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202-114
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/1/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240501 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# HV B-13 50231200320000 207151 4/10/2024 YELLOW JACKET GPT-PERF KU 13-06A 50133207160000 223112 3/27/2024 YELLOW JACKET GPT-PERF KU 13-06A 50133207160000 223112 4/1/2024 YELLOW JACKET GPT-PLUG-PERF KU 13-06A 50133207160000 223112 3/22/2024 YELLOW JACKET GPT-PERF KU 33-08 50133207180000 224008 4/30/2024 YELLOW JACKET SCBL KU 41-08 50133207170000 224005 4/23/2024 YELLOW JACKET SCBL KU 41-08 50133207170000 224005 4/11/2024 AK E-LINE GPT/Perf/CIBP MPU F-30A 50029226230100 213188 4/12/2024 READ CaliperSurvey MPU S-13 50029230930000 202114 4/16/2024 READ Caliper Survey NCI A-17 50883201880000 223031 3/22/2024 AK E-LINE Perf Paxton 6 50133207070000 222054 4/14/2024 AK E-LINE GPT/Perf PBU PTM P1-13 50029223720000 193074 4/8/2024 YELLOW JACKET CBL SRU 232-15 50133207140000 223091 3/28/2024 YELLOW JACKET GPT-PLUG-PERF SRU 232-15 50133207140000 223091 4/22/2024 YELLOW JACKET PLUG-PERF SRU 241-33B 50133206960000 221053 4/12/2024 YELLOW JACKET GPT-PERF SRU 241-33B 50133206960000 221053 4/4/2024 YELLOW JACKET GPT-PERF Please include current contact information if different from above. T38745 T38746 T38746 T38746 T38747 T38748 T38748 T38749 T38750 T38751 T38752 T38753 T38754 T38754 T38755 T38755 MPU S-13 50029230930000 202114 4/16/2024 READ Caliper Survey Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.05.13 09:32:35 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC S-13 MILNE PT UNIT S-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/22/2025 S-13 50-029-23093-00-00 202-114-0 W SPT 4166 2021140 1500 871 871 871 870 OTHER P Austin McLeod 3/30/2025 Two year. No AIO. Monobore. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT S-13 Inspection Date: Tubing OA Packer Depth 1028 1790 1741 1729IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250330181229 BBL Pumped:0.6 BBL Returned:0.6 Tuesday, April 22, 2025 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 999 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.04.22 16:16:42 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC S-13 MILNE PT UNIT S-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/22/2025 S-13 50-029-23093-00-00 202-114-0 W SPT 4166 2021140 1500 871 871 871 870 OTHER P Austin McLeod 3/30/2025 Two year. No AIO. Monobore. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT S-13 Inspection Date: Tubing OA Packer Depth 1028 1790 1741 1729IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250330181229 BBL Pumped:0.6 BBL Returned:0.6 Tuesday, April 22, 2025 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 999 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.04.22 16:16:42 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC S-13 MILNE PT UNIT S-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/26/2023 S-13 50-029-23093-00-00 202-114-0 W SPT 4166 2021140 1500 916 918 921 922 OTHER P Austin McLeod 3/19/2023 Two year. No AIO. Monobore. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT S-13 Inspection Date: Tubing OA Packer Depth 251 1713 1645 1635IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230320093326 BBL Pumped:0.9 BBL Returned:1 Wednesday, April 26, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 Two year. James B. Regg Digitally signed by James B. Regg Date: 2023.04.26 13:12:05 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg n 4DATE: Wednesday, March 17, 2021 ,{ LIf'' P.L Supervisor `Q'rt 1' IZ{) Z,I SUBJECT: Mechanical Integrity Tests 1 Hilcorp Atoka, LLC S-13 FROM: Brian Bixby MILNE PT UNIT S-13 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Sup" J L NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT S-]3 Insp Num: mitBDB210314152528 Rel Insp Num: API Well Number 50-029-23093-00-00 Permit Number: 202-114-0 Inspector Name: Brian Bixby Inspection Date: 3/14/2021. Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well s-13 Type Inj w TVD 4166 - Tubing 1000 toot - 1000 999 PTD 2021140 Type Test sPTTest psi tsoo IA us3— zozo 2003 en=� BBL Pumped: 0.3 BBL Returned: 0.3 OA Interval OTHER P/F P - Notes: Dual String Monobore Injector. 2 year cycle. Long String pretest 755psi, initial 755psi, 15 min. 756psi, 30 min. 755psi Wednesday, March 17, 2021 Page I of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 01 2019 REPORT OF SUNDRY WELL OPERATIONS A d %A'1.A 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing io n Li Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ Other: MBE Treatment ❑� 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Stratigraphic❑ Exploratory ❑ Service ❑v 202-114 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-23093-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0380109 MILNE PT UNIT S-13 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth measured 4,957 feet Plugs measured N/A feet true vertical 4,575 feet Junk measured 4,855' feet Effective Depth measured 4,857 feet Packer measured 4,525 & 4,603 feet true vertical 4,480 feet true vertical 4,167 & 4,240 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" x 34" 112' 112' N/A N/A Production 4949• 7" 4,949' 4,567' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feel SS 2-3/8" 4.6# / L-80 / IBT 4,554' 4,194' Tubing (size, grade, measured and true vertical depth) LS 2-3/8" 4.6# / L-80 / IBT 4,623' 4,259' 7" x 2-3/8" GT Ret. Dual Packers and SSSV (type, measured and true vertical depth) Baker FH N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 0 0 0 0 Subsequent to operation: 1 0 0 565 0 873 14. Attachments (required per 20 AAc 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory 11 Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ E] WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-046 Chad Helgeson Authorized Name: Contact Name: Stan Porhol Authorized Title: Operations Manager Contact Email: _sporhola@hilcorp.COm Authorized Si nature: Date: 3/18/2019 Contact Phone: 777-8412 qi/ �/ iBDMS-4�APR 0 2 2019 Form 10-104 Revised 412017 Submit Original Only nf Orig. KB Elw. = 66.70' / Orig. GL Eley. = 38.60' RKB-Tbg Wrgr. =20.70' (Nabors N4ES) TD(MD)=4,957/ MMM)=4,575' PMMD) =4,865 / PBID(1VD) = 4,488' SCHEMATIC Milne Point Unit Well: MP S-13 Last Completed: 8/23/2002 PTD: 202-114 TREE & WELLHEAD Tree 2-1/16"- 5M DuaICIW Wellhead 11" x 2-3/8" SM FMC Dual w/2.375" EUE T&B Thread OA 4,572' 4,587' FMC Tubing Hanger 2.0" CIV/ "H" BPV Profile OPEN HOLE / CEMENT DETAIL 20" 260 sx Arcticset in a 42" Hole 7" 1,218 sx 10.7 ppg Perm'L'/ 356 sx CGs7/8"H WELL INCLINATION DETAIL KOP @ 480' Max hole angle = 32 deg. at 2,544' MD Hole angle thru perfs = 20 deg at 4,600' MD CASING DETAIL Size Type Wt/Grade/Conn ID Drift Top Btm BPF 20" Conductor 92/H-40/N/A19.124" 1 18.936" Surface 112' 0.3552 7" Production 26/L-80/BTC-MOD 1 6.276" 1 6.151" Surface 4,949' 0.0383 TUBING DETAIL 2-3/8" Tubing (Short) 4.6/L-80/IST 1.995" 1.901" Surf 4,554' 0.0039 2-3/8" Tubing(Long) 4.6/L-80/IET 1.995" 1.901" Surf 4,623' 0.0039 TUBING DETAIL No Top Depth I Item Size Date Status OA 4,572' 4,587' SHORT STRING A 2,171' HES 2-3/8"'X'Nipple B 4,494' HES 2-3/8"'X' Nipple C 4,528' Baker Model'GT' Retrievable Dual Packer 40K Shear D 4,542' 2-3/8"'XN' Nipple 1.791" No Go E 4,544' 2-3/8"WLEG— Bottom @4,554' LONG STRING 1 2,201' HES 2-3/8"'%'Nipple 2 4,491' HES 2-3/8"'X' Nipple 3 4,525' Baker Model 'GT' Retrievable Dual Packer 40K Shear 4 4,603' Baker FH Packer 40K ROT Release 5 4,620' 2-3/8"'XN' Nipple 1.791" No Go 6 4,623' Cut 2-3/8" (Chemical Cut) 7 4,855' Top of Fish (10' Long), 2-3/8" pup 8 4,860' Baker Model 'E' Hydro -Trip Sub 9 4,861' 2-3/8" WLEG — Bottom @ 4,865' PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status OA 4,572' 4,587' 1 4,210' 4,224' 15 6 3-3/8" 8/20/2002 Open OB 4,632' 4,647' 1 4,266' 4,281' 15 6 3-3/8" 8/20/2002 Open Ref Log: SCMT— 7/02/2002 — Perf Guns 3-318"/34B HJ II RDX 0.4" EH 6 spf 60 deg n GENERAL WELL INFO M API: 50-029-23093-00-00 Drilled & Cased by Doyon 141 — 6/22/2002 lr Initial Completion by Nabors 4ES-8/23/2002 Revised By: TDF 3/18/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number StartDate End Date MPS -13 Coil 50-029-23093-00-00 202-114 10/26/18 3/5/19 Daily Operations: 10/24/2018- Wednesday No activity to report. 10/25/2018 - Thursday No activity to report. 10/26/2018 - Friday MIRU CTU 6. Perform BOP testing, PT PCE 4,000psi, 300 psi low per sundry. Injectivity testing. 1.5 bpm at 910 psi. 2.0 spm at 1150 psi. Perform MBE treatment as per schedule including 10 bbls of HEC Gel, 15 bbls of 15.8 Acid soluable cement and 5 bbls of HEC gel. Squeezed into OA (short String) at about .5 bpm at 1,156psi final pressure. Via 1.5" CT. Daylights operation. Move to Long String. 10/27/2018 -Saturday RU to Long stsring. PT PCE. 205/ 4,000psi. Injectivity test 0 .3 at 940 psi. 0.6 at 1,150psi. Lower than expected. RIH with 1.5" CT. Sat down hard at 4630just above the perfs. Could notjet by obstruction. POH to change to jetting nozzle. Attempt to work past obstruction. Still sitting down hard. Was decided to forgo MBE at this time. Blow down CT. Release to change out to 2" CT. Secure well. 10/28/2018 -Sunday No activity to report. 10/29/2018 - Monday No activity to report. 10/30/2018 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPS -13 Coil 50-029-23093-00-00 202-114 10/26/18 3/5/19 Daily Operations. 2/27/2019 - Wednesday No activity to report. 2/28/2019 - Thursday No activity to report. 3/1/2019 - Friday No activity to report. 3/2/2019 -Saturday No activity to report. 3/3/2019 -Sunday MIRU SLB CYU 6. RU to Short String MU Quadco tools including 1.5 CTC, 1.7" MHA, 1.7" Jar, 1.7 Titan Motor, 1.75 Junk mill. PT PCE and CT, Low 320psi, High 3,920psi. RIH with Motor and Mill. Well pressure up. Open choke to take returns. Start pumping at min rate on way in hole. Weight checks show pulling heavy at ,4000 wt is 19,000#. Order out 75 deg slick water. Wait on water. Water on location. RIH to start milling. Tag top of cement at 4,564'. Begin milling. Saw motor work. Milled off nicely. Mill to 4,572. Motor starting to stall hard. No mill off. Stalled 8 times at 4,573'. Ended milling operation. POH. FP top of well. Injectivity test. Pressure up to 890psi. Fell to 770psi in 10 minutes. Secure well for the night. 3/4/2019 - Monday SLB CTU 6. crew on location SLB crew change flange to line up with long string. RU to Long String. MU Quadco tools including 1.5 CTC, 1.7" MHA, 1.7" Jar, 1.7 Titan Motor, 1.75 Junk mill. PT PCE and CT. Low 380psi, High 4,020psi. test checks. RIH. RIH to dry tag top of obstruction at 4,642' CTM. Back on line with pump. RIH with mill turning. Stall 1 at 4,644'. pulled weight. Released at 4,639'. Mill down to 4,658.1'. Saw good motor work.and drill off. POH chasing cuttings. Pump 2 bottoms up. Stop for injectivity test. Pressure up to 900psi. Pressure dropped to 682 in 10 minutes. POH. FP top of well. Secure well for night. 3/5/2019 -Tuesday SLB CTU 6. crew on location SLB crew change flange to line up with long string..RU to Long String. MU Tools. 1.5 CTC roll on, checks, 1.5" stinger, 1.5 JSN. Fluid pack pipe PT PCE and CT. Low 250psi, High 4,080psi. LRS on location. Acid enroute. Open Swab, SSV. RIH with BH. Tag at 4,647'. Not as deep as milled yesterday. pick back up and drop back down to see if can go deeper. Safetty meeting. SD slick circulation. PT LRS line. Pt low/ high 350/4,000psi. Start pumping 15% hcl down CT.4 bbls acid away. Switch to M/W chase flush. Density 8.82PPG. Displace with slick Kcl water. Lay in HCL from 4,646. Pressure up to 500psi. Broke back. Lay in acid tuntil all out pipe. POH. FP CT. INjectivity tesd down tubing . 750psi at .75 bpm. Secure well (long String). Begin change over flange to long string. Prep for short string. LRS on way back to location. Extra Slick on location. Prep to peessure test. Fluid pack CT. Pressure test PCE Low/ High: 237/ 4,050psi. RIH into Short String with 1.5" CTC, 1.5" Check valve, S' stinger, 1.5" JSN. Tag bottom at 4,572'. Line up LRS to pump HCI into CT. Pump 5.5 bbls of 15% HCL down tubing. Displace with KCL water. Lay in acid from 4,572'. PUH holding pressure at 500psi. Pressure broke with 2.5 bbls of acid out nozzle. Continue lay in HCL. POH while FP CT. ON Surface. Pump Injectivity test from surface. Average injection 787psi at .7 bpm. Rack back. Secure well for the night. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg Op,� 3 2Lr�� ( DATE: Friday, March 22, 2019 P.I. Supervisor Zjy ` SUBJECT: Mechanical Integrity Tests ((((( HILCORP ALASKA LLC S-13 FROM: Lou LaubenStem MILNE PT UNIT S-13 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry fez— NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT S-13 API Well Number 50-029-23093-00-00 Inspector Name: Lou Laubenstein IBSp Num: mi[LOLI90316160122 Permit Number: 202-114-0 Inspection Date: 3/16/2019 Rel Insp Num: Packer Depth Well s-13 'Type Inj u'' TVD 4166 PTD E2021140E,3TypeTest sPT Test psi Isco BBL Pum1 BBL Returned: Interval) OTHER P/F P Notes: Dual string monobore (no OA). 2 year interval. ' Pretest Initial 15 Min 30 Min 45 Min 60 Min ubing793 796 - 765 - —7P IA IA 545 1648 1615 161? OA Friday, March 22, 2019 Page I of 1 THE STATE 01ALASKA GOVERNOR BILL WALKER Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU S-13 Permit to Drill Number: 202-114 Sundry Number: 318-446 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.claska.gov Enclosed is the approved application for the 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, Hollis S. French Chair k� DATED this a day of October, 2018. RBDM I OCT 10 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 r'4' 'ECEDV (`CT 7 3 2�9 /019a- 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ ✓ - Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MBE Treatment El - 2. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ Slratigraphic ❑ Service Q • 202-114 - 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23093-00-00• 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? xeN Yes ❑ No Q MILNE PT UNIT S-13 ' 9. Property Designation (Lease Number): 10 ✓ 10. Field/Pool(s): ADL02W27' / )9' MILNE POINT/ SCHRADER BLUFF OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 4,957' 4,575' 4,857' 4,480' 980 N/A 4,855' (Fish) Casing Length Size MD TVD Burst Collapse Conductor 112' 20" x 34" 112' 112' N/A N/A Production 4,949' 7" 4,949' 4,567' 7,240psi 5,410psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing SS 2-3/8" 4.6# / L-80 /IBT 4,554' See Schematic See! LS 2-3/8" 4.6# / L-80 / IBT 4,623' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7" x 2-3/8" GT Ret. Dual & Baker FH and N/A 4,525 MD/4,167 TVD & 4,603 MD/ 4,240 TVD and N/A 12. Attachments: Proposal Summary Ld Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory ❑ Slratigraphic ❑ Development ❑ Service E 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/10/2018 OIL ❑ WINJ ❑� . WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. [�Q -3 Authorized Name: Bo York Contact Name: Stan Porhola ' Authorized Title: Operati an ger Contact Email: sporholaicDhilcorp.com Contact Phone: 777-8412 Authorized Signature: E.ri ao V.Av-Date: 10/2/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Exception Required? No Subsequent Form Required: d ' —1 0 �1 Spacing Yes El APPROVED BY Approved by: COMMISSIONER THE COMMISSfON Date: / �� > /� ORIGINAL RBDMS1 OCT 10 2018 Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Xx//; ti, Y�A K Hilcurp Alaska, LU Well Prognosis Well: MPU 5-13 Date: 10/02/2018 Well Name: MPU S-13SS/LS API Number: 50-029-23093-00 Current Status: Water Injector Pad: Milne Point S -Pad Estimated Start Date: Oct 10, 2018 Rig: N/A Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-114 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907) 444-2881 (M) AFE Number: Job Type: MBE Treatment S-13SS (SHORT STRING) Current Bottom Hole Pressure: 1,380 psi @ 4,000' TVD (SBHPS 3/14/2007 / 6.64 ppg EMW) Maximum Expected BHP: 1,380 psi @ 4,000' TVD (No new perfs being added, EMW = 6.64 ppg) MPSP: 980 psi (0.1 psi/ft gas gradient) S-13LS (LONG STRING) Current Bottom Hole Pressure: 1,380 psi @ 4,000' TVD (SBHPS 3/14/2007 / 6.64 ppg EMW) Maximum Expected BHP: 1,380 psi @ 4,000' TVD (No new perfs being added, EMW = 6.64 ppg) MPSP: 980 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU 5-13 was drilled with Doyon #141 in 2002 as a deviated injector in the Schrader Bluff OA, and OB sands. The well was initially completed as a dual string injector using Nabors 4ES in August 2002. The well provides support in hydraulic unit 10 for the OA sand (Short -string) and the OB sand (Long -string) for offset producer MPU 5-23 (PTD 202-114). An MBE treatment was attempted with a Pumping Unit and Little Red in late 2107 with lower than expected results. Notes Regarding Wellbore Condition • Dual String Injector (Short -string = OA sand; Long -string = OB sand). • Well is a deviated dual -string water injector (max hole angle 32.0° @ 2,544'). • Last MIT -IA to 1,600 psi on 2/19/2016. • Shut-in water injection due to diagnosed MBE (Matrix Bypass Event). • Confirmed MBE between MPU 5-23 (Jet Pump Oil Producer) based on dye tests in the OA and OB sands. Objective: The purpose of this work/sundry is to utilize Coil Tubing to pump MBE treatments (at the perforations on the Long String [OB sand] and the Short String [OA sand]) and place the well back on water injection for both strings. Brief Procedure: Pumping Procedure (STEPS #1430 to be completed for both Long & Short Strings): 1. Production to SI offset producers up to 5 days prior to treatment (5-23). 2. Production to SI offset injectors up to 2 days prior to treatment (5-15, 5-26, S -33A). H Hileprp M.A., LG Well Prognosis Well: MPU 5-13 Date:10/02/2018 3. MIRU Coil Tubing Unit and Cement Pumping Unit. PT lines to 3,500 psi. [TREATMENT#1] a. Setup fluid manifold to allowing switching over from Cement Unit to Coil Unit. b. Pressure test BOPE to 3.500 psi Hi 250 psi Low. 5 min each test. i. Test using 60/40 methanol or 8.5 ppg seawater. ii. Each subsequent test of the lubricator will be to 3.500 psi Hi 250 psi Low to confirm no leaks. 4. RIH w/ 1.5" Coil to the top of the OA sand at 4,572' (SS perf) or OB sand at 4,632' (LS perf). 5. Displace the coil x tubing annulus to diesel. Estimated volumes is 8 bbl. 6. Perform injectivity test w/ 8.5 ppg freshwater. a. Inject at 2.0 bpm or a max 1,000 psi for injectivity test. Do not exceed 1,250 psi. 7. Mix and bullhead the following fluids with the Cementing Unit down the 1.5" coil string: rbd .+/-10 bbl of 100 ppt HEC (hydroxy ethyl cellulose) lead spacer pill. . +/-15 bbl of 15.8 ppg acid soluble cement. .+/- 5 bbl of 100 ppt HEC (hydroxy ethyl cellulose) tail spacer pill. . Drop foam ball. Chase w/ sufficient amount of diesel to fill coil string. 8. Mix and bullhead the following fluids with the Coil Tubing Unit down the 1.5" coil while POOH: a. +/-10.0 bbl of diesel (freeze protection to be left in the tubing). i. Volumes above will over -displace cement into formation by 1.0 bbl. ii. Injection pressure maybe increased to prevent leaving cement in tubing. 9. SD Pumps. Monitor wellhead pressures for 15 min (T/I/0). 10. RDMO Cement Pumping Unit and Coil Tubing Unit. 11. WOC 48 hours. 12. MIRU Pumping Unit. PT lines to 3,500 psi. [INJECTIVITY TEST #11 13. Mix and bullhead the following fluids: a. +/- 5 bbl of diesel (to ensure injectivity). b. +/- 10 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). C. ***Contingency*** If unable to establish injectivity. L Increase injection pressure, do not exceed 1,250 psi. d. +/- 10 bbl of diesel (freeze protection; after stable injection achieved). 14. Contingency: If residual cement exists (injectivity is below 0.15 bpm): a. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg seawater. b. Pressure test BOPE to 3,500 psi Hi 250 psi Low, 5 min each test. L Test using 60/40 methanol or 8.5 ppg seawater. ii. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 psi Low to confirm no leaks. ,t,K c. RIH w/ 1.50" coil w/ 1.50" wash nozzle to cement top. Circulate well w/ 8.5 ppg seawater. y d. Continue to RIH and cleanout cement to +/- 4,544' MD (SS-Tbg Tail) or+/- 4,623' MD (LS-Tbg Tail). y e. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 15. Contingency: If unable to cleanout cement w/ wash nozzle. a. RIH w/ 1.75" OD mill, 1-11/16" motor, and oil jars and cleanout cement to +/- 4,544' MD (SS-Tbg L Tail) or+/- 4,623' MD (LS-Tbg Tail). b. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 16. Contingency: If able to cleanout cement but unable to establish injectivity. a. RIH w/ 1.75" wash nozzle to +/- 4,544' MD (SS-Tbg Tail) or+/- 4,623' MD (LS-Tbg Tail). b. RU acid pumping unit. RU lines to pump down coil tubing. PT lines to 3,500 psi. c. Mix and pump 5-10 bbl of 15% HCI acid. Spot across from perfs and jet perfs. Displace acid w/ 8.5 ppg seawater. POOH. d. RD acid pumping unit. RU return lines to acid returns tank. e. Wait on acid minimum 4 hours (to dissolve calcium carbonate based cement). H I ilcorl, Alaska. LU Well Prognosis Well: MPU 5-13 Date: 10/02/2018 f. Circulate acid out of well pumping 8.5 ppg seawater. g. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 17. Contingency: If unable to establish injectivity test after HCI soak, repeat Step #16[a -g]. 18. MIRU Cement Pumping Unit. PT lines to 3,500 psi. [TREATMENT #2] 19. PT lines to 3,500 psi. 20. RIH w/ 1.5" Coil to the top of the OA sand at 4,572' (SS perf) or OB sand at 4,632' (LS perf). 21. Fluid -pack and maintain tubing pressure on offset wells affected by MBE (5-23). 22. Displace the coil x tubing annulus to diesel. Estimated volumes is 8 bbl. 23. Perform injectivity test w/ 8.5 ppg fresh water. a. Inject at 2.0 bpm or a max 1,000 psi for injectivity test. Do not exceed 1,250 psi. 24. Mix and bullhead the following fluids with the Cementing Unit down the 1.5" coil string: a. +/- 5 bbl of 100 ppt HEC (hydroxy ethyl cellulose) lead spacer pill. b. +/-10 bbl of 15.8 ppg acid soluble cement. c. +/- 5 bbl of 100 ppt HEC (hydroxy ethyl cellulose) tail spacer pill. d. Drop foam ball. Chase w/ sufficient amount of diesel to fill coil string. 25. Mix and bullhead the following fluids with the Coil Tubing Unit down the 1.5" coil while POOH: a. +/- 10.0 bbl of diesel (freeze protection to be left in the tubing). i. Volumes above will over -displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 26. Discontinue maintaining tubing pressure on offset wells affected by MBE (5-23). 27. SD Pumps. Monitor wellhead pressures for 15 min (T/I/0). 28. RDMO Cement Pumping Unit. 29. WOC 48 hours. 30. MIRU Pumping Unit. PT lines to 3,500 psi. [INJECTIVITY TEST #21 31. Mix and bullhead the following fluids: a. +/- 5 bbl of diesel (to ensure injectivity). b. +/-10 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). C. ***Contingency*** If unable to establish injectivity. L Increase injection pressure, do not exceed 1,250 psi. d. +/- 5 bbl of diesel (freeze protection; after stable injection achieved). 32. RDMO Coil Tubing Unit. 33. Turn well over to production. Attachments: 1. As -built Schematic 2. Coil BOPE Schematic 3. Fluid Flow Diagram - Acidizing 0 Hilcorp Alaake, LLC Orig. KB Elev. = 66.70'/ Orig. GL Elev. = 38.60' RKB!ft Hngr. = 20.70 (Nabors #4ES) 7 2 c 0. • 1_�, I_ C _ - 3 Mrf, u IR 1.791!'@4,542' i 41 r'MnimumlP- ,� I " 11.791" @ 4,620' DATubing 4,623' ELM , 5 7,. �9 _ � I TD(IVD)=4,957'/ TD(TVD)=4,575' PBTD(MD) =4,865' / PBTD(TVD) = 4,488' Milne Point Unit Well: MP S-13 SCHEMATIC Last Completed: 8/23/2002 PTD: 202-114 TREE & WELLHEAD Tree 2-1/16"- 5M Dual CIW Wt/Grade/Conn 11" x 2-3/8" 5M FMC Dual w/ 2.375" EUE T&B Thread Wellhead FMC Tubing Hanger 2.0" CIW "H" BPV Profile OPEN HOLE / CEMENT DETAIL 20" 260 sx Arcticset in a 42" Hole 7" 1,218 sx 10.7 ppg Perm 'L! / 356 sx Class'G' in a 9-7/8"Hole WELL INCLINATION DETAIL KOP @ 480' Max hole angle = 32 deg. at 2,544' MD Hole angle thru perfs = 20 deg at 4,600' MD CASING DETAIL Size Type Wt/Grade/Conn ID Drift Top Btm BPF 20" Conductor 92/H-40/N/A 19.124" 18.936" I Surface 1 112' 1 0.3552 7" Production 26/L-80/BTC-MOD 6.276" 6.151" 1 Surface 1 4,949' 1 0.0383 TUBING DETAIL 1/ AT TUBING DETAIL No Top Depth Item OA 4,572' 1 4,587' 4,210' SHORT STRING A 2,171' HES 2-3/8"'X'Nipple B 4,494' HES 2-3/8"'X'Nipple C 4,528' Baker Model 'GT' Retrievable Dual Packer 40K Shear D 4,542' 2-3/8"'XN' Nipple 1.791" No Go E 4,544' 2-3/8" WLEG - Bottom @ 4,554' LONG STRING 1 2,201' HES 2-3/8"'X'Nipple 2 4,491' HES 2-3/8"'X'Nipple 3 4,525' Baker Model 'Gr Retrievable Dual Packer 40K Shear 4 4,603' Baker FH Packer 40K ROT Release 5 4,620' 2-3/8"'XN' Nipple 1.791" No Go 6 4,623' Cut 2-3/8" (Chemical Cut) 7 4,855' Top of Fish (30' Long), 2-3/8" pup 8 4,860' Baker Model 'E' Hydro -Trip Sub 9 4,861' 2-3/8"WLEG- Bottom @4,865' PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status OA 4,572' 1 4,587' 4,210' 4,224' 15 6 3-3/8"8/20/2002 Open OB 4,632' 4,647' 4,266' 4,281' 15 6 3-3/8" 8/20/2002 Open Ref Log: SCMT - 7/02/2002 - Perf Guns 3-3/8" / 348 HJ II RDX 0.4" EH 6 spf 60 deg GENERAL WELL INFO API: 50-029-23093-00-00 Drilled &Cased by Doyon 141-6/22/2002 Initial Completion by Nabors 4ES-8/23/2002 Revised By: STP 9/26/2017 COIL BOPS MILNE POINT UNIT MPU 5-13 Rilrorp Alaska LLC 10/13/2017 9C MPU S-13 X 7 X 2%(Dual) Coil Tubing BOP Ja'e< 13(a Crossoverspool 4 1/16 10M X 4 1/16 5M Crossover spool 41/165M X 23/85M Valve, Swab, WKM-M, 2 3/8 5M FE (Long -String) Valve, Upper Master, Baker, 2 3/8 5M FE, w/ Hydraulic (Long -String) Valve, Lower Master, WKM-M, 2 3/8 5M FE (Long -String) Tubing Adapter, 11 x 7 x 2 3/8 dual 5M Lubricator to injection head Valve, Swab, WKM-M, 2 3/8 5M FE (Short -String) Valve, Upper Master, Baker, 2 3/8 SM FE, w/ Hydraulic (Short -String) Valve, Lower Master, WKM-M, 2 3/8 5M FE (Short -String) Coil Tubing Unit Fluid Flow Diagag ram Acidizing 400 BBL UPRIGHT We are now accepting payments online for case agreements and mining claims bills! 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Results - Case File Abstract Summary &)A G File: ADL 380109 ` Customer: 000053766 HILCORP ALASKA, LLC 3800 CENTERPOINT DR., STE.1400 ANCHORAGE AK 99503 SALE DATE Case Type: 784 OIL B GAS LEASE COMP DNR Unit: 78001L AND GAS File Location: DOG DIV OIL AND GAS 11 Case Status: 35 ISSUED Status Date: 01/29/1993 Total Acres: 2560.000 Date Initiated: 08/25/1992 Once of Primary Responsibility: DOG DIV OIL AND GAS 75 Last Transaction Date: 01212015 Case Subtype: NS NORTH SLOPE Last Transaction: DR DOCUMENT RECORDED Land Records MeridlawU Township: 012N Range:010E Section: 01 Section Acres: 640 Meridian:U Township: 012N Range:010E Section: 02 Section Acres: 640 Meridian: U Township: D12N Range: 010E Section: 11 Section Acres: 640 Mendian:U Township: 012N Range:010E Section: 12 Section Acres: 640��" Case Actions �tPGI -/3 a, �1�E/� rel.( 08-25-1991 TRACT DEFINED SALE DATE 12-06-1992 STATUS (11) 11 TRACT DEFINED BID TYPE 1 FIXED ROYALTY RATE SALE NUMBER 75 TRACT NUMBER 109 FORM NUMBER 30 DOG 9208 CONDITIONAL YIN N PRIMARY TERM 10 /2-08-1992 BID RECEIVED STATUS (12) 12 BID RECEIVED BID TYPE 1 FIXED ROYALTY RATE ROYALTY SHARE % 12.500000 12-08-1992 NOTIFICATION LESSEE DESIGNATED NEW REL (20) 20 NOTIFICATION LESSEE OLD REL CODE 21 DISPOSAL NAME NOTIFICATION CID NUMBER 107377 BP EXPLORATION (ALAS OLD CID # (SALE NO) 19927 SALE 75 12-09-1992 INITIAL OWNER SEGMENT CODE 1 CID NUMBER 000107377 BP EXPLORATION (ALAS WORKING INTEREST% 100 ROYALTY INTEREST% 87 500D 12-09-1992 INITIAL OWNER SEGMENT CODE 1 CID NUMBER W0019927 SALE 75 ROYALTY INTEREST% 12 500W 12.21-1992 LEASE AWARDED STATUS 13 13 LEASE AWARDED 01-29-1993 LEASE ISSUED EFFECTIVE DATE 02-01.1983 EXPIRATN DATE 0131-2003 STATUS (21) 21 ACTIVE LEASEISSUED 0647-1995 ASSIGNMENT APPROVED EFFECTIVE DATE 05.30.1995 SEGMENT CODE 1 ASSIGNOR'S CID 000107377 BP EXPLORATION (ALAS ASSIGNEE'S CID 000106425 OXY USA INC. WORKING INTER% 8.810000 ASSIGNED ROYALTY INTER% 7.708750 ASSIGNED LEASEISSUED 10.02-1995 COMMENTS STATE OF ALASKA MAR 0 1 2018 - ALIJA OIL AND GAS CONSERVATION COMWSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Plug Perforations Li Fracture StimulateLI Pull Tubing U Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Welu Re-enter Susp Well❑ Other: MBE Treatment Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Exploratory ❑ 202-114 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic Service Q 6.API Number: AK 99503 50-029-23093-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025627 MILNE PT UNIT S-13 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 4,957 feet Plugs measured N/A feet true vertical 4,575 feet Junk measured 4,855' feet Effective Depth measured 4,857 feet Packer measured 4,525&4,603 feet true vertical 4,480 feet true vertical 4,167&4,240 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20"x 34" 112' 112' N/A N/A Production 4,949' 7" 4,949' 4,567' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet SS 2-3/8" 4.6#/L-80/IBT 4,554' 4,194' Tubing(size,grade,measured and true vertical depth) LS 2-3/8" 4.6#/L-80/IBT 4,623' 4,259' 7"x 2-3/8"GT Ret.Dual Packers and SSSV(type,measured and true vertical depth) Baker FH N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A '! '/ j Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 980 1,000 587 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑I Exploratory❑ Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ E 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: 317-493 TP Authorized Name: Bo York a Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.com Authorized Signature: 'C.' Date: 2/28/2018 Contact Phone: 777-8412 74 3,74e if 2/f6' RBDiVIS G_- NAi( - 2C18 Form 10-404 Revised 4/2017 Submit Original Only • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-13 Pump 50-029-23093-00-00 202-114 11/11/17 11/14/17 Daily Operations: = l '1 11/8/2017-Wednesday No activity to report. 11/9/2017-Thursday No activity to report. 11/10/2017 - Friday No activity to report. 11/11/2017-Saturday Rig up on S-13SS.MIRU Cement Pump Unit and Little Red Pump Unit. PT lines to 250psi low/4,000psi high-test OK. Perform injectivity test at 0.9 bpm @ 1,000 psi. Mix and pump 10 bbl of HEC, 15 bbl of 15.8 ppg cement, and 5 bbl of HEC. Drop foam ball. Displace w/5.0 bbl of 1% KCI water. Switch to Little Red Pump Unit and pump 12 bbl of diesel. SD Pumps. Monitor well. Final SITP of 1,140 psi. Swap to Long String. Rig up on S-13LS.MIRU Cement Pump Unit and Little Red Pump Unit. PT lines to 250psi low/4,000psi high -test OK. Perform injectivity test at 0.9 bpm @ 1,000 psi. Mix and pump 10 bbl of HEC, 15 bbl of 15.8 ppg cement, and 5 bbl of HEC. Drop foam ball. Displace w/5.0 bbl of 1% KCI water. Switch to Little Red Pump Unit and pump 12 bbl of diesel.SD Pumps. Monitor well. Final SITP of 1,350 psi. RDMO Cement Pump Unit& Little Red Pump Unit. 11/12/2017-Sunday No activity to report. 11/13/2017- Monday No activity to report. 11/14/2017-Tuesday Rig up on S-13LS. MIRU Little Red Pump Unit. PT lines to 250psi low/4,000psi high -test OK. Perform injectivity test at 0.2 bpm @ 1,400 psi.;Rig up on S-13SS. MIRU Little Red Pump Unit. PT lines to 250psi low/4,000psi highi-test OK. Perform injectivity test at 0.4 bpm @ 1,280 psi. RDMO Little Red Pump Unit. • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, February 2, 2018 1:52 PM To: Wallace, Chris D (DOA);Alaska NS - Milne -Wellsite Supervisors Cc: Regg,James B (DOA); Brooks, Phoebe L(DOA); Stan Porhola; Darci Horner- (C) Subject: Shut-In Injector MPS-13 (PTD#2021140) Due for AOGCC MIT-IA All, Milne Point water injector MPS-13 (PTD#2021140)was shut-in on 1/23/2018 for reservoir management due to an MBE with its offset producer.The well is due for an AOGCC witnessed MIT-IA on 2/19/2018. The well will not be brought online in time for the test and will remain shut-in until its MBE is repaired.The well will be added to the Quarterly North Slope LTSI Injector Report. Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCAWK 1 or Tb • �w\��\� %�sv THE STATE Alaska Oil and Gas s Of sKA Conservation Commission lsri 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O „,•• Q• Main: 907.279.1433 ALASFax: 907.276.7542 www.aogcc.alaska.gov • Bo York Operations Manager Hilcorp Alaska, LLC 5;.':NW Nov 0 92017 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU S-13 Permit to Drill Number: 202-114 Sundry Number: 317-493 Dear Mr. York: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC 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, Hollis S. French Chair DATED this 2--' "day of October, 2017. RBD iS (A/ k3/ — 2 2617 • • t;9 -: L,,' STATE OF ALASKA /C-2 A ALASKA OIL AND GAS CONSERVATION COMMISSION ` . OTS -S � APPLICATION FOR SUNDRY APPROVALS � ` � '" 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations LI Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MBE Treatment Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 202-114 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service Q D. 6.API Number: Anchorage Alaska 99503 50-029-23093-00-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05 • Will planned perforations require a spacing exception? Yes ❑ No ❑., / MILNE PT UNIT S-13 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025627 • MILNE POINT/SCHRADER BLUFF OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 4,957' • 4,575' . 4,857' , 4,480' . 980 N/A 4,855'(Fish) Casing Length Size MD TVD Burst Collapse Conductor 112' 20"x 34" 112' 112' N/A N/A Production 4,949' 7" 4,949' 4,567' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): SS 2-3/8" 4.6#/L-80/IBT 4,554' See Schematic I See Schematic LS 2-3/8" 4.6#/L-80/IBT 4,623' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"x 2-3/8"GT Ret.Dual&Baker FH and N/A 4,525 MD/4,167 TVD&4,603 MD/4,240 TVD and N/A 12.Attachments: Proposal Summary D Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 • 14.Estimated Date for 15.Well Status after proposed work: 10/30/2017 Commencing Operations: OIL ❑ WINJ ❑., • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Stan Porhola STP Authorized Title: Operations Manager Contact Email: sporhola cl.hilcorp.com Contact Phone: 777-8412 Authorized Signature: 41,\.6.4........+ Date: 10/16/2017 J yecei I` COMMISSION USE ONLY Conditions of approv t• oti Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBD 'Lris l L t e 7 Spacing Exception Required? Yes EI No Zr Subsequent Form Required: 10 _4/04-i leu J — L 2617 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: I C, ( Z..F. I t Afn17- ORIGINAL _ ,0-:2y-17 `� , Submit Form and co Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Well Prognosis Well: MPU S-13 Hilcorp Alaska,LL) Date: 10/13/2017 Well Name: MPU S-13SS/LS API Number: 50-029-23093-00 Current Status: Water Injector Pad: Milne Point S-Pad Estimated Start Date: Oct 30th, 2017 Rig: N/A Reg.Approval Req'd? No Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-114 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Job Type: MBE Treatment S-13SS (SHORT STRING) Current Bottom Hole Pressure: 1,380 psi © 4,000' TVD (SBHPS 3/14/2007/6.64 ppg EMW) C. \ Maximum Expected BHP: 1,380 psi @ 4,000' TVD (No new perfs being added, EMW= 6.64 ppg) MPSP: 980 psi (0.1 psi/ft gas gradient) S-13LS (LONG STRING) Current Bottom Hole Pressure: 1,380 psi ©4,000' TVD (SBHPS 3/14/2007 /6.64 ppg EMW) Maximum Expected BHP: 1,380 psi @ 4,000' TVD (No new perfs being added, EMW= 6.64 ppg) 4 MPSP: 980 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU S-13 was drilled with Doyon #141 in 2002 as a deviated injector in the Schrader Bluff OA, and OB sands. The well was initially completed as a dual string injector using Nabors 4ES in August 2002. The well provides support in hydraulic unit 10 for the OA sand (Short-string) and the OB sand (Long-string) for offset producer MPU S-23 (PTD 202-114). Notes Regarding Wellbore Condition • Dual String Injector(Short-string= OA sand; Long-string= OB sand). • Well is a deviated dual-string water injector(max hole angle 32.0° @ 2,544'). • Last MIT-IA to 1,600 psi on 2/19/2016. • Shut-in water injection due to diagnosed MBE (Matrix Bypass Event). • Confirmed MBE between MPU S-23 (Jet Pump Oil Producer) based on dye tests in the OA and OB sands. Objective: The purpose of this work/sundry is to pump MBE treatments (down both the Long String [OB sand] and the Short String[OA sand])and place the well back on water injection for both strings. Brief Procedure: Pumping Procedure (STEPS#1-#30 to be completed for both Long&Short Strings} 1. Production to SI offset producers up to 5 days prior to treatment (S-23). 2. Production to SI offset injectors up to 2 days prior to treatment (S-15, S-26, S-33A). 3. MIRU Cement Pumping Unit and Little Red Pumping Unit. PT lines to 4,000 psi. [TREATMENT#1] • • Well Prognosis Well: MPU 5-13 xac„r„Alaska,Lb Date: 10/13/2017 a. Setup fluid manifold to allowing switching over from Cement Unit to Little Red. 4. Perform injectivity test w/8.5 ppg fresh water. a. Inject at 1.0 bpm or a max 1,000 psi for injectivity test. Do not exceed 1,250 psi. 5. Mix and bullhead the following fluids with the Cementing Unit: a. +/- 10 bbl of 100 ppt HEC (hydroxy ethyl cellulose) lead spacer pill. b. +/- 15 bbl of 15.8 ppg acid soluble cement. c. +/-5 bbl of 100 ppt HEC (hydroxy ethyl cellulose)tail spacer pill. d. Drop foam ball. 6. Mix and bullhead the following fluids with the Little Red Pumping Unit: a. +/-5.0 bbl of 1% KCL water. b. +/- 10.0 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 2.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 7. SD Pumps. Monitor wellhead pressures for 15 min (T/I/0). 8. RDMO Cement Pumping Unit and Little Red Pumping Unit. 9. WOC 48 hours. 10. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. [INJECTIVITYTEST#1] 11. Mix and bullhead the following fluids: a. +/-5 bbl of 60/40 McOH/Water(to ensure injectivity). b. +/- 10 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 1,250 psi. d. +/- 10 bbl of 60/40 McOH/Water(freeze protection; after stable injection achieved). 12. RDMO Little Red Pumping Unit. 13. Contingency: If unable to establish injectivity: a. MIRU Slickline. PT lubricator to 4,000 psi Hi 250 psi Low. b. RIH and tag cement top. POOH. c. RIH and bail cement. POOH. d. RIH w/dump bailer and spot 15% HCI acid to dissolve cement in tubing. e. Wait on acid minimum 4 hours (to dissolve calcium carbonate based cement). f. RIH and bail cement. POOH. g. RD Slickline. 14. Contingency: If residual cement exists: a. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg seawater. b. Pressure test BOPE to 4,000 psi Hi 250 psi Low, 10 min each test. i. Test using 60/40 methanol or 8.5 ppg seawater. ii. Each subsequent test of the lubricator will be to 4,000 psi Hi 250 psi Low to confirm no leaks. c. RIH w/1.50" coil w/ 1.50" wash nozzle to cement top. Circulate well w/8.5 ppg seawater. (tfl d. Continue to RIH and cleanout cement to+/-4,544' MD (SS-Tbg Tail) or+/-4,623' MD (LS-Tbg Tail). e. RU to test injectivity thru the tubing tail. Do not exceed 4,000 psi. POOH. 15. Contingency: If unable to cleanout cement w/wash nozzle. a. RIH w/1.75" OD mill, 1-11/16" motor, and oil jars and cleanout cement to +/-4,544' MD (SS-Tbg Tail) or+/-4,623' MD (LS-Tbg Tail). b. RU to test injectivity thru the tubing tail. Do not exceed 4,000 psi. POOH. 16. Contingency: If able to cleanout cement but unable to establish injectivity. a. RIH w/1.75" wash nozzle to+/-4,544' MD (SS-Tbg Tail) or+/-4,623' MD (LS-Tbg Tail). b. RU acid pumping unit. RU lines to pump down coil tubing. PT lines to 4,000 psi. • Well Prognosis Well: MPU S-13 IIilcorp Alaska,LL Date: 10/13/2017 c. Mix and pump 5-10 bbl of 15% HCI acid. Displace acid w/8.5 ppg seawater. POOH. d. RD acid pumping unit. RU return lines to acid returns tank. e. Wait on acid minimum 4 hours (to dissolve calcium carbonate based cement). f. Circulate acid out of well pumping 8.5 ppg seawater. g. RU to test injectivity thru the tubing tail. Do not exceed 4,000 psi. POOH. 17. Contingency: If unable to establish injectivity test after HCI soak, repeat Step#16[a-g]. 18. MIRU Cement Pumping Unit. PT lines to 4,000 psi. [TREATMENT#2] 19. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. 20. Fluid-pack and maintain tubing pressure on offset wells affected by MBE (S-23). 21. Mix and bullhead the following fluids with the Cementing Unit: a. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose) lead spacer pill. b. +/- 10 bbl of 15.8 ppg acid soluble cement. c. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose) tail spacer pill. d. Drop foam ball. 22. Mix and bullhead the following fluids with the Little Red Pumping Unit: a. +/-5.0 bbl of 1% KCL water. b. +/- 10.0 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 2.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 23. Discontinue maintaining tubing pressure on offset wells affected by MBE (S-23). 24. SD Pumps. Monitor wellhead pressures for 15 min (T/I/0). 25. RDMO Cement Pumping Unit and Little Red Pumping Unit. 26. WOC 48 hours. 27. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. [INJECTIVITY TEST#2] 28. Mix and bullhead the following fluids: a. +/-5 bbl of 60/40 McOH/Water(to ensure injectivity). b. +/- 10 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 1,250 psi. d. +/- 10 bbl of 60/40 McOH/Water(freeze protection; after stable injection achieved). 29. RDMO Little Red Pumping Unit. 30. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Fluid Flow Diagram-Acidizing • • Milne Point Unit Well: MPS-13 SCHEMATIC Last Completed: 8/23/2002 Hamra Alaska,IAA'. PTD: 202-114 TREE&WELLHEAD Orig.KB Elev.=66.70'/Orig.GL Elev.=38.60' Tree 2-1/16"- 5M Dual CIW RKB-Tbg Hngr.=20.70'(Nabors#4ES) 11"x 2-3/8"5M FMC Dual w/2.375"EUE T&B Thread Wellhead ), FMC Tubing Hanger 2.0"CIW"H"BPV Profile OPEN HOLE/CEMENT DETAIL 20" 20" 260 sx Arcticset in a 42"Hole *- 7" 1,218 sx 10.7 ppg Perm'L'/356 sx Class'G'in a 9-7/8"Hole WELL INCLINATION DETAIL P.' KOP @ 480' #ry Max hole angle=32 deg.at 2,544'MD ) Hole angle thru perfs=20 deg at 4,600'MD r' CASING DETAIL tO Size Type Wt/Grade/Conn ID Drift Top Btm BPF 20" Conductor 92/H-40/N/A 19.124" 18.936" Surface 112' 0.3552 - 1 ��w 7" Production 26/L-80/BTC-MOD 6.276" 6.151" Surface 4,949' 0.0383 4-: TUBING DETAIL t: 2-3/8" Tubing(Short) 4.6/L-80/IBT 1.995" 1.901" Surf 4,554' 0.0039 2-3/8" Tubing(Long) 4.6/L-80/IBT 1.995" 1.901" Surf 4,623' 0.0039 TUBING DETAIL t No Top Depth Item le SHORT STRING t; A 2,171' HES 2-3/8"'X'Nipple `e I, B 4,494' HES 2-3/8"'X'Nipple C 4,528' Baker Model'GT'Retrievable Dual Packer 40K Shear s D 4,542' 2-3/8"'XN'Nipple 1.791"No Go r", E 4,544' 2-3/8"WLEG—Bottom @ 4,554' LONG STRING w 1 2,201' HES 2-3/8"'X'Nipple g :', 2 4,491' HES 2-3/8"'X'Nipple 3 4,525' Baker Model'GT'Retrievable Dual Packer 40K Shear :, 2 4 4,603' Baker FH Packer 40K ROT Release 5 4,620' 2-3/8"'XN'Nipple 1.791"No Go B=' ;", 6 4,623' Cut 2-3/8"(Chemical Cut) 7 4,855' Top of Fish(10'Long),2-3/8"pup Cit 8 4,860' Baker Model'E'Hydro-Trip Sub b 9 4,861' 2-3/8"WLEG—Bottom @ 4,865' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Size Date Status OA 4,572' 4,587' 4,210' 4,224' 15 6 3-3/8" 8/20/2002 Open C, 9 OB 4,632' 4,647' 4,266' 4,281' 15 6 3-3/8" 8/20/2002 Open 7 A Ref Log:SC MT—7/02/2002—Perf Guns 3-3/8"/346 Hill RDX 0.4"EH 6 spf 60 deg MninumlD= _ D ',: 1.791"@4,542 '•• GENERAL WELL INFO 4- API:50-029-23093-00-00 E Drilled&Cased by Doyon 141—6/22/2002 'a OA Sands Initial Completion by Nabors 4ES-8/23/2002 5 4_..:..„,Mnirrum ID= Cut Tubing Y_i 6 ,'i1.791"@4,620' 4,623'ELM Suds f *CB ,4 ', 8 ° 7„ w. 9 TD(MD)=4,957'/ TD(TVD)=4,575' PBTD(MD)=4,865'/PBTD(TVD)=4,488' Revised By:STP 9/26/2017 • • . iii COIL BOPE MILNE POINT UNIT MPU S-13 Hilcorp Alaska,LLC 10/13/2017 MPU S-13 20 X 7 X 2%(Dual) Coil Tubing BOP Lubricator to injection head 0 r,; I 1.50"Single Stripper Il 1 �r` '■I■ Blind/Shear imm_41/1616 Blind/Shear 11111• 11 a l®- _ Blind/Shear Blind/Shearl111114 ill=aim O0 1011111 pJ'I Slip _- Slip ' ism --_ iii iip--)11111 Pipe o�'maim Pipe 111 1 11•�� Crossover spool 41/16 10M X 4 1/16 5M al as rpt `d,�r P4 1/16 5Mb Ii( : . t . _4411: 1502 Union l r Manual Gate Manual Gate Crossover spool liji I 2 1/8 5M 2 1/8 5M 41/165MX23/8SM Valve,Swab,WKM-M, "_° .!, 2 3/8 5M FE(Long-String) "� Valve,Swab,WKM-M, �'11 f 2 3/8 5M FE(Short-String)ll 0Osl\ r�) �� S�t�r \1�•\t'�'Scot. al a��e O\E\\ori 'allI ®' I 0911 J,z,Ve' `F \ 1ti3� �. Valve,Upper Master,Baker, 2 3/8 5M FE,w/Hydraulic 0 ,,N 0 Valve,Upper Master,Baker, (Long-String) 2 3/8 5M FE,w/Hydraulic 111110mi (Short-String) ill Iiii Valve,Lower Master,WKM-M, 2 3/8 5M FE(Long-String) 1, k��/ lw t Valve,Lower Master,WKM-M, `o i0401'- 2 3/8 5M FE(Short-String) .e1/r Tubing Adapter,11x7 its `® iii x23/8dual 5M • I .--. - CCU' w i.' z A u, 03 O co 0 0f —I 01 D3 0 0. -1 m 0. x• rn 77 f f ePtill ,,- .4- RE im 1111 NE 7 –I— I ;,. '. 1,r--'' ,J, li 4110114- 4 Elimilil k 1111191mmiii I.4.. .'6.1 p __ ' -- 4.! Mil lili'lli ini P 21.-23:=' - `• s ., .., F -L'.1! . egfin ..---- % A * —oipeT4•••— F T , —<•:1-061-71 A ....1 "1011111.1110.111 ,)...'' 09 , (1, g /2w. , .r•••• "Ititritsi ••—i — ...1 : i 4 '.0 %„..i 8 '• '4. 4) 6 •-• 1.-, , wi : A. . NN -- CD CD g• :• C • Z ....0 t or L___ : x : : ..... ..= ....._ m • cc › co 57. F ,,- = . :: • - ip.-1 2 0 z zi > z xl, > m -1 §: 41 . 0 ;, <= ,,7,- at- %.....::•: ,...::::: mr" rn Pa cra V+:r $It' F3- (3 2- R ... .: §' tv. co .8 r, 03 130c0 arci E. . c a z" i a -1 x -1 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,February 26,2016 TO: Jim Regg . JL P.I.Supervisor -fe( t" r�`I SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC S-13 FROM: Jeff Jones MILNE PT UNIT SB S-13 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB S-13 API Well Number 50-029-23093-00-00 Inspector Name: Jeff Jones Permit Number: 202-114-0 Inspection Date: 2/19/2016 Insp Num: mitJJ160221074959 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-13 iType Inj 1 W-TVD T 4166 - Tubing 947 I 946 - 946 - 946 - 2021140 SPT 1500 T 252 1724 - 1662 - 1656 - PTD Type Test Test psi IA Interval-011ER 1P/F P ''' OA Notes: Dual string monobore injector(no OA).0, =. - • -- • . . •• - - . -.Short String TBG pressures:Pre/985,Initial/986, 15 min/987,30 min/987 SCANNED SEP 2 6 2016 Friday,February 26,2016 Page 1 of 1 STATE OF ALASKA • RECEIVED A OIL AND GAS CONSERVATION COMMISSION 0 C T 0 7 2015 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon Li Plug Perforations L] Fracture Stimulate L] Pull Tubing❑ Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: MBE Treatment ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑ Exploratory ❑ 202-114 • 3.Address: Stratigraphic Service ❑✓ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23093-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025627 • MILNE PT UNIT SB S-13 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 4,957 • feet Plugs measured N/A feet true vertical 4,575 • feet Junk measured N/A feet Effective Depth measured 4,857 feet Packer measured 4,524/4,603 feet true vertical 4,480 feet true vertical 4,166/4,240 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20"x 34" 112' 112' N/A N/A Production 4,949' 7" 4,949' 4,%coital 7,240psi 5,410psi '` Z01Perforation depth Measured depth See Attached Schematic feetIr True Vertical depth See Attached Schematic feet SS 2-3/8" 4.7#/L-80/IBT 4,554' 4,194' Tubing(size,grade,measured and true vertical depth) LS 2-3/8" 4.7#/L-80/IBT 4,623' 4,259' 7"x 2-3/8"GT Ret.Dual Packers and SSSV(type,measured and true vertical depth) 7"x 2-3/8"FH Ret N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 690 Subsequent to operation: 0 0 0 1,120 956 14.Attachments(required Per 20 AAC 25.070,25_071,a 25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ • Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 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: 314-494 Contact Stan Porhola Email sporhola anhilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature .....47"'",&—. T(T�""1 Phone 777-8412 Date 10/5/2015 ?X‘ `o- �>�( �/ RBDM CT 132015 Form 10-404 Revised 5/2015 Submit Original Only e Tree: CIW 2 1/16"5M Dual string MPU S-13 i Wellhead:11"x 2 3/8"?lafVF _FMC dual string Orig. KB Bev. = 66.70 Hanger thread 2 3/8"EUE top and bottom Orig. GL-EIev. = 39.20 2"CIW-H BPV profile 20"x 34"insulated,215#/ft A-53 112' Short String Long String 2171' 2-3/8" HES X-Nipple(1.875"pkg. bore) 71 2-3/8" HES X-Nipple (1.875"pkg. bore) 2201' KOP @ 480' Max. hole angle = 32 deg @2,544' Hole angle thru perfs = 20 DEG. 7"26#, L-80, BTRC Casing (drift id =6.151, cap.= .0383 bpf) 2-3/8",4.7#/ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) 4494` 2-3/8" HES X-Nipple(1.875"pkg.bore) 2-3/8" HES X-Nipple(1.875" pkg. bore) 4491' Tx 2-3/8"Baker"GT' Ret. dual pkr. 4524' 1.945"I.D. 4542' 2-3/8" HES XN-Nipple(1.875"pkg. bore) No-Go 1.791" 4554' Tubing tail/WLEG Perforation Summary 7"x 2-3/8" Baker"FH"Ret. pkr. 4603' 2.41" I.D. Size Spf Interval (TVD) OA sandsXN'. 2-3/8" HES XN-Nipple(1.875"pkg. bore) 4620' No Go 1.791" 3 3/8" 4 4572'-4587' 4210'-4224' Tubing Cut ELMD 4623' OB sands 3 3/8" 4 4632'-4647' 4266'-4281' 2-3/8Fish 9"'Baker(cut offmodel tail pipe ) "E" ydro trip sub w/4857' 4'x23/8"pup h 4,866' 7" Halliburton Float Collar PBTD 1.75"ball. 4,949' 7" Halliburton float shoe 4'x 2 3/8"pup w/mule shoe. DATE REV. BY COMMENTS MILNE POINT UNIT 06/22/02 MDO Drilled by Cased Doyon 141 WELL No.: S-13i 08/23/02 J. Jones Completion Rig 4ES API : 50-029-23093-00 • • Hilcorp Alaska, LLC ►l i►curp Alaska.I L(: Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP S-13i 50-029-23093-00-00 202-114 10/7/2014 11/28/2014 Daily Operations: 10/7/14-Tuesday Injectivity test(Pre MBE Treatment). Pumped 5 bbls 60/40 meth followed by 25 bbls produced water down SS tubing to establish injectivity rate of 2 bbls per min. @±1,150 psi. Pumped 10 bbls meth for freeze protect. FWHP=-16/680/-9, LS, SS-WV/SV/SSV=Closed. LS,SS-MV=Open, IA=OTG. 10/11/14-Saturday Perform injectivity test. Pump 10 bbls of 100ppt HEC gel. Pump 15 bbls of 15.8 ppg acid soluble cement. Pump 2 bbls of 100 ppt HEC gel. Pump 17.7 bbls of diesel. 10/12/14-Sunday Freeze protect LS from divert shelter. Pumped 0.5 bbls up to header and 14.5 bbls down tubing. Header root valve closed, divert shelter to well open to thermal down hole. 10/14/14-Tuesday SS-121psi/LS-190psi/IA-Vac. Injectivity test. Pumped 4 bbls 60/40 methanol. Unable to establish injectivity. FWHP= 241psi on SSD, 205 psi on LS. IA on Vac. SwV,SSV,WV=Closed. MV=Open. IA=OTG. 10/27/14-Monday Run 1.74"cent., 1.50"sampler bailer,S/D @ 4,515'. Sample of cement recovered. S/I Well and leave location. 11/5/14-Wednesday T/I/0=0/0/0. Injectivity test. Pumped 20bbls 60/40 methanol down LS to establish injectivity. SwV=Closed,SSV, WV, MV= Open. IA/OA=OTG. FWP=413/0/0. 11/28/14-Friday RU CTU#8 on MPU S-13i short string. PT 250 psi Low/4,000 psi High. Witness of test waived by Jim Regg,AOGCC. Freeze protect long string. Make up hard lines to choke. Run fluid lines to 400 bbl upright tank. Little Red Services(LRS) heating up fluid. MU 1.73 OD mill, 1.69 motor,dual circulation valve, FAU disconnect,oil jar, dual back pressure valve, coil tubing connector.TIH @ 105 fpm taking PU weight every 2,000'.Circulate at.0.50 bpm @ 1470 psi.8.5 fluid density.TIH to 4,576' not tagging any cement or obstruction.Wash and circulate BU. Perform injectivity test.0.50 bpm @ 1095 psi.Test good. POOH with milling assembly. DMO CTU#8. Released at 10:00. OF Tit • • � �'\\I%%�cv THE STATE Alaska Oil and Gas 9 1 lAVKA (L.,onservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF J. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Alecia Wood SCANNED Production Engineer BP Exploration (Alaska), Inc. O D"- ( 1. 4 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit, Schrader Bluff Oil Pool, SBL MPS-13LS Sundry Number: 313-587 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, 7 Cathy P.Foerster Chair, Commissioner DATED this day of November, 2013. Encl. i • • A& RECEIVED STATE OF ALASKA A° ALASKA OIL AND GAS CONSERVATION COMMISSION \\ NOV 2 2013 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Weil❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.WeII❑ Stimulate❑ Alter Casing❑ Other. MBE Treatment • 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 202-114-0 3.Address: . r. Stratigraphic ❑ Service El. 6 API Nu�o_o 2.y_x 3 0 4 3-00 -00 P.O.Box 196612,Anchorage,AK 99519-6612 Pt4.13 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? SBL MPS-13LS Will planned perforations require a spacing exception? Yes El No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025627 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): 4957 • 4575 • 4866 • 4489• None 4857. Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"X 34"215.5#A53 28-108 28-108 Surface None None None None None None Intermediate None None None None None None Production 4921 7.26#L-80 28-4949 28-4567.33 7240 5410 Liner None None None None None None Perforation Depth MD(ft ):pttA Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4632-4647 4266.97-4281.09 2-3/8"4.7#L-80 L-80 21-4623 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths ✓ No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program el • BOP Sketch ❑ Exploratory El Development ❑ Service © • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 • GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG p 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alecia Wood Email Alecia.Wood @BP.Com Printed Name Alecia Wood Title Production Engineer Signature Phone 564-5492 Date Prepared by Garry Gabon 564-4424 W CI 0-- u3' Oki NO COMMISSION USE ONLY c/ -� Conditions of approval: Notify Commission so that a representative may witness Sundry Number. ^j\--2J 5 ` Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0•"'ii C) !-, NOV 1 APPROVED BY Approved by: , / �� COMMISSIONER THE COMMISSION Date: //--2,19 , n GlilaN ^ �/. Aftd•!3 P1ti3 1if 413 ��3t4a Form 10-403 Revised 10/2012 1 ApI ep iAlit for 1(m"onths from the date of approval. Submit Form a d A chments in Duplicate • • Packers and SSV's Attachment ADL0025627 Well Facility Type MD Top Description TVD Top MPS-13LS PACKER 4525 2-3/8" Baker GT Dual Packer 4167 MPS-13LS PACKER 4603 2-3/8" Baker FH Ret Packer 4240 �,II • • • bp 0 To: Mark O'Malley/Rob Handy Date: September 18, 2013 MPU Ops Team Leaders From: Alecia Wood, MPU Schrader Pad Engineer 907-564-5492 Subject: MPS-13LS MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPS-13LS 2 F Bullhead treatment down MPS-13LS. 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. 3 C Pending the post cement injectivity tests, perform a fill clean out and possible (Pending) 15bbl HCL acid soak to attempt to regain injectivity. OBJECTIVE l Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Should the cement or gel lock up the wellbore, a contingent acid job will be performed. 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. • It is unknown which zone has the MBE. Hold pressure on the SS while pumping the treatment down the LS to prevent cement/gel from entering the SS wellbore. f ,_• 1 Background MPS-13i was drilled in August 2002 as a Schrader Bluff OA/OB Injector. MPS-13i has an MBE to MPS-23 and confirmed pressure communication between the short string and long string. The nature f the intra-tubing communication is currently unknown. 4/3 u ' -1 is known to have •oor cement isola i in •-hi • •••- o both short and long strings track. Injection splits between the OA and OB are questionable as a result. Prior geochemical analysis on MPS-23 production shows approximately 75% from the OA and 25% from the OB, so it is possible that the OA is taking most of the injected water, however there are two other MBE's to S-23, one in the OA and one in the OB from S-26 so the zone of the MBE in S-13 is unkown. Injectivity in MPS-13 increased gradually over the one year period from February 2004 to 2005 culminating with a step change event that is typical of Schrader breakthroughs. The injector was shut in for one month and water cuts on offset producer MPS-23 were observed to decline. MPS-13 was placed back on injection in March 2005. Injectivity remained high and watercut at MPS-23 climbed rapidly. • • It was determined that since the zone of the MBE is unknown, the treatment will be pumped down the LS while holding minimum rate to maintain positive wellhead pressure on the SS. This is an attempt to keep the cement from pumping up the SS. Due to the string communication, should the MBE be in the LS, this would be the preferred method. Should the MBE be in the SS, the cement should travel up the backside of the liner due to the string communication, and into the MBE as it has the highest injectivity. This case will likely result in a FCO being required in the LS, which is less risky than a FCO and reperforation being required in the SS, as perforations in the SS run a risk of perforating the tubing of the LS. This cement job should also serve to squeeze off the string communication behind pipe. PROCEDURE Stage 1. Injection Test 1. RU, hold pre-job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear into the LS 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. Hold minimum pump rate on the SS during each stage of pumping of this treatment (Cement and gel) to maintain positive wellhead pressure on the SS due to string communication. 7. Pump down the LS a produced water pre-flush followed by cement acting fluid treatment and diesel or methanol displacement. Allow setup time. 8. Perform injectivity test of the LS following cement stage. Should well exhibit zero injectivity, perform CT fill clean out with possible 15bbl HCL acid soak to attempt to regain injectivity into the wellbore. 9. Pump down the LS a produced water pre-flush followed by a second stage of cement acting fluid treatment, holding pressure on the offset Producer connected by the Matrix Bypass Event. Attempt to squeeze second stage of cement and displace with diesel or methanol. Allow setup time. 10. Perform injectivity test on the LS following cement stage. Should well exhibit zero injectivity, perform CT fill clean out with possible 15bbl HCL acid soak to attempt to regain injectivity into the wellbore. 11. Pump down the LS a produced water or KCL pre-flush followed by high volume gel treatment and diesel or methanol over flush. 12. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 13. Perform injectivity test of the SS following second cement stage on the LS. Should well exhibit zero injectivity, perform CT fill clean out with possible 15bbl HCL acid soak to attempt to regain injectivity into the wellbore. 14. Rig down all equipment and hold post job assessment meeting to capture learnings to be • incorporated into future jobs. 15. Forward all post job assessments (w/all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. . • Tree:CNV 21116"5M Dual string Wel8tead:11"x 23/8' 1. 1:dual string M P U S-131 9.KB Elev.=66.70 Hanger thread 2 3/8'EUE top and bottom - Orig.GL Elev.=3920 2"CIW-H BPV profile 20"x34"bisutated,215 it/ft A-53 112' Short String Long String 2171' 2-3/8"HES X-Nipple(1.875'pkg.bore) p 2-3/8"HES X-Nipple(1.875'pkg.bore) 2201' KOP 480' Max.hole angle=32 deg 02,544` Hole angle ihru pests=20 DEG_ T 26E,L-80,BTRC Casing (drift id=6.151,cap.=.0383 bpi) 2-3/8",4.7#1ft L-80,IBT tubing (drift id=1.901,cap.=.00387 bpf) 4494' 2-3/8"HES Xple(1.875'pkg.bore) n X tipple(1_875'pkg_bore) 4491' n 7"x 23/8"Baker"GT"Rd_dual pkr. 4524' 1.945'I.D. 4542' 2-3/8'HES XN-Nipple(1.875"pkg.bore) No-Go 1.791' 4554' Tubing tail I WLEG � Perforation Summary Tx 2-318°Baker'Fig Rd.pkr. 4603' 2.41`ID. Size Spf Interval (TVD) XN 2-318"HES XN-Nipple(1.875"pkg_bore) 4620' CA Mo& No-Go 1.791' 3 3/8" 4 4572'-4587' 4210`-4224' ELMD 4623' Tubing Cut DELftaftda g MBg_ 3 3/8' 4 4632'-4647' 4266'-4281' Fish 9'(tat off tail pipe) wE E. 4'x23/6"pup 2-3/8"Baker model"E°hydro trip sub wi 4,866' T Halldaurton Float Collar PBTD 1.75'bat. 4,949' T Halkburton float stare 4`x 2 3/8"pup rid mule shoe. DATE REV_BY COMMENTS MILNE POINT UNIT 06122/02 MDO Drifted by Cased Doyon 141 WELL No.:S-131 08123102 J_Jones Completion Rig 4ES API:50-029-23093-00 BP EXPLORATION (AK) bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 5164 MINED FEB '2 4 Z01Z // , 2:7 (7--- Mr. Tom Maunder Alaska Oil and Gas Conservation Commission a09- 333 West 7 Avenue — ' Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -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 i Report of Sundry Operations (10-404) MPS -Pad 1011112011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date • ft bbls ft gal MPS-01A 2070340 50029231410100 0.25 NA 0.25 NA 5.1 9/6/2011 MPS -02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 MPS-03 2021460 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS-09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 / t, MPS-11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 j C-- , + MPS-12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7/29/2011 " ----- ) 1 • MPS -13 202424 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS-14 ' ' 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7/29/2011 MPS-15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS -16 2030650 50029231510000 1.2 NA 1.2 NA 10.2 7/29/2011 A l ` MPS-17 2021730 50029231150000 Open Flutes - Treated MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 MPS-20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS-22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7/28/2011 MPS -23 2021320 50029230980000 Open Flutes - Treated MPS-24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 7/28/2011 MPS-25 2021030 50029230890000 Open Flutes - Treated MPS-26 2030610 50029231500000 1 NA 1 NA 8.5 7/28/2011 MPS -27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7/28/2011 MPS-28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7/28/2011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS -30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS -31 2020140 50029230660000 Open Flutes - Treated MPS-32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7/28/2011 MPS -33A 2061720 50029231230100 1 NA 1 NA 6.8 7/28/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS -37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS -41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/11/2011 MPS-90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB-04 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 2Q2011 Not Operable Injector Report Page 1 of 2 0 0 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWetllntegrityCoordinator @bp.com] Sent: Monday, July 04, 2011 4:44 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 2Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 2Q2011.zip Tom, Jim, Phoebe and Guy, Attached is the 2Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 2Q2011.zip» ?.01'i Notes on wells: Removed from Quarterly Injection Report: 13 -09 (PTD #1811580): RWO repaired TxIA comm. On 04/30/11 END 3- 43/P -36 (PTD #1931700): Surface casing leak repaired with Brink platelets on 05/17/11 LGI -08 (PTD #1860570): Not Operable Producer that had been mismarked in BP system as a not operable injector thereby being generated to report MPF -92 (PTD #1981930): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 MPF -95 (PTD #1981790): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 P2 -16 (PTD #1931230): RWO repaired PC leak and TxIA comm. On 04/15/11 U -10 (PTD #1851970): TxIA comm. That was repaired with a tubing patch on 06/05/2011. Moved to Monthly Injector report pending AOGCC witnessed test WGI -06 (PTD #1900300): RWO repaired TxIA comm. Well moved to Monthly Injector report pending AA cancellation Z -12 (PTD #1891020): TxIA communication repaired with cement packer on 05/24/11. Added to Quarterly Injection Report: L -223 (PTD #2090990): MIT -IA failed on 05/01/11. MPS -07 (PTD #2020720 -IA failed on 04/09/11 ir (_ MPS -13 (PTD #2021140)• assed MIT -IA on 04/11/11. LTSI that requires AOGCC MIT -IA when put on production. V -227 (PTD #2091160): Exhibiting rapid IA repressurization. Classified as Not Operable on 06/20/11. 7/5/2011 Well MPS -13 Injection Plot Injection _ — — — — — TIO Plot I Well: MPS -13 a __ PraccurP vs, Rate — ° ' PTD: 2021140 CD Tbgl --- - IA LTSI for reservoir management OI -- -- - - - - -- ---- - - - --1 - - - - -- - -- --- - - - -- -- S. °- o — — i °o — N T i • Last 90 days • Last Month 0 0 1 I■ 0 0 0 1 1 1 1 2/19/11 5/12/11 8/2/11 Injection Rate, MCFPD — — • Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 07/01/11 0 0 -100 06/30/11 0 0 -100 06/29/11 0 0 -100 06/28/11 0 0 -100 06/27/11 0 40 -100 06/26/11 0 0 -100 06/25/11 0 0 -100 06/24/11 0 40 -100 06/23/11 0 0 -100 06/22/11 0 0 -100 06/21/11 0 0 -100 06/20/11 0 0 -100 06/19/11 0 0 -100 06/18/11 0 0 -100 06/17/11 0 0 -100 06/16/11 0 0 -100 06/15/11 0 0 -100 06/14/11 0 0 -100 06/13/11 0 0 -100 06/12/11 0 0 -100 06/11/11 0 0 -100 06/09/11 0 0 -100 06/08/11 0 0 -100 06/06/11 0 0 -100 06/05/11 0 0 -100 06/04/11 0 0 -100 06/03/11 0 0 -100 06/02/11 0 0 -100 06/01/11 0 0 -100 05/31/11 0 0 -100 05/30/11 0 0 -100 RE: MPS-13i . . tKJ"d--\ \ ......., Subject: RE: MPS-13i From: "Mathews, William L" <MathewWL@BP.co Date: Tue, 24 Jun 2003 15:30:27 -0500 To: Tom Maunder <tom _ maunder@admin.state. # Tom, The cement job on MPS-13 was evaluated prior to running the dual string injector completion. It was interpreted as having isolation between the OA and OB intervals from 4610' to 4626' md. Isolation from the overlying N sands was achieved by cement from 4546' to 4558' md. While cement quality is not as good as what is observed below the OB interval from 4718' to 4724' md, it was expected to be sufficient for zonal isolation. Post completion initial SBHP measurements were taken 9/10/02, but inconclusive regarding isolation since both intervals were observed to be normally pressured at 0.43 psi/ft. A subsequent SBHP was taken 10/6/02 that showed a decrease of 38 psi in the OA interval and an decrease of 33 psi in the OB interval. Again, these numbers are not conclusive in showing isolation. Injection performance has been monitored on both strings over time. A plot attached shows the rates and pressures for each string. There are instances of separation, which would be indicative of isolation. Often times, when pressures track, the injection rates are significantly different. Again, this could be an indication of isolation. At the very least, I am confident we have isolation either by cement or by interference from injection that is forcing water into each interval. Whether or not this is 100% isolation, I can't say for sure. We will continue to monitor the well. If you have any questions, please let me know. Bill Mathews Lead Schrader PE 564-5476 ~JUN 142007 -----Original Message----- From: Tom Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, June19-;2003 4: i2]?M-~-- To: Mathews, William L Subject: MPS-13i Hi Bill, I was wondering if you could give me an assessment of the bond on MPS-13. Sort of looks like MPS-31. There is cement there and it appears adequate for isolation. Tom Maunder 1 of 1 ßrf{ 7f1j . :J~' ('\ ~~ ........... ~ (fLC-CW I 6/11/2007 11 :55 AM J / . MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor (;7 A (Z¡;"lû 7 ~(rf '1" v DATE: Monday, April 23, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-l3 MILNE PT UNIT SB S- I 3 ~O~VII4' FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv~ Comm NON-CONFIDENTIAL Well Name: MILNE PT UNIT SB S-B API Well Number: 50-029-23093-00-00 Inspector Name: Chuck Scheve Insp N um: mitCS070415081439 Permit Number: 202-114-0 Inspection Date: 4/14/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S-l3 Type Inj. N TVD 4166 IA 0 I 1800 1720 I I710 P.T.D 2021140 TypeTest SPT Test psi 1500 OA I I Interval OTHER P/F P Tubing 1220 I 1220 1220 I 1220 I Notes: Test performed due to leaks encountered on other monobore completions. SGANNED APR 3 0 2007 Monday, April 23, 2007 Page I of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP ACT / Milne Point / S-Pad 04/14/07 Jeff Rea / Lee Hulme Chuck Scheve d. Dd--.-j ì If Packer Depth Pretest Initial 15 Min. 30 Min. WeIlIMPS-07 I Type Ini. N TVD I 4,231' Tubinq 400 500 500 500 Interval I 0 P.T.D.12020720 I Tvpe test I P T est psi! 1500 Casing 1,700 1,650 1,640 P/FI P Notes: 4.4 bbls diesel to 1700 psi. Bled to 0 psi OA Well is currentlv SI. Proactive testing to determine'lA status due to leaks found on other monobore completions. WeIlIMPS-09 I Type Ini. W TVD I 4,368' Tubing 800 800 800 800 Interval I 0 P.T.D.12020200 I Tvpe test I P Test psil 1500 Casing 280 1,710 1,670 1,670 P/FI P Notes: 1.6 bbls diesel to 1710 psi. Bled to 300 psi OA Proactive testing to determine IA status due to leaks found on other monobore completions. WeIlIMPS-13 I Type Ini.1 N I TVD I 4,166' Tubinq 1,220 1,220 1,220 1,220 Interval I 0 PTD.12021140 I Type test P Test psil 1500 Casing 1,800 1,720 1,720 P/FI P Notes: 3.4 bbls diesel to 1800 psi. Bled to 250 psi OA Well is currently SI. Proactive testing to determine IA status due to leaks found on other monobore completions. WeIlIMPS-21 I Type Ini.1 N I TVD I 4,027' Tubinq 200 250 250 250 Interval I 0 P.T.D.12020090 I Tvpe test P Test ps¡ 1500 Casing 220 1,720 1,680 1,680 P/FI P Notes: 1.7 bbls diesel to 1720 psi. Bled to 200 psi OA Well is currently SI. Proactive testina to determine IA status due to leaks found on other monobore completions. Weill I Type Ini.1 TVD I Tubinq Interval I P.T.D.I I Tvpe testl Test ps¡ Casing P/FI Notes: OA . . TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test NED APR 1 7 2007 R = Internal Radioactive Tracer ~ A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form BFL 9/1/05 MIT MPU S-07, S-09, S-13, S-21 4-14-07.xls e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker.doc ~1~~'1 DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2021140 Well Name/No. MILNE PT UNIT SB 5-13 Operator BP EXPLORATION (ALASKA) INC Jt!: u J. I q j ~~,,-~ LH" ct AP(No. 50-029-23093-00-00 MD 4957 v TVD 4575/ Completion Date 8/21/2002 ~ Completion Status 1WINJ Current Status 1WINJ UIC Y --~-~-~---- - -~ - -----~._----_.--" -~~---~-------------_. - ._---_.~--- -- REQUIRED INFORMATION Mud Log No Samples No -'\ ~ Directional su~e~~~___-- -~---_.._----------~----~. DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) ~ Log/ Electr Data Digital Dataset Type Med/Frmt Number Name &£D C 0rI122 Cement Evaluation ar( D Directional Survey CEÐ D C--f1244 LIS Verification ~ LIS Veñfication pt Directional Survey ~C L..41486 See Notes Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments ~-_.--_.._---_.._-- ~ 1 0 4819 Case 1 0/1/2002 0 4957 Open 7/25/2002 II çJ( 56 4897 Case 1 0/28/2002 56 0 4897 Case 1 0/15/2002 4957 Open 7/25/2002 MWD 4957 Case 1/15/2003 Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity MWD 110 ~- ~ ~/ ~ Directional Survey LIS Verification Name Interval Start Stop 0 4957 Open 7/25/2002 56 4897 Case 10/28/2002 0 4957 Open 7/25/2002 5 Col 3700 4840 Case 8/30/2002 56 4897 Case 1 0/15/2002 Sample Set Sent Received Number Comments ~~ L.ßÐ/D Dire?1 Survey ~ent Evaluation ~180 LIS Verification Primary Depth Control -------~----- -..-.------ Well Cores/Samples Information: Permit to Drill 2021140 MD 4957 TVD 4575 Well Cored? ADDITIONAL INFORMATION y'Q Chips Received? "- Y I N - Analysis Received? Comments: Y/N- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Well Name/No. MILNE PT UNIT SB 5-13 Operator BP EXPLORATION (ALASKA) INC Completion Date 8/21/2002 Completion Status 1WINJ Daily History Received? Formation Tops ~L API No. 50-029-23093-00-00 Current Status 1WINJ UIC Y WIN GIN Date: ~-~---~-_.._.~"--- ~, --------._~-------~_._--.~_.- ~~ Q Jz:f~1fiJ~E7==~~~~ f ------ ( (: ::?UD DA'::=:: G /\S ~o5 OPER & FIELD -f~'? df.):J-~. \ \ 1_\ . k \ \ 'f'-( \? --\-' ~ '3 MECHANICAL INTEGRITY REPORT' '--. :~ I G R E L E J.. S =.:: - WELL NUMBER s ~ \ ~\ CasiDg: TD: ~<;S~( ,HD.. l-\5'LS-TVD i ?BTD: ,-\<;5:~ç MD l-\~SS~ TVD '\ Shoe: ~S Lf~ HI) TVD i DV: \.:J h. MD .Tvu ~:":1 e:::- : "-J C\. S hoe: HJ) TVD j :0 P : tom :7D 'ò \.)(;J 'n . - ~5'ðS;S un \\SS ~ :- iJ b i:::: g: a--${ç/ r aCKe..:.. 'I.-\~'7/ .::~ TVD i Set ê.. t """C~ rl- ~ C'J, ì (//.', :, 5'\.;:¿ +-\.,.o ~,S-~, ...,~ t'\ :::'ole S.:.z e " )5 ana P er£s \ '-\ Cø'7~ ~ L-.,\ G ~ 'ì OS :~ ~LL DATA t:EC?..Þ.BICl-.L INTEGRITY - PART 11 Annulus Press Test: :î.P 15 min 30 min Cowments: ,...- ME CRËÜ;¡I CAL INTEGRITY - PART / 2 \ \ ~ \ ~ ~\, \ 'Ç Cement Volumes:' Þ-..mt.. Liner N~' ; Csg 3~tQ\,\ç DV ~~. , , C¡¡¡t 701 to cover peris \r; í\ ",~':J%:\"'¡ "-,,,Oe .\ \¡,c.<t'/'-..~" 1\\\CÌI' ~\ -\0 (~"fr'- .\ð\? c~~ . The or e ti cal TOC C( ""'-! ¥~,,"-'\(', "" ð \. '" -.0 \c... \t-~ ~ ~\,) \~<š ¡ I '1 , r Cement Bond Log (Yes or No),,\'\:~ ; :In AOGCCFile 'icS ". CBL Evaluation, ::one above perfs Q\,,--(t~\.\-~'.JCt\..~)~~á~~O---k- CD\\d;\,~ ...s\S~\t- QS Wt ~-- ~ \. \I (<LI/V\.CK~"\S.~CL\"( ~'J\-~W Q\IV\p\\'~¿\~~ ~ g...u -,,).~ P roàuc..tion La g : Tn> ~ Evaluation , t CONCLUSIONS: ? ar t : 1 : ? ar ~ : 2 : kr'\<)\~\~\ì . , ( .'" ,JçJ1Jv¡ &tl~-a~ .10 - . - - -- \ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: MPS-13: Digital Log Images: 50-029-23093-00 January 15, 2003 MPS-13, AK-MW-22097 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signed: BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED JAN 1 5 2003 ¡~IIKI Or. & liaS Coos. Comml88im Anchorage c9od-J/Lj ,I JLj ~0 ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned a Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3330' NSL, 107' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 1971' NSL, 927' WEL, SEC. 12, T12N, R10E, UM At total depth 1870' NSL, 997' WEL, SEC. 12, T12N, R10E, UM 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. KBE = 66.7' ADL025627 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 6-19-2002 6-21-2002 8-23-2002 17. Total Depth (MO+TVO) 18. Plug Back Depth (MO+TVO) 19. Directional Survey 4957 4575 FT 4865 4488 FT a Yes 0 No 22. Type Electric or Other Logs Run MWD , GR , CCL , RES, PWD , IFR 1 CASANDRA , OM , CNP , SLD 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 92# H-40 Surface 112' 42" 260 sx Arctic Set (Approx.) 7" 26# L-80 28' 4949' 9-7/8" 1123 sx PF 'L', 361 sx Class 'G' TUBING RECORD SIZE DEPTH SET (MD) 2-3/8",4.7#, L-80 4554' 2-3/8",4.7#, L-80 4623' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Diesel. 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 4 SPF MD TVD 25. MD TVD OA Sands 4572' - 4587' 26. OA Sands 4211' - 4225' 08 Sands 4632' - 4647' 08 Sands 4267' - 4281' 27. Date First Production October 29,2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR OIL-BBL TEST PERIOD WATER-BBL GAs-McF Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL 11/05/02, Put on Injection Classification of Service Well Dual Completion for Water Injection 7. Permit Number 202-114 302-250 8. API Number 50- 029-23093-00 9. Unit or Lease Name Milne Point Unit 10. Well Number MPS-13i 11. Field and Pool Milne Point Unit 1 Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MO 1800' (Approx.) AMOUNT PULLED PACKER SET (MD) 4528' 4603' CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. No core samples were taken. RBDMS BFt Form 10-407 Rev. 07-01-80 NOV I P } I"j Q~'VfD NOV 0 6 2002 Alaska Oil & Gas Qons. Commissicm Anchorage Submit In Duplicate ( 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. SBF2-NA 4421' 4071' SBF1-NB 4451' 4099' SBE4-NC 4480' 4125' SBE2-NE 4495' 4139' SBE1-NF 4545' 4186' TSBD-OA 4580' 4218' TSBC 4611' 4247' TSBB-OB 4633' 4268' SBA5 4661' 4294' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~"':~".."'-! ' ,--> Signed s~~,D_,,, Title Technical Assistant MPS-13i 202-114 302-250 Well Number Permit No. / Approval No. Date r l - O~ - 0 ~~- Prepared By Name/Number: Sondra Stewman, 564-4750 Drilling Engineer: Robert Odenthal, 564-4387 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 c9L8- IlL} I {J.L/~ WELL LOG TRANSMTITAL To: State of Alaska Alaska Oil and Gas Conservation Cotnm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 22, 2002 RE: MWD Formation Evaluation Logs MPS-13, AK-MW-22097 1 LIS fonnatted Disc with verification listing. API#: 50-029-23093-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Si~ (/.Oo-pJ Note: This data replaces any previous data for well: ( MPS-13 ). r:~fC. ~ t: I C":,;"-': r= fJJ:_~ l:: ¡"'¡','C'""r t,,") \J ~ ~' . io".,,,, ßJ~~k~ ,~~:, aOeJ-I/' J II <ttJ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 11, 2002 RE: MWD Fonnation Evaluation Logs MPS-13, AK-MW-22097 1 LIS fonnatted Disc with verificåtion listing. API#: 50-029-23093-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Sign~..m.(~---J RECE\VED OCT 15 2002 Ai.a Oi\ &. Gas Cons. eomm\lllm AndKØ96 Scblullberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well MPS-11 caØã.-J/~ ~PS-13 ~O d-JJt.-j D-08A aÖ;;>- } rl. ~ D-17B a~- } I I D.S.14-33 I&~-/~ ~ Job# 22443 SCMT (PDC) 22444 SCMT (PDC) 22434 GRlCCL (PDC) 22433 GRlCCL (PDC) 22386 RST -SIGMA Log Description Date 07/01102 07/02/02 07/15/02 07/12/02 07/21/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 -"--D . Date Delivered: ~ ~ (Å Oeb ~ Blueline NO. 2449 Company: 09/30102 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia 1 Color Prints - CD 1 1 1 1 1 ,'-c, Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth RECEIVED Received by: OCT 0 1 2002 AlIIke Oil & Gal Cons. CommlllG'" AndNnge ( STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned a Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface rCOM'!)U:ïiCN ¡, ,t.oCA'r1õÑ¡l 3330' NSL, 107' WEL, SEC. 12, T12N, R10E, UM '~,',', " nATE , J'.', '~~,' !. At top of productive interval ,- ~, 2./, Q.?l ~ , " ~ 1971' NSL, 927' WEL, SEC. 12, T12N, R10E, UM ~. -- YERW ! ~, . - .,~ At t~tal depth, 't', ..._-,~p 1>_, ,--j ~I,..~:~2.~ 1870 NSL,997 WEL, SEC. 12, T12N, R10E, UM _",>r;r...~JI'''''-'''''' - :~"'~.~~~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 66.7' ADL025627 12. Date Spudded 13. Date T.D. Reached 14. Date Co~~~sP., °'tband. 6-19-2002 6-21-2002 ~,j-2002 )JP , . 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 4957 4575 FT 4865 4488 FT aYes 0 No 22. Type Electric or Other Logs Run MWD , GR , CCL , RES, PWD , IFR 1 CASANDRA , DM , CNP , SLD 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 92# H-40 Surface 112' 42" ,260 sx Arctic Set (Approx.) 7" 26# L-80 28' 4949' 9-7/8" 1123 sx PF 'L'.I 361 sx Class 'G' Classification of Service Well Dual Completion for Water Injection 7. Permit Number 202-114 302-250 8. API Number 50- 029-23093-00 9. Unit or Lease Name Milne Point Unit 10. Well Number MPS-13i 11. Field and Pool Milne Point Unit 1 Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1800' (Approx.) 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 4 SPF MD TVD 25. SIZE 2-3/8",4.7#, L-80 2-3/8",4.7#, L-80 MD TVD AMOUNT PUllED TUBING RECORD DEPTH SET (MD) 4554' 4623' PACKER SET (MD) 4528' 4603' OA Sands 4572' - 4587' OA Sands 4211' - 4225' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Diesel. 26. 08 Sands 4632' - 4647' 08 Sands 4267' - 4281' 27. Date First Production Not on Injection Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) N/A PRODUCTION FOR Oil -BBl TEST PERIOD GAs-McF WATER-BBl Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE Oll-BBl GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RATIO Oil GRAVITY-API (CORR) ~8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. j t . fJ No core samples were taken. Form 10-407 Rev. 07-01-80 ~ ' GÝ ~ ;b'R B 0 M S B F L SEP I 6 2002Submit In Duplicate (' 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. SBF2-NA 4421' 4071' SBF1-NB 4451' 4099' SBE4-NC 4480' 4125' SBE2-NE 44951 4139' SBE1-NF 45451 41861 TSBD-OA 4580' 42181 TSBC 4611' 4247' TSBB-OB 4633' 42681 SBA5 4661' 4294' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the !9t;going is true and correct to the best of my knowledge Signed son~~~~ Title- Technical Assistant Date[)Ct - L b "0 Â- MPS-13i 202-114 302-250 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. Drilling ~ngineer : Robert Odenthal, 564-4387 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 (OF, 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 ( ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP Operations .S~umma..,;"eport MPS-13 MPS-13 DRILL +COMPLETE DOYON DOYON 141 Start: 6/19/2002 Rig Release: 6/23/2002 Rig Number: 141 Spud Date: 6/19/2002 End: 6/23/2002 Date From - Tö Hours Task Code NPT Phase Description of Operations 6/18/2002 12:00 - 14:00 2.00 MOB P INT1 PREP WELL AREA MPS-13 WITH DIRT WORK FOR SUB FOOTPRINT 14:00 - 15:00 1.00 MOB P INT1 LAY HERCULlTE AND MATTS ON MPS-13 15:00 - 16:00 1.00 MOB P INT1 MOVE SUB OFF MPS-25 - MOVE SUB 180 DEGREE ON MATTS TO MPS-13 16:00 - 17:00 1.00 MOB P INT1 MOVE SUB MODULE OVER MPS-13 - LEVEL SUB 17:00 - 19:00 2.00 MOB P INT1 MOVE - SPOT 4 UTILITY MODULES - SET IN PLACE - (ACCEPT RIG 19:00 HRS 06/18/2002) TWO EXTRA HOURS OF DIRT WORK REQUIRED TO LEVEL PAD ON MPS 13 - BACKED UP ACCEPTANCE 2 HOURS FOR THAT WORK 19:00 - 20:00 1.00 MOB P INT1 MOVE - SPOT ROCKWASHER MODULE - START UTILITY HOOK UPS 20:00 - 21 :00 1.00 MOB P INT1 MOVE PIPE SHEDS - SPOT PIPE SHEDS - BERM ROCKWASHER - COMPLETE RIG ACCEPTANCE LIST 21 :00 - 00:00 3.00 BOPSUR P INT1 NIPPLE UP 16" DIVERTER SYSTEM ON 20" - LOAD 4" DRILL PIPE IN PIPE SHED - TAKE ON WATER IN PITS FOR MIXING SPUD MUD 6/19/2002 00:00 - 01 :30 1.50 DIVRTR P INT1 FINISHED NIPPLlNG UP DIVERTER SYSTEM. STRAP DRILL PIPE IN PIPE SHED AND MIXED SPUD MUD. 01 :30 - 06:30 5.00 DRILL P INT1 RIGGED UP AND PICKED UP 50 STANDS OF 4" DRILL PIPE AND RACKED IN DERRICK. 06:30 - 07:00 0.50 DRILL P INT1 MADE UP 7 STANDS OF 5" HWDP AND STOOD IN DERRICK. 07:00 - 07:30 0.50 DIVRTR P INT1 FUNCTION TEST DIVERTER AND PERFORM ACCUMULATOR TEST. RIGHT TO WITNESS TEST WAIVED BY AOGCC INSPECTOR, CHUCK SCHEVE. 07:30 - 10:00 2.50 DRILL P INT1 PICKED UP 9-7/8" HUGHES MXC-1, MOTOR WITH 1.5 DEGREE BENT HOUSING AND 6-3/4" MWD (GAMMARES/DM/CNP/SLD). UPLOADED MWD. 10:00 - 10:30 0.50 DRILL P INT1 HELD PRE-SPUD SAFETY MEETING WITH RIG CREW AND SERVICE HANDS. 10:30 - 11 :00 0.50 DRILL P INT1 FILLED RISER WITH MUD AND CHECKED FOR LEAKS. 11 :00 - 13:30 2.50 DRILL P INT1 RAN IN HOLE WITH DRILLING ASSEMBLY AND TAGGED BOTTOM AT 110'. DRILLED FROM 110' TO 245' - WOB 10K TO 15K - GPM 450 - PP 1350 ON BTM -1100 OFF BTM - TQ 1 K ON BTM - 13:30 - 14:30 1.00 DRILL P INT1 STAND BACK 2 STANDS OF 5" HWDP - PICK UP 3 FLEX DC'S - 2 STABILIZER'S - LOAD 2 RA SOURCES 14:30 - 00:00 9.50 DRILL P INT1 DIRECTIONAL DRILL FROM 245' TO 1304 - WOB 25K - RPM 80 - TQ 2K ON BTM - OFF BTM 1K - GPM 450 - PP ON BTM 1930 - OFF BTM 1750 - ECD 9.7 - PU 70K - SO 70K - ROT 72K - ECD 9.8 6/20/2002 00:00 - 06:00 6.00 DRILL P INT1 DIRECTIONAL DRILL FROM 1304' TO 2519' - WOB 30K - RPM 80 - TQ 6K ON BTM 2K OFF BTM - GPM 500 - PP 2600 ON BTM - 2300 OFF BTM - ECD 10.2 - PU 80K - SO 77K - ROT 82K 06:00 - 07:30 1.50 DRILL P INT1 CBU 3 X - CLEAN HOLE - FOR SHORT TRIP - GPM 500 - PP 2300 - RPM 90 07:30 - 09:00 1.50 DRILL P INT1 OSBERVE WELL - PUMP OUT FROM 2519' TO 840' - GPM 500 - PP 2300 - TIGHT @ 09:00 - 09:30 0.50 DRILL P INT1 RIH FROM 840' TO 2426' - TIGHT SPOTS TAKING 20K DOWN WEIGHT - 1470', 1575', 1880',2045',2225' - WASH Printed: 6/24/2002 1 :22:24 PM ( ( laP Operatiol1sSummary.,..Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-13 MPS-13 DRILL +COMPLETE DOYON DOYON 141 Start: 6/19/2002 Rig Release: 6/23/2002 Rig Number: 141 Spud Date: 6/19/2002 End: 6/23/2002 Date From - To Hours Task Code NPT Phase Description of Operations 6/20/2002 09:00 - 09:30 0.50 DRILL P INT1 PRECAUCTIONARY FROM 2426' TO 2519' 09:30 - 00:00 14.50 DRILL P INT1 DIRECTIONAL DRILL FROM 2519' TO 4480' - WOB 5K TO 15K - RPM 100 - TO ON BTM 6K - OFF BTM 4K - GPM 500- PP ON BTM 3050 OFF BTM 2900 - ECD 9.9 - PU 115K - SO 92K - ROT 104K 6/21/2002 00:00 - 06:00 6.00 DRILL P INT1 DIRECTIONAL DRILL FROM 4480 TO 4957' - WOB 20K TO 25K - RPM 100 - TO ON BTM 6K OFF BTM 4K - GPM 500 - PP ON BTM 3350 PP ON BTM 3150 - ECD 10 1 - PU 125- SO 95 - ROT 110 06:00 - 08:30 2.50 DRILL P INT1 CIRCULATE AND CONDITION HOLE FOR SHORT TRIP. 520 GPM AT 3150 PSI, 100 RPM. RACK BACK STAND EVERY 30 MINUTES. 08:30 - 11 :30 3.00 DRILL P INT1 OBSERVE WELL. PULLED OUT OF HOLE TO 2050'. WELL APPEARED TO SWAB AT BOTTOM OF PERMAFROST. PUMPED OUT OF HOLE WITH 400 GPM FROM 2050' TO 1300'. CONTINUED PULLING OUT OF HOLE TO HWDP AT 840'. 11 :30 - 13:00 1.50 DRILL P INT1 OBSERVE WELL. TRIP IN HOLE WITH DRILLlING ASSEMBLY TO 1900'. WORKED THROUGH TIGHT SPOT FROM 1900' TO 2100'. CONTINUED RUNNING TO 4887' WITH NO PROBLEM. 13:00 - 13:30 0.50 DRILL P INT1 PRECAUTIONARY WASH AND REAMED 70' TO BOTTOM. 13:30 - 15:30 2.00 DRILL P INT1 PUMP SWEEP - CIRC 3 X BTMS UP - GPM 500 - PP 3100- MONITOR WELL - PUMP DRY JOB 15:30 - 17:00 1.50 DRILL P INT1 POH FROM 4957' TO 2400' 17:00 - 18:00 1.00 DRILL P INT1 PUMP OUT FROM 2400' TO 1300' - GPM 500 - PP 2000 18:00 - 19:00 1.00 DRILL P INT1 POH TO MWD - FROM 1300' TO 100' 19:00 - 22:00 3.00 DRILL P INT1 PJSM - REMOVE RA SOURCES - DOWN LOAD MWD - BREAK BIT - LD MOTOR 22:00 - 22:30 0.50 DRILL P INT1 PJSM - RIG UP SCHLUMBERGER 22:30 - 00:00 1.50 DRILL P INT1 RUN IN HOLE WITH SIDEWALL CORES - HIT BRIDGE @ 1645' - WORK ON BRIDGE TRYING TO PASS - NO SUCCESS - PULL OUT OF HOLE WITH SIDEWALL TOOL 6/22/2002 00:00 - 00:30 0.50 DRILL N DPRB INT1 PJSM - LAY DOWN SIDEWALL CORES - RIG DOWN SCHLUMBERGER 00:30 - 02:30 2.00 DRILL N DPRB INT1 MAKE UP HOLE OPENER - RIH TO 1648' - TAKING WEIGHT 10k - POPPED THROUGH - RIH TO 1670' - PICK UP TO 1600' - RIH TO 1670 - NO TIGHT SPOTS SEEN - PICK UP TO 1590' 02:30 - 03:00 0.50 DRILL N DPRB INT1 REAM FROM 1590' TO 2136' - RPM 120 - GPM 500 - PP 1320 03:00 - 03:30 0.50 DRILL N DPRB INT1 RIH WITHOUT PUMPS - FROM 2136' TO 2500' - SLICK HOLE 03:30 - 04:30 1.00 DRILL N DPRB INT1 CIRCULATE 3 X BTMS UP - GPM 500 - PP 1320 - RPM 120 - LOTS OF FINE SAND OVER SHAKERS - SHAKERS CLEANED UP - MONITOR WELL - WELL STATIC 04:30 - 06:30 2.00 DRILL N DPRB INT1 PULL OUT HOLE WITHOUT PUMPS - HOLE IN EXCELLENT SHAPE - NO OVERPULL SEEN - 06:30 - 09:00 2.50 DRILL N DPRB INT1 PICK UP SIDEWALL CORES - RIH ATTEMPT TO PASS AT 1645' - NO SUCCESS - PULL OUT HOLE - RIG DOWN SCHLUMBERGER 09:00 - 10:30 1.50 DRILL P INT1 RIG UP TO RUN 7" CASING 10:30 - 17:00 6.50 DRILL P INT1 PJSM - PICK UP I RUN 7" CASING TO 4949' - LANDED AT Printed: 6/24/2002 1 :22:24 PM Bf> E):perations',.Summary.,...Report Legal Well Name: MPS-13 Common Well Name: MPS-13 Spud Date: 6/19/2002 Event Name: DRILL +COMPLETE Start: 6/19/2002 End: 6/23/2002 Contractor Name: DOYON Rig Release: 6/23/2002 Rig Name: DOYON 141 Rig Number: 141 From - To Hours Task Code NPT Phase Description of Operations 6/22/2002 10:30 - 17:00 6.50 DRILL P INT1 17:00 HRS 17:00 - 18:00 1.00 DRILL P INT1 ESTABLISH CIRCULATION SLOWLY TO 285 GPM - 380 PSI - CIRCULATE THROUGH FRANKS TOOL FOR 3500 STKS 18:00 - 18:30 0.50 DRILL P INT1 LAY DOWN FRANKS CIRC TOOL - MAKE UP HOWCO CEMENT HEAD 18:30 - 19:30 1.00 DRILL P INT1 REESTABLISH CIRCULATION - 285 GPM - 380 PSI- CONTINUE TO CIRC / COND MUD FOR CEMENTING 7" CASING - PUMPED TOTAL 8300 STKS - PJSM FOR CEMENTING 19:30 - 23:00 3.50 DRILL P INT1 PUMPED 10 BBLS WATER - TEST LINES TO 3500 PSI- PUMPED 40 BBLS WATER - KICK OUT BOTTOM PLUG- PUMP 50 BBLS ALPHA SPACER 10.2# - PUMP 900 BBLS OF 10.7# LEAD CEMENT - CEMENT TO SURFACE AFTER 720 BBLS LEAD PUMPED - SWITCH TO PUMP 73 BBLS OF 15.8 # TAIL CEMENT - KICK OUT TOP PLUG WITH HOWCO 23:00 - 00:00 1.00 DRILL P INT1 DISPLACE WITH HOWCO - 30 BBLS DIESEL - 159 BBLS OF 9.2 BRINE - BUMP PLUG WITH 1000 PSI OVER CIRCULATING PRESSURE OF 1250 PSI (2250) - FULL RETURNS THROUGH JOB EXCEPT LAST 29 BBLS PUMPED OF TAIL - LOST RETURNS - CEMENT DID NOT FALL IN RISER BUT STAYED STATIC - 313 BLS OF CEMENT TO SURFACE. CIP 23:45 6/23/2002 00:00 - 01 :30 1.50 DRILL P INT1 BREAK OUT CEMENTING HEAD - LAY DOWN LANDING JOINT - CLEAR FLOOR OF CASING TOOLS - CEMENTING HEAD 01 :30 - 04:30 3.00 DRILL P INT1 NIPPLE DOWN DIVERTER SYSTEM 04:30 - 05:30 1.00 DRILL P INT1 NIPPLE UP FMC DUAL STRING 20" X 11" 5M GEN 6 WELLHEAD 05:30 - 06:30 1.00 DRILL P INT1 ENERGIZE SEAL - TEST CASG SPOOL TO 1000 PSI FOR 15 MINS - OK 06:30 - 08:00 1.50 DRILL P INT1 INSTALL FALSE BOWL -7" VALVE - BPV 08:00 - 08:30 0.50 DRILL P INT1 TEST FALSE BOWL ADAPTER VOID TO 5000 PSI FOR 5 MINS 08:30 - 11 :00 2.50 DRILL P INT1 LAY DOWN 7 STANDS HWDP -10 STANDS 4" DP - FROM DERRICK 11 :00 - 12:00 1.00 DRILL P INT1 RIG UP HB&R - TEST 7" CASING AGAINST BPV TO 500 PSI FOR 5 MINS - TEST TREE TO 500 PSI FOR 5 MINS - RIG DOWN HB&R - RELEASE RIG @ 12:00 HRS Printed: 6/24/2002 1 :22:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: (' BP Operations ,Summary Report MPS-13 MPS-13 COMPLETION NABORS DRILLING CO. NABORS 4 8/19/2002 12:00 - 18:00 18:00 - 19:00 19:00 - 20:30 20:30 - 21 :30 8/20/2002 21 :30 - 00:00 00:00 - 01 :30 01 :30 - 03:30 03:30 - 07:00 07:00 - 16:00 6.00 RIGU P 1.00 WHSUR P 1.50 BOPSUR P 1.00 BOPSUR P 2.50 CLEAN P 1.50 CLEAN P 2.00 CLEAN P 3.50 CLEAN P 9.00 PERF P 16:00 - 22:30 6.50 RUNCOrvP 22:30 - 00:00 1.50 RUNCOrvP 8/21/2002 00:00 - 03:00 3.00 RUNCOrvP 03:00 - 05:00 2.00 BOPSURP 05:00 - 08:00 3.00 RUNCOrvP 08:00 - 15:30 7.50 RUNCOrvP 15:30 - 19:00 3.50 RUNCOrvP 8/22/2002 19:00 - 20:00 20:00 - 20:30 20:30 - 21 :30 21 :30 - 22:30 22:30 - 00:00 00:00 - 00:30 00:30 - 03:00 03:00 - 07:30 07:30 - 20:00 1.00 RUNCOrvP 0.50 RUNCOrvP 1.00 BOPSUR P 1.00 WHSUR P 1.50 WHSUR P 0.50 WHSUR 2.50 RUNCOM 4.50 RUNCOM 12.50 EVAL N NPT Phase PRE COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP DPRB COMP Page 1 of2 Start: 8/19/2002 Rig Release: 8/23/2002 Rig Number: 4ES Spud Date: 6/19/2002 End: 8/23/2002 of Operations MI/RU & SAFE OUT EQUIPMENT. CHECK PSI. ON WELL & NIPPLE DN TREE & REMOVE FALSE BOWL & INSTALL TEST PLUG. NIPPLE UP BOP TEST BOP 250 LOW/ 3500 HIGH & PULL TWC & SET WEAR RING (TEST WAIVED BY CHUCK SHEVE WITH AOGC. MU BIT & SCRAPER & WITH 3.5" DP FROM SHED. RIH WITH SCRAPER & BIT TO 4859' 4ES KB CHG..OUT WELL BORE FLUIDS TO 9.1 PPG. & TEST CSG. TO 3500 PSI. LAY DN 3.5" DP RIG SWS & RIH & CORRELATE IN & PERF. RUN #1 4632'--4647' RUN #2 4572'--4587' & RUN GR/JB TO 4850' RIG GB&R TBG. TOOLS & PICK UP 141 JT.S 2-3/8" TBG. & RIH & POOH & STD IN DERRICK; RIH WITH 141 JTS. 2-3/8" TBG. FROM SHED & POOH & STD IN DERRICK. RIH WITH 141 JTS. 2-3/8" 4,7# L-80 IBT TBG & POOH & STD IN DERRICK CHANGE RAMS IN BOP TO 2-3/8" DUAL RAMS & PSI. TO 3500. RIG UP GBR DUAL STRING TBG. TOOLS. RIH WITH 2-3/8" DUAL COMPLETION WITH BAKER FH AND BAKER GT PKRS. & SPACE OUT FOR GR/CCL. RIG SWS & RUN GR/CCL DOWN LONG STRING & TIE STRING INTO CORRECT. SETTING DEPTH. (GR/CCL SHOWED THAT PKR. NEEDED TO BE MOVED DOWN HOLE 8' TO PUT PKR. @ 4598' SPACE OUT & LAND TBG. DUAL HANGER. RIG DOWN TBG. TOOLS. SET TWC & NIPPLE DN BOP NIPPLE UP DUAL COMPLETION TREE TEST TREE TO 5000 PSI. & HANGER PULL TWC RIG HARD LINES TO TREE & ADD COREXIT TO 150 BBL. 9.1 PPG. BRINE & REVERSE CIRC DOWN ANNULUS FOLLOWED WITH 80 BBL. DIESEL & U-TUBE TO SHORT & LONG STRING. DROP 1.75" SETTING BALL DOWN LONG STRING & LET FALL & PSI. LONG STRING TO 2500 PSI. TO SET "FH" & "GT'" PKRS. & PRESSURE ANNULSU TO 2000 PSI. & CHART TEST FOR 30-MINUTES . PSI. LONG STRING TO 5000 PSI. IN ATTEMPT TO SHEAR BAKER MODEL "E" HYDRO SET UNABLE. PSI. SHORT STRING TO 1500 PSI. & WAS ABLE TO SEE COMMUNICATION TO LONG STRING AS FLUID WAS PUMPING BALL OFF SEAT. DROP BALL DN SHORT STRING & TEST SAME TO 3000 PSI. OK SHEAR BALL OUT OF SHORT STRING. RIG HES SLICK LINE & MAKE RUNS AS FOLLOW IN ATTEMP TO SHEAR OUT BAKER E HYDRO SET SUB. #1 1.75" BLIND BOX #2 1.25" BAILER #31.5" SWEDGE #4 1.90" SWEDGE # 5 PLUG. & WHILE MAKING THESE RUNS Printed: 9/9/2002 1 :44: 13 PM ( BP Operations. Summary Report Page20f 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-13 MPS-13 COMPLETION NABORS DRILLING CO. NABORS 4 Start: 8/19/2002 Rig Release: 8/23/2002 Rig Number: 4ES Spud Date: 6/19/2002 End: 8/23/2002 Date From - To Hours Task Code NPT Phase Descri ption of Operations 8/22/2002 07:30 - 20:00 12.50 EVAL N DPRB COMP PRESSURE & BEATING DOWN WITH WIRELlNE TOOL STRING WAS THE METHODS APPLIED. (NO RESULTS POOH & RIG DOWN HES.ALL RUNS WERE MADE IN TAIL PIPE AREA OF "XN" NIPPLE TO BAKER liE' SET TOOL. WAIT ON SWS E-LlNE TRUCK & CHEMICAL CUTTER. SWS RIH WITH CHEMICAL CUTTER & GET ON DEPTH & CUT IN MIDDLE OF 6' PUP@ 4623' PERFORM CIRC TEST IN A ATTEMPT TO IDENTIFY DOWNHOLE FAILURE. SET BPV IN BOTH LONG & SHORT STRINGS & SECURE TREE AREA RIG RELEASED @ 0900 HRS. 8/23/2002 20:00 - 00:00 4.00 RUNCOI'vf\J DPRB COMP 8/23/2002 00:00 - 05:00 5.00 RUNCOI'vf\J DPRB COMP 05:00 - 07:00 2.00 RUNCOI'vf\J DFAL COMP 07:00 - 09:00 2.00 WHSUR P COMP Printed: 9/9/2002 1 :44: 13 PM AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ðt f:B. -I J<j 22-Jul-02 Re: Distribution of Survey Data for Well MPS-13 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , M D (if applicable) 4,957.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) RECEIVED ,,111 2 ~ '1002 0uL J L Alaska Oil & Gas Cons. Commision Anchorage BP EXPL( R~"1' J INC. MlltI8111J .. .. ~fJtllf 1iP*:, Milne Point .S,,~S/fltMPS-13 "",&-f- Job No. AKMW22097, SUWIJ,ed: 21 June, 2002 SURVey 22,J,.Iy,:,.2 ;..,.",~".." Your Ret:.~?;J¡j:~""~"l1O Surface Coordinates: 5999998.31 H, 56591í.4I'1!C70. '4' 37.56698 H, 1490 27' 48.13688 W) Kelly Bushing: 66.7Øft above Mean Sea Level ~;~~.~ A Halliburton Company Survey Ref: svy10146 Sperry.Sun Dr;,- Services . SurveyRepøt;tfO,.~ør8Jlfm Your Ref:A.'¡'í Job No. AKMWt20S', . $¡ BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coôrdlnates GlObal Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs lattlng. Northing. lastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 0.00 0.000 0.000 -66.70 0.00 O.OON O.OOE 5999998.31 N 565902.48 E 0.00 MWD Magnetic 173.30 1.370 280.010 106.58 173.28 0.36N 2.04'W 5999998~65 N 565900.44 E 0.791 0.51 Interpolated Az. 230.29 1.790 281.010 163.55 230.25 0.65N 3.58W 5999998.93 N 565898.89 E 0.739 0.88 319.82 2.080 221.730 253.04 319.74 0.305 6.04W 5999997.96 N 565896.44 E 2.156 2.75 408.60 3.650 162.790 341.72 408.42 4.205 6.28W 5999994.06 N 565896.24 E 3.528 6.41 497.65 5.550 155.110 430.48 497.18 10.81 5 3.62W 5999981.46 N 565898.95 E 2.238 11.35 586.81 7.430 163.770 519.07 585.77 20.26 S 0.lOW 5999978.05 N 565902.46 E 2.371 18.55 677.63 9.170 172.670 608.94 675.64 33.08 5 2.311: 5999965.25 N 565905.14 E 2.376 29.18 768.29 10.160 173.580 698.31 765.01 48.19 S 4.18E 5999950.16 N 565907.09 E 1.105 42.21 863.49 10.000 180.180 792.04 858.74 64.80 5 5.10E 5999933.56 N 565908.15 E 1.224 56.98 956.75 10.200 192.380 883.87 950.57 80.96 S 3.30'! 5999917.38 N 565906.49 E 2.300 72.45 1050.57 12.140 204.730 975.92 1042.62 98.04 S 2.61W 5999900.25 N 565900.74 E 3.272 90.45 1143.90 13.730 207.750 1066.88 1133.58 116.76 S 11.87W 5999881.45 N 565891.64 E 1.851 111.32 1236.62 14.550 208.050 1156.79 1223.49 136.785 22.47 W 5999861.34 N 565881.21 E 0.888 133.93 1331.02 15.330 210.670 1248.00 1314.70 157.985 34.41 W 5999840.04 N 565869.46 E 1.093 158.16 1424.13 15.410, 210.510 1337.78 1404.48 179.22 5 46.97 W 5999818.68 N 565857.09 E 0.097 182.69 1517.58 15.720 212.340 1427.80 1494.50 200.61 5 6O.05W 5999797.17 N 565844.20 E 0.621 207.57 1610.04 19.060 213.020 1516.02 1582.72 223.86 S 74.98 W 5999773.80 N 565829.48 E 3.619 234.90 1702.63 19.550 214.430 1603.41 1670.11 249.31 5 91.98 W 5999748.19 N 565812.71 E 0.730 265.09 1796.75 22.760 216.700 1691.17 1757.87 276.91 5 111.77 W 5999720.43 N 565793.16 E 3.519 298.38 1889.35 24.210 218.200 1776.10 1842.80 306.19 S 134.22 W 5999690.94 N 565770.97 E 1.694 334.30 1984.85 26.500 216.110 1862.40 1929.10 338.80 S 158.89 W 5999658.12 N 565746.59 E 2.574 374.16 2077.58 29.030 215.800 1944.45 2011.15 373.77 S 184.24 W 5999622.93 N 565721.54 E 2.733 416.46 2170.66 29.390 216.160 2025.69 2092.39 410.525 210.93 W 5999585.94 N 565695.18 E 0.430 460.94 2263.81 29.880 216.080 2106.66 2173.36 447.735 238.08 W 5999548.50 N 565668.36 E 0.528 506.02 2358.18 31.790 214.140 2187.68 2254.38 487.31 S 265.88 W 5999508.68 N 565640.91 E 2.282 553.52 2447.89 31 .330 212.820 2264.13 2330.83 526.47 S 291.78 W 5999469.29 N 565615.36 E 0.925 599.87 2544.38 32.060 211.790 2346.23 2412.93 569.32 5 318.87W 5999426.20 N 565588.65 E 0.942 650.07 2638.45 30.540 212.340 2426.60 2493.30 610.73 S 344.81 W 5999384.56 N 565563.07 E 1.644 698.48 2731.55 31.280 212.240 2506.48 2573.18 651.165 370.36 W 5999343.91 N 565537.88 E 0.797 745.84 - --_.-----------.- 22 July, 2002 - 9:58 Page 20f4 DrillQuest 2.00.08.005 . BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordin..s Global Coordinates Dogleg Vertical Depth Inel. Azlm. Depth Depth Northlngs E..tlnga Northing. Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) \........ 2826.07 29.230 212.930 2588.12 2654.82 691.29 5 396.00 W 5999303.55 N 565512.60 E 2.200 792.96 2919.21 29.760 213.950 2669.19 2735.89 729.55 5 421.27 W 5999285.07 N 565487.67 E 0.784 838.23 3012.59 30.120 214.560 2750.11 2816.81 768.07 S 447.50W 5999226.32 N 565461.77 E 0.505 884.13 3105.91 28.810 213.620 2831.36 2898.06 806.08 S 473.23 W 5999188.08 N 565436.38 E 1.489 929.36 3199.83 29.800 212.500 2913.26 2979.96 844.61 5 498.30 W 5999149.33 N 565411.65 E 1.205 974.79 3293.85 30.660 212.780 2994.49 3061.19 884.475 523.84 W 5999109.25 N 565386.4 7 E 0.927 1021.62 3386.99 28.770 211.570 3075.38 3142.08 923.54 S 548.43W 5999069.97 N 565362.22 E 2.129 1067.34 3480.55 28.660 210.150 3157.43 3224.13 962.125 571.49W 5999031.18 N 565339.50 E 0.739 1111.99 3573.84 25.650 211.490 3240.43 3307.13 998.69 5 593.28 W 5998994.42 N 565318.04 E 3.292 1154.29 3667.25 25.230 212.210 3324.79 3391.49 1032.785 614.45 W 5998960.15 N 565297.17 E 0.558 1194.06 3760.77 25.720 212.200 3409.21 3475.91 1066.81 5 635.89 W 5998925.93 N 565276.03 E 0.524 1233.90 3854.28 26.070 211.710 3493.33 3560.03 1101.46 S 657.50W 5998891.09 N 565254.73 E 0.439 1274.37 3947.55 26.190 212.330 3577.07 3643.77 1136.295 679.28 W 5998856.07 N 565233.25 E 0.320 1315.07 4040.97 26.690 213.030 3660.72 3727.42 1171.305 701.74 W 5998820.86 N 565211.10 E 0.631 1356.22 4133.50 26.570 212.470 3743.43 3810.13 1206.18 S 724.18 W 5998785.79 N 565188.97 E 0.301 1397.24 4227.90 24.820 213.200 3828.50 3895.20 1240.57 5 746.36 W 5998751.20 N 565167.09 E 1.884 1437.71 4320.39 24.850 213.410 3912.43 3979.13 1273.04 S 767.69W 5998718.54 N 565146.05 E 0.101 1476.08 4412.99 23.220 215.750 3997.00 4063.70 1304.105 789.07 W 5998687.30 N 565124.94 E 2.039 1513.18 ~~ 4507.17 22.520 214.600 4083.78 4150.48 1334.01 5 810.16 W 5998657.20 N 565104.12 E 0.882 1549.12 4600.61 20.250 215.470 4170.78 4237.48 1361.925 829.71 W 5998629.12 N 565084.82 E 2.453 1582.59 4693.81 18.930 216.420 4258.58 4325.28 1387.225 848.04 W 5998603.66 N 565066.71 E 1.457 1613.19 4786.99 18.470 214.720 4346.85 4413.55 1411.51 5 865.43 W 5998579.21 N 565049.54 E 0.765 1642.48 4880.37 18.320 214.130 4435.45 4502.15 1435.82 5 882.08 W 5998554.76 N 565033.10 E 0.256 1671.49 4887.28 18.240 213.800 4442.02 4508.72 1437.62 S 883.30 W 5998552.95 N 565031.90 E 1.893 1673.63 4957.00 18.240 213.800 4508.23 4574.93 1455.755 895.43 W 5998534.71 N 565019.93 E 0.000 1695.15 Projected Survey -- -- .~.~--_._---- 22 July, 2002 - 9:58 Page 3 of ., DrillQuest 2.00.08.005 Sperry-SUR .. SurveyR.,.. Your.Ifef:.AIJít, . Job No. AKMW2!097, S. . BP EXPLORATION (ALASKA) INC. Milne Point Unit BPXA Milne Point MPS All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Welt. ,-- The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 204.270° (Truè). -, Based upon Minimum Curvature type calculations, at a Measured Depth of 4957.00ft., The Bottom Hole Displacement is 1709.1 Oft., in the Direction of 211.596° (True). Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) Comment 173.30 4957.00 173.28 4574.93 0.36N 1455.75 S 2.04W 895.43 W Interpolated A'Z. Projected Survey Survey tool program for MPS-13 MWD .- From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 4957.00 4574.93 MWD Magnetic . ~"-----"----'-"------ 22 July, 2002 - 9:58 Page 4 0'4 DrillQuest 2.00.08.005 qOd-II<-! 22-Jul-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPS-13 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , M D (if applicable) 4,957.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED flit? :: 2002 vU,- (.... v Alaska Oil & Gas Cons. Commission Anchorage . 4~ÌALASKA) INcPEF"N T VE BP EXPLORA d i "- Milne point ftfIIIs.. Job No. AKZZ22091, SuWfJ ld: 21 June, 2002 "t.'..13 -,~ -~' ~ SURvei~'.PORT 22 JulY,-'-' Your Ref: API , Surface Coordinates: 5999998.31 N, 565902.""'" 24' 31."6S8 N, 149027' 48.1368" W) Kelly Bushing: 66. 70ft aboveAfean Sea Level ,~ ',-. "'UIX'-il"'II~ D lit) L L. ì N~ ~',', <'tftlVIC.'; A HaItltMton Company Survey Ref: svy10128 . BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coord I,... Global' Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eutlnp Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) '"-, 0.00 0.000 0.000 -66.70 0.00 O.OON O.COE 5999998.31 N 565902.48 E 0.00 AK-6 BP _IFR-AK -c 173.30 1.370 280.010 106.58 173.28 0.36 N 2.04W 5999998.65 N 565900.44 E 0.791 0.51 Interpolated Az. 230.29 1.790 280.960 163.55 230.25 0.65N 3.59W 5999998.93 N 565898.89 E 0.738 0.88 319.82 2.080 221.600 253.04 319.74 0.308 6.04W 5999997.96 N 565896.45 E 2.158 2.76 408.60 3.650 162.580 341.72 408.42 4.208 6.26W 5999994.05 N 565896.26 E 3.531 6.41 497.65 5.550 154.880 430.48 497.18 10.81 8 3.58W 5999987.47 N 565898.99 E 2.239 11.33 586.81 7.430 163.870 519.07 585.77 20.25 S 0.15W 5999978.06 N 565902.51 E 2.391 18.52 677.63 9.170 172.510 608.94 675.64 33.07 8 2.42& 5999965.26 N 565905.20 E 2.352 29.15 768.29 10.160 173.570 698.31 765.01 48.18 S 4.28E 5999950.17 N 565907.17 E 1.109 42.17 863.49 10.000 179.840 792.04 858.74 64.79 S 5.226 5999933.57 N 565908.28 E 1.164 56.91 956.75 10.200 192.300 883.87 950.57 80.95 S 3.491 5999917.39 N 565906.68 E 2.348 72.37 1050.57 12.140 204.540 975.92 1042.62 98.05 S 2.38'W 5999900.24 N 565900.96 E 3.255 90.36 1143.90 13.730 207.450 1066.88 1133.58 116.81 S 11.56 W 5999881.41 N 565891.95 E 1.841 111.23 1236.62 14.550 207.960 1156.79 1223.49 136.86 S 22.10 W 5999861.26 N 565881.59 E 0.895 133.84 1331.02 15.330 210.270 1248.00 1314.70 158.11 S 33.95 W 5999839.91 N 565869.93 E 1.039 158.09 1424.13 15.410 209.520 1337.78 1404.48 179.50 S 46.25 W 5999818.40 N 565857.82 E 0.230 182.65 1517.58 15.720 210.790 1427.80 1494.50 201.18 S 58.84 W 5999796.62 N 565845.41 E 0.493 207.59 1610.04 19.060 212.720 1516.02 1582.72 224.65 S 73.42 W 5999773.02 N 565831.05 E 3.665 234.97 - 1702.63 19.550 213.780 1603.41 1670.11 250.25 S 90.21 W 5999747.28 N 565814.49 E 0.651 265.21 1796.75 22.760 216.120 1691.17 1757.87 278.05 S 109.70 W 5999719.30 N 565795.24 E 3.526 298.57 1889.35 24.210 217.520 1776.10 1842.80 307.58 S 131.82 W 5999689.58 N 565773.38 E 1.678 334.58 1984.85 26.500 215.750 1862.40 1929.10 340.41 S 156.20 W 5999658.54 N 565749.29 E 2.526 374.53 2077.58 29.030 215.540 1944.45 2011.15 375.51 S 181.37 W 5999621.21 N 565724.43 E 2.730 416.87 2170.66 29.390 215.980 2025.69 2092.39 412.37 S 207.92 W 5999584.12 N 565698.21 E 0.450 461.39 2263.81 29.880 215.790 2106.65 2173.35 449.69 S 234.91 W 5999546.57 N 565671.54 E 0.536 506.50 2358.18 31.790 214.090 2187.68 2254.38 489.35 S 262.60 W 5999506.66 N 565644.21 E 2.224 554.03 2447.89 31.330 212.810 2264.12 2330.82 528.52 S 288.48 W 5999467.27 N 565618.68 E 0.906 600.38 2544.38 32.060 212.110 2346.22 2412.92 571.30 S 315.68 W 5999424.25 N 565591.85 E 0.847 650.56 2638.45 30.540 212.560 2426.60 2493.30 612.59 8 341.82 W 5999382.73 N 565566.08 E 1.635 698.95 2731.55 31.280 212.250 2506.48 2573.18 652.97 8 367.45 W 5999342.13 N 565540.81 E 0.813 746.29 -~~--- 22 July, 2002 - 10:09 Page 2 0'4 DrillQlIest 2.00.08.005 . SP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Cootdlnlt.. Global Coordinate. Dogleg Vertical Depth Inel. Azlm. Depth Depth Northing. Entin". Northing. Ea.tlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) '-.. 2826.07 29.230 212.840 2588.12 2654.82 693.11 S 393.06 W 5999301.75 N 565515.55 E 2.192 793.42 2919.21 29.760 214.070 2669.19 2735.89 731.37 S 418.34 W 5999263.28 N 565490.61 E 0.864 838.68 3012.59 30.120 214.370 2750.11 2816.81 769.91 S 444.55 W 5999224.51 N 565464.74 E 0.418 884.59 3105.91 28.810 213.430 2831.35 2898.05 808.00 S 470.16 W 5999186.19 N 565439.47 E 1.489 929.84 3199.83 29.800 212.450 2913.25 2979.95 846.58 S 495.15 W 5999147.39 N 565414.82 E 1.171 975.28 3293.85 30.660 212.680 2994.49 3061.19 886.47 S 520.63 W 5999107.28 N 565389.69 E 0.923 1022.12 3386.99 28.770 211.290 3075.38 3142.08 925.62 S 545.10 W 5999067.91 N 565365.57 E 2.160 1067.87 3480.55 28.660 209.850 3157.43 3224.13 964.32 S 567.98W 5999029.01 N 565343.05 E 0.749 1112.54 3573.84 25.650 211.350 3240.43 3307.13 1000.98 S 589.60 W 5998992.17 N 565321.73 E 3.309 1154.86 3667.25 25.230 212.020 3324.78 3391.48 1035.12 S 610.68 W 5998957.84 N 565300.96 E 0.545 1194.65 3760.77 25.720 211.960 3409.21 3475.91 1069.24 S 631.99 W 5998923.54' N 565279.95 E 0.525 1234.51 3854.28 26.070 211.420 3493.33 3560.03 1103.99 S 853.44W 5998888.60 N 565258.81 E 0.451 1275.00 3947.55 26.190 211.930 3577.07 3643.77 1138.95 S 675.01 W 5998853.45 N 565237.55 E 0.273 1315.74 4040.97 26.690 212.610 3660.72 3727.42 1174.12 S 697.22 W 5998818.09 N 565215.65 E 0.626 1356.93 4133.50 26.570 212.440 3743.43 3810.13 1209.08 S 119.52 W 5998782.92 N 565193.66 E 0.154 1397.97 4227.90 24.820 213.240 3828.49 3895.19 1243.48 S 141.70W 5998748.34 N 565171.78 E 1.890 1438.44 4320.39 24.850 213.360 3912.43 3979.13 1275.94 S 763.03 W 5998715.68 N 565150.74 E 0.063 1476.81 4412.99 23.220 215.450 3997.00 4063.70 1307.07 S 784.32 W 5998684.37 N 565129.72 E 1.986 1513.93 4507.17 22.520 214.330 4083.78 4150.48 1337.09 S 805.26 W 5998654.17 N 565109.05 E 0.875 1549.91 4600.61 20.250 215.050 4170.78 4237.48 1365.11 S 824.64 W 5998625.98 N 565089.92 E 2.446 1583.41 4693.81 18.930 216.020 4258.58 4325.28 1390.54 S 842.79 W 5998600.39 N 565071.99 E 1 .459 1614.06 4786.99 18.470 214.400 4346.84 4413.54 1414.94 S 860.02 W 5998515.83 N 565054.98 E 0.745 1643.39 4880.37 18.320 213.390 4435.45 4502.15 1439.40 S 876.46 W 5998551.23 N 565038.16 E 0.377 1672.44 4887.28 18.240 213.410 4442.01 4508.71 1441.21 S 817.65 W 5998549.41 N 565037.58 E 1.161 1674.58 4957.00 18.240 213.410 4508.23 4574.93 1459.43 S 889.66 W 5998531.09 N 565025.73 E 0.000 1696.13 Projected Survey ~~-----.-~,,~ -~-- ~-------~- . 22 July, 2002 - 10:09 Page 3 of4 DrlllQllest 2.00.08.005 Sperry-Stili Survey Your 1fW: Job No. AKZZftØ'7,:'-: . BP EXPLORATION (ALASKA) INC. Milne Point Unit BPXA Milne Point MPS All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are rélative to Well. \..." The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 204.270° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 4957.00ft., The Bottom Hole Displacement is 1709.22ft., in the Direction of 211.366° (True). Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) Comment 173.30 4957.00 173.28 4574.93 0.36N 1459.435 2.04W 889.66 W Interpolated AZ. Projected Sut'Vly '- Survey tool program for MPS-13 -,- From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 4957.00 4574.93 AK-6 BP _IFR-AK __.__0___."--- 22 July, 2002 - 10:09 Page4of4 DrlllQuest 2.00.08.005 08/21/02 Schfumbel'ger NO. 2343 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay -' Well Job# Log Description Color Date Blueline Sepia Prints CD 06/25/02 2 07/01/02 2 07/02/02 2 08/05/02 2 07/06/02 2 07/23/02 1 07/28/02 1 MPL-32 } <11- 0 to ~ MPS-11 dO~" /1~' MPS-13 a(')d,-Il PSI-01 ~O ~ - I t./ - D.S.18-09B /9~-Oï CJ C-16 l:t 0 - 0 /0 W-20 I ~'X'.. Oÿ~ 22374 SCMT 22371 SCMT 22375 SCMT 22373 US IT 22370 SCMT 22359 RST-SIGMA 22361 RST-SIGMA "- Date Delivered: RECEIVED AlJG .Be 2002 Alaska 0:1 & Gas Cons. Commission Anchorage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Receive& ~pA~ ~ Wú,^A- 1/1/01..- (' STATE OF ALASKA ( ~'1g/~'2- ALASKA OIL AND GAS CONSERVATION COMMISSION ÐCJ:J ?/o'? APPLICATION FOR SUNDRY APPROVAL 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 0 Suspend 0 Plugging 0 Repair Well 0 Pull Tubing 0 Operation Shutdown 0 Re-Enter Suspended Well 5. Type of well: 0 Development 0 Exploratory 0 Stratigraphic II Service 0 Time Extension II Perforate 0 Variance II Other 0 Stimulate Completion of Well 6. Datum Elevation (DF or KB) KBE = 66.7' 7. Unit or Property Name Milne Point Unit 1. Type of Request: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 4. Location of well at surface 3330' NSL, 107' WEL, SEC. 12, T12N, R10E, UM At top of productive interval /19711 NSL, 927' WEL, SEC. 12, T12N, R10E, UM At effective depth 1873' NSL, 995' WEL, SEC. 12, T12N, R10E, UM At total depth 1870' NSL, 997' WEL, SEC. 12, T12N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8. Well Number MPS-13i '" 9. Permit Number 202-114 1 O. API Number 50- 029-23093-00 11. Field and Pool Milne Point Unit / Schrader Bluff 4957 feet 4575 feet" 4948 feet 4566 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 80' 4921' 20" 7" 260 sx Arctic Set (Approx.) 1104 sx PF 'LI, 361 sx Class 'G' 112' 4949' 112' 4567' Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) None 13. Attachments 181 Description Summary of Proposal 0 Detailed Operations Program Alaska on & CCìmmis;¡~j(Jn Anchoraaa 0 BOP Sketch Packers and SSSV (type and measured depth) None 14. Estimated date for commencing operation August 22, 2002 16. If proposal was verbally approved 15. Status of well classifications as: 0 Oil 0 Gas 0 Suspended Service Water Injection Name of approver Date Approved Contact Engineer Name/Numbør: Robert Odenthal, 564-4387 17. I hereby certify thaflhe ~~~¡,g is, t, rue and, co~recýbJ the best of my knowledge Signed Robert Odenth¡ f)-¿)~-S: IA.-~ Title Drilling Engineer Prepared By Name/Number: Sondra Stewman, 564-4750 Date Conditions of Approval: Notify Commission so representative may witness Plug integrity - BOP Test L Location clearance - Mechanical Integrity Test X- Subsequent form required 10- '107 Mi: T) Cwt-t ~~tz. bJ~ tt'flAA'~ J > Approved by order of the CommIssion oßo/nat ~, '6', 1t.,,', . I L Form 10-403 Rev. 06/15/88 CammyOechrT~'~ {~ . ",/i\ILJ Approval No. 3lJd-d50 ~,%'f- ì50PE 10 Š500rft~Þ~ Commissioner Date ~ 91. 'tl# Submit l'{Iff" licate (' 8-13 1. MIRU N4ES. /' 2. NO Tree. NU BOP. There are no open perfs in the well. 3. RIH to -2000' md and displace out"diesel to kill weight brine. 4. Pressure test casing to 3500 psi. / 5. RIH and perforate using e-line conveyed guns. Intervals (Ref SCMT log dated 7/2/02) 4572' - 4587' md (OA sand) 4632 '- 4647' md (OB sand) Guns 3-3/8" HSO, 6 spf, 60 deg phasing, 34B HJ II, ROX (21.9" pen, 0.40" eh) 6. RIH with bit and scraper to TO to condition hole for completion. 7. Run the dual 2-3/8" completion as per attached schematic (top packer at -4540' md, bottom packer at -4600' md.) 8. NO BOP. NU dual 2-1/16" 5M Tree. 9. Freeze protect the well and RDMO. \ Tree:4 1/16" Wellhead: 20" X 11 "FMC dual string Gen 6 WI 7" full bore installed 20"x 34" insulated, 215 #/ft A-53 Œ] KOP @300' Max. hole angle = 32 degree @ 2540' Hole angle thru perfs = 20 degree 7" 26#, L-80, BTRC Casing (drift 10 = 6.151, cap.= .0383 bpf) Perforation Summary Size Spf Interval MPU S-13i A 750' of diesel 10.4# Brine (TVD) ~ ~ DATE 6/22/02 REV. BY MOO COMMENTS Drilled and Cased Doyon 141 ( Orig. DF Elev. = 66.70 Orig. GL Elev. = 39.20 7" Halliburton Float Collar I 4,866' I 7" Halliburton float shoe I 4,949' I MILNE POINT UNIT WELL No.: S-13i API: 50-029-23093-00 BP EXPLORATION (AK) OA Perfs 4572- 4587' md M , 1,'..- I' '~ . 'I J{ '~ ,,. I'." .~ : 1- : J: '2 ; IIf ~ t ., j¡ ~.j j ''J ;¡¿ 't '\ 't v i ~~ . > J OS Perfs - 4632- 4647' md - ...- Proposed -MPS13 La' string completion ~ 2-3/8" 'X' nipples (set at - 2200' md) 2-3/8" 4.7# L80 1ST tubing strings 7" x 2-3/8" Saker GT dual packer (set at - 4540' md) 2-3/8" 4.7# L80 1ST pup jt (-10') 2-3/8" 'X' nipple with 1.875" no-go 2-3/8" 4.7# L80 1ST pup jt (-10') Re-entry guide 7" x 2-3/8" Saker FH packer (set at -4600' md) 2-3/8" 4.7# L80 1ST pup jt (-10') 2-3/8" 'X' nipple with 1.875" no-go 2-3/8" 4.7# L80 1ST pup jt (-10') Re-entry guide 2-3/8" Dual Strings with dedicated OA and 08 injection. Note to File Well MPS-13i PTD 202-114 Sundry 302-250 The Area of Review around well MPS-13i was checked by H. Okland and W. Aubert on 8/8/02. AOGCC's GeoFrame planimeter measurement function was calibrated in feet. No wells in the AOGCC GeoFrame database pass within one quarter mile of MPS-13i's injection interval. iN (,A- JJ {/(-I ð L Winton Aubert Petroleum Engineer ~.~ -- U':J '"'I( ot4000 .::-J... .6 M PS..'" ~~ 1 i ~!5000 ~ (iOOG 7 10<-3. 1 .lOOO H-..(i7 42~ H .." Oi3A 6894,1, ) 1'1...0(3 ~ H,...(j:';\ ~. tv1 F)':::. ,. 1::;;11 \1 ..-.~, ~~fÆ~E :} !Æ~!Æ~~~!Æ / ! ,. l I ! / AIfASIiA. OIL AND GAS í CONSERVATION COMMISSION í í TONY KNOWLES, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Milne Point Unit MPS-13i BP Exploration (Alaska), Inc. Permit No: 202-114 Surface Location: 3330' NSL, 107' WEL, Sec. 12, T12N, R10E, UM Bottomhole Location: 2200' NSL, 847' WEL, Sec. 12, T12N, R10E, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, & ~,j~t~ ca~echsli Tayl& Chair BY ORDER OF THE COMMISSION DATED this~ day of June, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALAS~, STATE OF ALASKA . JIL AND GAS CONSERVATION CO~SSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil II Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Planned KBE = 68' Milne Point Unit / Schrader 6. Property Designation Bluff ADL025627 7. Unit or Property Name Milne Point Unit 8. Well Number MPS-13i 9. Approximate spud date 06/25/02 ' Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 5020' MD /4661' TVD 0 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 36 Maximum surface 1480 psig, At total depth (TVD) 4314' / 1911 psig Setting Depth T OD Bottom Lenath MD TVD MD TVD 80' Surface Surface. 112' 112' 4990' Surface Surface 5020' 4661' ~~ '5/;1/0 1- 0þ- b/3 1 a. Type of work. Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3330' NSL, 107' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 2311' NSL, 773' WEL, SEC. 12, T12N, R10E, UM At total depth 2200' NSL, 847' WEL, SEC. 12, T12N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 380109, 847' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade CouDlina 20" 92# H-40 Welded 7" 26# L-80 BTC 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Hole 42" 9-7/8" Quantitv of Cement (include staae data) 260 sx Arctic Set (Approx.) 1123 sx PF 'L', 361 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Su rface Intermediate Production Liner Length Size Cemented MD TVD R.ECEI ED ~v¡ A\I '7 t'\ ') Of]? ! W'U \.) \.) '" I"j V (.,. Perforation depth: measured Alaska Oil & Gas Cons. Commission Anchorage true vertical . Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch. Drilling Program . Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Matt Green, 564-5581 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby certify that and correct to the ~:eOf ;:n~;;;n~ Enginee~'g~~;;~';'i¿r' ?~~:.:,f¿::t( ~;~, ., Permit Number (j API Number A"p~at1'Rt~ See cover letter :zð¿- // / 50- 0.2-9- 2.3 CJ 93 \-f ') ()(ì) for other reQuirements Conditions of Approval: Samples Required 0 Ves B No Mud Log Requir dOVes S No Hydrogen Sulfide Measures 0 Ves 9 No Directional Survey Required gVes 0 No Required Worki2Q Pressure for ~OPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: Si.tb"-<A. t ~/~tit:r- plfM4'.:. ,-,^"" k;/r M. I () - L/t)~ . JlIL)- i ,,~i\.b 1LUt. (.¿ J-;- ¿, t! y.t'Ôu..( N d . by order of ! () / L ! :~:O~~~ Rev. 12-0~;=~:kJr ~ J 0",' e>1")~io~r; the commission Date l{.J,~~riPlicate ~ ~ '\ ili Ii""."",.' 20. Attachments ( IWell Name: MPS-13i Drill and Complete Program Summary Schrader St' ~~ S-Pad Program MPS-13i Permit I Type of Well (service I producer I injector): I S-Shaped Injector ./ Surface Location: 1949' FNL, (3330' FSL), 107' FEL, (5172' FWL), SEC. 12, T12N, R10E X=565,902.93 Y=5,999,998.37 2968' FNL, (23111 FSL), 773' FEL, (4506' FWL), SEC. 12, T12N, R10E X=565,246 Y=5,998,974 l=4,193 TVDss 3080' FNL, (2200' FSL), 847' FEL, (4432' FWL), SEC. 12, T12N, R10E X=565, 173 Y=5,998,862 Z = 4,594 TVDss Target Start Location: "OA" Bottom Hole Location: I AFE Number: 1 MSD337287 I I Estimated Start Date: I 06/25/02 I MD: 15,020 I 1 TVD: 14,661 I I RiQ: I Doyon 141 / I Operating days to complete: 16.6 / I Max Inc: 136 1 I KOP: 1300 I I I I KBE: 168 I I I 1 Well Design (conventional, slimhole, etc.): I Conventional Grass Roots Injector I Objective: I Schrader "NB", "OA", "OB" & "OBD" Mud Program 9.875-in Production Hole Mud Properties: Density (ppg) Funnel visc YP HTHP 8.6 - 9.20 ¡ 75 -150 25 - 60 N/A LCM Restrictions: None Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. Spud - LSND Freshwater Mud pH API Filtrate LG Solids 9.0 - 9.5 < 8 < 6.5 Cement Program Casing 7.0-in 26-lb/ft L-80 BTC surface casing Size / Basis 250% excess over gauge hole in permafrost interval, 400/0 excess over gauge hole below permafrost. Top of tail cement 500-ft TVD above top of N-sand. Total Cement Wash 20-bbl Water Spacer Vol: 905-bbl Spacer 50-bbl Viscosifi.~d Spacer (Alpha Design) weighte,Ø to 10.5-lb/gal Lead 830-bbl, 1123~sx 10.7-lb/gal Class L - 4.15 ft::i/sx/ (cement to surface) / Tail 74-bbl, 361 ~x 15.8-lb/gal Prem G - 1.15 fe/sx (top of tail at 7,480-ft MD) Temp 1 BHST == 85°F from SOR, BHCT 85°F estimated by Halliburton 1 ( M(' 'Point MPS-13 Well Proaram Evaluation Program 9.875-in Hole Section: Open Hole: MWD/GRlRES/PWD IFRlCASANDRA Cased Hole: SCMT (post rig) . Formation Markers Formation Tops M Orkb TVDrkb TVOss Pore Pressure Estimated EMW (ft) (ft) (ft) (psi) (ppg)* Base Permafrost 1818 1818 1750 788 Top Ugnu 3874 3618 3550 1598 8.65 NA 4447 4120 4052 1823 8.65 NB 4473 4144 4076 1834 8.65 NC 4507 4175 4107 1848 8.65 NF 4567 4231 4163 1873 8.65 Top OA 4599 4261 4193 1887 8.65 Base OA 4628 4288 4220 1899 8.65 Top OB 4656 4314 4246 1911 8.65 Base OB 4681 4338 4270 1922 8.65 Top OBO 4805 4455 4387 1974 8.65 Base OBO 4872 4519 4451 2003 8.65 TO 5020 4661 4593 2067 8.65 OWC * Based on 55 depths CasingITubing Program Hole Size Csg/ WtlFt Grade Conn Length Top Bottom Tbg O.D. MD / TVDrkb MD / TVDrkb 42-in 20-in* 92# H-40 Welded 80' 0' 112' / 112' 9.875-in 7.0-in 26# L-80 BTC 4,990' 0' 5,020' / 4,661' / * The 20-in conductors are insulated! Recommended Bit Program BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 9.875-in O'-TO Hughes MXC-1 3-15 & 1-1 0 2 ~( ~ Point MPS-13 Well ProQram Well Control: Production hole will be drilled with a diverter. . Maximum anticipated BHP: 1 ,911-psi @ 4,314-ft TVDrkb - Top of "OB" . Maximum surface pressure: 1 ,480-psi @ surface ./ (Based on BHP and a full column of gas from TD @ O.1-psi/ft) . Planned BOP test pressure: Function test diverter . Kick tolerance: N/ A . Planned completion fluid: 10.0-lb/gal brine /7.0-lb/gal Diesel (2,000-ft MD) Drilling Hazards & Contingencies: Hydrates . Hydrates have not yet been seen on S pad, but have been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur just below the permafrost (+/- 1 ,800-ft TVDss) but may be present in shallower SV sands and also as deep as 3,000-ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates. . Watch out for deeper gravels below the permafrost or gravels that calve off within the permafrost and tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past, several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation . Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. We do not expect losses while drilling this well. . MPS-27: Lost returns cementing 7.0-in casing at approx. 800-ft MD. SuccessfuI1.0-in top job. . MPS-21: Lost returns cementing 7.0-in casing. Used TAM port collar at 1 ,OOO-ft with still no returns. SuccessfuI1.0-in top job. . H-06 (1995): Lost 100-bbl running 9-5/8" casing, good returns during cementing except no returns for last 20-bbl, contaminated cement to surface, cement 12 ft down, no top job. . H-05 (1995): Lost returns drilling at 5,360-ft (3,700-ft TVD), 40-bph to keep full, treated w/ LCM pills for two days, total losses 838-bbl, made hole opener run with some continued losses. . H-05 (1995): Ran 9-5/8" casing, lost 46-bbl conditioning mud. . H-07 (1995): Lost 50-bbl running 9-5/8" casing. . E-24 (1998): Made hole opener run, worked tight spots 1965, 2620, 3465, 5900 and 6000, lost 72-bbl while circulating. . H-08A (1997): Had some minor losses while running 4-1/2" liner. 3 Nf'" 1 Point MPS-13 Well ProQram . Follow the LOST CIRCULATION DECISION MATRIX in the well program if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures . It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (8.65 Ib/gal EMW). In this well, the Schrader Bluff formation will be drilled with 9.1 to 9.2-lb/gal mud. / . There is a possibility of overpressure from MPE-29i and MPH-11 via transmissive faults. However, MPS-15 was drilled into the same fault block and was normally pressured. . Flow-check the well when the reservoir is entered. Pad Data Sheet . Please Read the S-Pad Data Sheet thoroughly. Breathing . N/A Hydrocarbons . Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Free Gas may be encountered below the Upper Ugnu. ' Faults . No faults are predicted to be crossed along the well trajectory. . The well will be drilled into the graben between two faults. Hydrogen Sulfide . Milne Point S-Pad is not designated as an H2S Pad. // Anti-collision Issues . None, except for consideration of planned wells. Integrity Testing ,/ . Will be drilled on diverter and no FIT/LOT is required. 4 ( ~ DRILL & COMPLETION PROCEDURE 1 Point MPS-13 Well ProQram DrillinQ 5. 6. / MIRU Doyon 141, NU diverter. Drill 9.875-in hole to TO as per directional plan. Obtain sidewall cores from reservoir sands. Rig up and run 7.0-in 26-lb/ft, L-80, BT&C casing to total depth and cement in place. ,,/ Install tubing head and Christmas tree. RD Doyon 141. 1. 2. 3. 4. 5 Field: Milne Point Well: MPS-13 DIRECTIONAL LWD OPEN HOLE LOGGING NONE NONE MWD/GRlRES IFRlCAS PWD NONE 28-5-2002 { BP EXPLORATION Milne Point Unit MPS.13 Actual Surface Location: 1949' NSL & 5172' FWL Bottom Hole Location: 3080' FSL & 4432' FWL Status: Not Drilled ( ENG: Steve Campbell, Matthew Green RIG: Doyon 141 RKB: 68-ft FORM DEPTH HOLE CASING MUD INFO MD I TVD SIZE SPECS PIT INFO INFORMATION Wellhead Permafrost 20" 92# H-40 FMC Gen 620" x 11" 5M Welded 112' 112' 42 Insulated 250 % Excess Permafrost 40 % Excess Top of Tail Cement Top of N sand OA sand OB sand Total Depth 1,942' 1,822' 3,947' 97/8" Hughes MXC-1 4,447' 4,119' 4,598' 4,259' 4,654' 4,312' 5,020' 4,661' Production Casing 7" 26# L-80 BT&C 6.276-in ID Lead Cement Volume 641.8 bbl 868 Sacks KOP @ 300' EOB @ 2858' AA=36 VS=286' Cement to Surface 189.0 bbl Tail Cement Volume 73.9 bbl 360 Sacks SOD @ 3782' EOD @ 5020' AA=17 VS=1350' MW = 9.2 MPS-13 Well Plan Schematic.xls ( ,-T---'--ì I I r ï I I L J 1 I I I +33 ~, .31 i ..¡ I 829i 1 I .27 I I' t~i 1 I 8211 1 L J I 1 I .1Si I I- 4-MPS-13i..¡ -- I . g¡ I -r- . 7i I I ----- -1-~C7' l' -.. - r- -, I St :¿ ì¡ ¿ I .CT "7 i¡----AJ. R10£ I I ZN . R71t I-- I I I >-1 ~ ~ I ~I~/}' --'-' - - _I... - - L - ..:..- :L J ... ~ /- /1 I -Z--: I PLANT . ) 1 ~.OO'OO" CRID MPU S-PAD CI <. 7' 'c, ;:¡ ... N S ~ .. ... '" 0- .~ ~ 1 ( CI IS 21 1-J;AQ T1 ,3N I':¿N 2 _/IIo ..7.8 ( -. '~ -- -~~- 31 'or 31~\ ,.~" , 33 1 ~ ~ ' ~===rk~-- e:. ECT3 S-:::>AO AREA ,;) 7 Ij /) 10 -- ...- 1\ 14 W"'¡ e :~ ~ 18 tt:tt: 15 1 J 16 VICtNITY MAP N.T.S. LEGEN"D + AT-SiAKED CONDUCTOR (THIS SURVEY) . EXISTING CONDUCTOR .. AS-SiAKED CONDUCTOR (PREVIOUS) UW A"'" JJC O'EC'((I) LOH ~~. .i¡Ÿ;;:- ORI'V I"G FRB02 Io4PS 13-01 JõØNO - ':ÇAII. 1". 200' ~ " ! LOCATED WITHIN PROTRACTEO SEC. 12, T. 12 N.. R. 10 E.. UMIAT MERIDIAN, ALASKA wË:LL A.S.P. PLANT GEODETIC GEODETIC GROUND SEëTlON- NO. COORDINA T.ES COORDINA TES POSI~.ON(DMS) POSITION(D.DD) ELEVATION OFFSETS MPS-1.3' Y=5.999,998.37 N;: 2.237,00 70'241'37.567" 70.41041.353. 38.6' 3,.:331: FSL I x= 5?5,902.93 E= 6.779.00 149"27'48.123" 1A.9A63367S. 107 FEl ._~-- Obp MILNE POINT UNIT S-PAD AS-STAKE: CONDUCTOR MPS-13i ~EET. 101'1 NO-rES: 1, DATE OF' SURVEY; APRIL 15, 2002. 2. REFERENCE tlElD BOOK: MP02-04 PAGES. A.2-4-4. ~. COORDIN A TES ARE ALASKA STATE PLANE ZONE 4. NAD-27. 4, GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS 0.999904923. 6. HORIZONTAL CONTROL IS BASED ON MPU CFP MONUMENT CFP-3 AND MPU ~....PAO MONUMENT H...1. 7, ELEvATIONS ARE BPX MEAN SEA LEVEL BASED ON MILNE ÞOINt PIPELINE VJ;:RTICAL CONTROL. ~ r. ... ~, .... ~ ~ ¡ ~ ~_........ ~ -- ~ ~ ~..- ~ .,,-" ~.~ 4/~~:'2 IS'M:O '~_~~II.l1OH f. R, 0. bell.' L -- ~ ~ -~ ~ , ~ .........-- -- Ë1~o JJC lOH ~ -.- -.... - N' <t' '~<tII t£"t ny Nit -.. ...~... ~I 186-~ ZOO/ZOO'd l88-! 9909-699-106+ 9 9NIM :J:ri-WOJ~ 9Z:9l ZOOZ-8l-Jd' 800 1600 ~ ~ 0 0 ~ t ö ] 2400 '€ >- ë E- 3200 4000 4800 bp REFERENCE INFORMATION COMPANY DETAILS BP Amoco Co-ordinate (NIE) Reference: Wen Centre: Plan MPS-I3, Tnæ North Vertical (fVD) Reference: S-pad D-141 66.40 Section (VS) Reference: SloI - (O,ooN,O,ooE) Measured Depth Reference: S-pad D-141 66.40 Calculation Method: Minimum Curvature Calculation Method: Miuimwn Curvature Error System: ISCWSA Scan Method: T ray Cylinder North En-of Surface: Elliptical + Casing WarninR Method: Rules Based 0 A Start Dir 1.5/100' : 300' MD, 300'TVD ¿ End Dir : 700' MD, 699,82' TVD 4 1000 SURVEY PROGRAM Plan: MPS-13 Wp05 (plan MI'S-13/Plan MPS-I3) Toot Date: 4/26/2002 Depth Fm Depth To SmveyiPlan 27,60 1300,00 Planned: MPS-13 WpOS VI 1300,00 5020,45 Planned: MPS-13 WpOS VI FORMATION TOP DETAILS No. TVDPath MDPath Fonnation 1 1816.40 1816.58 BPRF 2 3616.40 3872.38 Ugnu 3 4119.40 4447.11 SBF2-NA 4 4143.40 4473.14 SBFI-NB 5 4174.40 4506.61 SBE4-NC 6 4230.40 4566.68 SBE1-NF 7 4259.40 4597.60 TSBD-OA 8 4286.40 4626.32 TSBC 9 4312.40 4653.93 TSBB-OB 10 4335.40 4678.33 SBA5 (base OB) 11 4453.40 4803.07 TOBD 12 4517.40 4870.45 BOBD All TVD depths are ssTVD plus 66.4'for RKBE. Start Dir4/100': 1950.18' MD, 1950'TVD /' 2000 50 \f)~ ISo End Dir : 2857,98' MD, 2798.22' TVD Start Dir 2/100' : 3781.69' MD, 3542,49'TVD /' \~ ~ "'" DITO.19"', '591.6' MD, "".'TVD \\v Total Depth: 5020,45' MD, 466054' TVD 5000 ~ 7" 0 800 I I 1600 I I 2400 Vertical Section at 213.180 [800ft/in] ~ 3900 s:: ~ 0 0 ~ t ö <a () '€ >- ë 4200 E- 3600 tart Dir 2/100' : 3781.69' MD, 3542.49'TVD MPS,13 OA 4500 900 Created By: Ken Allen Checked: Date: CB-GYRO-SS MWD+IFR+MS Reviewed: . Date: .. WELL DETAILS Name +NI.S 'EI-W Northing Easting ¡..Iitude Lougituœ Slot Plan MPS-13 2430 442,61 599999837 56590223 70"24'37568N 149"27'48,I44W NiA TARGET DETAILS Name TVD +NI..s +EI-W Northing Easting Shape MPS-13 OA 4259,40 -1018.64 -66531 5998974,00 565246,00 Cin:1c (Radius: 125) SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 27.60 0.00 0.00 27,60 0.00 0.00 0.00 0.00 0,00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 ~ 3 500.00 3.00 170.00 499.91 -5.16 0.91 1.50 170.00 3.82 4 700.00 0.00 0.00 699.82 -10.31 1.82 1.50 180.00 7.63 5 1950.18 0.00 0.00 1950.00 -10.31 1.82 0.00 0.00 7,63 6 2857.98 36.32 213.49 2798.22 -242.33 -151.69 4.00 0.00 285.84 7 3781.69 36.32 213.49 3542.49 -698.60 -453.56 0.00 0.00 832.92 8 4597.60 20.00 213.49 4259.40 -1018.64 -665.31 2.00 180.00 1216,66 MPS-130A 9 4870.45 17.95 213.49 4517.40 -1092.63 -714.26 0,75 180.00 1305.37 10 5020.45 16.83 213.49 4660.54 -1130.02 -739.00 0.75 180.00 1350.21 CASING DETAILS No, TVD MD Name Size 4660.53 5020.44 7" 7.000 SBF2-NA SBFI-NB SBE4-NC ~\o SBEI-NF \TSBD-OA Start Dir 0.75/100' : 4597,6' MD, 4259.4'TVD TSBC TSBB<)B SBA5 (base OB) \ - ::¡OBD TargetI25'RadiUS. Top OA to Base OBD. ~o \ WOD ~--~~ " / -"-~" ~- . »/:'~~><~' I /;/~ ~>~::-< .I / / fA/. .'~"'- -~,~ ',~ l / / f /-~ - -,-~-~ ", I / :/ / -~ "" "'" I / / --J I"-~ "-~-- I / /-"--, -~-~ I /.-.~ ~~~ """ I / "-- ~/ I I~ ~. 1200 I 1500 I 1800 -~ ~ ~ ~ '..,.. ~ , """tþ ~ "'ii ~~ "- Total Depth: 5020.45' MD, 4660,54' TVD Vertical Section at 213.18° [300ft/in] Æ <ï:: 0 ~ +' ~ ~ ~ 0 CIJ -1200 bp COMPANY DETAILS REFERENCE INFORMATION BP Amoco C(H)rdina'" (NÆ) Reference: Well Centre: Plan MPS-13, Tme North Vertical (IVD) Reference: S-pad 0-14166.40 Section (VS) Reference: Slot - (O.OON,O,OOE) Measured Deptll Reference: S-pad 0-141 66.40 Calculation Method: Minimum CUIV3.tu.re Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: T..v Cylinder North Error Surface: Elliptical + C$ing Warnit1 Z Method: Rules Based All TVD depths are ssTVD plus 66.4'for RKBE. 0 ,/"" Start Dir 1.5/100' : 300' MD, 3OO'TVD 3nd :::>ir : 700' MD, 699.82' TVD Stllrt Dir 411 00' : 1950.18' MD, 1950'TVD -300 End Oir : 2857.98' MD, 2798.22' TVD -600 3500 " Start :::>ir 2J100' : 3ï81.69' MD, 3542.49'TVD -900 -900 -600 -300 0 W est( - )/East( + ) [300ft/in] I 300 SURVEY PROGRAM Plan: MI'S-13 Wp05 (I'lan MPS-13/I'lan MI'S-13) Depth Fm Depth To SurveylPlan 27,60 1300.00 Planned: MPS-13 Wp05 VI 1300,00 5020,45 Planned: MPS.13 Wp05 VI Tool Dale: 4/26/2002 Created By: Ken Allen Checked: CB-GYRO-SS MWD+IFR+MS Dale: . Reviewed: WELL DETAILS Name +N/-S +E/-W Northing I.alitudc L(.) lgillltk Slot ¡",sting Pian MPS-13 2430 -442,61 599999837 56590223 70'24'37.568N 149'21'48,144W N/A TARGET DETAILS Name TVD +N!..s +FJ.W Northing ¡;asting Shape 565246,00 Cin:1c (Radius: 125) MPS-13 OA 4259,40 -1018,64 -66531 5998974,00 SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFace VSee Target 1 27.60 0.00 0.00 ~7,60 0.00 0.00 0.00 0.00 0.00 -~ 2 300.00 0.00 0.00 11111.00 0.00 0.00 0.00 0.00 0.00 3 500.00 3.00 170.00 "",91 -5.16 0.91 1.50 170.00 3,82 4 700.00 0.00 0.00 ,."'1,82 -10.31 1.82 1.50 180,00 7.63 5 1950.18 0.00 0.00 1'''''.00 -10.31 1.82 0,00 0.00 7.63 6 2857.98 36.32 213.49 ~7");.22 -242.33 -151.69 4.00 0,00 285.84 7 3781.69 36.32 213.49 ,hj~.49 -698.60 -453.56 0,00 0.00 832.92 8 4597.60 20.00 213.49 . ~ "'.40 -1018.64 -665.31 2,00 180.00 1216.66 MPS-13 OA 9 4870.45 17.95 213.49 oj'l 7.40 -1092.63 -714.26 0.75 180.00 1305.37 10 5020.45 16.83 213.49 4''''''.54 -1130.02 -739.00 0.75 180.00 1350.21 CASING DETAILS FORMATION TOP DETAILS No. TVD MD Name Size No, TVDPath MDPath Formation 4660.53 5020.44 7" 7.000 1 1816.40 1816.58 BPRF 2 3616.40 3872.38 Ugnu 3 4119.40 4447.11 SBF2-NA 4 4143.40 4473.14 SBFI-NB 5 4174.40 4506.61 SBE4-NC 6 4230.40 4566.68 SBEI-NF 7 4259.40 4597.60 TSBD-OA 8 4286.40 4626.32 TSBC 9 4312.40 4653.93 TSBB-OB 10 4335.40 4678.33 SBA5 (base OB) II 4453.40 4803.07 TOBD 12 4517.40 4870.45 BOBD ~ ~~ I Company: Field: Site: WeD: WeDpatb: Field: ( BP My Planning Report MAP ( Date: 4/2612002 Time: 15:48:22 Page: CtHrdinate(NE) Referenœ: Well: PlánMPS-13, True North Vertieal(TVD) Reference: S-'padD-141 66.4 Sedion(VS)Referenee: WeJt(0.ooN,O.00E.213.18Azi) Survey Caleulation Method: Minimum Curvature Db: BP Amoco Milne Point M PtS Pad Plan MPS-13 Plan MPS-13 Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: Map Zone: Coordinate System: Geomagnetic Model: M Pt S Pad Site Position: From: Map Position Uncertainty: Ground Level: 0.00 ft 0.00 ft Northing: 5999978.00 ft Latitude: Easting: 566345.00 ft Longitude: North Reference: Grid Convergence: Well: Plan MPS-13 Slot Name: Well Position: +N/-S 24.30 ft Northing: 5999998.37 ft Latitude: +E/-W -442.61 ft Easting: 565902.23 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: Plan MPS-13 Current Datum: Magnetic Data: Field Strength: Vertical Section: Plan: Principal: Yes S-pad D-141 6/29/2001 57460 nT Depth From (TVD) ft 0.00 MPS-13 Wp05 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Height 66.40 ft +N/-S ft 0.00 Date Composed: Version: Tied-to: Casing Points MD TVD ft ft 5020.44 4660.53 Formations MD ft 1816.58 3872.38 4447.11 4473.14 4506.61 4566.68 4597.60 4626.32 4653.93 4678.33 4803.07 4870.45 Targets Diameter in 7.000 Hole Size in 9.875 7" Name TVD ft 1816.40 3616.40 4119.40 4143.40 4174.40 4230.40 4259.40 4286.40 4312.40 4335.40 4453.40 4517.40 Formations Li~hology BPRF Ugnu SBF2-NA SBF1-NB SBE4-NC SBE1-NF TSBD-OA TSBC TSBB-OB SBA5 (base OB) TOBD BOBD Name Map Map TVD +N/-S +E/-W Northing Easting ft ft ft ft ft 4259.40 -1018.64 -665.31 5998974.00 565246.00 Description Dip. Dir. MPS-130A -Circle (Radius: 125) -Plan hit target Alaska, Zone 4 Well Centre BGGM2001 70 24 37.329 N 149 27 35.171 W True 0.51 deg 70 24 37.568 N 149 27 48.144 W Well Ref. Point 0.00 ft Mean Sea Level 26.28 deg 80.78 deg Direction deg 213.18 4/26/2002 1 From: Definitive Path Dip Angle deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Oracle Dip Direction deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 <.;...... ',' Latitude ,~ <-,- Longitude---'> DegMinSec DegMin S~ 70 24 27.549 N 149 28 7.642 W ( ( BP My Planning Report MAP Company: BP Amoco Date: 4/26/2002 Time: 15:48:22 Page: 2 Field: Milne Point Co--ordinate(NE).,Referenœ: Well: Plan MPS-13. True North Site: M Pt S Pad Vertical (fVD) Referenœ: S-pad 0-14166.4 I Well: Plan MPS-13 Section (VS) Referenœ: Well (0.OON,0.00E,213.18Azi) Wellpatb: Plan MPS-13 Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +EI..,W DLS Build Turn TFO Target ft deg deg ft ft ft degl100ft deg/100ftdegl100ft deg 27.60 0.00 0.00 27.60 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 3.00 170.00 499.91 -5.16 0.91 1.50 1.50 0.00 170.00 700.00 0.00 0.00 699.82 -10.31 1.82 1.50 -1.50 -85.00 180.00 1950.18 0.00 0.00 1950.00 -10.31 1.82 0.00 0.00 0.00 0.00 2857.98 36.32 213.49 2798.22 -242.33 -151.69 4.00 4.00 0.00 0.00 3781.69 36.32 213.49 3542.49 -698.60 -453.56 0.00 0.00 0.00 0.00 4597.60 20.00 213.49 4259.40 -1018.64 -665.31 2.00 -2.00 0.00 180.00 MPS-13 OA 4870.45 17.95 213.49 4517.40 -1092.63 -714.26 0.75 -0.75 0.00 180.00 5020.45 16.83 213.49 4660.54 -1130.02 -739.00 0.75 -0.75 0.00 180.00 Survey 27.60 0.00 0.00 27.60 -38.80 5999998.37 565902.23 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 33.60 5999998.37 565902.23 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 133.60 5999998.37 565902.23 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 233.60 5999998.37 565902.23 0.00 0.00 Start Dir 1.5/100' : 300' MD, 400.00 1.50 170.00 399.99 333.59 5999997.08 565902.47 0.95 1.50 CB-GYRO-SS 500.00 3.00 170.00 499.91 433.51 5999993.22 565903.18 3.82 1.50 CB-GYRO-SS 600.00 1.50 170.00 599.83 533.43 5999989.36 565903.90 6.68 1.50 CB-GYRO-SS 700.00 0.00 0.00 699.82 633.42 5999988.08 565904.14 7.63 1.50 End Dir : 700' MD, 699.82' TV 800.00 0.00 0.00 799.82 733.42 5999988.08 565904.14 7.63 0.00 CB-GYRO-SS 900.00 0.00 0.00 899.82 833.42 5999988.08 565904.14 7.63 0.00 CS-GYRO-SS 1000.00 0.00 0.00 999.82 933.42 5999988.08 565904.14 7.63 0.00 CB-GYRO-SS 1100.00 0.00 0.00 1099.82 1033.42 5999988.08 565904.14 7.63 0.00 CB-GYRO-SS 1200.00 0.00 0.00 1199.82 1133.42 5999988.08 565904.14 7.63 0.00 CB-GYRO-SS 1300.00 0.00 0.00 1299.82 1233.42 5999988.08 565904.14 7.63 0.00 MWD+IFR+MS 1400.00 0.00 0.00 1399.82 1333.42 5999988.08 565904.14 7.63 0.00 MWD+IFR+MS 1500.00 0.00 0.00 1499.82 1433.42 5999988.08 565904.14 7.63 0.00 MWD+IFR+MS 1600.00 0.00 0.00 1599.82 1533.42 5999988.08 565904.14 7.63 0.00 MWD+IFR+MS 1700.00 0.00 0.00 1699.82 1633.42 5999988.08 565904.14 7.63 0.00 MWD+IFR+MS 1800.00 0.00 0.00 1799.82 1733.42 5999988.08 565904.14 7.63 0.00 MWD+IFR+MS 1816.58 0.00 0.00 1816.40 1750.00 5999988.08 565904.14 7.63 0.00 BPRF 1900.00 0.00 0.00 1899.82 1833.42 5999988.08 565904.14 7.63 0.00 MWD+IFR+MS 1950.18 0.00 0.00 1950.00 1883.60 5999988.08 565904.14 7.63 0.00 Start Dir 4/100' : 1950.18' MD 2000.00 1.99 213.49 1999.81 1933.41 5999987.35 565903.67 8.50 4.00 MWD+IFR+MS 2100.00 5.99 213.49 2099.54 2033.14 5999981.51 565899.88 15.46 4.00 MWD+IFR+MS 2200.00 9.99 213.49 2198.55 2132.15 5999969.85 565892.31 29.37 4.00 MWD+IFR+MS 2300.00 14.00 213.49 2296.35 2229.95 5999952.42 565881.00 50.14 4.00 MWD+IFR+MS 2400.00 18.00 213.49 2392.46 2326.06 5999929.31 565866.00 77.69 4.00 MWD+IFR+MS 2500.00 22.00 213.49 2486.41 2420.01 5999900.64 565847.39 111.88 4.00 MWD+IFR+MS 2600.00 26.00 213.49 2577.75 2511.35 5999866.53 565825.26 152.54 4.00 MWD+IFR+MS 2700.00 30.00 213.49 2666.03 2599.63 5999827.17 565799.71 199.48 4.00 MWD+IFR+MS 2800.00 34.00 213.49 2750.82 2684.42 5999782.73 565770.87 252.45 4.00 MWD+IFR+MS 2857.98 36.32 213.49 2798.22 2731.82 5999754.73 565752.70 285.84 4.00 End Dir : 2857.98' MD, 2798.2 2900.00 36.32 213.49 2832.07 2765.67 5999733.86 565739.15 310.72 0.00 MWD+IFR+MS 3000.00 36.32 213.49 2912.65 2846.25 5999684.18 565706.91 369.95 0.00 MWD+IFR+MS 3100.00 36.32 213.49 2993.22 2926.82 5999634.50 565674.67 429.18 0.00 MWD+IFR+MS 3200.00 36.32 213.49 3073.80 3007.40 5999584.83 565642.43 488.40 0.00 MWD+IFR+MS 3300.00 36.32 213.49 3154.37 3087.97 5999535.15 565610.19 547.63 0.00 MWD+IFR+MS 3400.00 36.32 213.49 3234.94 3168.54 5999485.48 565577.95 606.85 0.00 MWD+IFR+MS 3500.00 36.32 213.49 3315.52 3249.12 5999435.80 565545.71 666.08 0.00 MWD+IFR+MS 3600.00 36.32 213.49 3396.09 3329.69 5999386.12 565513.47 725.31 0.00 MWD+IFR+MS BP My Planning Report MAP Company: BPAmoco Date: ,', 4/26/2002 Time: 15:48:22 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Wetl: Plan MPS-13, True North Site: M PtS Pad Vertical (fVJ) Reference: S-pad 0-141 66.4 Well: Plan MPS-13 Section (VS) Reference: Well (0.OON,0.ooE,213.18Azi) Wellpath: Plan"MPS-13 Survey Calculation Method: Minimum' Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft degJ100ft 3700.00 36.32 213.49 3476.67 3410.27 5999336.45 565481.23 784.53 0.00 MWD+IFR+MS 3781.69 36.32 213.49 3542.49 3476.09 5999295.86 565454.89 832.92 0.00 Start Oir 2/100' : 3781.69' MD 3800.00 35.95 213.49 3557.27 3490.87 5999286.81 565449.02 843.71 2.00 MWD+IFR+MS 3872.38 34.50 213.49 3616.40 3550.00 5999251.79 565426.29 885.46 2.00 Ugnu 3900.00 33.95 213.49 3639.23 3572.83 5999238.76 565417.83 901.00 2.00 MWD+IFR+MS 4000.00 31.95 213.49 3723.14 3656.74 5999193.14 565388.23 955.39 2.00 MWD+IFR+MS 4100.00 29.95 213.49 3808.90 3742.50 5999150.00 565360.23 1006.82 2.00 MWD+IFR+MS 4200.00 27.95 213.49 3896.39 3829.99 5999109.40 565333.88 1055.22 2.00 MWD+IFR+MS 4300.00 25.95 213.49 3985.53 3919.13 5999071.39 565309.21 1100.54 2.00 MWD+IFR+MS 4400.00 23.95 213.49 4076.19 4009.79 5999036.01 565286.25 1142.73 2.00 MWD+IFR+MS 4447.11 23.01 213.49 4119.40 4053.00 5999020.27 565276.03 1161.50 2.00 SBF2-NA 4473.14 22.49 213.49 4143.40 4077.00 5999011.82 565270.55 1171.56 2.00 SBF1-NB 4500.00 21.95 213.49 4168.27 4101.87 5999003.30 565265.02 1181.72 2.00 MWD+IFR+MS 4506.61 21.82 213.49 4174.40 4108.00 5999001.24 565263.68 1184.18 2.00 SBE4-NC 4566.68 20.62 213.49 4230.40 4164.00 5998983.00 565251.84 1205.92 2.00 SBE 1-NF 4597.60 20.00 213.49 4259.40 4193.00 5998974.00 565246.00 1216.66 2.00 MPS-13 OA 4600.00 19.98 213.49 4261.65 4195.25 5998973.31 565245.55 1217.48 0.75 MWD+IFR+MS 4626.32 19.78 213.49 4286.40 4220.00 5998965.81 565240.68 1226.43 0.75 TSBC 4653.93 19.58 213.49 4312.40 4246.00 5998958.01 565235.62 1235.73 0.75 TSBB-OB 4678.33 19.39 213.49 4335.40 4269.00 5998951.18 565231.19 1243.86 0.75 SBA5 (base OB) 4700.00 19.23 213.49 4355.85 4289.45 5998945.17 565227.29 1251.03 0.75 MWD+IFR+MS 4800.00 18.48 213.49 4450.49 4384.09 5998918.06 565209.69 1283.35 0.75 MWD+IFR+MS 4803.07 18.46 213.49 4453.40 4387.00 5998917.24 565209.16 1284.33 0.75 TOBD 4870.45 17.95 213.49 4517.40 4451.00 5998899.59 565197.70 1305.37 0.75 BOBO 4900.00 17.73 213.49 4545.53 4479.13 5998891.99 565192.78 1314.43 0.75 MWD+IFR+MS 5000.00 16.98 213.49 4640.98 4574.58 5998866.97 565176.54 1344.26 0.75 MWD+IFR+MS 5020.44 16.83 213.49 4660.53 4594.13 5998861.99 565173.30 1350.21 0.75 7" 5020.43 16.83 213.49 4660.53 4594.13 5998861.99 565173.30 1350.20 0.00 Total Depth: 5020.45' MD, 466 5020.45 16.83 213.49 4660.54 4594.14 5998861.98 565173.30 1350.21 0.75 MWD+IFR+MS -64 -60 -so -40 -30 --20 -10 -0 270 -10 -20 -30 -40 -SO -60 --64 WELL DETAILS ANTI-COLLISION SETTINGS COMPANY DETAILS Name ~Ni-S +FJ-W Northing Latinlde Longitude Slol Interpolation Method:MD Depth Range From: 27.60 Maximum Range: 699.28 Ea~1ing Interval: 25.00 To: 5020.45 Reference: Plan: MPS-13 Wp05 Calculation Method: Minimum Curvature Error System: ISCWSA ScaD Metbod: Tmv Cylioder North Error Surfuce: Elliptical. Casing Warning Method: Rules Based PlaD MPS-l3 2430 -442,61 599999837 56590223 70'24'37568N 149°27'48.144W NiA ~~s~\:'} ~S~\:' ~'W :.-----~ ~ 33 I # ~ ~ ~ ~ 7 .sf 30 ...ìi CI) ;¿ fJ & r-- ..... rh ;¿ fJ, ;:r; ,'~ )' ;'1'- ,r ~,t ~:. ':~, 'I":i \. , ~ ~. 24<1 "',~~ ~ 18 <f54 BP Amoco From 0 300 600 900 1200 1500 2000 2500 3000 3500 4000 ~500 ~OOO 000 00 0 Colour ~ cP b -.D 90~ cP ~ ...¿ MD SURVEY PROGRAM h"tOl Deptb I'm I"'ptb To SUlVeyn'lan 27,60 1300,00 1'181111<<.1: MI'S-IJ Wp05 VI 1300.00 5020,45 1'18011<."<1: MPS.13 Wp05 VI ToMJ 300 600 900 1200 1500 2000 2500 3000 3500 4000 4500 5000 6000 8000 11000 12000 15000 C -GYRO.SS MWD'IFR.MS WELI.PAl1I DETAILS PL,,, MPS.13 Rig: MAlJD Rt}[ Datum: S-pad D-141 V.St."Clil)n Origin Otisu, ~~~~"fVI) Angle .N/,~ 'I~-W 21J,18° 0,00 o,no lJ,OlJ LEGEND - MPS.07 (MPS.lJ7), Mo.,... I''''' - MPS.09(MPS-lJ9),M.",o. ~". - MPS.15 (MPS-IS). M..,... ~"" MPS-21 (MPS-21), M.."" I''''' - MPS.31 (MPS-31), M."..' 1'." PlallMPS-Ol WlanMI""'-"I¡ M'I"II~',,, - PJanMPS-02WlanMI'....II.:'J M'II"I ~!.-.. PlanMPS-03WlanMI''''''¡¡ MI,,,. ~I" ....... Plan MPS.04 (Plan MI''''JaJl MI.!I'" (,I...... - Plan MPS4)5 (Plan MI'""u(l. M'II'" I~I-." - Plan MPS...06(plan MI'''':;:.(I',I M'II"II~I"k. - Plan MPS-08 (plan MI.'" 111<1 M.II'" 1'1"" - Pt8n MPS-IO(plan Mr" 1111 M'!II..'! IlJ"" - Plan MPS-t 1 (PL1n MI'''; II J ~1.JI,'r 1'1,,11. - Piall MPS-12 (pwn Mf'''; I~I M'II'"III"" - Plan MPS-14 (1'1111 MI''''' 1011. Mill'" kl'.k. - PlanMI~-16{p1aIlMI'''; II" M..,.., It..... - Plan MPS-11(plan MJ" IJ,. M"J'.' 1.(1"11. - Plan MPS-t8 (pian MI."" IH, F\.1,¡, "r tJ"" - Plan MPS-19 (l'lan MI" '", M'I'" ~I" Plan Mps.20 (l'lan MP~ ':1'1 MUI"! Itl,.1L - Plan MpS-23 (plan MI".~ -I ~1!11'.! Ii,.." - Plan MPS-23 (P18n MI".~ II I' M"I'" ~"" - Plan MPS-24 (PL'UI MI''';; ,'41 M.ul'" IlJ"k. Piau Mpsa2~ (l'lan MI"..'(I. M.II" tJ"" - Plan MPS-2S (pI8t1Mr" ~'! I, M""" ~".' Plan MPg-26 (Plan MI'''''.:'f'l M'!I'" ~I"" - Plan MPS-27 (Pian MI'''; ':'1. M'II,.r k....k. - Plan Mrs-27 (Plan Mr', .:71 II. M'II'.' Mo..." - Plan MPS-28 (plan MI.' ~kl. M'II'" tJ..I. - Plan MPS-29 (Plan MI" ":111. Mill'" RJ~" - Plan MPS-30 (plan M'" 1111. MIIJ",r I(J'." - PlanMpsa32(ßlII.MI.~ 1:'1 Moll'" 1(1.1 - Plan MPS.13 - MPS.13 Wp05 SECTION DETAILS lVl> +Ni.s .EJ.W 1>1-"8 TFace VScc Target 27.60 0,00 lJ,OO 0,00 0,00 0,00 300,00 0.00 lJ,OO o,( () O.!){) O,OlJ 499,91 -5.16 lJ,91 L~O 170,00 3.82 699.82 .IlJJI 1.82 L~O 180.00 7,63 19~0,00 .IlJJl 1.82 0.00 0,00 7,63 2798.22 -242.33 -151.69 4,( {) 0,00 285,84 3542,49 -698,60 -453.56 O,( {) 0,00 812,92 4259,40 .1lJ18,64 .665.31 2,00 18lJ,00 1216,66 MI'S.13 OA 4517,40 .1092,63 -714,26 O.7~ 18lJ,00 13lJ5.37 466054 -1I30,\J2 .739,00 0,75 180,00 135lJ,21 loe Azi . I~~ ~ See I 27,60 0.00 0,00 2 300,00 0,00 O,( () 3 500,00 3,00 17lJ,00 4 700,00 0,00 0.00 5 1950.18 0,00 0,00 6 2g57.98 36.32 213,49 7 3781.69 3632 213,49 8 4597,60 20,00 213,49 9 4870,45 17,9; 213,49 (J 5\J20,45 16.83 213.49 ~~"~""'~"""'.\oA.'"'''-\o''',.r'.-J.-¡'''>'''~W,yi-''''h''-"...~',>i.,..'t>S,,-,-~;..--~.,.;-,~j-(;'.-:..(-....'.{, ~, H 206709 DATE 04/11/02 CHECK NO, 00206709 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS 100.00 VENDOR DISCOUNT ALA8KAOILA NET 00 040902 CK040902K PYMT COMMENTS: HANDL:NG INST: PERMIT TO DRILL FEE S/H - TERRIE HUBBLE X4628 100. 00 H F~ E (' F' ~ '\/ r: ~t5- t~ ì' Alaska on 8" Gas CÜfi~~ i-\nctl()f.?oe THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100. 00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 208709 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00206709 PAY Oþ.lE<HUNDRED 8< OO/1004f**iti********************************* US DOLLAR DATE 04/11/02 AMOUNT $100.00 To The ORDER Of ALAS~A OIL AND GAS CONSERVATION COMMISSION 333dWEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 Ç¿~¡¿i~'«~... III 2 0 b ? 0 g III I: 0 ~ ¡. 2 0 j 8 g 5 I: 0 0 8 ~ ~ ¡. g III . ".. -.., ... ~~. ... .... . '. . , . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT RED RILL EXPLORA TION INJECTION WELL V INJECTION WELL RED RILL Rev: 5/6/02 C\jody\templates .I WELLNAME/l~q #/~-/'?I CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD L-) SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY .41'~ WELL NAME./Ø'q/*//l.>-/J/ PROGRAM: Exp - Dev - Redrll- Se~ X Wellbore seg - Ann. disposal para req- FIELD & POOL .s;¿$/~ô INITCLASS /-~"~7 ,~GEOLAREA J'?~ UNIT# 113~ ~ ON/OFFSHORE ~;J ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y. N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. " . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . .' . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N ;¡rR~' 12. Permit can be issued without administrative approval.. . . . . Y N ENG; N~R~:- ~:: ~:~::~::I s~~n~::::~::ef~re .1 ~~a.y W~i~.: : : : : : : : : : ~$~' ~ 'to 1'@lIzt, 15. Surface casing protects all known USDWs. . . . . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . ,N 17. CMTvol adequate to tie-in long string to surfcsg. ....... ~¡JIÆ 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N 19. Casing designs adequate for C, T, 8 & permafrost. . . . . . . , N D 20. Adequate tankage or reserve pit.. . . . . . . ., . . . . . . . . N 61-1~ ''-I-I 21. If a re-drill, has a 10-403 fo.r abandonment been approved. . . ~ ¡..ill( 22. Adequate wellbore-separatlon 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. . . . . . . . . . . . . . . . ¡VIA- A~~~ DAT~ 26. 80PE press rating appropriate; testto psig. ,~ 'W"'V"t" S/~¡I(') 1. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . .. Cl? N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ 30. Permit can be issued w/o hydrogen sulfide measures. . . .. X@N 31. Data presented on potential overpressure zones. . . . . . . Y ,J/"7 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . . . . Y ~ /. r7 ~"r~ J>fT9 33. Seabed condition survey (If off-shore). . . . . . . . . . . . . N IF ~ðG, 34. Contact name/phone for weekly progress reports [exploratory 0 1 Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for dispos (D) will not damage producing formation or impair recovery fro a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.41 Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP#t: GEOLOGY ) APPR DATE /fr: ~~Z- Y N / ~/ ¡l./:A Commentsllnstructions: JDH WGA ~6k-" <JfF COT DTS 06/ oS I ð:> - G:\geology\permits\checklist.doc Well H ¡story 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 dDd~ ¡it} II dLJL/ $Revision: 3 $ LisLib $Revision: 4 $ Mon Oct 21 11:22:29 2002 Reel Header Service name............ .LISTPE Date.... .$............... .02/10/21 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02 110 1 21 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.... ........... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD 1 MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-13 500292309300 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 10-0CT-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22097 J. PANTER E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3330 108 MSL 0) 66.70 39.20 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 20.000 111.0 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4)¡ COMPENSATED NEUTRON POROSITY (CNP)¡ STABILIZED LITHO- DENSITY (SLD)¡ AND PRESSURE WHILE DRILLING (PWD). 4. THERE ARE TWO UNEXPLAINED GAPS IN THE POROSITY DATA: 2076'-2085.5'MD (SLD), AND 2969.5'-2986.5'MD (CTN). THESE ARE SHIFTED DEPTHS. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN MPS-13 ON 2 JULY 2002. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY DEWAYNE SCHNORR ON 7 OCTOBER 2002. 6. MWD RUN 1 REPRESENTS WELL MPS-13 WITH API#: 50-029-23093-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4957'MD/4575'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 9.875" MUD WEIGHT: 8.7 - 9.3 PPG ( MUD SALINITY: 800 - 1000 PPM CHLORIDES FORMATION WATER SALINITY: 25,000 PPM CHLORIDES FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE $ File Header Service name........... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/21 Maximum physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE SNP2 SGRC SFXE SEDP SEMP SESP SEXP SROP SNNA SNFA SPSF SC02 SBD2 $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 35.5 56.0 65.0 65.0 65.0 65.0 65.0 105.0 148.5 148.5 149.5 156.0 156.0 STOP DEPTH 4867.0 4897.5 4906.5 4906.5 4906.5 4906.5 4906.5 4947.5 4858.0 4858.0 4858.0 4867.0 4867.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -----. BASELINE 35.5 57.0 71.5 107.5 128.0 152.5 155.0 158.5 167.5 199.0 215.0 243.0 278.0 281.0 285.5 294.5 303.0 316.5 332.5 338.5 363.0 414.0 DEPTH GR 41.0 62.5 77.5 113.5 137.5 162.0 165.0 171.5 180.5 211.5 226.5 253.5 287.5 291.0 296.0 305.0 313.5 327.0 341.5 348.0 372.5 424.5 439.5 446.0 495.5 510.5 513.5 523.5 525.0 528.0 530.0 538.5 553.5 567.5 570.5 584.5 597.5 602.5 661.0 674.5 695.0 699.0 708.0 723.5 741.5 775.5 784.0 799.5 821.0 828.0 839.0 844.0 855.5 872.5 898.0 922.0 938.5 958.5 974.5 1007.0 1021.5 1049.5 1065.0 1073.0 1081.0 1108.5 1122.0 1127.0 1130.5 1138.0 1154.0 1160.5 1166.5 1186.5 1203.5 1229.5 1241.0 1252.5 1260.0 1268.5 1283.0 1293.0 1306.0 1320.5 1331.5 1334.0 1362.0 450.0 455.5 505.0 520.5 522.5 532.0 534.5 538.0 539.5 547.0 563.0 577.0 580.5 593.0 606.5 611.5 666.0 680.5 704.0 708.0 717.5 733.0 751.0 785.5 793.0 807.5 830.0 837.0 847.0 852.5 864.0 879.0 905.5 931.0 947.0 967.5 985.0 1016.0 1031.0 1059.5 1075.0 1083.0 1090.5 1119.0 1132.0 1137.5 1140.0 1148.0 1164.0 1171.0 1176.5 1194.5 1211.5 1238.5 1251.5 1262.5 1270.5 1278.0 1291.5 1302.5 1316.0 1330.0 1340.0 1342.5 1371.5 (' 1388.5 1413.0 1425.5 1431.5 1443.0 1472.0 1486.0 1496.5 1514.0 1531.5 1539.0 1586.0 1599.5 1618.0 1635.5 1645.0 1652.0 1659.0 1667.0 1680.0 1745.5 1751.5 1762.5 1782.5 1809.0 1836.5 1862.0 1882.5 1894.5 1902.0 1911.5 1919.0 1947.0 1967.5 2006.0 2017.0 2035.0 2048.0 2056.5 2138.0 2164.5 2170.0 2202.0 2219.5 2238.5 2256.5 2264.5 2269.5 2285.5 2303.5 2310.5 2336.5 2347.5 2359.5 2366.5 2400.5 2410.0 2439.5 2445.0 2472.0 2490.5 2503.5 2524.5 2582.0 2586.5 1400.0 1424.5 1435.0 1441.5 1451.5 1481.0 1495.5 1507.0 1522.5 1540.5 1548.5 1595.0 1609.5 1626.0 1645.5 1654.5 1661.0 1667.0 1674.5 1688.5 1754.0 1758.5 1769.5 1788.5 1816.0 1845.5 1869.5 1891.0 1903.0 1909.0 1917.5 1923.5 1951.5 1972.0 2015.0 2025.0 2042.5 2056.5 2062.5 2147.5 2173.5 2179.5 2210.5 2223.5 2244.0 2265.0 2271.5 2277.5 2295.0 2312.5 2319.5 2342.5 2355.0 2367.5 2374.0 2406.5 2418.0 2446.5 2453.0 2479.0 2497.5 2511.0 2530.0 2590.0 2593.5 2606.0 2622.0 2626.0 2634.5 2649.0 2663.5 2687.5 2731.5 2753.5 2760.5 2779.0 2800.0 2826.0 2836.0 2848.5 2858.0 2862.0 2887.0 2904.0 2908.5 2913.5 2916.5 2934.0 2943.0 2947.5 2956.0 2964.0 2970.5 3009.0 3024.0 3033.5 3048.5 3059.5 3074.0 3091.5 3095.0 3105.5 3149.0 3157.0 3173.0 3177.0 3191.0 3208.0 3231.0 3334.0 3382.0 3402.5 3405.0 3408.0 3413.5 3424.0 3431.0 3435.5 3473.5 3493.0 3521.5 3535.0 3563.5 3573.0 3596.5 3627.5 3638.5 3659.5 3673.5 3679.5 2613.5 2631.5 2635.0 2645.5 2660.5 2673.0 2694.0 2739.0 2761.0 2767.5 2788.5 2808.0 2835.5 2845.5 2858.5 2867.0 2870.5 2893.0 2912.5 2916.0 2922.5 2924.5 2943.5 2952.5 2957.0 2964.0 2971.5 2981.0 3017.0 3033.0 3042.0 3057.0 3067.5 3082.0 3101.0 3105.5 3115.5 3155.5 3164.5 3181.0 3186.0 3198.5 3215.5 3240.0 3342.0 3390.0 3409.5 3413.5 3416.5 3422.5 3432.5 3439.5 3443.5 3481.0 3501.5 3529.5 3544.0 3571.0 3581.0 3604.5 3636.5 3648.0 3667.5 3679.5 3685.5 3692.0 3696.5 3699.0 3710.0 3727.5 3743.0 3748.5 3757.5 3773.0 3779.0 3785.0 3790.0 3817.5 3822.5 3838.0 3881.0 3896.0 3902.5 3922.0 3928.5 3932.5 3959.5 3975.5 3994.0 4015.5 4035.0 4046.0 4066.5 4087.0 4092.5 4100.5 4111.0 4130.0 4188.5 4223.0 4240.5 4248.0 4280.5 4302.5 4316.0 4334.5 4360.0 4368.5 4383.0 4388.5 4398.0 4416.5 4445.0 4475.0 4491.0 4564.5 4574.5 4626.5 4634.0 4656.5 4668.5 4685.5 4751.0 4767.5 4790.0 4802.5 4812.5 4947.5 $ 3700.0 3703.5 3706.5 3720.0 3734.5 3751.0 3756.0 3766.5 3779.5 3786.5 3792.5 3799.0 3827.0 3832.0 3847.0 3891.0 3903.0 3911.0 3930.5 3936.5 3941.0 3968.5 3984.5 4002.5 4024.5 4044.5 4054.5 4075.0 4095.0 4100.5 4108.5 4119.5 4138.5 4197.5 4231.5 4249.0 4256.5 4289.5 4312.5 4325.5 4343.0 4369.0 4376.0 4391.0 4396.5 4405.5 4424.5 4453.5 4483.5 4499.5 4573.0 4584.5 4635.0 4640.0 4662.0 4674.5 4694.0 4760.0 4775.5 4798.5 4812.0 4822.5 4957.5 # MERGED DATA SOURCE PBU TOOL CODE MWD $ BIT RUN NO MERGE TOP 1 41.0 MERGE BASE 4957.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ...............0 Data Specification Block Type... ..0 Logging Direction.. .... .......... . Down Optical log depth units...... .... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 35.5 4947.5 2491.5 9825 35.5 4947.5 ROP MWD FT/H 0.98 1580.77 313.238 9686 105 4947.5 GR MWD API 8.19 123.34 64.8206 9684 56 4897.5 RPX MWD OHMM 0.19 2000 37.2166 9684 65 4906.5 RPS MWD OHMM 0.15 2000 50.6181 9684 65 4906.5 RPM MWD OHMM 0.22 2000 78.7585 9684 65 4906.5 RPD MWD OHMM 0.15 2000 65.5601 9684 65 4906.5 FET MWD HOUR 0.03 4.16 0.375886 9684 65 4906.5 NPHI MWD PU-S 20.41 72.08 44.4545 9389 149.5 4858 FCNT MWD CNTS 402 647 495.021 9390 148.5 4858 NCNT MWD CNTS 2008 2992 2367.39 9420 148.5 4858 RHOB MWD G/CM 1.12 2.74 2.09346 9404 156 4867 DRHO MWD G/CM -0.22 0.65 0.111383 9404 156 4867 PEF MWD BARN 0.16 18.37 2.13218 9645 35.5 4867 First Reading For Entire File........ ..35.5 Last Reading For Entire File.......... .4947.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/21 ( Maximum Physical Record. .65535 File Type. .......... .... .LO Next File Name....... ....STSLIB.002 Physical EOF File Header Service name.......... ...STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/21 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE SNP2 SGRC SFXE SEDP SEMP SESP SEXP SROP SNNA SNFA SPSF SC02 SBD2 $ 2 (' header data for each bit run in separate files. 1 .5000 START DEPTH 41.0 61.5 71.0 71.0 71.0 71.0 71.0 111.0 158.0 158.0 159.0 167.0 167.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS STOP DEPTH 4877.0 4907.5 4916.5 4916.5 4916.5 4916.5 4916.5 4957.5 4868.0 4868.0 4868.0 4877.0 4877.0 21-JUN-02 Insite 66.37 Memory 4957.0 111.0 4957.0 1.4 32.1 TOOL NUMBER 9.875 111.0 ( MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.... ....... ..... . Down Optical log depth units....... ... .Feet Data Reference Point............. . Undefined Frame Spacing...... .............. .60 .1IN Max frames per record............ . Undefined Absent value...... . . . . . . . . . . . . . . . . - 9 9 9 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O (' Spud 9.20 147.0 8.0 1000 9.6 4.500 3.390 3.000 3.500 70.0 95.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWDOI0 OHMM 4 1 68 12 4 RPS MWDOI0 OHMM 4 1 68 16 5 RPM MWDOI0 OHMM 4 1 68 20 6 RPD MWDOI0 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 NPHI MWD010 PU-S 4 1 68 32 9 FCNT MWDOI0 CNTS 4 1 68 36 10 NCNT MWD010 CNTS 4 1 68 40 11 RHOB MWD010 G/CM 4 1 68 44 12 DRHO MWDOI0 G/CM 4 1 68 48 13 PEF MWD010 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 41 4957.5 2499.25 9834 41 4957.5 ROP MWD010 FT/H 0.98 1580.77 312.389 9694 111 4957.5 GR MWD010 API 8.19 123.34 64.8562 9693 61.5 4907.5 RPX MWDOI0 OHMM 0.19 2000 37.2076 9692 71 4916.5 RPS MWDOI0 OHMM 0.15 2000 50.7302 9692 71 4916.5 RPM MWDOI0 OHMM 0.22 2000 79.6586 9692 71 4916.5 RPD MWDOI0 OHMM 0.15 2000 65.883 9692 71 4916.5 FET MWDOI0 HOUR 0.03 4.16 0.374756 9692 71 4916.5 NPHI MWDOI0 PU-S 20.41 72.08 44.4588 9385 159 4868 FCNT MWDOI0 CNTS 402 647 495.104 9386 158 4868 ( ( NCNT MWDOI0 CNTS 2008 2992 2367.5 9421 158 4868 RHOB MWDOI0 GICM 1.12 2.74 2.09394 9401 167 4877 DRHO MWDOI0 GICM -0.22 0.65 0.111413 9401 167 4877 PEF MWDOI0 BARN 0.16 18.37 2.13978 9653 41 4877 First Reading For Entire File......... .41 Last Reading For Entire File.......... .4957.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/10/21 Maximum Physical Record..65535 File Type............. ...LO Next File Name........ ...STSLIB.003 Physical EOF Tap~ Trailer Service name........ .... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/21 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number.... ..01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02 1 10 121 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number.... ..01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ( aOd-- Jli.f I J} <tö Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Oct 11 07:08:11 2002 Reel Header Service name. ........... .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 10/ 11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/10/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-13 500292309300 BP Exploration (Alaska) f Inc. Sperry-Sun Drilling Services 10-0CT-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22097 J. PANTER E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3330 108 66.70 39.20 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 20.000 111.0 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); COMPENSATED NEUTRON POROSITY (CNP); STABILIZED LITHO- DENSITY (SLD); AND PRESSURE WHILE DRILLING (PWD). 4. THERE ARE TWO UNEXPLAINED GAPS IN THE POROSITY DATA: 2076'-2085.5'MD (SLD), AND 2969.5'-2986.5'MD (CTN). THESE ARE SHIFTED DEPTHS. 5. LOG AND DIGITAL DATA ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY LOG RUN IN MPS-13 ON 2 JULY 2002. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY DEWAYNE SCHNORR ON 7 OCTOBER 2002. 6. MWD RUN 1 REPRESENTS WELL MPS-13 WITH API#: 50-029-23093-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4957'MD/4575'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 9.875" MUD WEIGHT: 8.7 - 9.3 PPG ( MUD SALINITY: 800 - 1000 PPM CHLORIDES FORMATION WATER SALINITY: 25,000 PPM CHLORIDES FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE $ File Header Service name.. .......... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/11 Maximum Physical Record. .65535 File Type...... ......... .LO Previous File Name.... ...STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE PEF GR FET RPD RPM RPS RPX ROP NCNT FCNT NPHI DRHO RHOB $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 35.5 56.0 65.0 65.0 65.0 65.0 65.0 105.0 156.0 156.0 156.5 162.5 162.5 STOP DEPTH 4876.0 4897.5 4906.5 4906.5 4906.5 4906.5 4906.5 4947.5 4867.0 4867.0 4867.0 4876.0 4876.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ----- BASELINE 35.5 57.0 71.5 107.5 128.0 152.5 155.0 158.5 167.5 199.0 215.0 243.0 278.0 281.0 285.5 294.5 303.0 316.5 332.5 338.5 363.0 414.0 DEPTH GR 41.0 62.5 77.5 113.5 137.5 162.0 165.0 171.5 180.5 211.5 226.5 253.5 287.5 291.0 296.0 305.0 313.5 327.0 341.5 348.0 372.5 424.5 439.5 446.0 495.5 510.5 513.5 523.5 525.0 528.0 530.0 538.5 553.5 567.5 570.5 584.5 597.5 602.5 661.0 674.5 695.0 699.0 708.0 723.5 741.5 775.5 784.0 799.5 821.0 828.0 839.0 844.0 855.5 872.5 898.0 922.0 938.5 958.5 974.5 1007.0 1021.5 1049.5 1065.0 1073.0 1081.0 1108.5 1122.0 1127.0 1130.5 1138.0 1154.0 1160.5 1166.5 1186.5 1203.5 1229.5 1241.0 1252.5 1260.0 1268.5 1283.0 1293.0 1306.0 1320.5 1331.5 1334.0 1362.0 450.0 455.5 505.0 520.5 522.5 532.0 534.5 538.0 539.5 547.0 563.0 577.0 580.5 593.0 606.5 611.5 666.0 680.5 704.0 708.0 717.5 733.0 751.0 785.5 793.0 807.5 830.0 837.0 847.0 852.5 864.0 879.0 905.5 931.0 947.0 967.5 985.0 1016.0 1031.0 1059.5 1075.0 1083.0 1090.5 1119.0 1132.0 1137.5 1140.0 1148.0 1164.0 1171.0 1176.5 1194.5 1211.5 1238.5 1251.5 1262.5 1270.5 1278.0 1291.5 1302.5 1316.0 1330.0 1340.0 1342.5 1371.5 1388.5 1413.0 1425.5 1431.5 1443.0 1472.0 1486.0 1496.5 1514.0 1531.5 1539.0 1586.0 1599.5 1618.0 1635.5 1645.0 1652.0 1659.0 1667.0 1680.0 1745.5 1751.5 1762.5 1782.5 1809.0 1836.5 1862.0 1882.5 1894.5 1902.0 1911.5 1919.0 1947.0 1967.5 2006.0 2017.0 2035.0 2048.0 2056.5 2138.0 2164.5 2170.0 2202.0 2219.5 2238.5 2256.5 2264.5 2269.5 2285.5 2303.5 2310.5 2336.5 2347.5 2359.5 2366.5 2400.5 2410.0 2439.5 2445.0 2472.0 2490.5 2503.5 2524.5 2582.0 2586.5 1400.0 1424.5 1435.0 1441.5 1451.5 1481.0 1495.5 1507.0 1522.5 1540.5 1548.5 1595.0 1609.5 1626.0 1645.5 1654.5 1661.0 1667.0 1674.5 1688.5 1754.0 1758.5 1769.5 1788.5 1816.0 1845.5 1869.5 1891.0 1903.0 1909.0 1917.5 1923.5 1951.5 1972.0 2015.0 2025.0 2042.5 2056.5 2062.5 2147.5 2173.5 2179.5 2210.5 2223.5 2244.0 2265.0 2271.5 2277.5 2295.0 2312.5 2319.5 2342.5 2355.0 2367.5 2374.0 2406.5 2418.0 2446.5 2453.0 2479.0 2497.5 2511.0 2530.0 2590.0 2593.5 2606.0 2622.0 2626.0 2634.5 2649.0 2663.5 2687.5 2731.5 2753.5 2760.5 2779.0 2800.0 2826.0 2836.0 2848.5 2858.0 2862.0 2887.0 2904.0 2908.5 2913.5 2916.5 2934.0 2943.0 2947.5 2956.0 2964.0 2970.5 3009.0 3024.0 3033.5 3048.5 3059.5 3074.0 3091.5 3095.0 3105.5 3149.0 3157.0 3173.0 3177.0 3191.0 3208.0 3231.0 3334.0 3382.0 3402.5 3405.0 3408.0 3413.5 3424.0 3431.0 3435.5 3473.5 3493.0 3521.5 3535.0 3563.5 3573.0 3596.5 3627.5 3638.5 3659.5 3673.5 3679.5 2613.5 2631.5 2635.0 2645.5 2660.5 2673.0 2694.0 2739.0 2761.0 2767.5 2788.5 2808.0 2835.5 2845.5 2858.5 2867.0 2870.5 2893.0 2912.5 2916.0 2922.5 2924.5 2943.5 2952.5 2957.0 2964.0 2971.5 2981.0 3017.0 3033.0 3042.0 3057.0 3067.5 3082.0 3101.0 3105.5 3115.5 3155.5 3164.5 3181.0 3186.0 3198.5 3215.5 3240.0 3342.0 3390.0 3409.5 3413.5 3416.5 3422.5 3432.5 3439.5 3443.5 3481.0 3501.5 3529.5 3544.0 3571.0 3581.0 3604.5 3636.5 3648.0 3667.5 3679.5 3685.5 .4 ( 3692.0 3700.0 3696.5 3703.5 3699.0 3706.5 3710.0 3720.0 3727.5 3734.5 3743.0 3751.0 3748.5 3756.0 3757.5 3766.5 3773.0 3779.5 3779.0 3786.5 3785.0 3792.5 3790.0 3799.0 3817.5 3827.0 3822.5 3832.0 3838.0 3847.0 3881.0 3891.0 3896.0 3903.0 3902.5 3911.0 3922.0 3930.5 3928.5 3936.5 3932.5 3941.0 3959.5 3968.5 3975.5 3984.5 3994.0 4002.5 4015.5 4024.5 4035.0 4044.5 4046.0 4054.5 4066.5 4075.0 4087.0 4095.0 4092.5 4100.5 4100.5 4108.5 4111.0 4119.5 4130.0 4138.5 4188.5 4197.5 4223.0 4231.5 4240.5 4249.0 4248.0 4256.5 4280.5 4289.5 4302.5 4312.5 4316.0 4325.5 4334.5 4343.0 4360.0 4369.0 4368.5 4376.0 4383.0 4391.0 4388.5 4396.5 4398.0 4405.5 4416.5 4424.5 4445.0 4453.5 4475.0 4483.5 4491.0 4499.5 4564.5 4573.0 4574.5 4584.5 4626.5 4635.0 4634.0 4640.0 4656.5 4662.0 4668.5 4674.5 4685.5 4694.0 4751.0 4760.0 4767.5 4775.5 4790.0 4798.5 4802.5 4812.0 4812.5 4822.5 4947.5 4957.5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ BIT RUN NO MERGE TOP 1 50.0 MERGE BASE 4957.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing................ .... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 35.5 4947.5 2491.5 9825 35.5 4947.5 ROP MWD FT/H 0.98 1580.77 313.238 9686 105 4947.5 GR MWD API 8.19 123.34 64.8206 9684 56 4897.5 RPX MWD OHMM 0.19 2000 37.2166 9684 65 4906.5 RPS MWD OHMM 0.15 2000 50.6181 9684 65 4906.5 RPM MWD OHMM 0.22 2000 78.7585 9684 65 4906.5 RPD MWD OHMM 0.15 2000 65.5601 9684 65 4906.5 FET MWD HOUR 0.03 4.16 0.375886 9684 65 4906.5 NPHI MWD PU-S 21.08 77.6 44.6269 9389 156.5 4867 FCNT MWD CNTS 402 647 494.999 9387 156 4867 NCNT MWD CNTS 2008 2992 2367.45 9423 156 4867 RHOB MWD G/CM 1.12 2.74 2.09304 9408 162.5 4876 DRHO MWD G/CM -0.22 0.65 0.111433 9408 162.5 4876 PEF MWD BARN 0.16 18.3 2.12616 9662 35.5 4876 First Reading For Entire File......... .35.5 Last Reading For Entire File......... ..4947.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/10/11 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .02/10/11 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE PEF GR FET RPD RPM RPS RPX ROP NCNT FCNT NPHI DRHO RHOB $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 50.0 61.5 71.0 71.0 71.0 71.0 71.0 111.0 166.5 166.5 168.0 175.5 175.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ # STOP DEPTH 4886.0 4907.5 4916.5 4916.5 4916.5 4916.5 4916.5 4957.5 4877.0 4877.0 4877.0 4886.0 4886.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA 21-JUN-02 Insite 66.37 Memory 4957.0 111.0 4957.0 1.4 32.1 TOOL NUMBER PB0023 0 HWGVR6 PB00230HWGVR6 PB0023 0 HWGVR 6 PB00230HWGVR6 ( 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.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.. ................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 9.875 111.0 Spud 9.20 147.0 8.0 1000 9.6 4.500 3.390 3.000 3.500 70.0 95.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 NPHI MWD010 PU-S 4 1 68 32 9 FCNT MWD010 CNTS 4 1 68 36 10 NCNT MWD010 CNTS 4 1 68 40 11 RHOB MWD010 G/CM 4 1 68 44 12 DRHO MWD010 G/CM 4 1 68 48 13 PEF MWD010 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 50 4957.5 2503.75 9816 50 4957.5 ROP MWD010 FT/H 0.98 1580.77 312.389 9694 111 4957.5 GR MWD010 API 8.19 123.34 64.8562 9693 61.5 4907.5 RPX MWD010 OHMM 0.19 2000 37.2076 9692 71 4916.5 RPS MWD010 OHMM 0.15 2000 50.7302 9692 71 4916.5 RPM MWD010 OHMM 0.22 2000 79.6586 9692 71 4916.5 RPD MWD010 OHMM 0.15 2000 65.883 9692 71 4916.5 FET MWD010 HOUR 0.03 4.16 0.374756 9692 71 4916.5 NPHI MWD010 PU-S 21.08 77.6 44.6225 9387 168 4877 FCNT MWD010 CNTS 402 647 495.05 9387 166.5 4877 NCNT MWD010 CNTS 2008 2992 2367.83 9422 166.5 4877 RHOB MWD010 G/CM 1.12 2.74 2.09406 9402 175.5 4886 DRHO MWD010 G/CM -0.22 0.65 0.111598 9402 175.5 4886 PEF MWD010 BARN 0.16 18.3 2.13965 9653 50 4886 First Reading For Entire File.... ..... .50 Last Reading For Entire File.......... .4957.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/11 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.003 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/10/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/10/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
