment 204.39 N 222.82 N 1982.14 N . 386.99 E 420.68 E 3638.26 E Tie On Point Window Point Projected Survey Survey tool proçram for MPG-03A Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 1903.83 0.00 1807.17 2 December, 2004 - 14:50 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 1903.83 6536.00 1807.17 BP Conventional Gyro - Boss Gyro (MPG-03) 4525.10 MWD+IIFR+MS (MPG-03A) . Page 4 of 4 DrillQuest 3.03.06.006 . . 06-Dec-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPG-03A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 1,903.83' MD 1,964.13' MD 6,536.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services AUn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date c2 / /2A- ~Ivt '1 Þ7/ I 11 /1 Signed #M~ ()1l~1 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Halliburton Sperry-Sun Milne Point Unit BPXA MPG-03A MWD . Job No. AKMW3389345, Surveyed: 15 November, 2004 Survey Report 2 December, 2004 Your Ref: API 5002922194201 Surface Coordinates: 6014190.03 N, 557243.78 E (70' 26' 57.8511" N, 149' 31' 58.7513" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 63. 10ft above Mean Sea Level . SpE!I"""I"""Y-SU'r'1 bFtIL.. L.ING SSFtVICSS A Halliburton Company Survey Ref: svy1505 Halliburton Sperry-Sun , Survey Report for MPG-03A MWD Your Ref: API 5002922194201 Job No. AKMW3389345, Surveyed: 15 November, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 1903.83 39.250 61.100 1744.07 1807.17 204.39 N 386.99 E 6014397.39 N 557629.19 E 437.63 Tie On Point MWD Magnetic 1964.13 39.850 61.540 1790.56 1853.66 222.82 N 420.68 E 6014416.07 N 557662.73 E 1.098 476.02 Window Point 2031.26 41.320 57440 1841.55 1904.65 245.00 N 458.27 E 6014438.54 N 557700.16 E 4.536 519.65 2078.05 40.170 54.580 1877.00 1940.10 262.06 N 48359 E 6014455.80 N 557725.34 E 4.685 550.03 . 2174.05 38.710 48.740 1951.17 2014.27 299.82 N 531.41 E 6014493.92 N 557772.87 E 4.152 610.05 2218.49 38.760 46.380 1985.83 2048.93 318.58 N 551.93 E 6014512.84 N 557793.24 E 3.325 637.02 2268.20 38.470 51.760 2024.69 2087.79 338.89 N 575.34 E 6014533.33 N 557816.50 E 6.778 667.27 2364.39 38.410 44.700 2100.07 2163.17 378.67 N 619.88 E 6014573.45 N 557860.74 E 4.562 725.37 240876 38470 46.110 2134.82 219792 398.03 N 639.52 E 6014592.96 N 557880.23 E 1.980 751.85 2460.68 41 .480 48.510 2174.61 2237.71 420.63 N 664.05 E 6014615.74 N 557904.58 E 6.513 784.17 2556.90 44.630 50.150 2244.91 2308.01 46341 N 713.88 E 6014658.91 N 557954.08 E 3.474 848.35 2652.96 47.430 53.310 2311.60 2374.70 506.18 N 768.17 E 6014702.09 N 558008.04 E 3.755 916.44 2748.81 51.270 56.660 2374.04 2437.14 547.83 N 827.74 E 6014744.21 N 558067.28 E 4.803 988.65 2845.64 54.390 59.500 2432.54 2495.64 588.59 N 893.23 E 6014785.46 N 558132.46 E 3.980 1065.64 2941.58 57.390 63.120 2486.35 2549.45 626.67 N 962.91 E 6014824.07 N 558201.84 E 4.419 1145.04 3038.02 57.870 64.890 2537.99 2601.09 662.36 N 1036.12 E 6014860.33 N 558274.78 E 1.628 1226.42 3131.74 57.750 64.600 2587.91 2651.01 696.20 N 1107.85 E 6014894.72 N 558346.25 E 0.291 1305.62 3227.22 57.380 67.200 2639.13 2702.23 729.10 N 1181.40 E 6014928.19 N 558419.54 E 2.331 1385.97 3324.11 57.070 64.870 2691.59 2754.69 762.19 N 1255.83 E 6014961.84 N 558493.72 E 2.047 1467.18 3418.66 57.060 68.250 2743.00 2806.10 793.75 N 1328.62 E 6014993.96 N 558566.27 E 3.000 1546.22 3514.71 57.020 64.180 2795.27 2858.37 826.24 N 1402.34 E 6015027.01 N 558639.74 E 3.555 1626.53 . 3611.28 56.900 65.680 2847.93 2911.03 860.54 N 1475.67 E 6015061.88 N 558712.79 E 1.308 1707.34 3706.76 56.540 65.680 2900.32 2963.42 893.41 N 1548.41 E 6015095.31 N 558785.28 E 0.377 1786.96 3802.67 56.220 64.990 2953.42 3016.52 926.74 N 1620.99 E 6015129.19 N 558857.60 E 0.686 1866.66 3898.46 56.070 65.410 3006.79 3069.89 960.11 N 1693.20 E 6015163.11 N 558929.55 E 0.396 1946.06 3994.58 56.180 65.480 3060.36 3123.46 993.27 N 1765.78 E 6015196.83 N 559001.88 E 0.129 2025.68 4090.75 55.440 65.240 3114.41 3177.51 1026.44 N 1838.09 E 6015230.55 N 559073.93 E 0.797 2105.06 4185.32 56.790 62.750 3167.14 3230.24 1060.86 N 1.908.63 E 6015265.52 N 559144.21 E 2.610 2183.49 4280.41 57.290 64.660 3218.87 3281.97 1096.20 N 1980.16 E 6015301.41 N 559215.46 E 1.765 2263.22 4374.18 57.520 65.330 3269.39 3332.49 1129.60 N 2051.76E 6015335.35 N 559286.80 E 0.650 2342.08 2 December, 2004 - 14:50 Page 2 of4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun ~ Survey Report for MPG-03A MWD Your Ref: API 5002922194201 Job No. AKMW3389345, Surveyed: 15 November, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth IncL Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 4469.57 56.630 65.490 3321.23 3384.33 1162.91 N 2124.56 E 6015369.23 N 559359.35 E 0.944 2421.97 4566.78 56.560 65.340 3374.75 3437.85 1196.68 N 2198.36 E 6015403.56 N 559432.88 E 0.148 2502.95 4662.56 55.910 64.450 3427.99 3491.09 1230.46 N 2270.46 E 6015437.89 N 559504.72 E 1.028 2582.44 4759.13 57.450 64.040 3481.03 3544.13 1265.52 N 2343.13 E 6015473.51 N 559577.12 E 1.634 2663.05 4855.30 58.180 63.580 3532.26 3595.36 1 301.44 N 2416.17 E 6015509.99 N 559649.88 E 0.860 2744.38 . 4951.66 58.280 63.320 3582.99 3646.09 1338.06 N 2489.45 E 6015547.17 N 559722.88 E 0.252 2826.26 5047.04 57.480 63.490 3633.71 3696.81 1374.23N 2561.68 E 6015583.89 N 559794.83 E 0.852 2907.00 5143.40 57.440 63.530 3685.54 3748.64 1410.46 N 2634.39 E 6015620.68 N 559867.26 E 0.054 2988.19 5238.46 57.350 63.320 3736.76 3799.86 1446.28 N 2706.01 E 6015657.06 N 559938.60 E 0.209 3068.23 5334.50 56930 64.500 3788.87 3851.97 1481.76 N 2778.46 E 6015693.09 N 560010.77 E 1.121 314883 5430.82 57.130 63.030 384129 390439 1517.48 N 2850.94 E 6015729.37 N 560082.98 E 1.297 3229.58 5525.57 58.120 65.830 3892.03 3955.13 1552.01 N 2923.11 E 6015764.44 N 560154.89 E 2.706 3309.49 5622.01 57.270 64.780 3943.57 4006.67 1586.06 N 2997.17 E 6015799.06 N 560228.68 E 1.274 3390.84 5718.47 56.680 62.180 3996.15 4059.25 1622.16 N 3069.53 E 6015835.72 N 560300.76 E 2.341 3471.66 5814.37 56.410 61.180 4049.02 4112.12 1660.11 N 3139.96E 6015874.21 N 560370.90 E 0.914 3551.67 5911.10 56.530 60.940 4102.45 4165.55 1699.13 N 3210.53 E 6015913.77 N 560441 .16 E 0.241 3632.30 6005.90 55.990 61.870 4155.10 4218.20 1736.86 N 3279.74 E 6015952.03 N 560510.08 E 0.995 3711.13 6102.61 55.370 61.580 4209.63 4272.73 1774.70N 3350.08 E 6015990.41 N 560580.13 E 0.687 3791.00 6198.57 55.440 61.600 4264.11 4327.21 1812.28 N 3419.56E 6016028.52 N 560649.32 E 0.075 3869.99 6294.33 54.370 60.810 4319.17 4382.27 1850.02 N 3488.23 E 6016066.79 N 560717.69 E 1.305 3948.34 6390.57 53.840 60.790 4375.59 4438.69 1888.05 N 3556.28 E 6016105.34 N 560785.46 E 0.551 4026.29 6471.87 53.380 59.970 4423.83 4486.93 1920.40 N 3613.18 E 6016138.12 N 560842.10 E 0.990 4091.72 . 6536.00 53.380 59.970 4462.08 4525.18 1946.16 N 3657.74 E 6016164.22 N 560886.46 E 0.000 4143.17 Projected Survey All data is in Feet (US Survey) 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. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 61.620° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6536.00ft., The Bottom Hole Displacement is 4143.26ft., in the Direction of 61.984° (True). 2 December, 2004· 14:50 Page 3 of 4 DrillQuest 3.03.06.006 Milne Point Unit Comments Measured Depth (ft) 1903.83 1964.13 6536.00 Halliburton Sperry-Sun Survey Report for MPG-03A MWD Your Ref: API 5002922194201 Job No. AKMW3389345, Surveyed: 15 November, 2004 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 1807.17 1853.66 4525.18 Comment 204.39 N 222.82 N 1946.16 N Tie On Point Window Point Projected Survey . 386.99 E 420.68 E 3657.74 E Survey tool proqram for MPG-03A MWD Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 1903.83 0.00 1807.17 2 December, 2004 - 14:50 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 1903.83 6536.00 1807.17 BP Conventional Gyro - Boss Gyro (MPG-03) 4525.18 MWD Magnetic (MPG-03A MWD) . Page 4 of 4 DrillQuest 3.03.06.006 Re: MPG-03A, MPG-19 Bond logs e . Subject: Re: MPG-03A, MPG-19 Bond logs From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 06 Dec 2004 09:30:03 -0900 To: "Green, Matt D" <GreenMD@BP.com> CC: Dave Reem <reemdc@bp.com>, John Cubbon <CubbonJR@BP.com> Matt, You did send me the correct diagrams, what I was referring to were the drawings the Schlumberger included in their SCMT presentations. I understand that the correct drawings are the proposed completions and there will be some minor differences in final depths. I have completed my review of the bond logs you sent over. I conclude that the isolation in each well is acceptable and you may proceed to complete the wells as planned. Please be sure that the inner annulus pressure test is held for 30 minutes when 4ES completes the wells. This test should also be documented using the AOGCC MIT test reporting form. Please contact John Cubbon at Milne for an e-copy. John, after the wells have been placed in service and are thermally stable please make arrangements for an Inspector to witness a MIT. Please call or message with any questions. Tom Maunder, PE AOGCC Green, Matt D wrote: Hi Tom, I must have sent you the wrong completion diagrams! Those were the status that Doyon 14 left the wells with a kill string. Nabors 4ES will do the final completion. Those diagrams are also not the official final diagrams, so please excuse the inaccuracies - some data would still be planned data I would think. Here are the planned completion diagrams again. My apologies for the confusion. Cheers, Matt. From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Monday, December 06, 20048:11 AM To: Green, Matt D Subject: Re: MPG-03A, MPG-19 Bond logs Matt, 10f2 12/6/20049:30 AM Re: MPG-03A, MPG-19 Bond logs e e I just had a look at the bond logs and they look pretty good. I am curious regarding the completion drawings. It appears that there is just a tubing string hung in the wells. Will 4ES be doing the final completions?? Also, on the drawing in MPG-03, the correct name should be MPG-03A (the log header is correct) and the 7" casing setting depth noted on the front is actually the float collar depth. Similar information on MPG-19 is correct listing the shoe depth. Thanks, Tom Green, Matt D wrote: Hi Tom, One of those was a 2.4Mb zipped file! However, I just had copies of the logs delivered to my desk from another source and they are now in the mail and you should get them tomorrow anyway. Cheers, Matt. From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Thursday, December 02, 20043:15 PM To: Green, Matt D Subject: Re: MPG-03A, MPG-19 Bond logs Hi Matt, They won't even come zipped?? I just checked I have some 800 k compressed files from CP AI that are 4.2 m uncompressed. But, if they won't go they won't go. Tom Green, Matt D wrote: Tom. Those files are too big to send for us, so I'll have to get some more prints and mail them to you. It will probably be next week if that is OK. Cheers, Matt. 20f2 12/6/2004 9:30 AM · e ~04-d-\~ c.c\""'-.~\~ \-'to" ~~ ho~ ç-\ \&'o...~ oQ \)./\.- ME CHAN I CAL INTEGRITY REPORT' ".. :~IG RELE;.S£: k"ELL NUMBER -ß? M', \~. ? ~:)\ 4"~ \-\?C~-OS~ =PUDDP.:E: OPER & FIELD :rt!;.LL DATA TD: . liD.. TVD i :?BTD: ~ qS-ÜD TVD TVD¡ DV: .~~ MD ~~ ·DlD Cê.S ing: '\ Shoe: ~53 <;e MD _:.::.e:r: ~ ~ Shoe: MD _ .. "()-\u)"""Q~~ '-1 « ~ _~D~~g: PàcKer I . HD TVD i :CP: HD ;:VD TVD i See ë. t: ::ole Size 15\~ a.na ~~ Perfs ~ro~~ ,~.~~-,~-\<t.~\ ~ '"~~ ,-0 . ~C?_ANIc;·.L INTEGRITY - PART 11 Annulus Press Test: ~p 15 min 30 min COtri!:ùents: ...- ~CHÞ~ICÞ~ INTEGRITY - PART /2 Cement Volumes:' þ...mt. l.iner Csg DV Cilit ~ol to cover perfs Theoretical TOC Cement Bond Log @ or No) CEL Evaluation, ~one a.bove perfs ü~~~~~\C'J.~~V't\S Production Log: Type <;~M..' ; In AOGCC File . \\ l ò-,,~()~ ~,C(.\~~ ~~\~~\....~-..)~~ ~ ~L 'c,\ ~~ «.. S~O ¡Evaluation CONCLUSIONS: ? ar t f 1 : ?ar~ ¡Z: k.:c ,~ '\ C'-.~'-CJ.... ~ ."- '. Æ'7Vl \~ Ib-o,-\ MPG-03A and MPG-19 Perforations and paCk,ePths Subject: MPG-03A and MPG-19 Perforations and Packer Depths From: "Green, Matt D" <GreenMD@BP.com> Date: Thu, 02 Dec 2004 14:40:44 -0900 To: tom_maunder@admin.state.ak.us CC: "David Reem (Reem, David C)" <ReemDC@BP.com> Tom and Dave, , Here are the planned perforations and packer depths for MPG-03A and MPG-19. All depths are referenced to pertinent bond logs. Attached are the planned completion diagrams. Also attached are the bond logs for your perusal. Cement is good on both wells. We plan complete the wells in the next week or so. MPG-03A Packer NB Perfs NC Perfs Packer N E Perfs Packer OA Perfs OA Perfs Packer OB Perfs GR Marker Short Joint MPG-19 Packer NB Perfs Packer NE Perfs Packer OA Perfs OA Perfs Packer OB Perfs GR Marker GR Marker Cheers, lof2 5890-ft 5942 to 5952-ft (10-ft) 5962 to 5977-ft (15-ft) 5992-ft 6010 to 6050-ft (40-ft) 6100-ft 6157 to 6172-ft (15-ft) 6187 to 6217-ft (30-ft) 6244-ft 6277 to 6317-ft (40-ft) 5860-ft 5860 to 5880-ft 7570-ft 7650 to 7680-ft (30-ft) 7740-ft 7783 to 7823-ft (40-ft) 7946-ft 8004 to 8024-ft (20-ft) 8040 to 8080-ft (40-ft) 8130-ft 8183 to 8213-ft (30-ft) 7502-ft 7855-ft 12/2/20043: 11 PM MPG-03A and MPG-19 Perforations and Packer Depths e Matt. e «MPG-03A Proposed v2.0.ZIP» «MPG-19i Proposed v2.0.ZIP» Bond logs to follow (too big!) Proposed Content-Description: MPG-03A Proposed v2.0.ZIP Content-Type: application/x -zip-compressed Content-Encoding: base64 20f2 Content-Description: MPG-19i Proposed v2.0.ZIP Content-Type: application/x -zip-compressed Content-Encoding: base64 12/2/20043:11 PM MPG-03A rtþ>posed ITiÐA 13-3/8"48ppg H-40 11965' MnlT~p '1 Window 11995' MD Bottom Window 15985' Mq 16095' MD 16240' Mq 16450-ft MO I PBTD 16536-ft MD TD A Orig. DF Elev. = ' .. Orig. GL Elev. = ' Tree: 3-1/8" - 5M Wellhead: 11" 5M FMC Gen 6 ... ... HES X-Nipple (2.813") I 500' Mol 3-1/2" 9.2 ppf L-80 TCII Tubing (Drift ID = 2.867, Cap. = 0.0087 bpf) 9.625-in 471b/ft L-80 BTC-M 3 1/2' X 1 1/2" MMG GLM 12100' MDI HES X-Nipple (2.813") 15800' MD 7" X 3 1/2" Baker Premier PKR 15850' MD ~,- ,.... 3 1/2' X 1 1/2" MMGW GLM 3 1/2' X 1 1/2" MMG GLM ... NB Perforations: (MWD Jog only) 6 spf 5935-5945-ft MD 5955-5970-ft MD 7" X 3 1/2" Baker Premier PKR NE Perforations: (MWD Jog only) 6 spf 6000-6040-ft MD OA Perforations:(MWD log only) 6 spf 6150-6165-ft MD 6180-6210-ft MD 31/2' X 1 1/2" MMG GLM 3 1/2' X 1 1/2" MMGW GLM OB Perfora- tions: (MWD log only) 6 spf 6270- 10-ft MD 7" X 3 1/2" Baker S-3 Packer 3 1/2' X 1 1/2" MMGW GLM 3 1/2' X 1 1/2" MMG GLM HES XN-Nipple 2.75" Min. ID 3 1/2" WLEG 7" 26 ppf, L-80, BTC-MOO Casing (drift 10 = 6.151", cap. = 0.0383 bpf) DATE REV. BY 10/15/04 W Quay 17Nov04 7" float shoe M Green COMMENTS Proposed Selective Injector Added 4th packer and mandrels MILNE POINT UNIT WELL MPG-03A BP EXPLORATION (AK) -- ~~~~E lIDF !Æ~~~~~~ . AI1ASKA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Fred Johnson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPG-03A BP Exploration (Alaska) Inc. Permit No: 204-219 Surface Location: 1754' NSL, 3361' WEL, SEC. 27, T13N, RlOE, UM Bottomhole Location: 3713' NSL, 5014' WEL, SEC. 26, T13N, RI0E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above service well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commissio 0 'tness any required test. Contact the Commission's petroleum field inspector at (907) 65 - 0 (pager). :n rely BY ORDER OF THE COMM ION DATED this-.L day of . ::.i'~ ee: Department ofFish & Game, Habitat Section w/o ene!. Department of Environmental Conservation w/o ene!. .. . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION 0 PERMIT TO DRILL 20 AAC 25.005 1b. Current Well Class 0 Exploratory 0 Development Oil 0 Multiple Zone o Stratigraphic Test II Service 0 Development Gas 0 Single Zone 5. Bond: a Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 MPG-03A 6. Proposed Depth: 12. Field / Pool(s): MD 6492' / rvD 4495' / Milne Point Unit / Schrader Bluff 7. Property Designation: ADL 025518¿¡- tíz.s~ib(, 8. Land Use Permit: .::f7:> â¡13. Approximate Spud Date: tv 1,2. 11/07/04 ¿004 4, W o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. -3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 -4a. Location of Well (Governmental Section): Surface: . 1754' NSL, 3361' WEL, SEC, 27, T13N, R10E, UM Top of Productive Horizon: 3619' NSL, 5192' WEL, SEC. 26, T13N, R10E, UM Total Depth: 3713' NSL, 5014' WEL, SEC. 26, T13N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 557244./ y- 6014190' Zone- ASP4 16. Deviated Wells: Kickoff Depth: 1950' , feet Maximum Hole Angle: 57 9. Acres in Property: 2560 14. Distance to Nearest Property: 10000' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 59.27' feet 550' away from MPG-03 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2065 Surface: 1635 Hole 8-1/2" Casinç¡ 7" Weiç¡ht 26# Grade Couplinç¡ Lenç¡th MD L-80 BTC 6492' 0' rvD MD rvD (includinç¡ staç¡e data) 0' 6492' 4495' 68 Bbls Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth rvD (ft): Plugs (measured): I Effective Depth MD (ft): Depth rvD (ft):/ 5910' 4603' 1981',3201',4899' 1981' 1866' Structural Conductor 110' 13-3/8" Arctic Set to Surface (Approx.) 110' 110' Surface 2931' 9-518" 181 Bbls Perm 'E', 138 Bbls Class 'G' 2931' 2510' Intermediate Production 5891' 7" 87 Bbls 'G', 24 Bbls AS 1, followed by 5891' 4587' Liner 52 Bbls Dead Crude 20. Attachments a Filing Fee, $100 0 BOP Sketch a Property Plat 0 Diverter Sketch I Perforation Depth rvD (ft): 4111' - 4199' 4270' - 4310' a Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report a Drilling Fluid Program a 20 AAC 25.050 Requirements Perforation Depth MD (ft): N Sands - Plugged 5334' - 5438' o Sands - Open 5522' - 5568' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name F¡red Title Senior Drilling Engineer Date: Contact Walter Quay, 564-4178 Phone 564~~t< 7 Date Prepared By Name/Number: Sondra Stewman, 564-4750 Permit To Drill l/ API Number: Number: ;;;.07 - 2 Ie¡ 50- 029-21942-01-00 Conditions of Approval: Samples Required 0 Yes ~No Mud Log 0 Yes :8{No Hydrog ulfide Measures 0 Yes flGNo Directional Survey Required ,25(Yes 0 No Other: ~O ~~\, . .~\-û.~ þ\ú~~d, ~()\>-k~\-\~\<c.~\ ~ \'-\~'{S, \-\ \\~ ~~"\.~Cy~"~\O) ¡:,",~CL \-ro"-s \'" úc..c.()~ \)oJ , ~\() \() \3 \ Date II!¡ /ðl/ s'i~frn ~u~icate OR\G\NAt APPROVED BY THE COMMISSION . . MPG·03A Well ProQram I Well Name: I MPG-03A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Schrader Bluff Single Selective Injector Surface Location: (As Built) Target Location: Top OB Target Location: BHL OB Well TD Distance to Property line Distance to nearest pool 1,754' FSL, 3,361' FEL, SEC. 27, T13N, R10E " E=557244 N=6014190 ./ 3,619' FSL, 5,192' FEL, SEC. 26, T13N, R10E E=560675 N=6016082 Z= 4300' TVD SS 3,713' FSL, 5,014' FEL, SEC. 26 , T13N, R10E E=560851 N=6016178 Z=4434' TVD SS 10,000' 550' from MPG-03 AFE Number: I I I Rig: I Doyon 14 Estimated Start Date: 17 Nov 2004 I Operating days to complete: 18.5 MD: 16492' / 1 1 TVD: 14495' 1 ~ 1 Max Inc: 157 1 I KOP: 11950'1 I KBE:/63.5 Well Design (conventional, slim hole, etc.): 1 Conventional Single Selective Injector Objective: I Schrader Bluff OB, OA & NB ./ Page 4 . . MPG-03A Well Procuam Mud Program: 8-1/2" OB Production Hole (1950 - 6492'): Density (ppç PV YP API FL Chlorides (mg/I) 9.5-9.7 8-15 26-32 6-8 <1500 LSND pH MBT 9.0 - 9.5 < 25 LCM Restrictions: Yes. Use CaC03 as LCM 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 Phillips KRU lR. Cement Program: Casinq Size 17" 26 Ib/ft L-80 BTC-M Intermediate Casing Basis I Top of tail slurry 500' MD above TUZC. 40% excess over gauge. Total Cement Volume: 68 bbl Wash 25-bbl water Spacer Tail Temp 45-bbl (MW + 1.0-lb/gal) Alpha Spacer (AI~ha) 68-bbl, 326-sx 15.8 Ib/gal Prem G - 1.17 ft Isx BHST =80°F from SOR Page 5 . . MPG-03A Well Proaram Evaluation Program: 8-1/2" Section Open Hole: Cased Hole: MWD/GRlRES / IFRlCASANDRA Sperry InSite SCMT Formation Markers: Formation Tops M~~:b TVDrkb (ft) Pore Pressure Estimated EMW (psi) (Ib/gal)* BPRF 1976 1863 782 8.35 TUZC 4940 3646 1556 8.35 Ugnu-MA 5401 3898 1665 8.35 Ugnu-MB1 5423 3910 1670 8.35 Ugnu-MB2 5513 3959 1692 8.35 Ugnu-MC 5776 4103 1754 8.35 SBF2-NA 5846 4141 1959 9.24 / SBF1-NB 5899 4170 1972 9.24 SBE4-NC 5945 4195 1984 9.24 SBE2-NE 5988 4219 1996 9.24 SBE1-NF 6069 4263 2017 9.24 TSBD-Top OA 6129 4296 2033 9.24 TSBC-Base OA 6197 4333 2051 9.24 TSBB- Top OB 6252 4363 2065 9.24 SBA5-Base OB 6292 4385 2076 9.24 / Page 6 . CasingITubing Program Hole Size Csg I WtlFt Grade Conn Tbg O.D. 8.5" 7" 26# L-80 BTC Recommended Bit Program: BHA Hole Size Depth (MD) 1 8.5" 1950' - 6492' Length 6,492' Bit Type Mill Tooth . Top MD I TVDrkb 0/0 MPG-03A Well ProQram Bottom MD I TVDrkb 6,492'/4,495' Nozzle/Flow rate Page 7 . . MPG-03A Well ProQram Well Control: Intermediate/Production hole: · Maximum anticipated BHP: 2,065-psi @ 4,300-ft TVDrkb - TSBB-Top OB · Maximum suñace pressure: 1,635 psi '@ suñace(Based on BHP and a full column of gas from TD @ O.l-psi/ft) · Planned BOP test pressure: /3,000-psi. For this well, approval is ~ht to change the BOP testing interval from 7 to 14 days. · Integrity test: An LOT to 12.6-lb/gal minimum at the 9-5/8" window. Kick tolerance: 26-bbl with 9.6Ib/gal mud. · Planned completion fluid: Kill Weiight Brine + Freeze Protect Drilling Hazards & Contingencies: · Hydrates have not been reported on G-Pad however G-8 reporter gas-cut mud at 2020' ~ TVD. · The Schrader Bluff sands underlying G Pad are expected to be slightly over-pressured from to offset injection wells. Lost Circulation · We do not expect losses while drilling this well if there is good hole cleaning. · Offset wells have reported losses while running and cementing surface casing. If seepage and/or losses occur, follow the LOST CIRCULATION DECISION MATRIX in the well plan. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures · The Schrader Bluff sands are slightly elevated (9.24 ppg) due to offset injectors (MPG-03i). Pad Data Sheet · Please Read the G-Pad Data Sheet thoroughly. Breathing Hazards · Not expected or predicted.' Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Faults · One (1) fault is mapped in the well. This fault will be cut at ± 3269' MD. Hydrogen Sulfide · MPG Pad is not designated as an H2S Pad. There are no Kuparuk wells on MPG Pad. Anti-collision Issues · MPG-03A passes the Major Risk Criteria except for MPG-06. This well was plugged and abandoned in 2003. Distance to Nearest Property · MPG-03A is 10,000 ft from the nearest Milne Point property line. Distance to Nearest Well Within Pool · MPG-03A is 550 ft from the nearest Schrader Bluff sand penetration in MPG-03 Page 8 . . DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. MPG-03 was P&Ad by 4ES. EZSV @ 1981' , Drillina 1. MIRU Doyon 14, ND Tree/NU BOP. 2. Run whipstock and mill window. 3. PU 8-112" BHA & Drill 8-1/2"Section. 4. Run & Cement the 7" long string. 5. Clean out Casing to TD, lD DP 6. Run Cement evaluation log. 7. Run and cement 7" production casing. 8. Make a bit and scraper run. 9. Displace the well with completion fluid. 10. Run a GR 1 USIT 1 CCl (or scmt). 11. Perforate the NB, OA and OB. 12. Run the selective injection completion (see diagram). 13. ND BOP/NU Tree. 14. Freeze Protect. 15. RDMO Doyon 14. MPG-03A Well PrOQram Page 9 . Tree: 2 9/16" - 5M WKM Wellhead: 11" 5M FMC w/ 2 7/8" WKM Tubing Hanger, EUE lift threads, 2.5"" CIW H BPV profile 13 3/8" 48 ppf, H-40 ~ 9 5/8", 47 ppf, L-80 BTC I 2931' ,.. 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.0058 bpf) 7" 29#, L-80, BTC production casing (drift ID = 6.059, Annular cap. = .0371 bp~ RA Tag 5219' SlinaJatlon &.mmary: Frac '0' Sands (5522-5536') wI 30250 Ibs of 16/20 mesh Carbo-Lite GI'IMII PackSt."ßIJI(y. 'N' Sands Frac Pack - 20-40 Mesh Gravel behind screens Perforation &.mmary Ref log: 8125190 & 7/23/92 GRt CCL Size SPF Interval (TVD) 'N' Sand 4.5 " 24 5334' - 5356' {4111 '-4130') 4.5" 24 5372' - 5382' (4143'-41521 4.5" 24 541)4' - 5408' (4170'-4174') 4.5" 24 5433' - 5438' {4195'-41991 '0' Sand 4.5" 4 5522' - 5536' (4270'-4282') 111/16" 6 5538' - 5568' (4284'-4310') (,u . I ¡-1.....0Jtt- MPG-03 Orig. RKB. elev. = 30' (Parker 141) Orig. KDB-GL = 29.8' (Parker 141) Orig. KDB-SL = 59.3' (Parker 141) ~ ~ 5 jts of 2-7/8" tubing to 176' 9-5/8" Cement retainer at 1981' - 7" stub at 1984' 7" cut at 2194' ~ 7" cut at 2750' -- Bridge Plug at 3201' KOP @ 800' Max hole angle = 55 deg at 4000' Hole angle thru perfs = 31 deg Top of cement at 3875' 7" Cement retainer at 4899' Baker S-22 Locator Seal Assy 5 molded seals (2.35ID) Baker SC-1 L Pkr 4946' 3792' TVD 27/8" Bakerweld .012 ga. screen 5324' - 55449' I 5449' 27/8" Bakerweld .012 ga. screen 5450' - 5462' 7" Baker Model '0' Pkr. 5464' (3.25 ¡D) W;#:1;:: HES 'X' Nipple (1.875" id) 5486' ~ (2.00" id) 5493' WLEG WLEG ELMO I 5493' ~.... 7"floatcollar(PBTD) I 5814' DATE REV. BY COMMENTS MILNE POINT UNIT 9/5/89 Drilled and cased by Parker 141 WELL MPG-03 7/29/92 CFP Workover API NO: 50-029-21927 3/04/04 Lee Hulme Set Up Canvas Drawing BP EXPLORATION (AK) 9/28/04 J. Cubbon P&A by Nabors 4ES MPG-03A prop.ed [22£]~ 20" 91.1 ppf, H-40 16050' Mol 16220' Mol 16407' MOl 16492' MOl oria Elev. = ' Orig. GL Elev. = ' Tree: 3-1/8" - 5M Wellhead: 11" 5M FMC Gen 6 ~ ~ HES X-Nipple (2.813" I 500' Mol 3-1/2" 9.2 ppf L-80 TCII Tubing (Drift ID = 2.867, Cap. = 0.0087 bpf) 9-5/8"4O#/ft L-80 BTC-M 1-1950' Mol 3 1/2' X 1 1/2" MMG GLM 12100' MO HES X-Nipple (2.813") 15649' MOl 7" X 3 1/2" Baker Premier PKR 15950' MOl _F ~:~~ 3 1/2' X 1 1/2" MMG GLM 3 1/2' X 1 1/2" MMG GLM ~ NB Perforations: to be determined 6 spf between 5900-5940' MD OA Perforations: to be determined 6 spf between 6135- 6190' MD 3 1/2' X 1 1/2" MMG GLM 3 1/2' X 1 1/2" MMG GLM 7" X 3 1/2" Baker S-3 Packer OB Perfora- tions: to be determined 6 spf between 6255 -6290' MD 3 1/2' X 1 1/2" MMG GLM 3 1/2' X 1 1/2" MMG GLM HES XN-Nipple 2.75" Min. ID 31/2" WLEG 7" 26 ppf, L-80, BTC-MOD Casing ( drift ID = 6.151 ", cap. = 0.0383 bpf) DATE REV: BY 10/15/04 W Quay 7" float shoe COMMENTS Proposed Selective Injector MILNE POINT UNIT WELL MPG-03A BP EXPLORATION (AK) . L L____________________________________, t N2800:!j '1 ;: ¡ ~ w : u G-18 . I o : ~ G-8 . ¡ G-15. ¡ G-7 . ! G-14. i G-16. ¡ A G-6 (Abandoned): G-13. \ G-5 . G-17. ,,!,i . G-4 L, G-12: G-3 ] i,' G-11. · G-2 ¡f,j G-1O . · G-1 L G:: ¡ ] j ~ ~ r ~ \ ± J~2000 ~ (r-------------------------------- ~., II i w MPU G-PAD .- ~ 21 Mr §J - ---~ THIS SURVEY- Û 290 þ! «) ,0 CO 1-7 ~ " ~ II ~- I 20 LEGEND n . EXISTING CONDUCTOR ~ AS-STAKED CONDUCTOR ð ABANDONED CONDUCTOR VICINITY MAP N.T.S. NOTES 1. DATE OF SURVEY: JULY 15, 1989. 2. REFERENCE FIELD BOOK: MP 13-89 PAGES 22-24. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD 27. 4. PAD SCALE FACTOR IS 0.999903725. 5. HORIZONTAL AND VERTICAL CONTROL IS BASED ON MPU G-PAD MONUMENTS G-1 AND G-2. 6. ELEVATIONS ARE BPX MILNE POINT DATUM M.S.L. 7. GEODETIC COORDINATES ARE NAD 27. LOCATED WITHIN PROTRACTED SEC. 27, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION SECTION NO. COORDINA TES COORDINA TES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS OFFSETS MPG-1 Y= 6,014,071.65 N 2200.32 70'26'56.686" 70.4490794' 29.3' 1,635' FSL 3,645' FNL X= 557,260.71 E 1,185.25 149'31'58.280" 149.5328555' 3,346' FEL MPG-2 Y= 6,014,130.94 N 2,260.18 70'26'57.269" 70.4492414' 29.2' 1,695' FSL 3,585' FNL X= 557,252.51 E 1,185.48 149'31'58.508" 149.532919' 3,353' FEL MPG-3 Y= 6,014,190.03 N 2,319.92 70'26'57.851" 70.4494031' 29.3' 1,754' FSL 3,526' FNL X= 557,243.78 E 1,185.16 149'31'58.751" 149.5329864' 3,362' FEL MPG-4 Y=6,014,249.92 N 2,380.43 70'26'58.441" 70.4495669' 29.6' 1,814' FSL 3,466' FNL X= 557,235.15 E 1,185.04 149'31'58.991" 149.5330531' 3,370' FEL NOTE:THIS CERTIFICATE IS A RE-ISSUE AS-BUILT OF CONDUCTORS G1 Fm' Rn O__bi___e,t DRAWN, MLO CHECKED, LO'H DATE: 10-20-04 DRAWING: FRB04 MPG 04-00 MLO LO.N ¡ ff]~~¡m;o JOB NO, £NCINŒRS AND I,NCI SUIt'Æ'fORS SCALE: IlDlIIIEST F1R£IIEED lANE BY CHK ANOfOIWÆ. ALASKA HIIOJ o 10-20-04 RE-ISSUED, FORMATTED TO CONFORM TO CURRENT BP STANDARDS RE\1S1ON NO. DATE THRU G4 DATED AND STAMPED DEC 10, 1990 ObP '"=200' MILNE POINT UNIT G-PAD RE-ISSUE AS-BUILT CONDUCTOR WELLS MPG 1 THRU 4 SHEET, 1 OF 1 Well Status .~ Gas MiscI* Shut-In Not Yet ITd Not Yet ~ NulIUnkooWn .OI~ 01 Producer Gas lift 01 Producer 01 ~ Shut-In OI~ 01 .01 \Vel !S Bà For RedriI TSSS OS Malrken Reservoir TSBD OA Malrken Water Water I.:ftJl¡i.¡...-... ~;ð~-" C"'h...... ,~ SURVEY PROGRAM _: MPG.ß3A wp06 (MPG-03/Plan MPG.ß3Aj Depth Fro Depfh TQ SmveyiP1an Tool Created By: Troy J_ky Date: 10/14/21 195030 6492.36 Pmuned:MPG43A wp06 V39 Checked: Date_ Reviewed: Date:_ \\fELL DETAILS N_ - - lÆ!_ ~ Slot MPG..ü3 2457.: 865J}5 6014100,32 55124154 ro"ZlfS7.854N 14W3fSR758W 0' TARGETDETArLS Name ND +Nf-S +Ef-W Northing Easting Shape 150) DLeg TFace VSoc Target 1 CASING DETAILS TVD MD Name Size KOP REFERENCE INFORMATION FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 2 3 4 5 6 7 8 COMPANY DETAILS lV.lt"lr't}.;)f'\ ratU(¡.~· q;jQ.;).GU ¿1::1;J.OÖ ')QðU.n:l' oolQ AILS o. 1800- 2400- 3000- 4200- -¡;¡ ~ 1ê. t ¿¡ íI ~ > " 1: E-< 3600- SURVEY PROGRAM Plan: MPG.Q3A wpiJß (MPG-03IPhm I>iJPG.Q3A) Depth Fm Depth To SurveyfPlan T~I Cre-atBd By: Troy Jakabosky Date: 1O!l4/Z004 1950.30 6492,36 MWD+IFR+-MS Ched<:í!d; Date_ I WEL DETAiLS Name NrniliIng Eætmg '-">ud, lnn:gifUde SJO! MPC..o32457.". 8651)5 6014100.32 70"26'57.854N !49°31'58.758W 03 TARGET DETAILS Name TVD +Nf-S +EI-W Northing Eastlng Shape ( ( 150) ( SECTION DETAILS See MD !no AzI TVD +Nf-S +Ef-W Dug TF ace vSec Target I 2 3 4 5 6 MPG-03A T! 7 8 COMPANY DETAiLS REFERENCE INFORMATION BPAnltlCQ I'" J R~ IR, ,'" "'" CASING DETAILS No. TVD MD Name Size KOP FORMATION TOP DETAILS TVDPath MDPath Formallon No. I 2 3 4 5 6 7 8 9 j() ¡¡ 12 13 14 15 .36 56:87 62.89 .- - - - - - : - - ¡-¡;:; - - nq i -.1 : ."'~ ~" "'. M-' I /" ~ "'- ....;- /" - - - . . ß- ,,>- :4001 . I/° i .-- . / ., f i- L. ". . _iY ~ #- - I ¡O , , , , , , , , , , , , , I , , , , , , , , , I , I j j j , , , I I I I I , , , , , I 3 2000 1500 1000 500 2000- û 15 ]' ¢; o o t:? +" ¡ ~ :::;;: .s [5 (/) . . BP BP Planning Report Targets Name ft -Polygon 3 4363.50 2195.68 3680.79 6016414.00 560907.00 70 27 19.439 N 149 30 10.634 W -Plan out by 405.07 at 4363.50 1865.44 3446.22 6016082.00 560675.00 70 27 16.192 N 149 30 17.529 W Plan Section Information ft 1950.30 39.71 61.10 1843.20 218.47 412.54 0.00 0.00 0.00 0.00 1970.30 39.98 57.38 1858.55 225.02 423.54 12.00 1.34 -18.61 -85.00 2300.30 39.98 57.38 2111.44 339.32 602. " 0.00 0.00 0.00 0.00 2460.30 40.40 47.47 2233.79 402.14 683.70 4.00 0.27 -6.19 -90.00 2961.30 56.87 62.89 2564.85 609.59 993.23 4.00 3.29 3.08 40.51 6252.11 56.87 62.89 4363.50 1865.44 3446.22 0.00 0.00 0.00 0.00 MPG-03A r1 6292.36 56.87 62.89 4385.50 1880.80 3476.23 0.00 0.00 0.00 0.00 6492.36 56.87 62.89 4494.81 1957.13 3625.31 0.00 0.00 0.00 0.00 Survey MD NIS FJW J)LS MapN ft ft ft çk(1g11 ()()ft ft 1950.30 39.71 61.10 1843.20 1779.70 218.47 412.54 0.00 6014411.93 557654.35 9 5/8" KOP 1970.30 39.98 57.38 1858.55 1795.05 225.02 423.54 12.00 6014418.57 557665.30 End Dlr : 1970 1976.75 39.98 57.38 1863.50 1800.00 227.25 427.03 0.00 6014420.83 557668.77 BPRF 2000.00 39.98 57.38 1881.31 1817.81 235.31 439.61 0.00 6014428.97 557681.29 MWD+IFR+MS 2100.00 39.98 57.38 1957.94 1894.44 269.94 493.72 0.00 6014464.02 557735.13 MWD+IFR+MS 2200.00 39.98 57.38 2034.57 1971.07 304.58 547.84 0.00 6014499.07 557788.97 MWD+IFR+MS 2300.00 39.98 57.38 2111.21 2047.71 339.21 601.95 0.00 6014534.12 557842.81 MWD+IFR+MS 2300.30 39.98 57.38 2111.44 2047.94 339.32 602.11 0.00 6014534.22 557842.97 Start Dir 4/100 2400.00 40.14 51.18 2187.77 2124.27 376.74 654.15 4.00 6014572.04 557894.71 MWD+IFR+MS 2460.30 40.40 47.47 2233.79 2170.29 402.14 683.70 4.00 6014597.66 557924.06 MWD+IFR+MS 2500.00 41.62 49.03 2263.75 2200.25 419.48 703.13 4.00 6014615.15 557943.36 MWD+IFR+MS 2600.00 44.77 52.63 2336.65 2273.15 462.65 756.21 4.00 6014658.72 557996.10 MWD+IFR+MS 2700.00 48.02 55.84 2405.62 2342.12 504.91 814.98 4.00 6014701.43 558054.54 MWD+IFR+MS 2800.00 51.36 58.74 2470.31 2406.81 546.06 879.15 4.00 6014743.07 558118.38 MWD+IFR+MS 2900.00 54.76 61.38 2530.41 2466.91 585.90 948.41 4.00 6014783.44 558187.33 MWD+IFR+MS 2961 .30 56.87 62.89 2564.85 2501.35 609.59 993.23 4.00 6014807.47 558231 .96 End Dlr : 2961 3000.00 56.87 62.89 2586.00 2522.50 624.36 1022.08 0.00 6014822.46 558260.70 MWD+IFR+MS 3100.00 56.87 62.89 2640.66 2577.16 662.53 1096.62 0.00 6014861.19 558334.93 MWD+IFR+MS 3200.00 56.87 62.89 2695.32 2631 .82 700.69 1171.16 0.00 6014899.92 558409.17 MWD+IFR+MS 3269.86 56.87 62.89 2733.50 2670.00 727.35 1223.24 0.00 6014926.98 558461.04 MPG-03A Fault1 3300.00 56.87 62.89 2749.97 2686.47 738.85 1245.70 0.00 6014938.65 558483.41 MWD+IFR+MS 3400.00 56.87 62.89 2804.63 2741.13 777.D1 1320.24 0.00 6014977 .38 558557.65 MWD+IFR+MS 3500.00 56.87 62.89 2859.29 2795.79 815.18 1394.78 0.00 6015016.11 558631.89 MWD+IFR+MS 3600.00 56.87 62.89 2913.94 2850.44 853.34 1469.32 0.00 6015054.84 558706.12 MWD+IFR+MS 3700.00 56.87 62.89 2968.60 2905.10 891.50 1543.86 0.00 6015093.57 558780.36 MWD+IFR+MS 3800.00 56.87 62.89 3023.26 2959.76 929.66 1618.40 0.00 6015132.30 558854.60 MWD+IFR+MS 3900.00 56.87 62.89 3077.91 3014.41 967.82 1692.95 0.00 6015171.03 558928.84 MWD+IFR+MS 4000.00 56.87 62.89 3132.57 3069.07 1005.99 1767.49 0.00 6015209.76 559003.08 MWD+IFR+MS 4100.00 56.87 62.89 3187.23 3123.73 1044.15 1842.03 0.00 6015248.49 559077.31 MWD+IFR+MS 4200.00 56.87 62.89 3241.88 3178.38 1082.31 1916.57 0.00 6015287.22 559151.55 MWD+IFR+MS 4300.00 56.87 62.89 3296.54 3233.04 1120.47 1991.11 0.00 6015325.95 559225.79 MWD+IFR+MS 4400.00 56.87 62.89 3351.20 3287.70 1158.64 2065.65 0.00 6015364.68 559300.03 MWD+IFR+MS 4500.00 56.87 62.89 3405.85 3342.35 1196.80 2140.19 0.00 6015403.41 559374.27 MWD+IFR+MS 4600.00 56.87 62.89 3460.51 3397.01 1234.96 2214.73 0.00 6015442.14 559448.50 MWD+IFR+MS 4700.00 56.87 62.89 3515.17 3451.67 1273.12 2289.27 0.00 6015480.87 559522.74 MWD+IFR+MS . . BP BP Planning Report Survey EIW DLS MapN ft <:1eg1100ft ft 4800.00 56.87 62.89 3569.82 3506.32 1311.28 2363.81 0.00 6015519.60 559596.98 MWD+IFR+MS 4900.00 56.87 62.89 3624.48 3560.98 1349.45 2438.35 0.00 6015558.33 559671.22 MWD+IFR+MS 4940.29 56.87 62.89 3646.50 3583.00 1364.82 2468.38 0.00 6015573.93 559701.13 TUZC 5000.00 56.87 62.89 3679.14 3615.64 1387.61 2512.89 0.00 6015597.06 559745.46 MWD+IFR+MS 5100.00 56.87 62.89 3733.79 3670.29 1425.77 2587.43 0.00 6015635.79 559819.69 MWD+IFR+MS 5200.00 56.87 62.89 3788.45 3724.95 1463.93 2661.97 0.00 6015674.52 559893.93 MWD+IFR+MS 5300.00 56.87 62.89 3843.11 3779.61 1502.10 2736.51 0.00 6015713.25 559968.17 MWD+IFR+MS 5400.00 56.87 62.89 3897.76 3834.26 1540.26 2811.05 0.00 6015751.98 560042.41 MWD+IFR+MS 5401.35 56.87 62.89 3898.50 3835.00 1540.77 2812.06 0.00 6015752.50 560043.41 Ugnu-MA 5423.30 56.87 62.89 3910.50 3847.00 1549.15 2828.42 0.00 6015761.00 560059.71 Ugnu-MB1 5500.00 56.87 62.89 3952.42 3888.92 1578.42 2885.59 0.00 6015790.71 560116.65 MWD+IFR+MS 5512.95 56.87 62.89 3959.50 3896.00 1583.36 2895.25 0.00 6015795.72 560126.26 Ugnu-MB2 5600.00 56.87 62.89 4007.08 3943.58 1616.58 2960.13 0.00 6015829.44 560190.89 MWD+IFR+MS 5700.00 56.87 62.89 4061.73 3998.23 1654.75 3034.67 0.00 6015868.17 560265.12 MWD+IFR+MS 5776.42 56.87 62.89 4103.50 4040.00 1683.91 3091.64 0.00 6015897.76 560321.85 Ugnu-MC 5800.00 56.87 62.89 4116.39 4052.89 1692.91 3109.21 0.00 6015906.90 560339.36 MWD+IFR+MS 5845.94 56.87 62.89 4141.50 4078.00 1710.44 3143.46 0.00 6015924.69 560373.47 SBF2-NA 5899.00 56.87 62.89 4170.50 4107.00 1730.69 3183.01 0.00 6015945.24 560412.86 SBF1-NB 5900.00 56.87 62.89 4171.05 4107.55 1731.07 3183.76 0.00 6015945.63 560413.60 MWD+IFR+MS 5944.74 56.87 62.89 4195.50 4132.00 1748.14 3217.10 0.00 6015962.95 560446.81 SBE4-NC 5988.65 56.87 62.89 4219.50 4156.00 1764.90 3249.84 0.00 6015979.96 560479.41 SBE2-NE 6000.00 56.87 62.89 4225.70 4162.20 1769.23 3258.30 0.00 6015984.36 560487.84 MWD+IFR+MS 6069.15 56.87 62.89 4263.50 4200.00 1795.62 3309.84 0.00 6016011.14 560539.17 SBE1-NF 6100.00 56.87 62.89 4280.36 4216.86 1807.39 3332.84 0.00 6016023.09 560562.08 MWD+IFR+MS 6129.53 56.87 62.89 4296.50 4233.00 1818.66 3354.85 0.00 6016034.52 560584.00 TSBD-Top OA 6197.22 56.87 62.89 4333.50 4270.00 1844.50 3405.31 0.00 6016060.74 560634.25 TSBC-Base OA 6200.00 56.87 62.89 4335.02 4271.52 1845.56 3407.38 0.00 6016061.82 560636.31 MWD+IFR+MS 6252.11 56.87 62.89 4363.50 4300.00 1865.44 3446.22 0.00 6016082.00 560675.00 MPG-03A T1 6292.36 56.87 62.89 4385.50 4322.00 1880.80 3476.23 0.00 6016097.59 560704.88 SBA5-Base OB 6300.00 56.87 62.89 4389.67 4326.17 1883.72 3481.92 0.00 6016100.55 560710.55 MWD+IFR+MS 6400.00 56.87 62.89 4444.33 4380.83 1921.88 3556.46 0.00 6016139.28 560784.79 MWD+IFR+MS 6492.00 56.87 62.89 4494.61 4431.11 1956.99 3625.03 0.00 6016174.91 560853.09 7" 6492.36 56.87 62.89 4494.81 4431.31 1957.13 3625.31 0.00 6016175.05 560853.36 MWD+IFR+MS WELL DETAILS COMPANY DETAll.S ANTI ·COLLISION SETTINGS Name- +N!-S +E!-W Northing MPC-03 2457.51 865.05 6014190.32 -128 20 -100 -80 -60 --40 -20 0 270 --20 -40 -60 -80 -100 -120 - !.illirude Longi_ SJot Interval: 25.00 To: 6492.36 Reference: Plan: MPG-03A wp06 557243.54 7O~26'57.g54N 149°31'58.758W 03 BP Amoco SURVEY PROGRAM Depth Pm Depth To Swwy!P1aß 1950.30 6492.36 Planned; MPG..03A wp06 V39 Tool MWD+1FR+MS WEUPATH DETAILS From Colour ToMD P1anMPG-03A MPG-03A 0 1500 p-,}ffi¡!f:~~; 1500 2000 2000 2500 Rig- 2500 3000 Ref. Datum· 34.3+292 ß350ft 3000 3500 ~ 3500 4000 4000 4500 6J.64~ 0.00 0.00 34.30 4500 5000 5000 5500 5500 6000 6000 6500 6500 1000 1000 1500 7500 8000 8000 8500 8500 9000 9000 9500 90 Set Jot &J TVD MPG"Q3A 1'1 . . BP Anticollision Report Company: BP Amoco Field: Milne Point Reference Site: M Pt G Pad Reference Well: MPG-Q3 Reference Wellpath: Plan MPG-Q3A GLOBAL SCAN APPLffiD: All wellpatbs within 200' + 10011000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 1950.30 to 6492.36 ft Maximum Radius: 845.81 ft Date: 10/14/2004 Time: 14:14:37 Well: MPG-Q3. True North 34.3 + 29.2 63.5 Page: 1 Co-ordinate(NE) Reference: VertIc:aI (lVD) Referenc:e: Reference: Error Model: Scan Method: Error Surface: Db: Oracle Pian: MPG-03A wp06 & NOT PLANNED P~OGR ISCWSA Ellipse Trav Cytinder North Ellipse + Casing Casing Points MD 1VD ÐJameter Hole Size Name ft ft in in 1950.30 1843.20 9.625 12.250 9 5/8" KOP 6492.00 4494.61 7.000 8.500 7" I Plan' MPG-03A wp06 Date Composed: 8/12/2004 Version: 39 Principal: Yes Tied-to: From: Definitive Path Summary <--------------- Offset Wellpath -------------> Reference Offset Ctr-Ctr No-Go All0wabIe Site Well WeIIpath MD MD I>istaJK:e Ateå DeViation WaJ'I,Ilng ft ft ft ft ft MPtGPad MPG-03 MPG-03 Vl 4950.00 1950.00 0.00 0.00 0.00 FAIL: NOERRORS M Pt G Pad MPG-04 MPG-04 Vl 1979.81 2100.00 498.62 84.18 414.43 Pass: Major Risk MPtGPad MPG-04 Plan MPG-04A VO Plan: 1979.81 2100.00 498.62 84.25 414.37 Pass: Major Risk MPtGPad MPG-06 MPG-06 Vl 2085.34 2075.00 45.15 22.18 22.97 Pass: Minor 1/200 M Pt G Pad MPG-ll MPG-ll V2 1963.51 1975.00 203.76 78.77 124.99 Pass: Major Risk MPtGPad MPG-16 MPG-16 V6 1968.63 2050.00 231.27 45.00 186.27 Pass: Major Risk M Pt G Pad MPG-16 MPG-16L1 V4 1968.63 2050.00 231.27 44.87 186.40 Pass: Major Risk M Pt G Pad MPG-16 MPG-16PBl V9 1968.63 2050.00 231.27 44.85 186.42 Pass: Major Risk MPtGPad MPG-16 MPG-16PB2 V2 1968.63 2050.00 231.27 44.85 186.42 Pass: Major Risk M Pt G Pad MPG-18 MPG-18 V6 1952.62 1900.00 267.61 47.06 220.55 Pass: Major Risk MPtGPad MPG-18 MPG-18Ll V3 1952.62 1900.00 267.61 46.80 220.81 Pass: Major Risk MPtGPad MPG-18 MPG-18PBl V2 1952.62 1900.00 267.61 46.90 220.71 Pass: Major Risk M Pt G Pad Plan MPG-19 MPG-19 V3 Plan: MPG-19 4949.94 2025.00 323.18 154.07 169.11 Pass: Major Risk Site: M Pt G Pad Well: MPG-03 Rule Assigned: NOERRORS Wellpath: MPG-03 Vl Inter-Site Error: 0.00 ft Referenc:e Offset SemI-~or Aq Ctr-Ctr . No-Go All0wabIe MD 1VD MD 1VD Ref OffsetTFO+AZI TFO-HS ~Istànc:e Ateå DeViation W~ ft ft ft ft ft ft cieg deg in ft ft ft 4950.00 1842.96 1950.00 1842.96 37.17 12.36 61.16 0.00 9.625 0.00 0.00 0.00 FAIL 1974.98 1862.14 1975.00 1862.16 12.52 12.79 150.27 92.90 9.625 0.61 0.00 0.61 Pass 1999.96 1881.28 2000.00 1881.29 12.52 13.24 147.79 90.42 9.625 1.66 0.00 1.66 Pass 2024.94 1900.43 2025.00 1900.36 12.52 13.71 145.24 87.86 9.625 2.71 0.00 2.71 Pass 2049.92 1919.57 2050.00 1919.39 12.52 14.19 143.13 85.75 9.625 3.78 0.00 3.78 Pass 2074.89 1938.70 2075.00 1938.37 12.53 14.66 141.20 83.83 9.625 4.87 0.00 4.87 Pass 2099.87 1957.84 2100.00 1957.31 12.53 15.13 139.38 82.00 9.625 5.99 0.00 5.99 Pass 2124.84 1976.98 2125.00 1976.16 12.53 15.64 137.06 79.68 9.625 7.12 0.00 7.12 Pass 2149.81 1996.11 2150.00 1994.83 12.54 16.15 133.51 76.14 9.625 8.30 0.00 8.30 Pass 2174.77 2015.24 2175.00 2013.33 12.55 16.66 129.24 71.86 9.625 9.55 0.00 9.55 Pass 2199.72 2034.36 2200.00 2031.64 12.55 17.18 124.58 67.20 9.625 10.91 0.00 10.91 Pass 2224.65 2053.46 2225.00 2049.75 12.56 17.74 119.72 62.34 9.625 12.45 0.00 12.45 Pass 2249.56 2072.55 2250.00 2067.63 12.57 18.31 114.82 57.44 9.625 14.24 0.00 14.24 Pass 2274.44 2091.62 2275.00 2085.27 12.58 18.89 110.10 52.72 9.625 16.31 0.00 16.31 Pass 2299.29 2110.66 2300.00 2102.68 12.59 19.46 105.70 48.33 9.625 18.69 0.00 18.69 Pass 2323.86 2129.49 2325.00 2119.84 12.59 20.08 101.71 45.80 9.625 21.53 0.00 21.52 Pass 2348.33 2148.23 2350.00 2136.77 12.58 20.71 98.75 44.36 9.625 24.94 0.00 24.94 Pass 2372.70 2166.89 2375.00 2153.45 12.57 21.32 96.60 43.73 9.625 28.91 0.00 28.90 Pass 2396.95 2185.44 2400.00 2169.88 12.57 21.93 95.07 43.69 9.625 33.39 0.00 33.39 Pass 2421.07 2203.88 2425.00 2186.12 12.55 22.58 94.03 44.15 9.625 38.33 0.00 38.33 Pass 2445.09 2222.20 2450.00 2202.27 12.53 23.23 93.45 45.04 9.625 43.59 0.00 43.59 Pass 2469.48 2240.77 2475.00 2218.34 12.53 23.91 93.37 45.53 9.625 49.11 0.00 49.11 Pass . . BP Anticollision Report Site: M Pt G Pad Well: MPG-03 WeUpath: MPG-03 V1 Rule Assigned: NOE RRORS Inter-Site Error: 0.00 ft 2494.82 2259.87 2500.00 2234.32 12.56 24.64 93.65 44.82 9.625 54.41 0.00 54.41 Pass 2520.34 2278.88 2525.00 2250.25 12.59 25.39 93.92 44.12 9.625 59.33 0.00 59.33 Pass 2546.03 2297.78 2550.00 2266.17 12.62 26.13 94.26 43.52 9.625 63.83 0.00 63.83 Pass 2571.88 2316.53 2575.00 2282.10 12.65 26.88 94.66 43.00 9.625 67.93 0.00 67.93 Pass 2597.87 2335.14 2600.00 2298.03 12.68 27.62 95.11 42.56 9.625 71.61 0.00 71.61 Pass 2623.98 2353.56 2625.00 2313.97 12.71 28.35 95.61 42.18 9.625 74.86 0.00 74.86 Pass 2650.21 2371.80 2650.00 2329.94 12.75 29.08 96.15 41.87 9.625 77.63 0.00 77.63 Pass 2676.54 2389.81 2675.00 2345.93 12.78 29.80 96.74 41.62 9.625 79.93 0.00 79.93 Pass 2702.95 2407.59 2700.00 2361.96 12.82 30.53 97.37 41.44 9.625 81.75 0.00 81.75 Pass 2729.42 2425.11 2725.00 2378.02 12.85 31.25 98.05 41.33 9.625 83.09 0.00 83.08 Pass 2755.93 2442.34 2750.00 2394.13 12.89 31.97 98.81 41.31 9.625 83.94 0.00 83.94 Pass 2782.45 2459.28 2775.00 2410.28 12.93 32.68 99.64 41.39 9.625 84.31 0.00 84.31 Pass 2808.98 2475.89 2800.00 2426.48 12.97 33.39 100.56 41.57 9.625 84.21 0.00 84.21 Pass 2835.48 2492.17 2825.00 2442.70 13.01 34.13 101.55 41.84 9.625 83.64 0.00 83.64 Pass 2861.95 2508.10 2850.00 2458.90 13.05 34.88 102.58 42.17 9.625 82.62 0.00 82.62 Pass 2888.36 2523.66 2875.00 2475.09 13.09 35.62 103.65 42.57 9.625 81.16 0.00 81.15 Pass 2914.70 2538.84 2900.00 2491.25 13.13 36.36 104.80 43.05 9.625 79.25 0.00 79.25 Pass 29~0.95 2553.62 2925.00 2507.41 13.18 37.10 106.06 43.67 7.000 76.91 0.00 76.91 Pass 2966.80 2567.85 2950.00 2523.65 13.22 37.85 107.49 44.60 7.000 74.15 0.00 74.15 Pass 2991.57 2581.39 2975.00 2539.94 13.26 38.60 108.91 46.02 7.000 71.29 0.00 71.28 Pass 3016.33 2594.93 3000.00 2556.30 13.31 39.35 110.53 47.64 7.000 68.47 0.00 68.47 Pass 3041.08 2608.45 3025.00 2572.74 13.36 40.08 112.42 49.53 7.000 65.71 0.00 65.71 Pass 3065.81 2621.97 3050.00 2589.29 13.41 40.81 114.64 51.75 7.000 63.03 0.00 63.03 Pass 3090.52 2635.48 3075.00 2605.96 13.46 41.54 117.25 54.36 7.000 60.49 0.00 60.49 Pass 3115.21 2648.97 3100.00 2622.74 13.51 42.27 120.27 57.38 7.000 58.11 0.00 58.10 Pass 3139.88 2662.46 3125.00 2639.60 13.56 43.00 123.69 60.81 7.000 55.96 0.00 55.96 Pass 3164.55 2675.94 3150.00 2656.47 13.61 43.73 127.45 64.56 7.000 54.12 0.00 54.12 Pass 3189.22 2689.42 3175.00 2673.35 13.67 44.46 131.51 68.62 7.000 52.63 0.00 52.63 Pass 3213.88 2702.90 3200.00 2690.25 13.72 45.19 135.83 72.94 7.000 51.52 0.00 51.52 Pass 3238.56 2716.39 3225.00 2707.06 13.78 45.98 140.22 77.33 7.000 50.84 0.00 50.84 Pass 3263.30 2729.91 3250.00 2723.60 13.84 46.79 144.32 81.43 7.000 50.60 0.00 50.60 Pass 3288.08 2743.46 3275.00 2739.87 13.89 47.59 148.04 85.15 7.000 50.73 0.00 50.73 Pass 3312.90 2757.03 3300.00 2755.86 13.96 48.39 151.33 88.44 7.000 51.16 0.00 51.16 Pass 3337.75 2770.61 3325.00 2771.67 14.02 49.24 154.30 91.41 7.000 51.80 0.00 51.79 Pass 3362.60 2784.19 3350.00 2787.51 14.08 50.09 157.21 94.32 7.000 52.55 0.00 52.55 Pass 3387.45 2797.77 3375.00 2803.36 14.14 50.94 160.07 97.18 7.000 53.43 0.00 53.43 Pass 3412.29 2811.34 3400.00 2819.24 14.21 51.79 162.87 99.98 7.000 54.42 0.00 54.42 Pass 3437.12 2824.92 3425.00 2835.17 14.28 52.62 165.61 102.72 7.000 55.57 0.00 55.57 Pass 3461.94 2838.48 3450.00 2851.19 14.34 53.45 168.34 105.45 7.000 56.97 0.00 56.97 Pass 3486.74 2852.04 3475.00 2867.31 14.41 54.28 171.01 108.12 7.000 58.62 0.00 58.62 Pass 3511.52 2865.58 3500.00 2883.52 14.48 55.11 173.62 110.73 7.000 60.52 0.00 60.52 Pass 3536.29 2879.12 3525.00 2899.76 14.55 55.96 176.07 113.18 7.000 62.62 0.00 62.62 Pass 3561.08 2892.67 3550.00 2915.92 14.62 56.82 178.27 115.38 7.000 64.78 0.00 64.78 Pass 3585.88 2906.22 3575.00 2931.98 14.69 57.68 180.23 117.34 7.000 66.96 0.00 66.96 Pass 3610.70 2919.79 3600.00 2947.94 14.76 58.53 181.98 119.09 7.000 69.15 0.00 69.15 Pass 3635.53 2933.36 3625.00 2963.76 14.84 59.46 183.50 120.61 7.000 71.29 0.00 71.29 Pass 3660.41 2946.96 3650.00 2979.34 14.91 60.41 184.76 121.87 7.000 73.25 0.00 73.25 Pass 3685.31 2960.57 3675.00 2994.68 14.99 61.35 185.78 122.89 7.000 75.01 0.00 75.01 Pass 3710.24 2974.19 3700.00 3009.77 15.07 62.30 186.58 123.69 7.000 76.57 0.00 76.57 Pass 3735.18 2987.83 3725.00 3024.65 15.15 63.31 187.24 124.35 7.000 77.93 0.00 77.93 Pass 3760.14 3001.47 3750.00 3039.44 15.22 64.33 187.85 124.96 7.000 79.14 0.00 79.14 Pass . . BP Anticollision Report Site: M PI G Pad Well: MPG-03 Wellpath: MPG-03 Vl Rule Assigned: NOERRORS Inter-Site Error: 0.00 ft 3785.11 3015.12 3775.00 3054.13 15.30 65.36 188.41 125.52 7.000 80.19 0.00 80.19 Pass 3810.08 3028.76 3800.00 3068.73 15.38 66.38 188.94 126.05 7.000 81.09 0.00 81.09 Pass 3835.06 3042.42 3825.00 3083.25 15.47 67.43 189.44 126.55 7.000 81.86 0.00 81.86 Pass 3860.04 3056.07 3850.00 3097.75 15.55 68.49 189.95 127.06 7.000 82.58 0.00 82.58 Pass 3885.02 3069.72 3875.00 3112.23 15.63 69.54 190.47 127.58 7.000 83.24 0.00 83.24 Pass 3910.00 3083.38 3900.00 3126.70 15.72 70.60 190.99 128.10 7.000 83.84 0.00 83.84 Pass 3934.98 3097.03 3925.00 3141.14 15.80 71.68 191.51 128.62 7.000 84.40 0.00 84.40 Pass 3959.96 3110.69 3950.00 3155.52 15.89 72.77 191.98 129.09 7.000 84.91 0.00 84.91 Pass 3984.95 3124.34 3975.00 3169.84 15.97 73.86 192.41 129.53 7.000 85.37 0.00 85.37 Pass 4009.94 3138.00 4000.00 3184.10 16.06 74.95 192.81 129.92 7.000 85.78 0.00 85.78 Pass 4034.93 3151.66 4025.00 3198.38 16.15 76.03 193.25 130.36 7.000 86.14 0.00 86.14 Pass 4059.91 3165.31 4050.00 3212.80 16.24 77.11 193.89 131.00 7.000 86.44 0.00 86.44 Pass 4084.88 3178.96 4075.00 3227.38 16.33 78.18 194.72 131.83 7.000 86.70 0.00 86.70 Pass 4109.83 3192.60 4100.00 3242.11 16.42 79.26 195.74 132.85 7.000 86.93 0.00 86.93 Pass 4134.77 3206.23 4125.00 3256.92 16.51 80.32 196.89 134.00 7.000 87.15 0.00 87.15 Pass 4159.71 3219.86 4150.00 3271.70 16.60 81.39 197.99 135.10 7.000 87.40 0.00 87.40 Pass 4184.66 3233.50 4175.00 3286.45 16.69 82.45 199.04 136.15 7.000 87.69 0.00 87.69 Pass 4209.61 3247.13 4200.00 3301.16 16.78 83.51 200.04 137.15 7.000 88.00 0.00 88.00 Pass 4234.56 3260.77 4225.00 3315.85 16.88 84.59 201.01 138.12 7.000 88.34 0.00 88.34 Pass 4259.51 3274.41 4250.00 3330.55 16.97 85.67 201.97 139.08 7.000 88.72 0.00 88.72 Pass 4284.47 3288.05 4275.00 3345.25 17.07 86.76 202.91 140.02 7.000 89.14 0.00 89.14 Pass 4309.42 3301.69 4300.00 3359.96 17.16 87.84 203.83 140.95 7.000 89.61 0.00 89.61 Pass 4334.36 3315.32 4325.00 3374.76 17.26 88.88 204.85 141.96 7.000 90.13 0.00 90.13 Pass 4359.27 3328.94 4350.00 3389.84 17.36 89.91 206.13 143.24 7.000 90.78 0.00 90.78 Pass 4384.14 3342.53 4375.00 3405.18 17.45 90.94 207.68 144.79 7.000 91.57 0.00 91.57 Pass 4408.95 3356.09 4400.00 3420.79 17.55 91.96 209.49 146.60 7.000 92.55 0.00 92.55 Pass 4433.72 3369.63 4425.00 3436.56 17.65 92.96 211.44 148.55 7.000 93.70 0.00 93.70 Pass 4458.49 3383.16 4450.00 3452.33 17.75 93.95 213.35 150.47 7.000 94.93 0.00 94.93 Pass 4483.26 3396.70 4475.00 3468.09 17.84 94.94 215.23 152.34 7.000 96.24 0.00 96.24 Pass 4508.03 3410.24 4500.00 3483.83 17.94 95.92 217.06 154.17 7.000 97.63 0.00 97.63 Pass 4532.79 3423.78 4525.00 3499.59 18.04 96.91 218.85 155.96 7.000 99.14 0.00 99.14 Pass 4557.55 3437.31 4550.00 3515.46 18.15 97.89 220.58 157.69 7.000 100.87 0.00 100.87 Pass 4582.29 3450.83 4575.00 3531.41 18.25 98.87 222.25 159.36 7.000 102.83 0.00 102.83 Pass 4607.03 3464.35 4600.00 3547.47 18.35 99.85 223.85 160.96 7.000 105.00 0.00 105.00 Pass 4631.74 3477.86 4625.00 3563.68 18.45 100.78 225.42 162.53 7.000 107.44 0.00 107.44 Pass 4656.39 3491.33 4650.00 3580.16 18.55 101.69 227.02 164.13 7.000 110.27 0.00 110.27 Pass 4680.98 3504.77 4675.00 3596.90 18.65 102.61 228.64 165.75 7.000 113.51 0.00 113.51 Pass 4705.49 3518.17 4700.00 3613.91 18.75 103.52 230.26 167.37 7.000 117.16 0.00 117.16 Pass 4729.94 3531.53 4725.00 3631.17 18.86 104.36 231.85 168.96 7.000 121.23 0.00 121.23 Pass 4754.32 3544.86 4750.00 3648.66 18.96 105.19 233.35 170.46 7.000 125.70 0.00 125.70 Pass 4778.64 3558.15 4775.00 3666.38 19.06 106.02 234.77 171.88 7.000 130.56 0.00 130.56 Pass 4802.89 3571.40 4800.00 3684.33 19.17 106.85 236.09 173.20 7.000 135.81 0.00 135.81 Pass 4827.06 3584.62 4825.00 3702.49 19.27 107.62 237.33 174.44 7.000 141.42 0.00 141.42 Pass 4851.17 3597.79 4850.00 3720.83 19.37 108.38 238.48 175.59 7.000 147.36 0.00 147.36 Pass 4875.22 3610.93 4875.00 3739.36 19.48 109.14 239.54 176.65 7.000 153.62 0.00 153.62 Pass 4899.18 3624.03 4900.00 3758.07 19.58 109.90 240.53 177.64 7.000 160.20 0.00 160.20 Pass 4923.07 3637.09 4925.00 3776.97 19.68 110.61 241.44 178.55 7.000 167.10 0.00 167.09 Pass 4946.86 3650.09 4950.00 3796.09 19.79 111.31 242.29 179.40 7.000 174.35 0.00 174.34 Pass 4970.55 3663.04 4975.00 3815.40 19.89 112.01 243.08 180.19 7.000 181.94 0.00 181.94 Pass 4994.14 3675.93 5000.00 3834.93 19.99 112.71 243.81 180.92 7.000 189.89 0.00 189.89 Pass 5017.61 3688.76 5025.00 3854.66 20.10 113.35 244.48 181.60 7.000 198.18 0.00 198.18 Pass . . BP Anticollision Report Com~: BP Amóco Date: 10/1412004 Time: 14:14:37 Field: Milne Point Reference Site: MPtGPäd Co-otdinate(NJ.S) Reference: RefeJTence WeB: MPG,,03 Vertical ('I'VD)Reference: RefeJTence WeHpatb: Plan MPG..03A Site: M Pt G Pad WeB: MPG-03 Rule Assigned: WeBpath: MPG-03 V1 Inter-Site Error: RefeJTence Otrset Semi-~orAxis Ctr-Ctr N~GO MD TV» MD TV» Ref Offset TFO+AZI·TFO-HS ~Area ft ft ft ft ft ft deg deg in ft ft 5040.96 3701.52 5050.00 3874.62 20.20 113.98 245.10 182.21 7.000 206.85 0.00 Pass 5064.18 3714.21 5075.00 3894.80 20.30 114.61 245.65 182.76 7.000 215.89 0.00 215.89 Pass 5087.26 3726.83 5100.00 3915.19 20.40 115.24 246.15 183.26 7.000 225.30 0.00 225.29 Pass 5110.23 3739.39 5125.00 3935.77 20.51 115.82 246.59 183.70 7.000 235.D1 0.00 235.01 Pass 5133.12 3751.90 5150.00 3956.48 20.61 116.40 246.98 184.09 7.000 244.92 0.00 244.92 Pass 5155.94 3764.37 5175.00 3977.30 20.71 116.97 247.31 184.42 7.000 255.03 0.00 255.03 Pass 5178.68 3776.80 5200.00 3998.25 20.81 117.55 247.60 184.71 7.000 265.34 0.00 265.34 Pass 5201.34 3789.18 5225.00 4019.28 20.91 118.11 247.87 184.99 7.000 275.82 0.00 275.82 Pass 5223.93 3801.53 5250.00 4040.36 21.02 118.66 248.19 185.30 7.000 286.42 0.00 286.42 Pass 5246.43 3813.83 5275.00 4061.46 21.12 119.21 248.54 185.65 7.000 297.16 0.00 297.16 Pass 5268.85 3826.08 5300.00 4082.60 21.22 119.76 248.93 186.04 7.000 308.03 0.00 308.03 Pass 5291.19 3838.29 5325.00 4103.75 21.32 120.30 249.34 186.45 7.000 319.02 0.00 319.02 Pass 5313.44 3850.45 5350.00 4124.93 21.42 120.84 249.78 186.89 7.000 330.15 0.00 330.15 Pass 5335.60 3862.57 5375.00 4146.12 21.52 121.37 250.23 187.34 7.000 341.41 0.00 341.41 Pass 5357.67 3874.63 5400.00 4167.33 21.62 121.91 250.70 187.81 7.000 352.80 0.00 352.80 Pass 5379.67 3886.65 5425.00 4188.55 21.73 122.44 251.17 188.28 7.000 364.31 0.00 364.31 Pass 5401.65 3898.67 5450.00 4209.80 21.83 122.97 251.61 188.72 7.000 375.88 0.00 375.88 Pass 5423.62 3910.67 5475.00 4231.07 21.93 123.49 252.02 189.13 7.000 387.51 0.00 387.51 Pass 5445.56 3922.66 5500.00 4252.37 22.03 124.02 252.40 189.51 7.000 399.20 0.00 399.20 Pass 5467.48 3934.65 5525.00 4273.69 22.13 124.54 252.75 189.87 7.000 410.95 0.00 410.95 Pass 5489.38 3946.61 5550.00 4295.05 22.23 125.06 253.09 190.20 7.000 422.77 0.00 422.77 Pass 5511.24 3958.56 5575.00 4316.44 22.33 125.58 253.40 190.51 7.000 434.66 0.00 434.66 Pass 5533.08 3970.50 5600.00 4337.87 22.44 126.09 253.70 190.81 7.000 446.61 0.00 446.61 Pass 5554.90 3982.43 5625.00 4359.31 22.54 126.61 253.98 191.09 7.000 458.62 0.00 458.62 Pass 5576.72 3994.35 5650.00 4380.76 22.64 127.13 254.24 191.35 7.000 470.63 0.00 470.63 Pass 5598.54 4006.28 5675.00 4402.21 22.74 127.65 254.49 191.60 7.000 482.66 0.00 482.66 Pass 5620.35 4018.20 5700.00 4423.66 22.85 128.17 254.73 191.84 7.000 494.70 0.00 494.70 Pass 5642.16 4030.12 5725.00 4445.11 22.95 128.68 254.96 192.07 7.000 506.76 0.00 506.76 Pass 5663.95 4042.03 5750.00 4466.58 23.05 129.20 255.18 192.29 7.000 518.86 0.00 518.86 Pass 5685.71 4053.92 5775.00 4488.05 23.15 129.73 255.39 192.50 7.000 531.01 0.00 531.00 Pass 5707.45 4065.80 5800.00 4509.53 23.26 130.25 255.60 192.71 7.000 543.19 0.00 543.19 Pass 5729.17 4077.68 5825.00 4531.01 23.36 130.77 255.81 192.92 7.000 555.41 0.00 555.41 Pass 5750.90 4089.55 5850.00 4552.50 23.46 131.30 256.00 193.11 7.000 567.63 0.00 567.63 Pass 5772.62 4101.43 5875.00 4573.98 23.57 131.82 256.19 193.30 7.000 579.86 0.00 579.86 Pass 5794.34 4113.30 5900.00 4595.47 23.67 132.35 256.37 193.48 7.000 592.10 0.00 592.10 Pass 5809.58 4121.62 5917.53 4610.53 23.74 132.72 256.49 193.60 7.000 600.68 0.00 600.68 Pass Site: M PtG Pad WeB: MPG-04 Rule Assigned: Major Risk WeHpath: MPG-04 Vl Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr . N~GO AlloWable MD TV» MD TV» Ref Offset TFO...AZI TFO-HS ~ Area DtMådon W~ ft ft ft ft ft ft deg deg in ft ft ft 1979.81 1865.84 2100.00 2011.49 12.52 10.31 300.33 242.96 498.62 84.18 414.43 Pass 2000.96 1882.05 2125.00 2033.30 12.52 10.59 299.98 242.60 511.57 85.14 426.43 Pass 2022.11 1898.25 2150.00 2055.08 12.52 10.87 299.64 242.27 524.56 86.11 438.45 Pass 2043.25 1914.45 2175.00 2076.85 12.52 11.15 299.33 241.95 537.59 87.09 450.50 Pass 2064.38 1930.65 2200.00 2098.59 12.52 11.44 299.04 241.66 550.65 88.07 462.58 Pass 2085.52 1946.85 2225.00 2120.32 12.53 11.72 298.76 241.38 563.71 89.04 474.67 Pass 2106.71 1963.09 2250.00 2142.05 12.53 11.99 298.50 241.12 576.72 90.02 486.71 Pass 2127.94 1979.35 2275.00 2163.77 12.54 12.27 298.25 240.87 589.69 91.00 498.68 Pass 2149.21 1995.65 2300.00 2185.48 12.54 12.55 298.02 240.64 602.60 91.99 510.61 Pass e e . fi 9 - !f6 3 d04-d\S MECHANICAL INTEGRITY REPORT . SPUD DATE: 812?J8~ OPER & FIELD CO"oC/) /::.u..Daro.l:-(Z4'11Y J:kf£ 9/'6/70 r RIG RELEASE: ?/(~r90 1-.TELL NUMBER !vtP(l ~-3 WELL DATA TD: ~&}{O MD lff.O"$ TVD J PBTD : .s-~ r ? MD 115""(9 TVD Casing: 7 '2.~ L Shoe: S8~( MD TVD, DV: MD -TVD Liner: Shoe: MD TVD, TOP: MD TVD Tubing: -'¿.Vg JiQ'li. MD TVDI Set at tc 90('") Packer .!)l{~L( Hole Size and eÝ~. I Perf s _~-7'$ 'f- to SS""2."2.. MECHANICAL INTEGRITY - PART 11 Annulus Press Test: IP I 15 min J 30 min Comments: /" MECHANICAL INTEGRITY - PART 12 67 9~"J.o[. »>(, Cement Volumes: Amt. Liner I Csfš-fH fi£(s I DV . " e..;" .07o~ l'i.oF 1,3 OZ., 12.. Ú> ," þ. fJl:,.. : .0 ~U Cmt vol to cover perfrl!.9i-.07 ði) 'fQ¡I"'/~ ).0171 -f~ð"-57¡1f ).O?é!t.:- ,,·8 ,,, ,., \«" 'Z. .03 'rl . f( 67-('·8 . Theoretical Toe .5*"3 ~ t.¡ - Leu (-~7 ) -:- .01-r:r ~ :?¥'f ~ Cement Bond Log (Yes or No)_ ~ CBL Evaluation, zone above perfs hd( rl!fu.", A. c; Produc.tion Log: Type I In AOGCC File . I Evaluation CONCLUSIONS: Part 11: . Part #2: jV\1 /~ ¡Ad, 'c:n-tcz .L. ~..~-\-.~ \~ ~.."> ~\Xrc.~.. \'-..~ CÐt~\~(J··æ""~ (Òt>-~-ÖLy -Ø3~ .,/2Jf l~z- rev. OS/20/87 C.028 49 49 32 00 W I Feet J o I . . , . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ;tj;:/tf (j-D3/1 PTD# 2Ot/~ VC¡ Development vService CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LA TERAL (If API number last two. (2) digits are between 60-69) Exploration Stratigraphic "CLUE ". The permit is ~~~e))bore segment of existing weD ~ . Permit No, .' API No. . Production. should continue to be reponed as a function' of tbe original API number. stated above. HOLE ]n accordance with' 20 AAC 25.005(f), aU records, data and logs acquired for tbe pilot bole must be clearly differentiated In both name (name on permit plus PH) and API Dum ber (50 70/80) fTom records, data and logs acquired for we)) (name on permit). Pll.,OT (PH) SPACING EX CEPT] ON DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance with 20 AAC 25..055~ Approval to perforate and produce is contingent upon issuance of I! conservation order approving a spa dng e:J ception. (Company Name) assumes tbe liability of any protest to tbe spacing .e:Jception tbat may occur. AU dry ditcb sample sets submitted to tbe Commission must be in no greater 1baD 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and ] 0' sample hite:r:vals tbrougb target zones. Field & Pool MILNE POINT. SCHRADER BLFF OIL - 525140 Well Name: Jy'IILNE PT UNIT SB G-03A Program SER Well bore seg 0 PTD#: 2042190 Company BP EXPLORATION (ALASKA) INC Initial Classffype SER/PEND GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal 0 Administration 1 Pßrmitfee attached . - - - - - · Yß$ - - - - - - - - - -- - - - - - - - - - 2 .Leasß.numberapRropriate. . . . . . . . . · . . . Yß$ . Sidetrack welllpcaíed inADL025906 aod. AOL Q2.55t8~ - - - - - - 3 .U.nlqueweltn.a!11ß.a[1Q oumb.er . . . . . . . .. ... . . .. . . . . . . . . . ........ Yß$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - -- .. . 4 WeJIJQC<ltßd lna d.efinedppol. - - - - -- - - - - .... Yß$ - - - - - - - - - - - - - - - - - - 5 WeJIJQcaled proper .dlstance. from driJling unitbound.al)' - - - - -- ....Ye$ - - - - - - - - - -- - - - - - - - - - - - 6 WellJQc<itßd pr.oper .dlstance from other wßlls . . . . . - - - - - - · Yß$ - - - - - - - - - - - - -- 7 .S.ufficient acrßageayailable In. dJilJiOg unji. - - - - - - - - - - · Yß$ - - - - - - - - - - - -- - - - - - 8 Jf.dßviated. js. weJlbQre platincJu.ded . - - - - - - - - - - - ..... Ye$ - - - - - - - - - - - - - - - - - - - - - - - - 9 .Qperator onl}' affected party. . . . - - - - - - - - - - - - - - - - - · Yß$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - 10 .Operator bas.approprlate.Qond inJorce . . . . . . _ . . . . . . . . . . . . . ........ YßS - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - .. . 11 Pßrmit can be issued without co.n$el'\lajion order. . . . . - - - - - - - - - - · Yßs - - - - -- - - - - - - - - - - - - - - - - - - - - - - Appr Date 12 Pßunit c.a[1 be lS$ued wjthQut admioistrati\le.approvaJ . . - - - - - - Yßs - - - - - - - - - - - - - - - -- - - - - - . SFD 10/26/2004 13 Can permit be approved before 15-day wait Yes 14 WellJQcatßd within area and strata authorized by l[1jectiplJ Ordßr # (PutlO# in.C9!11meots).(For. .Yßs · . . . Arßa Injectjo.n.Qrder No.. tO~B . . . . . . - - - - - - - - - 15 AJlw~IJs.withi.n.1l4.rnile.area.ofreyiewjdß[1tlfied(Fors¡efVjCß.well on I}'). ..... _........ .YßS . . . . . MPU .!3:-1.1alJq G-.19 (CH6 isPM'dL . . . . . . . . . . . . - - - - - - - - - - - - - -- . _. 16 Pre-produced i[1jßctor; .dur<ltion.of pre-produetiplJ less than. 3 months (For .service well only) . . No. - - - - - - - - - - - - - - - - - - - - - - - - 17 .AÇMP F:ïndingof Consi$te[1cy.ha$ been is¡sued for.tbis project . NA · . . . Sidetrack of .e~isting w~IJ.. . . . - - - -- - - - - - - Engineering 18 C.o[1duct.or st(ÎngpJQvldßd . - - - - - - - - - -- - - - - - - - - - ....NA · . . . Conductor instaJled. in MPG~03(1 a.9~046t . . . . - - - - - - 19 .S.ur:faCß .casingpJotects all.known USOWs . - - - -- - - - - - - - -- .. .NA · . . . All aq.uifers eXßmpled 40 CFR 147.. t03(b)(3). . . - - - - 20 .CMT v.ol adßquate.to circulate.on .conductor. & su.rf.CSg . . . . . . - - - - - · NA · . . . Surface ca.si.ng inst<llJedin MPG-.03. - - - - - - - - - - - - - - - 21 .CMT v.ot adequate.to tie-inJQngstring to surf cs.g. . . . . · . . . No . All hydr.ocarbon.zooeswill Qe.cove.red~ . - - - - - 22 .CMT will coyer.aU kno.wn.produetiye hQri;!:on.s. . . . . . . . . . - - - - - · Yß$ - - - - - - - - - - - - -- - - - - - - 23 .C.asing desigos ad.eQua.te for C,.T. B& p-ermafros!. - - - - · Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate.tan.kage.oJ re.serve pit. . . . . - - - - - - - - - - - · .Yßs · . Rig js equippe.d.with stße!.pits. . NQ rßsel'\le.pjtplanned. All waste todjspos.al wells. 25 Jfa.re-drilt bas.a to:-403 for <lbandOl'lment beßn apPJQved . . . . . . . . . . . · Yßs · . . .304-342.apprpved913/04 . . . . - - - - - - - - - - - - 26 Adequ<lte.wellbore separatjon.proposed. . . _ . . . . . . . . . . . . . . . . . . . · . . . .Yß$ . . . . . Proximijy. analYSis perfoune.d. Çlose aRProaCl)e$jqenijfißd.. Travejiog c-ylin.d~r. RIQtJncludect .. . 27 Jf.djv~rter required, dQes jt meßt reguJations. . - - - - - - - - - - · NA · . . eop will.already be in place.. . . . - - - - - - - - - - - - Appr Date 28 .DJilling flujd pJogram $chematic&. equip Ji$tadequate. . . . . . . - - - -- · YßS · . . el:l~ expected at ~.3EMW. PlalJl'led MW 9.5.- 9.] ppg.. . . - - - - - . TEM 10/28/2004 29 .BOPEs.do .they meet regulation. - - - - - - - - - - - - - - - . . .Yßs - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - MJr0~ 30 .BOPEpress rajilJg approp(iate; .test to (pu.t psig in .comments). - - - - · Y.es · . M~S¡:> calculated.at 1635 psi. Planne.d.tesj press.ure3.000 psj.. . . . - - - - - 31 Choke. rnanjfold complies w/API RF'-53 (May 84). - - - - - - - -- · .Yßs - - - - - - - - - - - - - - - - - - - - - - - - 32 WQrk will pccur withputoperation .shutdown. · Yes - - - - - - - - - - - - - - - - - - - - - - 33 .Is Rrese[1ce Qf H2S gas. proQable. . . - - - - - - - - - - - - - - -- · No. · . .1:128 ha$.notbeen reported.on MPGp.ad. Rigjs.equipped with$ensor.s and alarms.. . 34 Mecha.niC<ll.cpndit[o[1of wells within AOR yeriJied (For.s.erYice w~1J only). Yes · . The. ce!11eottng re.cords of2 welJs.on .line 15. and MP.G-03. are satisfactory.. MPG: 19 .has¡ noj drjlled yet Geology 35 .Peunit can be issued wlo hydr.ogen. s.ulfide meaSJJres. . - - - - - - - -- · Yßs - - - - - - - - - - - - - - - - - - - - - - - 36 .D.atapresented on. Rotential PveJRressurß .zone$. . . . - - - - · .Yßs · . . EXPßct .sUght oVß!]>ressure (9.2.4 .Ppg EMW); will driJI with 9.5 ~ 9.7 ppg mud. Appr Date 37 .Sßtsmicanalysjs Qf shallow gas. zones. . . . . . . · NA - - - - - SFD 10/26/2004 38 .Sßabed .condjtiolJ SUl'\ley.(if off-sh.ore) . . . . . . . . . . .NA - - - - 39 . CQntact namelp/lOn.eJorweelçly prpgres¡s.reRorts [eXRloratpl)' .only] . . NA. - - - - Geologic Engineering ~ Date Commissioner: Date: Commissioner: Date . ioner t5\.s LOI <rJ4- /Yð~y . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ..... . Sperry-Sun Drilling Services LIS Scan Utility . ó?Oc/ - ;;<IC¡ $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 14 14:45:24 2005 ,,- fr ) ) I ~~ Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/14 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. . . . . . . . . . . . . . . . . . . . .05/04/14 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 MPG-03A 500292194201 BP Exploration (Alaska) Inc. Sperry Drilling Services 14-APR-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003389345 T. MCGUIRE E. VAUGHN MWD RUN 2 MW0003389345 T. MCGUIRE E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 27 13N 10E 1754 3362 MSL 0) 63.10 29.30 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.250 9.625 1964.0 # . . REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. THE TOP OF THE WHIPSTOCK WAS AT 1964'MD, AND THE BOTTOM WAS AT 1981'MD. SROP DATA ARE PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER PHONE CONVERSATION BETWEEN DENNIS URBAN (BP GEOSCIENTIST) AND BUSTER BRYANT (SDS) ON 4/13/05. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 & 2 REPRESENT WELL MPG-03A WITH API#: 50-029-21942-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6536'MD/4525'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) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number...... .... .1.0.0 Date of Generation.. .... .05/04/14 Maximum Physical Record..65535 File Type.... ........... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE RPX RPS RPM RPD FET GR 1 and clipped curves; all bit runs merged. .5000 START DEPTH 1952.0 1952.0 1952.0 1952.0 1952.0 1960.0 STOP DEPTH 6491.5 6491. 5 6491. 5 6491. 5 6491.5 6499.0 ROP $ . 1968.0 6536.0 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 1 2 MERGE TOP 1968.0 1995.0 MERGE BASE 1995.0 6536.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction... .... .... ......Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value................. .....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1952 6536 4244 9169 1952 6536 ROP MWD FT/H 0.02 884.67 265.566 9137 1968 6536 GR MWD API 9.38 13 0 . 04 70.9539 9079 1960 6499 RPX MWD OHMM 1. 49 133.99 9.82553 9080 1952 6491.5 RPS MWD OHMM 1.49 119.88 10.0543 9080 1952 6491. 5 RPM MWD OHMM 1. 52 2000 12.8635 9080 1952 6491. 5 RPD MWD OHMM 0.02 2000 13.9659 9080 1952 6491. 5 FET MWD HOUR 0.1 15.84 0.521045 9080 1952 6491. 5 First Reading For Entire File...... ....1952 Last Reading For Entire File.......... .6536 File Trailer Service name... ......... .STSLIB.001 Service Sub Level Name. . . Version Number...... .... .1.0.0 Date of Generation.... ...05/04/14 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...... .05/04/14 Maximum Physical Record. .65535 File Type........... .... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 1968.0 STOP DEPTH 1995.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 13-NOV-04 Insite 66.37 Memory 1995.0 1964.0 1995.0 39.3 39.9 TOOL NUMBER 8.250 1964.0 Water Based 9.05 56.0 9.0 800 8.2 .000 .000 .000 .000 .0 90.0 .0 .0 REMARKS: . $ # Data Format Specification Record Data Record Type.. ....... '" ......0 Data Specification Block Type.....O Logging Direction. ..... ...........Down Optical log depth units.......... .Feet Data Reference Point......... .....Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ....Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 1968 0.02 Max 1995 38.28 Mean 1981. 5 15.7811 First Reading For Entire File......... .1968 Last Reading For Entire File........ ...1995 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..05/04/14 Maximum Physical Record..65535 File Type.... .......... ..LO Next File Name......... ..STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..05/04/14 Maximum Physical Record..65535 File Type............... .LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM RPD FET 3 Nsam 55 55 . First Reading 1968 1968 Last Reading 1995 1995 header data for each bit run in separate files. 2 .5000 START DEPTH 1952.0 1952.0 1952.0 1952.0 1952.0 STOP DEPTH 6491.5 6491.5 6491 . 5 6491. 5 6491. 5 GR ROP $ . 1960.0 1995.5 6499.0 6536.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units...... .... .Feet Data Reference Point.. ......... ...Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value........ ......... .... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code . 15-NOV-04 Insite 66.37 Memory 6536.0 1995.0 6536.0 38.5 58.3 TOOL NUMBER 53519 134760 8.250 1964.0 LSND 9.00 58.0 8.5 850 14.0 3.000 2.290 2.600 3.400 75.0 100.4 75.0 75.0 Offset o 4 8 Channel 1 2 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1952 6536 4244 9169 1952 6536 ROP MWD020 FT/H 3.82 884.67 267.079 9082 1995.5 6536 GR MWD020 API 9.38 13 0 . 04 70.9539 9079 1960 6499 RPX MWD020 OHMM 1.49 133.99 9.82553 9080 1952 6491.5 RPS MWD020 OHMM 1.49 119.88 10.0543 9080 1952 6491. 5 RPM MWD020 OHMM 1. 52 2000 12.8635 9080 1952 6491. 5 RPD MWD020 OHMM 0.02 2000 13.9659 9080 1952 6491. 5 FET MWD020 HOUR 0.1 15.84 0.521045 9080 1952 6491.5 First Reading For Entire File...... ....1952 Last Reading For Entire File.......... .6536 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number. ........ ..1.0.0 Date of Generation. ......05/04/14 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name. ........... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/14 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments. .... ........... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/14 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments.... ............ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File