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Home My WebLink About197-208 MEMO RANDU! • State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday,May 18,2018 Jim Regg P.I.Supervisor J Z3L I eb SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC J-17 FROM: Bob Noble MILNE PT UNIT J-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry T2—"NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT J-17 API Well Number 50-029-22828-00-00 Inspector Name: Bob Noble Permit Number: 197-208-0 Inspection Date: 5/14/2018 Insp Num: mitRCN180514155835 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3-17 ,Type Inj W -TVD 3773 Tubing 858 - 859 - 858 - 860 PTD 1972080 ' Type Test SPT Test psi Boo ' IA 479 1675 1602 - 1599 - BBL Pumped: 1 BBL Returned: I - OA Interval ) 4YRTST JP/F P Notes: Monobore well SLANE() JUN 0 12018 May Friday, 18,2018 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. / ~ ~' ~~ File Number of Well History File PAGES TO DELETE Complete RESCAN n Color items - Pages: GraYScale, halftones, pictures, graphs, charts- Pages: Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type 'OVERSIZED [] Logs of various kinds Other Scanned by: Beverly Mildred Daretha ~l. owell Date.: Isl TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ nCLdC1!/CV STATE OF ALASKA A OIL AND GAS CONSERVATION COMMaON JAN 0 3 2013 REP5RT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon [J Repair Well U Plug Perforations [_f Perforate LJ OtherL MBE Treatment Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑ Exploratory ❑ 197 -208 -0 3. Address: P.O. Box 196612 StratigraphiC Service 12 6. API Number: Anchorage, AK 99519 -6612 50- 029- 22828 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025517 SBJ MPJ -17 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted MILNE POINT, SCHRADER BLFF OIL 11. Present Well Condition Summary: Total Depth measured 6725 feet Plugs measured None feet true vertical 4205.24 feet Junk measured 6578 feet Effective Depth measured 6613 feet Packer measured See Attachment feet true vertical 4131.26 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 81 20" 91.1# H -40 32 - 113 32 - 113 1530 520 Surface None None None None None None Intermediate None None None None None None Production 6668 7" 26# L -80 31 - 6699 31 - 4188.07 7240 5410 Liner None None None None None None Perforation depth Measured depth 6174 - 6208 feet 6220 - 6230 feet 6380 - 6430 feet 6480 - 6508 feet True Vertical depth 3843.87 - 3865.8 feet 3873.56 - 3880.03 feet 3977.8 - 4010 62 feet 4043.49 - 4061.93 feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# L -80 31 - 6473 31 - 4038.89 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: SCANNED JAN 1 s 2013 Intervals treated (measured): 6480' - 6508' Treatment descriptions including volumes used and final pressure: 6 Bbls K -max, 9.3 Bbls Thermatek, 3 Bbls K -max, 30 Bbls Produced Water, 22.4 Bbls Diesel, 620 psi; 390 Bbls H2Zero Gel, 940 psi. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 468 0 1027 Subsequent to operation: 0 0 266 0 823 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil [_f Gas ❑ WDSPLU GSTOR ❑ WINJ 5 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 -289 ✓ Contact Garry Catron Email Garry BP.Com Printed Name Garry Catron Title PDC PE Signature A 4, aA,- Phone 564 -4424 Date 1/2/2013 RBDMS JAM 0 4 201_ ,/ ". r i Form 10 -404 Revised 10/2012 % • / 3 Submit Original Only • • Packers and SSV's Attachment ADL0025517 SW Name Type MD TVD Depscription MPJ -17 PACKER 6064 3709.04 3 -1/2" Baker Premier Packer MPJ -17 PACKER 6275 3844.92 3 -1/2" Baker Premier Packer MPJ -17 PACKER 6457 3964.04 3 -1/2" Baker S -3 Packer Daily Report of Well Operations ADL0025517 1 X ,11 .._ �.... 'Y ,��.�. * ** CONTINUIb F 12O[A 09 -08 -12 * ** (c /o wfv's,pull ttp) LRS DISPLACED TBG W/ 60 BBLS OF CRIESEL. PULLED 1.5" WFR & SET 1.5" DGLV IN ST #3 @ 6182' MD. PULLED PXN PLUG FROM 6468' MD. DRIFT 2.55" CENT, T.E.L. (brass),1.5" SAMPLE BAILER, LOC EOT @ 6451' SLM/6473' MD (22' Correction ), TAG TD @ 6475' SLM/6497' MD (24' Rat Hole form EOT ). 9/9/2012 ***WELL S/I ON DEPARTURE * ** Pad Op Notified HES Thermatek Treatment; Pertorm low / high PT - passed. Open well. Pumped 43 • bbls of produced water at 1/2 bpm @ 705 psig WHP. Town engineers elected not to pump the MBE volume evaluation. Pumped Thermatek treatment; 6 bbls K -max, 9.3 bbls Thermatek, 3 bbls K -max, 30 bbls produced water, 22.4 bbls diesel. Shut down - pumping. Secure well. Wash up HES equipment. Secure location for the evening. 9/19/2012 Cont' on WSR 9/20/12 ... HES I hermatek Treatme Coont' from WSR 9/19/12 ... Post treat ment injection survey. Perform low / high PT - Passed. Spear 50/50 meth to establish injection at 1/2 bpm. WHP steadily climbed to 2500 psig. Shut down. WHP held relatively steady, 2370 psig after 8 mins. Bled WHP back to zero. Ramped back up to 3000 psig. WHP held, loss of 50 psig in 8 mins. Bled WHP back to zero. Cycled WHP up to 3500 psig four times. Could not break down. Bled WHP to zero and secured well. ... Job 9/20/2012 Complete ... ** *WELL S/I ON ARRIVAL * ** DRIFTED TBG W/ 2.60" CENT, TEL, & S.BAILER, TOOLS STARTED SLOWING DOWN @ 5850' SLM, STOPPED FALLING @ 5977' SLM, RECOVERED -1 QT OF GEL &THERMATEK • RAN 2.25" DRIVE DOWN BAILER TO 5982' SLM, RECOVERED — 1 GALLON OF GEL & THERMATEK, RDMO 11/8/2012 ** *WELL S/I ON DEPARTURE * ** CTU #3 - 1.75" Coil Job Objective: FCO to establish inj. Leave Maint. and travel to location. Rig up. 11/14/2012 ...Continued on WSR 11- 15 -12... Daily Report of Well Operations ADL0025517 CTU #3 - 1.75" Coil Job Objective: FCO to establish inj. Leave Maint. and travel to location. Rig up. 11/14/2012 ...Continued on WSR 11- 15 -12... CTU #3 - 1.75" CT (CTV =33.2) * ** *Continued from WSR 11- 14 -12 * ** Job Objective: FCO to establish inj. Finished rigging up. Made up Jetting /logging BHA with 2.625" JSN and 2.2" GR /CCL w/ carrier. RIH w/o pump to tag at 6000'. Jet w/ slick 2% KCI to 6024' and had no more progress. Log OOH to 2350'. POH. Tie -in log to GLM at 2428', corr -5'. MU milling . assy. RIH w/ 2.705" 5 bladed junk mill to tag at 6025' CTM. Mill stiringers to 6387' still getting 1:1 return. Standby for fluids support. 11/15/2012 ...WSR Continued on 11- 16 -12... CTU #3 - 1.75" CT * ** *Continued from WSR 11- 15- 12 * * ** Job Objective: FCO to restore inj. Continue milling down to target depth. Reached 6513' and had a slight over pull when picking up. Pumped 10 bbl gel sweep from TD and POOH at 60 %. Completed injectivity test of 0.3 bpm at 680 psi WHP, 0.8 bpm at 780 psi WHP, 1.0 bpm at 830 psi. Freeze protect well with 60/40 methanol. RDMO to MPE -03. 11/16/2012 Job complete HES MB treatment: H2Zero gel post C1 U clean out. Perform success ul high and low PT, pumped 5 bbls of MEOH swapped to PW 1 bpm @ 900 psi, swapped to H2Zero gel and pumped 170 bbls 11/17/2012 « «Job in progress cont' on WSR 11- 18 -12 »» • HES MB treatment: H2Zero gel post CTU clean out Job cont' from WSR 11- 17 -12. Pumped 390 bbls total H2Zero treatment followed by 50 bbls Produced Water and displaced with 22 bbls Diesel to freeze protect surface lines and tubing 11/18/2012 « «Job Complete »» Tree: 4 1/16" - 5M car steel MPU J - 17i Wellhead: 11" 5M FMC Gen. 6 Orig. DF elev. = 64.32' (N 22E) w/ 11" x 4.5" NSCT FMC Tbg. Hng., Orig. GL. elev.= 35.2' 4" CIW "H" BPV profile DF to 7" csg. hgr. = 31.14' (N 22E) 20" 91.1 ppf, H -40 113' 3.5" HES X Nipple (2.813" pkg.) 2,408' ® KOP @ 300' Max. hole angle = 66 to 68 deg. ,11411 1 3.5" x 1.5" Camco MMG GLM I 2,428' f/ 3000' to 4700' Hole angle through perfs = 49 deg. 0 7" Howco ES' cementer 1 2177'md Valves in SPIV): Arrangement as of 9/11/12 7" 26 ppf, L -80, BTRC. production casing Two 7" x 21' marker jts. f/ 5639' to 5680' ( drift id = 6.151", cap. = 0.0383 bpf ) 3.5" 9.3 ppf, L -80 TC -11 tubing ( drift id = 2.992", = .0087 bpf ) 3.5" HES X- Nipple (2.813" pkg.) 6,042' Minimum tubing restriction = 2.75 9 " 6,064` 7 "x 3.5" Baker Premier Packer I "XN" profile @ 6468 IA 3.5" x 1.5" Camco MMG GLM 6,124` I Stimulation Summary none performed 3.5" x 1.5" Camco MMG GLM 6,182' Perforation Summary Ref log: 11/15/97 EWR / GR 7 "x 3.5" Baker Premier Packer 6,275` Size spf Interval (TVD) NB Sands #" 3.5" x 1.5" Camco MMG GLM 6,336` 2" 4 6174' -6208' 3844' -3866' NC Sands x :•; 0 2" 4 6220' -6230' 3873' -3880' OA Sands 3.5" x 1.5" Camco MMG GLM 6,396' 2" 4 6380' -6430' 3913' -4010' OB Sands „.., 4.5" 5 6480' - 6508' 4048' - 4062' 7 "x 3.5" Baker S -3 Packer 6,457' I 0 3.5" HES XN- Nipple (2.813" pkg.) 6,468` SWS 51B HJII deep penetrating charges 2.75" No -Go 3.5" WLEG 6,473` 2" Powerjet guns, 60 deg. phasing 4 -spf deep penetrating charges 7" landing collar (PBTD) 6613' and Agamigalmak 7" float collar 6656' and 7" casing shoe 6699' and * Fish at TD SWS 2 -5/8" Severing head & Centralizer 35.12" long. DATE REV. BY COMMENTS MILNE POINT UNIT 11/20/97 JBF Drilled and Completed by Nabors 22E WELL J - 17i 9/03/99 MDO Add Perfs API NO: 50 - 029 - 22828 07/23/02 MDO Re- Complete Injector Nabors 4 -ES BP EXPLORATION (AK) FitU IVED STATE OF ALASKA NOV O 9 2012 AA. OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate 11 OtherU MBE Treatment Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdowr0 Stimulate - Other ❑ Re -enter Suspended Weil❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 197 -208 -0 3. Address: P.O. Box 196612 StratigraphiC Service el 6. API Number: Anchorage, AK 99519 -6612 • 50- 029 - 22828 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025517 ,- SBJ MPJ -17 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted MILNE POINT, SCHRADER BLFF OIL 11. Present Well Condition Summary: Total Depth measured 6725 feet Plugs measured None feet true vertical 4205.24 feet Junk measured 6578 feet Effective Depth measured 6613 feet Packer measured See Attachment feet true vertical 4131.26 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 81 20" 91.1# H-40 32 - 113 32 - 113 1530 520 Surface None None None None None None Intermediate None None None None None None Production 6668 7" 26# L -80 31 - 6699 31 - 4188.07 7240 5410 Liner None None None None None None Perforation depth Measured depth 6174 - 6208 feet 6220 - 6230 feet 6380 - 6430 feet 6480 - 6508 feet True Vertical depth 3843.87 - 3865.8 feet 3873.56 - 3880.03 feet 3977.8 - 4010.62 feet 4043.49 - 4061.93 feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3# L -80 31 - 6473 31 - 4038.89 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): 6480' - 6508' Treatment descriptions including volumes used and final pressure: '. tt f ,j 7 l :i 6 Bbls K -max, 9.3 Bbls Thermatek, 3 Bbls K -max, 30 Bbls Produced Water, 22.4 Bbls Diesel, 620 psi. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 468 0 1027 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: f Copies of Logs and Surveys Run Exploratoq❑ Development ❑ Service El Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil U Gas U WDSPLU GSTOR ❑ WINJ ID WAG ❑ GINJ ❑ SUSP ❑ SPLUGO 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 -289 Contact Garry Catron Email Garrv Printed Name Garry Catron Title PDC PE Signature e7.€ Phone 564 -4424 Date 11/9/2012 ,. N0V14 M V , / /4f� 1I /lid Form 10 -404 Revised 10/2012 Submit Original Only • • Packers and SSV's Attachment ADL0025517 SW Name Type MD TVD Depscription MPJ -17 PACKER 6064 3709.04 3 -1/2" Baker Premier Packer MPJ -17 PACKER 6275 3844.92 3 -1/2" Baker Premier Packer MPJ -17 PACKER 6457 3964.04 3 -1/2" Baker S -3 Packer Daily Report of Well Operations ADL0025517 ACTIVITYDATE SUMMARY •\ \I p -ST 1•-1 ;- co s,pu 'p LRS DISPLACED TBG W/ 60 BBLS OF CRIESEL. PULLED 1.5" WFR & SET 1.5" DGLV IN ST #3 @ 6182' MD. PULLED PXN PLUG FROM 6468' MD. DRIFT 2.55" CENT, T.E.L. (brass),1.5" SAMPLE BAILER, LOC EOT @ 6451' SLM/6473' MD (22' Correction ), TAG TD @ 6475' SLM/6497' MD ( 24' Rat Hole form EOT ). 9/9/2012 ***WELL S/I ON DEPARTURE*** Pad Op Notified WSR continued from 09 -08 -12 Assist slickline. Pumped 60 bbls criesel to displace tubing. Final 9/9/2012 WHPs =750/0 Slickline on location at departure • HES Thermatek Treatment; Perform low / high PT - passed. Open well. Pumped 43 bbls of produced water at 1/2 bpm @ 705 psig WHP. Town engineers elected not to pump the MBE volume evaluation. Pumped Thermatek treatment; 6 bbls K -max, 9.3 bbls Thermatek, 3 bbls K- max, 30 bbls produced water, 22.4 bbls diesel. Shut down pumping. Secure well. Wash up HES 9/19/2012 equipment. Secure location for the evening. Cont' on WSR 9/20/12 ... HES Thermatek Treatme t; Cont' from WSR 9/19/12 ... Post treat ment injection survey. Perform low / high PT - Passed. Spear 50/50 meth to establish injection at 1/2 bpm. WHP steadily climbed to 2500 psig. Shut down. WHP held relatively steady, 2370 psig after 8 mins. Bled WHP back to zero. Ramped back up to 3000 psig. WHP held, loss of 50 psig in 8 mins. Bled WHP back to zero. Cycled WHP up to 3500 psig four times. Could not break down. Bled WHP to zero and secured 9/20/2012 well. ... Job Complete .. ** *WELL S/I ON ARRIVAL * ** DRIFTED TBG W/ 2.60" CENT, TEL, & S.BAILER, TOOLS STARTED SLOWING DOWN @ 5850' SLM, STOPPED FALLING @ 5977' SLM, RECOVERED -1 QT OF GEL & THERMATEK RAN 2.25" DRIVE DOWN BAILER TO 5982' SLM, RECOVERED - 1 GALLON OF GEL & • THERMATEK, RDMO 11/8/2012 ** *WELL S/I ON DEPARTURE * ** • MPU J - 17i Tree: 4 1/16" - 5M carbon steel Wellhead: 11" 5M FMC Gen. 6 Orig. DF elev. = 64.32' (N 22E) w/ 11" x 4.5" NSCT FMC Tbg. Hng., Orig. GL. elev.= 35.2' 4" CIW "H" BPV profile DF to 7" csg. hgr. = 31.14' (N 22E) 20" 91.1 ppf, H -40 113' 3.5" HES X- Nipple (2.813" pkg.) 2,408' KOP @ 300' Max. hole angle = 66 to 68 deg. 3.5" x 1.5" Camco MMG GLM 2,428' f/ 3000' to 4700' Hole angle through perfs = 49 deg. 0 7" Howco 'ES' cementer 2177' and Valves in SPM: Arrangement as of 9/11/12 7" 26 ppf, L -80, BTRC. production casing Two 7" x 21' marker jts. f/ 5639' to 5680' ma . ( drift id = 6.151", cap. = 0.0383 bpf ) 3.5" 9.3 ppf, L -80 TC -11 tubing !IF ( drift id = 2.992 ", = .0087 bpf ) I I 3.5" HES X- Nipple (2.813" pkg.) 6,042' Minimum tubing restriction = 2.75" 7 "x 3.5" Baker Premier Packer 6,064' "XN" profile @ 6468 I 3.5" x 1.5" Camco MMG GLM 6,124' Stimulation Summary none performed 3.5" x 1.5" Camco MMG GLM I 6,182' Perforation Summary > Ref log: 11/15/97 EWR / GR 7 "x 3.5" Baker Premier Packer I 6,275' Size spf Interval (TVD) NB Sands 3.5" x 1.5" Camco MMG GLM 6,336' 2" 4 6174' -6208' 3844' -3866' NC Sands 2" 4 6220' -6230' 3873' - 3880' " OA Sands LI 3.5" x 1.5" Camco MMG GLM 6,396' 2" 4 6380' -6430' 3913' -4010' OB Sands 4.5" 5 6480' - 6508' 4048' - 4062' 1=41114 7 "x 3.5" Baker S -3 Packer I 6,457' 14" 3.5" HES XN- Nipple (2.813" pkg.) 6,468` SWS 51B HJII deep penetrating charges 2.75" No -Go 3.5" WLEG 6,473' 2" Powerjet guns, 60 deg. phasing 4 -spf deep penetrating charges l 7" landing collar (PBTD) 6613' and 7" float collar 6656' and 7" casing shoe 6699' and * Fish at TD SWS 2 -5/8" Severing head & Centralizer 35.12" long. DATE REV. BY COMMENTS MILNE POINT UNIT 11/20/97 JBF Drilled and Completed by Nabors 22E WELL J -17i 9/03/99 MDO Add Perfs API NO: 50- 029 -22828 07/23/02 MDO Re- Complete Injector Nabors 4 -ES BP EXPLORATION (AK) • • w \� O \ � j /j. s 9 THE STATE Alaska Oil and Gas of ALASJ A Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 SCANNED JAN 1.1 2013 Fax: 907.276.7542 Alecia Wood MPU Schrader Pad Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 l� Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, SBL MPJ -17 Sundry Number: 312 -390 Dear Ms. Wood: 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, t_4 Cathyl. Foerster Chair DATED this 1 7Ida of October, 2012. Encl. 0 0 0,, ‘ RECEIVED STATE OF ALASKA � OC 10 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION DO `D /' Jl Z 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 0 • Alter Casing ❑ Omer ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 197-208-0 . 3. Address: Stratigraphic ❑ Service 6. API Number. P.O. Box 196612, Anchorage, AK 99519 - 6612 50- 029 - 22828 -00 -00 . 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? SBL MPJ -17 Will planned perforations require a spacing exception? Yes ❑ No ❑ _ 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0025517 ' 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): j Plugs (measured): Junk (measured): 6725 • 4205 ' 6613 4131 None 6578 Casing Length Size MD TVD Burst Collapse Structural Conductor 81 20"91.1#H-40 32 - 113 32 -113 Surface None None None None None None Intermediate None None None None None None Production 6668 7" 26# L -80 31 - 6699 31 - 4188.07 7240 5410 Liner None None E None None None None Perforation Depth MD ft : Perforation Depth TVD (ft): Tubin Size: Tubing G rade: Tubing MD 1t P O P Tubing 9 n9 : O See Attachment See Attachment 3 -1/2" 9.3# L -80 L-80 31 - 6473 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Pecker Depths No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 151 BOP Sketch ❑ Exploratory ❑ Development ❑ Service IS • 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0 • GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alecia Wood Email Aleda.Wood @BP.Com Printed Name Alecia Wood Title MPU Schrader Pad Engineer Signature - Phone 564 -5492 Date i 9 Lk 1U bct 1 ,a COMMISSION USE ONLY ]� Conditions of approval: Notify Commission so that a representative may witness 'Sundry Number. 317....: J ' b Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: / a 4 /0 Y APPROVED BY Approved by: 6.Vt'''' /_.� .i ) / COMMISSIONER THE COMMISSION Date: / 0 17 - t 2---- .1j R DMS OCT192012 J 7 /a '/z tJ � ; FGI d 1 /2010 Approved application is valid for 12 months fro d of p prova . / Submit in Duplicate t 0 • Perforation Attachment ADL0025517 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPJ -17 9/9/12 STC 6174 6208 3844 3866 MPJ -17 9/9/12 STC 6220 6230 3874 3880 MPJ -17 6/21/12 STC 6380 6430 3978 4011 MPJ -17 9/9/12 STO 6480 6508 4043 4062 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH 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 • • Packers and SSV's Attachment ADL0025517 Well Facility Type MD Top Description TVD Top MPJ -17 PACKER 5433 3 -1/2" Baker S -3 Packer 3432 MPJ -17 PACKER 6064 3 -1/2" Baker Premier Packer 3773 MPJ -17 PACKER 6275 3 -1/2" Baker Premier Packer 3909 MPJ -17 PACKER 6457 3 -1/2" Baker S -3 Packer 4028 • • tip 0 To: Mark O'Malley /Rob Handy Date: October 09, 2012 MPU Well Operations Supervisor From: Alecia Wood, MPU Schrader Pad Engineer 907 - 564 -5492 Subject: MPJ -17 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 injectivity. PROCEDURE Cleanout 1. RU, hold pre -job safety meeting, PT 2. RIH and cleanout wellbore with coil tubing to bottom perf (6508'MD) 3. Perform injectivity test with produced water. Sid' Contingency if injectivity is not regained 4. Spot 2.5 bbls of HCI and tubing /Liner. (WBV from bottom perf to Tubing Tail is 1.34bbls, do not want to acidize the thermatek in the matrix and compromise the treatment). 5. Perform injectivity test with produced water raising injection pressure to a max of 4000 psig if necessary to regain injectivity. • • Tree: 4 1/16" - 5M carbon oteel MPU J - 17i Wellhead" 11* 5M FMC Gen. 6 Ong. DF elev. = 64.37 (N 22E) WI 11" x 4.5' NSCT FMC Tbg. Hng Ong. GL. elev.= 35.7 4' CIW 'M' BPV profile DF to 7" cog. hgr- = 31.14' (N 22E) 20r 91.1 ppf, H-40 I 113' 3.5' HES X- Tipple (2.813" pkg.) I 2,408' I KOP :J, 300' Max. hole angle = 66 to 68 deg. 1111 3.5' x 1.5' Camas MMG GLM I 2,428' N. 3000' to 4700' fff Hole angle through pert: = 49 deg 0 "' Kowa* 1E0' oarnsntar 1 217 r and Vahn.s r SPM Arrangerrert as mf 7' 26 ppf, L-80, BTRC. production cawing Tvrx 7' a 21' marker Pm. fl 5639' to 5 ( drift id= 5.151', cap. =0.0383bpf) 3.5" 9.3 ppf, L -80 TC-11 tubing ( drift id = 2.£19'_"", = .0087 bpf ) I 1 I ES X- Nipple (2.813' Pkg.) 6,042' Minirnrun tubing restriction = 2.75" I " r 3.5' Baker Premier Packer ( 6,064' I "X1`,1" profile ;' 6468 3 5' x t .5" Came= WAG GLM ( 6.124' I Stimulation Summary none pertorrned DV " 3 5 r. ' =,' °ammo MMG GLM I 6,182' I Perforation Summary Ref log: 1115 EWR r Gfi ''x 3.5' Baer Premier Packer ( 6,275' at trACro "t ∎TY n NB 3 3 1 K a x 1.5" Ca nco MMG :4LMA I 6,336' I 2" 4 6174 -6208' 3844-3866' 111. NC Sando 2" 4 6220'- 6230' 3873 - 3380' OA Barmy DV ' . 3 5' x 1.5''2amco MMG GLM 2" 4 6380' -6430' 3913'- 4010' CIB 3arxb 4.5" 5 6480' - 6508' 4048' - 4062' 7'x 3.5' Baker 3-3 Packer I 6.457' 3.5' HES XN- Nipple (2.813' pkg.) I 6,46E' SWS 51 B HJII deep penetrating charge: 2.75' No Go 3.5' WLEG I 6,473' 2" Powerjet gtric, 60 deg. pha: ing 4-q cif deep penetrating charges 7" landing collar (P6TD1 6613' rod 7" float collar 6656" rnd 7" casing shoe 6699' and x Fish at TD SWS 2 -5i8' Severing head & Centralizer 35.12" long. .347E ;EV. BY COMMENTS MILNE POINT UNIT 1 1,'201x97 JBF Drifted and Completed by Naborc 22E WELL J - 171 9;03199 MDO Add Perfc API NO: 50 - 029 - 22828 07;23102 MOO Re- Complete Injector Nabors 4 -ES BP EXPLORATION (AK) . • 0 i /6 -1- rr ( 7 ..,, i i ' ' ? 4 f , ! ., " p cu g, SEAN PARNELL, GOVERNOR ti , " L N I 100 * � �+ AND GAS �+ ALASKA OIOIL A1�D rirAS 333 W. 7th AVENUE, SUITE ANCHORAGE, ALASKA 99501 -3539 CONSERVATION COMMISSION i PHONE (907) 279 -1433 ,/ FAX (907) 276 -7542 Alecia Wood Production Engineer 1 -1 7_ A © g BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPJ -17 Sundry Number: 312 -289 se,ANNEDAuG C 1 2012 Dear Ms. Wood: 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, /tk i,j / ms_ Cathy • . Foerster /I Chair . i Sr DATED this - day of July, 2012. Encl. q ' -`� RECEIVED 0 o STATE OF ALASKA JUL 2 6 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION 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 Perforation; , 711.1,0'0— Perforate ❑ Pull Tubing ❑ Time Extension ❑ ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing Other: e 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: I "" BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 197-208-0 ° 54- 3. Address: Stratigraphic ❑ Service 6. API Number: 7A.rL P.O. Box 196612, Anchorage, AK 99519 -6612 50-029-22828-00-00 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 0 MPJ -17 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025517 ' 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): 6725. 4205 ' 6613 4131 6468 None Casing Length Size MD TVD Burst Collapse Structural Conductor 81 20" 91.1# H -40 32 - 113 32 - 113 Surface None None None None None None Intermediate None None None None None None Production 6668 7" 26# L -80 31 - 6699 31 - 4188.07 7240 5410 Liner None None None None None None Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 3 -1/2" 9.3# L -80 4039 31 - 6473 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 is 13. Well Class after proposed work: I Detailed Operations Program n BOP Sketch n Exploratory n Development n Service [✓] 14. Estimated Date for 15. Well Status after proposed work: 8/21/12 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0 GINJ ❑ WAG ❑ Abandoned El 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 Production Engineer Signature Phone Date � wick iJ � t 5t1A - 5' 19 3 l 9 to/ /9- COMMISSION USE ONLY 2 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: J` 20-23 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: 16 — yes y APPROVED BY Approved by: ag f COMMISSIONER THE COMMISSION Date: 7— 3 / —/Z ORIGINAL ��;� �,!" PI + , ' ,. e �t11 1f! 7.36./4— 749b Duplicate -51 • • Perforation Attachment ADL0025517 • Well Date Perf Code MD Top MD Base TVD Top TVD Base MPJ -17 4/13/11 STO 6174 6208 3844 3866 MPJ -17 4/13/11 STO 6220 6230 3874 3880 MPJ -17 6/21/12 STC 6380 6430 3978 4011 MPJ -17 6/20/12 STC 6480 6508 4043 4062 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH 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 • • Packers and SSV's Attachment ADL0025517 Well Facility Type MD Top Description TVD Top MPJ -17 PACKER 5433 3 -1/2" Baker S -3 Packer 3432 MPJ -17 PACKER 6064 3 -1/2" Baker Premier Packer 3773 MPJ -17 PACKER 6275 3 -1/2" Baker Premier Packer 3909 MPJ -17 PACKER 6457 3 -1/2" Baker S -3 Packer 4028 p • To: Mark O'Malley /Rob Handy Date: July 06, 2012 MPU Ops Team Leaders From: Alecia Wood, MPU Schrader Pad Engineer 907 - 564 -5492 Subject: MPJ -17 MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPJ -17 2 F Bullhead treatment down MPJ -17 (OB sand). Keep well and offset producers and injectors shut in for the duration of the treatment and flow producers to a tank before returning to production if necessary. OBJECTIVE Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. • Measure of success 1. Treatments are 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 observed. 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 MPJ -17i was drilled and completed in November 1997 as an OB injector. In September 1999 the N and OA sands were perforated and in 2002 it was converted to a regulated injector. The well supports MPJ -08A (OB), MPJ -09A (LTSI - OA) J -25 (NB) and MPJ -26 (NB, OA, OB). In January 2009 there was a sanding event in offset producer MPJ -26 which caused a slowdown of the ESP. The sand production continued for the next 3 months , accompanied by an increase in WC from 70% to 90 %. Both MPJ -17i and MPJ -26 were SI on 4/1/09 to stabilize due to suspicion of a pressure connection between the two. Two days later MPJ -17i was returned to injection and the pressure response was observed in the MPJ -26 within two hours. In September 2009, a zonal injection test confirmed the connection between the wells in the OB zone. In April 2010 a polymer treatment was pumped into the OB of MPJ -17 to reduce the water cut . and sand production in the MPJ -26. A negative Red Dye tracer survey was pumped on 3/16/11 with all three zones open to injection. MPJ -26 has since produced solids and at low oil rates without support. MPJ -26 will remain SI until an MBE treatment is pumped in MPJ -17. In June 2012 the N sand was put on injection to support MPJ -25 which was SI for high GOR. The OA and OB have remained dummied off. • PROCEDURE Stage 1. Injection Test 1. RU, hold pre -job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. 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 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre -flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 7. Pump produced water pre -flush followed by high volume gel treatment and diesel over flush. 8. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 9. Rig down all equipment and hold post -job assessment meeting to capture learnings to be incorporated into future jobs. 10. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. 4110 Tree: 4 116" - 5M carbon steel. MPU J - 171 Wellhead 11* 5M FMC Gen. 6 1 1 Ong, DF elev. = 6432 (N 22E) wr 1 r x 45NSCT FMG Mg. Hng Ong. GL. elev.= 35.7 CIO/ "H" BPV profile 4 to 7 cog. gr„ = 31.14' (N 22E) 20* 91.1 ppf, 440 113' 1 1 3.5' HES X-Nipple (2.813' P I 24°8* KOP @ 300' Max. hole arde = 66 to 68 de3 j 35 x 15 Camoc WAG SIM I 2,428' (I 3000' to 4700' Hole angle through perta =49 deg„ 0 Howco ES' zvermantAr 2177d , Arrangement as al 5130/10 7 26 ppf, L430, BTRG. woduction pacing . Two 7 x 21 marker its. te 5639' to 5680" ( dnft id = 3151', cap. = 0.0333 bpi' ) 3.5* 9.3 ;apt L-80 TC-11 tubing (iftd=2Q2 = _0087 Pp( ) 35° HES X-Nipple (2 313°' pkg.) 6042 I minimum tubing reetriction = 2.75" 7x 3.5" Baker Premier Packer 6,064' xpr profile la 6466 4fk., 3.5 x 1.5 Camcc MKS GLIM 6,124' Stimulation Summary norfe performed x 1.5" Camp kft4G SIM 6,182' Perforation Summary Ref i00: 11115:97 EWR GPI 7x 3.5' Esker Pnernier Packer 6275' Si:7Q zpf IntAmal (TVDJ .„„„. NB Swath. :40:4„1 0 A 15' x 1.5* Camoo WAS SLIA 6,33 2" 4 6174 -3203' 3344-3866" NG Sancb 2 4 6z2c. r-62'40‘.. 3873-3380' OA Senob 01,k 35"x 15 Canso MUG GUI j 6,396' 2' 4 6380 3913-4010" 03 S 4.5" 5 648� - 6508' 4048' - 4062" 7 35 Baker 5-3 Packer 8A57 I if 3.5"HES XN-N4e (2813" pits)! 6 SWS 5113 HUM deep per charge 's"trfr---.1 r 3 6,47? 2" Poweriet giss% 60 deg. ph 'acing 4-opf -rge,-frine01— dew penetrating ChEttg. 7' landing collar (PBTD) I 6613° md ASMISRMISRMI r float- filar 6656' md 7 owing oboe 66129" md Fish at TO SWS 2-518" Severing head & Centralizer 35.12" long. DATE ;IEV. BY COMMENTS MILNE POINT UNIT 11,204i7 483 °riled and Gamed by Nabora 22E WELL J MIDO Add Pens API NO: 50-029-22828 07/23102 MOO Re-Complete hector Nabors 4 - BP EXPLORATION (AK) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 CL cutkiNED C t Las - 1a December 30, 2011 Mr. Tom Maunder I , JQ g • Alaska Oil and Gas Conservation Commission 333 West 7 Avenue I— i v Anchorage, Alaska 99501 e Subject: Corrosion Inhibitor Treatments of MPJ -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPJ -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10.404) MPJ -Pad 9/512011 Corrosion Vol. of cement Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped Final top of cement date inhibitor sealant date ft bbls ft gal MPJ -01A 1991110 50029220700100 Sealed Conductor NA NA NA NA NA MPJ -02 1900960 50029220710000 Sealed Conductor NA NA NA NA NA MPJ -03 1900970 50029220720000 Sealed Conductor NA NA NA NA NA MPJ-04 1900980 50029220730000 Sealed Conductor NA NA NA NA NA MPJ -05 1910950 50029221960000 Dust Cover NA NA NA 3.4 9/5/2011 MPJ-06 1940950 50029224930000 4 NA 4 NA 8.5 8/21/2011 MPJ -07 1910970 50029221980000 3.8 NA 3.8 NA 3.4 8/21/2011 MPJ -08A 1991170 , 50029224970100 18 NA Need top job MPJ -09A 1990114 50029224950100 Sealed Conductor NA NA NA NA NA MPJ -10 1941100 50029225000000 Sealed Conductor NA NA NA NA NA MPJ -11 1941140 50029225020000 Sealed Conductor NA NA NA NA NA MPJ -12 1941180 50029225060000 Sealed Conductor NA NA NA NA NA MPJ -13 1941260 50029225080000 1 NA 1 NA 3.4 8/21/2011 MPJ -15 1991070 50029229520000 Dust Cover NA NA NA 5.1 9/5/2011 MPJ -16 1951690 50029226150000 1.8 NA 1.8 NA 11.1 8/20/2011 "- ---- -' MPJ -17 1972080 50029228280000 0.8 NA 0.8 NA 8.5 9/5/2011 MPJ -18 1972200 50029228340000 1.3 NA 1.3 NA 17.0 9/5/2011 MPJ -19A 1951700 50029226070100 2.2 NA 2.2 NA 15.3 8/20/2011 MPJ -20A 2001850 50029228320100 5.8 NA 5.8 NA 65.5 9/5/2011 MPJ -21 1972000 50029228250000 3.5 NA 3.5 NA 28.1 8/20/2011 MPJ -23 2001200 50029229700000 0.8 NA 0.8 NA 10.2 11/1/2009 MPJ -24 2001490 50029229760000 Open Flutes - Treated MPJ -25 2040730 50029232070000 1 NA 1 NA 8.5 8/21/2011 MPJ -26 2040640 50029232050000 1.2 NA 1.2 NA 11.9 8/20/2011 C~ J MEMORANDUM To: gg P, I. Supervisor ~~~ ~IZ-S I+~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 10, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC J-] 7 MILNE PT iINIT SB J-17 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J ~n Comm Well Name: MILNE PT UNIT SB J-17 API Well Number: 50-029-22828-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100607093707 Permit Number: 197-208-0 Inspection Date: 6/5/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~ J-17 ~ W~ Well TypeInj. ~--~, TVD ~ -- 3773 ~~ IA r p ~ i 2000 i 1900 1900 ~1 1972080 i SPT ' P.T.D; T eTest Test is i _YP 11- p zooo ~ pA ---- ~ ~'T--- - Interval axRTST p~ _ _ P ~ Tubing toll 996 i 999 1000 Notes: Monobore well ~:-~., Thursday, June 10, 2010 Page 1 of 1 ~~~~~ASKA AND GASTCONSERVATION COMMISS~ qpR ~R~~RT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair W ell ^ Plug Perforations ^ Stimulate^ Other ^ MBE REPAIR 11 S Performed: f~COfIS.~itiing ^ Perforate New Pool ^ Waiver^ Time Extension ^ ~ ~y ~,., ~~' t Change Approved Program t. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ r 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development ^ Exploratory ^ 197-2080 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ .API Number: Anchorage, AK 99519-6612 50-029-22828-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-025517 ~ MPJ-17 10. Field/Pool(s): MILNE POINT FIELD SCH A FF OOL 1 R DER BLU P 11. Present Well Condition Summary: Total Depth measured 6725 feet Plugs (measured) 6560' 11/19/02 feet true vertical 4205.24 feet Junk (measured) None feet Effective Depth measured 6560 feet Packer (measured) 6064 6275 6457 true vertical 4096 feet (true vertical) 3773 3909 4028 Casing Length Size MD TVD Burst Collapse Structural Conductor 112 20" 91.1# H-40 SURFACE - 148 SURFACE - 148 1490 470 Surface Intermediate Production 6668 7" 26# L-80 SURFACE - 6699 SURFACE - 4188 7240 5410 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 3-1/2" 9.3# L-80 SURFACE - 6473 SURFACE - 4039 Packers and SSSV (type, measured and true vertical depth) 7"X3" BAKER PREMIER PKR 6064 3773 7"X3" BAKER PREMIER PKR 6275- 3909 7"X3" BAKER PREMIER PKR 6457 4028 12. Stimulation or cement squeeze summary: Intervals treated (measured): gg tt y [~ ~~ Treatment descriptions including volumes used and final pressure: _`' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 837 1090 Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^Q 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: 310-047 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 4/12/2010 ~i i i i i v-vu•r r~ynacu r i cvva • wy~Y1tJ Hrrs 1 di lUN ~- ~( /3•Id vuvi i m vi n~u iai vi uy MPJ-17 197-208 ococ ATTA!`IJIIACAIT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPJ-17 11/19/ PER 6,480. 6,508. 4,043.49 4,061.93 MPJ-17 9/3199 APF 6,174. 6,208. 3,843.87 3,865.8 MPJ-17 9/3/99 APF 6,220. 6,230. 3,873.56 3,880.03 MPJ-17 9/3/99 APF 6,380. 6,430. 3,977.8 4,010.62 MPJ-17 7/23/02 STC 6,064. 6,275. 3,773.36 3,909.24 MPJ-17 7/23/02 STC 6,275. 6,457. 3,909.24 4,028.36 MPJ-17 818/02 STO 6,275. 6,457. 3,909.24 4,028.36 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • C~ • MPJ-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/4/2010EHES pumping, H2zero polymer WSO treatment: Pump 50 bbl PW, start pumping H2Zero polymer WSO treatment per procedure. ***JOb In Progress"*" 4/5/2010EContinued from 4/4/10 - H2ZER0 polymer WSO: Pumped 434 bbl's of H2ZER0 polymer followed by 57 bbl's produced water & 30 bbl's 60/40 meth displacement/freeze protect. ***Job complete*"" FLUIDS PUMPED BBLS 110 PW 35 60/40 METH 434 FDP-S835 H2ZER0 POLYMER 300 3% KCL 30 HZ-20 LINKER 909 Total Tree: 4 1/16" - 5M carbon steel Wellhead: 11" 5M FMC Gen. 6 " w/ 11" x 4.5" NSCT FMC Tbg. Hng., 4" CIW "H" BPV profile 20" 91.1 ppf, H-40 113' Orig. DF elev. = 64.32' (N 22E) Orig. GL. elev.= 35.2' DF to 7" csg. hgr. = 31.14' (N 22E) 3.5" HES X-Nipple (2.813" pkg.) 2,408` 3.5" x 1.5" Camco MMG GLM 2,428' 7" Howco `ES' cementer 2177' and Valves in SPM: Arrangement as of 9/18/09 17" 26 ppf, L-80, BTRC. production ca ( drift id = 6.151", cap. = 0.0383 bpf ) 3.5" 9.3 ppf, L-80 TC-11 tubing ( drift id = 2.992", _ .0087 bpf ) Minimum tubing restriction = 2.75" "XN" profile @ 6468 Stimulation Summary none performed Pertoration Summary Ref loa: 11/15/97 EWR / GR Size spf Interval (TVD) NB Sands 2" 4 6174'-6208' 3844'-3866' NC Sands 2" 4 6220'-6230' 3873'-3880' OA Sands 2" 4 6380'-6430' OB Sands 3913'-4010' 3.5" x 1.5" Camco MMG GLM 6,336` 3.5" x 1.5" Camco MMG GLM 6,396` 4.5" 5 6480' - 6508' 4048' - 4062' 7"x 3.5" Baker S-3 Packer 6,457` RMX - 3.5" HES XN-Nipple (2.813" pkg.) 6,468` SWS 516 HJII deep penetrating charges FR 2.75" No-Go -- 3.5" WLEG 6,473` 2" Powerjet guns, 60 deg. phasing 4-spf deep penetrating charges 7" landing collar (PBTD) 6613' and 7" float collar 6656' and 7" casing shoe 6699' and * Fish at TD SWS 2-5/8" Severing head 8~ Centralizer 35.12" long. DATE REV. BY COMMENTS 11/20/97 JBF Drilled and Completed by Nabors 22E 9/03/99 MDO Add Perfs 07/23/02 MDO Re-Complete Infector Nabors 4-ES MILNE POINT UNIT WELL J-17i API NO: 50-029-22828 Two 7" x 21' marker jts. fl 5639' to 5680' 3.5" HES X-Nipple (2.813" pkg.) 6,042' 7"x 3.5" Baker Premier Packer 6,064' 3.5" x 1.5" Camco MMG GLM 6,124` 3.5" x 1.5" Camco MMG GLM 6,182` 7"x 3.5" Baker Premier Packer 6,275' MPU J -17i • Ms. Kaity Longden Staff Geologist BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point Field, Schrader Bluff Pool, MPJ-17 Sundry Number: 310-047 Dear Ms. Longden: • ~$ ~°~~~2- ~01~ 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. Sincerely, Daniel T. Seamount, Jr. Commissioner r°~ DATED this Z 3 day of February, 2010 Encl. ~~ ~o • `~ STATE OF ALASKA V' r ~, J``~j ~ALAS~IL AND GAS CONSERVATION COMMISSI /1r~' ~ APPLICATION FOR SUNDRY APPROVALS ~n nnr ~~ inn RECEIVED ~E~ Y 6 201Q Al~lska Ail FI 6ss Cetrr-. Camussion 1. Type of Request: Abandon ^ Plug for Redrill ^ Pertorate New Pool ^ Repair Well ^ Chan~(Program ^ Suspend ^ Plug Perforations ^ Pertorate^ Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ Other: MBE REPAIR 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 197-2080 3. Address: P.O. Box 196612 Stratigraphic ^ Service O 6. API Number: Anchorage, AK 99519-6612 50-029-22828-00-00 ~ 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. WeII Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ MPJ-17 • 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-025517 ~ Milne Point Unit 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): 6725 4205.24 6560 4096 6560' 11/19/02 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 112 20" 91.1# H-40 SURFACE 148 SURFACE 148 1490 470 Surface Intermediate Production 6668 7" 26# L-80 SURFACE 6699 SURFACE 4188 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED 3-1/2" 9.3# L-80 SURFACE 6473 Packers and SSSV Tvoe: 7"x3-1/2" BAKER PREMIER PKR Packers and SSSV MD and TVD (ftl: 6064' 3773 7"x3-1/2" BAKER PREMIER PKR 6275' 3909 7"x3-1/2" BAKER PREMIER PKR 6457' 4028 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: 3/1/2010 Oil ^ Gas ^ WDSPL ^ Plugged ^ 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 Kaity Longden Printed Name Kaity Longden Title Staff Geologist Signature Phone Date 564-5554 2/15/2010 Prepared b Gary Preble 564-4944 COMMISSION USE ONLY / J witness Sundry Number: /~tJ `~/~~ resentative ma mi sion so that a re N tif C diti f l C y p y om s ons o approva : o on Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: /Q T~ f APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 2 ~er 6 Form 10-403 Revised 12/2009 1 ~I~~O MPJ-17 197-208 DFRF ATTArHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPJ-17 11/19/97 PER 6,480. 6,508. 4,043.49 4,061.93 MPJ-17 9/3/99 APF 6,174. 6,208. 3,843.87 3,865.8 MPJ-17 9/3/99 APF 6,220. 6,230. 3,873.56 3,880.03 MPJ-17 9/3/99 APF 6,380. 6,430. 3,977.8 4,010.62 MPJ-17 7/23/02 STC 6,064. 6,275. 3,773.36 3,909.24 MPJ-17 7/23/02 STC 6,275. 6,457. 3,909.24 4,028.36 MPJ-17 8/8/02 STO 6,275. 6,457. 3,909.24 4,028.36 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • To: Mark O'Malley/Jerry Sharp MPU Well Operations Supervisor From: Jack Lau, Wells Engineer Kaity Longden, MPU Schrader-E Pad Engineer Subject: MPJ-17 Gel Job Date: February 11, 2010 227-2760 Step Unit Operation 1 S Set dumm valves in tubin mandrels to isolate zone for treatment 2 O Shut in all offset roducers. Bullhead water into MPJ-17. 3 O Bullhead gel treatment down MPJ-17. 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 rigid gel. Measure of success 1. Gel 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 gel per guidance from the Environmental Team. PROCEDURE Stagel. Injection Test 1. RU, hold pre-job safety meeting, PT surface lines 2. Ensure offset producers are SI. ~j ~~'60 "`' ? 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. 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 2. High Volume Gel Treatment 5. Ensure offset producers are offline 6. Pump produced water preflush, followed by gel treatment and produced water over flush, then bbls freeze protect. 7. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 8. Rig down all equipment and hold post-job assessment meeting to capture learnings to be incorporated into future jobs. 9. Forward all post job assessments (w/ all theology test summary) and continuous pressure and rate data from job to Pad Engineer. . d .~ . Tree: 4 1116" - 5M carbon steel Wellhead: 11" 5N9 FNIC Gen. 6 w1 11" x 4.5` NSCT FAhG Tbg. F~ 4" CIW "H" BP'J profile 20" 91.1 ppf, 1-~-4{I 113' KOP L 300' Max. hole angle = 66 to 88 deg. #! 3000' ~ 4700' Hole angle through perfs = 49 des T" 26 ppP, L-80. BTRG_ prtxJ~a~ti~ { drift id = 6.151", cap. = 4.0383 b~ 3:5" 9.3 pR#. L-Sfl TC-11 tubing 1 dnit id = 2.962", _.0(187 bpF j Minimum tubing restriction = 2.7.' "}~N° profile ~ 64e8 Stimt,7lation Summary none perfiamied Perfaratron Summary 12ef tos,: 11f15/97 EWR # GR ~Iae spr °~ntervar (~ID~ ° , NB Sands @, ~ 2` 4 6174'-@~E]8' N[_: Saiulc 38A4`-3$i ,~" $ BAw~`-6~3~}' X73•'- C?A Sands 2" 4 6380'-8430' C36 hands 3913°-4Q Orig, DF ebev. = 64.32' {N 22Ey t?rig_ GL. ~^t_= 35,2' QF to 7' csg_ hgr. = 31.14' {N 22E) HES X-Ntiapp~ 1;2.813' pkg. j 2,4(x` x 1.`s` Caruux MMG GLM ~,~~~ hrowcts `ES' setter 2177` and Vahres in 3P#~M Arrartigemerrt as cf flP1$JD9 vo 7' x 21' marker jts_ fl 5639` tts 51130` 'HES X-T~lipp~ 12.813' pkg.j 6,!D42` 3b` Baker Premier Packer 6,064`. ~' x 1.5` Camw MMG C-lM 6,124` • x 1.5' Car-rco MMG ~SLM 6,162` ~ 3.5' Baker Premier Packer 6,275` S' x 1 ~+' Gamso MMG GLM 6,336` 5' x 1.5` Cameo AlIM1i Gl_!A 6,396' 4.5` 5 8480' - 6508" 404$' - 4{ x 3.5' Baker 5-3 Packer 6,457' HES XN-Nipple (2.813' Fkg•} 6,46$` SWS 51 B FIJI{ deep penetrating d =.7'3' No-Go 3.5' WI.EG 6,473` 2" Pow+erje3 guns, Ba deg.. phasing deep penetratieig charges 7° t collar {PBTD) 68.13' nxi 7" fiat collar 6856' rrad 7" casting shoe 8699' rrxl Fish at TD SWS ?-518`° Severing head & Centralizer 35.12" long. eanTt I~w. ev ~~ MILNE Pt31NT UIiOT 11/?f)!97 JBF C.7rilled arxi Completed by Nabors 22E VMELl J-171 9t03r`61g MDR Add Pens i4Pt 1~IQ: X4129-2282$ 07P23/02 MQt7 Re-Complete Enie~a Nabors 4-ES CPU ,~ -'~7! ~ ~ YI/~L.L i.~4a / ~H/ fla7~~~Q~ ~B• PxoAc~ive Di,-ynwsric SeevicFS, Iroc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Qpen Hole/Mechanical Logs and/orTubing {nspection(Caliper/ M'TT) The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to the follawing : BP Exploration (Alaska), Inc. P'etrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Bensan Blvd. Anchorage, Alastca 99508 and uT~ ~9~ - ~v~ ProActive Diagnostic Services, Inc. C~15'~.- Attn: Robert A. Richey 130 West tnternational Airport Raad P~ ~, ~~y~ t~ ~;`~ `> .~'~~~~ Suite C Anchorage, AK 9951$ Fax (907) 245~8952 1) Injection Profile 19~ug-09 MPU J-17 2) Signed : ~ Print Name: PROACTNE DIAGNOSTIC SERYICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUlTE C, ANCHORAGE, AK 99518 PHONE: {907)245-8951 FnX: (907j245~$952 E~In~~ : pdsanchoraqeCoamemorvba.com WEBSRE : www.memorylog.com ~ C:~Dociunents and Settings\Owner~Desltiop\Trensaut BP.docx . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. ji· To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / M1T) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8951 1) 1 BL / EDE Disk 2) 3) 4) 5) 6) 7) Signed: /' ri C'.vk (\ Î r'7z J--.' L- {<l' [7)\\ I VI. ~ Print Name: MPU J - 17i 22-Aug-06 Injection Profile ~f"'Li".Y~IZ:Ð q ( I,JIf,¡¡I4"V'CU~_ fe. D RECE 0 Date: OCT Z 4 2úú6 'lJ g ¡I' .< I) .0. tflÁ £".'- PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: POSANCHORAGE@MEMORYLOG.CO[\!1 Û.I C- I C( 'j- - dO"õ tJ= 11..( I 7S CJ WEBSITE : \¡WNV.MEMORYLOG.COM 0:\00 ]OSANC-2006\Z _ W ord\Distribution\TransmittaI _ Sheets\Transmit_ Original.doc MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor "R¿11,(q!orP , . DATE: Wednesday, June 07, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC J-17 MILNE PT UNIT SB J-17 a.- DC¿ \ 0\1/ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv Jí?iZ- Comm NON-CONFIDENTIAL Well Name: MILNE PI UNIT 5B J-17 API Well Number 50-029-22828-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060603202838 Permit Number: 197 -208-0 Inspection Date: 6/3/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. J-17 ¡Type Inj. ¡ w i TVD ! i , ! Well I 3374 ¡ IA 200 i 2lO0 i 2100 I 2100 [TypeTest i SPT ! Test psi ! I --- P.T. ! 1972080 1500 ! OA I ! i ! I i -- T b' ¡ I i -- Interval 4YRTST P/F P u IOg¡ 750 i 750 750 I 750 ¡ - , ..-'- Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. This well is a single casing design with no OA to monitor. ./ ~CAN~\ii::;''J iUI ;\1 ¡,}1IIioI....... t,.,¡· II ~ ..:.. 'J ')rr·., t LUUU Wednesday, June 07, 2006 Page I of I WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 JUN 2 0 ~C, Alaska 0J~ & G~s Cons. Anchorage RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Bu~con / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration(Alaska), Inc. Petro-Technical Data Center LR2-1 900 East Benson Blvd. Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(SI OR CD-ROM FILM BLUELINE Open Hole I I 1 MPJ-17i 5-12-03 Res. Eval. CH I '1 I 1 Mech. CH 1 Caliper Survey Signed · Print Name: Date · ProActive Diagnostic Services, Inc., 310 K Street' Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax: (907) 245-8952 E-mail: pdsanchorage~memorylog.com Website: www.memory_log, com 0C7 ! 20113 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate_ H20 INJECTOR RECOMPLETION Pu, tubing_X Alter casing_ Repair well _ Other_X RECOMPLETION 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2989' FNL, 3324' FEL, Sec. 28, T13N, R10E, UM At top of productive interval 2021' FNL, 2340' FEL, Sec. 29, T13N, R10E, UM At effective depth 2006' FNL, 2399' FEL, Sec. 29, T13N, R10E, UM At total depth 1975' FNL, 2519' FEL, Sec. 29, T13N, R10E, UM 5. Type of Well: Development __ Explorato~.__ Stratigraphic._ Service X (asp's 551997, 6014688) (asp's 547692, 6015627) (asp's 547633, 6015642) (asp's 547513, 6015672) 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Milne Point Unit 8. Well number MPJ-17 9. Permit number / approval number 197~208 / 302-211 10. APl number 50-029-22828-00 11. Field / Pool Milne Point Unit / Schrader Bluff Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 112' Production 6668' 6725 feet Plugs (measured) 4205 feet 6560 feet Junk (measured) 4096 feet Tagged TD @ 6560' (11/19/2002) Size Cemented Measured Depth 20" 260 sx Arcticset (Aprox) 148' 7" 1272 sx PF 'E', 163 sx 6699' Class 'G' True Vertical Depth 148' 4188' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Open Peds Behind Tubing 6174'-6208',6220'-6230',6380'-6430', Open Peffs Below Tubing 6480'-6508'. Open Peds Behind Tubing 3844'-3866',3873'-3880',3913'-4010', Open Peds Below Tubing 4048'-4062' 3-1/2",9.3#,L-80 TBG @ 6473' MD. Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker Premier Packers @ 6064', 6275' & 6457'. 3-1/2" HES X-Nipple @ 2408'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. C0~missi~ Anchorage 14. Prior to well operation 07/05/2002 Subsequent to operation 08/20/2002 OiI-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 2210 Casing Pressure Tubing Pressure 1433 1699 1194 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~"~ ~~~ Title: Techn,cal A~'Istant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · EBDMS BFL 16. Status of well classification as: Oil_ Gas__ Suspe~{~,,~ N ~1-~. _¢~_ I_W~T~'~ ~NjJ ECTOR Date January 23, 2003 Prepared b~ DeWayne R. Schnorr 564-5174 . , FEB ~ " .... SUBMIT IN DUPLICATE MPJ-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/09/2002 08/20/2002 11/19/2OO2 11/21/2002 01/18/2003 01/20/2003 01/21/2003 01/22/2003 FIRST WATER INJECTION AFTER RWO. INJECTION RATE AFTER RWO--- 1699 BWPD @ 1194 PSI. DRIFT & TAG FOR INJECTION PROFILE SLICKLINE/PERFORM INJECITON SURVEY W/PDS SLICKLINE --- SET XXN PLUG. SLICKLINE --- PERFORM INJECTION TEST. SLICKLINE --- PULL XXN PLUG. TESTEVENT---INJECTION PRESSURE, PSI: 1,166 TYPE: PW VOLUME: 1,735 BWPD. EVENT SUMMARY 08/09/02 FIRST WATER INJECITON AFTER RWO. 08/20/02 INJECTION RATE AFTER RWO --- 1699 BWPD @ 1194 PSI. 11/19/02 TAGGED BOTTOM @ 6560' RKB. APPROXIMATELY 52 FT OF RAT HOLE 11/21/02 STABLE INJECTION RATE @ 2200 BWPD. RAN PDS INJECTION SURVEY. RKB MEASUREMENTS OBTAINED, USING 25' CORRECTION FROM DRIFT & TAG ON 11/19/2002. 01/18/03 SET XXN PLUG @ 6447' WLM (6468' MD). FLUSHED TBG W/60 BBLS METHANOL, AND FREEZE PROTECT LINE WITH 2 BBLS METHANOL. WILL RETURN TO FLOW TEST VALVE. 01/20/03 PERFORMED INJECTION TEST ON WATER FLOOD VALVE @ 6396' MD. VALVE APPEARS TO BE FLOW CUT OUT. VALVE WILL TAKE UP TO 1273 BWPD @ 1800 PSI. PULLED VALVE. SET NEW WATER FLOOD VALVE (0.233" PORT). PERFORMED INJECTION TEST ON NEW WATER FLOOD VALVE. AT 1800 PSI VALVE WAS TAKING 636 BWPD. WILL RETURN IN AM TO PULL XXN PLUG. 01/21/03 PULLED XXN PLUG @ 6457' MD. 01/22/O3 TESTEVENT---INJECTION PRESSURE, PSI: 1,166 TYPE: PW VOLUME: 1,735 BWPD. FLUIDS PUMPED BBLS 92 iMETHANOL 92 TOTAL c:,",~ktl::l'~ ~'F'~ !~ 0 ~.[~D~ Page I Tree: 4 1/16"-5M carbon steel MPUJ- 17i Wellhead: 11" 5M FMC Gen. 6 ! Orig. DF elev. = 64.32' (N 22E) w/ 11" x 4.5" NSCT FMC Tbg. Hng., Orig. GL. elev.= 35.2' = DF to 7" csg. hgr. = 31.14' (N 22E) 4" CIW "H" BPV profile 20"91.1 ppf, H-40 I 113' I ~ 3.5" RES X-Nipple (2.813" pkg.)I 2,408' KOP @ 300' Max. hole angle -- 66 to 68 deg. 3.5" x 1.5" Camco MMG GLM I 2,428' f/3000' to 4700' Hole angle through perle = 49 deg. I } 7" HOWCO 'ES' cementer ! 12177' mdI i I 7" 26 ppf, I_-80, BTFIG. production casing Two 7" x 21' marker its. f/5639' to 568o' ( ddft i0 = 6.151", cap. = 0.0383 bpf ) 3.5" 9.3 ppf, /-80 TG-11 tubing ( drift id = 2.992", = .0087 bpf ) 3.5" HES X-Uipple (2.813" pkg.) I 6,042' Minimum tubing restriction = 2.75" 7"x 3.5" Baker Premier Packer I 6,064' "XN"RefPerforationStimulationPrOfileloq:none11/15/97 @ performed6468SummarySUmmaryEWR / GR ~ 3.5" x 1.5' Camco MMG GLM 3.5" x 1.5" Camco MMG GLM II 6'182'16'124' 7"x 3.5" Baker Premier Packer I 6,275' S~ze spf Interval (TVD) I NBSands :~,~¢, 35"x1'5"Camc°MMGGLM 16'336'1 2" 4 6174'-6208' 3844'-3866' 2" 4 6220'-6230' 3873'-3880' 3.5"x 1.5" Camco MMG GLM I 6,396' OA Sands · ~ 2" 4 6380'-6430' 3913'-4010' OB Sands 4.5" 5 6480' - 6508' 4048' - 4062 .................................................................~.~-,~-,~.*--..~.-~,.~.?,-----~---., 7"x 3.5' Baker S-3 Packer I 6,457' 3'5" HES XN-Nipplo (2'813" pkg')I 6,468'I SWS 51B HJII deep penetrating charges 2.75" No-Go 3.5-w,E I 6.473. I 2" Powerjet guns, 60 deg. phasing 4-spf deep penetrating charges ~ 7" landing collar (PBTD) 6613' md · ~ ~k 7" float collar 6656' md 7" casing shoe 6699' md * Fish at TD SWS 2-5/8" Severing head & Centralizer 35.12" long. DATE REV. BY COMMENTS MILNE POINT UNIT 11/20/97 JBF Drilled and Completed by Nabors 22E WELL J-17i 9/03/99 MDO Add Perfs APl NO: 50-029-22828 07/23/02 MDO Re-Complete Injector Nabors 4-ES .~., ~klMl::r~ C'~'B -~ ~ '~r~rt'~ BP EXPLORATION tAK! 3.5 ing T 3.~ 3.~ 9s ~ 3.5 )f STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 64.32' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2290' NSL, 3324' WEL, SEC. 28, T13N, R10E, UM MPJ-17i At top of productive interval 9. Permit Number / Approval No. 197-208 3193' NSL, 2080' WEL, SEC. 29, T13N, R10E, UM 10. APl Number At effective depth 50-029-22828-00 3283' NSL, 2437' WEL, SEC. 29, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 3304' NSL, 2518' WEL, SEC. 29, T13N, R10E, UM 12. Present well condition summary Total depth: measured 6725 feet Plugs (measured) true vertical 4205 feet Effective depth: measured 6613 feet Junk (meaSured) true vertical 4131 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 250 sx Arctic Set I 112' 112' Surface 6663' 7" 1272 sx PF 'E', 163 sx Class 'G' 6699' 4188' Intermediate Production Liner .' -.. · · Perforation depth: measured Open: 6174'- 6208', 6220'- 6230', 6380'- 6430', 6480' - 6508' true vertical 3844' - 3866', 3874' - 3880', 3978' - 4011', 4044' - 4062' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 tubing to 6473'. Packers and SSSV (type and measured depth) 7" x 3.5" Baker Premier Packers at 6064', 6275' and a Baker S-3 Packer at 6457'. 3.5" SSSV HES nipple at 2408'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service Water Injection [] Daily Report of Well Operations 17. I hereby certify that the fore_cloing is true and correct to the best of my knowledge - T,tle Techn,cal' As~s~NED AUG Signed Sondra ~ ~ ,' Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate ~ ,iBp ~ExpLORATION Page 1 of 1 i ~, ~ ~ ~ner=Hon~ ~ummar. Report Legal Well Name: MPJ-17 Common Well Name: MPJ-17 Spud Date: 11/12/1997 Event Name: RECOMPLETION Start: 7/19/2002 End: 7/23/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 7/23/2002 Rig Name: NABORS 4 Rig Number: 4ES Date From ,To i Hours I Task i Code] NP phase Description of Operations 7/19/2002 12:00 - 20:00 I 8.00, RIGU PRE AND SAFE OUT EQUIPMENT &ACCEPT RIG @ 2000 I J I I 'HRS. 7/19/2002 20:00 - 20:30 0.50! KILL P !1Il DECOMP PULL BPV. WITH LUB 20:30 22:30 2.001 KILL P DECOMP RIG LINES TO TREE & TEST SAME TO 2500 PSI. 22:30 00:00 I 1.501 KILL ' P I I DECOMP I C~RC SEAWATER AROUND & CLN-INFLUX & MONITOR i ! ]I WELL 190 PSI. SIP. 7/20/2002 00:00- 03:00 I 3.00 KILL ~ P I DECOMP CIRC & RAISE BRINE WT. TO 9.8 PPG. & MONITOR SAME(STATIC) 03:00 - 03:30 ' 0.50 WHSUR ~P I DECOMP SET & TEST TWC 03:30 - 04:30 1.00 WHSURI P[ DECOMP NIPPLE DN TREE · 04:30 07:00 07:00- 2.5oI BOPSURP i DECOMP NIPPLE UP BOP'S 10:30 3.501BOPSUF~P I DECOMP TEST BOP TO 250 LOW & 2500 HIGH (TEST WAIVED BY 11:30 -I II I JOHN SPAULDING WITH AOGC) BOPSURP I DECOMP RIG LUB & PULLTWC. 10:30 - 11:30 1.00/ i p ' DECOMP MU LANDING JT. & PULL HANGER & LAY DN SAME. 12:30 - 12:30 1.00i PULL Ip 17:00 4.50 PULL I~ DECOMP LAY DN 3.5" COMPLETION STRING. (GOOD CUT) !17:00 - 19:30 2.50 PULL P DECOMP MU FTA #1 PACKER MILL-JARS-BS-15- DC. 19:30 - 23:30 4.001 FISH ' DECOMP RIH WITH 3.5" DP FROM SHED TAG TBG. STUMP @ 5413' 23:30 00:00 0.50i FISH f i DECOMP MILL ON TBG. STUB & PACKER 7/21/2002 00:00 06:00 6.00 FISH IP DECOMP MILL 3.5" STUB & PKR. & PUSH TO 5449 06:00 07:30 1.50 FISH P DECOMP CIRC. BO-I-rOMS UP AFTER PKR. FELL 07:30 08:00 0.50 FISH iP DECOMP POOH 10 STDS. 08:00 - 09:00 ! 1.001 FISHjP DECOMP CUT DRLG. LINE 09:00 - 10:30 i 1.50 FISH P DECOMP POOH & LAY DN PACKER MILL [ 10:30 - 13:00 2.50 FISH P 'DECOMP MU FTA # 2 CENTER SPEAR & JARS ETC & RIH & ENGAGE I FISH & PUSH TO 6508' 13:00 - 16:00 3.00 FISH P ! DECOMP POOH & LAY DN PKR & TAILPIPE 16:00 - 17:00 1.00 CLEAN P DECOMP CLEAR RIG FLOOR & WASH UP SAME. 17:00 - 20:00 3.00 CLEAN P , !DECOMP MU CLN-OUT ASSY & RIH WITH SAME TO 6404' 20:00 22:30 2.50 CLEAN P I i DECOMP i REVERSE ClRC DN TO 6599' & ADD CORROSION I INHIBITOR TO FLUID 22:30- 00:00 1.50 CLEAN ~P DECOMP POOH LAYING DN 3.5" DP 7/22/2002 00:00- 02:00 2.00 CLEAN P , DECOMP LAY DN 3.5" DP 02:00 - 03:30 1.50 CLEAN P DECOMP ILAY DN BHA # 3 03:30 - 07:00 3.50 EVAL I P DECOMP RIG HES & RUN 6" GR/JB TO 6553' & POOH & REC IRON I CUTTINGS & RE-RUN SAME TO 6553' & POOH & HAD VERY SMALL RECOVER RIG DOWN HES SLICKLINE. 07:00 - 09:00 2.00 RUNCO 'COMP RIG UP COMPLETION RUNNING EQUIPMENT. 09:00 - 19:00 10.00 RUNCOI~ COMP ~ i MU PKRS & RIH WITH TRIPLE PKR. COMPLETION TO j ~SETTING DEPTH @ 6470' 19:00 - 22:30 i 3.50! RUNCON~ COMP RIG SWS & RIH WITH 1-11/16" GR/CCL & POSITION PKRS. 22:30 23:00I 0.50 RUNCOI~ ~ I COMP LAY DN 1-JT. INSTALL HANGER & LAND SAME & RILDS 23:00 00:00 1.00 RUNCO ~I~P I COMP RD COMPLETION EQUIPMENT & SET TWC 7/23/2002 00:00- 01:00 1.00 BOPSUR~ P iJ COMP NIPPLE DN BOP :01:00 - 02:00 1.00 WHSUR I P I i COMP NIPPLE UP & TEST TREE. 02:00 - 04:30 2.50 RUNCO ,1~I ICOMP i PULL TWC & SET PKRS. PER PROCEDURE & BAKER TECH REP. ALL OK. (TEST WAIVED BY JOHN I SPAULDING WITH AOGC) 04:30 -06:00 1.50 RUNCON~ COMP FREEZE PROTECT WITH 100 BBL. DIESEL. Printed: 7~29~2002 4:39:56 PM STATE OF ALASKA r") .~-~ .... _ ALASKA OIL AND GAS CONSERVATION COMMISSION ; ~ -" 1. Tyl~ of reque~st:.z_ AbandOn_ ' ............ ~uspend'_'"" '0'~'erational shutdown _ Re-enter suspended well _ _=~,,,.~.E~_.~/~ Alter casing _ Repair well_ Plugging _ Time extension _ Stimulate _ -P~ed-te. Inject Well Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 64.0 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 196612 Stratigraphic __ Anchorage, AK 99519-6612 Service__ Milne Point Unit 4. Location of well at surface 8. Well number 2989' FNL, 3324' FEL, Sec. 28, T13N, R10E, UM (asp's 551997, 6014688) MPJ-17 At top of productive interval 9. Permit number ! approval number 2021' FNL, 2340' FEL, SEC 29, T13N, R10E, UM (asp's 547692, 6015627) 197-208 At effective depth 10. APl number 2018' FNL, 2354' FEL, Sec. 29, T13N, R10E, UM (asp's 547678, 6015630) 50-029-22828-00 At total depth 11. Field / Pool 1975' FNL, 2519' FEL, Sec 29 T13N, R10E, UM (asp's 547513, 6015672) Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 6725 feet Plugs (measured) Tagged TD @ 6498' (03/20/2002) true vertical 4205 feet Effective depth: measured 6498 feet Junk (measured) true vertical 4055 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 112' 20" 250 sx AS I (Approx) 148' 148' Production 6668' 7" 1272 Ssx PF 'E', 163 sx 6699' 4188' Class 'G' ? RECEIVED Perforation depth: measured Open Perfs 6174'-6208', 6220'-6230', 6380'-6430', 6480'-6508' JUL 9 2002 true vertical Open Peris 3844'-3866', 3873'-3880', 3913'-4010', 4048'-4~G~ Oil & ~,a$ Oofl$. Anchorage Tubing (size, grade, and measured depth 3-1/2", 9.3#, L-80 TBG @ 5433' MD. 3-1/2", 9.3#, L-80 Tubing Tail @ 5461'. Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker S-3 Packer @ 5433'. No SSSV ,., 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operatio/n 15. Status of well classification as: July 24th, 2002" 16. If proposal was verbally approved Oil __ Gas __ Suspended __ Name of approver Date approved Service WATER INJECTION 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Sean Petersen @ 564-5025. Signed ~ I:~~ Title: Milne Point Production Engineer Date July 03, 2002 _.Sean Petersen Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so represent~ive may witness I Approval no. Plug integrity_ ~OP Test ~ Location clearance__[ ~..~ ~:~ Mechanical Integrity Test~_ Subsequent form required 10- q ~ ~ ~ngi~a~; ,~gned By. Approved by order of the Commission Cammv ~81i T___.u._l~. Co~_m. i_s.si__o._n._e._r__.,~, ....: epee ~_ Form 10-403 Rev 06/15/88 · 0R[G[hlAL SUBMIT IN TRIPLICATE bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99,519-6612 (907) 561-5111 July 10, 2002 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for MPJ-17i Injector Recompletion BP Exploration Alaska, Inc. proposes to recomplete injector MPJ-17i from a single packer open to multiple zones (N, OA, and OB sands) to a triple packer injector with water injector valves/orifices that will allow for control into each zone. MPJ-17i will continue to support MPJ-08A, MPJ-09A, MPJ-19A, and MPJ-21. MPJ-17i was drilled, cased, and completed as an Schrader Bluff injector in November 1997. Initially only the OB sands were perforated, with the N and OA sands perforations added in September 1999. A TD tag in November 1999 found that all perforations were open for injection. However, since that time TD Tags have consistently found that the lower OB perforations are partially covered. IPROFs in both November 2000 and April 2002 have demonstrated roughly the same injection splits: 70% N, 30% OA, and 0% OB. By recompleting MPJ-17i to allow for control into the individual sands we should have better vertical conformance and sweep to the producers. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5025, home 349-3098, or e-mail me at rnailto:pete~ssd~bp.corn Sincerely, Sean Petersen Milne Point Unit/Schrader Bluff Production Engineer JUL 3 1 7_007. Well MPJ-17i Current Status: · 3/20/2002 Tag TD at 6498' ELMD - 18' OB open & bottom 10' covered · Well is currently on injection, but will be shut-in and freeze protected. Order of Operations: 1. 2. 3. 4. Kill well and Chemical Cut Tubing two to four feet above packer. MIRU Work Over Rig. Pull existing completion and remove fill. USIT cement bond log run at the time of the initial completion and indicates sufficient zone isolation above the perforated intervals. '/ a. Have been injecting since November 1997. 5. Run packer completion w/3,5" inje/ction string. 6. Obtain a state witness of MITIA. ~' 7. RDMO Work Over Rig, 8. Install surface injection equipment and tie in, 9, Commence injection into the Schrader Bluff sands with water for 9 months 10. Run state required injection profile survey, SCANNED JUL 3 I tO0 Tree: 4 1/16" - 5M carbon steel Wellhead: 11" 5M FMC Gen. 6 w/ 11" x 4.5" NSCT FMC Tbg. Hng., 4" ClW "H" BPV profile 20" 91.1 ppf, H-40 I 113' MPU J - 17i Orig. DF elev. = 64.32' (N 22E) Orig. GL. elev.= 35.2' DF to 7" csg. hgr. = 31.14' (N 22E) KOP @ 300' Max. hole angle = 66 to 68 deg. f/3000' to 4700' Hole angle through perfs = 49 deg. 7" Howco 'ES' cementer [ 2177' md I 7" 26 ppf, L-80, BTRC. production casing ( drift id = 6.151", cap. = 0.0383 bpf ) 3.5" 9.3 ppf, L-80 NSCT tubing ( drift id = 2.992", = .0087 bpf ) Minimum tubing restriction = 2.75" "XN" profile @ 5449 Stimulation Summary none performed Perforation Summary Ref log: 11/15/97 EWR / GR Interval (TVD) NB Sands 6174'-6208' NC Sands 6220'-6230' OB Sands 6380'-6430' 6480'-6508' 3844'-3866' 3873'-3880' 3913'-4010' 4048'-4062' SWS 51B HJII deep penetrating charges 2" Powerjet guns, 60 deg. phasing 4-spf ~ deep penetrating charges Fill at 6502' wlm 7" Baker 'S-3" Packer I 5433' md I 3.5" HES 'XN' npl. I 5449' md I (w/2.75" no-go' 5448' ELMD Two 7" x 21' marker jts. f/5639' to 5680' 7" landing collar (PBTD) 7" float collar 7" casing shoe 6613' md 6656' md 6699' md DATE REV. BY COMMENTS 11/20/97 JBF Drilled and Completed by Nabors 22E 9/03/99 MDO Add Perfs MILNE POINT UNIT WELL J-'l 7i APl NO: 50-020-~11~.8~ BP EX~~ATION (AK) I I ~1 I II (' MPU J- 17i {i Tree: 4 1/16" - 5M carbu,~ steel Wellhead: 11" 5M FMC Gen. 6 -- "-]----[~ii~i=::' ::=.: Orig. DF elev. - 64.32' (N 22E) w/ 11"x 4.5" NSCT FMC Tbg. Hng. I /'i!!i!'::~i'::!'::: Orig. GL. elev.= 35.2' 4" CIW "H" BPV profile ~ I I ::' i' i DF to 7" csg. hgr. = 31.14' (U 225) 20" 91.1 ppf, H-40 113' I Ii. ' _ ' t) 7"Howco'ES'cementer , 2177'md ioP@ 3oo' I 3.5" NBS 'X' iipp e Max. hole angle = 66 to 68 deg. I ~1 f/3000' to 4700' I Hole angle through perfs = 49 deg. I ~[Fi'l-"l Camco 3 1/2" x I 1/2' MMG I /~¢1 I 2.867" Drift I.D. 7" 26 ppf, L-80, BTRC. production casingI ( dr, iff id = 6'151"' cap' = 0'0383 bPf ) I 3.5 9.3 ppf, L-80 NSCT tubing . Minimum tub ng restriction = 2.75" I ~ ........... "XN" Nipple @ 6488' MD I ~ 6.o" r~-~ ,~, r~pple .. --.:.. ~ 7"x 3.5" Packer I 6O82' MD I I~ I"~.~'~..'."'" ~1 t;;I Camco 3 1/2" x 1 1/2" MMG , ~, 7"x 3.5" Packer I 6288' MB Stimulation Summary I none performed I~ ~ - Camco 3 1/2"x 1 1/2" MMG Perforation Summary ~:rr I~ '. i 2 MM Ref Ioq 11/15/97 EWR / GR 1 _:! ::'? ... ! '~,i 2C.%6%c,,°D3ri~t' ,2."DX. 1 1/" G 2" 4 6174'-6208' 3844'-3866' 7"x 3 5" Packer NCSands I~ ' I 6464'MDI ...... [!!~.:i.~;~.'~'~.;~ 2 4 6220-6230 3873-3880 II CA Ssnds ' " .,.:- 3.5" HES 'XN' npl. 6488' MDJ 2" 4 6380'-6430' 3913'-4010' I I ~ (w/2.75" no-.qo: ~-~-~II"~"!!':'~ 3.5" WLEGI MD I 4.5" 5 6480'- 6508' 4048'- 4062' I[~ SWS 51B HJII deep penetrating charges ~ Two 7" x 21' marker its. f/5639' to 56880' 2" Po',verjet guns, 60 deg. phasing 4-spf 1 deep penetrating charges ~ 7" landing collar (PBTD) ~ k 7" float collar 7" casing shoe 6699' md DA~- R~¥.~v, "C~Ji~M~__~TS MILNE POINT UNIT 11/20/97 JBF Drilled and Completed by Nabors 22E WELL J-17i 9/03/99 MDC Add Perfs APl NO: 50-029-22828'~ Proposed Recompletion 5/28/02 SDP BP EXPLORATI,~'~(AK) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor (.~, Chair . ..~"X~J BJ ECT: THRU: Tom Maunder ,~ ¢~r~~_..~~_ P.I. Supervisor,~~." ~,~~ FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL DATE' May 14, 2002 Mechanical Integrity Tests BPX MPU B-25, F-41 ,J-17,L-34 Milne Point Field Milne Point Unit P.T.D.I 1853~20 NoteS: ....... WellI F-41 ' p.T.D.I 1970950 Notes: , ,' w,e!!! J-17 P.T.D.! 1972080 Notes: Well[ L-34 ''' , P.T...D.I. 1970,800. Notes: Packer "Deptl~ ' ' Pretest Initial 15 Min. 30 Min. ' I TyPe inj.! N'I ,.'V.D. I'7'032' ITubingl 2600' ! 2600 1"'2600 I 26'00 I'nte~a'l '4 I Type re,sti !~ Test. I I I I.ps," ~o60'" Casing '650' ....... '~Ooo, i ~.06' i ~.~o .... ! >/~ '1.._1" I Type lnj.! Nl,.v.~:l'~o' l,u~,n~l~oo !~oo ! i ooo I','h,~a,I 4 Type teStl .p i Tes!,,p, si.i ~'500 lC~singi 590 l,,15j0.. ! ~.~0 !..146o' I" P/F I P Type,nj.I S ! T.v..:D. l'3.432 IT"b, ng 1~25o i125o J~2go i 12.5o !!.ni4Va, I 4, iTypetest! P I Test psil 1500. I.Casing ! 360. I 1540 I .1500 J 1490. ! PIE I, .P "Type lnj.! 'N l~.V.~, i 64o8"lTub, ng[ ?so ! s40 I a40 i ~40 l,n'~;~v~,l' 4 Type'tesil P. I T,estpsii 17°° Icasingl , ,' ,'I 170011670 I, 166° I P/F ,J,, ,_P ' Notes' Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details I traveled to BP's Milne Point Field to wimess MIT's. No Failures wimcssed. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance VV= Test during Workover O= Other (describe in notes) M.I.T.'s performed' 4 Number of Failures: 0_ Attachments: Total Time during tests: 8 hm. cc: MIT report form 5/12/00 L.G. MIT BPX MPU 05-14-02jc.xls 5/16/02 ALASKA c~ AND GAS CONSERVATION COP f'--SSION REPO. I' OF SUNDRY WELL OPERA~ iONS 1. Operations performed: [] Operation Shutdown []Stimulate E~ Plugging [] Perforate I--IPull Tubing F-]Alter Casing [] Repair Well []Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 4. Location of well at surface 2290' NSL, 3324' WEL, SEC. 28, T13N, R10E, At top of productive interval N/A At effective depth 1996' NSL, 2437' WEL, SEC. 29, T13N, R10 At total depth 3305' NSL, 2521' WEL, SEC. 29, T13N, R10E 5. Type of well: I-~ Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 64' 7. Unit or Property Name Milne Point Unit 8. Well Number MPJ-17 9. Permit Number / Approval No. 97-208 10. APINumber 50-029-22828 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 6725' feet true vertical 4205' feet Effective depth: measured 6613' feet true vertical 4131' feet Casing Length Structural Conductor Surface Intermediate Production Liner Size 83' 20" 6670' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx.) 1272 sx PF 'E', 163 sx Class 'G' MD TVD 112' 112' 6699' 4153' Perforation depth: measured 6480'-6508' true vertical 4043'-4062' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 @ 5461' Packers and SSSV (type and measured depth) Packer @ 5433' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: E] Oil I-q Gas [] Suspended Service Water Injection 17. I hereby certify that the fore, g_oing is true and correct to the best of my knowledge Signed PATR,OK J. COLUNS~" ") ~O~, ~- ~.~(~( [L..-~ Title Production Engineer Prepared By Name/Number: Date tO(7_,~ lqq Michael Williams, 564~4657 Form 10-404 Rev. 06/15/88 Submit In Duplicate MPJ-17 DESCRIPTION OF WORK COMPLETED ADDPERF 09/03/99 SUMMARY The following additional interval were perforated using 2" guns, 4 SPF, zero orientation and 60° phasing. 6174' - 6208' MD 6220' - 6230' MD 6380' - 6430' MD RECEIVED · ~','/ 0 5 1999 Gas Cons. Commission AOGCC Geological Materials Inventory PERMIT 97-208 BP EXPLORATION Log Data 8416 ~ SPERRY MPT/GR/EWR4/CNP/SLD CHEM CUTT ? /~- 4700-6600 DGR/CNP/SLD-MD /J.~'a~2561-6725 DGR/CNP/SLD-TVD j 2241-4204 DGR/EWR4-MD ~ 2561-6725 DGR/EWR4-TVD J 2241-4204 INJP-SPIN/TEM/ ~RES 6300-6604 PERF L~4700-6600 RFT ~5837-6520 USIT j BL(C) 6600-4700 Are dry ditch samples required? yes Was thewell cored? yes ~ no Are tests required? yes~ no Well is in compliance Initial Comments Sent Received 4/1/1998 4/1/1998 1/21/1998 1/29/1998 4/8/1998 4/8/1998 4/8/1998 4/8/1998 4/8/1998 4/8/1998 4/8/1998 4/8/1998 1/6/1999 1/15/1999 1/21/1998 '1/29/1998 1/21/1998 1/29/1998 3/23/1998 3/25/1998 Dailywellops ]}/!! / ~ ~ - ~ no And received? ~.Y.e,~.-.~.- no Analysis _description received? ----...y~ Received? --~.~.~2g.~ ..... no Box - no UIC Wednesday, October 13, 1999 Page I of 1 1/7/99 .'::11' GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN: Sherrie NO. 12211 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) Color Well Job # Log Description Date BL Sepia Print LIS Tape MPL-39 L,~t ~ 99003 USIT 980627 1 MPF-80 ~ ~'1 99005 DDL (PDC) 981207 1 MPB-O5A L~I c.. INJECTION PROFILE 981227 1 1 MPB-18 I RST-INJECTION WFL 981223 1 1 MPJ- i 7~ INJECTION PROFILE 981220 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) inc. Petrotectnical Data Center MBJ-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED 1999 Alaska Oil & Gas Cons. Commission /~nchofa,qe Schlumberger GeoQuest 3940 Arctic BIvd Anchorage, AK 99503 A'n'N: Sh~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND 1. Status of Well Classification of Service Wel'P,':-~ 7' {~, ..-.~);;~.?r- [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection '~,;~:W~:.~ .... & -.. ,. ,~ 'i 2. Name of Operator 7. Permit Number u, ..~a_.~ ~,0r~,% {~'8i BP Exploration (Alaska)Inc. 97-208 ~chora?.' ' 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22828 4. Location of well at surface 7%:~.-..:::;.; ..~:... ~ . 9. Unit or Lease Name 2290' NSL, 3324' WEL, SEC. 28, T13N, R10E, UM!~____, .t ~ i Milne Point Unit interval ~ ~~';i '". ~.~' t 10. Well Number At top of productive 3258' NSL, 2340' WEL, SEC. 29, T13N, R10E, UM ~ -~/r../~...,.¢.. ~. . · MPJ-17i At total depth ~ ~'"~: '~'~:~:; ~ ,~-'Zi~. t,. ~..~~ i 3305' NSL, 2521' WEL, SEC. 29, T13N, R10E, UM i .'~; 11. Field and Pool ................ ~' ,' Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Plan KBE = 64I ADL 025517 12. Date Spudded11/12/97 113' Date I'D' Reached ! 14' Date C°mp" Susp" °r Aband'l15' Water depth' if OffshOre I16' NO' °f c°mpletiOnsl 1/15/97 11/25/97 N/A MSLI One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional SurveY 120. Depth where SSSV set 121 · Thickness of Permafr°st 6725 4205 FTI 6613 4131 FTI [~Yes []No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, USIT, DPC RFT 23. CASING~ LINER AND CEMENTING RECORD CASING SE'FI-lNG DEPTH HOLE S~ZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 7" 26# L-80 31' 6699' 8-1/2" 1272 sx PF 'E', 163 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.3#, L-80 5461' 5433' MD TVD MD TVD 6480'-6508' 4043'-4062' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 70 bbls diesel I IRL 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) March 25, 1998 ! Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure ;CALCULATED OIL-EEL GAS-MCF WATER-EEL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. TSBF 6126' 3813' TSBE 6217' 3872' TSBD 6380' 3978' TSBB 6477' 4041' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the..J~oing is tr~'~and~rrect to the best of my knowledge Signed T. Bren~~~~C'JTitle. Drillin~ Engineering Supervisor Date MPJ-17i 97-208 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5-' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 11 Nov 97 12 Nov 97 13 Nov 97 14 Nov 97 15 Nov 97 16 Nov 97 17 Nov 97 M Pt J Pad Progress Report Well MPJ- 17 Rig Nabors 22E Page Date 19:00-19:30 Duration Activity 1/2 hr Rig moved 0.00 % 19:30-20:00 20:00-22:00 22:00-23:00 23:00-02:30 02:30-04:30 04:30-06:00 06:00-08:00 08:00-13:00 13:00-15:00 15:00-16:00 16:00-17:00 17:00-17:30 17:30-03:00 03:00-04:00 04:00-06:00 06:00-11:30 11:30-12:00 12:00-13:30 13:30-14:00 14:00-15:00 15:00-16:00 16:00-17:30 17:30-20:00 20:00-04:00 04:00-05:00 05:00-06:00 06:00-07:30 07:30-08:30 08:30-11:00 11:00-18:00 18:00-19:00 19:00-21:30 21:30-22:30 22:30-00:30 00:30-06:00 06:00-06:30 06:30-17:00 17:00-18:30 18:30-19:15 19:15-20:00 20:00-21:00 21:00-01:00 01:00-03:00 03:00-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-10:00 10:00-12:30 12:30-14:00 14:00-14:30 14:30-02:30 02:30-03:30 1/2 hr Held safety meeting 2 hr Rig moved 20.00 % 1 hr Rig moved 40.00 % 3-1/2 hr Rig moved 60.00 % 2 hr Rig moved 80.00 % 1-1/2 hr Rig moved 100.00 % 2 hr Rig moved 100.00 % 5 hr Rigged up Divertor 2 hr Made up BHA no. 1 1 hr Serviced Drillfloor / Derrick 1 hr Tested Divertor 1/2 hr Held safety meeting 9-1/2 hr Drilled to 1183.0 ft 1 hr Serviced High pressure lines 2 hr Drilled to 1457.0 ft 5-1/2 hr Drilled to 2563.0 ft 1/2 hr Circulated at 2563.0 ft 1-1/2 hr Pulled out of hole to 905.0 ft 1/2 hr Pulled BHA 1 hr Made up BHA no. 2 1 hr Serviced Top drive 1-1/2 hr Made up BHA no. 2 2-1/2 hr R.I.H. to 2563.0 ft 8 hr Drilled to 3988.0 ft 1 hr Circulated at 3988.0 ft 1 hr Pulled out of hole to 2500.0 ft 1-1/2 hr Pulled out of hole to 2142.0 ft 1 hr Serviced Top drive 2-1/2 hr R.I.H. to 3988.0 fi 7 hr Drilled to 5205.0 ft 1 hr Circulated at 5205.0 ft 2-1/2 hr Pulled out of hole to 943.0 ft 1 hr Serviced Top drive 2 hr R.I.H. to 5205.0 ft 5-1/2 hr Drilled to 5874.0 ft 1/2 hr Held safety meeting 10-1/2 hr Drilled to 6725.0 ft 1-1/2 hr Circulated at 6725.0 ft 3/4 hr Pulled out of hole to 5111.0 ft 3/4 hr R.I.H. to 6525.0 ft 1 hr Circulated at 6525.0 ft 4 hr Pulled out of hole to 900.0 ft 2 hr Pulled BHA 1 hr Serviced Block line 1/2 hr Serviced Top drive 1-1/2 hr Conducted electric cable operations 1/2 hr Held safety meeting 3-1/2 hr R.I.H. to 5728.0 ft 2-1/2 hr Circulated at 5728.0 ft 1-1/2 hr R.I.H. to 6585.0 ft 1/2 hr Pulled out of hole to 6100.0 ft 12 hr Conducted electric cable operations 1 hr Conducted electric cable operations 1 04 May 98 Progress Report Facility M Pt J Pad Well MPJ-17 Page 2 Rig Nabors 22E Date 04 May 98 Date/Time 03:30-06:00 06:00-08:30 08:30-08:45 08:45-10:30 10:30-16:30 16:30-19:00 19:00-19:30 19:30-20:30 20:30-21:00 21:00-21:45 21:45-22:45 22:45-23:15 23:15-00:00 18 Nov 97 00:00-02:00 02:00-04:00 04:00-06:00 06:00-12:00 12:00-16:30 16:30-20:30 20:30-21:00 21:00-00:30 19 Nov 97 00:30-01:00 01:00-02:00 02:00-04:30 04:30-06:00 06:30-07:30 07:30-13:30 20 Nov 97 01:00-04:00 04:00-06:00 06:00-08:00 08:00-09:30 09:30-10:00 10:00-18:00 18:00-22:00 22:00-04:30 21 Nov 97 04:30-06:00 06:00-08:00 08:00-08:30 08:30-11:00 11:00-14:30 14:30-21:00 21:00-22:00 22:00-01:30 22 Nov 97 01:30-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-11:00 11:00-15:30 15:30-20:00 20:00-23:00 23:00-00:00 23 Nov 97 00:00-04:30 04:30-05:00 Duration 2-1/2 hr 2-1/2 hr 1/4 hr 1-3/4 hr 6hr 2-1/2 hr 1/2 hr lhr 1/2 hr 3/4 hr lhr 1/2 hr 3/4 hr 2hr 2hr 2 hr 6hr 4-1/2 hr 4hr 1/2 hr 3-1/2 hr 1/2 hr lhr 2-1/2 hr 1-1/2 hr lhr 6hr 3hr 2hr 2hr 1-1/2 hr 1/2 hr 8hr 4hr 6-1/2 hr 1-1/2 hr 2hr 1/2 hr 2-1/2 hr 3-1/2 hr 6-1/2 hr 1 hr 3-1/2 hr 2-1/2 hr 1/2hr 1-1/2 hr 1/2 hr 4-1/2 hr 4-1/2 hr 4-1/2 hr 3hr lhr 4-1/2 hr 1/2 hr Activity Pulled out of hole to 4000.0 ft Pulled out of hole to 0.0 ft Held safety meeting Rigged up Casing handling equipment Ran Casing to 6699.0 ft (7in OD) Circulated at 6699.0 ft Held safety meeting Mixed and pumped slurry - 156.000 bbl Displaced slurry - 240.000 bbl Circulated at 2177.0 ft Mixed and pumped slurry - 395.000 bbl Displaced slurry - 72.000 bbl Rigged down Cement unit Removed Divertor Installed Casing head Installed BOP stack Installed BOP stack Tested BOP stack Singled in drill pipe to 2177.0 ft Worked toolstring at 2177.0 ft Singled in drill pipe to 6576.0 ft Worked toolstring at 6612.0 ft Tested Casing Circulated at 6612.0 ft Pulled out of hole to 4000.0 ft Pulled out of hole to 0.0 ft Rigged up Lines / Cables Ran Drillpipe to 6000.0 ft (3-1/2in OD) Pulled out of hole to 4000.0 ft Pulled out of hole to 0.0 ft Serviced Top drive Held safety meeting Ran Tubing to 3806.0 ft (3-1/2in OD) Conducted slickline operations on Slickline equipment - Retrival run Conducted electric cable operations Pulled Tubing in stands to 3000.0 ft Pulled Tubing in stands to 0.0 ft Installed Wear bushing Ran Drillpipe to 1000.0 ft (3-1/2in OD) Singled in drill pipe to 3798.0 ft Worked toolstring at 3798.0 ft Circulated at 3828.0 ft Pulled out of hole to 0.0 ft Ran Drillpipe to 3918.0 ft (3-1/2in OD) Circulated at 3918.0 ft Singled in drill pipe to 4500.0 ft Singled in drill pipe to 4700.0 ft Serviced Draw works Singled in drill pipe to 6540.0 ft Pulled out of hole to 0.0 ft Ran Drillpipe in stands to 6609.0 ft Reverse circulated at 6609.0 ft Pulled out of hole to 0.0 ft Serviced Top drive Milne Point Unit, Ak. TO: J. Hendrix FROM: Herb Thackeray Well Name: IMP J-17i Main Category: IE-Line Sub Category: ILo~l/Perf Operation Date: 111-19-97 Date: 111-20-97 I Objective: Run Schlumberger USIT log to evaluate cement. Perforate "OB" interval from 6480 - 6508'. Sequence of Events: RU SWS. RIH with USIT tool. Depth correlate to Sperry Sun MWD DGR/EWR4/ROP log 11-15-97. Run USIT log from 6600-4700' (1000' above "M" sand). Good cement (avg. bond index of 80%) from 6600-6000', fair from 6000-5700' (avg. bond index 70%), excellent from 5700-5550' (>80% bond index), fair to good cement 5550-4700'. PJSM. Ready to arm guns, requested radio silence. PU 4 ~/~" perf guns and start in hole. Pressure test lubricator - leaked at 200 psi. Changed ©-ring and retest to 1000 psi- ok. RIH with guns and depth correct. Perforate "OB" sand from 6480- 6508' with 5 SPF 51B HJ 2-RDX. POOH, all shots fired. RD SWS. Results: Ran USIT log from 6600 - 4700'. Cement okay across zones of interest. Perforated "OA" sand from 6480 - 6508' MD. Diesel Used 10 I Methanol Used 10 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING MPU / MPJ-17 500292282800 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 111597 MWD SURVEY JOB NUMBER: AKNLM80007 KELLY BUSHING ELEV. = PAGE 1 64.32 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD vERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES VERT. DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -64.32 0 0 112.00 112.00 47.68 0 0 146.40 146.40 82.08 0 4 208.40 208.40 144.08 0 7 297.10 297.09 232.77 1 7 N .00 E .00 .00N .00E .00 N .00 E .00 .00N .00E .00 N 68.63 E .23 .01N .02E -.02 S 37.52 W .33 .03S .02E -.03 N 72.10 W 1.23 .16N .87W .89 387.47 387.41 323.09 478.17 478.03 413.71 567.83 567.51 503.19 658.19 657.49 593.17 754.20 752.89 688.57 2 22 2 37 4 22 5 56 6 57 N 68.02 W 1.39 1.13N 3.46W 3.63 N 77.29 W .52 2.29N 7.23W 7.56 N 83.59 W 2.00 3.13N 12.62W 13.00 N 80.70 W 1.77 4.27N 20.67W 21.10 N 78.21 W 1.09 6.26N 31.27W 31.88 844.22 842.12 777. 937.81 934.44 870. 1029.67 1024.30 959. 1120.08 1111.99 1047. 1212.41 1200.51 1136. 80 8 10 12 10 41 98 13 12 67 14 54 19 18 6 N 80.09 W 1.38 8.48N 42.92W 43.73 N 75.80 W 2.79 11.76N 57.90W 59.07 N 73.10 W 2.80 16.90N 76.22W 78.07 N 74.61 W 1.92 22.99N 97.32W 99.99 N 76.06 W 3.48 29.60N 122.69W 126.20 1303.90 1286.49 1222. 1394.61 1369.53 1305. 1487.09 1452.25 1387. 1580.20 1533.64 1469. 1673.13 1612.20 1547. 17 21 49 21 25 34 93 27 31 32 30 33 88 34 0 N 77.31 W 4.09 36.76N 153.09W 157.43 N 78.26 W 4.16 44.45N 188.71W 193.87 N 77.79 W 2.13 53.03N 229.14W 235.20 N 78.52 W 3.28 62.29N 273.38W 280.39 N 76.97 W 3.81 72.86N 321.86W 330.00 1763.98 1686.20 1621. 1856.98 1759.49 1695. 1947.67 1829.61 1765. 2040.80 1900.25 1835. 2132.14 1967.22 1902. 88 36 54 17 39 3 29 39 39 93 41 39 90 43 59 N 76.44 W 3.21 84.98N 373.13W 382.69 N 76.78 W 2.33 98.23N 428.80W 439.91 N 77.93 W- 1.04 110.82N 484.92W 497.42 N 78.35 W 2.17 123.28N 544.29W 558.08 N 77.20 W 2.69 136.44N 604.96W 620.15 2223.38 2031.15 1966. 2315.94 2092.07 2027. 2408.42 2149.26 2084. 2499.93 2202.44 2138. 2544.54 2227.38 2163. 83 47 2 75 50 37 94 52 57 12 55 58 06 56 1 N 76.26 W 3.42 151.39N 668.30W 685.23 N 75.99 W 3.88 168.10N 735.94W 754.89 N 77.34 W 2.76 184.84N 806.63W 827.53 N 76.61 W 3.37 201.63N 879.17W 901.99 N 76.57 W .13 210.21N 915.14W 938.97 2635.47 2276.89 2212. 2727.88 2324.11 2259. 2821.08 2368.09 2303. 2915.62 2409.84 2345. 3007.14 2448.42 2384. 57 57 58 79 60 33 77 63 7 52 64 28 10 65 39 N 75.72 W 2.28 228.48N 989.17W 1015.21 N 77.52 W 3.26 246.84N 1066.44W 1094.63 N 78.16 W 2.81 264.14N 1146.76W 1176.78 N 77.86 W 1.46 281.76N 1229.73W 1261.59 N 78.88 W 1.65 298.49N 1311.01W 1344.56 ORiGiNAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING MPU / MPJ-17 500292282800 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 111597 MWD SURVEY JOB NUMBER: AK~V~80007 KELLY BUSHING ELEV. = 64.32 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3100.02 2485.67 2421.35 67 3 N 77.59 W 1.96 3192.36 2521.81 2457.49 66 52 N 78.24 W .68 3285.18 2558.65 2494.33 66 21 N 76.94 W 1.40 3377.31 2595.74 2531.42 66 9 N 76.44 W .54 3469.42 2633.71 2569.39 65 8 N 76.14 W 1.15 315.84N 1394.29W 1429.62 333.63N 1477.38W 1514.58 351.93N 1560.58W 1599.77 371.35N 1642.65W 1684.10 391.24N 1724.17W 1768.00 3559.78 2670.58 2606.26 66 41 N 76.54 W 1.77 410.71N 1804.33W 1850.48 3652.58 2707.96 2643.64 65 47 N 75.98 W 1.13 430.89N 1886.83W 1935.40 3745.62 2746~14 2681.82 65 45 N 75.70 W .28 451.64N 1969.09W 2020.22 3837.86 2784.25 2719.93 65 26 N 75.34 W .48 472.64N 2050.43W 2104.18 3928.35 2820.37 2756.05 67 30 N 78.75 W 4.14 491.22N 2131.27W 2187.14 4020.52 2855.60 2791.28 67 32 N 78.02 W .73 4112.82 2890.65 2826.33 67 49 N 77.91 W .32 4204.30 2925.21 2860.89 67 47 N 78.36 W .46 4295.72 2960.23 2895.91 67 9 N 78.08 W .74 4389.05 2996.61 2932.29 66 57 N 77.72 W .41 508.37N 2214.70W 2272.29 526.17N 2298.20W 2357.66 543.59N 2381.09W 2442.35 560.83N 2463.76W 2526.78 578.84N 2547.80W 2612.73 4484.03 3034.04 2969.72 66 37 N 77.33 W .52 4577.50 3071.46 3007.14 66 10 N 77.75 W .63 4672.72 3110.30 3045.98 65 40 N 78.62 W .99 4767.82 3149.77 3085.45 65 16 N 78.34 W .51 4863.44 3189.39 3125.07 65 46 N 78.46 W .55 597 . 70N 2633.03W 2700.02 616.18N 2716.66W 2785.67 633.98N 2801.76W 2872.59 651.26N 2886.54W 2959.09 668 . 76N 2971 . 79W 3046.10 4958.77 3228.62 3164.30 65 36 N 78.45 W .18 5053.43 3268.07 3203.75 65 8 N 77.94 W .70 5143.08 3306.11 3241.79 64 38 N 77.97 W .56 5241.26 3348.27 3283.95 64 30 N 77.40 W .54 5335.16 3389.11 3324.79 63 56 N 78.58 W 1.28 686.15N 3056.91W 3132.96 703.75N 3141.14W 3219.00 720.69N 3220.53W 3300.17 739.60N 3307.15W 3388.83 757.20N 3389.85W 3473.37 5433.18 3432.45 3368.13 63 34 N 78.37 W .42 5527.86 3476.62 3412.30 60 48 N 78.25 W 2.92 5622.99 3522.83 3458.51 61 3 N 77.16 W 1.04 5717.67 3569.84 3505.52 59 24 N 76.07 W 2.02 5817.36 3623.10 3558.78 56 0 N 76.15 W 3.41 774.76N 3475.99W 3561.26 791.73N 3557.99W 3644.99 809.43N 3639.23W 3728.13 828.45N 3719.17W 3810.30 848.68N 3800.96W 3894.53 5912.41 3678.29 3613.97 53 0 N 75.97 W 3.16 6003.98 3734.99 3670.67 50 28 N 78.10 W 3.30 6103.25 3798.34 3734.02 50 13 N 77.40 W .60 6198.36 3859.47 3795.15 49 47 N 76.28 W 1.01 6293.77 3921.34 3857.02 49 20 N 76.14 W .47 867.31N 3876.06W 3971.89 883.46N 3946.11W 4043.78 899.68N 4020.80W 4120.21 916.27N 4091.75W 4193.06 933.58N 4162.28W 4265.68 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING MPU / MPJ-17 500292282800 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 111597 MWD SURVEY JOB NUMBER: AKMM80007 KELLY BUSHING ELEV. = 64.32 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6388.09 3983.00 3918.68 49 0 N 75.23 W .81 951.22N 4231.44W 4337.03 6483.46 4045.66 3981.34 48 50 N 74.96 W .28 969.72N 4300.91W 4408.87 6576.74 4107.18 4042.86 48 37 N 75.85 W .75 987.38N 4368.76W 4478.95 6669.18 4168.26 4103.94 48 39 N 75.48 W .30 1004.56N 4435.99W 4548.31 6725.00 4205.13 4140.81 48 39 N 75.48 W .00 1015.07N 4476.56W 4590.20 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4590.20 FEET AT NORTH 77 DEG. 13 MIN. WEST AT MD = 6725 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 282.78 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 6,725.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING MPU / MPJ-17 500292282800 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 111597 JOB NUMBER: AKMM80007 KELLY BUSHING ELEV. = 64.32 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -64.32 .00 N .00 E 1000.00 995.37 931.05 15.03 N 69.91 W 2000.00 1869.76 1805.44 117.80 N 517.73 W 3000.00 2445.47 2381.15 297.23 N 1304.63 W 4000.00 2847.76 2783.44' 504.43 N 2196.15 W 5000.00 3245 65 3181.33 693.67 N 3093.70 W 6000.00 3732.46 3668.14 882.83 N 3943.10 W 6725.00 4205.13 4140.81 1015.07 N 4476.56 W .00 4.63 4.63 130.24 125.60 554.53 424.29 1152.24 597.71 1754.35 602.11 2267.54 513.19 2519.87 252.34 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 SHARED SERVICES DRILLING MPU / MPJ-17 500292282800 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 111597 JOB NUMBER: AKMM80007 KELLY BUSHING ELEV. = 64.32 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -64.32 64.32 64.32 .00 164.32 164.32 100.00 264.32 264.32 200.00 364.36 364.32 300.00 464.45 464 32 400.00 564. 63 564.32 500.00 665.05 664.32 600.00 765.71 764.32 700.00 866.67 864.32 800.00 .00 N .00 E .00 N .00 E .02 N .04 E .04 S .26 W .77 N 2.57 W 2.16 N 6.62 W 3.10 N 12.38 W 4.38 N 21.37 W 6.55 N 32.64 W 9.09 N 46.19 W .00 .00 .00 .00 .00 .00 .00 .04 .03 .13 .09 .31 .18 .73 .42 1.39 .66 2.35 .95 968.27 964.32 900.00 1070.80 1064.32 1000.00 1174.49 1164.32 1100.00 1280.10 1264.32 1200.00 1388.85 1364.32 1300.00 13.26 N 63.60 W 19.64 N 85.29 W 26.81 N 111.70 W 34.84 N 144.64 W 43.95 N 186.32 W 3.95 1.60 6.48 2.53 10.17 3.69 15.78 5.62 24.53 8.75 1500.73 1464.32 1400.00 1616.09 1564.32 1500.00 1736.79 1664.32 1600.00 1863.20 1764.32 1700.00 1992.87 1864.32 1800.00 54.37 N 235.35 W 66.11 N 291.61 W 81.22 N 357.43 W 99.12 N 432.61 W 116.85 N 513.23 W 36.41 11.88 51.77 15.36 72.47 20.70 98.88 26.41 128.55 29.67 2128.11 1964.32 1900.00 2272.99 2064.32 2000.00 2433.70 2164.32 2100.00 2611.76 2264.32 2200.00 2812.81 2364.32 2300.00 135.82 N 602.23 W 160.20 N 704.12 W 189.33 N 826.42 W 223.52 N 969.69 W 262.62 N 1139.57 W 163.79 35.24 208.67 44.88 269.38 60.71 347.44 78.06 448.49 101.05 3045.82 2464.32 2400.00 3299.33 2564.32 2500.00 3543.96 2664.32 2600.00 3789.83 2764.32 2700.00 4043.34 2864.32 2800.00 305.33 N 1345.60 W 354.86 N 1573.21 W 407.33 N 1790.19 W 461.62 N 2008.14 W 512.75 N 2235.33 W 581.50 133.01 735.01 153.50 879.64 144.63 1025.51 145.87 1179.02 153.51 4306.25 2964.32 2900.00 4559.82 3064.32 3000.00 4802.61 3164.32 3100.00 5044.52 3264.32 3200.00 5278.54 3364.32 3300.00 562.83 N 2473.26 W 612.75 N 2700.86 W 657.64 N 2917.48 W 702.06 N 3133.23 W 746.94 N 3339.99 W 1341.93 162.91 1495.50 153.57 1638.29 142.79 1780.20 141.91 1914.22 134.02 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MPU / MPJ-17 500292282800 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 111597 JOB NUMBER: AKMM80007 KELLY BUSHING ELEV. = 64.32 FT. OPERATOR: BP EXPLORATION iNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5502.32 3464.32 3400.00 787.18 N 3536.08 W 2038.00 123.78 5706.83 3564.32 3500.00 826.20 N 3710.11 W 2142.51 104.50 5888.96 3664.32 3600.00 862.75 N 3857.78 W 2224.64 82.13 6050.05 3764.32 3700.00 890.82 N 3980.86 W 2285.73 61.09 6205.88 3864.32 3800.00 917.63 N 4097.32 W 2341.56 55.83 6359.62 3964~32 3900.00 945.74 N 4210.66 W 2395.30 53.74 6511.81 4064.32 4000.00 975.25 N 4321.53 W 2447.49 52.20 6663.22 4164.32 4100.00 1003.44 N 4431.66 W 2498.90 51.41 6725.00 4205.13 4140.81 1015.07 N 4476.56 W 2519.87 20.97 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11734 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 1/21/98 Well Job # Log Description Date BL RF Sepia LIS Tape MPB-25 PERFORATION RECORD 9 8 0101 1 1 MPU C-15 INJECTION PROFILE 971 1 24 1 1 MPG-11 STATIC PRESSURE SURVEY 971 223 I 1 MPG-11 PERFORATION RECORD 9 71 2 23 I 1 MPG-11 PERFORATION RECORD 9 71 2 2 9 I 1 MPG-12 PERFORATING RECORD 9 8 01 10 I 1 MPG-12 PERFORATING RECORD 9 801 13 I 1 MPG-12 PERFORATING RECORD 9 8 01 1 6 I 1 MPJ-17 RFT 971 1 16 I 1 MPJ-17 PERF RECORD 971 1 1 9 I 1 MPJ-17 CHEMICAL CUT RECORD 9 71 1 19 I 1 MPK-34 PERFORATION RECORD 971 1 17 1 1 MPK-34. SUMP PACKER SET RECORD 971 1 17 I 1 MPL-35 TCP GR TIE IN W/PRESS-TEMP 971 207 I I . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 STATE. OF ~ ALASKA OL AI~ GAS CONSERVA~ COMAflS~K)N DATE: f .~v'~.3 I I ! I ~1 = ~INJ. - I: NOT INdECTING AII~I.A.A~ FLUIO: 8~LT WATER OTTER o3qg O~TOR REP MI~.XLT WELL TEST: Initial 4 - Year Wor~r .RECEIVED & ~as Cons. Comr~i,~,ion Anchorage TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 10. 1997 Chip Aivord Scnior Drilling Enginccr BP Exploration (Alaska). Inc. PO Box 196612 Anchoragc, AK 99519-6612 Re: Milnc Point Unit MPJ-17i BP Exploration (Alaska). Inc. Pcrmit No. 97-208 Sur. Loc 2290'NSL. 3324'WEL. SEC.28. T13N. RIOE. UM Btmholc Loc. 3361 'NSL: 2779'WEL. SEC.29. TI3N. R10E. UM ,. Dcar Mr. Alvord: Encloscd is thc approved application for pcrmit to drill thc abovc rcfcrcnccd xvcll. Thc pcrmit to drill docs not cxcmpt you from obtaining additional pcrmits rcquircd by law from other govcrnmcntal agcncics, and docs not authorizc conducting drilling opcrations until all other rcquircd pcrmitting dctcrminations arc made. Thc blowout prcvcntion cquipmcnt (BOPE) must bc tcstcd in accordancc xvith 20 AAC 25.035: and thc mcchanical intcgrity (MI) of thc injection wells must bc dcmonstratcd undcr 20 AAC 25.412 and 20 25.030(g)(3). Sufficicnt noticc (approximatcly 24 hours) of thc MI tcst bcforc opcration, and of thc BOPE tcst pcrtbrmcd bcforc drilling bclov,' thc surfacc casing shoe. must be givcn so that a rcprcscntativc of thc Commission may wimcss thc tcsts. Noticc may bc givcn by contacting thc Commission pctrolcum ficld inspcctor on thc North Slopc pagcr at 659-3607. David W. Johnst6n Chairman BY ORDER OF THE COMMISSION dlf/Enclosurc cc: Dcpartmcnt of Fish & Game. Habitat Section xv/o cncl. Dcpartmcnt of Environmcntal Conscrvation xv/o cncl. · STATE OF ALASKA ALASKA ,~,-iL AND GAS CONSERVATION CObi~ilSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil; I--IRe-Entry ElDeepenI [~Service [] Development Gas [-'lSingleZone [-I Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 64.5' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025517 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2290' NSL, 3324' WEL, SEC. 28, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3201' NSL, 2072' WEL, SEC. 29, T13N, R10E, UM MP J-17i At total depth 9. Approximate spud date Amount $200,000.00 3361' NSL, 2779' WEL, SEC. 29, T13N, R10E, UM 11/11/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025515, 1919'I No Close Approach 2555 6930' MD / 4151' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 64.53° Maximum surface 1276 psig, At total depth (TVD) 3741' / 1650 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 8-1/2" 7" 26# L-80 BTC-MOD 6899' 31' 31' 6930' 4151' 764 sx PF 'E', 183 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet / Effective depth: measured feet Junk (measured) %,// true vertical feet ~-/ / Casing Length Size Cementedk,.~--~/ MD TVD Structural Conductor ~f~/ . Surface Intermediate '~' ~.~ ~V ~D 0~ ' Liner Perforation depth: measured ~"~?f~i~~_'P,(j6A¢~~ true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Aivord///'~..,~ '~. ~ Title Senior Drilling Engineer Date "["~f '~ :~ Chip . Commission Use Only Permit Number I APl Number I Acrov, al Date I See cover letter ~'.~-~__O~' 50- 0.2--I~.-- 2_ P__~"~.~_~ /, [L~O[¢'~ for other requirements Conditions of Approval: Samples Required []Yes l~No Mud Log Required []Yes ~No Hydrogen Sulfide Measures []Yes ~i~'No Directional Survey Required J~Yes[]No Required Working Pressure for BOPE ~2M; []3M; []5M; [] 10M; [] 15M ...- Other: Original Signed By by order of [/ Approved By David W. Johnston Commissioner the commission Date ! '~ . . Form 10-401 Rev. 12-01-85 Submit Shared Services Drilling Contact: I Well Name: James E. Robertson IMP J-17i Well Plan Summary IType of Well (producer or injector): SCHRADER BLUFF INJECTOR 564-5159 Surface Location: 2290 FSL, 3324 FEL, S28 T13N R10E UM Tar~let Location: 3201 FSL, 2072 FEL, S29 T13N R10E UM Bottom Hole Location: 3361 FSL, 2779 FEL, S29 T13N R10E UM I AFE Number: I 337101 I Estimated Start Date: I 11NOV97 I IMD: 1683°' I ITVD: Rig: I Nabors 22E I Operating days to complete: 14108' I I KBE: 64.5 ft I Well Design: Schrader Bluff Injector Formation Markers: Formation Tops MD TVDSS KOP 300 300 Base of Permafrost 1945 1775 Top of Ugnu 4996 3255 Top M Sand 5540 3489 Top NA (Target) 6126 3741 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 6196 3771 NCND 6278 3806 NE 6322 3825 NF 6435 3874 OA 6524 3912 OA4 66O3 3924 OB 6680 3979 Top of Seabee 6731 4001 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 6930 4087 TD at 200' MD past base of Schrader Casin~l/'rul: in~l Program: Hole ,~ize ' Csg~ Wt/Ft Grade Conn. Length Top Bottom Tb~l O.D. MD/TVD MD/'rVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112'/112' 8-1/2" 7" 26# L80 BTC-MOD 6899' 31 '/31' 6930' / 4087' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/fi) to the reservoir at +3741' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1650 psi (8.50 ppg EMW), is 1276 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Op~ H~le L~gs: MWD from surface to TD LWD (GR/Resistivity/Density/ROP) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr through the Ugnu and Schrader Bluff intervals. Cased Hole Logs: NONE Mudloggers are NOT required for this well. Mud Program' Spud Mud ISpecial design considerations I See "Drilling Hazards and Risks" section about dealing with the I possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 10.2 100 35 15 30 10 8-10 (final) TOP OF SCHRADER BLUFF TO TD: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.8 80 20 10 20 9.5 6 (as required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. A Completion/Workover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: IKOP: 1300' MD Maximum Hole Angle: Close Approach Well: 64.53 NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. Fluids Handling' All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on J-Pad have been permitted for annular injection. MP J-171 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. N/U and function test 21-1/4" Hydril MSP 2M diverter system. Build Spud Mud. 5. Drill 8-1/2" surface hole as per directional plan to 6930' MD / 4151' TVD. Run Directional MWD from surface to TD and run LWD GR/Resistivity/Density/ROP from the top of the Ugnu to TD. NOTE: Fill hole with mud and check diverter for leaks before spudding in. NOTE: Short trip no deeper than 300' md past the base of permafrost. NOTE: Utilize lubricants as necessary to enhance sliding performance. NOTE: Drill at a controlled rate of no more than 200 ft/hr through the Ugnu and Schrader Bluff sands to ensure good LWD readings. 6. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 7. POOH and LD BHA. 8. Run and cement 7", 26#, L-80, BTC-Mod casing. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost. 9. N/D Diverter. N/U FMC Gen 6 Wellhead and Tree. Note that MP J-17i will have 3-1/2" tubing. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) DRILLING HAZARDS AND RISKS: See the latest Milne Point I-Pad Data Sheet prepared by Pete Van Dusen for information on J pad. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: NO HYDRATES HAVE BEEN ENCOUNTERED ON ANY WELLS DRILLED AT MILNE POINT 'J' PAD TO DATE. If hydrates are encountered the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MP J-17i. 3. Lost Circulation: 7 Schrader Bluff wells have been drilled on Milne Point 'J' pad since 1990 and none of them experienced any problems associated with lost circulation. In an effort to continue this trend maintain slow, steady running speeds while running casing and ensure mud is in good shape before POOH to run casing. LCM should be kept on hand, particularly if the mud is weighted up to counteract gas cut mud due to hydrates. 4. Stuck Pipe Potential: No stuck pipe incidents have been associated with the drilling of Schrader Bluff wells on Milne Point 'J' Pad to date. Some tight hole on trips has been encountered in the 2000' TVD to 3500' TVD range. Once tripped through the tight hole problems went away. The wells on Milne Point 'H' Pad drilled during the summer of 1997 encountered severe tight hole problems; especially swabbing problems while POOH. We will also break circulation at the first indication of swabbing on short trips. If heavy gravels are encountered while drilling the surface hole section, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.5 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinq Concerns Care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 7. Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. A 'C' cement for the second stage tail cement will be incorporated into the cementing program only if hydrates are encountered. ,- MP J-171 7" SURFACE/PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: ~ 80°F SPACER: 50 BBL water STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST FLOCELE (0.25 #/sk) 12.0 ppg YIELD: 2.17 ft3/sk MIX WATER: 11.63 gal/sk 250 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE TOP OF THE STAGE1 TAIL AT 5040' MD TO THE ES CEMENTER STAGE TOOL (2200' MD > 200' MD BELOW BASE OF PERMAFROST) + 50% EXCESS. STAGE1 TAIL CEMENT TYPE: ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: PREMIUM SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk), FLOCELE (0.1 #/sk) 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 183 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (6930' MD) TO 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (5540' MD) + 50% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. EST TOC 5040' MD SPACER: 50 BBL water STAGE2 LEAD: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: Retarder 12.0 ppg 514 SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM ES CEMENTER TOOL AT 2200' MD TO SURFACE +300% EXCESS. STAGE2 TAIL: ADDITIVES: ~WEIGHT: APPROX #SACKS: TYPE 'C' PERMAFROST Retarder 15.6 ppg YIELD:0.95 ft3/sk MIX WATER: 3.60 gal/sk 000 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - one (1) per joint on the bottom twenty-three (33) joints of 7" casing. Run two centralizers on the bottom joint of casing and on the top centralized joint of casing as well. (33+2 = 35 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8.0-10.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is not necessary. DISPLACEMENT OF CEMENT: Because Nabors 22E will be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with water a volume equal to the capacity of the 7" casing from TD up to the ES Cementer at 2200' md followed by mud at TD mudweight. 2. After bumping the plug, quickly check to ensure that the floats are holding and then shear the ES cementer to the open position. 3. Circulate mud through the ES cementer for a minimum of two hours to clean and condition contaminated cement. 4. Pump the second stage as per the detailed cement program. When cement returns are seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for reuse on another well. Z ~907) 3~9-4511 Fax 344-2160 D[RECTIONAL W~Lh PLAN for SHARHD SHR¥~CEg$ DRILhlNO Well ......... : MPJ-17 (P4) Field ........ : Miloe Po/nC Copulation.,: Minimum Curvature Units ........ : FSBT Surface Lat..: 70.45086820 Su~faoe Long.; 149.57577369 Legal Description ~rface ...... : 2290 FSh 3325 PSt S28 T13N R10E U M Target ....... : 3201 FSL 2072 FEL S29 TI3N R30H 124 8HL .... : ..... : 3361PSb 2779 FI~ ~29 TI3N RZOH ~ L~TIONS - AI~KA Zone: XlCoord 5~1995,~1 54796~.00 54725[.67 4 Y-Cx>ord 60~4687.83 60£S~2.00 6015727.45 b-~ATION MF_,ASU~D INCLN 1DBNTIFICATION DE~;~/'H ANGLE KB O.0D 0.00 KD~/~UiLD ~/~00 300.00 0.00 BUILD 3.5/~00 400.00 ~.00 500.00 2.50 8UrLD 2/100 600.00 4.00 D]P~TION VH~TIC~-DBPT~S S~XZTZON AZI ~ 'TVD SU~ - $]~ DRPART , 0.00 0.00 -64.70 0.00 0.00 300.00 235.30 282.76 399.99 335.29 O.fi7 282.76 499.95 ~35.25 3.93 282.76 599.78 53~.00 9.60 ~repared ..... : 04 Nov 1997 Vert sect a~,: 282.76 KB elevation.= 64.70 ft Magnetic Dcln: 427.854 (8) Sea~e Factor.: 0.99990307 Conve~ence..: +~.39977256 0.00 N O. O0 0.00 N 0.00 0'.19 N O.85 D.B7 N 3.83 2.£2 N 9,36 X Y PACB ZOO 551995.51 6014687.83 HE 0.00 553995.5~ 6014687.83 77L 0.00 5~1994.66 601{680.02 77L 1.00 55199~.67 6014688.67 qqL 1,50 55~906.14 6014689.88 77~ ~.50 eurz~ 2.5/~oo 700.00 6.00 BOO.O0 B.O0 900,00 10,00 1000.00 12.50 llO0.DO 15.00 1200.00 17.50 1300.00 20.50 282.76 699.40 634.70 18-31 282,76 798.65 733.95 30.50 282,76 897.41 832.7~ 46.14 282.76 995.48 930.78 65.65 282.76 LD92.61 1027.91 89.41 282.76 1108.60 LL23.90 117.39 282,76 L283.15 1218,45 149.95 4.04 N 17.86 6,74 N 29.74 10.19 N 45.00 14.50 N 64.03 19.~S N 87.21~ 25.93 N 114.49 33.~2 N 346.24 551977.63 6014691,75 HS 2.00 551965.72 6034694.36 NS 2.00 5~L950.~4 60L4697.7~ HS 2.00 55193L.39 6014703.88 NS 2.50 55190~,1~ 6014706.97 HS 2.50 551880.85 6014712.96 H$ 2,$0 551849.05 601i719.93 HS 3.00 (AnadrllL (c)97 ~IPJ17P5 3,0C 10:22 Abl P) W O_ n~ Z MPJ-17 (P4) 04 Nov L997 Pa~e 2 STAT/ON ID~NTIFICAT]0N MHA~URHD I~CLN DIRECTION VERT~ CAL-DE~THZ SECTION DEPT~ ,P~qOL1~ AZI MOTH TVD SUB- SRA DEPART L400,O0 23.50 282.76 1375.85 13 Lf.]5 ~87.40 1500.00 26.50 282,76 1466.47 1401.77 229.66 3600.00 29.50 282,76 3554.?6 t490.06 276.60 ~700.00 32.50 282.76 1640,~7 1575.77 328.t0 1800.00 35.50 282.76 ~723.36 1658.66 384.0~ C00RD£NATHS-FROM Aldt~KA Zone ~ H~L~ X Y 41.39 N 182.78 W 55~832.47 6054727.94 50,73 N 223.99 W 55£77t.~9 60~4736.99 61.30 N 269.77 ~ 551725.35 6014747.04 72.47 N 320.00 W 551675.05 60~4758.06 84.82 N 374.53 W 551620.43 6014770.03 TOOb PACE HS 3.00 ~S 3.00 Hg 3.00 RS 3.00 NS 3.00 END 3/~00 BUILD BUZ/.D 3/L00 ~A$8 PERMAFROST END 3/300 BURL/) TOP UGNU TOP M .qIU4DS TARGET TOp SC'm~.ADER NCl~ 1824.00 36.22 282.76 3742.81 L678.]1 398.07 1884.00 36.22 282.76 L79].22 1726.52 433.53 1900.00 36.70 282.76 1804.06 1739.38 443.03 L944.82 38.04 282.76 1839.70 L775.00 470.24 2000.00 39.70 282.76 1882.66 1817.96 504.87 2~00.00 42,70 282.76 1957.89 L893.19 570.93 2200.00 45.70 282.76 2029.58 1964.80 640.44 2300.00 48.70 282.76 2097.51 2032.8L 7L3.80 2400.00 51,70 282.76 2161.52 2096.82 790.62 2500.00 54.?0 282.76 222~.41 2156.71 870.69 2600.00 57.70 282.76 2277.03 2212.33 953.78 2700.00 60.70 282.76 2328.23 2263.53 L039.66 2800.00 63.70 282.76 2374.87 2330.17 1128.~1 2827.46 64.52 282.76 2386.86 2322.16 ~152.8~ 4996.17 64.52 282.76 3339.70 3255.00 3110.65 5540.19 64.52 282.76 3553.70 3489.00 3601.77 6126.05 64.52 292.76 3805.70 3741.00 4L30.66 6126.05 64,52 282.76 3805.70 3743.00 4130.66 6195.79 64.52 282.76 3835.70 377%.00 4193.62 6277.~6 64.52 282,76 3870.70 3806,00 4267.08 87.93 N 380.24 W 551606.70 60~4773.0~ RS 3.00 95.76 N 422.82 W 55L572.07 6OL4780.63 HS 0.00 97.86 N 432.09 W 553562,79 6014782.66 HS 3.00 103.87 N 458,62 W 551536.22 60~4780.48 HS 3.00 111.52 N 492.40 W 55L502.39 60~4795,90 HS 3.00 126.06 N 556.63 W 551438.07 6014810.00 RS 3.00 ~41.46 N 624.62 W 551369.98 6014824,92 H$ 3.00 Z57.67 N 696.Z7 W 55~298.32 6014840.62 174.63 ~ 77].09 W 55Z223.29 6014857.06 ~S 3.00 192.32 N 849.18 W 551145.09 6014874,20 HS 3.00 210.67 N 930.22 W 55/063.94 60~4891.99 HS 3.00 229.64 N 1013.98 W 550980.05 6014930,37 H~ 3.00 249.18 N ~100.25 W 550893,66 6014929.30 MS 3.00 254.64 N 1~24.34 W 550869.53 60L4934.59 H$ 3.00 687.09 N 3033.82 W. S48957.27 6015353.67 H~ 0.0O 795.56 N 35~2.80 W 548477.58 60L5458.79 HS 0.00 912.39 N 4028.63 W '547961.00 60~5572.00 H~ 0.00 9~2.39 N '4028.63 W 54796~.00 6015572.00 HS 0.00 926.29 N 4090.0~ W 547899.50 6015585.~8 Hg 0,0O 942.52 N 4161.69 ~ 547827.75 6015601.20 HS 0.00 NE OA OB 632L.33 64.52 282.76 3889.70 3825.00 4306.96 6523.60 64.52 282.76 3976.70 3912.00 4489.55 6679.36 64.52 282.76 4043.70 3979.00 4630.17 951.33 N 4200.58 W 547788.8~ 6015609.74 H3 0.00 991.66 N 4378.66!W 5476~0.§6 6015648.82 BS 0.00 1022.72 N 45~5.81 W 547473.32 60L5678.91 HS 0,00 (A~adrJll (c) 97 MPJlTP5 3.0C !0:22 AM P) BASE SCHRADER MEASURED INC~ DRPTR A~GL~ 6730o51 64.52 6930.51 64.52 04 NOV 1997 Page 3 ~o~ ?' ' .?$?Li i~ .................................................................................. .......... TD DIRECTIO~ UB~T£CAL-DEPTHS SHCTIO~ AZ £M1]T~ T~D SUB - SEA D~PART 282.76 4065.70 4001.00 4676.34 282.76 %151.75 4087.03 4856.90 GOORDINATH$-PROM AI.~SKA Zone 4 TOOL DL/ ~LLII/~AD X Y FACB 10 O ]032.92 N 4S60.94 ~ 547428.02 60~S688.80 ~ 0.00 ID72.80 N 4736.9] W 547251.67 60~$727.45 O.0D <~ Z (Anadril][ (c) 97 MPJ17P5 3.0C L0:22 A~ P) §~A~D' gE.R~] I CE_S OR ILL I NG .... [ , , ,, , mn . ~. L.-';'-"7'.-~Z ';-.'~ .... .; .l ....................... i ~ iiiii il i iiii ii iii Anadr~ 11 Schlumberger MPJ-17 [P.4) VERTICAL SECTION VIEW ii ! ANAD~IU. AKA-DPCi S~ction at: 282.76 ....'...,., { PL, kN , ~F:;;~;Ti i~i~;: soo ~ ]Dep'Sca]e.: ! inch BO0 feet ~ , NO~' AP :'RD'CED FOR ~ -" '~ ' · ' c.,X.E'CUTiON' I [BPa,n......: 04 Nov I ':' ~=P-':'~ *~ 'I~g ~rker Identification MD BK8 SECTN INCL ........ ~ ........ ~ A) KB O' 0 0 0.0 B) K~/BU]LD l/iOn 300 300 -0 0,0 ~ . ~. C) BUILD ~,5/]00 400 400 t J,O} ..... DI BUILa 2/100 , 600 600 . E). BUILD 2,5/100 900 897 _ _ ~, F) .BUILD 3/JOO' ~200 !J89 117 17.5 .......... G) END 3/~00 BUILD J'a24' J743 398 36.2 .~~ H) BUILD,3/IO0 tBS4, t79} 434 36.2 ', .' I) END 3/tO0 ~ILD 2827 ' ~387 [t53 64.5 .. . .. ~A~~ N~F'~ J) TARGEI 6~26' 3806 4131 64 : . , '. '. ~ ' . , , : , ',, " .... , . · ...... ~ ~ . ~' . . I , .... ' I~ , ' I' I ' _ , ....... i .. . , . , ' , .~ K ., , .... 0 400 800 ~200, 1600 2000 2400 2800 3200 3~0 4000 4400 4800 5200 5600 6000 6400 6800 Section Departure fA~dri)] [cJ97 NP¢ll~ 3.OC !0:Z2 ~ P) '1_........ - H- RED ,sERvIcES DRILLING L IIllI II I · I I II III I I I ' ...... ' ' ' ' ' .. ' ............... '-'-:':':':':' "":::" ...... ' ......................... · - ;-,o, ,,.~,' xu~l~C]T]~a~:¥Ofl ..... MD .....~B S'ECTN INCLN ~nadri l l Schlumberger -I MPJ-17 (P4) ~1 ~,~_~ ~ ~o~ ,~ ~.~ ~1~ ~' ~ ~ ~'~ VERIICAL SECTION VIEW Section et: 282,76 j Ajx! e-.j;,r~!.L A~i'D ]:i',ITVD Scale.: t ~nch: ]00 t. eet -?(-' IDea Scale.: t inch = tO0 feet ~ ~ , ._ . , ,. ~ ~ . ....... . , . . 4000 4050 4100 4150 4;:)0.0 4250 4300 4350 4400 4450 4500 4550 4600 4650 4700 4750 4800 4850 4900 Section Departure {4aadril] (c)97 I~dJ71:'5 3.0C !1):.23 ~ PI ' n~ i Ji i · _ Al KG 0 0 N 0 E sERVZcES D-RiLLIN6 --__ .................... ~..--..-..~.."__'Z.Z::'.--. --LL:-" -- ::Z ::% B) KOP/BUILD l/JO0 300 0 bi 0 C) BUILD 1.5/100 400 0 N ! §) BUILD 2/JOO 600 2 N 9 W E) BUILD 2.5/100 900 10 N 4§ W F) BUILD 3/100 i~O0 26 N i14 G) END 3/100 BULL/) 1824 BB N 388 N H) BUILO 3/i0O ~BB4 96 N .423 I) ENO 3/100 BUILD 28~7 255 N J124 W' J) TARGET 6126 9~2 N 40P9 W K) ltD 6931 1073 N 4737 N mil i iii ANADMLL · F.c/',,SIBfLFT'Y PLAN NOT APPROVED FOR 1 :XE~ ~ ~ tON '~ ~F... ...... ='::---:--: I '-~ T '%-: '~"' '-'~ '-' ~:~"" '~'~"-T '~% '-' "-?: ":-'C-~: "--' '-'- "-;"-'~'t'. _ - ............ -/ ....... ow. AKA-DPC" - -- m i mm nu i Anadr ~ ] ]- Sch/umbers/er I ......... :'-'%'T ...................... m ,m MPJ.-17 (P4) PLAN VlE~ J i i i mln ii I mi CLOSUFIE ' 4857 feet at Azimuth 282,76 DECLINATION.; +27.854 (E) SCALE ' ! inch: 600 feet DRAWN ' 04 Nov 1997 K ' larget (Radius 100 ~eet ) ' .. . .... , · ,, , ,~ . ,, , . · , ' I' 5100 4800 4500' 4200 3900 , 3600 3300 3000 2700 2400 2100 .' ~B,O0. 1500 1200 900 600 . 300. 0 300 . ' <. WEST · EAST -> ....... mm I I m mlllm iim i m mn , ,imm I I ! ~ ~ II I mi I II ' ~ MON J-1 NORTH + N ~6oo + -F -~ J-16 -~ J-17 -~ J-19 ~- J-20 · J-01 · J-11 · J-02 · d-08 · J-03 · J-lO · j-04 · J-06 · J-12 · d-09 · J-13 · J-05 · J-14 · J-07 600 -F .~ MON J-2 SOUTH -- r- i.~ + ~~, , VICINITY MAP N.T.S. I SURVEYOR'S CERTIFICATE g -~- N 600 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF SEPTEMBER 26, 1995. NOTES MPU J-PAD LEGEND -~ AS-BUILT CONDUCTOR 1. DATE OF SURVEY: SEPTEMBER 26, 199.5. 2. REFERENCE FIELD BOOK: MP95-19 (pgs. 52-36). .3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. 4. GEODETIC COORDINATES ARE NAD 1927. 5. PAD SCALE FACTOR IS 0.9999031. 6. HORIZONTAL/VERTICAL CONTROL IS BASED ON MONUMENTS J-1 AND J-2. 7. ELEVATIONS ARE BASED ON MILNE POINT DATUM M.S.L. · EXISTING WELL LOCATED WITHIN PROTRACTED SECTION 28, T. 15 N., R. 10 E., UMIAT MERIDIAN ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV.! OFFSETS Y= 6,014,714.85 N= 970.08 70'27'05.592" 70.4509422' 2,517' FSL J-16 X= 551,984.58 E= 1,024.83 149',34'53.101" 149.5758614' 35.2' 5,536' FEL Y=6,014,687.85 N= 940.54 70'27'O5.125" 70.4508681' 2,290' FSLi J-17 iX= 551,996.51 E= 1,024.92 149'54'52.756" 149.5757655' 35.2' 5,324' FEL Y=6,014,652.23 N= 880.00 70'27'02.577" 70.4507158' 2,234' FSL d-19 X= 552,020.45 E= 1,024.54 149'54'32.064" 149.5755753' 35.0' 3,501' FEL Y=6,014,605.30 N= 850.20 70'27'02.511" 70.4506419' 2,207' FSL J-20 X= 552,053.21 E= 1,025.43 149'34'.31.695" 149.5754708' 55.1' 5,288' FEL )RAWN: BARNHART t"o-I o ~ ORIGINAL AS-~3UILT ISSUE RE.SION BY CHK~ CNECK£O: FERAUDO DATE: 10/1/9.5 )RA~ING: MPU-J-AB SCALE: 1 "=200' BP EXPLORATION MILNE POINT UNIT J PAD CONDUCTOR AS-BUILT WELLS J-16, J-17, J-19 &: J-20 · WELL PERMIT CHECKLIST COMPANY FIELD & POOL , ~ ~/~ INIT CLASS ADMINISTRATION WELL NAME ,,~/¢ ¢7'"., //7./ GEOL AREA ENGINEERING A~~ DAT.E 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ,~, N Y 14. Conductor string provided ................... (,,~N 15. Surface casing protects all known USDWs ........... (~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ N 18. CMT will cover all known productive horizons .......... N 19. Casing designs adequate for C, T, B & permafrost ....... I~N 20. Adequate tankage or reserve pit ................. C~N 21. If a re-drill, has a 10-403 for abandonment been approved... Y,, N 22. Adequate wellbore separation proposed ............. ~.~ N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... (~)N 25. BOPEs, do they meet regulation ..... -- . . 26. BOPE press rating appropriate; test to Psig' 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y PROGRAM: exp [] dev [] redrll [] serv/BI, wellbore seg E; ann. disposal para req [] ~2¢'~,:~ UNIT# /./ ~ ~-~/ ON/OFF SHORE REMARKS GEOLOGY APPR D T - 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for we,eklyjorogress reDo, rts /Y N lexploratory omyj ...... ~" GEOLOGY: ENGINEERING: COMMISSION: JDH r~ RNC '-'" CO Comments/Instructions: HOW/lit - A:\FORMS\cheklist rev 09/97 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 Fri Mar 27 14:04:11 1998 Reel Header Service name ............. LISTPE Date ..................... 98/03/27 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/03/27. Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: APl NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MM-80007 A. PIEPER R. JAYE MPJ-17 500292282800 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 27-MAR-98 28 13N 10E .00 64.30 35.20 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 8.500 6725.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBES, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 ( EWR4 ), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). 4. ALL MWD RUNS REPRESENT MPJ-17 WITH API# 50-029-22828-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6725'MD, 4204'TVD. SROP= SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC= SMOOTHED GAMMA RAY COMBINED. SEXP= SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP= SMOOTHED PAHSE 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 FOR RESISTIVITY SENSOR. SPSF= SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX FIXED HOLE SIZE) SNNA= SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA= SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC= SMOOTHED BULK DENSITY-COMPENSATED. SCOR= SMOOTHED STANDOFF CORRECTION. SNPE= SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR LO~ PROCESSING: HOLE SIZE: 8.5" MUD FILTRATE SALINITY: 1000 PPM. MUD WEIGHT: 9.1 PPG. FORMATION WATER SALINITY: 14545 PPM. FLUID DENSITY: 1.00 G/CC. MATRIX DENSITY: 2.65 G/CC. LITHOLOGY: SANDSTONE. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NI/MBER: DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH FCNT 2449.0 NCNT 2449.0 NPHI 2449.0 FET 2471.5 RPD 2471.5 RPM 2471.5 RPS 2471.5 RPX 2471.5 PEF 2484.0 DRHO 2484.0 RHOB 2484.0 GR 2493.0 ROP 2553.5 $ BASELINE CURVE FOR SHIFTS: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 2449.0 4728.0 4737.0 4778.0 4837.0 4868.5 4878.5 4895.0 4900.5 4905.0 4942.5 4962.0 4978.0 5022.0 5032.5 5052.5 5059.5 5108.0 5237.5 5242.5 5315.5 5340.5 5359.0 5376.5 5502.0 5509.0 5556.0 5668.0 5735.0 5741.0 5819.5 5828.0 5888.0 5908.0 5911.5 6057.0 GR 2454.0 4733 0 4742 0 4783 5 4841 5 4873 0 4883 0 4898 5 4906 0 4910 0 4948.5 4965.5 4982.5 5026.5 5034.5 5055.5 5062.5 5113.0 5240 5 5245 5 5321 0 5345 0 5363 5 5381 5 5503 5 5510 0 5557 0 5671.0 5737.5 5743.5 5823.0 5831.0 5889.5 5910.5 5913.5 6061.5 STOP DEPTH 6615.5 6615.5 6615.5 6641.5 6641.5 6641.5 6641.5 6641 5 6650 0 6650 0 6650 0 6661 5 6723 5 EQUIVALENT UNSHIFTED DEPTH 6059.5 6063.5 6068.5 6072.5 6127.0 6128.5 6189.5 6191.5 6200.0 6199.0 6209.5 6208.0 6223.5 6224.0 6230.5 6228.5 6237.5 6236.0 6249.0 6254.0 6251.5 6257.5 6332.5 6333.0 6340.0 6340.5 6379.5 6380.5 6427.5 6428.0 6430.5 6431.0 6481.5 6483.0 6723.5 6725.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 2561.0 6725.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHM~ 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHM~ 4 1 68 FET MWD HOUR 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean DEPT 2449 6723.5 4586.25 Nsam 8550 First Reading 2449 Last Reading 6723.5 ROP 7.7918 1488.28 245.191 8341 GR 12.894 114.934 58.6333 8338 RPX 1.5762 115.127 12.7217 8341 RPS 0.5308 2000 13.6263 8341 RPM 0.1787 2000 13.9637 8341 RPD 0.2375 2000 14.6008 8341 FET 0.2142 8.9768 1.05993 8341 RHOB 1.1944 2.8818 2.09621 8333 DRHO -0.183 0.6401 0.0835417 8333 PEF 1.0236 6.1417 2.14129 8333 NPHI 17.069 76.5744 44.4494 8334 NCNT 2008 3609.32 2569.9 8334 FCNT 402 959.676 550.669 8334 2553.5 2493 2471.5 2471.5 2471.5 2471.5 2471.5 2484 2484 2484 2449 2449 2449 6723 5 6661 5 6641 5 6641 5 6641 5 6641 5 6641 5 6650 6650 6650 6615.5 6615.5 6615.5 First Reading For Entire File.' ......... 2449 Last Reading For Entire File ........... 6723.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/27 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 ....... 98/03/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI FET RPD RPM RPS RPX PEF DRHO 2 .5000 START DEPTH 2454 0 2454 0 2454 0 2476 5 2476 5 2476 5 2476 5 2476 5 2489 0 2489 0 STOP DEPTH 6617.0 6617.0 6617.0 6643.0 6643.0 6643.0 6643.0 6643.0 6651.5 6651.5 RHOB 2489.0 GR 2498.0 ROP 2558.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 6651.5 6663.0 6725.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED .TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 15-NOV-97 5.07 5.46 MEMORY 6725.0 2561.0 6725.0 48.6 67.8 TOOL NUMBER P0887CRLGM6 P0887CRLGM6 P0887CRLGM6 P0887CRLGM6 8.500 8.5 SPUD / LSND 9.00 74.0 9.0 1000 6.0 3.000 2.580 3.000 4.500 28.6 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD 2 FT/H 4 1 68 GR MWD 2 AAPI 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHI~M 4 1 68 FET MWD 2 HOUR 4 1 68 NPHI MWD 2 P.U. 4 1 68 NCNT MWD 2 CNTS 4 1 68 FCNT MWD 2 CNTS 4 1 68 RHOB MWD 2 G/CC 4 1 68 DRHO MWD 2 G/CC 4 1 68 PEF MWD 2 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean DEPT 2454 6725 4589.5 ROP 7.7918 1488.28 245.23 GR 12.894 114.934 58.6458 RPX 1.5762 115.127 12.6749 RPS 0.5308 2000 13.5697 RPM 0.1787 2000 13.8966 RPD 0.2375 2000 14.5331 FET 0.2142 8.9768 1.05838 NPHI 17.069 76.5744 44.4317 NCNT 2008 3609.32 2570.58 FCNT 402 979 550.886 RHOB 1.1944 2.8818 2.09681 DRHO -0.183 0.6401 0.0836088 PEF 1.0236 6.1417 2.14203 Nsam 8543 8334 8331 8334 8334 8334 8334 8334 8327 8327 8327 8326 8326 8326 First Reading 2454 2558.5 2498 2476.5 2476.5 2476.5 2476.5 2476.5 2454 2454 2454 2489 2489 2489 Last Reading 6725 6725 6663 6643 6643 6643 6643 6643 6617 6617 6617 6651.5 6651.5 6651.5 First Reading For Entire File .......... 2454 Last Reading For Entire File ........... 6725 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ....... · .... 1.0.0 Date of Generation ....... 98/03/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE ~I~ SIq ~0 puz ZOZ T~OTsZqd