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Home My WebLink About197-163CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Stephen Soroka To:Regg, James B (OGC); Wallace, Chris D (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Ryan Thompson; Alaska NS - Wells Integrity Subject:Milne Point Monthly September MIT"s Date:Tuesday, September 30, 2025 1:46:06 PM Attachments:MIT MPU H-11 9-1-25.xlsx MIT MPU I-01 09-5-25.xlsx MIT MPU R-107 09-21-25.xlsx MIT MPU S-46 S-48 9-15-25.xlsx MPU F-17 AOGCC MIT form 10-426 9_29_25.xlsx MIT MPU B-32 CO808 9-12-2025.xlsx All – Attached are recently completed MIT’s performed in September for Milne Point. Well PTD# Comment MPB-32 2161510 Biennial MIT-OA Per Sundry #323-462 MPH-11 1971630 CMIT-TxIA for RWO Reservoir Abandonment plug per Sundry #325-454 MPI-01 1900900 CMIT-TxIAxOA for P&A per Sundry #325-128 MPR-107 2250490 Initial 4-year MIT-IA MPS-46 2210450 4-Year MIT-IA MPS-48 2210490 4-Year MIT-IA MPF-17 1971960 Service Coil MIT of Reservoir Abandonment plug per Sundry #325-462 Please call with any questions. Thank You Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the 0LOQH3RLQW8QLW+ 37' MPH-11 1971630 CMIT-TxIA for RWO Reservoir Abandonment plug per Sundry #325-454 onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: OOPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1971630 Type Inj N Tubing 0 1712 1700 1696 Type Test P Packer TVD 3757 BBL Pump IA 0 1712 1700 1696 Interval O Test psi 1500 BBL Return OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Alaska, LLC Milne Point / MPU / H DEMOSKI 09/01/25 Notes:Per RWO Sundry #325-454, MIT test to 1500 psi of reservoir cement plug for Schrader Bluff abandonment, TOC ~ 6060'. AOGCC witness waived by Bob Noble. Notes: Notes: Notes: H-11 Form 10-426 (Revised 01/2017)2025-0901_MIT_MPU_H-11 9 9 9 9 999 999 9 9 -5HJJ 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: 11/14/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251114 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# PBU 01-10A 50029201690200 225055 8/29/2025 BAKER MRPM BRU 224-34T 50283202050000 225044 8/9/2025 AK E-LINE CBL MGS ST 17595 30 50733204560000 193120 8/13/2025 AK E-LINE CBL MPU H-11 50029228020000 197163 8/17/2025 AK E-LINE JetCut PCU D-10 50283202080000 225082 10/6/2025 AK E-LINE CBL Please include current contact information if different from above. T41100 T41101 T41102 T41103 T41104 MPU H-11 50029228020000 197163 8/17/2025 AK E-LINE JetCut Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.14 12:58:13 -09'00' 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: 09/19/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250919 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 212-35T 50283200970000 198161 8/10/2025 AK E-LINE PPROF T40899 BRU 223-34T 50283202060000 225059 8/17/2025 AK E-LINE CBL T40900 BRU 234-27 50283202070000 225065 9/12/2025 AK E-LINE CBL T40901 BRU 242-04 50283201640000 212041 6/9/2025 AK E-LINE Perf T40902 KBU 11-08Z 50133206290000 214044 9/8/2025 AK E-LINE Perf T40903 MPU H-03 50029220630000 190088 9/9/2025 AK E-LINE SetPacker T40904 MPU H-11 50029228020000 197163 2/9/2025 AK E-LINE Caliper T40905 MPU M-62 50029237440000 223006 8/31/2025 AK E-LINE LDL T40906 NCIU A-06 50883200260000 169050 8/25/2025 AK E-LINE TubingCut T40907 NCIU A-21A 50883201990100 225075 8/26/2025 AK E-LINE Perf T40908 ODSK-33 50703205620000 207183 9/10/2025 READ Caliper Survey T40909 ODSN-01a 50703206480100 216008 9/8/2025 READ Caliper Survey T40910 ODSN-06 50703207150000 215098 9/9/2025 READ Jewelry Log T40911 PBU C-34C 50029217850300 225068 8/25/2025 BAKER MRPM T40912 PBU Q-06A 50029203460100 198090 8/21/2025 BAKER SPN T40913 TBU M-25 50733203910000 187086 8/31/2025 AK E-LINE Drift T40914 Please include current contact information if different from above. MPU H-11 50029228020000 197163 2/9/2025 AK E-LINE Caliper Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.22 13:22:50 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Erik Nelson Subject:2025080602150 APPROVAL Request for Approval to Suspend Operations with ASR on MPU H-11 (PTD# 197-163) operating under Approved Sundry# 325-454... Date:Wednesday, September 3, 2025 9:51:55 PM Erik, If you have a passing pressure test above the cement retainer of the 7” casing, Hilcorp is approved to install the kill string and RDMO ASR. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Erik Nelson <erik.nelson@hilcorp.com> Sent: Wednesday, September 3, 2025 8:54 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Request for Approval to Suspend Operations with ASR on MPU H-11 (PTD# 197-163) operating under Approved Sundry# 325-454... Mel, During E-Line operations on MPU H-11 (PTD # 197-163), we discovered an anomaly in our 7” production casing. Further evaluation of this anomaly has us doubting our ability to execute our current recompletion plan. We are requesting approval to pause work on Approved Sundry # 325-454 in order to move ASR off of the well while we work up another plan. Our abandonment of the Schrader Bluff formation has been completed and tested per the Approved Sundry and we continued work thru step 24) b) on our Approved RWO procedure. Our plan forward is to run a 4-½”, 12.6# IBT-Mod tbg string to +/- 2300-ft MD ( 2217-ft TVD) then RDMO ASR. We do not have a clearly defined timeline for when we might return to MPU H-11. Thank you for your time and consideration of our request to suspend operations. Please let me know if you have any questions and/or comments. Q Erik Q. Nelson Milne Point OE O (907) 777 - 8353 C (907) 903 – 7407 Erik.Nelson@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Tubing Cut Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to WSW 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,020'6,859' Casing Collapse Conductor N/A Surface 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WSW WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Erik.Nelson@hilcorp.com 907-777-8353 See Schematic See Schematic 3-1/2" 7" Baker Model S-3 and N/A 6,192 MD/ 3,758 TVD and N/A Erik Nelson N/A 7,240psi4,281'7,002' 77' 20" 7"6,971' Length Size Proposed Pools: 110' 110' 9.2 / L-80 / EUE 8rd TVD Burst 6,260' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 197-163 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22802-00-00 Hilcorp Alaska LLC C.O. 477B AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 8/23/2025 Perforation Depth MD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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 and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT H-11 MILNE POINT SCHRADER BLUFF OIL Tertiary Underf WTRSP 4,293' 6,918' 4,225' 1,422 6,730' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 7:51 am, Aug 01, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.08.01 07:41:45 - 08'00' Taylor Wellman (2143) 325-454 10-404 * BOPE test to 2500 psi. 24 hour notice to AOGCC for opportunity to witness. * AOGCC to witness jointed pipe tag and pressure test to 1500 psi of reservoir cement plug TOC ~6095' MD. DSR-8/14/25 ADL 025906, MGR18AUG25 Convert to W SW SFD 8/18/2025 Perforate New Pool SFD *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.19 12:28:41 -08'00'08/19/25 RBDM JSB 082025 ®ôīīϙbÍıôϡ aϙFϱ͐͐IϙbŪıæôŘϡ ͔͏ϱ͏͑͘ϱ͑͑͗͏͑ϱ͏͏ϱ͏͏ ŪŘŘôĲťϙťÍťŪŜϡ ēŪťϱIĲϙIĲĤôèťĺŘ ĖČϡ ϙϭ͐ (ŜťĖıÍťôîϙťÍŘťϙ"Íťôϡ ͗ϯ͑͒ϯ͑͏͔͑(ŜťĖıÍťôîϙ"ŪŘÍťĖĺĲϡ ͐͏ϙîÍƅŜ ôČŪīÍťĺŘƅϙĺĲťÍèťϡ ĺıϙ>ĺŪťŜ ôŘıĖťϙťĺϙ"ŘĖīīϙbŪıæôŘϡ ͖͐͘ϱ͕͐͒ >ĖŘŜťϙÍīīϙ(ĲČĖĲôôŘϡ (ŘĖħϙϟϙbôīŜĺĲ ϼ͘͏͖Ͻϙ͖͖͖ϙϳϙ͔͗͒͒ϙϼiϽ ϼ͘͏͖Ͻϙ͘͏͒ϙϳϙ͖͓͏͖ϙϼϽ ôèĺĲîϙÍīīϙ(ĲČĖĲôôŘϡ ÍƅīĺŘϙ®ôīīıÍĲ ϼ͘͏͖Ͻϙ͖͖͖ϙϳϙ͓͓͗͘ϙϼiϽ ϼ͘͏͖Ͻϙ͓͖͘ϙϳϙ͔͒͒͘ϙϼϽ @ôĺīĺČĖŜťϡ XÍťĖôϙŪĲēÍ ϼ͘͏͖Ͻϙ͔͕͓ϙϳϙ͓͖͕͗ϙϼiϽ ϼ͘͏͖Ͻϙ͗͏͑ϙϳϙ͏͏͖͗ϙϼϽ ŪŘŘôĲťϙĺťťĺıϙFĺīôϙŘôŜŜŪŘôϙϼFϽϡ èēŘÍîôŘϙīŪƯϙϼiϠϙbϠϙbϠϙÍĲîϙiϽ ЂťĺϟæôϟÍæÍĲîĺĲôîϟîŪŘĖĲČϟ®iЃ ͔͐͗͐ϙŕŜĖϙЬϙ͕͓͖͏ϱċťϙa"ϙϼ͒͒͒͘ϱċťϙ«"ϽϙϼiϽ ͐͏ϙaÍƅϙ͑͏͔͑ϙиϙ͗ϟ͕͏ϙ(a®ϙϼ͗ϟ͘ϙX®>Ͻ aÍƄϙĺťôĲťĖÍīϙŪŘċÍèôϙŘôŜŜŪŘôϙϼaϽϡ ͓͐͑͑ϙŕŜĖ @ÍŜϙĺīŪıĲϙ@ŘÍîĖôĲťϙϼ͏ϟ͐ϙŕŜĖϯċťϽ ŪŘŘôĲťϙĺťťĺıϙFĺīôϙŘôŜŜŪŘôϙϼFϽϡ ôŘťĖÍŘƅϙĲîôċϙ®ϙϼ͔͔͑͐͒͏Ͻ ЂťĺϟæôϟŘôèĺıŕīôťôîϟÍŜϟ®®Ѓ ͐͑͏͘ϙŕŜĖϙЬϙ͒͏͖͑ϱċťϙa"ϙϼ͖͓͖͑ϱċťϙ«"ϽϙϼīÍĲĲôîϙ iϽ >ŘĺıϙĺƯŜôťϙ®®ϙиϙ͗ϟ͓͕ϙ(a®ϙϼ͗ϟ͖ϙX®>Ͻ aÍƄϙĺťôĲťĖÍīϙŪŘċÍèôϙŘôŜŜŪŘôϙϼaϽϡ ͓͒͘ϙŕŜĖ @ÍŜϙĺīŪıĲϙ@ŘÍîĖôĲťϙϼ͏ϟ͐ϙŕŜĖϯċťϽ aÍƄϙ"ôŽĖÍťĖĺĲϡ ЂċĺŘϟôĲťĖŘôϟſôīīæĺŘôϟŘôīôŽÍĲťϟťĺϟŘôϷ®iϟſôīīſĺŘħϟ ÍĲîϟ®iЃ ͖͔ϟ͘еϙЬϙ͔͏͗͘ϱċťϙa" aÍƄϙ"ĺČīôČϡϙ ЂċĺŘϟôĲťĖŘôϟſôīīæĺŘôϟŘôīôŽÍĲťϟťĺϟŘôϷ®iϟſôīīſĺŘħϟ ÍĲîϟ®iЃ ͓ϟ͓еϯ͐͏͏ϱċťϙЬϙ͕͑͗͐ϱċťϙa" aĖĲϙI"ϡϙ ЂċĺŘϟôĲťĖŘôϟſôīīæĺŘôϟŘôīôŽÍĲťϟťĺϟŘôϷ®iϟſôīīſĺŘħϟ ÍĲîϟ®iЃ ͒ϱΫЋϙæČϙϳ ͒ϱΫЋϙ³ϱĲĖŕŕīôϙϼ͑ϟ͗͐͒ϱĖĲϽϙÍťϙ͕͖͐͘ϱċťϙa"ϙÍĲîϙ͔͑͒͗ϱċťϙ a" ͖ЋϙŜČϙϳ bĺϙI"ϙŘôŜťŘĖèťĖĺĲϙæŪťϙťēôŘôϙĖŜϙÍϙ͖ЋϙFĺſèĺϙЊ(Ћϙ ôıôĲťôŘϙÍťϙ͑͐͐͒ϱċťϙa"ϙϼ͑͏͔͖ϱċťϙ«"ϽϙťēÍťϙſÍŜϙ ıĖīīôîϙĺŪťϙſϯϙÍϙ͕ЋϙæĖť Xϡ ͒͏ϟ͘ϱċťϙϼbÍæĺŘŜϙ͑͑(Ͻ ЂťĺϟæôϟÍæÍĲîĺĲôîϟîŪŘĖĲČϟ®iЃ ЂťĺϟæôϟŘôèĺıŕīôťôîϟÍŜϟ®®Ѓ ®ôīīϡ aϙFϱ͐͐ "ϡ ͖͐͘ϱ͕͐͒ Iϡ ͔͏ϱ͏͑͘ϱ͑͑͗͏͑ϱ͏͏ϱ͏͏ "Íťôϡ ͖͑ϙVŪīƅϙ͑͏͔͑ ŘĖôċϙ®ôīīϙŪııÍŘƅϡ aϙFϱ͐͐ϙſÍŜϙîŘĖīīôîϙÍĲîϙèÍŜôîϙæƅϙbÍæĺŘŜϙ͑͑(ϙĖĲϙôŕϙ͖͐͘͘ϙÍŜϙÍϙèēŘÍîôŘϙīŪƯϙĖĲĤôèťĺŘϟϙϙIťϙſÍŜϙŕôŘċôîϙÍĲîϙ èĺıŕīôťôîϙæƅϙbÍæĺŘŜϙ͔ϙĖĲϙŪČϙ͐͗͘͘ϙĖĲťĺϙiϱŜÍĲîŜϟϙϙbϠϙbϙÍĲîϙiϱŜÍĲîϙŕôŘċŜϙſôŘôϙÍîîôîϙĺĲϙ͑͑ϙôŕϙ ͐͘͘͘ϟϙϙIťϙſÍŜϙĺĲϙĖĲĤôèťĖĺĲϙ͐͗͘͘ϱ͑͏͐͏ϙÍĲîϙēÍŜϙæôôĲϙŜēŪťϙĖĲϙŜĖĲèôϟ bĺťôŜϙôČÍŘîĖĲČϙ®ôīīæĺŘôϙĺĲîĖťĖĺĲϡ -͏͓ϙVŪīϙ͑͏͐͏ϙϳϙiϙIϙŜôťϙÍťϙ͕͖͒͏ϱċťϙa"ϙťĺϙĖŜĺīÍťôϙťēôϙiϱŜÍĲîϙŕôŘċĺŘÍťĖĺĲŜ -͐͏ϙaÍƅϙ͑͏͔͑ϙϳϙ®ôīīϙſÍŜϙîŘĖċťôîϙſϯϙ͑ϟ͕͘͏ϱĖĲϙŜÍıŕīôϙæÍĖīôŘϙťĺϙ͕͕͕͔ϱċťϙa"ϙϼ͓͏͕͏ϱċťϙ«"ϽϟϙϙѭϯϱϙήϙèŪŕϙĺċϙ ƱīīϙŘôèĺŽôŘôîϟϙϙFϙŜŪŘŽôƅϙŕôŘċĺŘıôîϟ -͐͐ϙaÍƅϙ͑͏͔͑ϙϳϙaIϱIϙϼ͑͏͗͏ϙŕŜĖϽϙŕÍŜŜôî iæĤôèťĖŽôϡ FĖīèĺŘŕϙīÍŜħÍϠϙ[[ϙŕŘĺŕĺŜôŜϙŕôŘċĺŘıĖĲČϙŘôŜôŘŽĺĖŘϙÍæÍĲîĺĲıôĲťϙĺċϙťēôϙèēŘÍîôŘϙīŪƯϙbϠϙbϠϙiϠϙÍĲîϙiϙ ŜÍĲîŜϙÍĲîϙťĺϙŘôϱèĺıŕīôťôϙťēôϙſôīīϙĖĲťĺϙťēôϙôŘťĖÍŘƅϙĲîôċϙ®ϙϼ͔͔͑͐͒͏ϽϙċĺŘıÍťĖĺĲϙÍŜϙÍϙēĖČēϱŽĺīŪıôϙ ċŘôŜēſÍťôŘϙŜĺŪŘèôϙſôīīϟ ēĖŜϙŕŘĺèôîŪŘôϙîôťÍĖīŜϙťēôϙæôīĺſϙĺŪťīĖĲôϙĺċϙťēôϙŜèĺŕôϙĺċϙťēĖŜϙŕŘĺĤôèťϡ -ŪťϙÍĲîϙŕŪīīϙťēôϙôƄĖŜťĖĲČϙ͒ϱΫЋϠϙ͘ϟ͒ϭϙ[͗͏ϙ͗Řîϙ((ϙťæČϙÍæĺŽôϙťēôϙÍħôŘϙaĺîôīϙϱ͒ϙŕôŘıÍĲôĲťϙŕÍèħôŘ -ôťϙ͖ЋϙèôıôĲťϙŘôťÍĖĲôŘϙÍĲîϙŕŪıŕϙīÍŜŜϙ@ϙĲôÍťϙèôıôĲťϙťĺϙÍæÍĲîĺĲϙťēôϙèēŘÍîôŘϙīŪƯϙbϠϙbϠϙiϠϙ ÍĲîϙiϙŕôŘċĺŘÍťĖĺĲŜ -ôŘċĺŘÍťôϙťēôϙôŘťĖÍŘƅϙĲîôċϙ®ϙϼ͔͔͑͐͒͏ϽϙċĺŘıÍťĖĺĲϙÍĲîϙĖĲŜťÍīīϙÍϙÍŜôîϙFĺīôϙ@ŘÍŽôīϙÍèħϙ ϼF@ϽϙīĺſôŘϙèĺıŕīôťĖĺĲ -IĲŜťÍīīϙÍϙ͓ϱΫЋϙťŪæĖĲČϙ(ϙèĺıŕīôťĖĺĲϙÍæĺŽôϙťēôϙÍŜôîϙFĺīôϙ@ŘÍŽôīϙÍèħ ŘôϱĖČϙiŕôŘÍťĖĺĲŜϙϼbĺĲϱŪĲîŘĖôîϙ®ĺŘħϽϙŘôıÍĖĲĖĲČϡ ͐Ͻ (ϱ[ĖĲô ÍϽ IFϙſϯϙôƄŕīĺŜĖŽôϙĤôťϙèŪťťôŘϙÍĲîϙèŪťϙ͒ϱΫЋϠϙ͘ϟ͒ϭϙ[͗͏ϙ͗Řîϙ((ϙťæČϙÍťϙ͕͔͐͗ϱċťϙa"ϙϼıĖîϙĤťϙĖĲϙťēôϙ ŕŪŕϙæôīĺſϙťēôϙīĺſôŜťϙ³ϱĲĖŕŕīôϙŕŘĺƱīôϽ ͑Ͻ >ŪīīæĺŘô ÍϽ īôôîϙÍĲƅϙČÍŜϙĺƯϙĺċϙťæČϙÍĲîϙIϙťĺϙŜīĺŕϙťÍĲħ æϽ ĖŘèŪīÍťôϙſôīīϙĺŽôŘϙťĺϙ͗ϟ͘ϙϭϯČÍīϙæŘĖĲôϙϼ͖͑͐ϙææīŜϽϙîĺſĲϙťēôϙťæČϙťēŘĺŪČēϙĤôťϙèŪťϙÍťϙ͕͔͐͗ϱċťϙa"Ϡϙ ťÍħĖĲČϙŘôťŪŘĲŜϙċŘĺıϙťēôϙIϙϙϙϼIϙѱϙ͕͐͒ϙææīŜϙϯϙæČϙѱϙ͔͓ϙææīŜϽ èϽ iĲèôϙ͗ϟ͘ϙϭϯČÍīϙæŘĖĲôϙĖŜϙŜēĺſĲϙĖĲϙŘôťŪŘĲŜϙÍťϙŜŪŘċÍèôϠϙŜťĺŕϙŕŪıŕĖĲČϙÍĲîϙŜēŪťϱĖĲϙťēôϙIϟϙϙ ŪīīēôÍîϙѭϯϱϙ͑͏ϙææīŜϙîĺſĲϙťēôϙťæČϙĖĲťĺϙťēôϙċĺŘıÍťĖĺĲϟ îϽ aĺĲĖťĺŘϙſôīīϙċĺŘϙæŪĖīîŪŕ ͒Ͻ ®ôīīŜϙŪŕŕĺŘť ÍϽ īôÍŘϙÍĲîϙīôŽôīϙŕÍîϙÍŘôÍϙĖĲϙċŘĺĲťϙĺċϙſôīīϟϙŕĺťϙŘĖČϙıÍťŜϙÍĲîϙèĺĲťÍĖĲıôĲťϟ æϽ "ϙſôīīϙēĺŪŜôϙÍĲîϙƲĺſīĖĲôŜϟϙϙīôÍŘϙÍĲîϙīôŽôīϙÍŘôÍϙÍŘĺŪĲîϙſôīīϟ èϽ ĺĲƱŘıϙſôīīϙĖŜϙîôÍîϙſϯϙb>ϟϙ ŘôϱèĺıŕīôťôϙťēôϙſôīīϙĖĲťĺϙťēôϙôŘťĖÍŘƅϙĲîôċϙ®ϙϼ͔͔͑͐͒͏ϽϙċĺŘıÍťĖĺĲϙÍŜϙÍϙēĖČēϱŽĺīŪıô ċŘôŜēſÍťôŘϙŜĺŪŘèôϙſôīīϟ ®ôīīϡ aϙFϱ͐͐ "ϡ ͖͐͘ϱ͕͐͒ Iϡ ͔͏ϱ͏͑͘ϱ͑͑͗͏͑ϱ͏͏ϱ͏͏ "Íťôϡ ͖͑ϙVŪīƅϙ͑͏͔͑ îϽ ôťϙ«ϟϙb"ϙťŘôôϟϙbϙi(ϟ bi(ϡϙϙ®ôīīēôÍîϙĖŜϙÍĲϙ͐͐Ћϙ͔aϙ>aϙ@ôĲϙ͕ϙſϯϙ͓Ћϙ«ϙŕŘĺƱīôϙÍĲîϙ͓ϱΫЋϙƄϙ͒ϱΫЋϙbϙēÍĲČôŘ ®iϙŘĺèôîŪŘôϙϼŪĲîŘĖôîϙĺŘϙbĺĲϱŪĲîŘĖôîϙ®ĺŘħϽϡ aIϯôŜťϙi(ϡ ͐Ͻ aIϙFĖīèĺŘŕϙϙϭ͐ϙĖČϠϙÍĲèĖīīÍŘƅϙôŗŪĖŕıôĲťϙÍĲîϙīĖĲôŜϙťĺϙ͔͏͏ϙææīϙŘôťŪŘĲŜϙťÍĲħ ͑Ͻ ēôèħϙċĺŘϙŕŘôŜŜŪŘôϙÍĲîϙĖċϙ͏ϙŕŜĖϠϙŜôťϙϙŕīŪČϟϙϙIċϙĲôôîôîϠϙæīôôîϙÍĲƅϙŘôŜĖîŪÍīϙŕŘôŜŜŪŘôϙĺƯϙťŪæĖĲČϙ ÍĲîϙèÍŜĖĲČϟϙϙIċϙĲôôîôîϠϙħĖīīϙſôīīϙſĖťēϙ͗ϟ͘ϭϯČÍīϙæŘĖĲôϙŕŘĖĺŘϙťĺϙŜôťťĖĲČϙϟ ͒Ͻ ôŜťϙi(ϙťĺϙ͔͑͏ϙŕŜĖϙ[ĺſϙϯϙ͔͑͏͏ϙŕŜĖϙFĖČēϠϙÍĲĲŪīÍŘϙťĺϙ͔͑͏ϙŕŜĖϙ[ĺſϙϯϙ͔͑͏͏ϙŕŜĖϙFĖČēϙϼēĺīîϙôÍèēϙťôŜťϙ ĺċϙŘÍıϯŽÍīŽôϙċĺŘϙ͔ϱıĖĲϽϟϙϙôèĺŘîϙÍèèŪıŪīÍťĺŘϙŕŘôϱèēÍŘČôϙŕŘôŜŜŪŘôŜϙÍĲîϙèēÍŘťϙťôŜťŜϟ ÍϽ ôŘċĺŘıϙi(ϙôŜťϙÍŜϙŕôŘϙϙ͐ϙiϙôŜťϙŘĺèôîŪŘô æϽ bĺťĖċƅϙi@ϙ͓͑ϱēŘŜϙĖĲϙÍîŽÍĲèôϙĺċϙi(ϙťôŜť èϽ ĺĲƱŘıϙťôŜťϙŕŘôŜŜŪŘôϙŕôŘϙťēôϙŪĲîŘƅϙĺĲîĖťĖĺĲŜϙĺċϙŕŕŘĺŽÍī îϽ ôŜťϙŕĖŕôϙŘÍıŜϙĺĲϙ͑ϱ͖ϯ͗ЋϙÍĲîϙ͓ϱΫЋϙťôŜťϙĤťŜ ôϽ ŪæıĖťϙèĺıŕīôťôîϙ͐͏ϱ͓͓͑ϙīĺſϱiŪťϙŘôŽôĲťôŘϙ(ŗŪĖŕıôĲťϙϼi(ϽϙôŜťϙċŘĺıϙſĖťēĖĲϙ͔ϙîÍƅŜϙĺċϙ i(ϙťôŜť ͓Ͻ ŪīīϙϙŕīŪČϟϙϙīôôîϙÍĲƅϙŕŘôŜŜŪŘôϙťĺϙťēôϙŘôťŪŘĲŜϙťÍĲħϟϙϙXĖīīϙſôīīϙſϯϙ͗ϟ͘ϙϭϯČÍīϙX®>ϙÍŜϙĲôôîôîϟϙϙ Ūīīϙ«ϟ bi(ϡϙϙIċϙĖĲîĖèÍťĖĺĲŜϙŜēĺſϙŕŘôŜŜŪŘôϙŪĲîôŘĲôÍťēϙ«ϠϙīŪæŘĖèÍťôϙĺŪťϙ«ϟ ŪīīϙæČϡ ͔Ͻ aϙīÍĲîĖĲČϙĤťϙĺŘϙŜŕôÍŘϠϙi["ϠϙϙĺĲϙťēôϙťæČϙēČŘ ÍϽ æČϙēČŘϙĖŜϙÍĲϙ͐͐ЋϙƄϙ͒ϟ͔ЋϙbϱϙϼæťıϽϙƄϙ͓ϟ͔ЋϙbϱϙϼťĺŕϽϙſϯϙ͓Ћϙ«ϙŕŘĺƱīô æϽ bÍæĺŘŜϙ͔ϙŘôèĺŘîŜϙċŘĺıϙ͐͗͘͘ϙĖĲîĖèÍťôϙ͓͔XϙīæċϙϙÍĲîϙ͒͏XϙīæċϙiϙĖĲϙ͗ϟ͘ϙϭϯČÍīϙæŘĖĲô bi(ϡϙϙôèĺŘîŜϙîĺϙĲĺťϙĖĲîĖèÍťôϙſēôťēôŘϙĺŘϙĲĺťϙťēôϙϯiϙſôĖČēťŜϙĖĲèīŪîôϙæīĺèħϙſť èϽ ͗͏҇ϙĺċϙ͒ΫЋϠϙ͘ϟ͑ϙ[ϱ͗͏ϙ͗Řîϙ((ϱaĺîϙƅĖôīîϙĖŜϙ͕͔͐XϙīæċϙċĺŘϙæĺťēϙŕĖŕôϙæĺîƅϙÍĲîϙŪŕŜôťϙ èĺĲĲôèťĖĺĲŜ îϽ ͗͏҇ϙĺċϙƅĖôīîϙĺĲϙťēôϙ͒ϱΫЋϙbϙϼæťıϽϙĺĲϙťēôϙťæČϙēČŘϙĖŜϙÍīŜĺϙ͕͔͐Xϙīæċ ͕Ͻ ĺĲƱŘıϙēČŘϙċŘôôϠϙīÍƅϙîĺſĲϙťæČϙēČŘ ͖Ͻ iiFϙħĖèħĖĲČϙĺŪťϙĺīîϙ͒ϱΫЋϙŕŘĺîϙťæČϙÍĲîϙĤôſôīŘƅϟϙϙ®ÍŜēϙÍĲîϙťŘÍŜēϙÍīīϟ ͗Ͻ ŘôŕϙƲĺĺŘϙċĺŘϙèıťϙŘôťÍĖĲôŘϙŘŪĲ bi(ϡϙϙŘĺŽĖîôϙ͓͑ϱēŘϙĲĺťĖèôϙťĺϙi@ϙĺċϙŪŕèĺıĖĲČϙŕīŪČČĖĲČϙĺŕôŘÍťĖĺĲŜϙŕôŘϙ͑͏ϙϙ͔͑ϟ͐͐͑ϙϼēϽ æÍĲîĺĲϙèēŘÍîôŘϙīŪƯϙċĺŘıÍťĖĺĲϡ ͘Ͻ aϙ͖ЋϙıôèēϙèıťϙŘôťÍĖĲôŘϙFϙĺĲϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙIϱaĺîϙſĺŘħŜťŘĖĲČ bi(ϡϙϙ(ĲŜŪŘôϙĲôſϙôƲĺĲϙŘĖĲČŜϙÍŘôϙĺĲϱēÍĲîϙÍŜϙĲôôîôî ͐͏Ͻ IFϙťĺϙæŪıŕϙ͒ϱΫЋϙťæČϙŜťŪæϙϼѭϯϱϙ͕͔͐͗ϱċťϙa"Ͻ bi(ϡϙϙŽĺĖîϙŘĖČēťϱēÍĲîϙŘĺťÍťĖĺĲϙæôĖĲČϙťŘÍĲŜıĖťťôîϙťĺϙťēôϙıôèēÍĲĖèÍīϙŜôťťĖĲČϙťĺĺīŜϙſēĖīôϙIF ͐͐Ͻ iæťÍĖĲϙϙÍĲîϙiϙſôĖČēťŜϟϙϙϙťĺϙŜôťϙťēôϙèıťϙŘôťÍĖĲôŘϙѭϯϱϙ͕͖͔͐ϱċťϙa"ϟ bi(ϡϙϙôťϙîôŕťēϙĺċϙťēôϙŘôťÍĖĲôŘϙèÍĲϙæôϙÍîĤŪŜťôîϙċĺŘϙŕŪıŕϙĖŘĺĲϙťĖôϱĖĲϙĺĲϙťēôϙŘĖČϙƲĺĺŘϙÍĲîϙ ÍŜŜŪŘÍĲèôϙťēÍťϙſôЍīīϙēÍŽôϙÍϙċŪīīϙĤťϙťĺϙϙÍċťôŘϙŪĲϱŜťĖĲČĖĲČϙċŘĺıϙťēôϙèıťϙŘôťÍĖĲôŘϙÍťϙťēôϙôĲîϙĺċϙťēôϙ ®ôīīϡ aϙFϱ͐͐ "ϡ ͖͐͘ϱ͕͐͒ Iϡ ͔͏ϱ͏͑͘ϱ͑͑͗͏͑ϱ͏͏ϱ͏͏ "Íťôϡ ͖͑ϙVŪīƅϙ͑͏͔͑ ŜŗƏϙĤĺæϟϙϙôŘϙ͑͏ϙϙ͔͑ϟ͐͐͑ϙϼèϽϙϼ͐Ͻϙϼ"ϽϙťēôϙèıťϙŘôťÍĖĲôŘϙĖŜϙŘôŗŪĖŘôîϙťĺϙæôϙŜôťϙĲĺϙèīĺŜôŘϙťēÍĲϙ͔͏ϱċťϙ a"ϙæŪťϙĲĺϙıĺŘôϙťēÍĲϙ͔͏͏ϱċťϙa"ϙċŘĺıϙiϙϼ͕͓͖͏ϱċťϙa"ϽϠϙĺŘϙæôťſôôĲϙ͕͓͑͏ϱċťϙa"ϙťĺϙ͔͖͘͏ϱċťϙa"ϟ ͐͑Ͻ ĺťÍťôϙťæČϙťĺϙťēôϙŘĖČēťϙťĺϙŜťÍŘťϙťēôϙèıťϙŘôťÍĖĲôŘϙŜôťϟϙϙ>ĖĲÍīĖƏôϙŜôťťĖĲČϙĺċϙťēôϙèıťϙŘôťÍĖĲôŘϙæƅϙŕŪīīĖĲČϙ ťēôϙŘôèĺııôĲîôîϙťôĲŜĖĺĲϟϙϙFĺīîϙťôĲŜĖĺĲϙċĺŘϙŘôèĺııôĲîôîϙŕôŘĖĺîϙťĺϙôĲŜŪŘôϙèıťϙŘôťÍĖĲôŘϙĖŜϙ Ŝôťϟ ͐͒Ͻ ťÍèħϙ͐͏XϙīæċϙĺĲϙèıťϙŘôťÍĖĲôŘ ͓͐Ͻ īÍèôϙ͓ϱΫЋϙťæČϙĖĲϙѭϯϱϙ͔XϙīæċϙťôĲŜĖĺĲϙÍťϙťēôϙŘôťÍĖĲôŘϙÍĲîϙÍŕŕīƅϙ͔͐͏͏ϙŕŜĖϙťĺϙ͓ϱΫЋϙſĺŘħŜťŘĖĲČϙƄϙ͖ЋϙèŜČϙ ÍĲĲŪīŪŜϙťĺϙôĲŜŪŘôϙŘôťÍĖĲôŘϙĖŜϙŜôÍīĖĲČϟϙϙīôôîϙÍĲĲŪīŪŜϙŕŘôŜŜŪŘôϙæÍèħϙÍťϙŜŪŘċÍèôϙÍċťôŘϙŜŪèèôŜŜċŪīϙ ťôŜťϟ bi(ϡϙϙťôŕŜϙ͐͒ϙЭϙ͓͐ϙċŪīƱīīϙŘôŗŪĖŘôıôĲťŜϙċĺŘϙ͑͏ϙϙ͔͑ϟ͐͐͑ϙϼČϽϙϼ͐Ͻ ͔͐Ͻ ťÍèħϙѭϯϱϙ͔XϙīæċϙÍťϙťēôϙŘôťÍĖĲôŘϙÍĲîϙôŜťÍæīĖŜēϙĖĲĤôèťĖĺĲϙŘÍťôŜϙſϯϙ͗ϟ͘ϙϭϯČÍīϙæŘĖĲô ͕͐Ͻ ϙôıôĲťϙŪıŕϙôŗŪĖŕıôĲť bi(ϡϙϙ(ĲŜŪŘôϙèıťϙîôīĖŽôŘôîϙĖŜϙÍèĖîϙŜĺīŪæīôϙŜĺϙſôϙèÍĲϙèīôÍĲϱŪŕϙÍĲƅϙŘôıÍĖĲîôŘϙĖĲϙťēôϙťæČϙſĖťēϙ ťēôϙŕŘôϱ@ϙŕĖèħīô ôťÍĖĲôŘώa"ώϼċťϽ æČώťŪæώϼċťϽ ˏώa"ώϼċťϽ ıťώ«ĺīώϼææīϽ ͖Гώıťώôťώťĺώ͒ϱ͐ϯ͑ГώæČώťŪæ ͕͖͐͏ ͕͔͐͗ ͔͐ ͏ϟ͕ æČώťŪæώϼċťϽ ®[(@ώϼċťϽ ͒ϱ͐ϯ͑ГώæČώťŪæώťĺώ͒ϱ͐ϯ͑Гώ®[(@ ͕͔͐͗ ͕͕͑͏ ͖͔ ͏ϟ͖ ®[(@ώa"ώϼċťϽ ťıώôŘċώѭώ͐͏͏ώϼċťϽ ͒ϱ͐ϯ͑Гώ®[(@ώťĺώ͐͏͏ϱċťώæôīĺſώťıώôŘċ ͕͕͑͏ ͕͓͗͘ ͕͓͒ ͓͑ϟ͒ ĺťÍīώ«ĺĖîώŕÍèôώæôīĺſώıťώôťÍĖĲôŘϡ ͔͑ϟ͔ ĺťÍīώ«ĺīŪıôώѭώ͐͏͏҇ώ(ƄèôŜŜϡ ͔͐ϟ͏ īÍĲĲôîώiώa"ώϼċťϽ ĺŕώĺċώ͖ГώıťώôťώϼċťϽ ˏώa"ώϼċťϽ ıťώ«ĺīώϼææīϽ īÍĲĲôîώiώĖĲώ͖ГώÍæĺŽôώıťώôť ͕͏͔͘ ͕͖͔͐ ͗͏ ͒ϟ͐ ĺťÍīώ«ĺīŪıôώťĺώæôώŪıŕôîϡ͔͓ ææīϯċť ææīϯ͐͏͏ϱċť ͖ГώŜČ ͏ϟ͏͕͖͒͗͑͑͏ ͒ϟ͕͖͗͑͑ ͒ϱ͐ϯ͑ГώæČ ͏ϟ͏͏͕͕͖͗͑͘ ͏ϟ͕͕͗͒͘ ͖ГώƄώ͒ϱ͐ϯ͑ГώĲĲŪīŪŜώϼIϽ ͏ϟ͏͕͕͖͑͒͑͏ ͑ϟ͕͕͖͒͑ ͖ГώƄώ͒ϱ͐ϯ͑ГώĲĲŪīŪŜώϼIϽώѭώ͒ϱ͐ϯ͑ГώæČ ͏ϟ͏͔͒͏͔͖͗͘ ͒ϟ͔͏͔͘͏ ͓ϱ͐ϯ͑ГϠώ͐͑ϟ͕ϭώIϱaĺîώſĺŘħŜťŘĖĲČ ͏ϟ͏͔͐͑͐͏͏͏ ͐ϟ͔͑͐͏͏ ͖ГώƄώ͓ϱ͐ϯ͑ГώſĺŘħŜťŘĖĲČώÍĲĲŪīŪŜ ͏ϟ͏͔͐͗͐͒͘͏ ͐ϟ͔͗͐͒͘ ώ͒ϱ͐ϯ͑ГϠώ͐͏ϟ͖͒ϭώb͒͐ώſĺŘħŜťŘĖĲČ ͏ϟ͏͏͗͒͗͏͔͘ ͏ϟ͗͒͗͐͏ ͖ГώƄώ͒ϱ͐ϯ͑ГώſĺŘħŜťŘĖĲČώÍĲĲŪīŪŜ ͏ϟ͏͕͕͖͑͒͑͏ ͑ϟ͕͕͖͒͑ ®ôīīēôÍîώa"ώϼċťϽ ôťÍĖĲôŘώa"ώϼċťϽ ˏώa"ώϼċťϽ «ĺīώϼææīϽ ͓ϱ͐ϯ͑Гώ®ώ«ĺīώċŘĺıώ®Fώťĺώıťώôť ͏ ͕͖͔͐ ͕͖͔͐ ͒͘ϟ͘ ôıôĲťώ«ĺīŪıôŜ ôīôŽÍĲťώIĲċĺŘıÍťĖĺĲ ŘĺŕĺŜôîώŪıŕώèēôîŪīô ĺťÍīώ«ĺīώſÍƅώϼѷææīŜϽ ĺııôĲťŜϡ ͔͓ ıťώÍſÍƅώϱώſÍŕώťĺώ͗ϟ͘ϭώæŘĖĲô ͓͘ ıťώÍťώŘôťÍĖĲôŘώſϯώ͓͏ώææīŜώ͗ϟ͘ϭώæŘĖĲôώÍſÍƅώæôēĖĲîώèıť ͓͓͐ ͔͏ώææīŜώèıťώťēŘŪώŘôťÍĖĲôŘώϼ͓ώææīŜώŘôıÍĖĲĖĲČώĖĲώ͓ϱ͐ϯ͑ГώťæČϽϠώèĺıôώîĺſĲώĺĲώťēô ŕŪıŕώÍĲîώŪĲŜťĖĲČώċŘĺıώèıťώŘôťÍĖĲôŘϟώώēĖŜώſĖīīώÍīīĺſώťēôώŘôıÍĖĲĖĲČώѭϯϱώ͓ώææīŜ èôıôĲťώťĺώċÍīīώĺŪťώťēôώæĺťťĺıώĺċώťēôώŜôťťĖĲČώťĺĺīώīôÍŽĖĲČώѭϯϱώ͐͏͏ϱċťώĺċώèôıôĲť ĺĲώťĺŕώĺċώťēôώèıťώŘôťÍĖĲôŘϟ ®ôīīϡ aϙFϱ͐͐ "ϡ ͖͐͘ϱ͕͐͒ Iϡ ͔͏ϱ͏͑͘ϱ͑͑͗͏͑ϱ͏͏ϱ͏͏ "Íťôϡ ͖͑ϙVŪīƅϙ͑͏͔͑ ͖͐Ͻ ŪıŕϙèıťϙÍæÍĲîĺĲıôĲťϙŜŗƏϙŕôŘϙťēôϙÍæĺŽôϙŘôèĺııôĲîÍťĖĺĲŜ bi(ϡϙϙIċϙĲĺϙŜŗƏϙŕŘôŜŜŪŘôϙîôŽôīĺŕŜϙÍĲîϙèıťϙŘŪĲŜϙÍſÍƅϙċŘĺıϙŪŜϠϙŕīÍĲϙċĺŘϙīôÍŽĖĲČϙÍîîĖťĖĺĲÍīϙ ŽĺīŪıôϙĖĲϙťēôϙťæČϙſēôĲϙſôϙČĺϙťĺϙŪĲϱŜťĖĲČϙċŘĺıϙťēôϙèıťϙŘôťϟ ͐͗Ͻ ŜϙĲĺťôîϙÍæĺŽôϠϙſϯϙѭϯϱϙ͓ϙææīŜϙŘôıÍĖĲĖĲČϙĖĲϙťēôϙťæČϙϼѭϯϱϙ͕͐͑ϙææīŜϙťĺťÍīϙŕŪıŕôîϽϙÍŕŕīƅϙѭϯϱϙ͐Xϙīæċϙ ťôĲŜĖĺĲϙÍĲîϙÍŕŕīƅϙŘĖČēťϱēÍĲîϙťĺŘŗŪôϙŪĲťĖīϙīÍťèēϙŘôīôÍŜôŜϙÍťϙťēôϙŘôťÍĖĲôŘ ͐͘Ͻ ϙ͑ϙĤťŜϙĖĲϙĺŘîôŘϙťĺϙÍīīĺſϙťēôϙŘôıÍĖĲĖĲČϙèôıôĲťϙťĺϙċÍīīϙĺŪťϙĖĲťĺϙťēôϙ͖ЋϙèŜČϙīôÍŽĖĲČϙèıťϙĺĲϙťĺŕϙĺċϙ ŘôťÍĖĲôŘ ͑͏Ͻ ŕĺĲϙŕŪīīĖĲČϙŪŕϙÍĲîϙīÍƅĖĲČϙîĺſĲϙ͑ϙĤťŜϠϙŕŪıŕϙ͗ϟ͘ϙϭϯČÍīϙæŘĖĲôϙťēôϙīĺĲČϙſÍƅϙÍťϙıÍƄϙŘÍťôϟϙϙĖŘèŪīÍťôϙ ÍťϙīôÍŜťϙĺĲôϙēĺīôϙŽĺīŪıôϙϼѭϯϱϙ͑͏͏ϙææīŜϽϟ bi(ϡϙϙŜϙĖĲîĖèÍťôîϙÍæĺŽôϠϙſôϙſĖīīϙŜťĖīīϙēÍŽôϙѭϯϱϙ͑͏ϱċťϙĺċϙèôıôĲťϙÍŘĺŪĲîϙťēôϙŜôťťĖĲČϙťĺĺīϙÍċťôŘϙ ŘôīôÍŜĖĲČϙċŘĺıϙťēôϙèıťϙŘôťÍĖĲôŘϙÍĲîϙŕŪīīĖĲČϙŪŕϙ͑ϙĤťŜϟϙϙĖŘèŪīÍťĖĲČϙĺŪťϙċŘĺıϙťēĖŜϙŕĺĖĲťϙŜēĺŪīîϙīôÍŽôϙ iϙѭϯϱϙ͕͏͔͘ϱċťϙa"ϙϼ͖͒͏͑ϱċťϙ«"Ͻ ͑͐Ͻ iiFϙſϯϙèıťϙŘôťÍĖĲôŘϙŜôťťĖĲČϙÍŜŜƅ ͑͑Ͻ ®ēôĲϙŘôèĺııôĲîôîϙťĖıôϙċĺŘϙèıťϙťĺϙŘôÍèēϙ͐͏͏͏ϙŕŜĖϙèĺıŕŘôŜŜĖŽôϙŜťŘôĲČťēϙēÍŜϙŕÍŜŜôîϠϙϙ͖Ћϙ èŜČϙÍĲîϙèıťϙŕīŪČϙťĺϙ͔͐͏͏ϙŕŜĖϙċĺŘϙ͒͏ϙıĖĲŜϙÍĲîϙŘôèĺŘîϙĺĲϙèēÍŘť bi(ϡϙϙIċϙſôϙŘôÍèēϙ͐͏͏͏ϙŕŜĖϙèĺıŕŘôŜŜĖŽôϙŜťŘôĲČťēϙÍĲîϙſôЍŘôϙŜťĖīīϙiiFϠϙŜťĺŕϙŕĖŕôϙıĺŽôıôĲťϠϙ èīĺŜôϙťēôϙŕĖŕôϙŘÍıŜϠϙÍĲîϙŕôŘċĺŘıϙťēôϙϟϙϙIċϙſôϙÍŘôϙĺŪťϙĺċϙťēôϙēĺīôϙťēôĲϙèīĺŜôϙťēôϙæīĖĲîϙŘÍıŜϙĺĲϙ ťēôϙiŜϙÍĲîϙŕôŘċĺŘıϙťēôϙϟ ͑͒Ͻ ŘôŕϙŘĖČϙƲĺĺŘϙċĺŘϙ(ϱ[ĖĲô ôťϙŪıŕϙħŘϡ ͓͑Ͻ aIϙ(ϱ[ĖĲô ÍϽ "Ūııƅϙ"ŘĖċťϙċĺŘϙôŘıÍĲôĲťϙħŘϙϼ͔ϟ͗͐͒ϱĖĲϙi"ϙƄϙ͔͒ϱĖĲϙīôĲČťēϽϙťĺ ϙ͓͐͏͏ϱċťϙa" æϽ [ĺČϙ͖ЋϠϙ͕͑ϭϙèŜČϙċŘĺıϙ͓͓͏͏ϱċťϙťĺϙŜŪŘċÍèôϙſϯϙ͓͏ϱÍŘıϙèÍīĖŕôŘϙÍĲîϙ@ϯ[ bi(ϡϙϙôŗŪôŜťϙŘŪŜēϙŕŘĺèôŜŜĖĲČϙĺċϙ@ϯ[ϙÍĲîϙÍīĖŕôŘϙ[ĺČϟϙϙĺĲťÍèťϙi(ϙÍĲîϙ@(iϙťĺϙ èĺŘŘôīÍťôϙťĖôϱĖĲϙĺċϙŕħŘϙŜôťťĖĲČϙîôŕťē èϽ aϙ͖ЋϙôŘıÍŕÍħϙôÍīϙĺŘôϙħŘϙťĺϙîôŜĖČĲÍťôîϙ®[XϙÍĲîϙŜôťťĖĲČϙèēÍŘČôϟϙϙIFϙťĺϙŜôťϙŕħŘϙſĖťēϙ ıĖîϱôīôıôĲťϙÍťϙѭϯϱϙ͓͏͕͏ϱċťϙa"ϙϼ͒͏͕͗ϱċťϙ«"Ͻ bi(ϡϙϙħŘϙŘôŗŪĖŘôŜϙÍťϙīôÍŜťϙÍϙ͒͏ϱŜôèϙæŪŘĲϙĺĲϙťēôϙſĖŘôīĖĲôϙŜôťťĖĲČϙťĺĺī ͔͑Ͻ "aiϙ(ϱ[ĖĲô ôŘċĺŘÍťôϙôŘťĖÍŘƅϙĲîôċϙ®ϙϼ͔͔͑͐͒͏Ͻϡ ͕͑Ͻ aϙ͓ϱΫЋϙ͐͑ŜŕċϙFϙ"³ϙϙ@ŪĲŜϙſϯϙŜŕÍèôŘŜϙÍŜϙŘôŗЍî ͖͑Ͻ IFϙĺĲϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙIϱaĺîϙſĺŘħŜťŘĖĲČϙťĺϙæŪıŕϙťēôϙŜŪıŕϙŕħŘϙÍĲîϙťĖôϱĖĲϙťĺϙŕôŘċĺŘÍťôϙťēôϙæôīĺſϙ ŜôīôèťôîϙĖĲťôŘŽÍīŜϡ bi(ϡϙϙaÍĖĲťÍĖĲϙēĺīôϙƱīīϙſēĖīôϙIF ͑͗Ͻ ĺĲƱŘıϙſôīīϙĖŜϙîôÍîϙÍċťôŘϙŕôŘċĺŘÍťĖĲČϟϙϙŪīīēôÍîϙ͗ϟ͘ϙϭϯČÍīϙæŘĖĲôϙÍŜϙŘôŗЍîϟ ®ôīī ĺŕϙa" ÍŜôϙa" ĺťÍīϙa" ĺŕϙ«" ÍŜôϙ«" ĺťÍīϙ«" IĲèϙÍťϙĺŕ ĖĲťôŘŽÍī IĲèϙÍť æÍŜô ĖĲťôŘŽÍī Fϱ͐͐͒͏͖͑ ͓͔͒͑ ͖͖͓͖͐͒͑͑͗͒͑ ͔͗ ͔͖ ͕͑ Fϱ͕͔͐͐͒͏ ͓͏͔͏ ͓͏͏͖͖͑͗͒͏͓͗ ͑͏͖ ͖͔ ͖͔ ͔͖͒Fϱ͐͐ϙi[ϙ(> * TIH with jointed pipe to tag TOC ~ 6095' MD. AOGCC to witness tag and pressure test to 1500 psi. - mgr ®ôīīϡ aϙFϱ͐͐ "ϡ ͖͐͘ϱ͕͐͒ Iϡ ͔͏ϱ͏͑͘ϱ͑͑͗͏͑ϱ͏͏ϱ͏͏ "Íťôϡ ͖͑ϙVŪīƅϙ͑͏͔͑ ͑͘Ͻ iiFϙÍĲîϙīÍƅϙîĺſĲϙϙÍŜŜƅϟϙϙ(ĲŜŪŘôϙÍīīϙŜēĺťŜϙƱŘôîϟ ͒͏Ͻ ŘôŕϙŘĖČϙƲĺĺŘϙċĺŘϙèīôÍĲĺŪťϙŘŪĲ īôÍĲĺŪťϙŪĲϡ ͒͐Ͻ aϙīôÍĲĺŪťϙFϡ ÍϽ ͑ϱ͖ϯ͗ЋϙŕŪŕϙſϯϙıŪīôŜēĺôϙϼѭϯϱϙ͔ϱċťϽ æϽ ³ϱĺŽôŘ èϽ ıĺĺťēϙi"ϙťŘĖĲČϙaĖīīϙċĺŘϙ͖ЋϠϙ͕͑ϭϙèŜČϙϼ͕ϟ͖͕͑ϱĖĲϙI"Ͻ îϽ ͓ϱίЋϙťŘĖĲČϙaÍČĲôť ôϽ ³ϱĺŽôŘ ċϽ ³³³ϙĤťŜϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙIϱaĺîϙſĺŘħŜťŘĖĲČϙťĺϙŜŪŘċÍèô ͒͑Ͻ IFϙťĺϙi ͒͒Ͻ īôÍĲĺŪťϙ͖ЋϙèŜČϙæƅϙŘĺťÍťĖĲČϯèĖŘèŪīÍťĖĲČϙſēĖīôϙIF ͓͒Ͻ ÍŘôċŪīīƅϙôĲťôŘϙŜôÍīϙæĺŘôϙĺċϙ͖ЋϙôŘıÍŕÍħϙôÍīϙĺŘôϙħŘϙťĺϙôĲŜŪŘôϙĖťϙĖŜϙèīôÍŘϙċĺŘϙĲÍŕϙ[Íťèē ͔͒Ͻ ϙťĺϙŜĺϙıŪīôŜēĺôϙĖŜϙĤŪŜťϙÍæĺŽôϙŕħŘϙÍĲîϙèĖŘèŪīÍťôϙÍϙ͑͏ϱææīϙČôīϙŕĖīīϙŜŪŘċÍèôϙťĺϙŜŪŘċÍèôϙťēôϙīĺĲČϙ ſÍƅϙſēĖīôϙÍīŜĺϙîĖŜŕīÍèĖĲČϙťēôϙſôīīϙťĺϙ͗ϟ͖ϙϭϯČÍīϙæŘĖĲôϙϼѭϯϱϙ͓͐͏ϙææīŜϽ ͕͒Ͻ iiFϙīÍƅĖĲČϙîĺſĲϙīôÍĲĺŪťϙFϟϙϙbĺťôϙÍĲƅϙîôæŘĖŜϙŘôèĺŽôŘôîϙĺĲϙıÍČĲôťŜϟ ͖͒Ͻ ŘôŕϙŘĖČϙƲĺĺŘϙċĺŘϙīĺſôŘϙèĺıŕīôťĖĺĲϙŘŪĲ [ſŘϙĺıŕīôťĖĺĲϙŪĲϡ ͒͗Ͻ aϙ@ϙèŘôôĲϙŜŜƅϙĺĲϙťēôϙŜèŘôôĲϙťÍæīôϙÍŜϙċĺīīĺſŜϡ bi(ϡϙϙèŘôôĲϙŜôèťĖĺĲϙŜēĺŪīîϙŜťÍŘťϙѭϯϱϙ͐͏ϱċťϙæôīĺſϙīĺſôŘıĺŜťϙŕôŘċŜϙÍĲîϙŜťĺŕϙѭϯϱϙ͐͏ϱċťϙÍæĺŽôϙ ŪŕŕôŘıĺŜťϙŕôŘċŜ ÍϽ ĲÍŕϱ[ÍťèēϙċĺŘϙ͖ЋϙôŘıÍŕÍħϙôÍīϙĺŘôϙħŘ æϽ ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔Ћϙ[͗͏ϙ((ϱ͗ŘîϙŜŕÍèôŘϙŕĖŕôϙÍŜϙĲôôîôîϙċĺŘϙŕĺŜĖťĖĺĲĖĲČϙĺċϙæťıϙĺċϙŜèŘôôĲŜϙѭϯϱϙ͐͏ϱċťϙ æôīĺſϙæťıϙŕôŘċĺŘÍťĖĺĲŜ èϽ ³ϱĺŽôŘϙ͑ϱ͖ϯ͗ЋϠϙ͕ϟ͔ϭϙ((ϱ͗ŘîϙŕĖĲϙƄϙ͓ЋϠϙ͘ϟ͔ϭϙV>(ϙôÍŘϙæĺƄ îϽ ͔͑ϙĤťŜϙ͓ЋϠϙ͘ϟ͔ϭϙ[͗͏ϙV>(ϙôÍŘϙæÍŜôŕĖŕôϙŜèŘôôĲŜϙƄϙ͒ bi(ϡϙϙϙèŘôôĲϟŘĺŕôŘťĖôŜϡ ͒ϟ͔͓͗ϱĖĲϙI" ͓ϟ͓͏͏ϱĖĲϙŜèŘôôĲϙi" ͒ϯ͗ЋϙēĺīôŜϙîŘĖīīôîϙÍťϙ͓͗ϙēĺīôŜϯċť ͏ϟ͏͐͑ϱČÍŪČôϙſĖŘôϙſŘÍŕϙϼ͘͏Ͻϙϯϙ͘͏«ϙŜèŘôôĲϙŘĖæŜ ͕ϟ͏͕͑ϱĖĲϙi"ϙ͓ϱæīÍîôϙèôĲťŘÍīĖƏôŘϙĺĲϙŕĖĲϙôĲî ôϽ ͗ϙĤťŜϙ͓ЋϠϙ͘ϟ͔ϭϙ[͗͏ϙV>(ϙôÍŘϙæÍŜôŕĖŕô bi(ϡϙϙôèĺııôĲîôîϙťĺŘŗŪôϙċĺŘϙ͓ЋϠϙ͘ϟ͔ϭϙV>(ϙôÍŘϡ aĖĲĖıŪı ͓͕͔͒ϙċťϱīæŜ iŕťĖıŪı ͖͓͔͒ϙċťϱīæŜ aÍƄ ͓͏͔͑ϙċťϱīæŜ ͒͘Ͻ ϙċÍīŜôϙŘĺťÍŘƅϙťÍæīôϙÍĲîϙèēÍĲČôϙēÍĲîīĖĲČϙôŗŪĖŕıôĲťϙĺŪťϙťĺϙÍèèĺııĺîÍťôϙ͑ϱ͖ϯ͗ЋϙſÍŜēŕĖŕô ͓͏Ͻ ϠϙaϠϙÍĲîϙIFϙſϯϙ͑ϱ͖ϯ͗ЋϠϙ͕Ϡ͓ϭϙ[͗͏ϙF͔͐͐ϙſÍŜēŕĖŕôϙĖĲŜĖîôϙĺċϙ@ϙèŘôôĲϙŜŜƅ bi(ϡϙϙôèĺııôĲîôîϙťĺŘŗŪôϙċĺŘϙ͑ϱ͖ϯ͗ЋϠϙ͕Ϡ͓ϭϙ[͗͏ϙF͔͐͐ϡ aĖĲĖıŪı ͖͏͏ϙċťϱīæŜ ®ôīīϡ aϙFϱ͐͐ "ϡ ͖͐͘ϱ͕͐͒ Iϡ ͔͏ϱ͏͑͘ϱ͑͑͗͏͑ϱ͏͏ϱ͏͏ "Íťôϡ ͖͑ϙVŪīƅϙ͑͏͔͑ iŕťĖıŪı ͗͏͏ϙċťϱīæŜ aÍƄ ͐͑͏͏ϙċťϱīæŜ ͓͐Ͻ ϙťēôϙF(ϙ@ϙħŘϙŜŜƅϟϙϙaϙťēôϙ͑ϱ͖ϯ͗ЋϙſÍŜēŕĖŕôϙťĺϙťēôϙF(ϙŪĲĲĖĲČϙĺĺīϙÍĲîϙaϙťēôϙæīÍĲħϙ æÍŜôŕĖŕôϙťĺϙťēôϙF(ϙ@ϙħŘϙŕôŘϙF(ϙĺĺīϙŪŕôŘŽĖŜĺŘЍŜϙîĖŘôèťĖĺĲ ͓͑Ͻ "ϙċÍīŜôϙŘĺťÍŘƅϙťÍæīôϙÍĲîϙèēÍĲČôϙēÍĲîīĖĲČϙôŗŪĖŕıôĲťϙĺŪťϙťĺϙÍèèĺııĺîÍťôϙ͓ϱΫЋϙťæČϙſĺŘħŜťŘĖĲČ ͓͒Ͻ IFϙıÍĖĲťÍĖĲĖĲČϙēĺīôϙƱīīϙťĺϙĤŪŜťϙÍæĺŽôϙ͖ЋϙôŘıÍŕÍħϙôÍīϙĺŘôϙħŘϟϙϙiæťÍĖĲϙϙÍĲîϙiϙſôĖČēťŜϟ bi(ϡϙϙŕÍèôϙĺŪťϙŜēĺŪīîϙťÍħôϙĖĲťĺϙèĺĲŜĖîôŘÍťĖĺĲϙťēôϙēôĖČēťϙĺċϙťēôϙ͓ϱΫЋϙťæČϙſĺŘħŜťŘĖĲČϙĺĲϙťēôϙŘĖČϙ ƲĺĺŘϙċĺŘϙŘĖČČĖĲČϙŪŕϙťēôϙ@ϙŕŪıŕĖĲČϙħĖť ͓͓Ͻ iϙĖĲťĺϙ͖ЋϙôŘıÍŕÍħϙôÍīϙĺŘôϙħŘϙŪĲťĖīϙŜťÍèħϙĺŪťϙĖŜϙĲĺťôîϟϙϙϙťĺϙŜĲÍŕϙĺŪťϙÍĲîϙèĺĲƱŘıϙīÍťèēϟ ͓͔Ͻ ôϱôĲČÍČôϙŜĲÍŕϙīÍťèēϙÍĲîϙϙťĺϙĲôŪťŘÍīϙŕĖŕôϙſôĖČēť ͓͕Ͻ ôťϙF(ϙF(ϙ«ϙħŘϙÍŜϙŕôŘϙF(ϙĺĺīϙŪŕôŘŽĖŜĺŘЍŜϙîĖŘôèťĖĺĲ ͓͖Ͻ ôŘċĺŘıϙ@ϙĺŕôŘÍťĖĺĲŜϙÍŜϙŕôŘϙF(ϙĺĺīϯŪıŕĖĲČϙŪŕôŘŽĖŜĺŘЍŜϙîĖŘôèťĖĺĲŜ ÍϽ @ôĲôŘÍīϙťôŕŜϡ ĖϽ aÍĲĖŕŪīÍťôϙF(ϙ@ϙĺĺīϙŜŜƅϙĖĲϙĺŘîôŘϙťĺϙŕĖèħīôϙſĺŘħŜťŘĖĲČϙſĖťēϙ͔͐҇ϙFīϙϼѭϯϱϙ͐͏ϙææīŜϽϙ ÍĲîϙîĖŜŕīÍèôϙĖťϙťĺϙťēôϙF(ϙ@ϙĺĺīϙŜŜƅϙſϯϙ͗ϟ͖ϙϭϯČÍīϙæŘĖĲô ĖĖϽ ôŽôŘŜôϙèĖŘèŪīÍťôϙŕĖèħīôϙċŘĺıϙťēôϙſĺŘħŜťŘĖĲČϙťÍħĖĲČϙŘôťŪŘĲŜϙťĺϙÍĲϙĺŕôĲϙťĺŕϙťÍĲħ bi(ϡϙϙ(ĲŜŪŘôϙĲôŪťŘÍīĖƏĖĲČϙÍČôĲťϙĖŜϙĺĲϙīĺèÍťĖĺĲ ĖĖĖϽ aÍĲĖŕŪīÍťôϙF(ϙ@ϙĺĺīϙŜŜƅϙťĺϙŕôŘċĺŘıϙŜťôŕϙŘÍťôϙĖĲĤôèťĖĺĲϙťôŜťϙÍťϙ͐Ϡϙ͑Ϡϙ͓ϠϙÍĲîϙ͕ϙæŕıϟϙϙ ēŪťϙîĺſĲϙŕŪıŕŜϙÍĲîϙŘôèĺŘîϙťæČϯèŜČϙŕŘôŜŜŪŘôŜ ĖŽϽ Ūıŕϙ@ϙſϯϙѭϯϱϙ͔͐XϙīæŜϙ͑͏ϯ͓͏ϙÍŘæĺīĖťô ͓͗Ͻ ŕĺĲϙŜŪèèôŜŜċŪīϙŕīÍèôıôĲťϙĺċϙ@ϠϙiiFϙÍĲîϙīÍƅϙîĺſĲϙťēôϙF(ϙŘŪĲĲĖĲČϙťĺĺīŜ ͓͘Ͻ ēÍĲČôϙēÍĲîīĖĲČϙôŗŪĖŕıôĲťϙĺŪťϙťĺϙÍèèĺııĺîÍťôϙ͑ϱ͖ϯ͗ЋϙſÍŜēŕĖŕô ͔͏Ͻ iiFϙ͑ϱ͖ϯ͗ЋϙſÍŜēŕĖŕô ͔͐Ͻ ŘôŕϙŘĖČϙƲĺĺŘϙċĺŘϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[͗͏ϙ³ϱϙŕŕôŘϙ(ϙèĺıŕīôťĖĺĲϙŘŪĲ ŕŕôŘϙ(ϙĺıŕīôťĖĺĲϙŪĲϡ ͔͑Ͻ (ĲŜŪŘôϙēÍĲîīĖĲČϙôŗŪĖŕıôĲťϙĖŜϙĺĲϱēÍĲîϙċĺŘϙŘŪĲĲĖĲČϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[ϱ͗͏ϙ³ϱϙèĺıŕīôťĖĺĲ ͔͒Ͻ aϙŕĺĺīôŘϙťĺϙŘŪĲϙ(ϙŕĺſôŘϙèÍæīô ͔͓Ͻ ϙ(ϙÍŜŜôıæīƅϙÍĲîϙIFϙĺĲϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[ϱ͗͏ϙ³ϱϙťæČϠϙıÍħĖĲČϙôīôèťŘĖèÍīϙèēôèħŜϙĺĲϙťēôϙ èÍæīôϙôŽôŘƅϙ͐Ϡ͏͏͏ϱċťϟϙϙIĲŜťÍīīϙèŘĺŜŜϱèĺŪŕīĖĲČϙèīÍıŕŜϙĺĲϙťēôϙƱŘŜťϙ͐͏ϙĤťŜϙťēôĲϙôŽôŘƅϙĺťēôŘϙĤťϙťĺϙ ŜŪŘċÍèôϟ bi(ϡϙϙôèĺııôĲîôîϙťĺŘŗŪôϙċĺŘϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[ϱ͗͏ϙ³ϱϡ aĖĲĖıŪı ͔͔͔͏ϙċťϱīæŜ iŕťĖıŪı ͕͖͐͏ϙċťϱīæŜ aÍƄ ͕͖͘͏ϙċťϱīæŜ ÍϽ aĺťĺŘϙôĲťŘÍīĖƏôŘϙϳϙÍŘČôťϙŜôťϙîôŕťēϙÍťϙ͑͒͏͏ϱċťϙa" æϽ "Fϙ@ÍŪČô èϽ ͔͕͑ϙ(ϙaťŘ îϽ [ĺſôŘϙôÍī ôϽ ŕŕôŘϙôÍī ċϽ IĲťÍħô ČϽ ͔͒͗ϙ(ϙŕŪıŕ ēϽ ͔͒͗ϙ(ϙŕŪıŕ ®ôīīϡ aϙFϱ͐͐ "ϡ ͖͐͘ϱ͕͐͒ Iϡ ͔͏ϱ͏͑͘ϱ͑͑͗͏͑ϱ͏͏ϱ͏͏ "Íťôϡ ͖͑ϙVŪīƅϙ͑͏͔͑ ĖϽ ĺīťϱĺĲϙ"ĖŜèēÍŘČôϙēôÍîϙſϯϙ͓ϱΫЋϠϙ((ϙ͗ŘîϙæĺƄϙŪŕ ĤϽ ³ϱĺŽôŘϙ͓ϱΫЋϠϙ͐͑ϟ͕ϙ((ϙ͗ŘîϙŕĖĲϙƄϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ³ϱϙæĺƄ ħϽ ϼ͐ϽϙĤťϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[ϱ͗͏ϙ³ϱϙťæČ īϽ ϼ͐Ͻϙ͓ϱΫЋϙ³bϙĲĖŕŕīôϙŕŘĺƱīôϙϼ͒ϟ͗͐͒ϱĖĲϙĺŘôϠϙ͒ϟ͖͔͑Ћϙbĺϱ@ĺϽϙſϯϙ͐͏ϱċťϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[ϱ͗͏ϙ³ϱϙ ēÍĲîīĖĲČϙŕŪŕŜ ıϽ ³³ϙĤťŜϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[ϱ͗͏ϙ³ϱϙťæČϙťĺϙŜŪŘċÍèô ĲϽ æČϙFČŘϙ³ϱĺŽôŘϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[ϱ͗͏ϙ³ϱϙŕĖĲϙƄϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙϙϱIIϙæĺƄ ͔͔Ͻ ϙÍĲîϙaϙťēôϙťæČϙēČŘϟϙϙaÍħôϙƱĲÍīϙŜŕīĖèôϙĺċϙťēôϙ(ϙèÍæīôϙťĺϙťēôϙŕôĲôťŘÍťĺŘϠϙaϙèĺĲťŘĺīϙīĖĲôϙťĺϙ ťēôϙťæČϙēČŘϙÍĲîϙîŪııƅϙĺƯϙÍĲƅϙÍîîĖťĖĺĲÍīϙèĺĲťŘĺīϙīĖĲôϙŕĺŘťŜϙĖċϙĲôèôŜŜÍŘƅϟ bi(ϡϙϙŜôϙèÍŪťĖĺĲϙſēôĲϙīÍĲîĖĲČϙťēôϙťæČϙēČŘϙŜĺϙÍŜϙťĺϙÍŽĺĖîϙîÍıÍČĖĲČϙťēôϙ(ϙèÍæīôϙĺŘϙ ŕôĲôťŘÍťĺŘϟ ͔͕Ͻ [ÍĲîϙťæČϙēČŘϙÍĲîϙŘôèĺŘîϙ®ϙÍĲîϙi®ϙĺĲϙťæČϙťÍīīƅ ͔͖Ͻ I["ϙÍĲîϙīÍƅϙîĺſĲϙīÍĲîĖĲČϙĤť ͔͗Ͻ ôťϙ«ϟϙϙb"ϙi(ϟϙϙôťϙϙīŪČϟ ͔͘Ͻ bϙťæČϙēôÍîϙÍîÍŕťôŘϟϙϙϙťæČϙēČŘϙŽĺĖîϙťĺϙ͔͏͏ϯ͔͏͏͏ϙŕŜĖϟ ͕͏Ͻ bϙ͓ϱ͐ϯ͕͐Ћϙ͔aϙťŘôôϟϙϙϙťŘôôϙ͔͏͏ϯ͔͏͏͏ϙŕŜĖϟ ͕͐Ͻ ŪīīϙϙŕīŪČϙÍĲîϙ« ͕͑Ͻ IĲŜťÍīīϙČÍŪČôŜϟϙϙôèŪŘôϙťŘôôϙÍĲîϙèôīīÍŘϟ ͕͒Ͻ "aiϙ ĺŜťϱĖČϙŘĺèôîŪŘôϡ ͐Ͻ ŪŘĲϙſôīīϙĺŽôŘϙťĺϙiŕŜϙŽĖÍϙēÍĲîĺŽôŘϙċĺŘı ͑Ͻ ϙſôīīϙēĺŪŜôϙÍĲîϙƲĺſīĖĲôŜ ͒Ͻ iϙŕôŘϙF(ϙŪııĖťϙťÍŘťŪŕϙŘĺèôîŪŘô ťťÍèēıôĲťŜϡ ͐Ͻ ŪŘŘôĲťϙ®ôīīæĺŘôϙèēôıÍťĖè ͑Ͻ ŘĺŕĺŜôîϙ®ôīīæĺŘôϙèēôıÍťĖè ͒Ͻ i(ϙèēôıÍťĖè Tree: 4 1/16” CIW Wellhead: 11"x 4-1/2" 5M FMC Gen 6 Tbg. Hgr.: 11” x 3.5” NSCT btm. x 4.5” NSCT top w/ 4” BPV profile. 7" landing collar (PBTD) DATE REV. BY COMMENTS Orig. DF Elev. = 67.0' (N 22E) Orig. GL Elev. = 37.0' Orig. DF to 7” csg hng. = 30.9’(N 22E) MILNE POINT UNIT WELL No : H-11i API : 50-029-22802 Perforation Summary Ref log: 08/08/98 CBT / GR Size SPF Interval (TVD) BP EXPLORATION (AK) 7" float collar (PBTD) KOP @ 500’ Max. hole angle = 74 to 75 deg. f/ 3600’ to 5600’ Hole angle thru' perfs = 49 deg. 7" float shoe 20" 91.1 ppf, H-40 SWS 51B UJ deep penetrating charges 112' Stimulation Summary none performed 7" 26 ppf, L-80, BTC mod production csg. ( drift ID = 6.276", cap. = 0.0383 bpf ) MPU H-11i 09-13-97 Howco 7” “ES” Cementer X Marker Joints two 21’ from 6272’-6313’ rkb M.Linder Drill and Case by Nabors 22-E 2113’ md 6918’ md 6958’ md 7002’ md 08/10/98 JBF Initial completion by Nabors 5S O 3.5” 9.3 ppf, L-80 8rd EUE (Cap. =0.0087 bpf, ID =2.992”) Minimum tbg. restriction = 2.75” ‘XN’ profile @ 6248’ md. 7” Baker Model S-3 pkr. 3-1/2" X-N nipple, 2.813" packing bore, 2.750" no-go 3-1/2" WLEG 3-1/2" ‘X’ Nipple (2.813" packing bore) 6179’ md 2385’ md 6192’ md 6248’ md 6260’ md 3-1/2" ‘X’ Nipple (2.813" packing bore) 2” 2” 4.5”5 6662’-6682’4057’-4070’ 2”4 6754’-6794’4117’-4143’ 4 4 6470’-6490’ 6514’-6520’ 2” guns SWS Powerjet 2006 perf charges 9/22/99 M. Linder Add 2” perforations 3933’-3946’ 3962’-3965’ 4.5”5 6682’-6702‘’4070’-4083’ 2 1/2“ BOT IBP (1.375” FN) (Set 07-04-10) 6730‘md Fish: 2-1/2“ BOT IBP (3” G FN) & Powerwave tool (OAL=36.89‘) CTU tagged at 6859’ CTM. 07-04-10 J. Perl Added fish and IBP to drawing _____________________________________________________________________________________ Revised By: TDF 7/31/2025 PROPOSED Milne Point Unit Well: MPU H-11 Last Completed: 8/9/1998 PTD: 197-163 TD =7,020’ (MD) / TD =4,293’(TVD) 20” Marker Joints (2) 21’ from 6,272 to 6,313 RKB DF Elev.:67’/ GL Elev.:37’ DF to 7” Casing Hanger: 30.9’ (Nabors 22E) 7” 2 4 & 5 7 8 9 10 TOC @ ±6,095’ Prince Creek PBTD =6,918’ (MD) / PBTD =4,225’(TVD) 3 Howco 7” ES Cementer @ 2,113’ MD 6 1 Fish: 2-1/2” BOT IBP 3” G FN & PW Tool OAL= 36.89. Tagged @ 6,859’ CTM 12 13 14 11Tubing Cut @ 6,185’ MD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / Welded N/A Surface 110' N/A 7" Production 26 / L-80 / BTC 6.276 Surface 7,002’ 0.0383 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP BTC 3.958 Surface ±3,025’ 0.0152 4” Tubing 9.5 / L-80 / JFE Bear 3.548 ±3,075’ ±4,075’ 0.0152 3-1/2" Tubing 9.3 / L-80 / NSCT 2.992 ±6,100’6,260’ 0.0087 JEWELRY DETAIL No Depth Item 1 ±X,XXX’ Discharge Head: 2 ±X,XXX’ Pump: 3 ±X,XXX’ Gas Separator: 4 ±X,XXX’ Upper Tandem Seal: 5 ±X,XXX’ Lower Tandem Seal: 6 ±X,XXX’ Motor: 7 ±X,XXX’ Sensor w/ 6 Fin Centralizer –Bottom @ ±2,300’ 8 ±2,762’ 7” Packer 9 ±X,XXX’ Screens 10 ±4,060’ 7” Packer 11 ±6,175’ Cement Retainer 12 6,192’ 7” Baker Model S-3 Packer 13 6,248’ 3-1/2” XN Nipple –Min ID 2.813 14 6,730’ 2-1/2” BOT IBP –1.375” FN PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Prince Creek ±3,072’ ±3,245’ ±2,747’ ±2,832’ ±173’ Future Future Prince Creek ±3,650’ ±4,050’ ±2,877’ ±3,084’ ±400’ Future Future Schrader 6,470’ 6,490’ 3,933’ 3,946’ 20’ 9/22/1999 Closed Schrader 6,514’ 6,520’ 3,962’ 3,965’ 6’ 9/22/1999 Closed Schrader 6,662’ 6,702’ 4,057’ 4,070’ 20’ 8/8/1998 Closed Schrader 6,654’ 6,794’ 4,117’ 4,144’ 140’ 9/12/2009 Closed Schrader 6,754’ 6,794’ 4,052’ 4,144’ 40’ 9/12/2009 Closed OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arctic set (Approx.) in 24” Hole 7” 1,262 sx PF ‘E’, 100 sx PF ‘C’142 sx ‘G’ in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 74 to 75 deg. f/ 3,600’ to 5,600’ Max Hole Angle through perforations = 49 deg. TREE & WELLHEAD Tree CIW 4-1/16” Wellhead 11” x 4-1/2”” 5M FMC. Tbg.Hgr., 11” x 3.5” NSCT btm. X 4.5” NSCT top w/ BPV profile GENERAL WELL INFO API: 50-029-22802-00-00 Drilled & Cased by Nabors 22E –9/4/1997 Completed by Nabors 5S –8/9/1998 Milne Point ASR Rig 1 BOPE 2025 Updated 7/31/2025 11” BOPE 4.48' 4.54' 2.00' INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: GraYScale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other - Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type 'OVERSIZED Logs of vadous kinds Other COMMENTS: Scanned by:~-'~~.Oaretha Nalhan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /si • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 OF Et! 7 2Or' December 30, 2011 Mr. Tom Maunder _ 16 3 Alaska Oil and Gas Conservation Commission 1 q 333 West 7 Avenue I I Anchorage, Alaska 99501 1 Subject: Corrosion Inhibitor Treatments of MPH -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPH -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 • 1 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10.404) MPH -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPH -01 1900860 50029220610000 Dust Cover NA NA NA 6.8 9/4/2011 MPH -02 1900870 50029220620000 Sealed Conductor NA NA NA NA NA MPH -03 1900880 50029220630000 Sealed Conductor NA NA NA NA NA MPH -04 1900890 50029220640000 Sealed Conductor NA NA NA NA NA MPH -05 1950980 50029225720000 1.3 NA 1.3 NA 11.9 8/17/2011 MPH -06 1951150 50029225800000 0.2 NA 0.2 NA 5.1 10/9/2011 MPH -07A 2020240 50029225970100 6 NA 6 NA 59.5 10/31/2009 MPH -08B 2010470 50029228080200 1.2 NA 1.2 NA 17.0 9/4/2011 MPH -09 1971650 50029228040000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -10 1971490 50029227950000 1.2 NA 1.2 NA 11.9 10/31/2009 --"* MPH -11 1971630 50029228020000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -12 1971700 50029228070000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -13A 2021670 50029228180100 0.8 NA 0.8 NA 8.5 8/17/2011 MPH -15 2051590 50029232840000 0.5 NA 0.5 NA 5.1 8/17/2011 MPH -16 2041900 50029232270000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -17 2070660 50029233580000 1.3 NA 1.3 NA 13.6 8/17/2011 MPH -18 2041740 50029232240000 18.6 NA Need top job MPH -19 2071360 50029233710000 0.1 NA 0.1 NA 2.6 9/4/2011 STATE OF ALASKA ALASKA O L AND GAS CONSERVATION COMMISSI~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ SET PKR Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ INJ TEST 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ , 197-1630 3. Address: P.O. Box 196612 Stratigraphic^ Service 0 .API Number: Anchorage, AK 99519-6612 50-029-22802-00-00 8. Property Designation (Lease Number) : `~ 9. Well Name and Number: , ADLO-380109 ~` MPH-11 10. Field/Pool(s): MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 7020 feet Plugs (measured) 6730' 7/4/10 feet true vertical 4292.88 feet Junk (measured) 6859' feet Effective Depth measured 6918 feet Packer (measured) 6192 true vertical 4225.5 feet (true vertical) 3757 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.1# H-40 32 - 112 32 - 112 1490 470 Surface Intermediate Production 6971 7" 26# L-80 31 - 7002 31 - 4281 7240 5410 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 3-1/2" 9.3# L-80 30 - 6260 30 - 3800 Packers and SSSV (type, measured and true vertical depth) 7" Baker S-3 Packer 6192 3757 ~C'~1VED 12. Stimulation or cement squeeze summary: ~ 4 Intervals treated (measured): JJ ~~~~yyFF ~ U i- ~~8Sk8 Qd St ~~ G~• G~~pp~ssion Treatment descriptions including volumes used and final pressur e: Rnctrorage 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 278 1598 Subsequent to operation: 458 669 14. Attachments: 5. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service', ^Q Daily Report of Well Operations X Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^~ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-190 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 7/12/2010 MPH-11 197-163 L~ Sw Name Operation Date Perf Operation Code PERF ATTACHME Meas Depth Top NT Meas Depth Base Tvd Depth Top Tvd Depth Base MPH-11 8/8/98 PER 6,662. 6,702. 4,057.54 4,083.6 MPH-11 9/22/99 APF 6,470. 6,490. 3,933.32 3,946.19 MPH-11 9/22/99 APF 6,514. 6,520. 3,961.65 3,965.52 MPH-11 9/22/99 APF 6,754. 6,794. 4,117.59 4,143.84 MPH-11 9/12/09 BPS 6,654. 6,794. 4,052.34 4,143.84 MPH-11 7/1/10 BPP 6,654. 6,794. 4,052.34 4,143.84 MPH-11 7/4/10 BPS 6,730. 6,735. 4,101.89 4,105.16 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • MPH-11 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY I [ 7/1/2010 CTU #8 Objective FCO/Set IBP : MIRU. MU/RIH w/ 1.75" DJ nozzle. Jet SBG from ` ~ surface @ 1 bpm/80 fpm in tubing & 20 fpm in liner. Jet to tag @ 6897'. Recip ,interval 6550'-6800' w/SBG 4 round trips. POOH. Let SBG soak. MU/RIH w/3" F Hyd. Spear.Tag fish @ 6898' stack 5k down. PUH to 6100' RBIH tag at 6896' stack ~5k PUH 2.5k overpull POOH """" Continued on 7/2/10'"*** 7 2/2010CTU #8 ""** Continued from 7/1 /10 '`*"* POOH check for fish. At surface no fish ad~ ~ ~ Hyd Cent to fishing string RBIH. Tagged at 6865' stack 5k repeat tag POOH check for fish. No fish. Modify fishing string by adding 2nd centralizer, one above and one I below jars. RIH. Tag fish @ 6859'. Attempt to latch fish. POOH to check. No fish. Cut pipe. MU/RIH w/ PDS mem GR/CCL w/ 2.65" JSN. Tag at 6865' make logging pass stop at 6550' paint white flag continue logging to 6100'. POOH ***"* Job continued on 7/3/10'"*'''`* 7/3/2010 CTU #8 ***** Continued from 7/2/10 ***** POOH w/ Mem. logging tools. At surface confirm good data. Correlate logs make +8' correction. MU/RIH w/ #1 treating packer. Correct depth at flag. Set at 6582.3' to avoid collar. Perform injectivity tests down coil @ 0.5 bpm /60 min. Perform inj down backside @ 0.5 & 0.7 bpm for 1 hour each. Pull release packer with 28k#. Let element relax 30 minutes. Pull pkr #1. MU/RIH w/ pkr #2. Tag @ 6171'. Can't pass. POOH, inspect BHA, no problems found. MU/RIH/ w/ jars/2.625" venturi. Venturi from 6100' to 6250' several passes. Continue ! to venturi to 6730' make several passes from 6700' to 6750'.POOH stop repaint flag. Check venturi nothing found that we should have tagged on. Perform weekly BOP test.***""" Job continued on 7/4/10"**** ._._._ _ _ .: _ __ e _ ._ ___~ 7/4/2010 CTU #8 ****** Continue from 7/3/10 *"""*" Finish weekly BOP test. MU/RIH 2.5" BOT !#~iq~.R.~c ,.Stop at setting depth drop 1/2" steel ball. Packer set stack down 2k perform njectivity test of 0.5 bpm /60 min's down coil, stack 4-5k on prk, repeat injectivity down backside @ 0.5 bpm/60 min's. Pull release @ 27k#. Relax element. ~ POOH. All treating packer elements/rubber were retrieved. MU/RIH w/ 2.5" IBP. Max DP on this IBP is 2300 psi. Correct depth at flag. Set 2.5" IBP @ 6730' mid .element. Stack 3k#, confirm set. FP wellbore. Job is complete. RDMO. FLUIDS PUMPED BBLS 18 METH 688 KCL 165 SBG 871 Total W head161 x14-1/2" 5M FMC teen 6 MPU H-11 i Tbg. Hgr.: 11" x 3.5" NSCT btm. x 4.5" NSCT top w/ 4" BPV profile. f i 20" 91.1 ppf, H-40 112' Orig. DF Elev. = 67.0' (N 22E) Orig. GL Elev. = 37.0' Orig. DF to 7" csg hng. = 30.9'(N KOP @ 500' Howco 7" "ES" Cementer 2113' and Max. hole angle = 74 to 75 deg. f/ 3600' to 5600' 3-1/2" 'X' Nipple 2385' and Hole angle thru' perfs = 49 deg. (2.813" packing bore) 3.5" 9.3 ppf, L-80 8rd EUE (Cap. =0.0087 bpf, ID =2.992") 7" 26 ppf, L-80, BTC mod production csg. ( drift ID = 6.276", cap. = 0.0383 bpf ) Minimum tbg. restriction = 2.75" 'XN' profile @ 6248' md. 3-1/2" 'X' Nipple 6179' and Stimulation Summary (2.813" packing bore) none performed 7" Baker Model S-3 pkr. 6192' and 3-1/2" X-N nipple, 2.813" 6248' and " packing bore, 2.750 no-go Perforation Summary Ref loa: 08/08/98 CBT / GR 3-1/2" WLEG 6260' and Size SPF Interval D) 2" 4 6470'-6490' 3933'-3946' Marker Joints two 21' from 6272'-6313' rkb 2" 4 6514'-6520' 3962'-3965' 4.5" 5 6662'-6682' 4057'-4070' 4.5" 5 6682'-6702" 4070'-4083' 2" 4 6754'-6794' 4117'-4143' 2 1/2" BOT IBP (1.375" FN) 6730`md (Set 07-04-10) SWS 51 B UJ deep penetrating charges 2" guns SWS Powerjet 2006 pert charges 7" landing collar (PBTD) 6918' and ~ .w_ Fish: 2-1/2" BOT IBP (3" G FN) & °~ ' 7" float collar (PBTD) 6958' and ) CTU tagge Powervvave tool (OAL=36.89 at 6859' CTM. 7" float shoe 7002' and DATE REV. BY COMMENTS MILNE POINT UNIT 09-13-97 M.Linder Drill and Case by Nabors 22-E WELL No : H-11i 08/10/98 JBF Initial completion by Nabors 5S API • 50-029-22802 9/22/99 M Linder Add 2" perforations . 07-04-10 J. Perl Added fish and IBP to drawing BP EXPLORATION AK • 5~ ~~p~l~ 0[~ Q~Q~~Q /,~,M.~E..w~.~ Keith Lopez Pad Engineer BP Exploration (Alaska), Inc. ~,~~~;~~ ~~?~~! `~ ~~~~' P.O. Box 196612 ~.' ~~ Anchorage, AK 99519-6612 ~ ~ 7 Re: Milne Point Field, Schrader Bluff Pool, MPH-11 Sundry Number: 310-190 Dear Mr. Lopez: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~? day of June, 2010. Encl. STATE OF ALASKA ' ;,p,.~A ALAS~IL AND GAS CONSERVATION COMMISS~ fit' APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~Il~ ,'~~ ,~~ 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate^ Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ Other: Set gackerr 2. Operator Name: 4. Current Well Class: 5. Permit to DriII Number. TsrF BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 197-1630 • 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-22802-00-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ MPH-11 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-380109 Milne Point Field / SCHREADER BLUFF Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7020 4292.88 6918 4225.5 6647 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.1# H-40 32 112 32 112 1490 470 Surtace Intermediate Production 6971 7" 26# L--80 31 7002 31 4281 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached - - 3-1/2" 9.3# L-80 30 6260 Packers and SSSV Tvoe: 7" Baker S-3 Packer Packers and SSSV MD and TVD (ftl: 6192 3757 12. Attachments:.. Description Summary of Proposal ^ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/5/2010 Oil ^ Gas ^ WDSPL ^ Suspended ^ 16. Verbal Approval: Date: WINJ ^~ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kieth Lopez Printed Name Kieth Lopez Title pad Engineer Phone Date Signature ~ 564-5718 6/21/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY N mb it S d diti f l N tif i i th t t ti C C 2 er: /~ ~ - ~~ O ~ un ry u on ons o approva : o y omm ss on so a a represen a ve may w ness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ~~~EIVEp Other: Sl~~l ~ ~. 2010 Alaska 011 & gar Ces~:. Cotrimi Subsequent Form Required: /~ ~- yQY ~,I?~:C1A60Q APPROVED BY ~ / Approved by: COMMISSIONER THE COMMISSION ~ ~~ ~~ Date: Form 10-403 Revised 1/2010 ORIGINAL GzB~io ~sien .~. ~.~4_.~~ Submit in Du ~ ,~,/,~ - l /` MPH-11 197-163 PERF ATTAC`I-IMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPH-11 8/8/98 PER 6,662. 6,702. 4,057.54 4,083.6 MPH-11 9/22/99 APF 6,470. 6,490. 3,933.32 3,946.19 MPH-11 9/22/99 APF 6,514. 6,520. 3,961.65 3,965.52 MPH-11 9/22/99 APF 6,754. 6,794. 4,117.59 4,143.84 MPH-11 9/12/09 BPS 6,654. 6,794. 4,052.34 4,143.84 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • by To: MPU Field Ops TL Date: June 1, 2010 From: Subject: Keith Lopez, Tract 14 Pad Engineer MPH-11 Coil Cleanout 8~ Injection Test AFE: AMSHPDWL11 IOR: 150 BOPD Please perform the followin well work on MPH-11: Step Type Procedure 1 C Cleanout and Pull Inflatable Packer 2 C Set Treating packer and Injection Tests. Set IBP. ' Current Status: Operable Produced Water Injector Current Injection: 6/1/10: 677 bwpd at 664 psi Max Deviation: 71-75° through 3515-5658'MD Min. ID: 2.75" through 2-7/8" XN-Nipple at 6248'MD Last TD tag: 2/11/10: Tagged Schmoo at 6517'MD w/ S-Bailer Last Downhole Ops: 02/11/10: SL tagged with S-Bailer at 6517' 09/12/09: Coil set Inflatable Packer @ 6647' Latest H2S level: N/A BHP/BHT: 07/25/06: 1926 si 4000'TVDss / 72°F Objective: The objective of this well intervention is to: 1) Jet well clean of Schmoo to top of the IBP (IBP may have moved) 2) Retrieve Inflatable Packer 3) Set treating packer between N perfs (6470'-6520') and OA perfs (6662'-6702'). Perform injection tests down coil and down the annulus separately. 4) Release treating packer and reset between OA perfs (6662'-6702') and OB perfs (6754'- 6794'). Perform injection tests down coil and down the annulus separately. 5) Set IBP @ 6730'. Well History: MPH-11 i is an offset injector to two ESP producers MPH-09 (LTSI) and MPH-10 (Exhibiting High GOR). The well is perforated in the NB/NC/OA & OB intervals with target injection of 600 bwpd (1000 psi WHIP) '/ Due to concerns of increasing water cut trend observed in MPH-10i, a red-dye tracer test was performed on 3/14/2009 which showed a connection between H-11 i and H-10 (producer) with a transient time of 16 minutes for 7.2 bbls of red-dye water to come though. Two IPROF's have been run in the past yielding inconclusive results except that little to no water is entering the N sand. MPH-11 RETRIEVE IBP, PERFORM INJECTION TEST, AND IBP SET Page 1 of 2 r~ r~ The recent production trends on MPH-10 raises questions about the possibility of one of the O sands being mature/depleted and acting as a thief or potential of an imminent catastrophic breakthrough with MPH-11 i. Plan Forward: The plan forward is to jet to the top of the Inflatable Packer (may have moved down the hole). Then, the Inflatable Packer will be retrieved. A treating packer will then be run and set between the N and OA perfs and injection tests performed down the coil and down the annulus to determine the injectivity. The treating packer will then be moved and set between the OA and OB perfs and injection tests performed down the coil and down the annulus to determine the injectivity. Finally, an IBP will be set between the OA and OB sands. Curl 1) MIRU Coil 2) RIH w/ JSN jetting with hot diesel till Inflatable Packer #agged @ 6517' (may have moved downhole). Take returns to the formation (Fluff and Stuff). POOH. • Min ID is 2.75" through 2-7/8" XN-Nipple at 6248'MD • Previous Tag on 02111/10: Tagged Schmoo at 6517'MD w/ S-Bailer 3) RIH & retrieve Inflatable Packer set @ 6647' (may have moved downhole). 4) RIH w/ treating packer and set @ 6600' tied into PDS' Coil Flag log dated 9112/09. Inject down coil @ 0.5 bpm for 1 hour with produced water. Shut down injection down coil and bring on injection down backside (tubing & coil) at 0.5 bpm for 1 hour with produced water. Release treating packer, POOH, and redress packer. 5) RIH w/ treating packer and set @ 6730' tied into PDS' Coii Flag log dated 9/12/09. Inject down coil @ 0.5 bpm for 1 hour with produced water. Shut down injection down coil and bring on injection down backside (tubing & coil) at 0.5 bpm for 1 hour with produced water. Release treating packer and POOH. 6) RIH w/ IBP and set @ 6730' tied into PDS' Coil Flag log dated 9!12/09. 7} RDMO. MPH-11 RETRIEVE IBP, PERFORM INJECTION TEST, AND IBP SET Page 2 of 2 ~Tree~4 1/16" CIW Wellhead: 11 "x 4-1/2" 5M FMC Gen 6 M P U Tbg. Hgr.:11" x 3.5" NSCT btm. x 4.5" NSCT top w/ 4" BPV profile. . 20" 91.1 ppf, H-40 112' 3.5" 9.3 ppf, L-80 8rd EUE (Cap. =0.0087 bpf, ID =2.992") 7" 26 ppf, L-80, BTC mod production csg. ( drift ID = 6.276", cap. = 0.0383 bpf ) Minimum tbg. restriction = 2.75" `XN' profile @ 6248' md. Stimulation Summary none performed Perforation Summary Ref loa: 08/08/98 CBT / GR Size SPF Interval D) 2°° 4 6470'-6490' 3933'-3946' 2" 4 6514'-6520' 3962'-3965' 4.5" 5 6662'-6682' 4057'-4070' 4.5" 5 6682'-6702" 4070'-4083' 2" 4 6754'-6794' 4117'-4143' SWS 51 B UJ deep penetrating charges 2" guns SWS Powerjet 2006 perf charges H -11 i Orig. DF Elev. = 67.0' (N 22E) Orig. GL Elev. = 37.0' Orig. DF to 7" csg hng. = 30.9'(N 2113' and 2385' and Howco 7" "ES" Cementer 3-1/2" `X' Nipple (2.813" packing bore) 3-1/2" `X' Nipple (2.813" packing bore) 7" Baker Model S-3 pkr 6179' and 6192' and 3-1/2" X-N nipple, 2.813" 6248' and packing bore, 2.750" no-go 3-1/2" WLEG 6260' and Marker Joints two 21' from 6272'-6313' rkb 2 1/2" BOT IBP w/ 3" GS fish neck & .50 ID (Set 9/12/09) Power Wave Tool 6647' 6684' 7" landing collar (PBTD) 6918' and ~a n__a __n_._ ir~r~-rr~• .....-... II~ PaoAcrivE DiayNOSric SeevicES, Inc_ ESL LC1f To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ~"°~ " ~~~~ BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: [907) 245-8952 1) Injection Profile 15-Jun-0B MPU H-1 1 BL / EDE 2) Signed Print Name: Date 50-029-22802-00 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~ WEBSITE C 7-0cumrnts and Settings?Diane Williazns DesktooiTrunsmit._BP.docs e e \<:;'\- \~~ MECHANICAL INTEGRITY REPORT ...... '-""UD ,..,.~- .: :-' iJ ..:._ ,;.::. : 1ft -<; ~_. .rl-~ q/î.ø-;" OPER & FIELD -~.? M\\~fC \?d',~~ kV\\-\\ (~~'\ :. i G R E L ~;_ s ~ : w'"ELL NUMBER 7rt t:.LL DAI_f._ TD :~O òO . MD.. t.tÕ~~ TVD; :? E TD: Co q \ <6 MD 4ððÇ TVD _::"":ìer: 'l Shoe: "1Cl)~J till \-) ~ Shoe: MD £ l{ '-\ t'. Z) ;) P acke:r- ~ \, ';), MD TVD j DV: d \\?:> MD ·'Ivu Cë..S Ì'::g: TVD; :CP: HD ::~;D -=-~'oi.:;g: TVD i Set. ê. i: ~d(Q ê) P er£s Col-\'\.Q i:o (, '\ ~ ~ '. ::ale Si.z.e G. t{ C> 7). ê.nci :"SC?.Þ-.l-EC;'.L INTEGRITY - PART il Annulus Press Test: ~p 15 min 3 0 ml..n Com::oents: M\\ 'o"t ~ <=-lO/~4.-= 0 ~ l- ,..,- :-Œ:CHJÜfICAL INTEGRITY - PART 12 \<è.ø..'0 ~OSc¡.~ ~ \\1>~\<> ~\ ~ \4';) ~", ~ 5;)\o\:>\.S \~\-S~1è Ce!llenc VohImes:' P-..mt. Liner ~~ ; Csg ; DV Cwi: -JO 1 to cove:c peri s Q '50"20 '" ~ çç ~s~ <;'0t,.C;~~\.\o Lð\j(Ç \'.. '~p ~\ç ,,\ù~ :00' Ih e or e C i c al TOC \ ~ \- s\cs~ ~ -\~'f-~'~:c..S- ~ . "eocl.c;,..\e..~€.:~ \ d",J S~..cc,S\--o0Çj ~~. à(L0h~i) .~ Cement Bond Log (Yes or No) 1k..'<7 CEL ~valuation, z.one ë..DOVe perfs t; (). ~() 0Cc:. ~w·la\Ü.~\ 0 \'-~ ; In AOGCC File . 'Y.~",> ~C>~ ~\.JtÐ<ê~\o..c~t;.~ Prociuction Log: Type Evaluation CONC.LUSIONS: ~x ~s"'à(lMo~ç.~y. .. ~:ç- '\:c.." t~ ~~ \Q:.c.O'--*'<~ Þtf1'tÆ..,,¡ ",-oy ? ar i: t 1 : ? ar:: : 2 : fJjfl.) , H -! I MECRAN'AL INTEGRITY REPORT' ....... e lzr:¡-¡-b3 --G"'~'-'''''- :....!- t\.;:'l..,¡'::'.r.~ ~ : 'ß}. bC¡ 1"'11 ~¡bI4i OPER & FIELD 5'px /I/¡PU 3?UD DA:E: w'"ELL NUMBER l1,- 1-6~ ' "Zb~ Casing:?" 1-'80 Shoe: -=1002..\ HD TD: "7025 . MD. -42.-'13 TVD j :?ETD: b9 ì 8 till ..If 22..5" TVD 7rt ~LL DATA TVD¡ DV: MD .1'\11) TVD; :CP: l-m ;:'ID i,'2..i::,t:) . TVD¡ Set ê.t Perfs bbb'Z.- to b"1oZ. ~::"":ìer: Shoe: £-ill '112-~ '::'ubi::g: 'ß'h.. 1..-,8ð Packe:r b\e¡2....' till Eole Size ô'I2-" anci ~CHÞ-.lnc;..L INTEGRITY - P.tŒ.T ¡ 1 Annulus Press Test: ~? 15 ml.n 30 min Comments: ,.......- MECHÞJECÞ-L INTEGRITY - PART 12 n;.z'9' PF"£' ¡OO 1:,'; PF t.. Csg 11-2.5>' 6 j DV Cement: Volumes:' )...mt. Liner C~i: ~ol to cove:c Deris ¡"UIOo ::. .!g,~6~j/~- Ie:- .... - ~I:, 5 .. þf """..., 0,1 ~. S'Iz. ~ . ~5 bß Lj 002. - i:/ìia}" 1'6 '34.:. .¡... (10'2.0- ':¡O¡8J^ . '?~68 i- l":f oo? - bbb zJ ~.i 053 ~ "52.. ,ð¡ sx f X'5Yz.~ -:::- . J08 ~ Iheo:ce tical TOC Cement Bond Log (Yes or No) ,.- :1Q"J5' bbb2-- ¡ L ¡S'o 4- ~S2.-4 J -:- dOSS I-=::. 01 .......- - In AOGCC File 'LS~ ," ,.s '(t- CBL ~valuation, zone aDove perfs !\r)SQ.UA-r¿ bOIJC;\i^.JG p, p...,oV'E...- PtE.fiJ-:::-:5 . Prociu~tion Log: Type Evaluation CONCLUSIONS: Part #1: P ar:: : 2 : t.J\ 1 l~ Ì ¡JD!¿A-¡~-hrJ ¡uN¡ " // ~l-'L¡ð:o' I ¡ ¿"-.;! i 1 , , e ~1r~1rŒ mJ~ e fM Cše ~ í~,\ n¡) ì U.J,~ FRANK H. MURKOWSKI, GOVERNOR A.TIA.~1iA. ORAND GAS CONSERVATION COMMISSION 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Kristin Krom Production Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPH-11 Sundry Number: 306-114 \ q1- 1193 Dear Ms. Krom: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thiSmay of March, 2006 Sincerely, Encl.· MPH-II i FCO & acid stirn e e Subject: MPH-11 i FCO & acid stim From: "Krom, Kristin L" <Kristin.Krom@bp.com> .Date: Fri, 24 Mar 2006 10:36: 19 -0900 To: tom_maundcr@admin.state.ak.us Tom- Please use this email as confirmation that there is an error on the application for sundry that was submitted today for injector MPH-11. We are hoping to perform this job March 31, not May 31 as the application states. Thanks for catching that! Thanks, Kristin Krom ACT Production Engineer 907-564-5850 1 of 1 3/24/2006 10:50 AM _ STATE OF ALASKA e A~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ...... ." RECEIVED MAR 2 4 2006 Alaska Oil & G C 20 AAC 25.280 as ons. f'^~ . 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate U waiverTI'ÄnchorageOther U Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development 0 Exploratory 0 197-1630 3. Address: P.O. Box 196612 Stratigraphic 0 Se rvice ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22802-00-00 7. KB Elevation (ft): 9. Well Name and Number: 67.9 KB MPH-11 8. Property Designation: 10. Field/Pools(s): ADL-380109 Milne Point Field 1 Schrader Bluff Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): ITotal Depth TVD (ft): IEffective Depth MD (ft): Effective Depth TVD (ft): I Plugs (measured): IJUnk (measured): 7020 4292.88 6918 4225.5 None None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.1# H-40 32 112 32 112 1490 470 Production 6971 7" 26# L -80 31 7002 31 4281 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6470 - 6794 3933.32 - 4143.84 3-1/2" 9.3# L-80 30 - 6260 Packers and SSSV Type: 7" Baker S-3 Packer Packers and SSSV MD (ft): 6192 12. Attachments: Descriptive Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Se rvice ~ 14. Estimated Date for :3 P~\ <é.~\ \~ 15. Well Status after proposed work: Commencing Operations: ft31/2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: '0" IIWAG 0 GINJ 0 WINJ ~ WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kristin Krom Printed Name " Kristin Krom Title Production Engineer Signature ~ A.. 0 ^'~ Phone 564-5850 Date 3/23/2006 '~-J " COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness ISUndry Number: âJlD -1l4 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Subsequent Form Required: 7ž4~~ APPROVED BY Date: 3~ ¡if-Of; Approved by: COMMISSIONER THE COMMISSION -' (/ L/ .,~ Form 10-403 Revised 7/2005 DUPLI CA TE RBDMS BFL MARZ 8 2006 ( Submit in Duplicate ..,' e e BP Exploration Alaska Milne Point To: John Cubbon/Clint Spence MPU Well Operations Supervisor Date: 3/22/06 From: Kristin Krom Schrader Bluff Production Engineer lOR: AFE: COST: 200 bopd MSHPDWLll $75,000 Subject: MPH-lli CTU FCO to TD OBJECTIVES: Perform CT FCO to provide access to lower perf zones and allow injection support to return to full OA and OB zones. S or E 2 BACKGROUND MPH-lli is offset injector to ESP producers MPH-09 and MPH-I0 (both currently SI with ESP problems). The well contains perfs in the NB, NC, OA, and OB intervals. Target injection is 500 bwpd while remaining below 830 psi injection pressure. The last IPROF on this well as run 6/15/01 and indicated splits of 21 % NB, 0% NC, 61 % OA, and 18% OB. This IPROF was performed following a CT jetting and acidizing of the perfs. Recently (3/4/06) SL was drifting for the IPROF and tagged bottom at 6687'MD. This depth indicates 15 feet of OA perfs and all OB perfs are covered by fill. Based on this observation, all injection is going into the NB, NC, or OA zones. It is necessary to reestablish injection into the OB in order to properly support MPH-09 and MPH-I0. In order to restore injection to the OB in the area a CT FCO is required. Note: Following restoring injection into MPH-ll, producer MPH-I0 (which is currently SI with an ESP problem, but also for reservoir management) will be returned to production not long after, provided a well test shows lower GORs. Note: ~\h\l --") "J,,"," I~ ~~)/~,-\ *The tbg size is ~and the production liner is 7". *Min ID = 2.75" @ 6248'MD (XN Nipple) .'~ ' . e e *Max angle 75deg. 74-75 degrees from 3600-5600'MD, Max DLS 5.3 deg at 6226' MD DETAILED PROGRAM: Cate20ry Step Description C 1 · RIH, FCO to TD with venturi nozzle and dead crude · RIH, jetting perfs with 2% KCL to TD. · Switch to 12% Dad acid, reciprocate 20 bbls acid across perfs focusing on specific perf depths (6470-6520'MD, 6662-6794'MD). · Shut down for a 15 min soak period after first pass across perfs. · Continue acid wash with additional 20 bbls. Flush perfs with at least 50 bbls of produced water or 2% KCl. Do not POOH until overflush is behind pipe. · POOH. Ifpossible, return well to injection immediately to flush acid and precipitates away from wellbore. 1. Minimum I.D.: 2.75" at XN 6248' MD 2. Pressure: SBHP was 2016 psi @ 4000' TVDss (0.421 psi/ft) on 9/25/03 (pressure has likely dropped in area since then) 3. Inclination between 74° and 75° from 3600' MD to 5600' MD 4. Hole angle through perfs 70°. SorE 2 IPROF (Program on WBL). POINTS OF CONTACT: Production Engineer: Kristin Krom Office: 564-5850 Home: 345-5766 MPU Wells Operation Supervisor: John Cubbon & Clint Spence Office: 670-3330 DISTRIBUTION: MPH-lli Anchorage Well File MPU Admin. Assistant North Slope MPH-1li Well File MPU Ops Supervisors MPU Ops Coord 1 & 2 ""frt:e: 4,'1/16" CIW a MPU H 11- Wellhead: 11 "x 4-1/2" 5M FM~n 6 - I Tbg. Hgr.: 11" x 3.5" NSCT btm. x 4.5" NSCT top w/ 4" BPV profile. 20" 91.1 ppf, H-40 I 112' KOP @ 500' Max. hole angle = 74 to 75 deg. f/ 3600' to 5600' Hole angle thru' perfs = 49 deg. 3.5" 9.3 ppf, L-80 8rd EUE (Cap. =0.0087 bpf, 10 =2.992") 7" 26 ppf, L-80, BTC mod production csg. ( drift 10 = 6.276", cap. = 0.0383 bpf ) Minimum tbg. restriction = 2.75" 'XN' profile @ 6248' md. Stimulation Summary none performed Perforation Summary Ref log: 08/08/98 CBT / GR Size SPF Interval (TVD) 3933'-3946' 3962' -3965' 4057'-4070' 4070'-4083' 4117'-4143' 2" 4 2" 4 4.5" 5 4.5" 5 2" 4 6470' -6490' 6514'-6520' 6662' -6682' 6682' -6702" 6754'-6794' SWS 51 B UJ deep penetrating charges 2" guns SWS Powerjet 2006 perf charges u ........................................... ........ ...... ",.... ....................... ........................................... ........................................... ........................................... ........................................... e Orig. OF Elev. = 67.0' (N 22E) Orig. GL Elev. = 37.0' Orig. OF to 7" csg hng. = 30.9'(N 22E) Howco 7" liES" Cementer 12113' md 3-1/2" 'X' Nipple 12385' md (2.813" packing bore) 3-1/2" 'X' Nipple (2.813" packing bore) 7" Baker Model S-3 pkr. 16179' md I 1 1 1 16192' md 3-1/2" X-N nipple, 2.813" 1 6248' md packing bore, 2.750" no-go 3-1/2" WLEG 16260' md Marker Joints two 21' from 6272'-6313' rkb 7" landing collar (PBTO) 7" float collar (PBTO) 7" float shoe 6918' mdl 6958' md I 7002' md I DATE REV. BY COMMENTS MILNE POINT UNIT 09-13-97 M.Linder Drill and Case by Nabors 22-E WELL No: H-11i .,08/10/98 JBF Initial completion by Nabors 5S API : 50-029-22802 9/22/99 M. Linder Add 2" perforations BP EXPLORATION (AK) " .~-.I MEMORANDUM TO: Mike Bill"~c Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 24, 2002 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder- /~'~-?~.,,.,,,~ BPX P.I. Supervisor ~\,(~...O~-~ UPU ~ H-11 FROM: John Cdsp :L-42 Petroleum Inspector Milne Point Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. We,,I H-~4 I Type,nj.I P IT'V'D' I 37S8 I Tubing14450 1~450 14450 1~450 I,nte~,a,I 4 P.T.D.I 1971630 ITypetestl P ITestpsil ~500 I Casingl 0 I ~600 I ~580 I ~SS0 I P/F I P Notes: I L-42 P! T.V.D. [ 7o2s I T~b,ngl 2sSo I I I I, erva, I 4 P.T.D.I 1980186 ImypetestI P ITestpsil 2000 I Casingl 0 I 2000 I 4950 I ~9301 P/F I P Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: IType Inj. Type test Type Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER I NJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal RadioaclJve Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= InilJal Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Well H-11 has no OA to monitor during MIT. The OA pressure on L-42 was 0 before MIT began. The OA psi on L-42 increased to 250 psi during MIT. No failures witnessed. M.I.T.'s performed: 2 Number of Failures: 0 AttachmentS: Total Time during tests: 3 hrs. cc: MIT report form 5/12/00 L.G. MIT BPX MPU 10-25-02 JC.xls 11/8/2002 Well Compliance Report File on Left side of folder 197-163-0 MILNE POINT UNIT SB H-11 Roll #1: Start: Stop Roll #2: Start MD 07020 TVD 04293 Completion Date: 50- 029-22802-00 BP EXPLORATION (ALASKA) INC Stop 9/6/98 Completed Status: 1WINJ Current: . _ Name Interval Sent Received D 8499 2 SPERRY MPT/GR/EWR4/CNP/SLD OH 8/19/98 8/19/98 D 9074 I PDS INJP/JWL CH 12/1/99 12/1/99 L DGR/CNP/SLD-MD FINAL 5008-7020 OH 8/19/98 8/19/98 L DGR/CNP/SLD-TVD FINAL 3333-4293 OH 8/19/98 8/19/98 L DGR/EWR4-MD FINAL 5008-7020 OH 8/19/98 8/19/98 L DGR/EWR4-TVD FINAL 3333-4293 OH 8/19/98 8/19/98 L INJP/JWL FINAL 6304-6852 11/23/99 CH 5 12/3/99 12/3/99 L PCD-CBL/GR FINAL 1100-6900 CH 5 8/25/98 8/27/98 L PERF FINAL 6900 CH 5 9/25/98 10/22/98 L RFT FINAL 6200-6778 CH 11/5/97 11/5/97 R MWD SRVY SPERRY 0-7020. OH 1/22/99 1/25/99 T 8614 1 SCHLUM PCD CH 8/25/98 8/27/98 Are Dry Ditch Samples Required? yes n~ And Received? yes no Daily Well Ops Was the well cored? yes no Analysis Description Received? yes ~ Sample Set # Comments: T/C/D D T Wednesday, November 08, 2000 Page 1 of 1 STATE OF ALASKA ALASKA ( AND GAS CONSERVATION COl~ SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [~] Operation Shutdown [~ Stimulate I--I Plugging ~] Perforate E~ Pull Tubing E~Alter Casing E~ Repair Well ~]Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 4. Location of well at surface 2863' NSL, 4158' WEL, SEC. 34, T13N, R10E, At top of productive interval 4026' NSL, 2734' WEL, SEC. 02, T12N, R10E, At effective depth At total depth 3781' NSL, 2786' WEL, SEC. 02, T12N, 5. Type of well: ~] Development E~] Exploratory [~] Stratigraphic [~Service 6. Datum Elevation (DF or KB) Plan KBE = 66.5' 7. Unit or Property Name Milne Point Unit 8. Well Number MPH-11i 10.9' A~l~N'u~m~eerPe ' umr~.~__ Approval No. 50-029-22802 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 7020' feet true vertical 4293' feet :~""+"'" ,,~,,h. ,. ..... ,4 ~ ~' feet -,,~,.,,,v~ ~'"'-'+ · true vertical 4225' feet Casing Length Structural Conductor Surface Intermediate Production Liner 80' 6972' Size 20" 9-5/8" Plugs (measured) Junk (measured) Cemented 260 sx Arctic Set (Approx) 1262 sx PF'E',100 sx PF 'C',142 sx MD TVD 110' 110' 7002 A282' Perforation depth: measured 6662'-6702' true vertical 4120'-4147' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 @ 6260' Packers and SSSV (type and measured depth) Packer @ 6192' SSSV @ 2385' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure i15. Attachments 116. Status of well classifications as: .FI Copies of Logs and Surveys run I [~ Oil [~ Gas E~ Suspended ~. Daily Report of Well Operations 17. I hereby certify that the foreg.o~ is true and correct to the best of my knowledge Signed ('.,/~ PATRICKJ. COLLINS ' ~(.W (,'~/'~ Title Production Engineer Prepared By Name/Number: Service Water Injection rO(L~ (clot Date Michael Williams, 564-4657 Form 10-404 Rev. 06/15/88 Submit In Duplica~ MPH-11 DESCRIPTION OF WORK COMPLETED ADDPERF O9/22/99 SUMMARY The following additional interval were perforated using 2" guns, 4 SPF, zero orientation and 0° phasing. 6470' - 6490'MD 6514' - 6520'MD 6754' - 6794'MD RECEIVED Gas C~ns. Commi~ion An~h0rage Date: January 14, 1999 To: Attn: Alaska Oil & Gas Conservation Commission Steve McMains Reference: Fro m: Completion Report - MPH-11 ey ssistant III Steve: While preparing the 10-407 for the above subject well, it was necessary for me to utilize our Production Database (PDB) for purposes of calculating the total depth and productive interval coordinates. The north slope participating areas and lease status map shows the convergence of the meridians. Because of the convergence, it was not possible to manually calculate the correct township, section and range. Please call me if you have questions at 564-4114. Attachments Cc: Well File Anchorage 18-10 18-1o GUIDE MERIDIANS 6~55 These standard parallels are numbered, as shown in Pig. 18-4, as the first (second, third, and so on) standard parallel north (or south). In the earlier surveys standard parallels have been placed at intervals of 30 or 36 miles north and south of the baseline. In connecting new work with old work, it has been necessary to establish intermediate correction lines which have been given local names, as "Pifi;h Auxiliary Standard Parallel North" or "Cedar Creek Correction Line." Guide Meridians The survey district is next divided into tracts approximately 24 miles square by means of guide meridians. These lines are true meridians that start at points on the baseline or standard parallels at intervals of 24 miles east and west of the prin- cipal meridian and extend north to their intersection with the next standard paral- lel, as shown in Fig. 18-4. Because of the convergence of the meridians, the distance between these hnes ~,xdl be 24 miles only at the starting points. At all FIGURE 18-4 Standard parallels and guide m. eridia~s. 636 CHAPTER 18 UNITED STATES PUBLIC LAND SURVEYS 18-11 other points the distance bet~veen them will be less than 24 miles. Guide meridians are designated by number, as the first (second, third, and so on) guide meridian east (or west). As they extend from one standard parallel to the next, their lengths are limited to 24 miles (30 or 36 miles on older work). At their intersection with the standard parallel to the north, a new monument is established. On the stan- dard parallels, two sets of monuments are thus to be found. The monuments that were established as the parallel was first located are called stctndctrst corr~ers and apply to the area north of the parallel. The second set, found at the intersection of the parallel with the meridians from the south, are called closing corr~ers and gov- ern the area to the south of the parallel. The distance between the closing corner and the nearest standard corner should be measured and recorded in the field notes. The guide meridians are located with the same care for securing accuracy of alignment and measurement as the principal meridian. The monuments are placed at haft-mile intervals, except that all discrepancies in measurement are thrown into the last half mile. For this reason the distance from the closing corner to the first monument south of the standard parallel may be more or less than 40 chains. Township Exteriors The regular order of establishing the township exteriors can be followed bt' refer- ence to Figure 18-4. Beginning at ct, on the baseline (or standard parallel) and 6 miles east of the principal meridian (or guide meridian), a line is run due north for 6 miles, monuraents being established at intervals of 40 chains. From the totvnship corner b, a random line is run to the west to intersect the principal meridian (or a guide meridian) at c. As this line is run, temporary monuments are set at intervals of 40 chains. From. the amount by which the random line fails to strike c, the direc- tion of the true line between c and b can be calculated. The line is then run on this calculated course from c back to b, and the temporary monuments are replaced by permanent ones in proper position. The true line is blazed through timber, and dis- tances to important items of topography are adjusted to the correct true-line mea- surements. On account of the convergence of meridians and errors in field work, the northern boundary of the township will not be exactly 6 miles in length. All stis- crepancies due to convergence and to errors in measurement or alignment are thrown into the most westerly half mile, all other distances being made exactly 40 chains. Although every attempt is made to keep lines within 0° 14' of the true courses, the boundaries of a township are not considered defective unless the error exceeds 0° 21'. If the random north boundary fails to close on the corner previously set by more than 3 chains for line or by more than 3 chains, minus the theoretical convergence, for distance, it is evident that the 0° 21' limit has been exceeded, and the lines are retraced and the error is corrected. The eastern boundary of the next township to the north is next run by extending the meridian from b to st, a distance of 6 miles, and locating permanent monuments at intervals of 40 chains. A random is then run westerly from st toward e and corrected back as the true line with monuments at intervals of 40 chains, .: . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [-] Oil I--]Gas [~]Suspended ~JAbandoned [~ Service Water Iniection 12. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-163 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22802 4. Location of well at surface 9. Unit or Lease Name i: ':<~:.'i~!~ ~ .i~'':~ ~._.,_ _. ~ '. ............ ,' , . ~ '~,-.:)~-4¢~ Milne Point Unit 2863' NSL, 4158' WEL, SEC. 34, T13N, R10E, UM At top of productive interval ~~I 10. Well Number 1237' SNL, 2856' WEL, SEC. 2, T12N, R10E, UM ' MPH-11 At total depth !}~ ~: ~,.r~..~! 11. Field and Pool 1492' SNL, 2766' WEL, SEC. 2, T12N, R10E, UM ~ ................ Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 67.9'I ADL 380109 12. Date Spudded8/29/97 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if °ffsh°re 16' N°' °f C°mpleti°ns9/3/97 9/6/97 N/A MSL One 17. Total Depth (MD+TVD) I18. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 7020 4293 FTI 6918 4225 FTI [~Yes [~NoI 2385' MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD/LWD, RFT, GR/CCL/CBL 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-II-OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91/1# H-40 33' 110' 24" 260 sx Arctic Set (Approx.) 7" 26# L-80 31' 7002' 8-1/2" 1262 sx PF 'E', 100 sx PF 'C', 142 sx 'G' I 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.2#, L-80 6260' 6192' MD TVD MD TVD 6662' - 6702' 4120' - 4147' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) August 17, 1998I Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Schrader Bluff 'Fl' 6465' 3930' Schrader Bluff 'D3' 6660' 4056' Schrader Bluff 'B' 6748' 4114' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32'lherebyc~~~trueandc°rrectt°thebest°fmykn°~wledg~/ccrf/Signed - ~_.~, /// /,~ Title //~¢.¢rr~ /.j~/- Date r'7/ ¢ MPH-11 /' ! 97-163 Prepared By Name/Number: Well Number ~N / Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility M Pt H Pad Well MPH- 11 Rig Nabors 5S Page 1 Date 11 January 99 Date/Time 06 Aug 98 07 Aug 98 08 Aug 98 09 Aug 98 06:00-07:30 07:30-09:00 09:00-09:30 09:30-10:00 10:00-11:00 11:00-12:30 12:30-15:00 15:00-15:30 15:30-17:00 17:00-18:00 18:00-19:00 19:00-21:30 21:30-02:30 02:30-06:00 06:00-07:00 07:00-08:30 08:30-09:30 09:30-14:00 14:00-18:00 18:00-20:00 20:00-23:00 23:00-04:30 04:30-06:00 06:00-10:00 10:00-13:30 13:30-15:00 15:00-18:00 18:00-21:30 21:30-00:30 00:30-06:00 06:00-11:00 11:00-11:30 11:30-12:30 12:30-13:30 13:30-14:00 14:00-18:00 18:00-21:00 21:00-21:30 21:30-06:00 Duration 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr lhr 1-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr lhr lhr 2-1/2 hr 5hr 3-1/2 hr lhr 1-1/2 hr lhr 4-1/2 hr 4hr 2hr 3hr 5-1/2 hr 1-1/2 hr 4hr 3-1/2 hr 1-1/2 hr 3hr 3-1/2 hr 3hr 5-1/2 hr 5hr 1/2 hr lhr lhr 1/2 hr 4hr 3hr 1/2 hr 8-1/2 hr Activity Rig moved 100.00 % Rigged up Draw works Held safety meeting Rigged up Hanger plug Rigged down Xmas tree Rigged up All rams Tested All rams Rigged down Tubing hanger Singled in drill pipe to 0.0 ft Singled in drill pipe to 500.0 ft Singled in drill pipe to 2097.0 ft Rigged up Drillstring handling equipment Singled in drill pipe to 2108.0 ft Singled in drill pipe to 2168.0 ft Singled in drill pipe to 2168.0 ft Singled in drill pipe to 2500.0 ft Singled in drill pipe to 2500.0 ft Singled in drill pipe to 6912.0 ft Reverse circulated at 6910.0 ft Circulated at 6910.0 ft Pulled Drillpipe in stands to 0.0 ft Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Ran Drillpipe in stands to 6910.0 ft Reverse circulated at 6910.0 ft Laid down 3975.0 ft of 3-1/2in OD drill pipe Laid down 6912.0 ft of 3-1/2in OD drill pipe Ran Tubing to 0.0 ft (3-1/2in OD) Ran Tubing to 3125.0 ft (3-1/2in OD) Ran Tubing to 6260.0 ft (3-1/2in OD) Rigged up Tubing hanger Removed BOP stack Installed Xmas tree Removed Hanger plug Circulated at 6260.0 ft Circulated at 6260.0 ft Rigged up Hanger plug Rig moved 100.00 % Progress Report Facility M Pt H Pad Well MPH- 11 Rig Naborsfldg' c) D ~ Page 2 Date 11 January 99 Date/Time 05 Sep 97 06 Sep 97 07:00-08:30 08:30-09:30 09:30-13:00 13:00-13:30 13:30-14:30 14:30-15:30 15:30-17:00 17:00-21:00 21:00-23:00 23:00-03:00 03:00-03:30 03:30-04:30 04:30-06:00 06:00-15:00 15:00-15:30 15:30-17:30 17:30-20:30 20:30-22:30 22:30-00:00 00:00-05:00 05:00-06:00 06:00-08:00 08:00-09:00 09:00-12:30 12:30-13:00 13:00-06:00 Duration 1-1/2 hr lhr 3-1/2 hr 1/2 hr lhr lhr 1-1/2 hr 4hr 2hr 4hr 1/2 hr lhr 1-1/2 hr 9hr 1/2 hr 2hr 3hr 2hr 1-1/2 hr 5hr lhr 2hr lhr 3-1/2 hr 1/2 hr 17hr Activity Rigged down Logging/braided cable equipment Circulated at 6155.0 ft Pulled out of hole to 47.0 ft Removed Logging/braided cable equipment Pulled BHA Serviced Block line Made up BHA no. 3 R.I.H. to 7020.0 ft Circulated at 7020.0 ft Pulled out of hole to 858.0 ft Pulled BHA Serviced Top drive Rigged up Casing handling equipment Ran Casing to 7002.0 ft (7in OD) Rigged up Cement head Circulated at 7002.0 ft Mixed and pumped slurry - 169.700 bbl Circulated at 2113.0 ft Mixed and pumped slurry - 387.000 bbl Rigged down Cement head Rigged down Divertor Rigged down Casing handling equipment Rigged down Divertor Installed Xmas tree primary components Installed Xmas tree primary components Rig moved 100.00 % Progress Report Facility M Pt H Pad Well MPH- 11 Rig Nabors ~ ~ D'[ Page 1 Date 11 January 99 Date/Time 28 Aug 97 29 Aug 97 30 Aug 97 31 Aug 97 01 Sep 97 02 Sep 97 03 Sep 97 04 Sep 97 22:01-02:30 02:30-06:00 06:00-09:00 09:00-12:00 12:00-19:00 19:00-21:15 21:15-21:30 21:30-22:00 22:00-02:00 02:00-06:00 06:00-22:30 22:30-23:30 23:30-01:00 01:00-02:00 02:00-03:00 03:00-06:00 06:00-14:30 14:30-15:15 15:15-17:00 17:00-17:30 17:30-20:00 20:00-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-09:00 09:00-11:00 11:00-12:00 12:00-12:30 12:30-13:30 13:30-15:30 15:30-17:45 17:45-21:00 21:00-06:00 06:00-10:30 10:30-12:00 12:00-13:00 13:00-13:30 13:30-14:30 14:30-02:00 02:00-03:15 03:15-03:45 03:45-04:15 04:15-05:30 05:30-06:00 06:00-10:00 10:00-11:30 11:30-12:30 12:30-14:00 14:00-20:00 20:00-20:30 20:30-00:30 00:30-06:00 06:00-07:00 Duration 4-1/4 hr 3-1/2 hr 3hr 3hr 7hr 2-1/4 hr 1/4 hr 1/2 hr 4hr 4hr 16-1/2 hr lhr 1-1/2 hr lhr lhr 3hr 8-1/2 hr 3/4 hr 1-3/4 hr 1/2hr 2-1/2 hr 9hr lhr 1/2 hr lhr 1-1/2 hr 2hr lhr 1/2 hr lhr 2hr 2-1/4 hr 3-1/4 hr 9hr 4-1/2 hr 1-1/2 hr lhr 1/2 hr lhr 11-1/2 hr 1-1/4 hr 1/2 hr 1/2 hr 1-1/4 hr 1/2 hr 4hr 1-1/2 hr lhr 1-1/2 hr 6hr 1/2 hr 4hr 5-1/2 hr lhr Activity Rig moved 35.00 % Rig moved 65.00 % Rig moved 100.00 % Rigged up Divertor Serviced Drillfloor / Derrick Installed Divertor Tested Divertor Held safety meeting Made up BHA no. 1 Drilled to 450.0 ft Drilled to 2371.0 ft Circulated at 2371.0 ft Pulled out of hole to 176.0 ft Serviced Top drive R.I.H. to 2371.0 ft Drilled to 2926.0 ft Drilled to 3676.0 ft Circulated at 3676.0 ft Pulled out of hole to 1818.0 ft Serviced Top drive R.I.H. to 3676.0 ft Drilled to 5011.0 ft Circulated at 5011.0 ft Circulated at 5011.0 ft Pulled out of hole to 4180.0 ft Backreamed to 4180.0 ft Pulled out of hole to 901.0 ft Pulled BHA Downloaded MWD tool Serviced Top drive Made up BHA no. 2 R.I.H. to 4000.0 ft Reamed to 4000.0 ft Drilled to 5905.0 ft Drilled to 6285.0 ft Circulated at 6285.0 ft Pulled out of hole to 4001.0 ft Serviced Top drive R.I.H. to 6285.0 ft Drilled to 7020.0 ft Circulated at 7020.0 ft Pulled out of hole to 6190.0 ft R.I.H. to 7020.0 ft Circulated at 7020.0 ft Pulled out of hole to 6372.0 ft Pulled out of hole to 940.0 ft Pulled BHA Serviced Top drive Ran logs on tubulars R.I.H. to 6155.0 ft Circulated at 6155.0 ft R.I.H. to 6476.0 ft Ran logs on tubulars Pulled out of hole to 6155.0 ft SPE SHARED SERVICES DRILLING MILNE POINT / MPH-11 500292280200 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 8/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -67.90 112.00 112.00 44.10 201.75 201.75 133.85 291.41 291.41 223.51 385.62 385.62 317.72 474.81 474.80 406.90 565.60 565.53 497.63 657.24 657.04 589.14 749.38 749.03 681.13 840.59 840.04 772.14 929.44 928.58 860.68 1022.21 1020.79 952.89 1115.46 1113.06 1045.16 1205.72 1201.87 1133.97 1299.49 1293.27 1225.37 1388.13 1378.98 1311.08 1477.41 1465.31 1397.41 1571.39 1555.80 1487.90 1665.10 1645.06 1577.16 1756.02 1730.94 1663.04 1847.13 1816 1939.85 1901 2031.29 1984 2-122.76 2065 2216.86 2146 .09 1748.19 .76 1833.86 .84 1916.94 .79 1997.89 .81 2078.91 .92 2155.02 .49 2230.59 .33 2303.43 .71 2374.81 .58 2441.68 2307.45 2222 2399.78 2298 2491.98 2371 2586.38 2442 2679.57 2509 2768.15 2569 2861.07 2627 2953.57 2681 3046.18 2732 3137.31 2780 COURS INCLN DG MN '-SUN DRILLING SERVICES A/~CHOR3kGE ALASKA DATE OF SURVEY: MWD SURVEY PAGE 1 JOB NUMBER: AK-MM-70259 KELLY BUSHING ELEV. = 67.90 FT. OPERATOR: BP EXPLORATION 0 0 0 0 0 14 0 19 0 15 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 1 11 2 34 3 27 3 4 4 23 N .00 E .00 .00N .00E N .00 E .00 .00N .00E S 29.92 E .27 .16S .09E S 49.51 E .14 .49S .38E S 52.30 E .07 .79S .75E .O0 .00 .18 .58 .98 5 7 9 11 14 S 47.90 E 1.04 1.53S 1.59E S 34.92 E 1.59 3.84S 3.46E S 31.93 E .96 7.87S 6.10E S 32.10 E .40 12.32S 8.88E S 28.73 E 1.46 17.46S 11.86E 1.94 4.71 9.34 14.42 20.22 10 14 18 8 36 14 56 14 35 16 41 18 4O 19 39 S 25.98 E .91 24.04S 15.25E S 23.07 E 2.26 33.18S 19.37E S 17.62 E 2.36 45.76S 23.96E S 16.08 E 2.06 61.09S 28.58E S 12.94 E 3.77 81.33S 33.74E 27.51 37.47 50.85 66.86 87.71 21 57 23 0 26 19 29 8 31 58 33 41 36 25 39 11 42 32 45 44 S 15.48 E .83 103.24S 39.29E S 15.73 E .41 125.17S 45.42E S 18.66 E 2.39 149.34S 52.94E S 17.56 E 2.15 176.40S 61.78E S 16.98 E 1.10 204.91S 70.64E 110.28 133.03 158.35 186.81 216.67 .45 2501.55 49 12 .68 2559.78 53 10 .64 2613.74 55 26 .91 2665.01 57 19 .32 2712.42 59 58 S 16.00 E 2.55 235.94S 79.81E S 14.72 E 1.25 270.14S 89.19E S 15.84 E 3.67. 306.94S 99.27E S 17.55 E 3.19 347.70S' 111.52E S 16.89 E 3.04 393.40S 125.68E -- S 17.18 E 1.90 440.35S 140.07E S 16.99 E 2.97 491.05S 155.64E S 17.21 E 3.00 545.07S 172.27E S 16.49 E 3.58 604.17S 190.15E S 15.63 E 3.49 666.53S 208.09E 249.02 284.45 322.59 365.14 412.98 462.09 515.12 571.64 633.39 698.26 S 14.99 E 3.94 729.49S 225.31E S 16.22 E 4.40 799.20S 244.81E S 17.12 E 2.58 871.14S 266.36E S 17.67 E 2.09 944.72S 289.42E S 18.49 E 3.02 1018.69S 313.57E 763.48 835.82 910.92 988.03 1065.84 ORIGINAL. SPE] -SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-11 500292280200 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 8/97 DATE OF SURVEY: 090397 MWD SURVEY JOB NUMBER: AK-MM-70259 KELLY BUSHING ELEV. = 67.90 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3231.97 2825.84 2757.94 62 31 3324.68 2866.87 2798.97 64 56 3419.74 2904.52 2836.62 68 23 3515.34 2937.49 2869.59 71 15 3610.78 2965.65 2897.75 74 25 S 19.18 E 2.76 1097.23S 340.37E S 19.49 E 2.63 1175.66S 367.89E S 18.88 E 3.68 1258.09S 396.56E S 19.16 E 3.00 1342.91S 425.81E S 18.37 E 3.42 1429.24S 455.13E 1148.80 1231.87 1319.11 1408.80 1499.95 3706.58 2991.84 2923.94 73 49 3800.77 3017.25 2949.35 74 52 3896.04 3042.14 2974.24 74 50 3993.63 3067.85 2999.95 74 35 4090.65 3093.64 3025.74 74 35 S 19.94 E 1.70 1516.28S 485.36E S 19.14 E 1.37 1601.75S 515.70E S 19.36 E .22 1688.57S 546.02E S 19.69 E .42 1777.30S 577.48E S 16.73 E 2.94 1866.13S 606.70E 1592.05 1682.69 1774.61 1868.69 1962.20 4185.16 3118.91 3051.01 74 23 4279.94 3143.97 3076.07 74 56 4374.82 3168.54 3100.64 75 1 4470.50 3193.31 3125.41 74 57 4565.58 3218.03 3150.14 74 54 S 16.84 E .24 1953.32S 633.00E S 16.78 E .59 2040.82S 659.44E S 16.30 E .50 2128.67S 685.53E S 16.05 E .26 2217.43S 711.27E S 15.25 E .81 2305.84S 736.04E 2053.26 2144.66 2236.29 2328.68 2420.44 4662.21 3243.15 3175.25 74 4758.21 3267.96 3200.06 75 4851.30 3291.98 3224.08 75 4947.39 3316.93 3249.03 74 4992.78 3328.69 3260.79 75 58 S 14.19 E 1.06 2396.08S 759.75E 4 S 14.04 E .18 2486.02S 782.36E 1 S 14.15 E .12 2573.25S 804.26E 52 S 14.32 E .24 2663.19S 827.08E 5 S 12.92 E 3.02 2705.80S 837.40E 2513.64 2606.22 2696.00 2788.64 2832.38 5088.99 3352.77 3284.87 75 55 5184.18 3376.40 3308.50 75 20 5274.81 3399.77 3331.87 74 46 5371.03 3425.18 3357.28 74 35 5466.55 3450.62 3382.72 74 30 5563.71 3476.73 3408.83 74 18 5657.75 3505.27 3437.37 70 20 5752.91 3540.51 3472.61 66 10 5847.46 3580.20 3512.30 64 9 5941.51 3622.94 3555.04 61 46 S 14.31 E 1.64 2796.32S 859.33E S 16.15 E 1.97 2885.28S 883.55E S 18.43 E 2.51, 2968.87S 909.57E S 19.01 E .61 3056.76S 939.35E S 18.36 E .66 3143.98S 968.85E S 18.10 E .33 3232.86S 998.12E S 19.26 E 4.37 3317.73S 1026.80E S 19.02 E 4.39 3401.22S 1055.78E S 18.36 E 2.23 3482.49S 1083.28E S 19.37 E 2.72 3561.75S 1110.35E 2925.30 3017.43 3104.98 3197.76 3289.80 3383.38 3472.95 3561.29 3647.06 3730.79 6036.77 3670.30 3602.40 58 35 6132.04 3721.88 3653.98 55 49 6225.88 3777.87 3709.97 50 53 6324.16 3840.07 3772.17 50 35 6419.02 3900.51 3832.61 50 14 S 19.27 E 3.33 3639.73S 1137.70E S 20.75 E 3.19 3714.99S 1165.08E S 20.04 E 5.30 3785.53S 1191.33E S 19.59 E .47 3857.13S 1217.13E S 19.46 E .38 3926.03S 1241.56E 3813.39 3893.39 3968.57 4044.60 4117.66 SPE '-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-11 500292280200 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 8/97 DATE OF SURVEY: 090397 MWD SURVEY JOB NUMBER: AK-MM-70259 KELLY BUSHING ELEV. = 67.90 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6515.42 3962.43 3894.53 49 49 6608.43 4022.60 3954.70 49 32 6705.13 4085.51 4017.61 49 16 6801.41 4148.58 4080.68 48 52 6895.07 4210.24 4142.34 48 45 S 19.52 E .43 3995.68S 1266.21E 4191.50 S 19.98 E .48 4062.43S 1290.18E 4262.37 S 18.81 E .96 4131.70S 1314.56E 4335.76 S 19.64 E .77 4200.39S 1338.52E 4408.48 S 20.67 E .84 4266.56S 1362.80E 4478.89 6966.94 4257.68 4189.78 48 38 S 18.57 E 2.20 7020.00 4292.74 4224.84 48 38 S 18.57 E .04 4317.41S 1380.93E 4532.84 4355.16S 1393.61E 4572.66 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4572.70 FEET AT SOUTH 17 DEG. 44 MIN. EAST AT MD = 7020 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 162.51 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 7,020.00' MD SPE '-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-11 500292280200 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 8/97 DATE OF SURVEY: 090397 JOB NUMBER: AK-MM-70259 KELLY BUSHING ELEV. = 67.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .00 -67.90 .00 N .00 E .0 1000.00 998.76 930.86 30.60 S 18.28 E 1.2 2000.00 1956.66 1888.76 293.85 S 95.60 E 43.3 3000.00 2707.97 2640.07 907.69 S 277.62 E 292.0 4000.00 3069.55 3001.65 1783.08 S 579.54 E 930.4 1.24 42.10 248.68 638.43 5000.00 3330.55 3262.65 2712.60 S 838.96 E 1669.4 6000.00 3651.48 3583.58 3609.92 S 1127.26 E 2348.5 7000.00 4279.52 4211.62 4340.93 S 1388.83 E 2720.4 7020.00 4292.74 4224.84 4355.16 S 1393.61 E 2727.2 739.00 679.07 371.96 6.78 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE! -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-11 500292280200 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 8/97 DATE OF SURVEY: 090397 JOB NUMBER: AK-MM-70259 KELLY BUSHING ELEV. = 67.90 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -67.90 67.90 67.90 .00 167.90 167.90 100.00 267.90 267.90 200.00 367.90 367.90 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .04 S .02 E .00 .00 .40 S .28 E .00 .00 .74 S .68 E .00 .00 467.91 467.90 400.00 567.97 567.90 500.00 668.12 667.90 600.00 768.28 767.90 700.00 868.53 867.90 800.00 1.44 S 1.49 3.93 S 3.52 8.43 S 6.45 13.18 S 9.42 19.34 S 12.89 E .01 .01 E .07 .06 E .22 .15 E .38 .16 E .63 .25 968.93 967.90 900.00 1069.72 1067.90 1000.00 1171.09 1167.90 1100.00 1273.33 1267.90 1200.00 1376.66 1367.90 1300.00 27.30 S 16.83 38.89 S 21.72 54.67 S 26.73 75.15 S 32.27 100.39 S 38.50 E 1.03 .40 E 1.82 .80 E 3.19 1.37 E 5.43 2.24 E 8.76 3.33 1480.09 1467.90 1400.00 1584.03 1567.90 1500.00 1689.21 1667.90 1600.00 1795.27 1767.90 1700.00 1903.07 1867.90 1800.00 125 152 183 217 256 .81 S 45.60 .78 S 54.10 .76 S 64.11 .54 S 74.49 .23 S 85.54 12.19 3.42 16.13 3.94 21.31 5.18 27.37 6.06 35.17 7.80 2012.46 1967.90 1900.00 2125.19 2067.9-0 2000.00 2241.72 2167.90 2100.00 2362.04 2267.90 2200.00 2487.58 2367.90 2300.00 299.02 S 97.Q4 348.84 S 111.88 405.99 S 129.50 469.91 S 149.17 542.43 S 171.45 ,E E E E E 44.56 9.39 57.28 12.72 73.82 16.53 94.14 20.32 119.68 25.55 2620.91 2467.90 2400.00 2765.82 2567.90 2500.00 2929.35 2667.90 2600.00 3112.80 2767.90 2700.00 3327.17 2867.90 2800.00 626.83 S 196.79 727.80 S 224.87 852.08 S 260.49 998.64 S 306.91 1177.80 S 368.64 153.01 33.32 197.92 44.92 261.45 63.53 344.90 83.45 459.27 114.38 3619.17 2967.90 2900.00 3993.80 3067.90 3000.00 4372.33 3167.90 3100.00 4757.96 3267.90 3200.00 5150.60 3367.90 3300.00 1436.92 1777.46 2126.37 2485.78 2854.07 S 457.68 S 577.53 S 684.85 S 782.30 S 874.51 651.27 192.00 925.91 274.63 1204.43 278.53 1490.06 285.62 1782.70 292.64 SPE ' SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-11 500292280200 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 8/97 DATE OF SURVEY: 090397 JOB NUMBER: AK-MM-70259 KELLY BUSHING ELEV. = 67.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5531.04 3467.90 3400.00 3202.97 S 988.35 E 2063.14 280.44 5819.23 3567.90 3500.00 3458.38 S 1075.28 E 2251.33 188.19 6032.11 3667.90 3600.00 3635.96 S 1136.38 E 2364.21 112.88 6209.87 3767.90 3700.00 3773.78 S 1187.02 E 2441.97 77.76 6367.98 3867.90 3800.00 3889.01 S 1228.47 E 2500.08 58.11 6523.90 3967.90 3900.00 4001.78 S 1268.37 E 2556.00 55.92 6678.13 4067.90 4000.00 4112.33 S 1307.97 E 2610.23 54.24 6830.80 4167.90 4100.00 4221.24 S 1345.96 E 2662.90 52.66 6982.41 4267.90 4200.00 4328.42 S 1384.63 E 2714.51 51.61 7020.00 4292.74 4224.84 4355.16 S 1393.61 E 2727.26 12.75 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST .20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 9/25/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 11515 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape MPB-03 JEWELRY LOG 9 8 0 8 2 3 I 1 MPB-04 JEWELRY LOG 9 8 0 8 2 3 I 1 MPB-10 JEWELRY LOG 9 8 0 8 2 3 I 1 MPB-15 JEWELRY LOG 9 8 0 8 2 5 I 1 MPB-20 JEWELRY LOG 9 8 0 91 1 I 1 MPC-22A TUBING PUNCHER RECORD 9 8 0 8 0 2 I 1 MPE-21 PERFORATING RECORD 9 8 0 9 0 3 I 1 MPE-30 PERFORATING RECORD 9 8 0 9 0 7 I 1 M PH-10 PERFORATING RECORD 9 8 0 8 2 7 I 1 MPH-10 PERFORATING RECORD 9 8 0 8 2 9 I 1 . , M P H- 10 PERFORATING RECORD 9 8 0 8 31 I 1 M PH-11 PERFORATION RECORD 9 8 0 8 0 8 I 1 M P H-14 PERFORATING RECORD 9 8 0 7 2 8 I 1 M P H- 14 PERFORATING RECORD 9 8 0 7 3 0 I 1 MPH-14 PACKER SETTING RECORD 9 8 0 8 01 I 1 MPJ-22 PERFORATION RECORD 9 8 0 7 3 0 I 1 MPJ-22 BRIDGE PLUG SET RECORD 9 8 0 813 I 1 M PJ-22 PERFORATION RECORD 9 8 0 817 I 1 MPK-21 L4/(-- JEWELRY LOG 980913 I I ~2. · o'7(,, ~.ofq PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd // ,~ Schlumberger- GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518-1199 ~ (907) 562-7669 (Bus.) (907) 563-3309 (Fax) Aug. 25, 1998 TO: BP Exploration (Alaska) Inc. Petmtectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the CBT ~PDC) for well MPH -11, Job # 98414. was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 State of A~Jask'E Alaska~ii & Gas Conservation ~-t~: Lori TaYlor qA3001 Porcupine Drive nchorage, AK 99501 E-TRANS (8/21/98) 1 Film 3 Bluelines 1 CH LIS TaPe .... 1 Blueline 1 RFolded Sepia OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 CH LIS Tape 1 Blueline 1 RFolded Sepia Sent Certified Mail P 067 695 487 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Biv~~,.~/ Anchorage, Alask~"'~_~ 1~ AUG 27 1998 Date Delivered;"a~k&,,u C~ & ~ '"'~'' ~"~" ' *' ,,~,.~. ,,0remission Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received ~ ri Iai I I.__1__ I IM I~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPH-11, AK-MM-70259 August 19, 1998 MPH-11: 2" x 5" MD R~ and Gamma Ray Logs: 50-029-22802-00 2"x 5" TVD Resisfivit7 and Gamma Ray Logs: 50-029-22802-00 2" x 5" MD Neutron & Density Logs: 50-029-228024~ 2" x 5" TVD Neutron & Density Logs: 50-029-22802-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNO~E RECEIPT BY SIGNING AND RETURNING THE A~FACHED COPIES OF ~ TRANSM1TYAL LETYER TO THF~ ATYENTION OF: Sperry-Sun Drilling Services Attrr Ali Turker 5631 Silverado Way, Suite G. Anchora~e_Alaska.9~l 8 RECEIV L DazeAUG 19 ~998 Alaska 0~ ~ Gas Co.~. C~ma'~ission Andmmge BP Exploration (Alaska) Inc. Petro-technical Data Cemer, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Signe? <~' 5631 Siiverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs August 19, 1998 MPH-11, AK-MM-70259 1 LDWG formatted LIS tape with verification listing. APl#: 50-029-22802-00 PLEASE ACKNOWLEDGE RECEHXr BY SIGNING AND RETURNING THF, ATYACHED COPIES OF THF~ TRANSMITrAL LETTER TO THle~ ATTENTION OF: Sperry-Sun Drilling Services Atto: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11525 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 1 1/5/97 Well Job # Log Description Date BL RF Sepia LIS Tape MPC-6 (.~1C_... WATER FLOW LoG/TDTP-GR/CCL 970615 "1 1 MPU C-8 ~,)3, d_.- TDT WATER FLOW LOG 970927 1 1 MPU C-10 { ~Ll C--- WATER FLOW LOG W/EST INVERTED 970911 1 1 ,, _ MPE-10 · TUBING PUNCHER 970928 I 1 MPU E-22 ~ TUBING LEAK DETECTION LOG 970702 I 1 ,. MPU E-22 ~ TUBING PATCH RECORD 97071 9 I 1 MPU F-09 ~ PERFORATING RECORD 970712 I 1 MPU F-09 ,~ STATIC TEMP/PRESS SURVEY 970712 I 1 .... MPU F'09' ~ PERFORATING RECORD 97071 9 I 1 F-41 , CHEMICAL CU'I-rER 970820 I 1 F-41 ~ CHEMICAL CUTTER 970829 I 1 MPU F-73 ~ PERFORATION RECORD 970815 I 1 MPG-09, RFT 970702 I 1 MPH-11 ~ RFT 970903 I 1 MPU J-2 ~[ [(..,. WATER FLOW LOG/TDT-GR 970726 1 1 MPU J-09 ~1,[~..-- JETCUTI'ER RECORD 970807 I 1 MPK-43A · GAMMA RAY CORRELATION LOG 971 024 I 1 MPU L-9 {,At ~ WATER FLOW LOG/TDTP-GR/CCL 97061 4 I 1 MPU L-32 ~ GAMMA RAY CCL TCP CORRELATION LOG 970515 1 1 MPL-33 ' TUBING CONVEYED PERF TIE-IN GR-CCL 971 010 I 1 MPL-33 ' TIE-IN GR-CCL 971014 I I qo. Cio - ... q-q · PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received bY:~~~' TONY KNOWLE$, GOVERNOR ALASi~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 29, 1997 Chip Alvord Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPH-11 i BP Expoloration (Alaska) Inc. Permit No. 97-163 Sur. Loc. 2863'NSL. 4158'%VEL. Sec. 34. T13N. R10E. UM Btrnhole Loc. 3781'NSL. 2786'WEL. Sec. 02. T12N. R10E. UM Dear Mr. Alvord:: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by la~v from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical inte~m-ity (Nil) of the injection ~vells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling beloxv the surthce casing shoe. must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Commissioner BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game. Habitat Section w/o encl. Department of Enviromnental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type ofwork [] Drill I-'lRedrill ilb. Type of well I-IExploratory [-IStratigraphic Test [] Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 66.5' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 380109 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2863' NSL, 4158' WEL, SEC. 34, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 4026' NSL, 2734' WEL, SEC. 02, T12N, R10E, UM MPH-11i At total depth 9. Approximate spud date Amount $200,000.00 3781' NSL, 2786' WEL, SEC. 02, T12N, R10E, UM 08/28/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025518, 1499' MDI No Close Approach 2560 7023' MD / 4271' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.O35 (e)(2)} KickOff Depth 500' Maximum Hole An,qle 74-96° Maximurnsurface 1311 psig, At total depth (TVD) 3835'/1695 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 260 sx Arctic Set (Approx.) 8-1/2" 7" 26# L-80 BTC-Mod 6992' 31' 31' 7023' 4271' 695 sx PF 'E', 142 sx 'G', 100 sx PF 'C' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet EffeCtive depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate Production Liner Perforation depth: measured ~,UC 2 51997 true vertical .~a-$~ .0ii .& Gas Cons..C0.mmissl, ' ~nnhnrnnn 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] [] Ddlling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number: Terrie Hubble, 564-4628 21., hereby certify that the/~oing is t,~n~d c..)orrect to the best of my knowledge~'~ ] Signed Chip Alvord ~) ~..- ~..-J,.,~, Title Senior Ddlling En~lineer Date Commission Use Only Permit Number i APl Number i Appro.val Dj~e) See cover letter /~;~,~.-/",~'.~ 50- O ~- '~ - ~ 2_ ~<:::3 ~ .~! ~OI for other requirements Conditions of Approval: Samples Required []Yes []No Mud Log Requ~rea, []Yes ~]No Hydrogen Sulfide Measures !-] Yes 'J~ No Directional Survey Required ~ Yes I-] No Required Working Pressure for BOPE .[~2M; []3M; []5M; []10M; []15M Other: Approved By R~bert N. Christenson Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit / iplicate STATE OF ALASKA ALASKA',J1L AND GAS CONSERVATION COb%VllSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test !--I Development Oil []Re-Entry I--IDeepenI []Service I--] Development Gas I--lSingleZone I--I Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 66.5' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 380109 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2863' NSL, 4158' WEL, SEC. 34, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 25100302630-277 4026' NSL, 2734' WEL, SEC. 02, T12N, R10E, UM MPH-11i At total depth 9. Approximate spud date Amount $200,000.00 3781' NSL, 2786' WEL, SEC. 02, T12N, R10E, UM 08/28/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025518, 1499' MDI No Close Approach 2560 7023' MD / 4271' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 500' Maximum Hole Angle 74.96° Maximum surface 1311 psig, At total depth ti'VD) 3835' / 1695 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 260 sx Arctic Set (Approx.) 8-1/2" 7" 26# L-80 BTC-Mod 6992' 31' 31' 7023' 4271' 895 sx PF 'E', 142 sx 'G', 100 sx PF 'C' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor SurfaceRE(E V , Intermediate .... Production Liner AUG E 5 1997 Perforation depth: measured ~~~-~.¢ true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I herebycertifythatthe/fore~oing ist,~~orrect tothe best ofmyknowledgesigned ~)~ ~7~ / Chip AIvord v~,'*-/~'~, Title Senior Drilling Engineer Date 2,, Commission Use Only ,~,/'>'-/~',.~' 50- O ~- ~'~- ~ -P--- ~'4:3.2._ ~(.~Ot l~ ") for other requirements Conditions of Approval: Samples Required I--lYes I~No Mud Log Required []Yes ~No Hydrogen Sulfide Measures l-lYes ,j~ No Directional Survey Required J~Yes[~ No Required Working Pressure for DOPE J~2M; []3M; [] 5M; [] 10M; [] 15M Other: ORIGINAL SIGNED By by order of ~/~),71" a~e Approved By Robert N. Chdsten.~c~ Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submitqn Tri[~,lic I Well Name: IMP H-11i Well Plan Summary IType of Well (producer or injector): SCHRADER BLUFF INJECTOR Surface Location: 2863 FSL, 4158 FEL, S34 T13N R10E UM Target Location: 4026 FSL, 2734 FEL, S02 T12N R10E UM Bottom Hole Location: 3781 FSL, 2786 FEL, S02 T12N R10E UM I AFE Number: J 337093 I Estimated Start Date: I 28 AUG 97 I I MD: 17023' I I TVD: I Well Design: J Rig: I Nabors22E Operating days to complete: ® I 16.0 I KBE: 66.5 Schrader Bluff Injector Formation Markers: Formation Tops MD TVDSS KOP 500 433 Base of Permafrost 1818 1725 Top of Ugnu 5472 3381 Top M Sand 6080 3606 Top NA (Target) 6448 3835 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 6484 3858 NCND 6534 3890 NE 6558 3906 NF 6630 3952 OA 6680 3984 OA4 6726 4014 OB 6775 4045 Top of Seabee 6823 4076 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 7023 4204 TD at 200' MD past base of Schrader Casinl~/Tubin~l Program: Hole ~ize Csg'/ Wt/Ft Grade Conn. Length Top Bottom Tb~l O.D. MD/TVD MD/TVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112'/112' 8-1/2" 7" 26# L80 BTC-Mod 6992' 31 '/31' 7023' / 4271' Pipe Specifications: O.'D. Wt/Ft Grade Conn. ID Area Tensile Max Pull Collapse Burst (bbl/ft) (kips) (80% TR) (psi) (psi) 20" 94# H-40 Weld 19.124" 0.3552 40.0 32.0 520 1530 7" 26# L-80 BTC-Mod 6.276" 0.0382 80.0 64.0 5410 7240 5" 19.5# G (Pr) 4-1/2" IF 4.276" 0.0178 436.1 348.9 8765 12163 5" 19.5# E (Pr) 4-1/2" IF 4.276" 0.0178 311.5 249.2 7041 8688 Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/fi) to the reservoir at +3835' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1695 psi (8.65 ppg EMW), is 1311 psi, well below the internal yield pressure rating of the 7" casing. Shared Services Drilling Contact: J.E. Robertson 564-5159 Logging Program: Open Hole Logs: Cased Hole Logs: Mudloggers are NOT re¢ MWD from surface to TD LWD (GR/Resistivity) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr through the Ugnu and Schrader Bluff intervals. USIT for cement bond GR/CCL with the completion rig.) uired for this well. Mud Program' Spud Mud rSpecial design considerations ISee "Drilling Hazards and Risks" section about dealing with the possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel ~lel Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 9.0 100 35 15 30 10 8-10 (final) TOP OF SCHRADER BLUFF TO TD: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.3 80 20 10 20 9.5 6 (as required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. A Completion/Workover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1500', S-shaped profile Maximum Hole Angle: 174.96© Close Approach Well: I NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on H-Pad have been permitted for annular injection. MP H-11i Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. N/U and function test diverter system. Build Spud Mud. 5. Drill 8-1/2" surface hole as per directional plan to 7,023' MD ! 4,204' TVD. Run Directional MWD from surface to TD and run LWD GR/Resistivity from the top of the Ugnu to TD. NOTE: Short trip no deeper than 300' MD past the base of permafrost. After the base of the permafrost, trips should be made every 1000'-1300' MD, or as hole conditions require. NOTE: The well will require two insert bits. Drill no deeper than the top of the Ugnu with the first bit, then POOH for a bit change, new MWD tool, and to pick up LWD tools. Current guidelines are to run the first bit at least 30 hours drilling. NOTE: Drill at a controlled rate of no more than 200 ft/hr through the Ugnu and Schrader Bluff sands to ensure good LWD readings. 6. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 7. POOH and LD BHA. 8. Run and cement 7", 26#, L-80, BTC-Mod casing with centralizers appropriately placed as per program. 9. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost (2100' md). Displace STAGE1 cement with seawater at 8.0-10.0 bpm. NOTE: Reciprocate pipe while pumping cement if possible/practical. After opening the ES cementer, circulate seawater a minimum of 2 hours before pumping the STAGE2 cement slurry. Displace the second stage with diesel. 10. N/U FMC Gen 6 Wellhead and Tree. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) DRILLING HAZARDS AND RISKS: See the latest Milne Point H-Pad Data Sheet prepared by Pete Van Dusen for information on H pad. Particularly close attention should be paid to hydrate experiences on previous H-Pad wells. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: HYDRATES WERE ENCOUNTERED ON MP H-14. PLAN ON LECITHIN TREATMENT AS WELL AS WEIGHTING UP TO AN APPROPRIATE MUD WEIGHT TO MANAGE THE HYDRATES. 9.8 PPG WORKED ON MP H-14. Hydrates have occurred on H-Pad and there is a possibility that hydrates may be encountered in the drilling of MP H-111. Three wells drilled in 1995, MPH-05, MPH-06, and MPH-07 all encountered hydrates below the permafrost. On MPH-05 and MPH-06, mud weight was significantly cut as a result. Lecithin (DrillTreat) should be added to the mud system as a precaution before drilling through the base of the permafrost. If hydrates are encountered, mud weights will be increased to 10.2 ppg, or heavier if required, and lecithin (DrillTreat) will be added to the mud system. The cement program includes an ES cementer set below the permafrost. Should hydrates be encountered while drilling, the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MP H-11i. 3. Lost Circulation: Lost circulation has been experienced when drilling the Schrader sands and can be countered by having LCM on hand. MPH-05 experienced lost returns at 3708' TVDSS while drilling with heavy 11.5 ppg mud that was used to deal with hydrates. LCM should be kept on hand, particularly if the mud is weighted up to counteract gas cut mud due to hydrates. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on H-Pad to date, but the rig crew should remain attentive and take precautions to prevent stuck pipe from occurring. If heavy gravels are encountered, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinq Concerns Due to the relatively shallow depth of the Schrader Bluff wells and the large stepouts, some directional drilling will have to be done in the permafrost. The rig crew should be particularly attentive to the wellbore trajectory to ensure that the target objectives are met. Note that care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 8. Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Also, the relatively small 8-1/2" by 7" annulus will require extra attention to pump rates and pressures. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. Plan on using a 'C' cement for the second stage tail cement due to probability of hydrates. MP H-11i 7" SURFACE/PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: ~ 80°F SPACER: 50 BBL Weighted Spacer (Weighted to TD mudweight). STAGE1 LEAD: TYPE 'E' PERMAFROST ADDITIVES: FLOCELE (0.25 #/sk) WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sk APPROX #SACKS: MIX WATER: 11.63 gal/$k 305 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE TOP OF THE STAGE1 TAIL TO THE ES CEMENTER STAGE TOOL (2100' MD > 200' MD BELOW BASE OF PERMAFROST) + 50% EXCESS. STAGE1 TAIL CEMENT TYPE: PREMIUM ADDITIVES: SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk), FLOCELE (0.1 #/sk) WEIGHT: APPROX #SACKS: FLUID LOSS: 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 142 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (7023' MD) TO 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (5580' MD) + 50% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. STAGE2 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg 39O SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM TOP OF STAGE2 TAIL AT 1668' MD TO SURFACE +300% EXCESS. STAGE2 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'C' PERMAFROST Retarder 15.6 ppg 100 SACKS YIELD:0.95 ft3/sk MIX WATER: 3.60 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. 430' OF ANNULAR VOLUME AT 30% EXCESS FROM ES CEMENTER AT 2100' MD. EST TOP 'C' 1668' MD WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - one (1) per joint on the bottom twenty-three (23) joints of 7" casing. Run two centralizers on the bottom joint of casing and on the top centralized joint of casing as well. (23+2 = 25 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 7.0-8.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is not necessary. DISPLACEMENT OF CEMENT: Because Nabors 22E will be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with seawater a volume equal to the capacity of the 7" casing from TD up to surface. Ensure that the seawater has been treated with biocide and is relatively "bug-free." 2. After bumping the plug, quickly check to ensure that the floats are holding and then shear the ES cementer to the open position. 3. Circulate seawater through the ES cementer for two hours to clean and condition contaminated cement. 4. Pump the second stage as per the detailed cement program, circulating the water through the ES cementer and across the permafrost to surface. When cement returns are seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for reuse on another well. Anadrtll Schlumbezz3er Alaska District lff£ East 80th Avenue Anchorage, AK 995£8 (907) 349-45%1 Fax 344-2160 DIRBCTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPH-i[(PS] Field ........ : Milne Pofnt, H-Pad Cc~putation.,: Minim~u~ Ch~rvature Units ........ : FHBT Surface Lat,.: 70.~3800782 N Surface Lon~.: 149.5394£798 W Legal Description Surface ...... : 2062 FSi 4158 PHi Target ....... : 4026 FSb 2734 FH5 BHL .......... : 3781 FSb 2786 FEi LOCQ%TIONS - ALASKA Zone: 4 X-Coord Y-Coord S34 T13N RIO~ L~4 556487.05 603OOL3.33 S02 Tf2N R1OH UM 557945.00 600~909.00 S02 TI2N R10~ b~4 557894.56 6~O5663.01 PROPOSHD NELL S~ATION N]{~SURED K~CL~ ~O~NT~FICATION D~t~TH AI~G6E KB 0.00 0.00 ~P/BUELD ~/100 500.00 0.00 600.00 1.00 700.00 2~00 BUI~ ~.5/100 800.00 3.00 DIRECTION V~RT~CA~-D~PTH8 AZIMUTH TVD SUg-SEA O.00 0.00 -66.50 0-00 500.00 ~33.50 L62-53 ~99.99 533.49 £62.5] 699.96 63].46 £62.5] 799.86 733.36 SECT/ON DEPART 0.00 -0.00 0.97 3.49 7.85 Prepared ..... : 30 Jul 3997 Vert sect az.: 162.5~ KB elevation.: 66.50 ft Magnetic DCJn: +2~.975 Scale Factor.: 0.99990362 Convergence..: .~.~2299~!? -- '~DR~ AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION PLAN # "" OOORDIHATES-FRO~ ALASKA Zone 4 TO05 WEL~HHAD X Y FACH 100 0.00 N 0.00 ~ ~56487.05 60~0013.~3 HS 0.00 0.00 H 0.00 E 5564Bg.05 6010013.~ 163R 0.00 0.B3 S 0.26 E ~56~B?.32 6010012.50 163R 1.00 3,33 S L.05 ~ 556488,12 6010010.01 163R 1.00 7.49 S 2.36 H 556489.47 6010005.86 163R £.00 ,cur ~.~2/~ oo 900,00 4.50 ~62.51 899.65 833.15 1000,00 6.00 ~62.5~ 999.22 932.72 1100.00 7.50 162.51 ~090.5] 1032.03 ~200.00 9.50 162.5L 1397.42 £130.92 ~300.00 11.50 162.5/ 1295.74 1229.24 1400.00 13.50 L62.5~ 1393.37 1326.87 1S00.00 i5.50 162.51 1490.18 1423.68 14.39 23.54 35.30 50.08 68.30 89,94 114,98 13.73 S 4.33 H 556491.48 6009999,64 163R ~.50 22.45 S 7.08 E 556494.30 6009990,93 HS 1.50 33.66 S 10.61 E ~6497.91 6009979.75 HS 1,~0 47.76 S 15.05 E 556502.~6 6009965.69 HS 2.00 65.14 S 20.53 E 556508,0~ 6009948.35 HS 2.00 85.78 S 27.04 H 556514.73 6009927.76 MS 2.00 309.66 $ 34.56 H 556522.44 6009903.95 HS 2.00 "0 ]> ~-) rq STATION I DENT I F £CAT]ON HND 2/100 BUILD BASH PHRMAFROST BUILD 3/LO0 >9 0<,.,, SND 3/ioo TOP UGNU PROPOSHD WEI.~. PROFXLH M~ASURED INCLN DIRECTION DEPTH ANGLE AZIMUTH 1600.00 17.50 162.51 1700.00 19.50 £62.51 1788.24 21-26 ~62.51 1818.18 21.26 162.51 1848.24 21.26 162,51 1900.00 22.82 2000.00 25.82 2L00.00 28.82 2200.00 31.82 2300.00 34.82 2400.00 37.82 2500.00 40.82 2600.00 43.82 2700.00 46.82 2800.00 49.82 2900.00 52.82 3000.00 55.82 3100.00 58.82 3200.00 61.82 3300.00 64,82 3400-00 67.82 3500.00 70.82 3600.00 73.82 3637.93 74.96 5472.71 74.96 VHRT ICAh- DHFI"HS SHCTIO~ TVD SUB-SKA DHPAET 1586.06 1519.56 143,38 [680.88 1614.38 175,LL [763.60 1697.10 205.84 1791.50 1725.00 216.70 ]819,51 1753.01 227.60 162.51 1867.49 1800.99 247.02 162.51 1958.60 1892.10 288.20 162.5! 2047.44 1980.94 334.08 162.5] 2133.76 2067.26 384.56 162-5] 22L7.3£ 2150.81 439.48 L62.51 2297.88 223L.38 498.70 L62.51 2375.23 2308.73 562.05 L62.51 2449.16 2382.66 629.37 162.51 2519.47 2452.97 700.46 362.51 2585,97 2519.47 775.14 162,51 2648.46 2581.96 853.19 162.51 2706,78 2640.28 934.41 162.51 2760.78 2694.28 L018.~7 162.51 2810.29 2743.79 1105,44 162.5~ 2855.19 2788.69 2194.78 162.51 2895.35 2828.85 1286.34 162.51 2930.66 2864.16 1379_89 [62.51 296L.04 2894.54 1475.X5 L62.51 297L.24 2904.74 15LL~68 ~62.51 3447.50 3381.O0 3283.58 30 JuL 199'; Page 2 COORD/NAT~S-FRO~ AL~KA Zoae 4 TOOL DL/ WELLHHAD X Y FACE 100 : 136.75 S 43.L0 E 556531,18 60098~6.93 ES 2.00 167.01 S 52.64 E 556540.95 6009846.74 HS 2-00 196.32 S 61.88 ~ 556550.4~ 60098L7.50 RS 2.00 206.67 S 65.14 ~ 556553.75 6009807.17 ~S 0.00 217.07 S 68.42 H 556557.~1 6009796.80 HS 0.O0 235-60 S ~4,26 B 556563.08 6009??8.33 RS 3.00 274.87 S 86.64 E 556575.76 6009739.15 HS 3.00 3L8.63 S 200.43 E 556589.88 6009695.50 HS 3.00 366.77 S 115.60 E 556605,42 6009647.48 HS 3.00 419.15 S 132.11 ~ 556622.32 6009595.23 ~ 3.00 475.63 S 149.92 H 556640.55 6009538.89 HS 3.00 536.06 B 168.96 H 556660.05 6009478.62 HS 3.00 600.26 $ 189.20 ~ 556680.?7 6009414.58 RS 3.00 668.06 S 2L0.57 ~ 556702.65 6009346.95 RS 3.00 · 739.28 S 233,02 B 556725.64 6009275.90 HS 3.00 8L3.73 S 256.48 B 556?49,66 600920L.65 HS 891.19 S 280.90 g 556774.66 6009124.38 }IS 971.45 S 306.20 ~ 556000.5~ 6009044.32 }ES L054.30 S 332.31 H' 55682~.30 6008961.68 HS 1139,51 S 359.17 ~ 556854.80 6008876.68 HS 1226.84 9 386.70 H 556882.99 6008789.5~ RS 1316.06 S 4L4.82 R 556911.78 6008700.57 HS 1406.92 S 443,45 H 556941,10 6008609.94 HS 1441.76 S 454.43 E 556952,]~ 6008575.19 HS 3131.?0 S 987.09 E 557497,74 6006889.50 HS 3.00 3.00 3.00 3.00 3.00 3.00 2.00 3.00 3.00 0.00 DR09 4/100 5624,59 74.96 5700.00 71.94 5800.00 67.94 (Anadrill (c) 9~ MPHllP5 3.0C 8:L6 AM P) L62.51 3486.92 ]420.42 3430.25 162.51 3508.40 344190 3502.52 162.51 3542.70 3476.20 3596.44 3271.58 S 2031.19 E 557542.88 6006749.9? 3340.52 S 1052_91 E 557~65./3 6006681.2l 3430,09 S 1081.15 H 557594.04 6006591,86 0.00 4.00 4. O0 "0 rq M~H-LL(~5) 30 Oul ~997 ~age 3 STATION IDRNTIFICATION TOP M SAND DHPTH A/~GLE 5900.00 63.94 6000.00 59.94 6080.04 56.74 6100.00 55.94 6200.00 51.94 D~P.~CT]ON ~RT£CAL-D~PTHS AZ rMUTH TVD SU~ - SEA 162.5L 3583.46 35L6.96 3687.73 362.5l 3630,49 3563.99 3575.96 162.5£ 3672,50 3606,00 3844.07 162.51 3683.57 3617.07 3860.69 162.5] 3742.42 3675.92 3941.51 SECTION COORD1NATHS-PROM DEPART WELLHHAD __ 3517.16 S 5601.30 S 3666.27 S 3682.~ S 3759.90 S ALASKA Zone 4 TOOL DL/ X Y FACE 100 ]108.59 E 557622.14 6006505.01 LS 4.00 1135.11 E 557649.30 6006421,08 LS 4.00 1155.59 E 557670.26 6006356.27 LS 4,00 1~60.58 H 557675.58 6006340.47 DS 4.'00 ~84.88 E 557700_25 6006263.58 LS 4-00 END 4/~00 DROP TARGHT TOP SCHRADHR / NA ~c/~ 6248.47 50.00 6448.47 50.00 6448.47 50,00 6484.25 S0.00 6534.04 50.00 162.51 3772.94 3706.44 3979.16 3795-13 ~ £196.20 E 162.51 390£.50 3835.00 ~132.37 ]941.23 S 1242.26 H 162.51 390L.50 3835.00 4132,37 3941.23 S 1242.26 E 162.53 3924.50 3858.00 41~9.78 3967.37 S 1250.50 E 162.51 3956.50 3890.00 4197.92 4003.75 S 126~.96 E 557711.84 6006227.76 HS 4.00 557759,~0 6006082-00 }iS O.QO 557759.00 6006082.00 HE 0.00 557767.44 6006055,92 ]{S 0.00 557779.~8 6006019.64 HS 0.00 NE NF OA4 6558.93 50.00 6630.49 50.00 6680.28 50.00 6726.95 50.00 6775_17 50.00 162.51 3972.50 3906.00 42£6.99 4021.93 162.51 40LS.5Q 3952.00 423£.8l 4074.22 S 162.51 4050.50 3984.00 4309.94 4110.59 162.51 4080.50 4014.00 4345.g0 41%4-69 £62,51 4~11.50 4045.00 4382.64 4179.92 1267.69 H 557785.04 600600L.50 H8 0.00 1284.17 ~ 55780£.92 6005949.35 HS 0.00 1295,64 H 5578£3.66 600591].07 H$ 0.00 1306.38 H 557824.66 6005879.05 85 0.00 1337.49 ~ ~57836.03 6005843.91 HS 0.00 EASH SCHRADER ?' CASING POINT TD 6823.40 50.00 7023.40 50.00 7023.40 50.00 ~62.51 4£42.50 4076.00 4419.58 42~5-16 £62.51 4273,06 4204.56 4572.79 436[.28 162.5[ 427~.06 4204.56 4572.79 4361.28 1328.60 E 557847.40 600S808.76 ]374.65 E 557894.56 6005663.01 3374.65 E 557894.56 6005663.01 0. O0 (I .00 0.00 ANADRILL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION PLAN - ,.____..._.__~ ....... (Anadrill (c) 9? MPHt£P~3.0%k4:16"~"'ZP) ..................................... ,.~ ............. ~'~/7'¢~' .......................................................................................................................................... ~,. Z ' SHARED SERVI'CES DRILLING i Anadr~ ]] Schlumberger I i ii ii i i iii ~1 i MPH- _1 [PS) VERTICAL SECTION VIEW - I -- A " ANAi)RiLL ~v~ r~)¢' Section at: 162,5] . -" ..... TVD Scale.: I inch = BOO feet FEAS!3ILl~ Plan I~e~ s~,.: 1 ~.~h = ~00 EX ECU T~Or 4.~ ~pk~p Identification ~ 8K8 SEC]~ INCL ~ ~-~ .............. B) KOP/BUILD !/100 500 ~0 -0 0.0 O - C) BUILD 1.5/100 800 ~0 8 3.0 ' D) BUILD 2/100 ilO0 JOg9 35 7.5 E) END ~/lOO eU~LO ~Tee ~754 206 F) BUILD 3/t00 1848 )8~ a28 G) END 3/]00 BUZLD ~38 2971 1512 74.9 H) ~OP 4/100 5625 3487 3430 74.9 ...... ~-~K'~l~ I) ENO 4/)00 DROP 6~48 3773 3979 50.0 J) IARGEI 6448 3901 4i3a 50.0 ...... K] 7" CASING POINI 70~3 427l 4573 50.0 L) lB 70~3 4~71 4573 50.0 , .,. , ,, -,............ ~~ ~ --- & = ~ ....................... _ ................. ) ...................................................................................................................................................................................................................................... Section Departure i im ii i ii i m I IN~adrli] Ic197 iPHiim 3:~C-8:22 AH p) '7- "13 :I> ITl I . SHAREB SERV I'C~'S ..B. RILL I NG I VERTICAL SECTION, VIEW /Section at: 168.51 ITVD Scale.: 1 inch.= ~00 feet ,,, /Oep Scale.: ~ inch -- ~00 feet ~0 /Dnawn ..... : 30 Jul ~997 ~ Anadni ]] $chJumbergef' MarkeA ~entJficatJon MD BKB SECTN INCLb ]0~ _.. ~ A) END 4/t00 DROP 6248 3773 3979 50.0[ B) T~RGET 6~8 ~901 4J32 50,0C C] 7" CASING POINT 70~3 4~71 ~57~ 50.0C ~0--- · D) TO 70~3 . ~7~ 4573 50.0C ,.. ~-~ ............ ~ m mmm ,. )~ , . ~ ANADRtL![~1~11~ AKA .DPC ~ ' ' NOT/kPP~:OVE~D FC)R ........... E;<ECI ., ' ~ ~% ~__. I ~.. 4000 4050 4JO0 4150 4200 4250 4300 4350 4400 4450 4500 4550 ,Se.c t. lo.n. Departure 08/25/i997 10'06 907-344-2i60 ANADRILL DPO SHARED SERV ICES DR ILL I'NG i mi i i i i ! i ~rker Identification HO N/S Il KB 0 o N BI KOP/BU[LD t/~O0 500 0 N C) BUILD i.5/100 800 7 S D) BUILD 2/100 ~100 34 S E) END 2/t00 BUILD ~788 t96 S F) BUILD 3/100 1848 2~7 S G) ENO 3/t00 BUILD 3638 1442 S H) DROP 4/100 5625 3872 S I) END 4/~00 DROP 6248 3795 S J) TARGET 6448 394t S K) 7" CASING POINT 7023 4361S L) TO 7023 4361S i ill MpH-ii (p5) PLAN VIEW 62 E PAGE 68 E 454 E 1031E 1196 E 1242 E 1375 E 1375 E 07 , i CLOSURE ..... : 4573 feet at Azimuth 162.5,.' DECLINATION.' +27.975 (E) ,SCALE - ~ inch = 800 feet 'DRAWN ' 30 Jul ~997 .m /nadr J ] ] $£hYumb£rger ! ;'_! ~ .-_ ANA )RILL AKA-C',PC i F F_..ASI B! LI--Y PLANi N()T APPR()VE[) FOR ' ' E>:ECL TIOiq : t , PLAN ~__¢-.~''~ _ [ , , '--' t (R~dius 100 feet "1 i . ~...- 2800 2400 2000 1600 1200 800 400 0 400 BOO J200 1600 2000 2400 <- WEST' EAST-> · ~.800 I Well Name: IMP H-11i I IType of Well (producer or injector): Well Plan Summary SCHRADER BLUFF INJECTOR Surface Location: 2863 FSL, 4158 FEL, S34 T13N R10E UM Target Location: 4026 FSL, 2734 FEL, S02 T12N R10E UM Bottom Hole Location: 3781 FSL, 2786 FEL, S02 T12N R10E UM I AFE Number: I 337093 Estimated Start Date: I 28 AUG 97 I I MD: J 7023' I ITvD: I Well Desitin: Formation Markers: Rig: I Nabors 22E I Operating days to complete: 14271' I 16.0 KBE: 66.5 Schrader Bluff Injector Formation Tops MD TVDSS KOP 5OO 433 Base of Permafrost 1818 1725 Top of Ugnu 5472 3381 Top M Sand 6080 3606 Top NA (Target) 6448 3835 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 6484 3858 NCND 6534 3890 NE 6558 3906 NF 6630 3952 OA 6680 3984 OA4 6726 4014 OB 6775 4045 Top of Seabee 6823 4076 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 7023 4204 TD at 200' MD past base of Schrader Casing/Tul~ ing Program: Hole Size Csg/ WtJFt Grade Conn. Length Top Bottom Tbs O.D. UDrrVO MD/TVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112'/112' 8-1/2" 7" 26# L80 BTC-Mod 6992' 31'/31' 7023' / 4271' Pipe Specifications: O.D. Wt/Ft Grade Conn. ID Area Tensile Max Pull Collapse Burst (bbl/ft) (kips) (80% TR) (psi) (psi) 20" 94# H-40 Weld 19.124" 0.3552 40.0 32.0 520 1530 7" 26# L-80 BTC-Mod 6.276" 0.0382 80.0 64.0 5410 7240 5' 19.5# G (Pr) 4-1/2" IF 4.276" 0.0178 436.1 348.9 8765 12163 5" 19.5# E (Pr) 4-1/2" IF 4.276" 0.0178 311.5 249.2 7041 8688 Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/fi) to the reservoir at ±3835' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1695 psi (8.65 ppg EMW), is 1311 psi, well below the internal yield pressure rating of the 7" casing. Shared Services Drilling Contact: J.E. Robertson 564-5159 Logging Program: Open Hole Logs: Cased Hole Logs: Mudloggers are NOT re( MWD from surface to TD LWD (GR/Resistivity) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr through the Ugnu and Schrader Bluff intervals. USIT for cement bond ',GR/CCL with the completion rig.) uired for this well. Mud Program: Spud Mud ISpecial design considerations I See "Drilling Hazards and Risks" section about dealing with the I possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 9.0 100 35 15 30 10 8-10 (final) TOP OF SCHRADER BLUFF TO TD: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.3 80 20 10 20 9.5 6 (as required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4', 2000 psi W.P. Diverter with 10" Diverter Line. A CompletionNVorkover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1500', S-shaped profile tMaximum Hole Angle: Close Approach Well: 74.96 NONE Waste Management: Cuffings Handling: All cuttings will be hauled to the CC-2A.facility.' Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on H-Pad have been permitted for annular injection. MP H-11i Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2.. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. N/U and function test diverter system. Build Spud Mud. 5. Drill 8-1/2" surface hole as per directional plan to 7,023' MD / 4,204' TVD. Run Directional MWD from surface to TD and run LWD GR/Resistivity from the top of the Ugnu to TD. NOTE: Short trip no deeper than 300' MD past the base of permafrost. After the base of the permafrost, trips should be made every 1000'-1300' MD, or as hole conditions require. NOTE: The well will require two insert bits. Ddll no deeper than the top of the Ugnu with the first bit, then POOH for a bit change, new MWD tool, and to pick up LWD tools. Current guidelines are to run the first bit at least 30 hours drilling. NOTE: Drill at a controlled rate of no more than 200 ft/hr through the Ugnu and Schrader Bluff sands to ensure good LWD readings. 6. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 7. POOH and LD BHA. 8. Run and cement 7", 26#, L-80, BTC-Mod casing with centralizers appropriately placed as per program. 9. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost (2100' md). Displace STAGE1 cement with seawater at 8.0-10.0 bpm. NOTE: Reciprocate pipe while pumping cement if possible/practical. After opening the ES cementer, circulate seawater a minimum of 2 hours before pumping the STAGE2 cement slurry. Displace the second stage with diesel. 10. N/U FMC Gen 6 Wellhead and Tree. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) DRILLING HAZARDS AND RISKS: See the latest Milne Point H-Pad Data Sheet prepared by Pete Van Dusen for information on H pad. Particularly close attention should be paid to hydrate experiences on previous H-Pad wells. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: HYDRATES WERE ENCOUNTERED ON MP H-14. PLAN ON LECITHIN TREATMENT AS WELL AS WEIGHTING UP TO AN APPROPRIATE MUD WEIGHT TO MANAGE THE HYDRATES. 9.8 PPG WORKED ON MP H-14. Hydrates have occurred on H-Pad and there is a possibility that hydrates may be encountered in the drilling of MP H-111. Three wells drilled in 1995, MPH-05, MPH-06, and MPH-07 all encountered hydrates below the permafrost. On MPH-05 and MPH-06, mud weight was significantly cut as a result. Lecithin (DrillTreat) should be added to the mud system as a precaution before drilling through the base of the permafrost. If hydrates are encountered, mud weights will be increased to 10.2 ppg, or heavier if required, and lecithin (DrillTreat) will be added to the mud system. The cement program includes an ES cementer set below the permafrost. Should hydrates be encountered while drilling, the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MP H-11i. 3. Lost Circulation: Lost circulation has been experienced when drilling the Schrader sands and can be countered by-having LCM on hand. MPH-05 experienced lost returns at 3708' TVDSS while drilling with heavy 11.5 ppg mud that was used to deal with hydrates. LCM should be kept on hand, particularly if the mud is weighted up to counteract gas cut mud due to hydrates. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on H-Pad to date, but the rig crew should remain attentive and take precautions to prevent stuck pipe from occurring. If heavy gravels are encountered, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinq Concerns Due to the relatively shallow depth of the Schrader Bluff wells and the large stepouts, some directional drilling will have to be done in the permafrost. The rig crew should be particularly attentive to the wellbore trajectory to ensure that the target objectives are met. Note that care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 8. Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Also, the relatively small 8-1/2" by 7" annulus will require extra attention to pump rates and pressures. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. Plan on using a 'C' cement for the second stage tail cement due to probability of hydrates. MP H-11i 7" SURFACE/PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: ~ 80°F SPACER: 50 BBL Weighted Spacer tWeighted to TD mudweicjht). STAGE1 LEAD: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: FLOCELE (0.25 #/sk) 12.0 ppg YIELD: 2.17 ft3/sk MIX WATER: 11.63 gal/sk 305 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE TOP OF THE STAGE1 TAIL TO THE ES CEMENTER STAGE TOOL (2100' MD > 200' MD BELOW BASE OF PERMAFROST) + 50% EXCESS. STAGE1 TAIL CEMENT TYPE: PREMIUM ADDITIVES: SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk), FLOCELE (0.1 #/sk) WEIGHT: APPROX #SACKS: FLUID LOSS: 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 142 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 rains @ 80°F FREE WATER: TAIL CEMENT FROM TD (7023' MD) TO 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (5580' MD) + 50% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. STAGE2 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sk . 39O SACKS MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM TOP OF STAGE2 TAIL AT 1668' MD TO SURFACE +300% EXCESS. STAGE2 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'C' PERMAFROST Retarder 15.6 ppg 100 SACKS YIELD:0.95 ft3/sk MIX WATER: 3.60 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. 430' OF ANNULAR VOLUME AT 30% EXCESS FROM ES CEMENTER AT 2100' MD. EST TOP 'C' 1668' MD WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - one (1) per joint on the bottom twenty-three (23) joints of 7" casing. Run two centralizers on the bottom joint of casing and on the top centralized joint of casing as well. (23+2 = 25 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 7.0-8.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is no.t. necessary. DISPLACEMENT OF CEMENT: Because Nabors 22E will be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with seawater a volume equal to the capacity of the 7" casing from TD up to surface. Ensure that the seawater has been treated with biocide and is relatively "bug-free." 2. After bumping the plug, quickly check to ensure that the floats are holding and then shear the ES cementer to the open position. 3. Circulate seawater through the ES cementer for two hours to clean and condition contaminated cement. 4. Pump the second stage as per the detailed cement program, circulating the water through the ES cementer and across the permafrost to surface. When cement returns are seen at surface, 'drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for reuse on another well. Anadrt[[ Schlumbe~jer 1[[[ t{ast 8Otb Avenue Anchorage, ~K 995L8 (90~] 349-4511 Fax 344-2~60 D[RBCTIONAL WELL PI~MN for SHAR.SD SERVICES DRILLING Well ......... : P£eld ........ : MiLne ~oLnt, H-Pad Computation..: Minimum Curvature Surface Lat..: 70.43800782 N Surface Long.: /49.5394/798 begal DescrLptton Surface .... ~: 2862 I~SL 4158 Tarset ...... :.: 4026 WSb 2734 BHL ......... {~: 378/ FSU 2786 hOCATIONS - AIASKA Zone: X-Coord 834 TL3N R10H OM 556487.05 R02 TL2N RIOH ~ 553945.00 S01 TI2N R~OB ~ 557894.56 4 ,Y-Coord 60100L3.33 6005909.00 6005663.01 PROPOSRDWEI~L PROPIbR S~ATION '~O~ASURED INC~N ]DH~ICATZON DRL~I'H ANGLE KB 0,00 0.00 KDP/gU£LD ~/10~ ~00,00 0.00 600.00 1.00 700.00 2,00 BUILD 1.5/1~0 800.00 3.00 Prepared ..... : 30 Jul 399~ Verb sect az.: 162.51 YJ3 elevation.: 66.50 ft Masnet/c Du'ln: +23,975 (R) Scale Pactor. ~ 0.999903~;2 Convergence..: .~.~2'3 · 'A-NA~ AKA-DPC FEASIBILITY APPROV[D FOR .... _ .. . ~ .~,~ ...... , D[RJ~CTION V~RTICA~-DBPTHS SECT/ON OOO]~DINATES-~RO~ ALASKA Zone 4 ~6 DL/ AZ~H ~ S~-S~ DEPART ~LLH~ X Y ~ACE 100 O.00 0.00 -66.50 0.00 0.00 N O.00 E ~5648g.05 60~0013.~3 ~S 0.00 0-O0 500.00 433.50 -0.00 0.00 N O.00 E 556489.05 60L0013.33 163R 0,00 [62.51 599.99 533.49 0.87 0.83 ~ 0,26 I 556t87.32 6010012.~0 163~ 1.00 [62,51 699.95 633.46 3.49 3.~ S 1,05 B 556488.12 6010010.01 163R 1.00 162.51 799.86 733.36 7.85 7.49 S 2.36 B 556489.47 6010005.86 163R L.00 aur Z.D 2/100 ,900.00 4-50 162.51 899.65 833.15 14.39 13.73 ~ 4.33 H 556491.48 6009999.64 163R 1.50 /00O.00 6.00 362.5l 999.22 932.72 23.54 22.~5 ~ 9.08 R 556494.30 6009990.93 HS 1.50 1100.00 7.50 162.5[ 1098.51 1032.03 35.30 33.66 ~ 10.61 E 5~6497.91 6009979.75 HS 1,50 ~200.00 9.50' 162.5L ]397.42 L130.92 50.08 47.76'8 15.05 E 556502.46 6009965.69 RS 2,00 3300.00 11..50 162.5/ ~295.74 1229.24 68,30 65.14 S 20.53 E 556508.07 6009948.35 H$ 2.0D 1400.00 13.50 L62.51 1393.37 ]326.87 89.94 85.78 8 27.04 H 556514.73 6009923.76 HS 2.00 1500.00 £5.50 ~62.51 1490.18 1423.68 114.98 109.66 B 34.56 R ~6522.44 6009903.95 ~S 2,00 Z~ Z -0 I'rl LA~laGrl£L Icl~'/ mF~LF~ ~.v~ u:aO ~ r; ................................................................................. C53 STATION IDENTIFICATION END 2/100 BUILD BASE PERMAFROST BU/LD 3/[00 {lEmmm t, tHASURED XNCLN DEPTH ANGLE ~mmmmmmm ~ 3600,00 [7.50 1700.00 ~9.50 1788.24 21-26 1818.~8 2~.26 1848.24 23.26 END 3/100 BUILD TOP ~GNU DROP 4/100 1900.00 22.82 2000.00 2~,82 2/00.0~ 28,82 2200.00 31.82 2300,00 34,82 2400,00 3q.82 2500.00 40.92 2600.00 43.62 2700.00 46.62 2800.00 49.82 2900.00 52.82 3000.00 ~5.82 '3100.00 58,82 3200.00 61,82 3300.00 64,82 3400.00 67.82 3500.00 70.82 3600.00 73.82 3637.93 74.96 5472.71 74.96 5624.59 94.96 5700.00 71.94 5800.00 69.94 (Anadrill (c)~g MP811P5 3.0C 8:16 AM P) PROPOSED WE4~ PROFILE DIRRCTION YERTICA~-DRPT~S AZIMUTH TVD SU~-$BA [62.5~ 1586.06 ~519.56 162.51 [680.88 1614.30 ~62.51 ~763.60 1697.10 ~62.51 179~.~0 1725.00 ~62,~1 ~819,51 175~.01 SECTION D~PART [43.38 205.~4 2[6.~0 227.60 30 Ju~ 1997 Page COORD [NATES WHLLHHAD ~m 136.75 S 43.[0 167,01 S 52.64 396.32 S 61.~8 206.67 S 65.34 217.07 S 68.42 162.SL 1867.49 1800.99 247.02 235.60 S ';4,26 162.51 1958,60 LB92,lO 288.20 274.87 S 86.64 162.51 204'/.44 ~980.94' 334.08 318.63 S ]00.43 I~. 162.5~ 2L33.76 206?.26 384.56 ~66.~ S 115.60 162.5] 221'/.3[ 2150.81 439,48 4~9,15 .q 232 ..~1 [62.51 2297.88 2231.38 498.70 4~S.6] $ 149.92 [62.51 2395.23 2308-7] 562.05 536.06 ~ 168.96 162.51 2449.~6 2382-66 629.~? 600.26 S 189.20 162.51 25~9.4~ 2452.97 700.46 668.06 $ 2£0.5~ ~62.51 2585.97 25[9,47 '/'/5.~4 739.28 S 233,O2 162.51 2648,46 2561.96 853.19 813.73 162.51 2706.78 2640.28 934,41 893.19 162.5[ '2760.78 2694.28 L0~8.~7 97~,47 162.5[ 2810.29 2743.79 1~0~.44 [054.30 162.5~ 2875.19 2788.69 ~194.78 ~339.5[ 162.51 2895.35 2828.85 1286.34 162.51 2930.66 2864.16 1379-89 [62.51 296[.04 2894.54 14~5.15 ['62.51 297/.~4 ~904.74 162.51 3447.~0 338~,00 3283.58 £62.51 3486.92 3420.42 3430.25 162,51 3508.40 3441,90 3'502.52 162.51 3542.70 3476.20 3596.44 ALASKA Zone 4 TOOL X Y FACE 100 556531.18 6089876.93 HS 2.00 5~6540,95 6009846.74 85 2.00 $$6550.4~ 60098[7.50 HS 556573.g~ 6009807.17 }[S 0.00 55655'/.~1 6009796,80 ~S 0.O0 556563.08 6009~78.3~ HS 3.00 S56575.76 6009739.~5 HS 3.00 556589.88 6009695.50 HS 3.00 SS6605.42 6009647.48 HS 3.00 556622.32 6009595.23 HS 3.00 556640.55 6009538.89 RS 3.00 556660.05 6009478.62 HS 3.00 556680.~ 6009414.~8 H8 3.00 556702.65 6009346.95 HS 3.00 556725,64 600927S.90 HS 3.00 256,48 B 556~49,66 6009201.65 HS ~.00 280.90 E 556'/'/4,66 6009[24,38 NS 3.00 306.20 ~ 556800,5? 6009044,32 NS 3,00 332,31 E 556827,30 6008961,68 HS 3.00 359.1'/ ~ 556854,80 6008876,68 HS 3.00 1226.84 S 386.70 ~ 556882.99 6008789.5'/ NS 3.00 1316.06 S 414.82 H 556911.78 6008700.57 HS 3.00 1406.92 S 443,45 H 556941,10 6008609.94 HE 3.00 144[.76 S 454,43 ~ 556952,3~ 6008775.~9 HS 3.00 313£.?0 S 987,09 E S57497,74 6006889.50 BS 0.00 327L.58 S 2031.19 E 557542.88 6006749.9'/ LS 0.00 3340.52 S 1052.91 E 557565.13 6006681.21 LS 4,00 3430.09 S 1081.15 E 557594.04 6006591.86 bS 4,00 ]~ Z ~0 S~ION $900.00 63.94 6000.00 59'94 6080.04 56.74 TOP ~ gAND 6100.00 55.94 6200.00 51.94 pROPOSe3 ~SL, IJ pRO~Ih~ DIRIICT3ON ~RT~CAL-DBPTH8 AZ£tTOTH TVD 162.5L 3583.46 3~L6.96 162.~Z 3630.49 3563.99 16~-5L 3672.50 3606.00 162.~1 ~683.~7 3617.0~ ~62.51 3742-42 36~.92 --' ..... ALP~KA zone SECT~O~ COORD2NAT~$-vROM DEPART 3687,?3 ]744-07 ~860.69 S~ 4/200 DROP 62~8.47 SO.O0 162.~1 3772.94 ~706.44 3979 ~6 6488-47 50.00 ~62.51 ~90~.~0 3835.00 ~132.32 TARGBT 162,51 390L.50 3835.00 ~132.37 6484.25 50.00 162.Sl 3924.50 3858.00 ~ 6534.04 50.00 162.61 3956.50 3890.00 4X9q.92 ~c/~ 6558-93 50.00 262 .SX 39q2.Sa 3906.00 42 L6.99 ~ 6630.49 50.00 ~62.5X ~0kB.50 3952.00 BP 6680.~8 50'.00 ~62.~ 4050.5~ 3904.00 4309,94 .O~ 6726,95 50.00 162.5~ 40B0.5~ 4~4.00 OA4 '677'5-17 ~O.00 .~62.5~ 4Lll.50 404~,00 4382.64 OB BASB SCHRADHR 6823.40 SO,00 L62.SL 4[42.50 4076.00 4419,58 L62.SL 4273.06 4204.55 4572.79 7023.40 ~0,00 162.5L 42~1.06 X ~ FACE 100 ........ == ===== == = 4.00 3537,16 S 3108,59 ~ 55~622.L4 6006505-01 ~601.30 S 1135-~1 g 557649,30 6006421.08 4.00 4,00 · 3666.~ S 4.00 3682.LL S 4.00 3~59.20 ~ LS 1155.59 E 5576T0.26 6006356.2~ bS 1L60.58 H 557675,~8 6006340,4? IJS ~L84.88 H 55~00.25 6006263.58 ~ 3795,11 S L196,20 H 557711.8~ 6006227-~6 ~S 4.00 394L,23 S 1242.26 B 557759.00 6006082.00 ~ 0.OO 3941.23 S 1242,26 E 557959,00 6006082.00 }IS 0.00 396~.37 S 1250.50 E 557967.44 6006055.92 }iS 0,00 4003.75 S 1~6L,96 E 557779.~8 6006019.64 ~S 0,00 4021.93 S 1267-69 B 557785-04 6006001.50 HS 0.00 4074,22 S 12~4.1~ B 557~0L-9,2 6005949-35 ES 0,00 ~110.59 G 1295,64 H ,5578L3.66 6005913-07 HS O,O0 4144.69 S 1306.38 ~ 55T824.66 6005879.05 ~S 0.00 4179~92 S 1317.49 H 5578~6.03 6005843-91 ~S 0.00 42L5.16 436L,28 4361,28 t328.60 B 557847.40 6005808-T6 1374.65 B 553894.S6 600566~.01 ~374.65 5 557894.56 6005663.0L 0. O0 0.00 0.00 ANADRILL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION PLAN # -- ._;,.=~, -=._:. - . .._~--~_~: ....... "0 crt (Anadrtll (c)97 VIpHLLP5 3.0C 8:16 Aid P) SHARED' SERV I"CES DRILLING i ii i ii i i i iii · i VERTICAL SECTION VIEW i i · I ~--A " ANA)RiLL AKA D')r'- Section at: ~.62,5] ITVOScale.: ! inch = BO0 feet F:AS!31LI"Y P.AN ID.p scale.: )_- I,. ,~,~'r' A ~Dl~k/~r~ FO'~ jOrawn ..... : 30 dui ~997 I E~ ECUT$O~ ~rker I~entification ffi BKB SECI~ INCI ~~ .............. B) KOP/BU]LD !/]00 500 ~0 -0 0.( O ' . . C) BUILD 1.5/100 800 ~0 B 3.( ]-- ' ' . , ' · D) BUILD ~/~00 ~00 ~099 35 7.~ ' . E) END . F) GUILD 3/t00 1848 ~B~ ~28 2~.; )- - ' , G) END 3/]00 BUILD ~38 2971 15~2 74.~ H) ~OP 4/100 5~25 3~87 ~30 7~.'~ ..... ' '-"'-" .... ~-~ ~r []~ I) ENO 4/~00 OROP 6~48 3773 3979 50. :' ~; J) 1A~EI 6448 3901 4t3~ 50.1 }~- K] 7' CAS[N6 POINI 70~3 4271 4573 50.1 . , ~; , L] TO 70~3 427~ 4573 50.1 :1 ., ..... . , , , , ' ~~ ,, ~ .................. . , ~x ~ .......................... ~ =====~ ~- ~,~- , , . L~ · , . . . . ~ ,~ ,', ,. .,. q ....... ~'~ ...... ....... . .' ................ i...:: ................................ .. _ " _ ............. ' ' ' " O0 O0 O0 5O O0 O0 O0 O0 lc)97 NPHtlI~ 3.0C Ii:E2 ~1 P) Sect ion Departure , .. I SHARED SERVT'C~s DRILLING m i i PAGE 86 ii i ' ~ ! IVil-'F!- 1 1 I VERTICAL SECTION VIEW i. ii Section TVB Scale.' ! inch = 100 feet: ) , Dep Scale.' 1 inch = 100 Peet Drawn · 30 Jul ~997 · i /~nadri 11 $chJumberger . Marker Identifipet~on MD 8KB SECTN INCLN A) .END 4/t00 DROP 6248 3773 3979 50.00 B) T~RGET 6~a8 3901 4~32 50.00 C] 7" CASING POINT 70E3 4271 ~573 50.00 )-~ D) mD 7023 . 4275 4573 50,00 T~ 5~E~ /N~ 39[~ .0 ~ - . ~ ....... ,, '~~ ' - -. ~.,, , ....... .: ........ . · . ¢ ANADR!L[ L A~i'DpC , P~N ~-~~ -, -, . , 4000 (~aorill (c)97 I, tR-IJ{P5 3.0C 8:. 20 AH P] 4050 4:~00 4150 -4200 4250 4300 4350· 4400 4450 4500 '4550 ' 4600 4650 1700 · , ,SeFt, i,o.n' Departure , · -i. SHAREB ANADRZLL DPC ii iiii i i Marker Identification HO N/S A] KB 0 0 N 8J KOP/BUILO t/t00 §00 0 N ¢) BUILO 1.5/100 BO0 7 S DJ BUILD 2/100 ~100 34 S E) ENO 2/tO0 BUILD 178B 196 s F) BUILD 3/100 1848 2~7 S G) ENO 3/100 BUILD 3838 t442 S H) DROP 4/100 5625 3~72 S I) END 4/100 DROP 6248 3795 S J) TARGET 8448 394t S K) 7' CASING POINT 7023 4381S L] TO 7023 4361S SERVICES 62 E SB E 454 E 'to3~, E 1196 E t242 E 1375 E ~ 1375 E PAGE 87 DRZ LL Z'.N.,G :'3 i iI.i MPH-I 1 (p5) PLAN VIEW i · CLOSURE. · 4573 feet at Azimuth 162.5' DECLINATION.' +2?. 975 - (El SCALE ' 1 inch : 800 feet : DRAWN · 30 Jul 1997 mm tnadrl ]] $£h]umb£rger m ANA :)RILL -AKA4] . .....NF(EASIBILI'FY PLAN' I ' . ' )T APPR()VE[)-FO ~ -. " PLAN~":'-~'""'~_5-~' _ !'" ' . · .... (R~dius 100 feet.) -- : · _ . 2800 2400 2000 1600 1200 800 400 0 400 BO0 J200 J600 2000 2400 <- WEST ' EAST -> i i [ mm !800 DATE IN¥OIOE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET · ~u~h ~u~h~ ,~ ,., ~.~ ..................... ~,CHED CHECK IS IN PAYMEHT FOR ri'EMS ;3;:_e,z~.Qim=:rt A=~,~ · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ,-~"'-2_,.~/'?" <~ INIT CLASS WELL NAME ,/¢'///¢;'/~..../,/,~" GEOL AREA ~.~' PROGRAM: exp [] dev [] redrll [] serv'~wellbore seg LJ ann. disposal para req D UNIT# //./',,~',~ ¢/ ON/OFF SHORE ,~'"k,) ADMINISTRATION II A~_...R DATE APPR 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool ................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... REMARKS 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................... <:~ N Surface casing protects all known USDWs ........... L.~ N CMT vol adequate to circulate on conductor & surf csg ..... (~N CMT vol adequate to tie-in long string to surf csg ........ ~) N f.2/ -- CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... N Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. )~,~ ~ N If diveder required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ ) N BOPE press rating appropriate; test to ~_,.~ psig. ( ) N Choke manifold complies w/APl RP-53 (May 84) ........ ( .? N Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. GEOLOGY 31. Data presented on potential overpressure zones ....... , 32. Seismic analysis of stlallow gas zones ............. 33. Seabed condition survey (if off-shore) ............ ./// Y N 34. Contact name/phone for weeklyproQress reports ..... /.. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: JDH ~_/¢_.2 ¢-¢-..~,..- RNC Comments/Instructions: HOW/Ijt - A:\FORMS\cheklis! rev 07~97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER . ............................ ....... SCHLUF1BERGER ....... . ............................ COMPANY NAME : BP EXPLORATION WELL NAME : MP H-ii FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMiBER : 500292280200 REFERENCE NO : 98414 LIS Tape Verification Listing Schlumberger Alaska Computing Center. 21-AUG-1998 10:42 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/08/21 ORIGIN : FLIC REEL NA~E : 98414 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, MILNE POINT, MP H-ii, #50-029-22802-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/08/21 ORIGIN : FLIC TAPE NAME : 98414 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : BP EXPLORATION, MILNE POINT, MP H-ii, #50-029-22802-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MP H-ii API NUMBER: 500292280200 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 21 -AUG- 98 JOB NUMBER: 98414 LOGGING ENGINEER: DANIEL PALMER OPERATOR WITNESS: LEE HIAHfLE SURFACE LOCATION SECTION: 34 TOWNSHIP: 13N RANGE: 10E FNL: FSL: 2863 FEL: 4158 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 67. O0 DERRICK FLOOR: 67. O0 GROUND LEVEL: 37. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 7002.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 10~42 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... CET REMARKS: CONTAINED HEREIN IS THE CEM~2VT BOND LOG GR/CCL/TENS DATA ACQUIRED ON BP EXPLORATION WELL MP H-ii ON 8-8-98. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL DATA. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUF~/~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 6830.0 1065.0 CET 6870.0 1065.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASLrRED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... CET CET LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 10:42 PAGE: REMARKS: THIS FILE CONTAINS THE CLIPPED GR/CCL/TENS DATA FROM CET PASS #i. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NO?~B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189321 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CET GAPI 1189321 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CET LB 1189321 O0 000 O0 0 1 ! 1 4 68 0000000000 CCL CET V 1189321 O0 000 O0 0 ! 1 1 4 68 0000000000 ** DATA ** DEPT. 6870.000 GRCH. CET -999.250 TENS.CET 3401.000 CCL.CET DEPT. 1065.000 GRCH. CET 47.782 TENS. CET 1381.000 CCL.CET O. 010 O. 003 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 10:42 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE Sb?4FLaJ~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 6922.5 1063.0 CBT $ LOG HEADER DATA DATE LOGGED: 8-AUG-98 SOFTWARE VERSION: 8Cl-205 TIME LOGGER ON BOTTOM: 302 8-AUG-98 TD DRILLER (FT) : 6912.0 TD LOGGER (FT) : 6905.0 TOP LOG INTERVAL (FT) : 1063.0 BOTTOM LOG INTERVAL (FT) : 6900. 0 LOGGING SPEED (FPHR) : 1800. 0 DEPTH CONTROL USED (YES/NO) : NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CALIPER GR GAF~CA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER SGC-SA 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 10:42 PAGE: DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~PERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 7002.0 BRINE 8.60 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: FIRST WIRELINE RUN IN THIS WELL PRIMARY DEPTH CONTROL APPLIED. COULD NOT GET PAST 3620' ON FIRST RUN IN HOLE. ADDED ROLLERS AND WORKED TOOL DOWN TO BOTTOM. TOOLS STUCK AT 6880 PULLED 2500 LBS TO GET FREE. TOOLS RAN CENTRALIZED WITH ROLLERS AND IN-LINE CENTRALIZERS. THIS FILE CONTAINS THE RAW GR/CCL/TENS DATA FOR PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 10:42 PAGE: 6 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 1189321 O0 000 O0 0 2 1 1 4 68 0000000000 GR PS1 GAPI 1189321 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PS1 LB 1189321 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PS1 V 1189321 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 6922.500 GR.PS1 76.947 TENS. PSi 882.000 CCL.PS1 0.005 DEPT. 1063.000 GR.PS! 57.143 TENS. PSi 1379.000 CCL.PSI -999.250 ** END OF DATA ** LIS Tape Verification LisTing Schlumberger Alaska Computing Center 21-AUG-1998 10:42 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/08/21 ORIGIN : FLIC TAPE NAME : 98414 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, MILNE POINT, MP H-ii, #50- 029-22802 - 00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/08/21 ORIGIN : FLIC REEL NAME : 98414 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, MILNE POINT, MP H-ii, #50-029-22802-00 Sperry-Sun Drilling Services LIS Scan Utility Fri Aug 14 14:37:50 1998 Reel Header Service name ............. LISTPE Date ..................... 98/08/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 98/08/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER MILNE POINT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 2 AK-MM-70259 ROBERTS BURLEY ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: RECEIVED AUG 1 9 1998 Alaska Oil & G~s Cons. Commission Anchorage MPH- 11 500292280200 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 14 -AUG- 98 34 13N 010 2863 4158 .00 67.90 37.00 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 8.500 7020.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY, AND NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). 4. MWD RUNS 1-2 REPRESENT WELL MPH-11 WITH API#: 50-029-22802-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7020'MD, 4293'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTI¥ITY (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 COMPENSATRED NEUTRON POROSITY- SS MATRIX, FIXED HOLE SIZE. SBDC = SMOOTHED BULK DENSITY-COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR LOG DATA: HOLE SIZE: 8.5" MUD FILTRATE SALINITY: 500 PPM CHLORIDES MUD WEIGHT: 8.6- 9.8 PPG FORMATION WATER SALINITY: 14545 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH FCNT 4851.5 NCNT 4851.5 NPHI 4851.5 FET 4876.5 RPD 4876.5 RPM 4876.5 RPS 4876.5 RPX 4876.5 PEF 4891.0 DRHO 4891.0 RHOB 4891.0 GR 4899.0 ROP 5006.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 4851 4903 4905 4907 4943 4951 5046 5048 5052 505~ 5055 5072 5074 5094 5106 5116 5139 5154 5166 5168 5173 5175 5177 5178 5180 5181 5186 5188 5209 5218 5220 5221 5248 5257 GR 5 4850.0 5 4902.0 5 4904.0 0 4906.0 5 4941.5 0 4951.5 5 5048.5 5 5051.5 5 5054.5 0 5055.5 0 5057.5 0 5071.5 0 5072.5 0 5096.0 5 5109.5 0 5117.5 0 5139.5 5 5155.5 0 5167.5 5 5170.0 5 5173.5 0 5174.5 0 5176.0 5 5177.5 0 5179.0 5 5180.5 5 5185.5 5 5186.5 5 5212.0 5 5221.0 0 5222.0 5 5223.5 5 5247.0 5 5256.0 STOP DEPTH 6914.5 6914.5 6914.5 6940.0 6940.0 6940.0 6940.0 6940.0 6948.5 6948.5 6948.5 6959.5 7023.0 EQUIVALENT UNSHIFTED DEPTH.-- 5260.0 5261.5 5273.5 5281 0 5283 5 5285 5 5295 0 5309 5 5319 5 5323.0 5325 5 5330 5 5337 0 5339 0 5342 0 5349 5 5352 5 5357 0 5360 0 5364 0 5367 0 5370 5 5371 5 5374 0 5391 5 5398 0 5399 0 5400 5 5449.0 5451.5 5454.0 5456.0 5457.5 5462.5 5473.5 5488.5 5493.5 5494.5 5496.0 5497.0 5498.5 5500 0 5509 0 5511 5 5516 0 5519 0 5520 0 5550 0 5587 0 5589 0 5592 0 5594 5 5598 0 5607 0 5608 5 5613 5 5626 5 5628 0 5629 0 5645 0 5258.5 5259.5 5275.0 5280.0 5282.0 5285.0 5294.5 5309.0 5320.0 5322.0 5324.0 5328.0 5337.0 5338.0 5343.5 5350.5 5354.0 5356 5 5361 5 5363 5 5365 0 5368 0 5368 5 5370.5 5389.5 5397.0 5398.0 5399.0 5448 5 5451 0 5455 0 5457 0 5457 5 5462 0 5473 5 5490 0 5494 5 5496 5 5498 0 5499 0 5500 5 5502 0 5510 5 5512 5 5518 5 5521 0 5522 0 5550 0 5585 0 5588 5 5591 0 5593 0 5596 5 5606 0 5606 5 5613 0 5626 5 5627 5 5629 0 5643 5 5647. 0 5656.5 5658.5 5663. 0 5664.0 5665.5 5681 0 5683 0 5700 0 5702 0 5726 5 5729 5 5731 0 5741 0 5747 5 5749 0 5752 5 5756 0 5759 5 5767 0 5771 0 5775 5 5803 0 5812 0 5825 5 5830 0 5831 5 5893 0 5905 5 5910.0 5919 5 5924 5 5927 5 5928 5 5930 0 5932 0 5934 0 5943 5 5945 0 5949 5 5954 0 5958 5 5959 5 5964 5 5975 0 5986 5 6083 5 6101 5 6110 0 6111 5 6117 0 6132 0 6134 0 6139 5 6140 5 6143 0 6148 0 6151 0 6162 5 6166 5 5646.5 5655.5 5656.5 5661.5 5663 0 5664 5 5679 0 5682 0 5697 5 5699 5 5725 5 5729 5 5731 0 5741 0 5747.5 5750.0 5753.5 5757.0 5759.5 5766.0 5770 5 5774 0 58O2 5 5810 5 5822 5 5827 0 5828 0 5888 5 5901 0 5908 0 5916.5 5922.5 5925.5 5926.0 5927.5 5930.0 5932.5 5943.5 5944.5 5950.0 5954.0 5957.5 5960.0 5963.5 5971.5 5984.0 6083.5 6101.0 6109 5 6111 0 6114 5 6129 0 6131 5 6136 5 6138 5 6140 0 6145.5 6147.0 6159.5 6162.5 6170 6172 6177 6178 6180 6191 6195 6199 6202 6204 6205 6208 6236 6241 6248 6255 6257 6259 62 65 5 6274.0 6278 0 6279 5 6286 5 62 92 0 6297 5 6298 5 6302 5 6306 0 6348 0 6353 0 6355 5 6360 0 6365.0 6374.5 6378.5 6381.0 6382.5 6392.5 6395.0 6397.0 6401.0 6408 0 6420 5 6425 0 6426 5 6442 0 6471 0 6481 5 6486 0 6488 5 6490 5 6499 5 6506 5 6511 0 6517 5 6521 0 6527 0 6531 5 6536 0 6538 0 6166.5 6169.5 6177.0 6178.5 6180 0 6189 5 6192 5 6196 0 6200 5 6202 5 6204 5 6207 5 6235 5 6240 0 6246 0 6254 0 6256 0 6257 5 6266 0 6275 0 6276.5 6278.5 6286.0 6291.5 6296.5 6298.0 6300.5 6305.5 6345.0 6348.0 6354.5 6358.0 6365.5 6372.0 6376.0 6379.0 6380.5 6390.5 6394.5 6397.0 6400.0 6407.0 6417 5 6422 0 6424 5 6441 0 64 69 5 6481 0 6483.5 6486.0 6488.5 6496.5 6506.0 6509.5 6515.5 6518.0 6525.5 6528.5 6533.5 6535.5 6539 6541 6546 6549 6567 6573 6575 6578 658O 6597 6601 6611 6614 6630 6642 6645 6660 6664 6674 6678 6681 6693 6698 6704 6753 6754 6757 6762 6763 6765 6767 6769 6770 6780 6781 6789 6796 6797 6823 7023 .5 .5 .0 .0 0 5 5 5 5 5 0 5 0 0 5 .5 5 5 5 0 5 5 0 0 0 0 0 0 5 0 5 .0 .5 .5 .5 .5 .0 .5 .5 .0 MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 6538.0 6540.0 6544.5 6548 5 6565 5 6570 5 6573 0 6576 0 6578 0 6597 0 6599 5 6610 0 6611 5 6627 5 6640 5 6642 0 6659 0 6662.0 6669 5 6674 0 6678 5 6690 5 6694 0 6701 0 6749 0 6751 0 6753 5 6760.0 6761.5 6763.5 6765.0 6766.5 6767.5 6778.0 6779.5 6787.0 6792.0 6794.0 6820.5 7020.0 BIT RUN NO MERGE TOP MERGE BASE 2 5008.0 7020.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Bi ock sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 ROP MWD FT/H 4 1 68 RPX MWD OHM~ 4 1 68 RPS MWD OHM}4 4 1 68 RPM I~WD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CTS/ 4 1 68 FCNT MWD CTS/ 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 4851.5 7023 5937.25 4344 GR 18.6904 110.622 62.6066 4122 ROP 7.0524 531.106 147.628 4034 RPX 1.5999 2000 8.42864 4128 RPS 1.648 2000 8.82139 4128 RPM 0.4521 2000 8.78339 4128 RPD 0.251 2000 10.9714 4128 FET 0.4429 17,0408 2.15604 4128 NPHI 19.3334 81.7622 44.3013 4127 NCNT 2008 3576 2652.82 4127 FCNT 414 884.297 557.704 4127 RHOB 1.5051 2.5734 2.17008 4116 DRHO -0.095 0.3795 0.0686835 4116 PEF 1.7323 5.4889 2.59519 4116 First Reading 4851.5 4899 5006.5, 4876.5 4876.5 4876.5 4876.5 4876.5 4851.5 4851.5 4851,5 4891 4891 4891 Last Reading 7023 6959.5 7023 6940 6940 6940 6940 6940 6914.5 6914.5 6914.5 6948.5 6948.5 6948.5 First Reading For Entire File .......... 4851.5 Last Reading For Entire File ........... 7023 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT 4850.0 NCNT 4850.0 NPHI 4850.0 FET 4875.0 RPD 4875.0 RPM 4875.0 RPS 4875.0 RPX 4875 0 PEF 4889 5 DRHO 4889 5 RHOB 4889 5 GR 4897 5 ROP 5008 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 DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: STOP DEPTH 6911.5 6911.5 6911.5 6937.0 6937.0 6937.0 6937.0 6937.0 6945.5 6945.5 6945.5 6956.5 7020.0 03-SEP-97 5.06 5.46 MEMORY 7020.0 5008.0 7020.0 48.6 75.9 TOOL NUMBER P0811CRDGP6 P0811CRDGP6 P0811CRDGP6 P0811CRDGP6 8.500 8.5 SPUD / LSND 9.80 75.0 9.0 MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5OO 4.0 2.70O 2.390 2.400 3.800 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHN~ 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHM~ 4 1 68 20 6 ROP MWD 2 FT/H 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 NPHI MWD 2 P.U. 4 1 68 32 9 FCNT MWD 2 CNTS 4 1 68 36 10 NCNT MWD 2 CNTS 4 1 68 40 11 RHOB MWD 2 G/CC 4 1 68 44 12 DRHO MWD 2 G/CC 4 1 68 48 13 PEF MWD 2 BARN 4 1 68 52 14 32.8 First Name Min Max Mean Nsam Reading DEPT 4850 7020 5935 4341 4850 GR 18.6904 110.622 62.664 4119 4897.5 RPX 1.5999 2000 8.19691 4125 4875 RPS 1.648 2000 8.59773 4125 4875 R?M 0.4521 2000 8.54811 4125 4875 RPD 0.251 2000 10.1283 4125 4875 ROP 7.0524 531.106 147.718 4025 5008 FET 0.4429 17.0408 2.18274 4125 4875 NPHI 19.3334 81.7622 44.3278 4124 4850 Last Reading 7020 6956.5 6937 6937 6937 6937 7020 6937 6911.5 FCNT 414 884.297 557.483 NCNT 2008 3576 2651.84 RHOB 1.505 2.573 2.16916 DRHO -0.095 0.38 0.0688609 PEF 1.732 5.489 2.59829 4124 4850 6911.5 4124 4850 6911.5 4113 4889.5 6945.5 4113 4889.5 6945.5 4113 4889.5 6945.5 First Reading For Entire File .......... 4850 Last Reading For Entire File ........... 7020 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/08/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/08/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File