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Home My WebLink About208-031MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 10, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-221 PRUDHOE BAY UN ORIN L-221 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/10/2025 L-221 50-029-23385-00-00 208-031-0 N SPT 4106 2080310 1500 1023 2977 2830 2793 130 132 132 130 OTHER P Bob Noble 4/23/2025 2 year MIT-T as per CO 736 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN L-221 Inspection Date: Tubing OA Packer Depth 97 107 110 108IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250425151207 BBL Pumped:0.5 BBL Returned:0.5 Tuesday, June 10, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 9 9 9 9 9 ,$UHPHGLDOFHPHQW James B. Regg Digitally signed by James B. Regg Date: 2025.06.10 16:11:33 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Saturday, January 25, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-221 PRUDHOE BAY UN ORIN L-221 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/25/2025 L-221 50-029-23385-00-00 208-031-0 W SPT 4106 2080310 1500 1387 1380 1379 1381 169 173 173 174 OTHER P Bob Noble 12/2/2024 2 Year MIT-IA per CO 736 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN L-221 Inspection Date: Tubing OA Packer Depth 208 2753 2662 2627IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN241202172353 BBL Pumped:3.7 BBL Returned:2.2 Saturday, January 25, 2025 Page 1 of 1 9 9 9 9 9 9 999 99 99 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.01.25 23:09:48 -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: 1/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240107 Well API #PTD #Log Date Log Company Log Type AOGCC Eset # END 2-72 50029237810000 224016 11/16/2024 HALLIBURTON TEMP END 2-74 50029237850000 224024 12/5/2024 HALLIBURTON MFC24 END 2-74 50029237850000 224024 8/13/2024 DarkVision HADES (Down hole camera) KGSF 1A 50133101600100 220063 12/5/2024 HALLIBURTON EPX-MFC40 MPU F-13 50029225490000 195027 12/22/2024 HALLIBURTON WFL-TMD3D PU F-40 50029222150000 191117 11/9/2024 READ CaliperSurvey MPU I-04A 50029220680100 201092 11/22/2024 HALLIBURTON COILFLAG MPU J-02 50029220710000 190096 12/22/2024 READ CaliperSurvey PBU L-04 50029233190000 206120 11/23/2024 HALLIBURTON WFL-TMD3D PBU L-221 50029233850000 208031 12/11/2024 HALLIBURTON WFL-RMT3D PBU Z-ϯϰ 50029234690000 212061 12/15/2024 HALLIBURTON WFL-RMT3D PBU Z-2ϯϱ 50029237600000 223055 9/24/2024 READ InjectionProfile PBU Z-ϮϮϯ 50029237200000 222080 11/24/2024 HALLIBURTON WFL-TMD3D SCU 42-05Y 50133205700000 207082 12/7/2024 HALLIBURTON EPX-MFC24 TBU D-16RD 50733201830100 180110 12/19/2024 READ CaliperSurvey TBU D-17RD 50733201680100 181023 12/21/2024 READ CaliperSurvey Please include current contact information if different from above. T39915 T39916 T39916 T39917 T39918 T39919 T39920 T39921 T39922 T39923 T39924 T39925 T39926 T39927 T39928 T39929 PBU L-221 50029233850000 208031 12/11/2024 HALLIBURTON WFL-RMT3D Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.07 15:26:55 -09'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU L-221 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-031 50-029-23385-00-00 6050 Conductor Surface Intermediate Production Liner 4779 80 3088 6015 5451 20" 9-5/8" 7" 4338 30 - 110 29 - 3117 26 - 6041 30 - 110 29 - 2753 26 - 4772 5850 3090 5410 5772 5750 7240 5206 - 5757 3-1/2" 9.2# L-80 24 - 5794 4167 - 4558 Structural 3-1/2" HES Dual Feed Thru Packers (2) 5318, 4343 / 5536, 4398 / 5670, 4494 5117, 5318, 5459, 5536, 5670 4106, 4343, 4244, 4398, 4494 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, SCHRADER BLUFF OIL, Orion Development Area Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028239, 0028241 24 - 4585 N/A N/A 387 335 125 500 1396 1411 N/A 13b. Pools active after work:SCHRADER BLUFF OIL, Orion Development Area 3-1/2" HES Single Feed Thru Packers (3) 5117, 4106 / 5459, 4244 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations No SSSV Installed Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.07.17 11:15:07 - 08'00' Torin Roschinger (4662) By Grace Christianson at 1:34 pm, Jul 17, 2024 DSR-7/17/24 RBDMS JSB 071924 WCB 9-30-2024 ACTIVITYDATE SUMMARY 7/13/2024 T/I/O= 469/108/175 (PROFILE MODIFICATION) Pumped 50 bbls of 180* Diesel down TBG to assist SL. Job postponed. SL in control of well upon departure. FWHPs= 1860/288/182 7/13/2024 ***WELL INJECTING UPON ARRIVAL**** RAN 3-1/2" BRUSH & 2.75" G. RING TO 5,400' SLM (abort run due to leak at wlv - LRS pumped 50 bbls hot diesel) ***CONTINUE ON 7/13/24 WSR 7/14/2024 ***CONTINUED FROM 7/13/24 WSR*** (Profile modification) RAN 3-1/2" BRUSH & 2.75" G. RING TO RED SPIDER AT 5,562' MD SET 3-1/2" PX PLUG AT 5,451' MD PERFORMED SUCCESSFUL DRAWDOWN (see log) ***WELL LEFT S/I ON DEPARTURE*** Daily Report of Well Operations PBU L-221 SET 3-1/2" PX PLUG AT 5,451' MD MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 19, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-221 PRUDHOE BAY UN ORIN L-221 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/19/2023 L-221 50-029-23385-00-00 208-031-0 N SPT 4106 2080310 2500 638 2769 2589 2548 138 138 138 138 OTHER P Adam Earl 4/16/2023 MIT-T tested as per CO 736 to 2500psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN L-221 Inspection Date: Tubing OA Packer Depth 66 76 78 78IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230419193441 BBL Pumped:0.4 BBL Returned:0.5 Friday, May 19, 2023 Page 1 of 1            Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/19/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221219 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU Z-34 50029234690000 212061 12/5/2022 HALLIBURTON WFL-TMD3D PBU W-08A 50029219060100 202090 12/12/2022 HALLIBURTON WFL-TMD3D PBU_L-221 50029233850000 208031 12/13/2022 HALLIBURTON WFL-TMD3D BCU-14B 50133205390200 222057 12/8/2022 HALLIBURTON PPROF BRU 222-34 50283201860000 222039 12/11/2022 HALLIBURTON PPROF PBU 09-41 50029220540000 190074 11/30/2022 READ Multi-Array-Pprof Please include current contact information if different from above. By Meredith Guhl at 1:47 pm, Dec 19, 2022 T37385 T37386 T37387 T37388 T37389 T37390 PBU_L-221 50029233850000 208031 12/13/2022 HALLIBURTON WFL-TMD3D Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.19 13:56:07 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-221 PRUDHOE BAY UN ORIN L-221 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/26/2023 L-221 50-029-23385-00-00 208-031-0 W SPT 4106 2080310 2000 907 910 910 909 172 175 172 175 REQVAR P Austin McLeod 12/12/2022 Two year MITIA to maximum anticipated injection pressure (2000) per AIO 26B.004. 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: PRUDHOE BAY UN ORIN L-221 Inspection Date: Tubing OA Packer Depth 1530 2755 2651 2631IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM221212185915 BBL Pumped:1 BBL Returned:1 Thursday, January 26, 2023 Page 1 of 1 Two year MITIA to maximum anticipated injection pressure (2000) per AIO 26B.004.Two year MITIA to maximum anticipated injection pressure (2000) per AIO 26B.004. MEMORANDUM TO: Jim Regg� P.I. Supervisor FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 27, 2021 SUBJECT: Mechanical Integrity Tests Hdcorp North Slope, LLC 4221 PRUDHOE BAY UN ORIN 0221 Src Inspector Reviewed By: P.I. Supry � Comm Well Name PRUDHOE BAY UN ORIN L-221 API Well Number 50-029-23385-00-00 Inspector Name: Adam Earl Permit Number: 208-031-0 Inspection Date: 4202021 Insp Num: milAGE210425135253 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Lzn Type Inj N TVD 4106 - Tubing 99 2737 - 2627- 2590' PTD zoao3to Type Test I SPT Test psi 2500 - IA 63 72 73 .- 73 - BBL Pumped: 0.7 BBL Returned: 0.7 OA 93 83 83 - 83 - Interval OTHER P/F P Notes: Tested as per C.O. 736 MIT -T req. for cern ent packer squeeze. Sundry 318-119 Cd.��e�43v� Tuesday, April 27, 2021 Page 1. of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, December 31, 2020 To: Jim Re 99 �I P.I. Supervisor SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC L-221 FROM: Lou Laubenstein PRUDHOE BAY UN ORIN L-221 Petroleum Inspector Sre: Inspector Reviewed By. P.I. Supry p NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN L-221 API Well Number 50-029-23385-00-00 Inspector Name: Lou Laubenstein Permit Number: 208-031-0 Inspection Date: 12/30/2020 Insp Num' mitLOL201230120851 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-221 Type Ind W t� 4106 TUbing 1359 1359 1360 2080310 Type Test SPT Test psi 1500 IA 1014 2730 - 2635 N1360PTD BBL Pumped: T 1.3 BBL Returned: 1.3 OA 59 59 59 Interval 1 OTHER �P/F P ✓ MIT -IA for re AA evaluation, this well has a cement plug in the IA isolating from 4545 to 51 17 ft. Sundry # 318-119. Notes: p P g g ry Thursday, December 31, 2020 Page 1 of 1 Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Thursday, December 31, 2020 8:42 AM To: Oliver Sternicki Cc: Alaska NS - PB - Field Well Integrity; Rixse, Melvin G (CED) Subject: Re: [EXTERNAL] RE: L-221 (PTD# 208031 ) request for temporary water injection service For evaluation of TxlA communication. Oliver, Thanks for the call and email update. Keep the well online until the AA is finalized. Thanks Chris From: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Sent: Monday, December 28, 2020 2:13:23 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com>; Rixse, Melvin G (CED) <m a Iv i n. rixse @ a l a s ka. gov> Subject: Re: [EXTERNAL] RE: L-221 (PTD# 208031 ) request for temporary water injection service for evaluation of TxIA communication. Oliver, I will see the MIT results and so an updated AA request is not required. Thanks Chris From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Monday, December 28, 2020 1:29:07 PM To: Wallace, Chris D (CED) <chris.waIlace@alaska.gov> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com>; Rixse, Melvin G (CED) <m a Ivi n. rixse@a laska.gov> Subject: RE: [EXTERNAL] RE: L-221 (PTD# 208031 ) request for temporary water injection service for evaluation of TxIA communication. Not a problem, I'll get it set up. Assuming all goes well with the MIT -IA, do you want me to resubmit the AA with the new information? Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcoro.com Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/21/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU L-221 (PTD 208-031) TMD3D Water Flow Log 12/15/2020 Please include current contact information if different from above. PTD: 2080310 E-Set: 34458 Received by the AOGCC 12/22/2020 Abby Bell 12/23/2020 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Friday, November 20, 2020 4:47 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Aras Worthington; Oliver Sternicki Subject: UNDER EVALUATION: Injector L-221 (PTD#2080310) 45 days of PWI Mr. Wallace, Per the approval below. Injector L-221 (PTD # 2080310) will now be classified as Under Evaluation to POI and complete the monitoring and diagnostics. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Sent: Wednesday, November 18, 2020 10:26 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: L-221 (PTD# 208031 ) request for temporary water injection service for evaluation of TxIA communication. Oliver, Your request for up to 45 days water injection for monitoring and diagnostics is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Tuesday, November 17, 2020 3:45 PM To: Wallace, Chris D (CED) <chris.wa[lace @alaska.gov> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com>; Rixse, Melvin G (CED) Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Wednesday, November 18, 2020 10:26 AM To: Oliver Sternicki . Cc: Alaska NS - PB - Field Well Integrity; Rixse, Melvin G (CED) Subject: RE: L-221 PTD# 208031 ) request for temporary water injection service for evaluation of xIA communicatio_ n Oliver, Your request for up to 45 days water injection for monitoring and diagnostics is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Tuesday, November 17, 2020 3:45 PM To: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: L-221 (PTD# 208031 ) request for temporary water injection service for evaluation of TxIA communication. Chris, Well L-221 (PTD# 208031) is a currently a Not Operable WAG injector. Here is the recent history: 7/29/16 Failed MIT -IA, LLR= 0.25 BPM. 8/22/16 LDL Identified a packer leak @5117'. 12/31/18 Placed 572' of cement in IA repairing packer leak at 5117' MD. Sundry #318-119. 4/17/19 SCMT logged IA TOC= 4545' MD. 4/19/19 AOGCC Witnessed MIT -T passed to 2480 psi. 5/11/19 Placed on water Injection under eval. 5/13/19 AOGCC Witnessed MIT -IA passed to 3127 psi. 6/8/19 Not operable due to IA repressurization (130 psi/day) on water injection . We request permission to place L-221 on PWI for a 45 day under eval period to complete the water flow log required under C0736 and evaluate the IA repressurization to determine if an administrative approval request would be considered for continued operation of the well on PWI only. Annulus pressures will be maintained below 2100, 1000 psi (IA, OA). Expected PWI pressure should be -1500 psi. Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 i sJ� TRANSMITTAL DATE TRANSMITTAL# SERVICE ORDER SERVICE COLOR WELL NAME API # # FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED PRINTS CDs A Transmittal Receipt signature confirms that a package (box, Qnvelope, etc.) has been received and the contents of the have been verified to match the media noted above. The Print Name/ Signature " `-� Date specific content of the CDs and/or hardcopy prints may or may U not have been verified for correctness or quality level at this. Please return via courier or sign/scan and email a copy t oth Schlumberger and BP point. Schlumberger -Private STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Failed Pkr Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number 208-031 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 0 1 8. API Number. 50-029-23385-00-00 7. Property Designation (Lease Number): ADL 028239 & 028241 8. Well Name and Number PBU L-221 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, SCHRADER BLUF OIL RECEW 11. Present Well Condition Summary: Total Depth: measured 6050 P feet Plugs measured 5772 reel JUN 28 201c true vertical 4779 feet Junk measured 5850 feet ti Effective Depth: measured 5772 feet Packer measured See Attachment feet a true vertical 4569 feet Packer true vertical See Attachment feet AOGC Casing: Length. Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 31 -109 30-109 1533 515 Surface 3087 9-5/8" 30-3117 30-2753 5750 3090 Intermediate Production 6013 7" 27-6041 27-4772 7240 5410 Liner Perforation Depth: Measured depth. 5206-5757 feel True vertical depth: 4187-4558 feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# L-80 25-5794 25-4585 Packers and SSSV (type, measured and See Attachment See Attachment See Attachment true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: RIH with coil to 5072'and pump 14 bbls of 15.8# cement into IA while taking returns to surface. Underdisplace by 0.6 bble and POOH while pumping pipe displacement. TOC per SCMT (4/19/2019) = 4545'. Intervals treated (measured): 4545' - 5079' Treatment descriptions including volumes used and final pressure: 14 bbls of 15.8# cement. Final Pressures: OA = 0 psi, IA = 450 psi, TBG = 500 psi 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut In 400 0 Subsequent to operation: Shut In 450 500 14. Attachments: (Mgmre° per20 MC 25070.25.071, s 25283) 15, Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ I GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-119 Authorized Name: Hibbert, Michael Contact Name: Hibbert, Michael Authorized Title: Well Interventions Engin Contact Email: Michael.HibbertcMBP.wm t Authorized Signature: Date: ciContact Phone* +1 907 564 4351 Form 10-404 Revised 04/2017 ,�Pj Mi,AdGIQ RBDMSA/JUL 0 12919 Submit Original Only ED r 0 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) June 28, 2019 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Repair Well (Packer Squeeze), covered under Approved Sundry #318-119 for Well PBU L-221, PTD #208- 031. The scope of this Sundry Approval was not completed due to the following After the well was brought online and appeared to exhibit IA repressurization it was determined that the packer repair was a failure. With the well no longer on track to be an operable injector we also determined that there was no benefit in proceeding with the Water Flow Log as required by the 10-403 conditions. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Packers and SSV's Attachment PBU L-221 SW Name Type MD TVD De scri tion L-221 TBG PACKER 5117 4106 3-1/2" HES Dual Feed Packer L-221 TBG PACKER 5318 4244 3-1/2" HES Single Feed Packer L-221 TBG PACKER 5459 4343 3-1/2" HES Dual Feed Packer L-221 TBG PACKER 5536 4397 3-1/2" HES Single Feed Packer L-221 TBG PACKER 5670 4494 3-1/2" HES Single Feed Packer Daily Report of Well Operations PBU L-221 ACTIVITYnATF RI IMMARY 'WELL S/I ON ARRIVAL*** (Cement squeeze) EQUALIZE & PULL COMPLETE 3-1/2" WFD WRP FROM 5,124' SLM / 5,139' MD. BAIL -3-1/2 GALLONS OF SCHMOO FROM 5,702' TO 5,750' SLM (Station #1 now clear). PULL RK -P15 WFR FROM ST #2 & SET RK-DGLV AT ST #2 (5,641' MD). PULL RK -P15 WFR FROM ST #4 (5,516' MD). 10/27/2018 ***JOB IN PROGRESS, CONTINUED ON 10/28/18 WSR*** ***CONTINUED FROM 10/27/18 WSR*** (Cement squeeze) SET RK-DGLV AT ST #4 (5,516' MD). PULL RK -P15 WFR FROM ST #6 & SET RK-DGLV AT ST #6 (5,438' MD). PULL RK-P15XJR FROM ST #1 & SET RK-DGLV AT ST #1 (5,722' MD). PULL RK -P15 WFR FROM ST #8 & SET RK-DGLV AT ST #8 (5,236' MD). LRS ATTEMPTED PRESSURE TEST ON TUBING (IA not tracking, Valve out below top zone). BAIL -2-1/2 GALLONS OF SCHMOO FROM 5,729' SLM TO 5,749' SLM. FISH RK-DGLV THAT POPPED OUT OF ST #1 FROM 5,749' SLM. SET RK-DGLV AT ST #1 (5,722' MD). LRS PERFORMED SUCCESSFUL PRESSURE TEST TO 1845 PSI. PULL RK-DGLV FROM ST #10 (5,068' MD). MADE 1 ATTEMPT TO SET RK-RWF-B AT ST #10. 10/28/2018 ***JOB IN PROGRESS, CONTINUED ON 10/29/18 WSR*** ***CONTINUED FROM 10/28/18 WSR*" (Cement squeeze) SET RK-RWF-B (Modified w/ no seat size for cement squeeze) AT ST #10 (5,068' MD). BAIL -2-1/2 UALLUNS OF SCHMOO OFF OF PRMG. PULL P -PRONG FROM 3-1/2" PXN PLUG BODY @ 5,772' MD CLEAN TBG TO 3-1/2" PXN PLUG BODY @ 5,772' MD W/ 2.80" GAUGE RING BAIL -2 GALLONS OF SCHMOO FROM 3-1/2" PXN PLUG BODY @ 5,772' MD PULL 3-1/2" PXN-PLUG BODY FROM 5,758' SLM / 5,772' MD (All intact) TAG STICKY BOTTOM @ 5,806' SLM / 5,820' MD W/ 2.70" GAUGE RING. ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*'* 10/29/2018 DRIFT TO 2,800' SLM W/ 2.70" x 20' DUMMY WHIPSTOCK FOR SUBSIDENCE SURVEILLANCE. ***WELL S/I ON ARRIVAL''* (SLB ELINE SET CBP) INITIAL T/I/O = 450/450/0. MIRU & PT. RUN 1: SET 3.5" WFD CBP AT 5080' MID -ELEMENT. TOP OF PLUG AT 5079'. ALL LOGS CORRELATED TO SLB CORRELATION LOG DATED 08 -APRIL -2009 RDMO. WELL LEFT S/I ON DEPARTURE. FINAL TWO = 240/450/0. 11/16/2018 ***JOB COMPLETE ON 16-NOV-2018*** ***Job Cont from 11-16-2018 WSR*** LLR on Tbg and IA. Figured all LLR from Timing my tank levels. Pumped 18 bbls ambient DSL down Tbg and I to establish LLRs.. Got a LLR of -.5 bpm @ 1490 down Tbg Got a LLR of -.6 bpm @ 1490 down IA Got a LLR of -.75 bpm @ 1480 down Tbg and IA at the same time. DSO notified of well status per LRS departure. FWHP's=750/750/10 SV,WV,SSV=C MV=O IA,OA=OTG 11/17/2018 **Tags hung on IA and Master CTU#8 - 1.75" coil -- Job Objective: Packer Squeeze RIH with ball drop nozzle and tag CBP. Cement valve failed on SLB cement unit allowing more than required water to enter cement tub. Extra water diluted cement and unable to reach 15.8 ppg cement. Suspend job until more cement arrives location. 12/30/2018 **In Progress" CTU#8 - 1.75" coil -- Job Objective: Packer Squeeze Continue to standby for new cement blend. Cement arrives location. RIH with coil to 5072' and pump 14 bbls of 15.8# cement into IA while taking returns to surface. TOC in IA = 4608'. Underdisplace by 0.6 bbls and POOH while pumping pipe displacement. Pump 10 bbls powervis through coil with 1-1/8" ball to drift coil and jet across BOPs. WOC 12/31/2018 **In progress" Daily Report of Well Operations PBU L-221 CTU#8 - 1.75" coil -- Job Objective: Packer Squeeze Continue to WOC. MIT-IA to 1600 psi. RIH with 2.80" string mill / 2.80" junk mill. Mill through cement in tubing and tag CBP at 5071' ctmd. Mill CBP and push to XN nipple at 5764' ctmd. POOH. Remove 2.80" string mill/junk mill and MU 2.70" junk mill. RIH and push CBP to 5,850' ctmd. Freeze protect with diesel to 2500' md. 1/1/2019 **Complete** ***WELL S/I ON ARRIVAL***(Cement Squeeze) LRS PERFORMED FAILING MIT-IAs. LLR OF 0.014 BPM 1/7/2019 ***CONT ON 1-8-19 WSR*** ***CONT FROM 1-7-19 WSR***(Cement Squeeze) BRUSHED TBG W/ 3-1/2" BRUSH & 2.80" GAUGE RING TO XN-NIPPLE @ 5772' MD. LRS LOADED TBG W/ 58 BBLS OF CRUDE. SET 3-1/2" X-SELECTIVE TEST TOOL IN X-NIPPLE @ 5096' MD. LRS PERFORMED TWO FAILING PRESSURE TESTS TO 2500psi. SET 3-1/2" X-SELECTIVE TEST TOOL IN SVLN @ 2721' MD. LRS PERFORMED PASSING PRESSURE TEST TO 2500psi. SET 3-1/2" XXN PLUG IN XN-NIPPLE @ 5772' MD. LRS PERFORMS FAILING CMIT TxIA TO 2500#. 1/8/2019 ***CONT ON 1-9-19 WSR*'* TWO = 1160/590/30. Temp = SI. MIT-IA (PASSED), MIT-T (FAILED). (Post packer squeeze). TBG FL @ 1192', (10.5 bbl), IA FL @ Surface. 3rd test MIT-IA lost 25 psi in the first 15 minutes, IA lost 17 psi in the second 15 minutes for a total loss of 42 psi in 30 minutes (PASSED MIT-IA). Bled IAP from 3959 psi to 580 psi in 5 minutes (2.1 bbl of returns). Swap rig up to MIT-T. Bled TP from 1510 to 340 psi, fluid to surface. 2nd MIT-T TP lost 249 psi in the fiorst 15 minutes, lost 191 in the second 15 minutes for a total loss of 440 psi (FAIL). Bled TP down to 400 psi, ( 2.1 bbl of returns). Bled IAP from 860 psi to 410 psi, (.56 bbl of returns. Final WHP's = 400/410/30. SV, WV, SSV = C MV = O. IA, OA = OTG. 17:15 1/2012019 T/I/O = 430/460/20. Temp = SI. MIT-IA PASSED to 3718 psi (post PKR squeeze). Max applied = 4000 psi, target = 3700 psi. T FL @ near surface. IA FL @ surface. Bled TP from 430 psi to 290 psi in 2 min (FTS). Bled TP again from 290 psi to 200 psi in 15 min (0.5 bbl), unable to bleed below 200 psi. Used 1.6 bbls of diesel to pressure IAP to 4000 psi. Monitored for 1 hr. IAP lost 184 psi in the 1st 15 min, 50 psi in the 2nd 15 min, 28 psi in the 3rd 15 min, and 20 psi in the 4th 15 min, for a total loss of 282 psi in 1 hr. Bled IAP from 3718 psi to 500 psi (1 bbl). Tags hung. Final WHPs = 300/500/20. 1/29/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 18:00 **'WELL S/I ON ARRIVAL***(Cement squeeze) RIG UP SWCP 4522 4/16/2019 '**CONT ON 4-17-19 WSR*** ***CONT FROM 4-16-19 WSR***(Cement squeeze) DRIFTED TO 5200' SLM WITH 2.25" CENT & 33' OF 1.75" BAILER DRIFT. RAN SLB SCMT LOG FROM 3450' SLM - 5100' SLM. ood data DRIFTED TBG W/ 20'x 2.70" DUMMY WHIPSTOCK DRIFT TO 5200' SLM.(no issues) ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** ***DRIFT TO 5200' SLM W/ 2.70" x 20' DUMMY WHIPSTOCK FOR SUBSIDENCE 4/17/2019SURVEILLANCE'*' "*WELL S/I ON ARRIVAL*** RUN 3 1/2" X-LINE TO X NIPPLE FOR TIE IN RUN. LOCATED X-NIPPLE AT 5079' SLM + 17' _ 5096' MD. 4/18/2019 ***CONT ON 4-19-19 WSR*** Daily Report of Well Operations PBU L-221 ***CONT FROM 4-18-19 WSR***(Cement Squeeze) SET 3 1/2" WFD WRP AT 5124' MD. LRS PERFORMED PASSING MIT -T TO 2500psi.(aogcc witnessed Jeff Jones) PULLED 3-1/2" WFD WRP FROM 5124' MD. EQUALIZED & PULLED 3-1/2" XXN PLUG FROM XN-NIPPLE @ 5772' MD.(chunks of cement inside plug) BRUSHED TBG W/ 3-1/2" BRUSH & 2.50" GAUGE RING TO 5780' SLM. LRS PUMPED 10 BBLS OF CRUDE DOWN TBG FOR BRUSH RUN. SET 3-1/2" XN-LOCK W/ RMX SUB IN XN-NIPPLE @ 5772' MD. VERIFIED WITH CHECK SET. SET RMX DMY-PRONG IN BODY AT 5772' MD. 4/19/2019 ***CONT ON 4-0-19 WSR*** ***CONT FROM 4-19-19 WSR***(Cement squeeze) SET 3 1/2" WCS ON RMX PLUG AT 5772' MD. MADE TWO ATTEMPTS TO PULL RK-DGLV FROM ST#4 @ 5516' MD. RAN 1.70" LIB TO ST#4 @ 5516' MD.(debris around latch) PULLED RK-DGLV FROM ST#4 @ 5516' MD.(latch damaged) RAN 1.5" POCKET BRUSH TO ST#4 @ 5516' MD.(tt pins sheared, ring on no-go) LRS ATTEMPT OPEN POCKET RATE TEST ON ST#4, ESTABLISHED RATE OF .005 BPM. SET RK-DGLV IN ST#4 @ 5516' MD. PULLED RK-DGLV FROM ST#5 @ 5485' MD. SET 12/64" 190 BWPD IN STA #5- FAILED SRT. PULLED VALVE BACK OUT. 4/20/2019 ***CONT ON 4-21-19 WSR*** ***CONT FROM 4-20-19 WSR***(Cement squeeze) SET RK-P15.XJR(12/64", 190bwpd) IN ST#5 @ 5485' MD. LRS PERFORMED PASSING STEP RATE TEST ON ST#5. PULLED RK-DGLV FROM ST#6 @ 5438' MD. SET RK-P15.XJR(12/64", 190bwpd) IN ST#6 @ 5438' MD. LRS PERFORMED PASSING STEP RATE TEST ON ST#5 & ST#6. PULLED RK-DGLV FROM ST#8 @ 5236' MD. SET RK-P15.XJR(1 2/64",190bwpd) IN ST#8 @ 5236' MD. LRS PERFORMED PASSING STEP RATE TEST ON ST#5, ST#6 & ST#8. PULLED 3-1/2" WHIDDON CATCHER SUB FROM 5742' SLM.(empty) 4/21/2019 ***WELL S/I ON DEPARTURE, PAD -OP NOTIFIED OF WELL STATUS*** T/I/O = 519/460/27. Temp = SI. AOGCC MIT -IA PASSED to 3769 psi (Witnessed by Jeff Jones). Max pressure= 4000 psi. Target pressure= 3700 psi. IA FL @ near surface. Bled IAP from 460 psi to 70 psi in 1 min. Used 2.7 bbls of Diesel to pressure IAP to 4000 psi. IAP lost 183 psi in the 1st 15 min, 48 psi in the 2nd 15 min fora total loss of 231 psi in 30 min. Bled IAP from 3769 psi to 80 psi in 15 min, returned 2.6 bbls. Tags hung. Final WHIPS = 520/230/30. 5/10/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 11:30 T/I/O = 1347/729/37. Temp = 132*. AOGCC MIT -IA PASSED to 3127 psi. (Witnessed by Jeff Jones) On PWI. Max PSI = 3300 psi . Target = 3000 psi. IA FL @ surface. Used 1.75 bbls to pressure IAP to 3300 psi. IAP lost 149 psi in 1st 15 min, lost 24 psi in 2nd 15 min, for a total of 173 psi in 30 min. Bled IAP from psi to 3127 psi in 10 min, returned 1.75 bbls. Continued to bleed IAP to 500 psi, returned 0.75 bbls. Tags hung. WHPs = 1347/490/37. 5/13/2019 JSV = C. WV, SSV, MV = O. IA, OA = OTG. 12:00 4-1/16" CNV WELLHEAD = FIX ACRJATOR= GLEO KB. ELEV = 77.4' BF. ELEV = 51.51' KOP= 300' Max Angle = 53- @N80 - Dad/m MD= 564T Datum TVD = 4400'. SS I VA CMT SOZ TOC (01)01/19)(SCMT 04/17/191 I 17"X3-12"IESDUALFEOTHRJPKR,D=2.965" -t 511T Minimum ID (L-221) = 2.75" @ 5772' 3-1/2" HES XN NIPPLE 7' MARKER JOINT w/PA PP TAG GIST 3-12' RA PP TAG 5245' T X 3-12" HES SINGLE FEEIYDRU Fi07. D = 2.965" SAFETY NOTES: H2S READINGS AVERAGE 125 ppm L�� WHEN ON MI. WELL REQUIRES A SSSV WHEN ON ` ML — HES PKR @ 6117' IS "PULL TO RELEASE- BUT CAN ALSO HE RELEASED BY PRESS. DO NOT IXC® 2000 PSI ON THEM wIOUT PE FORiMING TBG MOVEMENT CALCS & DISCUSSING w/ APE— GAS LIFT MANDRELS ST1 MD 1 ND 1 DEV TYPE I VLV I LATCH PORI DATE 1161566aI40731 47 ji MUG IRWF--E4 RK 1 0 10/29/18 3-1/2" NDPG MULhSBJSOR SUB, D = WATPR rA1FGmM UAMnp i a ST MD TVD I DEVI TYPE VLV LATCH PORT DATE 9 5143 4124 47 MMG4V DMY RK 0 04/07)08 8 5236 4187 47 MMIiW P-15XJR RK 12 0421M9 7 5344 4263 46 MMGW DMY RK 0 04107)08 6 5438 4328 45 MMG4N P-15XJR RK 12 0421119 5 5485 4362 45 MMG-W P-15XJR RK 12 0421119 4 5516 4384 45 IIM041F DMY RK 0 0421/19 3 5570 4422 44 MMGJW DMV RK 0 04107108 2 5641 4473 44 MMGFW DMY RK 0 1029118 1 5722 4532 43 MNW&W DMY RK 0 I 1029118 DATE REV BY COMMENTS DATE REV BY COMMENTS N 6331' 1-j3-1/2" NDPG MULTI SR4SOR SUB, D=2.992 01/07/19 Mf/JMD W CMT SQZ, MILL CBP, FISH 09/05/08 JMPJC DRAWING CORRECTIONS 01/10/19 6461' 3-12'HES X NP, D=2.813' �� 7" X 3-12" HES DUAL F®iFRU PKR, D= 2.965" L.� 0422/19 h"JMD« A TOC PER 4/17/19 SCMT 11/12118 GJB/JMD WFR Cl0 (1029118) 0422/19 RCB/JM> RMX SET/GLVS CJO (0422/19) 11/12(18 JMG(JMD RA-LEDPLLIGS(1029/18) 05/09/19 DO/JMD CF1ANGE02SNG1-EPKRSTOD1 6473' H 3-1/2" NDPG MULT4SENSOR SUB, D = 2.992 6638' 7- X 3-12" SINGLE F®THRU PKR, D = 2.985" PERFORATION SLAWRY W\ 6649' 3-12' NDPG MULTLSf3JSOR SUB, D=2.992 REF LOG: USfT LOG ON 04/07/08 ANGLE AT TOP FERF: 47°@5024' 666Y 3-12"HESX NP, 0=2.813" Note: Refer to Production DB for t storical pert data SIZE SPF ZONE KrERVAL OprdSgz DATE 4-12" 5 Nb 5206-5228 O 04/06/08 6670' 7" X 3-12" SNGLE FEEDTHRU FKR, D = 2-905- 4-10 5 OA 5396- 5448 O 04/06!08 4-12" 5 OBa 5487- 5530 O 04/06/08 6683' 3-1/2" NDPG MULTI -SENSOR SUB , D = 2.992 4-12" 5 OBb 5548-5568 O 04/06/08 4-12" 5 OBc 5622- 5649 O 04/06/08 6701' 3-12" HES X NP, D = 2.813" 412" 5 OBd 5692-5757 O 04/06/08 6751' 3-12" HES X NP, D = 2.813" 6772' 3-12" HES XN NP, ID 5772' 3-12"RMX w/DMY PRONIG(04MW19) 3-12" TBG, 9.2#, L-80 TCR .0087 bpf, D = 2.992" 5794' 6784' 3-12'WLEG,9)=2.992" PBTD 6966, � ELMD NOT LOGGED 6860' CMT FISFL MILLED & PUSHED CBP (01/01/19) 7' CSG, 2810, L-80 BTGM, .0383 bpf, D = 6.278' 6041' DATE REV BY COMMENTS DATE REV BY COMMENTS 04109108 N9ES ORIGINAL COMPLETION 01/07/19 Mf/JMD W CMT SQZ, MILL CBP, FISH 09/05/08 JMPJC DRAWING CORRECTIONS 01/10/19 MTI4JM) SEFXXNPLUG(01/08/19) 0125/18 EZ/JMD ADDED SPRING Wf3GF f TO WR 0422/19 h"JMD« A TOC PER 4/17/19 SCMT 11/12118 GJB/JMD WFR Cl0 (1029118) 0422/19 RCB/JM> RMX SET/GLVS CJO (0422/19) 11/12(18 JMG(JMD RA-LEDPLLIGS(1029/18) 05/09/19 DO/JMD CF1ANGE02SNG1-EPKRSTOD1 1123/18 KFWJMD SETWFDCBP(11/16118) ORION UN FT WELL: L-221 PERMT No: '2080310 AH No: 50-029-23385-M 1-121% RI I E, 2404' FSL & 166X FAL BP Exploration (Alaska) Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, June 8, 2019 3:31 PM To: AK, GWO Well Integrity Engineer; AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PGC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad LV; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Duong, Lea; Nottingham, Derek; Youngmun, Alex, Wallace, Chris D (CED) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis 1; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (CED); AK, GWO Well Integrity Well Information Subject: NOT OPERABLE: Injector L-221 (PTD #2080310) Slow IA repressurization after IA cement squeeze All, Injector L-221 (PTD #2080310) was made under evaluation on 5/11/2019 following a remedial IA cement squeeze. The well was put on injection 5/11/2019 and has required multiple inner annulus bleeds to maintain pressure below 1,700psi. After a review of the real-time TIO data it has been confirmed that the well is exhibiting slow IA repressurization. At this time the well is reclassified as Not Operable and the planned water flow log is canceled. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: AK, Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Saturday, Ma -M 2019 7:33 AM To: AK, OPS EOC Specia <AKOPSGC2 !cialists@bp.com>; Ak, OPS GC2 Facility PTL GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 ad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Con ers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWeliPadDFTN2@bp.com>; AK, OPS Well Pad LV < SWeIIPadLV@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr ESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProd L <AKOPSPCCEOCTL@bp.com>; Duong, Lea <Lea.Duong@bp.com>; Nottingham, Derek <Derek.Nottingham @bp.com>; You n, Alex <younak@BP.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DH ell Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWelllntegrityEn er@b MEMORANDUM State of Alaska Alaska Oil and Cas Conservation Commission TO: Jim Regg2 DATE: Monday, June 10, 2019 P.I. Supervisor `�s �ZIC i SUBJECT: Mechanical Integrity Tests (l BP EXPLORATION (ALASKA) INC. L-221 FROM: Jeff Jones PRUDHOE BAY UN ORIN L-221 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Suprvjgz— NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORM L-221 API Well Number 50-029-23385-00-00 Inspector Name: Jeff Jones Permit Number: 208-031-0 Inspection Date: 5/13/2019 - InspNum: miUJ190531100722 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min zoso3lo" - ITypeTest 'TVD aloe Tubing 347 49 so ur L221 T eIn' W'TVD �- 3000 IA 729 3300 3151 e PTD '� BBL Pumped: is 1.7 - IBBL Returned: -1.7 - OA 37 3a -38 s Interval OTHER P/F P Notes: Sundry 318-119; post IA cement squeeze repair MIT -IA. I well inspected, no exceptions noted. Monday, June 10, 2019 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 10, 2019 TO: Jim Regg /�p� q 6lIZ,II P.1. Supervisor 1>'Y� SUBJECT: Mechanical Integrity Tests ll BP EXPLORATION (ALASKA) INC. L-221 FROM: Jeff Jones PRUDHOE BAY UN ORIN L-221 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN L-221 API Well Number 50-029-23385-00-00 Inspector Name: Jeff Jones Permit Number: 208-031-0 Inspection Date: 5/102019, Insp Num: mitIJ190531092922 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 NIm 60 Min Well L-221Type Inj N 'TVD 4106 - ITUbing 519 530. 527 - 5'5 PTD 2080310 Type Test SPT Test psi 3700 IA 7s 4000 ' 3a17 1 3769 BBL Pumped: 2.7 BBL Returned: OA n 28 28 a �- - - -� ± Interval l OTHER P/F P /I Notes: Sundry 318-119; pre-injection MIT -!A to 3700 psig, packer cement squeeze repair. 1 well inspected, no exceptions noted. Monday, June 10, 2019 Page I of I P -b 2Z603(c) Regg, James B (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, May 8, 2019 4:27 PM !7.,• 6 f l G To: Regg, James B (DOA); AK, GWO Projects Well Integrity ((��LL��(9G 1 I Cc: AK, GWO SUPT Well Integrity; Brooks, Phoebe L (DOA); Loepp, Victoria T (DOA) Subject: RE: BPXA April 2019 MIT Forms Mr. Regg, There was some early confusion around the CO 736 requirements for pressure testing and it was assumed that this well needed a witnessed MIT -T. The well is currently Not Operable and an AOGCC witnessed MIT -IA to 3,700psi is in the scheduled plan forward. Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 From: Regg, James B (DOA) <jim.regg@alaska.gov> Sent: Wednesday, May 8, 2019 3:49 PM To: AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com> Cc: AK, GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@bp.com>; AK, GWO <AKGWOWeliSiteEnginee@bp.com>; Brooks, Phoebe L (DOA) <phoebe.brooks@alaske <victoria.loepp@ a la ska.gov> / Subject: RE: BPXA April 2019 MIT Forms Also, the required test was 3700psi; actual test had initial pressure of also explain this. Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 itegrity Engineer Loepp, Victoria T (DOA) and ending pressure of 2436 psi. Please CONFIDENTIALITY NOTICE: This e-mail message, includin any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sol use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such i9rormation may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding' , and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.reggPalaska.zov. Regg, James B (DOA) From: Regg, James B (DOA) I Sent: Wednesday, May 8, 2019 3:49 PM 1 I To: AK, GWO Projects Well Integrity Cc: AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Engineer; Brooks, Phoebe L (DOA); Loepp, Victoria T (DOA) Subject: RE: BPXA April 2019 MIT Forms Also, the required test was 3700psi; actual test had initial pressure of 2740 psi and ending pressure of 2436 psi. Please also explain this. Jim Regg Supervisor, Inspections AOGCC 333 W.Th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.reggOalaska.gov. From: Regg, James B (DOA) Sent: Wednesday, May 8, 2019 3:44 PM To: AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com> Cc: AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com>; Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: BPXA April 2019 MIT Forms PBU L-221; PTD 2080310; Sundry 319-119 Please explain why there was an MIT -T done (post cement squeeze) instead of an MIT -IA as indicated in the approved sundry work procedure. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.reggCdalaska.gov. From: AK, GWO Projects Well Integrity<AKDCProiectsWelllntegrityEngineer@bp.com> Sent: Saturday, May 4, 2019 6:41 AM To: Regg, James B (DOA) <iim.regg@alaska.gov>; Wallace, Chris D (DOA) <chris.waIlace @alaska.gov>; Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov> Cc: AK, GWO SUPT Well Integrity<AKDCWelllntegritVCoordinator@bp.com>; AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com>; AK, GWO Projects Well Integrity<AKDCProiectsWelllntegrityEngineer@bp.com> Subject: BPXA April 2019 MIT Forms MA Attached are the completed AOGCC MIT forms for tests performed by BP in April of 2019. Well: PTD: Notes: 01-05B 2070480 MIT -T per Sundry 319-036 for P&A 04-01A 2070350 CMIT-TxIA per Sudry 319-009 for P&A 04-05A 1931860 CMIT-TxIA per Sundry 319-023 for P&A 04-28 1852800 MIT -T & IA post TxIA communication repair 16-14C 2181170 Post Rig MIT -IA to 4000 psi A -27A 1982350 4 year test L-221 2080310 MIT -T post packer squeeze for Sundry 318-199 NGI-04 1750690 2 year test, AA 4E.024 P1-21 1930590 2 year test, AA 4G.005 P2-28 1950440 4 year test 132-46 1931320 4 year test 5-09 2140970 4 year test V-217 2061620 4 year test Y -10B 2120210 4 year test to trouble shoot IA repressurization Z -19A 2061050 2 year test, AA 38.006 Thank you, tek 106 ae BP Well Integrity Office: 907-659-5297 Harmony -2468 ;lhcrnate- Rcen 41a,e, Gy� g G,inb;11'NVS Z! �P Oraarnzaopr Submit to "m reaoliptalaska.pov'. OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test AOGCCInsoectors0alaskaoov: phoebebreoks(Malaskaoov BP Exploration (Alaska) Inc Prudhoe Bay I GPB I L chla WallaaeAalaska oov i Veit Well L-221 INTERVAL Cutler Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4=Four Year Cycle F=Fall PTD 2080310 Type Inj N Tubing 522 2740 2544 1 2480 1 2436 Type Test P Packer ND 4106 BBL Pit 0.7 IA 11 23 27 29 31 Interval 0 Test psi 1500 BBL Re Ium 0.5 OA 16 16 16 ifi 18 Rasull P Nates: Sundry 3l for packer squese.MIT-T post squeeee Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 50 Min. PTD Type Inj Tubing Type Test Packer ND BELL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer ND BBLPump IA Interval Inteal Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min, 30 Min, 45 Min. 60 Min. PTD Type Int Tubing Type Test Packer ND BBLPump IA Interval Test psi BBL Return OA Result Nates: Well Pressures'. Pretest Initial 16 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Purr IA Interval Test psi BBL Return OA Result Notes: WeII Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBLPump IAInterval Test psi BBL ReturnOA Result Notes: Well Pressures: Pretest Initial 15 Min. W Min. 45 Min. W Min. PTD Type lnj Tubing Type Test Packer ND BBLPump IA Interval Test psi BBL Return OA Result Notes: Well I Pressures: Pretest Initial 15 Min. W Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Pecker ND BSL Pull IA Interval Test psi BBL Return OA Result Nobs: TYPE INN Coies TYPE TEST Louses INTERVAL Cutler Result Co.- W=WMer P=Pressure Test 1=lreial Ton P=Pa. G=Gas 0= Other (dra eIn Notes) 4=Four Year Cycle F=Fall 5=alio" V= Re,wred by Variance 1=Inconclusive 1=1n0uAeel Wnuh—ale' G= other(tlessitaln notes) N=Not lai Form 10426 (ReVIseE 0112017) MIT Pau L-22104.19.19 .Yum Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, May 11, 2019 7:33 AM To: AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad LV; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Duong, Lea; Nottingham, Derek, Youngmun, Alex; Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity, AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (DOA) Subject: UNDER EVALUATION: Injector L-221 (PTD #2080310) Well barriers restored with IA cement squeeze, MITs passed All, Injector L-221 (PTD #2080310) was made not operable on 8/23/2016 for having a confirmed production packer leak at 5,117'. On 1/1/2019 service coil performed a remedial IA cement squeeze under sundry #318-119 and the well passed a subsequent AOGCC witnessed MIT -T to 2,480psi on 4/19/2019 and MIT -IA to 3,769psi on 5/10/2019. At this time the well is being reclassified as Under Evaluation so that it can be put on injection for a waterflow log. Plan Forward / Completed Steps: 1. Coil Tubing — Cement squeeze — Done 1/1/2019 2. Slickline — SCMT— Done 4/17/2019 3. Fullbore —AOGCC MIT-T—Passed to 2,480psi 4/19/2019 4. DHD—AOGCC MIT -IA — Passed to 3,769psi 5/10/2019 5. E -Line — Water Flow Log 6. Well Integrity Engineer— Reclassify pending WFL results Please reply if in conflict, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg ��l�)///%�� / DATE: Tuesday, April 30, 2019 � /1 SUBJECT: Mechanical Integrity Tests P.I. Supervisor yCr tL `G BP EXPLORATION (ALASKA) INC. L-221 FROM: Jeff Jones PRUDHOE BAY UN ORIN L-221 Petroleum Inspector Sre: Inspector Reviewed By: �� P.I. Supry —IVP— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN L-221 API Well Number 50-029-23385-00-00 Inspector Name: Jeff Jones Permit Number: 208-031-0 Inspection Date: 4/19/2019 Insp Num: mitJJ190424103152 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min WellL-zzl TType Inj� N"'TVD 410e 'Tubing _ z 10 a-1 av0 '1x6 PTD 2080310 'Type tSPT_Test psi 2700 IA I 11 23 9 31 BBL Pumped 0.6 ' BBL Returned: 0.5 OA 16 16 H, 16 16- Interval OTHER TP/F P J✓ Notes: WINJ MIT -Tubing post packer cement squeeze. Sundry 9 318-119. 1 well inspected, no exceptions noted. Tuesday, April 30, 2019 Page I of I S • of Tey Iy/, 6. THE STATE Alaska Oil and Gas h... OfA LA SKA Conservation Commission 333 West Seventh Avenue 117417i.1111;901 C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Michael Hibbert Well Interventions Engineer BP Exploration(Alaska), Inc. Ntow P.O Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool,PBU L-221 Permit to Drill Number: 208-031 Sundry Number: 318-119 Dear Mr. Hibbert: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this d day of April,2018. � SPR 111p18 RBpMS�'Ov`' RECE D • • STATE OF ALASKA IVB ALASKA OIL AND GAS CONSERVATION COMMISSI1) • APPLICATION FOR SUNDRY APPROVALS MAR 21 2 98 20 AAC 25.280 oA iva. �iuv /C 1. T • rilype of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well H Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change e rrl`1d Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Packer Squeeze H • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 208-031 • 3_ Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service H 6. API Number: 50-029-23385-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No H PBU L-221 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028239&028241 PRUDHOE BAY,ORION SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6050 • 4779 • 5139 4121 5139.5772 None Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20" 31-109 30-109 1533 515 Surface 3087 9-5/8" 30-3117 30-2753 5750 3090 Intermediate Production 6013 7" 27-6041 27-4772 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5206-5757 4167-4558 3-1/2"9.2# L-80 25-5794 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and ND(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary H Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service H ' 14.Estimated Date for Commencing Operations: April 15,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG H GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hibbert,Michael be deviated from without prior written approval. Contact Email: Michael.Hibbert(d)BP.com Authorized Name: Hibbert,Michael Contact Phone: +1 907 564 4351 Authorized Title: Well Interventions Engi Authorized Signature: N..;&-....`••06N Date: J.Vziho COMMISSION USE ONLY IO Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 5I'6 II'1 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test d Location Clearance 0 / 5,C/1 7- Other. L°d 7.3 4 l e v i`rf wi r vi--f S Ali d�tC tri�N f¢ w0 y to r1,5J cv ` ° a`'S Post Initial Injection MIT Req'd? Yes❑ No IMS i---er��U w I c Spacing Exception Required? Yes 0 No El" Subsequent Form Required: J12 —4 D 4. 0,1::: -C"...V.,, ,,11—^ APPROVED BYTHELApproved by: C:.,,,^. ,- _,. - COMMISSIONER COMMISSION Date: 'O 1�� VA i 4c }� ORIGINAL RBDMS .:. :>25--- ..„ b( ..._ -3 .,/-1',45: Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Packers and SSV's Attachment L-221 SW Name Type MD TVD Depscription L-221 TBG PACKER 5117 4106 3-1/2" HES Dual Feed Packer L-221 TBG PACKER 5318 4244 3-1/2" HES Single Feed Packer L-221 TBG PACKER 5459 4343 3-1/2" HES Dual Feed Packer L-221 TBG PACKER 5536 4397 3-1/2" HES Single Feed Packer L-221 TBG PACKER 5670 4494 3-1/2" HES Single Feed Packer • • by 0 L-221 Packer Squeeze Well Interventions Engineer: Michael Hibbert (907) 903-5990 Pad Engineer: Alex Youngmun (907) 564-4864 Expected Start Date: 04/15/2018 History L-221 is a regulated Schrader Bluff WAG injector drilled and completed in 2008 in the NB / OA / OBa / OBb / OBc / OBd sands supporting offset producer L-205. L-221 was temporarily POI'd in July 2016 for 5 days to check the wells operability as part of screening for the L-205A ST. During the screening, L-221 failed a MIT-IA on 7/29/16 with a LLR of 0.25 bpm at 790 psi. A SLB STP LDL was ran on 8/21/16. The STP results were inconclusive so a PDS acoustic log was run, identifying a leak point at the top packer at 5117' MD. The PDS LDL was ran with a LLR of 1 bpm at 1450 psi pumping down the IA to the formation. A caliper was run on 8/14/16 recording the tubing to be in good condition with no significant wall penetrations >20%. L-221 passed a MIT-T to 2410 psi on 8/22/16. Current Status The well is currently classified as "Not Operable" by BP and is shut-in due to the packer leak. Objective The objective of this job is to perform a packer squeeze and seal off the leak. Procedural steps Slickline 1. Pull WRP. Pull PX plug from tubing tail. Dummy off all WFRVs, and pull dummy valve from station #10. Install valve with check in station #10. Eline 2. Set CBP @ -5,075' MD. Coiled Tubing 3. Pump packer squeeze with -15 bbls cement. Mill out Cement/CBP after cement reaches -500 psi compressive strength. TOC in IA after packer squeeze expected to be -4600' MD and 3750' TVD. The surface casing shoe is at 3117' MD and 2750' TVD. • Cement Type/weight: 15.8 ppg batch mixed. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 6 hours Activity Time(hours) Shearing time,quality control, PJSM 1 Cement displacement 2 Cement contamination 2 Safety Minimum required thickening time: 6 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 130 3500 2:00 140 3500 3:00 150 3500 4:00 160 3500 7:00 160 3500 15:00 160 3300 DHD—WOC 4 days 4. MITIA to 3,700 psi. Eline 5. Run SCMT to determine TOC in the IA and Waterflow Log. Long-Term Monitoring 1. MIT-IA every 2 years 2. Waterflow Log every 2 years 2 • • Loepp, Victoria T (DOA) From: Hibbert, Michael <Michael.Hibbert@BP.com> Sent: Thursday,April 05, 2018 4:04 PM To: Loepp,Victoria T(DOA) Subject: RE: PBU L-221(PTD 208-031, Sundry 318-119) Packer Cement Squeeze Attachments: L-221 Pkr Sqz Sundry.doc Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, I made the requested changes and included them in the attached Word document.The changes are also noted below. Thanks, Michael From: Loepp,Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent:Thursday,April 5,2018 2:16 PM To: Hibbert, Michael<Michael.Hibbert@BP.com> Subject: PBU L-221(PTD 208-031,Sundry 318-119) Packer Cement Squeeze Michael, Please include the following: 1. TOC in IA determination method post procedure.SCMT to be included after the packer squeeze. 2. MIT-IA every two years. Included in long-term monitoring section. 3. Waterflow log every two years Included in long-term monitoring section. What is the TVD depth of the surface casing shoe and the expected TOC?TOC @ 3750'TVD, Surface Casing Shoe @ 2750'TVD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria,Loeppa( ..alaska.gov 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • 41,• 'TREE= 4-1/16"OW SAFETY NOTES;1-23 FEADINGS AVERAGE 125 ppm WEILI-EAD= RAO WHEN ON MI.WELL REQUIRES A SSW WHEN ON ACTUATOR= C-LEO L-22 1 Current FAL ***1-C3 NKR@ 5117'IS'PULL TO RELEASE"BUT KB.EIE'V- 77.4' CAN ALSO I3E RELEASE°BY PRESS. DO NOT EXCEED BF la2/= 51 51' KOP 7 300' I 1,.. I 2000 PSI ON THEM kr/OUT PERFORMING TBG Wax Angle- 53 .10 2980' , tA CWEtA ENT CALC'S&DISCUSSIAD w I'APE*" Datum MD /= 564T I IN...,. ?Jr —14-11T X 3-1/2"XO.D=2,992 ) n3turn 1VD= 4400'.SS ft —iii"--1 -ii:177. iiiZikii;:ii:iiiii7 -"-L. i f 1 20"CaNDUCTOR 91.59,A-53,El=19.124- H 108- i —, (AS La-I MA NLLS / Li ST ND TV°'CEV TYPE '-'VLV I LATCH-FORT CiA 1 L s : _ 1 10 5089 40731 47 ,,, MAXI ,Dv( I RK _ 0 06J21/08 9-5/8"CEO,409,L-80 BIC,D-8.835' H 3117' I .1 I I I 5096' J-13 02"HPS X NIP,13 2 613"J .______ ______........_ fr C$( Mk,L-813 101 X0 TO l-80 WIDNI H 4070' I/ 5131' H3-1/2"NC11- PALTI-SENSOR SUB,fl=2.992 1 I ./P>.. ,.....„,?`'' .-- r X 3-1/2'i,r,,,:'taik.vai 1, I#4•11t1,4An I wia,Itl 7 CillAk. 1.4 6117" , - .....---• WATER INALC BON MANDRELS II- SI I ksi) IVOT I PM 1 VW RI LIAR.i 3-1/2"AFL)WRP(0812 1/16) H 613W — DEV 9 5143 4124 47 MMGLAID 11 PO -W DM' RE 1 0 04/07103i 8 5236 4187 47 kINIG-W R15 FK i 151 05108431 Minimum ID (L-221)=2.75" e 6771' 1 7 5344 4263 46 MMG-W CMY RK I 0 ci4tone31 32112" HES XN NIPPLE . 6 5438 4328 45 MMG-W P-IS FOC 1211 054603 I 5 5485 4362 45 MMG-VV CMY RIK , 0 04/0743i 17'MARKER JOINT w/RA HP TAG '.--1 61157' 4 5516 4384 45 MMG-W P-15 FE 13L 05/08/03 3 5570 4422 44 MMGAAI OW W 1 0 04/07833 13 1f2-RA 11,MO 1 62415' E....".."41 2 5641 4473 44 MMG-W P-15 RIC ' 9t4 054641 iHRUKR.10 2.906 1— 5311_1----x 1 6722 4532 43 MMG-W'15X,Jf FE 161 08440/1 P - " , lk,... 5297' H3-1 "HES X NIP.ID=2 air I ,2 15331. H-3 1/2"NDFG ,UTI Se4SOR SUB•0-2 992 1 , I I 5451' n3-1/2"HPS x KIP,n--7 M3- r-X 3-1/2"HES SNGLE FEEIT1HRU H<F1,ID=2.965- H 646.!_i--- ,.< XS, 91. 5473" 1 13-1/2'WPC kilITISEKDOR SUB,10=2 092-1 Eil 1 I sg2ip 1 p-ii.1..sit-I*srigni r;'-F 4-1141-44i i Lisci4 EA at 7 tift.s. ] ----- PERFORATION SUP/WARY --1 6649' H34,-2-MJF G I&ail-SENSOR SUB,ID=2.992 I Rif LOG: USA-LOG ON 0'1/07/08 If-- ANGLEAT TOP FERE.47"@ 5024' I I [] 5662' .1—3-1/2-HES X MP,D=2.813' Note:Refer to Proth.iction DB for historical pert data SIZE SPF ZONEINTERVAL Oprilatz CATE Cil 9 4-112" 5 N 7, 5206-5228 C) 04/06108 1 15670' Thrr X 3-112-SPCA P FhT‘OTHRIJ OCR El=7 985" j 4-112" 5 CA ! 5396-5448 0 04/06/08 4-1/2' 5 OBa i 5487-5530 0 044648 7< 2_co... .,,..„„...---1 548_ _NeFG kAULTI SENSOR SW,ID-2.092 4-1/2' 5 0Db i 5548-5568 0 044648 412" 5 06c1 5622 5649 0 0446436 I I 9701" j—3-in*i-es X PAR ID,2813' 1 4 1/2" 5 OW /J692 5 Mt C) 0411.16/08 - l MI 1 -s I I 5751' —3-1/2"FES X tap ID=2 813' .„ i, 57 72' H3-1/2"HPS XN NP,i) 2.750' I lk0 1 -------: 5772 j 13 1/2'PXN HUG(06/19/08) 1 3-1/2"113C,9 2#,L-80 TCS, 0087 bpf D=2.992" I-- 5794' 1 , c FOTO 5955' ---....,...,i . 679 H 4. 3_112-kAA..EIG,10=2.992' '949.1 AVIA 1.9 AO • I 1---i Fl MO NOT I OGGED 17'CSC,289,L-ao ETC-AA,.03E13 bpf•ID=6.276" H 6041' 111,IALA,ALIO A4 ' CATE REV BY aMs14NrS DATE RE/BY CONININ-3 ORIONIPIT 04/09/08 t ORIGINAL COMPLETION 62/15/11-'IA/AiD ADDED SSSV SAI-EIV NOTE WELL L-221 ro"08108 TWYPJC DRL.G DRAFT DORFECTIONS 02/27/11 W/'PJC SFTY NOTE(tES F4(RS) — Fewu No ' 080310 002548 SVICISV SET PXN(06119108) 01/18/12 TWIN)ADDED 112S SA1-Liv NOTE - AR 1%lo 59-029-2338540 06/05/08 JMPJC DRAWING OORRECTIONS 08/24/16 BThVJM)SET WM W163(08/21/16) SEC 34,112N,R1 1E 2404'FSL&1663'PAIL I 0601i89 SWC/T-11 GLV 00(0548/09) 01;25/18 EZ.:JVID AIMED SPRING WEIGHT TO VVFR 1 ./.28109 3091W GLV coo(08134/09) _1 Bp EXplorabon(Alaska) 3 TREE= 4-1#16"OW 1 SAFETY MOTES:1-12$FLA L!N S AVERAGE 126 ppm WELLHEAD= FMC AC1UATOR= Gtr L-221 Proposed WHEN ON MI.WELL REQUIRES SSSV WHEN ON EiEV- 77.1' M/. TIES PKR@ 5117'13"PULL TO RELEASE"BUT KB.#3F ELEV= 51.51' CAN ALSO BERELEASED BY PRESS. DO NOT EXCEED I\ I 2000 PSI ON THEIA yr/OUT PERFORMING TBG 1COP- 30g Mix Angle- 53' 2980' B4MOVER MT CALC'S&DISMISSING wI APE`** @ CastumAM= 564r Datum D= 4400'.SS ' DaTVPacker squeeze; TOC 20'CJNOUCLOR.9t5#.A-53,I7=19.124' 108' f =4600'MD S MO TVD DEV: TYPE VLV LATCH PORT DATE I9-518`CSG,404,L-80 STC,ID=8.835' - 311T 10 5088 41)73 47 UNx; mon j RK 0 06111,538 5098' 13 1/2"111.S XMP 10 2 813` V CSG.26//,1.80 TCIXO TO 1-60 OTC-M I--1 4870` I Si 31' -13-liT M7PG MULTI-SENSOR 508,1D=2.982 7"X'J-1t2'1,11.:cu.�.1.14 c-1444 MICA I uru,WI,-r M • /147• --� _ -. �"'E 111YATF33!NEC DON Ab0.t�Lif�Fls 1 317Z"WFDWRF'(Od21li6l 6139' �- ST M) TVI)'i IXV 1Y II. 1 VW 1.ATCt1IFUfU IAACL_ I� I` n 9 5143 4124 47 MMG-W 13MY PK i 0 04 )710$ r-_----- 8 5236 4187 47 MMG-W R15 RIC 151 05/08109' MinFrnurn ID {L-224y 2.75 � to?7i' 3-112" HES XN NIPPLE Mil _ 7 5344 4263 46 MMG-W MY RK. 04/07403 6 5438 4326 45 MMG-W P-15 FSC i 12H 051(IBKP3 5 5485 4362 45 MMG-W CMY RK 0 04/07103 17'MARKER w nu PP TAG - sie r - 4 5516 4384 45 MMG-W X15 FDIC 131 051060 3 U2'FIIA F iT,: 62d6' 3 6570 4422 44 MMG-W COY FE 0 04/07103 � n� _.:._. ' 2 5641 4473 44 MMG-W P-15 RIC 911 Q5/001079 1 5722. 4532 43 MMG-W'15XJF FSC 151 0304/03 i ii"T"X 3-112'MES SINGLE FB1831144U MR D 2.865` 5316° I r r 5297' 3-112"HES X MP 13=2.813" I Eil `•1 5331' 1/2"NDPG MA fl SENSOR SUN,10-2.1192 1 ' ' i. 5451' H3-172'HF:SXNIP,I7=9air I 7'X 3-1/2"HES SINGLE FEETJTFfRU a.cR 0=2.965' H >< 5469 -R.,.r --' O� 547'3' -3-1/2"MVO lA H TI SENSOR SUB 13-2.592 IM 1436*.,.... I 1 J'Y"1..iC7"•:RYJ{ f 1+t'Ytf @J11 WI., 1 t "i WV,"_.-1 111 PERFURATILNNSUMMARY '-,I 6549' H3-1/2`M3FG &LTI-SE SOR SUE,D=2.392 I REF LOG: WIT LOG ON 04/07/38 ANC;LEAT TOP P .47"L 5024' s I I 0 666T .1-1,3-112'FES X MP•I) 2.813- Note:Refer to Ttoducbon 06 for historical perf cata SIZE 'SPF ZONE; INTERVALOprlrSgz DATE 4172" 5 Na '; 5206-5228 O 04/06108 cil _ 5670' 7"x 3-1/2'S#YGtE TEEM/MU F1(R,ID=2.965' 4-112' 5 OA i 5396-5448 0 04/06/08 ' 4-112" 5 OBa 5487-5530 0 04/06/055683' �--�3.1t2'NOF 4&i T1 S Sfc SUB•IO-2.992 4-112" 5 OE3b 5548-5568 0 04/06108 �' -- 4 112" 5 OBc 5622 5649 O 04/06/06 I I 1870-1;-1--1T---1/71.ES ..Nil, t Z.813'_1 4112" 5 Olid 5692 5!r)/ C) 04/06/08 Ell 0 , , ' 5751" 3-1/2"WS X MP 13=2.813' Win 5772' I--,3-1/2.1-FS XN MF,13-2750" I -1t 'TBC,E 7t'.I-80 TCI,.0087 bpf,D=2.9/92' �-. 5794' �--.—_ 5777 �$ 1/�"1'kN 11_CX (E)t111r17II8) 3 .. __ PEW 5955' 1. 5744" I-13-I2"MAL ,ID2.992" I .4.i #` 4. **it y1!♦ I IFI.I NOT IUGL�FTi� • is 0j�L4,4. .44ttM _.._...-___ 4 —..� _ Iz'CSG,264,L-80 BTC-A,.0383 bp1, =8.276" •--I 6041' UAW REV BY COMMENTS DATE RE/BY CONVENTS ORION UNIT L'""/09108 N9t3S ORIGINAL COMPLETION 02/15/11 1411JND ADDED SSSV SAFETY NOTE WELL. L-221 0E108/08 TWIPJC EMIG DRAFT OORRECTK)NS 02/27/11 I.AVUPJC SFTY NOTE(HES PKRS) - FERNIT No-"2'080310 OE/25108 SIACISV SET F'XN(06119108) 01i18112 TMtJND ADDH)142S SAI-t1 Y NOTE AR No. 50-029-23385-00 05405/08 JFNPJC DRAAWNG CX)RRBCTOONS 08/24/16 MUNI)SET'4WDVuRP(D&2916) SBC 34,T12N,R11E 2404'FSL 81663'RM.. 0E/01/09`51/1r/TA-1GLV C/O(05/38109) 01/25/18 EZ"J4U A008)SPRING WEIGHT TO WFR rEr928,109 JCMSV GLV GO(08/34109) BP Exploration(Alaska) 4 • •• by L-221 Packer Squeeze Well Interventions Engineer: Michael Hibbert (907) 903-5990 Pad Engineer: Alex Youngmun (907) 564-4864 Expected Start Date: 04/15/2018 History L-221 is a regulated Schrader Bluff WAG injector drilled and completed in 2008 in the NB / OA / OBa / OBb / OBc / OBd sands supporting offset producer L-205. L-221 was temporarily POI'd in July 2016 for 5 days to check the wells operability as part of screening for the L-205A ST. During the screening, L-221 failed a MIT-IA on 7/29/16 with a LLR of 0.25 bpm at 790 psi. A SLB STP LDL was ran on 8/21/16. The STP results were inconclusive so a PDS acoustic log was run, identifyjng a leak point at the top packer at 5117' MD. The PDS LDL was ran with a LLR of 1 bpm at '1450 psi pumping down the IA to the formation. A caliper was run on 8/14/16 recording the tubing to be in good condition with no significant wall penetrations >20%. L-221 passed a MIT-T to 2410 psi on 8/22/16. Current Status The well is currently classified as "Not Operable" by BP and is shut-in due to the packer leak. Objective The objective of this job is to perform a packer squeeze and seal off the leak. Procedural steps Slickline 1. Pull WRP. Pull PX plug from tubing tail. Dummy off all WFRVs, and pull dummy valve from station #10. Install valve with check in station #10. Eline 2. Set CBP @ -5,075' MD. Coiled Tubing 3. Pump packer squeeze with —15 bbls cement. Mill out Cement/CBP after cement reaches —500 psi compressive strength. TOC in IA after packer squeeze expected to be —4600' MD. • Cement Type/weight: 15.8 ppg batch mixed. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 6 hours Activity Time(hours) Shearing time, quality control, PJSM 1 Cement displacement 2 Cement contamination 2 Safety 1 Minimum required thickening time: 6 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 130 3500 2:00 140 3500 3:00 150 3500 4:00 160 3500 7:00 160 3500 15:00 160 3300 DHD —WOC 4 days 4. MITIA to 3,700 psi. 2 110 0 TREE- 4-1116"CNV 0AFETY NOTES;RN REACINGS AVINN,GE 125 ppm ViELLFEAD= RAC ACTUATOR= C-LEO L-221 Current WI-134 ON h11.WELL REQUIRES A SSSII WHEN ON Mt ""FEB PKFtfp 5117'IS"PULL TO RELEASEBUT Ka.Ei_EV- 77.4' CAN ALSO BE RELEASED BY PRESS. DO MDT DICER) BF.EV= 51 51' 1 KOP-. 300' , -,--,.,,.... 2000 PSI ON THE IA w!OUT PERFORMING TBG MOVEIA EMT CALC'S a DISCUSSING w i APE"' !Aix Angle- 53°0 2980' Datum MD= 5647' II I r---,..., ` ?X -41-1:2"X 2-1,7 XC).c=1992- ci3torn Tvu= 4400' SS 2i 21• .., 1.,.-,.,', x hilt, I, -2:61.i.:1 , ,____ 120"ODNOUCTOR,91.54„A-53,RD-19.124- H 108' j =—:. / [DI jiASLlt-I h4,11311JMLS ST MO ND'DEV Tr'FE yLy LATCH PORT OA-1 L , 10 5ona 4073, 47 Mror,(Info), RK 0 08121108 19-5/8 CSG,e.am,L so 3-rc,ID r 8.835" — 3117 _ '• - , .--"------- 1 I 1 5096' 11 11."-tlt",A rirri)-,23131 ri=6.5(3..264+ L-80 Tal X0 TO I.-410 EiTGA1 1— 4670' 1 5131' 1 L3 1,2'NDPG M...1 I I-SENSOR SUB.:,0=2.992 _ r 1,/^->C.' -- -1-- I 7"X 3-1/2•is,:.ap..r...ti 1.1 I—T111-11.11 I MCI?,III I,.'1411 iia,t - ....: WA[Lit inut( lir NoA,Ati li i'; SI i4) ND DIV IVII I VLV 'LAIGiltikTIII i LTAII 13-1+7 VIFI3 VW,"(08/21/18)I— 5139' i---- N , ..._ _ _ 9 5143 4124 47 MUG-W CIVY FE 0 04/07/0r 1 8 5236 4187 47 MMG-W P15 IRK , 15L 05/06/09 W191111111 ID (L-22 1)=, 2.76" (e) 5 7'1 1' ii 7 5344 4263 46 MIAG-W LW FE 1 0 04/07103 3-1/2" HES XN NIPPLE 6 5438 4326 45 MG-W P-15 RK 1 12H 05/06609 . ,. . / 1=1 0 5 5486 436 112 45 MMG-W LW FE 1 0 000743 17'MARKER.00,INT w/RA PP TAG — 6167' • 4 5516 4384 45 PA MG-W P-15 FE 13L 05/06,109 „.-. • liTiFRAWTAG —f- 1"—r 3 5570 4422 44 MMG-W 1W RK 0 0470743 2 5641 4473 44 MMG-W P-15 FE !. 91i 05/013,0) I 11\.\ ,6 1 1 5722 4532 43 MPAG.W 15X.f FE 1St I 0870401 j ' !-' 5318' I ,.....-. ----,---"N .. -... --..... . ,,. IV1 5297* —3-1,2't--EL,'X NIP,ID=2 813" 1 ,_. Eil , ' ", S331' --13 1 NI30-t;%All II SENSOR SUB,ID-2992 I:3 - I I 5461' —13 lir HFS X NIP,f) 2 iii3- I 7"X 3-112"HES SINGLE FEBSIHRU PM 13=2.965' I— 5459' 5473' I 1-V7 MVO MUI n-F11,70R SUB,0=2 992 1 Ell ,, ' , s....1, . NV.! 1 I,'IIIIA I WI) l', . ILI, _.—•,' '''' "---. ....., PERFORATION SUMMARY 5549' -3 1,7"NCFG MULTI-SaNSOR SUB,IrD-2 092 i ......, REF LOG: USif LOG CN 0407/98 r ANGLEAT TOP PERE 41'@ 5024' I I ., 5662' H3-1/2"FES X NP,D.2213' I Note:Refer to Production DB for historical perf data SIZE SW ZONE INTEWAL OpritSqz DATE Ell 4-1/2' 5 Ib = 5206-5228 0 04/06i086610' HT X 3-10'EINGL F FTI-F4J PIG;ID•2,965' I 4-112' 5 CA 53%-5448 0 04/06/08 01 /— 4-1/2' 5 OF3a 5487-5530 0 049698 ------ -- 5683' 1-1.3-112'NCCIG,AWL T1SENSOR SUB,ID=2.962 4-117 5 am) 5548-5568 0 04/06/08 11-" 4 1/2" 5 OBc 5622 5649 0 04/06,98 I I F, - 6701' -4---,3 1(2.Heas X MP,D=2.813' I 4 1i7' 5 OBd 5692 5151 0 04706/08 Eil 11 , I I 6751" -1—3-1/2'I-ES X MP,ID=2.813" WA 5772' j---1-1/2°HES XN MP.ID=2_757 . 11_3.-12"PAN R_UG(06119/08) I3-1/2'TEC,924 L-80 TC11, 0087 bpi,ID=2 992"1— 5794' 1 PITTD I 5954' 1 • A A A. l —pile NT LOGGED I 17"CSG,26#,L-80 BTC-M,.0383 bpf,,0=6.276' i—] 6041' •A'A'n''`''''•'''•A HJATE REV BY CONCEITS DATE REV BY C01.4.43.ITS ORDN UMT ,., 04409108 rem ORIGINAL COMPLETION 0211S/11 M3IJM1.0 ADDIS')SSSV SAFETY NOTE WELL_ L-221 I' 0E.,08108 TIMPJC CRLG CRAFT DORRECT10145 02127111. MA/IPJC SUTY 142/11 I FES WEI'S) PERMIT No ' 080310 0E/25108 SVVCiSV SCT PXN(06,19/08) 01/18/12 TNCl/JR,E) ADDEDI-T2S SAFETY NOTE AR No. 50-029-23385-00 ' 0035108 JI,I/PJC CRAWNG CORRECTIONS 08/24/16 BT4J11-.) SET V1/4FD WRP(08/21116) SEC 34,1-1214.R11C 2404'FSL&1669'PAIL 0E031/09 SWCITJ-I GLV GIC)(0508/09) 01/25/18 EZ JI) AWED SPRING WEIGHT TO WER 0E08109 JO/ASV GLV GO(08/(14/09) BP Exploration(Alaska) -3 • 0 TREE= 4-1/16'CPA? f— SAFETY MOTES;I-123 FACINGS AVEW.C.E 125 ppm WELLHEAD-,-. RIC ACTUATOR= 0-LEO L-221 Prow)sed WHEN ON MI.WELL REQUIRES A SSSV WHEN ON Mt ''''FEB PKRQ 5117'IS'PILL TO RELEASE"BUT KB.ELEV- 77.4' CAN ALSO BE RELEASED BY PRESS. DO NOT EXCEED E31 ELEV= 51 51' KOP r, 300' 41 1- EM1 2090 PSI ON THE IA w/OUT PERFORMING TBG Abz Angle . 53'Q 2980' 1 PADVENT CALC'S 8 DISCUSSING w/APE Datum MD= 5647' i 1 Ir---,. Datum TVD= 44/1(7 ss Packer squeeze; TOC 1 120-CDNDLCTOR 91.54.A-53,ID-19.124" H 108' I i 10 508 7 0 4600'MD / iT Ivo TV CI DEV 1Y PE V LV U OrnRD I-6A TE 8 4C) 1 47 WAG 11..).1.1.( _ RK C{,121138' 'g 5d8'cs0,Ti0N,L-88 eTc,O8.835' 1-- 311T I . 5996' 17-CSG.201, o Tat xo 101.-8,3 8-rom H 4S70' 1 5-0: 5131' I 13 1/2"NDPG M-L TI-SENSOR SUB,ID-2.992 ..... p.x 3-in,,.•..:'411ArLI f-I-144111MA I urra,ri,-7 S114%. H ill r - - .....2-- WA ILI<INA(.1101,1MAFIl.)1411,!„", 1— —ST i M) IVI);LXV !VII I VLV LATCH PORI LVkIt p_ia.VVFD INFIP(08.12'1.7-1 --i_ 5130' ----- 9 5143 4124 47 MMG-W MAY RK 0 0410743 ,, _....._... ..____ ,,..,... Minimum ID (L-221) 2 75" a 677V 8 5236 4187 47 MMG-W P-15 RK 151 05/08/01 .=- 7 5344 4263 46 MMG-W DAY Tic CI 0470701 3-112" HES XN NIPPLE /I MI 0 6 5438 4328 45 MUG-W P-15 Fac 1211 05/0601 5 5485 4362 45 PA MG-W DAY RK 0 97/07r01 I/'MARKERJONT v.,PRA F41Ji( -1— 515T / Al 4 5516 4384 45 MMG-W P-15 SK 131 05/06/0) 3 5570 4422 44 MMG-W CAW W 0 047077041 13 In-RA 11,mu 5245 --`"" s 1 2 5641 4473 44 MMG-W P-15 RK 911 05/0801' 1 5722 4532 43 MMG-W 7, 15X.IF W 16L oato400), [i'X 3 1/7 HES SNGLE FEEDTHRtIPKR,D-2 965' I , 5319* — -,>< 529 7- H 3-1/2"HES X NIP.I3=2 813" 1 5331' 1L13-112'NDPG IAA II sHkezx)R SUB,E) 2.992 ' I 6451' 7-3 1/71-iFS X rip.n v 7 81.3- 1 k , '7'X 3-1/7 HES SNGLE FFH ii FRU 'rk-Ft,ID=2 965n— 5445 ___I—><-- O f 5473' —] t1-1,12"NOPG witin-sasso9815,in=2 992 ] MI - 6.636' if^w L.w,.-..r.m.i 1 s I 4 mica I Lk 1.7 i',_'2 ______ PERFORATION SURNARY __--. 6549, —3 1,2'N[7 MLA T1SBNSOR SUB,ID=2 392 REF LOG: USIT LOG ON 04/07/08 ANGLEAT TOPPERF 47"ig 5024' Id 6667 H 3-1/2'HES X tip D=2.813" I Note:Refer to Producbon DB for historical pert data SIZE SFF ZONE INTERVAL Opn/Sqz DATE 4-1/2' 5 Fl, 5206-5228 0 04706/08 _I--1 -3=-1-/-2" "f-;hit-t.P.FE6337144U RCR,13,,2 965- J ... 4-117 5 CIA 539€-5448 (3 04/06708 4-1/2' 5 OBa 5487-5530 0 04/06108 X. ><1...r.._ _---- 5683' H3 1r2.NOPG,k1UL-11 SENSOR SUB,ID-2902 ,7 4-1 5 OM 5548-5568 0 04/06/08 — - 4 1/2" 5 OBc 5622 5649 0 04/06108 I I 5701' 1-11-1,2•Hes X NP,D-r 2.813:j 4 vr 5 Otid 561I2 5/51 0 04/0608 IMI 0 1 "•J 5751' _I--,3-1/2"I IM.X NP 13=2 813" 5772' 1---11-io-i-Fs xri NIP,ID=2.750".1 ..„,„ ... . 3-1/2'TBG,9 29,L-80 TCI 0087 bpf,ID=2 992' -- 5794' 1 / 5777 I;la 1/2'PXN R_UG(06/19* -----'"-----. 5794. .1—3-1"2LEG,ID,2.992.1] reTD 5955' 1 11.541* 0. .05150 I Lwr5PinT 1. 411054 17"CSG,26#,L-80 87C-to,.0383 bpf,0=6.276' H 6041' A A 4'A'..A4 J ----, DATE FEV BY COMMENTS DATE REV BY COMINTS OMR URI 04)09108 . N9E5 ORIGINAL COMPLETION 02115/11 IheIJIAD ADDED SSSV SAFETY NOTE AIELL. L-221 -0E/08,108 ' TIAIPJC CIRLG CRAFT DORRECTIONS 02127/11 MAPIRIC SFPf NOTE IFES[MRS) MAU tip "2080310 0E+2511)8 ,SWCISV SCT PXN(06119108) 01116/12 TlitIAM)AWED ICS SAFETY NOTE AR rqo 50-029-23385-C10 GE/05/08 ' JMRIC DRAIAtIG CORRECTIONS 08/24/16 671.114) SET VVFDIAIRP(08,121/16) SEC 34,712N,R11E,2404'FSL&1663'FWL 06101039 SWCTIJ-IGLV C/0{05108/09) 01125/18 12.:J11) ADDED SPRING WEIGHT TO YVFR — 0E42809 KAISV GLV GO(0811:44A39) RI'Exploration 1Alaska) 4 S • Loepp, Victoria T (DOA) From: Hibbert, Michael <Michael.Hibbert@BP.com> Sent: Thursday,April 05, 2018 4:04 PM To: Loepp,Victoria T(DOA) Subject: RE: PBU L-221(PTD 208-031, Sundry 318-119) Packer Cement Squeeze Attachments: L-221 Pkr Sqz Sundry.doc Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, I made the requested changes and included them in the attached Word document.The changes are also noted below. Thanks, Michael From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday,April 5, 2018 2:16 PM To: Hibbert, Michael<Michael.Hibbert@BP.com> Subject: PBU L-221(PTD 208-031,Sundry 318-119) Packer Cement Squeeze Michael, Please include the following: 1. TOC in IA determination method post procedure. SCMT to be included after the packer squeeze. 2. MIT-IA every two years. Included in long-term monitoring section. 3. Waterflow log every two years Included in long-term monitoring section. What is the ND depth of the surface casing shoe and the expected TOC?TOC @ 3750'ND, Surface Casing Shoe @ 2750'TVD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppAalaska.gov 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 Victoria Loepp at(907)793-1247 or Victoria Loepr4alaska.gov_ 1 J • • N to L c0 Q a 0 .0 > c, v O L L ,��Yy//��' Y h 1 v L O Y A _ w,w F (` O v v ,�` C7 N�Z _0 Zr N r6 4 O �n N `V O�m O n. 0 C O c > 0 :111 u o ° C " E >co 0 c) 0 Q u.l to t0 c0 t0 O O t0 f0 f0 N O 6 m a l7 6) m 6 Y L 'p O V) O 7 7 m - m 7 7 7 7 "6Y InW ' a a a a a Q a c @ Lu -c cu✓' I- Co M ,- N (D T o0 0 Y C N N u D (6 0 Y° 0) > a N s_ v O C L Y MI u Y (0 O C .. v TO N U 00001:10C100 d J J J J J J J J J C w- U 0 W W W W W W W W W v) v •4. 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N r N 0 0 N O O +'' C ?11i1� 0 0 0 0 0 0 0 O 0 Q �} e}tD 0 0 0) M In V I/') f0 1R\{) 1n CO (0 (0 'V h C) CO CO �j h M et r O M N e- 0 N N N M M C CO N 0 p, N N N N N N N N N y) C 8 4 O) O C) C) C) O C) C) 0) C O N N N N N N N N N (p v E. ODOOOOQQQ L C 0 0 0 0 0 0 O O O r+ Y 4) Y') U) IA N N N N U) N m �. cc p�� C .- cu y w CM Z Q1 E d 0O p 0 W Y v) u CO u as ro -o Z m m o m r- c-) a m •Q.( N E H a N N M N M N N N 0 u C _ 6. Q t N 2 ° U a 0 o J J J £ VI CD Z W D O . -= ' .•1 U ^ CC A u 0_ •••1O (0 01 C O R/? O. tti a Q1 a` a ° m • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, August 23, 2016 4:15 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Slickline; AK, GWO SUPT Special Projects; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Rupert, C. Ryan; Wallace, Chris D (DOA); AK, OPS Well Pad LV Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Regg,James B (DOA) Subject: NOT OPERABLE:Injector L-221 (PTD #2080310) Packer Leak All, Injector L-221 (PTD#2080310) failed an MIT-IA on July 29 2016 indicating a lack of two competent well barrier envelopes. The well was shut-in and reclassified as Under Evaluation. A leak detection log performed on August 22 2016 identified a packer leak at 5117'. This well is now classified as Not Operable. Thanks! Jack Lau (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent scht4t4ED NOV 0 8 2016 W: 907.564.5102 C: 907.943.0296 H: x2376 From: AK, GWO SUPT Well Integrity Sent: Friday, July 29;-,216 07:48 PM To: AK, OPS GC2 OSM; A ;,OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Slickline; AK, GWO SUPT Special Projects; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Ruper , Ryan; Chris Wallace (chris.wallace@alaska.gov); AK, OPS Well Pad LV Cc: AK, GWO SUPT Well Integrity; AK, GVW DHD Well Integrity; AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; 'zegg, James B (DOA) (jim.regg@alaska.gov_)' Subject: UNDER EVALUATION: Injector L-221 (PT. • 080310) Failed MIT-IA All, Injector L-221 (PTD#2080310)failed an MIT-IA on July 29 2016 indicating . ack of two competent well barrier envelopes.The test was performed after a prolonged period of being shut in, i •reparation for an AOGCC witnessed MIT-IA due August 25, 2016.The well is now classified as Under Evaluation and will r-main shut in until well barriers are verified. Plan Forward: 1. Production Engineer: Evaluate Repair/Secure 1 20`6-03� • • WELL LOG TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC Makana Bender 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 attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2-1 900 Benson Blvd. Anchorage, AK 99508 gancpdcC bp.com SCANNED NOV 0 4202 and ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C • Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 22-Aug-16 L-221 BL /CD 50-029-23385-00 2) Signed : �✓ 6,„„atDate : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFi le s\Templates\Distribution\TransmittalS heets\BP_Transmit.docx S • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday,July 29, 2016 7:48 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; Rupert, C. Ryan;Wallace, Chris D (DOA);AK, OPS Well Pad LV Cc: AK, GWO SUPT Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus,Whitney; Regg, James B (DOA) Subject: UNDER EVALUATION:Injector L-221 (PTD#2080310) Failed MIT-IA All, Injector L-221 (PTD#2080310)failed an MIT-IA on July 29 2016 indicating a lack of two competent well barrier envelopes.The test was performed after a prolonged period of being shut in, in preparation for an AOGCC witnessed MIT-IA due August 25, 2016.The well is now classified as Under Evaluation and will remain shut in until well barriers are verified. Plan Forward: 1. Production Engineer: Evaluate Repair/Secure 2. Well Integrity: Further Diagnostics as required Please call with any questions or concerns. Ryan Holt +Att<'i!rr tr r;-i-1 BP Alaska-Well Integrity Al Cloba1Wells � V Organizalior SCANNED OCT 3 12096 Office: 907.659.5102 From: AK, D& ell Integrity Coordinator Sent: Tuesday, Augu = 2012 4:11 PM • - To: 'Regg, James B DOA Sc Guy L DOA AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; ' oski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, • GPB West Wells Opt Engr; Kirchner, Carolyn J; Chris Wallace (chris.wallace@alaska.gov); Brooks, Phoebe L(DOA) .,;_.ebe.brooks(aalaska.gov) Cc: AK, D&C Well Support Coordinator; Walker, Greg (D&C , lingingsmith, Mike J Subject: OPERABLE: Injector L-221 (PTD #2080310) Passed A C Witnessed MIT-IA All, . WAG injector L-221 (PTD#2080310) passed a witnessed AOGCC MIT-IA to 3000 psi on s: 25/2012. The passing test confirms the presence of two competent barriers in the wellbore. The well is reclassified as e •erable. 1 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~~ - Q 3~ Well History File Identifier Or anizing (done) Two-sided III (VIII II III II III ^ Rescan Needed III II'III II II III III 9 RE AN DIG TAL DATA OVERSIZED (Scannable) Color Items: Diskettes, ~ ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ~ ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ I 0 /s/ Proofin IIIIIIIIIIIIIIIIIII Project g BY: Maria Date: ~, /Q /s/ Scannin Pre aration _~, x 30 = ~ a + =TOTAL PAGES ~~ g p " (Count does not include cover sheet) BY: Maria Date:. ~, ! ~~ /s/ Production Scanning Stage 1 Page Count from Scanned File: __(l~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria Date: `~ 1- ~ ~O /s! ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'III I II II I I III ReScanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III VIII III II'I III 10!6/2005 Well History File Cover Page.doc • • Wallace, Chris D (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIllntegrityCoordinator @bp.com] Sent: Tuesday, August 28, 2012 4:11 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Kirchner, Carolyn J; Wallace, Chris D (DOA); Brooks, Phoebe L (DOA) Cc: AK, D &C Well Support Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J Subject: OPERABLE: Injector L -221 (PTD #2080310) Passed AOGCC Witnessed MIT -IA Attachments: MIT PBU L -221 8- 25- 12.xls All, WAG injector L - 221 (PTD # 2080310) passed a witnessed AOGCC MIT -IA to 3000 psi on 08/25/2012. The passing test confirms the presence of two competent barriers in the welibore. The well is reclassified as Operable. A copy of the MIT -IA is enclosed for review. Since a copy of the MIT is included, a copy will not be sent in with the completed August MIT forms. «MIT PBU L -221 8- 25- 12.xls» Thank you, SCANNED MAY 0 2 2913 Gerald Murphy BP Alaska - Well Integrity Coordinator i WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Thursday, August 16, 2012 2:14 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Kirchner, Carolyn J; Chris Wallace (chris.wallace @alaska.gov) Cc: AK, D &C DHD Well Integrity Engineer; Clingingsmith, Mike J Subject: UNDER EVALUATION: Injector L -221 (PTD #2080310) Long Term Shut In Injector Ready to Place on Injection All, WAG injector L - 221 (PTD # 2080310) is a long term shut in injector that is ready to be placed on injection. The well passed an MIT -IA to 4000 psi on 08/15/2012 confirming competent barriers to formation. At this time the well is reclassified as Under Evaluation so it can be placed on injection for an AOGCC witnessed MIT -IA once thermally stable. 1 • • The MIT -IA form is attached for reference: Thank you, Mehreen Vazir BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator c BP.com 2 1111 • Wallace, Chris D (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Thursday, August 16, 2012 2:14 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Kirchner, Carolyn J; Wallace, Chris D (DOA) Cc: AK, D &C DHD Well Integrity Engineer; Clingingsmith, Mike J Subject: UNDER EVALUATION: Injector L -221 (PTD #2080310) Long Term Shut In Injector Ready to Place on Injection - Attachments: MIT PBU L -221 08- 15- 12.xls All, WAG injector L - 221 (PTD # 2080310) is a long term shut in injector that is ready to be placed on injection. The well passed an MIT -IA to 4000 psi on 08/15/2012 confirming competent barriers to formation. At this time the well is reclassified as Under Evaluation so it can be placed on injection for an AOGCC witnessed MIT -IA once thermally stable. The MIT -IA form is attached for reference: «MIT PBU L - 221 08 15 12.xls» Thank you, �� ;� fi 2013 SCANNED Mehreen Vazir BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator @BP.com 1 III • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . Mechanical Integrity Test Submit to: jim.regat0alaska.aov; doa .aoacc.Prudhoe.bav(ealaska.aov: phoebe.brooksektlaska.aov; tom.maunder(Qalaska.aov OPERATOR: BP Exploration (Alaska), Inc. • FIELD / UNIT 1 PAD: Prudhoe Bay/PBU /L -Pad DATE: 08/15/12 OPERATOR REP: Mehreen Vazir AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L -221 Type Inj. N TVD 4,106' Tubing 520 529 529 525 Interval O P.T.D. 2080310 _ Type test P Test psi 1500 Casing 120 4011 3922 3891 P/F P Notes: Pre -POI MIT -IA OA 30 _ 29 29 29 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA_ Well Type Inj. TVD Tubing Interval P.T.D. Type test_ Test psi_ Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = DriNing Waste M = Annulus Monitoring I = Initial Test G= Gas P = Standard Pressure Test 4 = Four Year Cycle 1= Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water 0 = Differential Temperature Test 0 = Other (describe in notes) Form 10-426 (Revised,06/2010) MIT PBU L- 221 08- 15- 12.xds DATA SUBMITTAL COMPLIANCE REPORT 2/17/2010 Permit to Drill 2080310 Well Name/No. PRUDHOE BAY UN ORIN L-221 Operator BP EXPLORATION (ALASF(a INC API No. 50-029-23385-00-00 MD 6050 TVD 4779 Completion Date 4/9/2008 Completion Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Surv y Yes DATA INFORMATION Types Electric or Other Logs Run: GR, GE / RES / NEU / AZI DEN / PWD, CBL /USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ~y meairrmc rvumoer Name scale meaia No Start Stop GH Received Comments ' D~ D Asc Directional Survey 0 6050 Open 4/9/2008 ^I ~ pt Directional Survey 0 6050 Open 4/9/2008 Cement Evaluation 5 Col 200 5900 Case 4/28/2008 USIT, CBL, CCL, GR 7- , Apr-2008 , C Pds 16167 dement Evaluation 200 5900 Case 4/28/2008 USIT, CBL, CCL, GR 7- Apr-2008 ~ D C Lis 16375GG~ement Evaluation 132 5885 Case 6/6/2008 LIS Veri, USIT, CCL C Lis 16521t~nduction/Resistivity 50 6051 Open 7/1/2008 LIS Veri, GR, ROP, FET, RPM, RAM, NPHI, TRPM, DCAV i og Induction/Resistivity 25 Blu 108 6016 Open 7/1/2008 MD Vision Service r~og Induction/Resistivity 25 Blu 108 6016 Open 7/1/2008 TVD Vision Service _g Caliper log _ _ 25 Blu 108 6016 Open 7/1/2008 MD Density Caliper Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments • ~' DATA SUBMITTAL COMPLIANCE REPORT 2/17/2010 Permit to Drill 2080310 Well Name/No. PRUDHOE SAY UN ORIN L-221 Operator BP EXPLORATION {ALASFU~ INC API No. 50-029-23385-00-00 MD 6050 TVD 4779 ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? Y.~N~-- Analysis ~#- Received? Comments: Completion Date 4/9/2008 Completion Status WAGIN Current Status WAGIN UIC Y Compliance Reviewed By: Daily History Received? N Formation Tops ~ N Date: BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 by ~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, O C T 0 5 2009 Alaska Uil 8t Gas Cons. Commission Anchorage a~B-~3, ~.-~.~- Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date L pad R/1.'3MnnQ Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al L-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 .: 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 ' 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 2.2 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 0.25 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late blockin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surtace NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28!2009 L-221 208(7310 50029233850000 NA 1.7 NA 16.2 6/25!2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 MEMORANDUM `~ To: Jim Regg 1 ~~~ 7/ ~1~`~,~'' P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 02, 2008 SUBJECT: Mechanical lntep ity Tests BP EXPLORATION (ALASKA) NC L-221 PRUDHOE BAY UN GRIN L-221 Sre: Inspector NnN-CnNFTnF.NTT e T . Reviewed By: r-? P.I. Suprv .J~ f nmm Well Name: PRUDHOE BAY UN GRIN L-22 t Insp Num: mitCS080702075427 Rsl Insp Num: API Well Number: 50-029-23385-00-00 Inspector Name: Chuck Scheve Permit Number: 208-oat-o Inspection Date: 7~I/2oo8 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-zz1 Type Inj. w TVD 4106 IA 970 2010 1950 1950 P.T. 2080310 TypeTest ~ SPT Test SI p lsoo QA 600 640 640 640 p/F Interval tNiTAL P i Tubing lzbo lzbo 12bo lzso Notes: Wednesday, July 02, 2008 Page I of STATE OF ALASKA 8 ~' Y I~ ALASK~IL AND GAS CONSERVATION COM~SSION~f iviaY U 9 2008 WELL COMPLETION OR RECOMPLETION REPORT AND LOGS <.~s~a O{ Gas Cons. Commission 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC25.105 2oAAGZS.~~o ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One 1 b. Well Clas ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban 4/9/2008 12. Permit to Drill Number 208-031 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 3/28!2008 ' 13. API Number _ S0-029-23385-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 4/2/20081 14. Well Name and Number: PBU L-221 " 2404 FSL, 3617 FEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 116' FNL, 3323' FEL, SEC. 03, T11 N, R11 E, UM 8. KB (ft above MSL): 77.4' Ground (ft MSL): 48.8' 15. Field /Pool(s): _ Prudhoe Bay Field / Orion Total Depth: 697' FNL, 3345' FEL, SEC. 03, T11N, R11E, UM 9. Plug Back Depth (MD+TVD) 5955' 4707' Schrader Bluff 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 583299 y- 5978127 Zone- ASP4 10. Total Depth (MD+TVD) 6050' 4779' 16. Property Designation: ADL 028241 TPI: x- 583626 y- 5975611 Zone- ASP4 Total Depth: x- 583611 y- 5975029 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and tinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, GR / RES / NEU / AZI DEN / PWD, CBL / USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING: DEPTH MD` SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING REGORD PULLED 20" 91.5# A-53 Surface 108' Surface 108' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 3117' 29' 2752' 12-1/4" 551 sx Dee Crete, 319 sx'G', 77 sx'G' 7" 26# L-80 26' 6041' 26' 4772' 8-3/4" 337 sx Class'G' 23. Open to production or inject ion? ®Yes ^ No 24. TueING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.2#, L-80 5794' 5117', 5318', 5459', MD TVD _ er MD TVD 5536' & 5670' p 5206' - 5228' 4167 - 4182' ~ 5396' -5448' 4299' - 4335' ~~`~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5487' - 5530' 4363' - 439° C°i'= DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 5548' - 5568' 4406' - 4420 ~ °`~ 5622' - 5649' 4459' -4479' 2200' Freeze Protect w/ 80 Bbls of Diesel 5692' - 5757' 4510' - 4558' ~~~ 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. Cone DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results peter 20,AAC 250.071. . ~: A ''~~ None }~~/'~ 1 ~t 7 („ ~0 ~ 41~~ ~ A 4~OY Form 10-407 Revised 02/2007 ~ ~ /~ 1 n ~NTINUED ON REVERSE SIDE ~~ f y /' fi (1 /[~j ` 1;~ 1 (7 28. GEOL`JGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME M TVD Well Tested . ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1789' 1769' detailed test information per 20 AAC 25.071. Top Ugnu 3188' 2797' None Ugnu MA 4812' 3900' Ugnu MB1 4872' 3941' Ugnu MB2 4967' 4005' Ugnu MC 5069' 4074' Schrader Bluff NA 5170' 4142' Schrader Bluff NB 5203' 4165' Schrader Bluff NC 5247' 4195' Schrader Bluff NE 5257' 4202' Schrader Bluff NF 5335' 4256' Schrader Bluff OA 5391' 4295' Schrader Bluff OBa 5484' 4361' Schrader Bluff OBb 5543' 4403' Schrader Bluff OBc 5618' 4456' Schrader Bluff OBd 5688' 4507' Schrader Bluff OBe 5771' 4568' Schrader Bluff OBf 5831' 4613' Schrader Bluff OBf Base / 5893' 4660' Top Colville Mudstone Formation at Total Depth (Name): Colville Mudstone 5893' 4660' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the forego' g is true and correct to the best of my knowledge. ^ ~/ / W Signed Terrie Hubble Title Drilling Technologist Date ~/ PBU L-221 208-031 Prepared By Name/Number.~ Terrie Hubble, 564-4628 Well Number Permit No. / A royal NO. Drilling Engineer: Adrienne MCVey, 564-4184 INSTRUCTIONS GeNertAt.: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: L-221 Common Name: L-221 Test Date Test Type Test Depth (TMD) Test Depth (TVL)) AMW Surface Pressure Leak Off Pressure (BHP) EMW _ _- 4/2/2008 LOT 3,117.4 (ft) 2,752.5 (ft) 8.80 (ppg) 830 (psi) 2,088 (psi) 14.60 (ppg) 4/5/2008 LOT 3,117.4 (ft) 2,752.5 (ft) 9.10 (ppg) 450 (psi) 1,751 (psi) 12.25 (ppg) Printed: 4/27/2008 1:17:54 PN BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: L-221 Common Well Name: L-221 Spud Date: 3/28/2008 Event Name: DRILL+COMPLETE Start: 3/26/2008 End: 4/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/9/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task ,Code I' NPT ~I, Phase I Description of Operations 3/26/2008 16:00 - 00:00 I 8.00 MOB I P PRE Move pits away from rig. Install jeep on mud pits. Move mud 3/27/2008 00:00 - 02:00 2.00 MOB P PRE 02:00 - 07:00 5.00 MOB P PRE 07:00 - 09:30 2.50 RIGU P PRE 09:30 - 12:00 2.50 RIGU P PRE 12:00 - 15:30 3.50 RIGU P PRE 15:30 - 20:30 5.00 RIGU P PRE 20:30 - 00:00 3.50 RIGU P PRE 3/28/2008 00:00 - 02:00 2.00 RIGU P PRE 02:00 - 07:00 5.00 RIGU P PRE 07:00 - 10:00 3.00 RIGU P PRE 10:00 - 13:30 3.50 RIGU P PRE 13:30 - 14:00 0.50 RIGU P PRE 14:00 - 18:30 4.50 RIGU P PRE 18:30 - 19:30 1.00 RIGU P PRE 19:30 - 20:00 0.50 DIVRTR P PRE 20:00 - 20:30 0.50 RIGU P PRE 20:30 - 22:30 2.00 DRILL P SURF 22:30 - 23:45 1.25 DRILL P SURF 23:45 - 00:00 0.25 DRILL P SURF pits to L-pad. Bridle up derrick. Prepare for laying down derrick. Load out surface hydril. Move rig off of V-2231. Laydown derrick. Begin moving rig to L-pad. Continue moving rig to L-pad. Spot rig on end of pad. Nipple up diverter and diverter lines using crane. Set wellhead and tree equipment in cellar area. Appx 2 hours delayed due to crane electrical problems. Spot, set rig mats and herculite. Spot rig over conductor. Set mats under pipeshed end of rig. Level rig and berm. Spot mud pits. Had to remove ladder off of well house to spot pits. Raise derrick. Hook up interconnect. Set cuttings box. Berm mud pits and cuttings box. 'Rig accepted for operations ~ 07:00 hr, 3/27/2008; Time rolled back for diverter rig down on V-223i and rig up on L-221 i, plus time spent on removing ladder on well house. Load pipe shed with drill pipe. Take on Spud mud. Rig up rig floor equipment. Bridle down. Connect hydraulic service loop to topdrive. Install kelly hose. Install diverter riser and flowline. Chink up cellar. Install 4" ball valves on conductor outlets. Load drill pipe in pipe shed. Spot bulk gel trailers. Take on Spud mud. Rig up rig floor for picking up drill pipe. Perform post move derrick inspection. PJSM. Pick up 78 single joints of drill pipe and 24 joints of 4" HWDP, building stands and racking back in derrick. Bring BHA drilling tools to rig floor. PJSM. Make up Jar and DC stands and rack back in derrick. Make up BHA #1: New 12 1/4" HTC MXL-1X bit, 1.50' ABH XP motor, NM lead DC, NM Stab, MWD, NM Stab, X-over, UBHO sub. 'Held Pre-Spud safety meeting with Langham's crew prior to picking up BHA. PJSM. Rig up Sperry E-line and Gyro Data. Perform Diverter function and accumulator draw down tests. Witnessing of test was waived by AOGCC rep John Crisp. Test witnessed by BP WSL R. French and NAD TP S. Beard. Fill mud lines and conductor. Check for leaks - OK. Pressure test surface mud equipment to 3,500 psi - OK. Spud L-221 i ~ 20:30 hr, 3/28/2008. Drill from 108' to 271'.- 560 gpm, 680 psi off, 710 psi on, 80 rpm, .6k TO. 'Experienced a 350 bbls loss starting ~ -140 ft to -185'. Losses slowed down while drilling to 272'. 'No surface broaching. POH to 87'. Pick up DC and Jar stands. Run back in hole to bottom. No fill. Drill from 271' to 310'. 550 gpm, 910 psi off, 1,050 psi on, 80 rpm, .5k TO off, 1 k TO on. Printed: 4/21/2008 4:36:56 PM BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: L-221 Common Well Name: L-221 Spud Date: 3/28/2008 Event Name: DRILL+COMPLETE Start: 3/26/2008 End: 4/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/9/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task , Code NPT I Phase Description of Operations 3/28/2008 23:45 - 00:00 0.25 DRILL P SURF PU - 50k, SO - 48k, RWT - 48k, WOB - 10k. AST - 0.00 hrs, ART - 1.10 hrs. 'No losses 'Lost 350 bbls S ud mud for the da . 3/29/2008 00:00 - 12:00 12.00 DRILL P SURF Directionally drill 12 1/4" surface hole from 310' to 930'. Gyro survey every 100'. 550 gpm, 1,550 psi off, 1,650 psi on. 80 rpm, 2k TO off, 3k TO on PU - 75k, SO - 70k, RWT - 72k, WOB - 15k. MW - 9.2 ppg, Vis - 450 AST - 0.98 hrs, ART - 2.08 hrs. 12:00 - 22:30 10.50 DRILL P SURF Directionally drill 12 1/4" surface hole from 310' to 930'. Gvro surve eve 100'. Last G ro surve ~ 1 6 550 gpm, 1,865 psi off, 2,025 psi on. 80 rpm, 1.5k TO off, 4.1 k TQ on PU - 81 k, SO - 78k, RWT - 72k, WOB - 25k. MW - 9.2 ppg, Vis - 400 AST - 3.70 hrs, ART - 1.82 hrs. 22:30 - 23:30 1.00 DRILL P SURF Rig down Gyro Data and circulate 3 times bottoms up. 550 gpm, 1,785 psi, 80 rpm, 1.3k TO. Shakers cleaned up good after 2nd bottoms up. 9.2 ppg MW in and out. 23:30 - 00:00 0.50 DRILL P SURF Blowdown topdrive, observe well - OK. Start short trip to Jars from 1,620' to 953. Good trip. 10k maximum drag in just a few spots. No swabbing. 'No mud losses f r 3/30/2008 00:00 - 01:30 1.50 DRILL P SURF Continue wiper trip from 953' to 214' without problem. Observe well - OK. Run back in hole to 1,620' without problem. 01:30 - 13:00 11.50 DRILL P SURF Directionally drill 12 1/4" surface hole from 1,620'to TD ~ 3,127' MD, 2,758' TVD. 700 gpm, 3,000 psi off, 3,150 psi on. 80 rpm, 3k TO off, 4k TO on PU - 98k, SO - 75k, RWT - 86k, WOB - 25k. AST - 5.37 hrs, ART - 2.82 hrs MW - 9.4 ppg, Vis - 250 in, 350 out. 'Encountered h drates C~3 1 810' - 2 150' 2 29 ' 13:00 - 14:30 1.50 DRILL P SURF Circulate 3 times bottoms up ~ 700 gpm, 3,150 psi, 100 rpm, 3k TO. MW - 9.4 ppg in and out. Vis in - 250, Vis out 310. 14:30 - 17:00 2.50 DRILL P SURF Monitor well - OK. Blowdown topdrive. POH from 3,127' to 953' without problem. 17:00 - 17:30 0.50 DRILL P SURF Stand back HWDP, Jar and DC stands. 17:30 - 20:00 2.50 DRILL P SURF Laydown BHA #1. Bitgrade:2-2-WT-A-E-1 -PN-TD. 20:00 - 21:30 1.50 DRILL P SURF Clear rig floor of surface drilling tools. Clean floor. 21:30 - 00:00 2.50 CASE P SURF Rig up to run 9 5/8" surface casin . 'Lost 20 bbls on tri out of hole. 'Lost total of 370 bbls of s ud mud for surface interval. 3/31/2008 00:00 - 02:00 2.00 CASE P SURF Continue rigging up to run 9 5/8" surface casing. Make dummy casing hanger run. 02:00 - 12:00 10.00 CASE P SURF PJSM. Baker Lok and make up 9 5/8" 40# L-80 BTC casina shoe track. Check floats - OK. Continue running in hole with 9 5/8" surface casing to 3,086'. Fill every joint with Franks tool Printed: 4/21/2008 4:36:56 PM ~ ~ BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: L-221 Common Well Name: L-221 Spud Date: 3/28/2008 Event Name: DRILL+COMPLETE Start: 3/26/2008 End: 4/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/9/2008 Rig Name: NABOBS 9ES Rig Number: Date ~I From - To ', Hours Task ~ Code NPT ~ Phase Description of Operations 3/31/2008 02:00 - 12:00 10.00 CASE P SURF and top off every 10 joints. Make up torque - 9,500 fUlbs, using BOL 2000 NM pipe dope. Washed through tight spot ~ 2,050'. Make up casing hanger and landing joint. Land casing on de th~311 ' 'Lost 14 b l t t l 'n run Halliburton 9 5/8" Float Shoe set C~ 3,117' 2 Jts 9 5/8" 40# L-80 BTC Casing (#1- #2) Halliburton 9 5/8" Float Collar 2 Jts 9 5/8" 40# L-80 BTC Casing (#3) 9 5/8" 40# L-80 BTC Pup Jts (15.01' & 19.75') 73 Jts 9 5/8" 40# L-80 BTC Casing (#4-#75) 9 5/8" 40# L-80 BTC Hanger P x P Pup Jt. 9 5/8" Fluted Casing Hanger PU Wt - 155k, SO Wt - 90k w/ 35K Blocks Baker-Lok Shoe-track Jts #1-3 Bowsprings Centralizers: 1 on stop ring 5' above shoe on jt #1 1 on joints #2- #22 22 Total Centralizers 12:00 - 12:30 0.50 CEMT P SURF Rig down casing equipment. Make up 2 plug Dowell cement head and circulating hose. 12:30 - 16:00 3.50 CEMT P SURF Circulate and condition mud for cement job. Stage pumps up to 6 bpm, 380 psi ICP, 340 psi FCP. MW - 9.4 ppg, Vis - 75, PV - 15, YP - 18. R Initial circulating casing weights - PU - 105k, SO - 78k. Final circulating casing weights - PU - 141 k, SO - 116k. Held cementing PJSM while circulating. 'No mud losses 16:00 - 18:00 2.00 CEMT P SURF Switch to Dowell. Pump 5 bbls of fresh water. Pressure test lines to 4,115 psi - OK. Pump 74 bbls of 10.5 opa MudPush II spacer C~ 5.2 bpm avg, 200 psi ICP, 125 psi FCP. Drop bottom plug with positive indication of plug exit. Mix on the fly and pump 377 bbls of 10.7 ppg DeepCRETE cement @ 5.3 bpm avg, 150 psi ICP, 470 psi FCP. Batch mix and pump 66 bbls of 15.8 ppa Class "G" Tail cement C~ 5.4 bpm avg, 550 psi ICP, 410 psi FCP. 'Landed casing after 15 bbls of Tail cement awa due to stick down weight. PU - 156k, SO - 56k. Batch mix and pump 16 bbls of 16.3 ppg Class "G". DuraSTONE tail cement ~ 5.5 bpm, 390 psi ICP, 390 psi FCP. Drop top plug and kick out with 5 bbls of fresh water. Positive indication of plug exit. Printed: 4/21/2008 4:36:56 PM BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: L-221 Common Well Name: L-221 Spud Date: 3/28/2008 Event Name: DRILL+COMPLETE Start: 3/26/2008 End: 4/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/9/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To I, Hours Task 'Code' NPT ' Phase Description of Operations 3/31/2008 16:00 - 18:00 2.00 CEMT P SURF Switch to rig and displace cement with 225.5 bbls of 9.4 ppg Spud Mud C~ 6.5 bpm, 420 psi ICP, 815 psi FCP. Slow pump to 3 bpm, 5 bbls prior to bumping plug. 660 psi ICP, 685 psi FCP. Bump plug with 3,500 psi, 95.5% pump efficency. CIP ~ 17:53 hr. 'Returned 110 bbls of cement back to surface = 173% washout fact r. 'No mud losses 18:00 - 18:30 0.50 CEMT P SURF Hold 3 500 si on casin for casin test -Good. Bleed off pressure and check floats. Floats held, 18:30 - 21:30 3.00 CEMT P SURF Rig down casing and cementing equipment. Flush BOP stack. Laydown landing joint. Clean out under rotary table and drip pan. 'Sim Ops: Clean mud pits, change out liners on mud pumps to 5". Load drill pipe in pipe shed. 21:30 - 00:00 2.50 DIVRTR P SURF Nipple down surface diverter lines and riser. 4/1/2008 00:00 - 01:30 1.50 DIVRTR P SURF Nipple down surface diverter stack. Secure in cellar. 01:30 - 03:00 1.50 WHSUR P SURF Install casing head and tubing spool. Test metal to metal seals to 1,000 psi - 30 min - OK. Make up casing & tubing working valves. 03:00 - 08:00 5.00 BOPSU P SURF Nipple up BOPE stack. Change out from surface nipple to drilling nipple. Make up turnbuckles to riser. 08:00 - 08:30 0.50 BOPSU P SURF Service top drive. 08:30 - 09:00 0.50 CASE P SURF Secure stabbing board. Change out casing handling equipment. 09:00 - 11:00 2.00 BOPSU P SURF Make up BOPE floor equipment. Install test plug. Fill all testing lines. 11:00 - 14:30 3.50 BOPSU P SURF Test BOPE & Floor manifold to 250 si low and 4000 i hi Test Annular preventer to 250 psi low and 3500 psi high. Test manual choke and super choke to 1500 psi. Witness of test waived by AOGCC representative John Crisp. Test witnessed by NAD Toolpusher Ronnie Dalton. 14:30 - 16:30 2.00 BOPSU P SURF Rig down BOPE floor equipment. Remove test plug. Install wear ring. Blow down lines. 16:30 - 17:30 1.00 BOPSU P SURF RIH on picking up 33 drillpipe singles from pipe shed to 1,045' md. 17:30 - 18:30 1.00 BOPSU P SURF POH racking back 11 stands of 4" DP. 18:30 - 20:00 1.50 BOPSU P SURF RU to handle BHA #2. Bring all BHA componants to rig floor. 20:00 - 21:30 1.50 DRILL P PROD1 PJSM. Pick up BHA #2 - 8-3/4" Rebuilt HCM506Z PDC bit, 1.15 degree PDM motor, ARC6, MWD, ADN6, tea NM DC, Jars. Load nuclear source in ADN. Run in the hole with remaining BHA from the derrick to 370'. 21:30 - 22:00 0.50 DRILL P PROD1 Shallow test MWD ~ 370'. 500 gpm, 750 psi - OK. 22:00 - 00:00 2.00 DRILL P PROD1 RIH on drillpipe singles from shed from 370' - 2,160' md. 4/2/2008 00:00 - 01:00 1.00 DRILL P PROD1 RIH w/ 8.75" BHA #2 on singles from pipeshed from 2,160' - 2,735' md. 01:00 - 02:30 1.50 DRILL P PROD1 Wash down from 2,735' to 3,026'. Tag top of cement plugs on de th at 3 026' md. Drill cement, landing collar, and shoe track Printed: 4/21/2008 4:36:56 PM ~ ~ BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: L-221 Common Well Name: L-221 Spud Date: 3/28/2008 Event Name: DRILL+COMPLETE Start: 3/26/2008 End: 4/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/9/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To ', Hours Task '~i Code : NPT Phase Description of Operations 4/2/2008 01:00 - 02:30 1.50 DRILL P PROD1 to 3,111'. 02:30 - 03:00 0.50 DRILL P PROD1 Begin displacement to new 8.8 ppg LSND mud while drilling 03:00 - 04:00 I 1.001 DRILL I P I I PROD1 04:00 - 04:30 0.50 DRILL P PROD1 04:30 - 05:30 1.00 DRILL P PROD1 05:30 - 12:00 6.501 DRILL P PRODi 12:00 - 21:00 9.001 DRILL P PROD1 21:00 - 22:00 1.001 DRILL P PROD1 22:00 - 00:00 2.001 DRILL P PROD1 4/3/2008 100:00 - 04:30 4.501 DRILL P PROD1 04:30 - 08:00 3.50 DRILL P PROD1 08:00 - 08:30 0.50 DRILL P PROD1 08:30 - 09:00 0.50 DRILL P PROD1 09:00 - 16:00 7.00 DRILL N RREP PROD1 16:00 - 17:30 1.501 DRILL P PROD1 17:30 - 20:00 2.50 DRILL N RREP PROD1 20:00 - 22:00 2.00 DRILL P PROD1 last few feet of shoe track. Shut down and clean shaker system, possum belly and troughs of cement contaminated mud. Service topdrive and crown while cleaning pit area. Drill out shoe track and 20' of new hole from 3111' - 3,147' md. Perform leak off test to 830 psi EMW of 14.60 ppg. Take benchmark ECD readings. CECD =AECD = 9.35 ppg. Correction +0.2 ppg Directional drill 8-3/4" hole from 3,147' - 4445'. 585 gpm, 2100 psi on, 1815 psi off. 100 rpm, 5k tq on, 4k tq off. PU - 122k, SO - 84k. RTW - 96k. 5-10k WOB. CECD - 9.54 ppg, AECD - 10.38ppg. Backreamed full stands Pumped Hi-Vis sweep C«~ 4440', increased cuttings 25% Directional drill 8-3/4" hole from 4445' - 6050'. 585 gpm, 2850 psi on, 2560 psi off. 100 rpm, 6-7k tq on, 4-5k tq off. PU - 138k, SO - 93k. RTW - 109k. 15-20k WOB. CECD - 9.67 ppg, AECD - 10.48ppg. Backreamed 30' on connections AST- 2.25 ART- 6.98 Circulate one open hole volume. 25 bbl Hi-Vis Sweep pumped on last stand drilled brought back 5% increase in cuttings. 585 gpm, 2640 psi, 100 rpm, 6k tq. PU - 120k, SO -95 k. RTW - 115k. Begin backreaming Ghost reamer to casing shoe. As of 23:59, bit depth is 5,300' and (above ghost reamer depth ~ TD). 585 gpm, 100 rpm, 2642 psi, 6k TO. MW In 9.1 ppg ,Out 9.1 ppg Backream Ghost reamer into casing shoe and bit to 4,445' and (above ghost reamer depth ~ TD). 550 gpm, 100 rpm, 2050 psi, 5k TO. MW In 9.1 ppg ,Out 9.1 ppg Monitor well - OK. MW in 9.1 ppg, MW out 9.1 ppg. POH from 4,445' to 922'. No overpulls or swabbing seen while POOH. Pump dryjob ~ 3,115' md. Service topdrive and drawworks. Troubleshoot pipeskate malfunction. RU & Prepare floor for laying down BHA#2. Troubleshoot pipe skate. Suspect faulty solenoid -replace same. Lay down 22 joints of 4" HW DP from 992' to 247' and before pipe skate malfunctioned again. Troubleshoot pipe skate. PJSM w/ all hands, NAD Toolpushers Ronnie Dalton, Gary Hoffman, & BP WSL Matt Martyn. Stand back Jar stand. Lay down 1 ea DC to skate w/ tugger. Remove radioactive source from BHA#2. POH to bit w/ MWD & Motor in elevators. Bit grade: 4-2-BT-T-X-1-N R-TD. Printed: 4/21/2008 4:36:56 PM • BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: L-221 Common W Event Nam Contractor Rig Name: Date : ell Name: e: Name: From - To ~ L-221 DRILL+C NABOB NABOB Hours OMPLE S ALASK S 9ES I Task TE A DRI :Code LLING NPT Start I Rig Rig Phase Spud Date: 3/28/2008 : 3/26/2008 End: 4/9/2008 Release: 4/9/2008 Number: Description of Operations 4/3/2008 22:00 - 00:00 2.00 BOPSU P RUNPRD Close blind rams. Change out upper pipe rams from 3.F+" x t;" VBRs to 7". 4/4/2008 00:00 - 02:00 2.00 BOPSU N RREP RUNPRD Finish troubleshooting and repairing pipeskate. Found faulty electrical plug connection & repair. Contact point inside plug was disconnected and loose, but would make intermittant contact. Repair plug. 02:00 - 02:30 0.50 CASE P RUNPRD Bring casing handling equipment to floor. Prepare for casing run. 02:30 - 04:00 1.50 CASE P RUNPRD Break out and lay down to pipe shed remaining items of stood back BHA #2. 04:00 - 05:30 1.50 BOPSU P RUNPRD Ri u and test 7" rams to 250 si low & 4 000 si hi h - OK. Rig down test equipment. Test witnessed by NAD TP Gary Hoffman and BP WSL Matt Martyn. Witness of test waived by AOGCC rep Lou Grimaldi. 05:30 - 06:00 0.50 CASE P RUNPRD Make dummy run with 7" hanger and landing joint. Rig up to run casing. 06:00 - 08:00 2.00 CASE P RUNPRD Rig up power tongs, 350 ton elevators, stabbing board, and long bails. 08:00 - 12:45 4.75 CASE P RUNPRD PJSM. Pick up and make up (Baker Lok) 7" shoe track. Check floats - OK. Continue running in hole ~ 1.5 minutes per joint with 7" 26# L-80 BTC-M casing o 1,410'. 21 jts of BTC-M, 1 marker jt. w/ 3-pip RA tag, 12 jts of BTC-M and 1 crossover joint. Make up casing to mark with average make-up torque of 9,400 fUlbs. Used BOL-2000 NM pipe lubricant. Fill each joint. PU - 68k, SO - 62k ~ 1,410' 12:45 - 16:00 3.25 CASE P RUNPRD Rig up Torque turn equipment for TCII casing. Continue running in hole C~ 1.5 minutes per joint with 7" 26# L-80 TC-II casin from 1 524' t ', Fill each joint. Take PU/SO every 10 joints. Torque Turn casing to make-up torque of 10,100 ft/Ibs. Used JetLube Seal Guard pipe lubricant. 42 joints of TC-II casing run so far. PU - 100k, SO - 85k ~ 3,096'. 16:00 - 16:30 0.50 CASE P RUNPRD Circulate and Condition the mud pumping 1.5X bottoms up 5 Bpm with ICP of 485 psi and FICP of 350 psi No losses to well so far. Shut down and monitor well -static Up Wt. 100k Down Wt. 85K 16:30 - 17:15 0.75 CASE P RUNPRD Continue running in hole ~ 2 minutes per joint with 7" 26# L-80 TC-II casing from 3,096' to 3,358'. Slack off weights are decreasing once out of the casing shoe. Try to establish circulation @ 3 bpm w/ 840 psi. Initally had good returns, but returns fell off to a trickle and started pumping fluid awav. 17:15 - 20:00 2.75 CASE P RUNPRD Continue to work pipe while attempting to circulate. Continuously had at least 0.2 bpm returns that continued steadily even on casing connections w/o pumping. Circulate down each joint C~ 2 bpm, -800 psi and then reciprocate full joint again before making next connection. Eventually gained returns back and staged up pumps to 6 bpm ~s the hole _ 20:00 - 00:00 4.00 CASE P RUNPRD Continue running in hole ~ 2 minutes per joint with 7" 26# L-80 TC-II casing from 3,550' to 4,715'. Wash down every joint from 3,550 to 3,743' md. Afterwards, fill each joint and break circulation every 10 joints for 3 minutes. Torque Turn casing to make-up torque of 10,100 fUlbs. Used JetLube Seal Guard Printed: 4/21/2008 4:36:56 PM • BP EXPLORATION Operations Summary Report Page 7 of 10 Legal Well Name: L-221 Common Well Name: L-221 Spud Date: 3/28/2008 Event Name: DRILL+COMPLETE Start: 3/26/2008 End: 4/9/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/9/2008 Rig Name: NABORS 9ES Rig Number: Date From - To Hours 'Task Code NPT Phase Description of Operations 4/4/2008 20:00 - 00:00 4/5/2008 00:00 - 03:00 03:00 - 03:30 4.00 CASE P RUNPRD pipe lubricant. 84 total joints of TC-II casing run so far. 3.00 CASE P RUNPRD Continue running in hole ~ 2 minutes per joint with 7" 26# L-80 TC-II casing from 4,715' to 6,040'. Fill each joint and break circulation every 10 joints for 3 minutes. Circulate last 5 joints down ~ 5 bpm, 600 psi. Torque Turn casing to make-up torque of 10,100 ft/Ibs. Used JetLube Seal Guard pipe lubricant. 114 joints of TC-II casing run. 0.50 CASE P RUNPRD Pick up 7" hanger, landing joint and land casing on depth ~ 6,040', Up wt 195k Dn Wt 117k. HES Float Shoe - Bottom ~ 6,040' 2 Jts 7", 26#, L-80 BTC-Mod (#1-2) HES Landing Collar - Top ~ 5,955' 19 Jts 7", 26#, L-80 BTC-Mod (#3-21) 7", 26#, L-80 BTC-Mod Marker Pup Jt. w/ 3 pip RA tag ~ 5,157' 12 Jts 7", 26#, L-80 BTC-Mod (#13-36) 7", 26#,L-80 TC-II X BTC-Mod Crossover Pup. 114 Jts 7", 26#, TC-II (#1-114) 7" 26# L-80 TC-II Pup Jt. FMC Hanger Total of 76 - 7 1/8" x 8 1/4" Rigid Straight Blade Centralizers and 30 stop collars: 2 centralizers on shoe joint w/ stop ring 5' from shoe. BTC-M jts 3-30 have 2 free floating per joint separated by stop ring in middle. BTC-M Joint 2, 20' BTC-M marker jt, BTC-M joints 31-33, XO jt, & TC-II jts 1-12 have one free floating on entire joint. 03:30 - 04:00 0.50 CEMT P RUNPRD Rig down Frank's tool. Make up cementing head. 04:00 - 05:30 1.50 CEMT P RUNPRD Break circulation. Stage pumps up to 6 bpm, 650 psi. Condition mud for cementin .Held cementing PJSM while circulating. Reciprocate casing. PU - 170k, SO - 107k. Batch up cement. 05:30 - 06:30 1.00 CEMT P RUNPRD Switch to Dowell. Pump 5 bbls water. Pressure test lines to 4,000 psi - OK. Pump 24.5 bbls 10.0 ppg of MudPush II viscosified spacer C~3 5 bpm, 400 psi. Drop bottom plug and pump 70.2 bbls of Class "G" 15.8 ppg cement ~ 5 bpm avg, ICP - 486, FCP - 123 psi. Drop top plug and wash up through 'T' w/ 10 bbls H2O. Swap to rig pumps. Reciprocate pipe in 15' 06:30 - 07:15 0.75 CEMT P RUNPRD Switch to rig and displace cement with 228.3 bbls of 9.0 ppg brine. 1st 213 bbls ~ 5 bpm, 119 psi ICP, 1093 psi FCP. Reduce rate to 3 bpm ~ 213 bbls away - 1050 psi ICP, 1218 psi FCP. Bumped plug at 3,933 strokes. Stopped reci rocatin and landed casin ~ 3,800 strokes. PU - 140k, SO - 85k. CIP ~ 07:13 hr. Attempt pressure test to 4,000 ps but small leak. Bleed off pressure, check for flowback - OK. Full returns during all of circulating, cementing, and dis lacement. 07:15 - 08:30 1.25 CASE P RUNPRD Rig down cementing head, Rig up swedge to top of landing joint. Pressure test 7" casing to 4000 psi for 30 minutes - OI(. 08:30 - 09:30 1.00 EVAL P RUNPRD Close hydril on landing joint & conduct LOT w/ 5 bbls LSND Printed: 4/21/2008 4:36:56 PM • BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: L-221 Common Well Name: L-221 Spud Date: 3/28/2008 Event Name: DRILL+COMPLETE Start: 3/26/2008 End: 4/9/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/9/2008 Rig .Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/5/2008 08:30 - 09:30 1.00 EVAL P RUNPRD down 9-5/8" x 7" annulus to 12.24 ppg. Leak off pressure at 450 psi. 09:30 - 11:00 1.50 CASE P RUNPRD Back out landing joint. Lay down all casing and cementing equipment. 11:00 - 12:00 1.00 WHSUR P RUNPRD Install 7" Packoff and run in lock down screws. Torque to 450 ft-Ibs. Test to 5000 psi for 30 min., Good Test. 12:00 - 13:00 1.00 WHSUR P RUNPRD Drain BOP stack. RU lines for OA injection. Inject 2 bbls 9.0 ppg LSND down OA (~ 10 spm. 13:00 - 14:30 1.50 BOPSU P RUNPRD Change Upper Pipe Rams to 3 1/2 x 6 variables & prepare to test w/ 3.5" and 4" test joints to 4,000 psi. 14:30 - 17:30 3.00 BOPSU P RUNPRD Test upper ipe rams w/ 3.5" and 4" test joints to 250 psi low & 4,000 psi high. Test annular preventer w/ 3.5" test joint only to 250 psi low & 3500 psi high. `Note: Sim Ops - OA injection: Inject 88 bbls 9.1 ppg LSND mud total @ 0.5 bpm to flush annulus After UCA indicates 700+ compressive strength. 17:30 - 18:00 0.50 PERFO P OTHCMP RU equipment for DPC perforating. 18:00 - 20:30 2.50 PERFO P OTHCMP PJSM. Pick up and make up 4.5" HSD Power Jet 4505 5 SPF DPC erforatin uns (16 ea loaded or partial guns, 11 ea blanks, including 6 ea blank punchers), Firing head, XO, bumper sub, MWD, XO, 1-stand 4" DP, 5 ft pup joint. 20:30 - 00:00 3.50 PERFO P OTHCMP Run in hole with DPC pert assembly to 4,650' md. Attempt shallow hole test ~ 2,953 -failed. RIH and re-test at 3,500' and -good test 285 gpm, 630 psi. 4/6/2008 00:00 - 01:00 1.00 PERFO P OTHCMP Run in hole with DPC pert assembly & tag up on float collar at 5 953'. `Note all depths reported are to bottom nose. G/R sensor is 631ft up from bottom nose. 01:00 - 05:00 4.00 PERFO P OTHCMP Log to correlate depth to reference log -MWD Realtime field print 3-Apr-2008. Apply -2 ft correction. Log second pass. Apply +1 ft correction to second pass. Log into position & set on depth w/ Top shot ~ 5,204', Bottom nose ~ 5,763'. DPM. 05:00 - 06:00 1.00 PERFO P OTHCMP PJSM with all hands prior to firing guns. Perforate well. Initiate firing sequence by pump and bleed. Wait 5 minutes for guns to fire. Good indication of guns firing. Well initially lost 6 bbls then went on a 6 b h loss rate. 06:00 - 06:30 0.50 PERFO P OTHCMP POH 6 stands from 5,763' to 5,129' (above top pert) and circulate bottoms up 285 gpm, 500 psi. Brine returns only had a hint of pert smell. No other debris on bottoms up. Shut down, monitor well -losses -4 bph. Blow down top drive. 07:30 - 09:30 2.00 PERFO P OTHCMP Slip and cut 79' drilling line. Service topdrive 09:30 - 10:30 1.00 PERFO P OTHCMP POH Laying down drillpipe to pipeshed 1x1 from 5,129' - 4,340' md. 9.0 ppg brine in and out. Losses ~ 3 bph. 10:30 - 10:45 0.25 PERFO P OTHCMP RIH with remaining stands of drillpipe from derrick to 5,040' md. 10:45 - 15:30 4.75 PERFO P OTHCMP POH Laying down drillpipe to pipeshed 1x1 from 5,040' - 661' md. 15:30 - 21:00 5.50 PERFO P OTHCMP PJSM. Lay down all guns, crossovers & firing head. All shots fired er design. No shots seen outside of scallop. No trapped pressure in any-guns. BHA Magnets had -1/2" of pert debris on each magnet. 21:00 - 22:00 1.00 PERFO P OTHCMP Clean and clear rig floor of perforating equipment. Printed: 4/21/2008 4:36:56 PM ~ ~ BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: L-221 Common Well Name: L-221 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date From - Ta Hours Task -Code NPT 4/6/2008 22:00 - 00:00 4/7/2008 00:00 - 02:00 02:00 - 03:00 03:00 - 03:45 03:45 - 04:30 04:30 - 05:15 05:15 - 06:00 06:00 - 07:00 07:00 - 13:30 13:30 - 15:00 15:00 - 18:30 18:30 - 00:00 4/8/2008 100:00 - 07:00 Spud Date: 3/28/2008 Start: 3/26/2008 End: 4/9/2008 Rig Release: 4/9/2008 Rig Number: Phase Description of Operations 2.00 EVAL P OTHCMP PJSM. Rig up Schlumberger E-Line unit and 6.125" OD Gauge ring /Junk basket tools. 2.00 EVAL P OTHCMP RIH on E-Line w/ 6.125" OD GR to 500' md. 1.00 EVAL N HMAN OTHCMP Troubleshoot problem with wireline spool. 0.75 EVAL P OTHCMP Spool issue resolved. RIH w/ Gauge Ring to Tag TD. Set down ~ top perforations. 0.75 EVAL P OTHCMP Work through top set of perforations after several attempts. Hang up hard near top of second set of perforations. Work tool repeatedly. Overpull -900 Ibs to get free. After overpull, able to pass through. RIH through last 4 sets of perforations with resistance, but able to pass. Tag TD ~ 5,924' referenced to perforations. 0.75 EVAL P OTHCMP Begin POH from TD. Overpull -900 Ibs passing up through second set of erforations ~ -5 420' d. Work gauge ring through tight area 3 more times until overpull on way out reduced to 200 Ibs. Didn't see more than 100 Ibs slackoff to RIH past tight spot. 0.75 EVAL P OTHCMP POH w/ Gauge ring & Junk basket to surface. Only -1/4 cup of debris in Junk Basket after working tool through tight spots repeatedly. 1.00 EVAL P O THCMP Rig down gauge ring tools. Rig up USIT. 6.50 EVAL P O THCMP Run in hole with USIT logging tools to 5,900'. Log Hi-Res pass from 5,900' and to 4,600' md. Log standard resolution pass from 5,900' to surface for primary depth control. Logs indicated top of channeled cement stringers ~ -3,350', with unchanneled cement too C~ 3.710'. (Note: 9-5/8" casino shoe 1.50 EVAL P 3.50 BUNCO 5.50 BUNCO 7.00 BUNCO 07:00 - 18:30 11.50 RU 18:30 - 20:00 1.50 RU 20:00 - 22:00 2.00 RU 22:00 - 22:30 0.50 RU OTHCMP ig down Schlumberger E-Line unit. RUNCMP Pull wear bushing. Make dummy run w/ tubing hanger. Rig up tubing running and I-wire equipment. RUNCMP PJSM. Run in hole with completion jewelry to 338'. Baker Lok'd all connections below bottom packer. Test line connections to 5,000 psi - OK. Test I-wire continuity - OK. RUNCMP Continue RIH w/jewelry from 338' to 735' md. 5 GLM's for a total of 10 GLM's in the hole 2 HES packers for a total of 5 packer in the hole 3 X-Nipples for a total 6 X-Nipples in t o hole 2 NDPG for a total of 5 NDPG in the hole Torque turn all TCII connections to 2,300 ft/Ibs Loss rate 0.5 bbls/hr RUNCMP Run in hole with 3.5" 9.2# L-80 TCII tubing from 735' to 5,793'.. Test I-wire continuity every 1,000' - OK. Torque turn all TCII connections to 2,300 ft/Ibs No losses while runnin in the hole. Spaced out completion with 19.78' and 9.77' tubing pups. Total 162 joints of 3.5" 9.2# L-80 tubing run in hole. Strap in with joint 163. PUW = 85K, SOW = 60K RUNCMP Rig up to confirm space out of completion. PJSM. Rig up SLB E-line. RUNCMP Run in hole with GR/CCL logging tools and log in packers RUNCMP ~ Rig down SLB E-line Printed: 4/21/2008 4:36:56 PM • BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: L-221 Common Well Name: L-221 Spud Date: 3/28/2008 Event Name: DRILL+COMPLETE Start: 3/26/2008 End: 4/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/9/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/8/2008 22:30 - 00:00 1.50 BUNCO RUNCMP Lay-down tubing joint 163, change elevators to PU 4-1/2" landing joint, MU tubing hanger, and terminate I-wires. clamps used: Full = 93 /Half = 31. 4/9/2008 00:00 - 01:00 1.00 BUNCO RUNCMP Continue to terminate I-wires and run in hole and land tubing hanger. Run in lock down screws and torque to 450 ft/Ibs. 01:00 - 03:00 2.00 BUNCO RUNCMP Drop 1 5/16" ball & rod. Pressure to 4000 psi to set packers. Tes u ina o osi 30 min. Bleed tubina down to 2.500 4000 si for 30 min. Bleed annular pressure down to zero, bleed tubing pressure down to zero, pressure up annulus to 2,200 psi and shear DCR vavle. Pump 2 bbls both ways to confirm ability to pump. 03:00 - 04:00 1.00 WHSUR P RUNCMP Drain stack and dry rod two way check, test to 1,000 psi from below and chart for 10 minutes. 04:00 - 10:00 6.00 WHSUR P RUNCMP ND BOP. LD mouse hole & flow riser. CO bellnipple to 20" f/diverter. Stand back BOP on stump. NU Tree & adapter flange and test to 5000 psi f/10 minutes and chart. 10:00 - 11:00 1.00 WHSUR P RUNCMP Rig up and test DSM lubricator, pull TWC. 11:00 - 12:30 1.50 WHSUR P RUNCMP Displace well with clean brine and spotted inhibited brine per the wellplan. Reverse circulated down the 7" x 3-1/2" annulus at 6 bpm, 1180 psi, 248 total bbls 9.0 ppg brine (71 bbls w/corrosion inhibitor). 12:30 - 15:00 2.50 WHSUR P RUNCMP RU Little Reds and pressure tested lines to 2500 psi and pumped 80 bbls of diesel down the 7" x 3-1/2" annulus to reeze protect the well to -2200' TVD on both sides of tubing J -tu ed over top o we I . 15:00 - 17:00 2.00 WHSUR P RUNCMP RD U-tube lines. Intall BPV and test to 1000 psi f/10 minutes. Set VR plugs. 17:00 - 19:00 2.00 WHSUR P RUNCMP Clean and secure cellar. Disconnect inter-connect to pits and prep rig for move to L-220i. 19:00 - 00:00 5.00 WHSUR P RUNCMP RD diverter system and move to L-220i. Rig release from L-221 i at 24:00 hrs. Printed: 4/21/2008 4:36:56 PM ., L-221 S u Report Date: April 3, 2008 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: L-PAD / L-221 Well: L-221 Borehole: L-221 UWVAPI#: 500292338500 Survey Name /Date: L-221 /April 3, 2008 Tort /AHD / DDI / ERD ratio: 101.226° / 3142.56 ft / 5.605 / 0.658 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US feet Location LaULong: N 70 21 0.753, W 149 19 25.332 Location Grid NIE Y/X: N 5978127.270 ftUS, E 583299.400 ftUS Grid Convergence Angle: +0.63691624° Grid Swle Factor: 0.99990788 Report Schlumberger survey r uw ~ompurauon memos: Minimum curvature / LuDinsKi Vertical Section Azimuth: 174.290° Vertical Section Origin: N 0.000 ft, E 0.000 ft ND Reference Datum: Rotary Table ND Reference Elevation: 77.40 ft relative to MSL Sea Bed /Ground Level Elevation: 48.90 ft relative to MSL Magnetic Declination: 23.013° Total field Strength: 57646.485 nT Magnetic Dip: 80.883° Declination Date: March 31, 2008 Magnetic Declination Model: BGGM 2007 North Reference: True North • Total Corr Mag North -> True North: +23.013° Local Coordinates Referenced 70: Well Head Measured Vertical Along Hole Comments Inclination Azimuth SulrSea ND ND Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de OOft ftUS ftUS RTE O.UU U.UU U.UU -//.4U U.UU U.UU U.UU U.UU U.UU U.UU U.UU 59/tf11/.L/ 5t33L99.4U N /U 21 0.753 W 149 19 25.332 GYD CT DMS 100.00 0.15 291.79 22.60 100.00 -0.06 0.13 0.13 0.05 -0.12 0.15 5978127.32 583299.28 N 70 21 0.753 W 149 19 25.336 200.00 0.14 287.18 122.60 200.00 -0.17 0.38 0.38 0.13 -0.36 0.02 5978127.40 583299.04 N 70 21 0.754 W 149 19 25.343 300.00 0.43 346.29 222.60 300.00 -0.59 0.85 0.78 0.53 -0.57 0.38 5978127.80 583298.83 N 70 21 0.758 W 149 19 25.349 400.00 0.83 346.44 322.59 399.99 -1.68 1.95 1.80 1.60 -0.82 0.40 5978128.86 583298.56 N 70 21 0.769 W 149 19 25.356 500.00 1.21 357.69 422.58 499.98 -3.45 3.72 3.52 3.36 -1.04 0.43 5978130.62 583298.33 N 70 21 0.786 W 149 19 25.362 600.00 1.21 358.01 522.55 599.95 -5.56 5.83 5.58 5.47 -1.12 0.01 5978132.73 583298.22 N 70 21 0.807 W 149 19 25.365 700.00 0.65 11.71 622.54 699.94 -7.15 7.45 7.16 7.08 -1.04 0.60 5978134.34 583298.28 N 70 21 0.823 W 149 19 25.362 800.00 0.53 81.26 722.54 799.94 -7.72 8.36 7.72 7.71 -0.47 0.68 5978134.97 583298.85 N 70 21 0.829 W 149 19 25.346 900.00 0.88 110.08 822.53 899.93 -7.41 9.57 7.55 7.51 0.71 0.49 5978134.79 583300.03 N 70 21 0.827 W 149 19 25.311 1000.00 2.26 148.02 922.49 999.89 -5.30 12.22 6.10 5.58 2.48 1.66 5978132.88 583301.82 N 70 21 0.808 W 149 19 2 1100.00 3.23 155.65 1022.38 1099.78 -0.87 17.01 4.87 1.34 4.68 1.03 5978128.66 583304.07 N 70 21 0.766 W 149 19 2 1200.00 5.70 167.48 1122.07 1199.47 6.74 24.76 9.21 -6.08 6.92 2.62 5978121.27 583306.39 N 70 21 0.693 W 149 19 25. 1300.00 6.76 168.26 1221.47 1298.87 17.52 35.62 19.05 -16.69 9.20 1.06 5978110.69 583308.78 N 70 21 0.589 W 149 19 25.063 1400.00 11.40 167.67 1320.19 1397.59 33.20 51.39 34.46 -32.11 12.51 4.64 5978095.30 583312.26 N 70 21 0.437 W 149 19 24.967 1500.00 15.37 168.51 1417.46 1494.86 56.21 74.54 57.42 -54.76 17.26 3.97 5978072.71 583317.27 N 70 21 0.214 W 149 19 24.828 MWD+IFR+MS 1553.47 15.91 167.76 1468.95 1546.35 70.54 88.95 71.78 -68.87 20.22 .1.08 5978058.64 583320.39 N 70 21 0.076 W 149 19 24.741 1648.07 18.69 168.48 1559.26 1636.66 98.51 117.08 99.84 -96.40 26.00 2.95 5978031.18 583326.47 N 70 20 59.805 W 149 19 24.572 1743.42 20.73 169.59 1649.02 1726.42 130.53 149.24 131.93 -127.97 32.10 2.18 5977999.68 583332.92 N 70 20 59.494 W 149 19 24.394 1839.47 23.18 171.59 1738.10 1815.50 166.36 185.14 167.74 -163.40 37.94 2.67 5977964.32 583339.15 N 70 20 59.146 W 149 19 24.223 1935.14 25.93 171.15 1825.11 1902.51 206.06 224.89 207.40 -202.70 43.91 2.88 5977925.09 583345.56 N 70 20 58.759 W 149 19 24.049 2031.26 29.04 170.58 1910.37 1987.77 250.34 269.25 251.70 -246.49 50.97 3.25 5977881.39 583353.10 N 70 20 58.329 W 149 19 23.843 2126.13 31.94 170.18 1992.11 2069.51 298.35 317.38 299.81 -293.94 59.02 3.06 5977834.03 583361.67 N 70 20 57.862 W 149 19 23.607 SurveyEditor Ver SP 2.1 Bld( doc40x_100) L-221\L-221\L-221\L-221 Generated 5/8/2008 2:04 PM Page 1 of 3 Comments Measured Inclination Azimuth Sub-Sea TVD Typ Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de f10 ft ftUS ftUS LLL7.LL 35.:51 lb`J. Cb LU/I.C25 L14iS.biS :55U. 23:5 :5/V.U:S JbC.4b -.545 ./4 b25. 4:i J.btl 5y///25L. :Sb bi5:i:i/l. bti N /ULU S/. .ibi W 14~J1~J1:i.:i:52 2316.43 38.63 169. 49 2147.34 2224.74 407. 87 427.28 409.69 -402. 01 78. 98 3.49 5977726. 20 583382. 84 N 70 20 56. 799 W 149 19 23. 024 2412.28 41.55 170. 21 2220.66 2298.06 469. 41 489.00 471.41 -462. 76 89. 85 3.08 5977665. 58 583394. 38 N 70 20 56. 202 W 149 19 22. 707 2507.26 46.53 171. 54 2288.91 2366.31 535. 29 555.00 537.38 -527. 94 100. 28 5.33 5977600. 53 583405. 53 N 70 20 55. 561 W 149 19 22. 402 2602.28 50.50 170. 32 2351.85 2429.25 606. 34 626.17 608.52 -598. 21 111. 52 4.29 5977530. 39 583417. 55 N 70 20 54. 870 W 149 19 22. 073 2697.44 49.96 170. 48 2412.72 2490.12 679. 31 699.31 681.65 -670 .33 123. 72 0.58 5977458. 42 583430. 55 N 70 20 54. 160 W 149 19 21. 717 2791.73 49.65 172. 83 2473.58 2550.98 751. 25 771.33 753.62 -741. 58 134. 17 1.93 5977387. 30 583441. 80 N 70 20 53. 460 W 149 19 21. 411 2886.18 51.87 174. 97 2533.33 2610.73 824. 39 844.47 826.58 -814. 31 141. 93 2.93 5977314. 67 583450. 35 N 70 20 52. 744 W 149 19 21. 185 2980.27 52.53 173. 80 2591.00 2668.40 898. 73 918.82 900.73 -888. 29 149. 20 1.21 5977240. 78 583458. 45 N 70 20 52. 017 W 149 19 20. 972 3063.68 52.03 173. 33 2642.03 2719.43 964. 70 984.80 966.62 -953 .85 156. 60 0.75 5977175. 31 583466. 57 N 70 20 51. 372 W 149 19 20. 756 9-5/8" @3117'md 3148.50 50.99 174. 38 2694.82 2772.22 1031. 09 1051.18 1032.91 -1019 .86 163. 71 1.56 5977109. 39 583474. 42 N 70 20 50. 723 W 149 19 20 3242.90 49.50 174. 09 2755.18 2832.58 1103. 66 1123.76 1105.37 -1092 .06 170. 99 1.60 5977037. 28 583482. 51 N 70 20 50. 013 W 149 19 20. ~ 3338.23 48.13 175. 48 2817.96 2895.36 1175. 39 1195.50 1176.97 -1163 .50 177. 52 1.81 5976965. 92 583489. 83 N 70 20 49. 310 W 149 19 20. 145 3432.53 47.00 175. 35 2881.59 2958.99 1244. 98 1265.09 1246.40 -1232 .88 183. 09 1.20 5976896. 62 583496. 16 N 70 20 48. 628 W 149 19 19. 982 3527.59 45.59 175. 50 2947.27 3024.67 1313. 68 1333.81 1314.97 -1301 .38 188. 57 1.49 5976828. 19 583502. 40 N 70 20 47. 954 W 149 19 19. 822 3621.17 44.64 176. 56 3013.31 3090.71 1379. 95 1400.11 1381.09 -1367 .52 193. 16 1.29 5976762. 11 583507. 73 N 70 20 47. 303 W 149 19 19. 688 3715.23 43.73 174. 89 3080.76 3158.16 1445. 48 1465.67 1446.51 -1432 .89 198. 04 1.57 5976696. 81 583513. 34 N 70 20 46. 661 W 149 19 19. 546 3811.37 47.09 171. 88 3148.25 3225.65 1513. 91 1534.12 1514.94 -1500 .87 205. 98 4.14 5976628. 93 583522. 03 N 70 20 45. 992 W 149 19 19. 314 3906.83 46.47 172. 83 3213.62 3291.02 1583. 44 1603.68 1584.50 -1569 .81 215. 24 0.97 5976560. 10 583532. 05 N 70 20 45. 314 W 149 19 19. 043 4000.91 49.73 170. 96 3276.44 3353.84 1653. 38 1673.69 1654.51 -1639 .12 225. 14 3.77 5976490 .91 583542. 72 N 70 20 44. 632 W 149 19 18. 754 4097.28 50.37 170. 96 3338.32 3415.72 1727. 14 1747.57 1728.37 -1712 .08 236. 74 0.66 5976418 .09 583555. 14 N 70 20 43. 915 W 149 19 18. 415 4192.90 49.43 170. 50 3399.92 3477.32 1800. 14 1820.71 1801.49 -1784 .26 248. 52 1.05 5976346 .05 583567. 72 N 70 20 43. 205 W 149 19 18. 071 4287.19 48.56 171. 35 3461.78 3539.18 1871. 17 1891.86 1872.63 -1854 .53 259. 75 1.15 5976275 .92 583579. 72 N 70 20 42. 514 W 149 19 17. 743 4381.82 46.81 171. 83 3525.48 3602.88 1941. 06 1961.84 1942.60 -1923 .75 269. 99 1.89 5976206 .83 583590. 73 N 70 20 41. 833 W 149 19 17. 444 4477.15 46.64 171. 62 3590.83 3668.23 2010. 40 2031.24 2012.00 -1992 .43 279. 98 0.24 5976138 .26 583601. 48 N 70 20 41. 158 W 149 19 17. 152 4572.51 45.91 172. 07 3656.75 3734.15 2079. 25 2100.16 2080.92 -2060 .65 289. 75 0.84 5976070 .17 583612. 01 N 70 20 40. 487 W 149 19 16. 867 4669.09 45.70 174. 78 3724.08 3801.48 2148. 47 2169.40 2150.13 -2129 .42 297. 68 2.02 5976001 .49 583620. 71 N 70 20 39. 810 W 149 19 16. 635 4765.20 46.66 179. 20 3790.64 3868.04 2217. 71 2238.72 2219.19 -2198 .64 301. 30 3.46 5975932 .32 583625. 09 N 70 20 39. 129 W 149 19 16. 4860.44 47.24 178. 82 3855.65 3933.05 2287. 07 2308.32 2288.31 -2268 .22 302. 51 0.68 5975862 .76 583627. 07 N 70 20 38. 445 W 149 19 16 4954.92 48.08 180. 88 3919.29 3996.69 2356. 57 2378.15 2357.56 -2338 .05 302. 68 1.84 5975792 .95 583628. 02 N 70 20 37. 758 W 149 19 16. 5048.87 47.26 181. 59 3982.56 4059.96 2425. 51 2447.61 2426.26 -2407 .49 301. 19 1.04 5975723 .50 583627. 30 N 70 20 37. 075 W 149 19 16. 533 5144.55 46.99 181. 50 4047.66 4125.06 2495. 07 2517.72 2495.59 -2477 .58 299. 30 0.29 5975653 .40 583626. 19 N 70 20 36. 386 W 149 19 16. 588 5239.81 46.52 181. 00 4112.92 4190.32 2563. 95 2587.11 2564.30 -2546 .96 297. 78 0.62 5975584 .02 583625. 44 N 70 20 35. 704 W 149 19 16. 633 5335.23 45.67 181. 88 4179.09 4256.49 2632. 16 2655.86 2632.38 -2615 .68 296. 06 1.11 5975515 .29 583624. 48 N 70 20 35. 028 W 149 19 16. 683 5430.03 45.54 182. 35 4245.42 4322.82 2699 .27 2723.60 2699.38 -2683 .37 293. 56 0.38 5975447 .58 583622. 74 N 70 20 34. 362 W 149 19 16. 756 5525.00 44.86 181. 70 4312.34 4389.74 2766 .04 2790.99 2766.09 -2750 .72 291. 17 0.87 5975380 .22 583621. 10 N 70 20 33. 700 W 149 19 16. 826 5620.55 43.72 182. 32 4380.73 4458.13 2832 .15 2857.71 2832.16 -2817 .40 288. 84 1.28 5975313 .52 583619. 51 N 70 20 33. 044 W 149 19 16. 894 5715.68 42.72 182. 39 4450.05 4527.45 2896 .65 2922.85 2896.66 -2882 .49 286. 16 1.05 5975248 .41 583617. 56 N 70 20 32. 404 W 149 19 16. 972 5810.37 41.70 182. 66 4520.19 4597.59 2959 .62 2986.47 2959.64 -2946 .04 283. 36 1.09 5975184 .84 583615. 46 N 70 20 31. 779 W 149 19 17. 054 5905.04 40.88 182. 21 4591.32 4668.72 3021 .45 3048.94 3021.52 -3008 .45 280. 70 0.92 5975122 .41 583613. 50 N 70 20 31. 165 W 149 19 17. 132 Last Survey 5986.52 39.98 182. 13 4653.34 4730.74 3073 .80 3101.78 3073.92 -3061 .26 278. 70 1.11 5975069 .59 583612. 09 N 70 20 30. 646 W 149 19 17. 191 SurveyEditor Ver SP 2.1 Bld( doc40x_100) L-221\L-221\L-221\L-221 Generated 5/8/2008 2:04 PM Page 2 of 3 Measured Vertical Along Hole Comments Inclination Azimuth Sub-Sea TVD TVD Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft tt ft de 100 ft ftUS ftUS IU(F'rOJ@Cted) (iUSU.UU :iy.yt5 ltiL.l:i 4/Ul.yy 4//y.:iy J114.LU ;i14'1.5ti :i114.J/ -J1UL.UI 'L//.ly U.UU by/bU1tS.tS1 SiS;iti71.U1 N/U1U:iU.14S W145151/.L35 Survey Type: Definitive Survey NOTES: GYD CT DMS - (Gyrodata -cont. drillpipe m/s -- Gyrodata pump-down multishot surveys with continuous tool (RGS-CT) in drill-pipe.) MWD + IFR + MS - (In-field referenced MWD with mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) iftUSl Easting (Xl iftUSl Surface : 2404 FSL 3617 FEL S34 T12N R11 E UM 5978127.27 583299.40 BHL : 4582 FSL 3346 FEL S3 T11 N R11 E UM 5975028.82 583611.02 • SurveyEditor Ver SP 2.1 Bld(doc40x_100) L-221\L-221\L-221\L-221 Generated 5/8/2008 2:04 PM Page 3 of 3 TREE= 4-1/16" CNV WELLHEAlS = FM ACT~'JATOR LEO KB. ELEV = 77.4' BF. ELEV..- 51.51 KOP = _ .._300' Max Angle = 53° @ 2980' Datum MD = 5647' Datum TV D = 4400'. SS 20" CONDUCTOR, 91.5#, A-53, ID = 19.124" 108' ~9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" ~-i 311T ~ 7" CSG, 26#, L-80 TCII XO TO L-80 BTGM 4670' 7" X 3-1/2" HES DUAL FEEDTHRU PKR, ID = 2.965" 5117' Minimum ID (L-221) = 2.75" @ 5771' 3-1 /2" HES XN NIPPLE 7' MARKER JOINT w /RA PIP TAG 5157' 3-1/2" RA PIP TAG 5245' 17" X 3-1/2" HES SINGLE FEEDTHRU PKR, ID = 2.965" I-~ 5318' 7" X 3-1/2" HES DUAL FEEDTHRU PKR, ID = 2.965" I~ 5459' PERFORATION SUMMARY REF LOG: USIT LOG ON 04/07/08 ANGLE AT TOP PERF: 47 ° @ 5024' Note: Refer to Roduction DB for historical perf data SIZE SPF ZONE INTERVAL Opn/Sqz DATE 4-1/2" 5 Nb 5206 - 5228 O 04/06/08 4-1/2" 5 OA 5396 - 5448 O 04/06/08 4-1/2" 5 OBa 5487 - 5530 O 04/06/08 4-1/2" 5 OBb 5548 - 5568 O 04/06/08 4-1/2" 5 OBc 5622 - 5649 O 04/06/08 4-1/2" 5 OBd 5692 - 5757 O 04/06/08 3-1/2" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" H 5794' PBTD 5955' 7" CSG, 26#, L-80 BTGM, .0383 bpf, ID = 6.276" 6041' S NOTES: *** HES PKR @ 6328' IS "PULL TO L -~ ~ ~ REL E" BUT CAN BE RELEASED BY PRESSURE DO NOT EXCEED 4300 PSI. TEST PRESSURE PKR RATING = 5415 PSI (4332 PSI IS 80%OF PKR RATING)"** 24' 4-112" X 3-1/2" XO, ID = 2.992" 2721' 3-1/2" HES X NIP, ID = 2.813" GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 10 5068 4073 47 MMG DCR RKP 0 04/07/08 5096' 3-1/2" HES X NIP, ID = 2.813" 5131' 3-1/2" NDPG MULTI-SENSOR SUB , ID = 2.992 WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 5143 4124 47 MMG-W DMY RK 0 04/07/08 8 5236 4187 47 MMG-W DMY RK 0 04/07/08 7 5344 4263 46 MMG-W DMY RK 0 04/07/08 6 5438 4328 45 MMG-W DMY RK 0 04/07/08 5 5485 4362 45 MMG-W DMY RK 0 04/07/08 4 5516 4384 45 MMG-W DMY RK 0 04/07/08 3 5570 4422 44 MMG-W DMY RK 0 04/07/08 2 5641 4473 44 MMG-W DMY RK 0 04/07/08 1 5722 4532 43 MMG-W DMY RK 0 04/07/08 5297' 3-1/2" HES X NIP, ID = 2.813 5331' 3-1/2" NDPG MULT4-SENSOR SUB , ID = 2.992 5451' 3-1/2" HES X NIP, ID = 2.813" 5473' 3-1/2" NDPG MULTI-SENSOR SUB , ID = 2.992 5536' ~ 7" X 3-1/2" SINGLE FEEDTHRU PKR, ID = 2.965" 5549' ~ 3-1 /2" NDPG MULTI-SENSOR SUB , ID = 2.992 5562' I-13-1/2" HES X NIP, ID = 2.813" 17" X 3-1/2" SINGLE FEEDTHRU PKR, ID = 2.965" I -13-1/2" NDPG MULTI-SENSOR SUB , ID = 2.992 3-1/2" HES X NIP, ID = 2.813" 575--13-1/2" HES X NIP, ID = 2.813" 5772' 3-1/2" HES XN NIP, ID = 2.750" 5j 794' ~-13-1/2" WLEG, ID = 2.992" ELMD NOT LOGGED DATE REV BY COMMENTS DATE REV BY COMMENTS 04/09/08 N9ES ORIGINAL COMPLETION 04/21108 ?I PJC DRLG DRAFT CORRECTIONS 05/08/08 TW/PJC DRLG DRAFT CORRECTIONS ORION UNfr WELL: L-221 PERMfT No: 2080310 API No: 50-029-23385-00 SEC 34, T12N, R11 E, 2404' FSL & 1663' FWL BP Exploration (Alaska) a• d SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc Field ..................... Orion Well ...................... L-221 API number ................ 50-029-23385-00 Engineer .................. St. Amour Rig :...................... Nabors 9ES STATE :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 48.90 ft KB above permanent.......: NA (Topdrive) DF above permanent.......: 77.40 ft ----- Vertical section origin-------------- Latitude (+N/S-).......... 0.00 ft Departure (+E/W-)......... 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 174.29 degrees ~..m~~ ~_ ~ j "4 (; . °' -,mow ~ l ..,~~~~, ~/ r ~ `- ~.`''~.... l~~l ~_~ ~` ~ ~ r ti. c" 1/~ ~, `~' ,,, 3-Apr-2008 10 16: 2~~~ ~~ Page ~l of 4 ,~~~ ~. ' ~' J., %: `_ Spud date ................. 28-Mar-08 Last survey date.......... 03-Apr-08 Total accepted surveys...: 65 MD of first survey........ 0.00 ft MD of last survey........: 6050.00 ft • ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2007 Magnetic date ............. 28-Mar-2008 Magnetic field strength..: 57646.62 LAMA Magnetic dec (+E/W-).....: 23.02 degrees Magnetic dip .............. 80.88 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G ............... H ............... Dip ............. of G............ of H............ of Dip.......... Criteria --------- 1002.68 meal 57646.50 GAMA 80.88 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.01 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.01 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction a r SCHLUMBERGER Survey Report 3-Apr-2008 10:16:28 Page 2 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ # depth angle angle length depth section +N/S- +E/W- - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) --------- (ft) ------- 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2 100.00 0.15 291.79 100.00 100.00 -0.06 0.05 -0.12 3 200.00 0.14 287.18 100.00 200.00 -0.17 0.13 -0.36 4 300.00 0.43 346.29 100.00 300.00 -0.59 0.53 -0.57 5 400.00 0.83 346.44 100.00 399.99 -1.68 1.60 -0.82 Total At displ Azim (ft) (deg) -------------- 0.00 0.00 0.13 291.79 0.38 290.32 0.78 313.36 1.80 332.78 6 500.00 1.21 357.69 100.00 499.98 -3.45 3.36 -1.04 3.52 342.86 7 600.00 1.21 358.01 100.00 599.95 -5.56 5.47 -1.12 5.58 348.47 8 700.00 0.65 11.71 100.00 699.94 -7.15 7.08 -1.04 7.16 351.67 9 800.00 0.53 81.26 100.00 799.94 -7.72 7.71 -0.47 7.72 356.55 10 900.00 0.88 110.08 100.00 899.93 -7.41 7.51 0.71 7.55 5.42 11 1000.00 2.26 148.02 100.00 999.89 -5.30 5.58 2.48 6.10 23.96 12 1100.00 3.23 155.65 100.00 1099.78 -0.87 1.34 4.69 4.87 74.04 13 1200.00 5.70 167.48 100.00 1199.47 6.73 -6.08 6.92 9.21 131.27 14 1300.00 6.76 168.26 100.00 1298.87 17.52 -16.69 9.20 19.05 151.14 15 1400.00 11.40 167.67 100.00 1397.59 33.20 -32.11 12.51 34.46 158.72 16 1500.00 15.37 168.51 100.00 1494.86 56.21 -54.76 17.26 57.42 162.51 17 1553.47 15.91 167.76 53.47 1546.35 70.54 -68.87 20.23 71.78 163.63 18 1648.07 18.69 168.48 94.60 1636.66 98.51 -96.40 26.00 99.84 164.90 19 1743.42 20.73 169.59 95.35 1726.42 130.53 -127.97 32.10 131.93 165.92 20 1839.47 23.18 171.59 96.05 1815.50 166.36 -163.39 37.94 167.74 166.93 21 1935.14 25.93 171.15 95.67 1902.51 206.06 -202.70 43.91 207.40 167.78 22 2031.26 29.04 170.58 96.12 1987.77 250.34 -246.49 50.97 251.70. 168.32 23 2126.13 31.94 170.18 94.87 2069.51 298.35 -293.94 59.02 299.81 168.65 24 2221.22 35.31 169.26 95.09 2148.68 350.83 -345.74 68.43 352.45 168.80 25 2316.43 38.63 169.49 95.21 2224.74 407.87 -402.01 78.98 409.69 168.88 26 2412.28 41.55 170.21 95.85 2298.06 469.41 -462.76 89.85 471.41 169.01 27 2507.26 46.53 171.54 94.98 2366.31 535.29 -527.94 100.28 537.38 169.24 28 2602.28 50.50 170.32 95.02 2429.25 606.34 -598.21 111.52 608.52 169.44 29 2697.44 49.96 170.48 95.16 2490.12 679.31 -670.33 123.72 681.65 169.54 30 2791.73 49.65 172.83 94.29 2550.98 751.25 -741.58 134.18 753.62 169.74 DLS Srvy Tool (deg/ tool Corr 100f) type (deg) 0.00 TIP None 0.15 BP_GYD CT DMS 0.02 BP_GYD CT DMS 0.38 BP_GYD CT DMS 0.40 BP GYD CT DMS 0.43 BP_GYD CT DMS 0.01 BP_GYD CT DMS 0.60 BP_GYD CT DMS 0.68 BP_GYD CT DMS 0.49 BP GYD CT DMS 1.66 BP_GYD CT DMS 1.03 BP_GYD CT DMS 2.62 BP_GYD CT DMS 1.06 BP_GYD CT DMS 4.64 BP GYD CT DMS 3.97 BP_GYD CT DMS. 1.08 BP_MWD+IFR+MS 2.95 BP_MWD+IFR+MS 2.18 BP_MWD+IFR+MS 2.67 BP MWD+IFR+MS 2.88 BP_MWD+IFR+MS 3.25 BP_MWD+IFR+MS 3.06 BP_MWD+IFR+MS 3.58 BP_MWD+IFR+MS 3.49 BP MWD+IFR+MS 3.08 BP_MWD+IFR+MS 5.33 BP_MWD+IFR+MS 4.29 BP_MWD+IFR+MS 0.58 BP_MWD+IFR+MS 1.93 BP MWD+IFR+MS • f " SCHLUMBERGER Survey Report 3-Apr-2008 10:16:28 Page 3 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2886.18 51.87 174.97 94.45 2610.73 824.39 -814.30 141.93 826.58 170.11 2.93 BP MWD+IFR+MS 32 2980.27 52.53 173.80 94.09 2668.40 898.73 -888.29 149.20 900.73 170.47 1.21 BP _ MWD+IFR+MS 33 3063.68 52.03 173.33 83.41 2719.43 964.70 -953.85 156.60 966.62 170.68 0.75 BP _ MWD+IFR+MS 34 3148.50 50.99 174.38 84.82 2772.22 1031.09 -1019.86 163.71 1032.91 170.88 1.56 BP _ MWD+IFR+MS 35 3242.90 49.50 174.09 94.40 2832.58 1103.66 -1092.06 171.00 1105.37 171.10 1.60 BP _ MWD+IFR+MS 36 3338.23 48.13 175.48 95.33 2895.36 1175.39 -1163.50 177.53 1176.97 171.32 1.81 BP MWD+IFR+MS 37 3432.53 47.00 175.35 94.30 2958.99 1244.98 -1232.88 183.09 1246.40 171.55 1.20 BP MWD+IFR+MS • 38 3527.59 45.59 175.50 95.06 3024.67 1313.68 -1301.38 188.57 1314.97 171.76 1.49 BP _ MWD+IFR+MS 39 3621.17 44.64 176.56 93.58 3090.71 1379.95 -1367.52 193.17 1381.09 171.96 1.29 BP _ MWD+IFR+MS 40 3715.23 43.73 174.89 94.06 3158.16 1445.48 -1432.89 198.04 1446.51 172.13 1.57 BP _ MWD+IFR+MS 41 3811.37 47.09 171.88 96.14 3225.65 1513.91 -1500.87 205.98 1514.94 172.19 4.14 BP MWD+IFR+MS 42 3906.83 46.47 172.83 95.46 3291.02 1583.44 -1569.81 215.24 1584.50 172.19 0.97 BP _ MWD+IFR+MS 43 4000.91 49.73 170.96 94.08 3353.84 1653.38 -1639.12 225.14 1654.51 172.18 3.77 BP _ MWD+IFR+MS 44 4097.28 50.37 170.96 96.37 3415.72 1727.14 -1712.08 236.74 1728.37 172.13 0.66 BP _ MWD+IFR+MS 45 4192.90 49.43 170.50 95.62 3477.31 1800.14 -1784.26 248.52 1801.49 172.07 1.05 BP _ MWD+IFR+MS 46 4287.19 48.56 171.35 94.29 3539.18 1871.17 -1854.53 259.75 1872.63 172.03 1.15 BP MWD+IFR+MS 47 4381.82 46.81 171.83 94.63 3602.88 1941.06 -1923.74 269.99 1942.60 172.01 1.89 BP _ MWD+IFR+MS 48 4477.15 46.64 171.62 95.33 3668.23 2010.40 -1992.43 279.98 2012.00 172.00 0.24 BP _ MWD+IFR+MS 49 4572.51 45.91 172.07 95.36 3734.15 2079.25 -2060.64 289.75 2080.92 172.00 0.84 BP _ MWD+IFR+MS 50 4669.09 45.70 174.78 96.58 3801.48 2148.47 -2129.42 297.68 2150.13 172.04 2.02 BP _ MWD+IFR+MS 51 4765.20 46.66 179.20 96.11 3868.04 2217.71 -2198.64 301.30 2219.19 172.20 3.46 BP MWD+IFR+MS 52 4860.44 47.24 178.82 95.24 3933.05 2287.07 -2268.22 302.51 2288.31 172.40 0.68 BP _ MWD+IFR+MS 53 4954.92 48.08 180.88 94.48 3996.69 2356.56 -2338.05 302.68 2357.56 172.62 1.84 BP _ MWD+IFR+MS 54 5048.87 47.26 181.59 93.95 4059.96 2425.51 -2407.49 301.19 2426.26 172.87 1.04 BP _ MWD+IFR+MS 55 5144.55 46.99 181.50 95.68 4125.06 2495.07 -2477.58 299.30 2495.59 173.11 0.29 BP _ MWD+IFR+MS 56 5239.81 46.52 181.00 95.26 4190.32 2563.94 -2546.95 297.78 2564.30 173.33 0.62 BP MWD+IFR+MS 57 5335.23 45.67 181.88 95.42 4256.49 2632.16 -2615.68 296.06 2632.38 173.54 1.11 BP _ MWD+IFR+MS 58 5430.03 45.54 182.35 94.80 4322.82 2699.26 -2683.37 293.56 2699.38 173.76 0.38 BP _ MWD+IFR+MS 59 5525.00 44.86 181.70 94.97 4389.74 2766.04 -2750.72 291.17 2766.08 173.96 0.87 BP _ MWD+IFR+MS 60 5620.55 43.72 182.32 95.55 4458.13 2832.15 -2817.39 288.84 2832.16 174.15 1.28 BP _ MWD+IFR+MS SCHLUMBERGER Survey Report 3-Apr-2008 10:16:28 Page 4 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5715.68 42.72 182.39 95.13 4527.45 2896.65 -2882.48 286.16 2896.65 174.33 1.05 BP_MWD+IFR+MS 62 5810.37 41.70 182.66 94.69 4597.59 2959.61 -2946.04 283.36 2959.63 174.51 1.09 BP_MWD+IFR+MS 63 5905.04 40.88 182.21 94.67 4668.72 3021.45 -3008.45 280.70 3021.52 174.67 0.92 BP_MWD+IFR+MS 64 5986.52 39.98 182.13 81.48 4730.74 3073.79 -3061.25 278.70 3073.91 174.80 1.11 MWD+IFR+MS BP 65 6050.00 39.98 182.13 63.48 4779.39 3114.20 -3102.01 277.19 3114.37 174.89 0.00 _ Projected to TD • [(c)2008 IDEAL ID13 OC 05] ~ Page 1 of 2 • AAaunder, Thomas E (DOA) Fram: Maunder, Thomas E (DOA) Sent: Thursday, July 31, 2008 11:23 AM To: 'Tirpack, Robert B' Cc: Sayers, Zach J; Kolstad, Scott R Subject: RE: L-221 (208-031) Thanks Rob. I figured the OA had been #reeze protected, but there was no mention in the operations log. I will place a copy of this information in the file. Tom Maunder, PE AOGCC From: Tirpack, Robert B [mailto:Robert.Tirpack@bp.com] Sent: Thursday, July 31, 2008 9:49 AM To: Maunder, Thomas E (DOA) Cc: Sayers, Zach ]; Kolstad, Scott R Subject: RE: L-221 (208-031) Tom, I reviewed DIMS and there is no mention of freeze protecting the OA. We contacted Little Red Hot Oil Service and got a copy of their job ticket (attached). A total of 65 bbls of dead crude was pumped on L-221 for freeze protection on 04/05/08. I will have DIMS updated. Please call with any questions or if you need anything else. Regards, Rob Tirpack. Engineering Team Lead GPB Rotary - WRD 907-564-4166 office 907-440-8633 cell tirpacrb@bp.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, July 28, 2008 11:31 AM To: Tirpack, Robert B Subject: RE: L-221 (208-031) Thanks Rob. Just seemed strange to read the ops summary and not see freeze protection of the OA no conducted with the rig over the well. Tom From: Tirpack, Robert B [mailto:Robert.Tirpack@bp.com] Sent: Monday, July 28, 2008 11:26 AM To: Maunder, Thomas E (DOA) Cc: McVey, Adrienne '7/31 /2008 Page 2 of 2 Subject: RE: L-221 (208-031) Tom -Adrienne has transferred to the slope as a Well Site Leader. Let me re-assign this well to a new drilling engineer and get back with you. Thanks, Rob From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sant: Friday, July 25, 2008 8:11 AM To: McVey, Adrienne Cc: Tirpack, Robert B Subject: L-221 (208-031) Adrienne and Rob, I was reviewing the completion report for this welt. Reading the operations report, I did not find that the 9-5/8" x 7" annulus was freeze protected. Atone point the annulus is displaced with mud, however 1 did not find anything where a "non-freezing fluid" had been pumped. t suspect that the freeze protection did occur, but wanted to confirm. Thanks in advance. Tom Maunder, RE AOGCC 7/31/2008 • LITTLE RED SERVICES, INC. formerly Hot Oil Service Company 9740 Vanguard Rd -Anchorage, Alaska 99516 (907) 659-2390 - (907)349-29Gi1 LOCATION: L-221 COMPANY REP.' DSfJr ~ OPERATOR: T. Schmitt ~ DATE: 4/5/2008 COMPANY: Nataors UNIT #: 46 RIGGED TO: OA JOB TYPE: Freeze Protect COMMENTS: Max PSI on OA is 3000 psi per y man Initial TBG,Ul,OA -> TIME B.P.M. BBLS FLUID TEMP TBG IA OA COMMENTS 21:00 Start Ticket 21:10 Load crude at FS1 21:50 Finished loading crude 21:55 Road to location 22:30 Arrive on location 22:50 PJSM, RU to OA 12:30 PT to 3000 psi 12:34 2 st crude 70`f 1100 Start w/crude down OA 12:38 2 5 1450 12:35 2 20 1450 12:51 2 30 1450 12:56 2 40 1450 1:01 2 50 1450 1:09 2 65 1450 SD, RD 2:00 End Ticket Final TBG, 44, OA:-->~ TOTAL FLU/D5 PUMPED: FLUID TYPE TOTAL BBLS CRUDE 65 DIESEL METH Water P:\Groups\Wells Group\Administration\FormslWelMmrk Forms L-221 FP Nabors 9es.xls • ~f~~ `~ V ~ 7~ I~G:iA.NIGAL 3NTEGRITY ~ SPORT - LUD L'_I~ : ~~ _ `s OPER ~ FIEL~J ~ ~ ~~~~~~~ ~F ~Gh nr LL DATC TD . ~~~ ~.?-~.. ~~~ 1 TVD ; ?BTD _ ~~~ ~ ?ZD ~~G~ TVD ~r~ Casing : Shoe : ~ `~rtID ~°\'1~ TVD ; L~l : S.~t~ ?~ ~~_.?ti~i ~_:~e, . ~ ~ Shoe . ~ ~ ' ~ T~~ ; ,:.CP . '_-~ 'iJ ~ •-r..~+ :;.ioz._:g _Paci~e~ ~~,~'~ y~~~'L"~i ; Set et _ ~~~L~ :ale S_ie -~ ana ~ (~. Peril ~ ~ ~, to j'l ~ "1 ~~ tic=.P?~IC~.~ l.~iTEGc'~?'TY - ? A.RT # 1 rnnu.lus ?ress Test: _? 15 rein ?,0 min. Comments . ~k,'"d~ .~~~.~~ ~= ~.~,r-r~, ~.~~~, ~~il}~.~`~ \~~ ~ s~~: y J ~ /~ :'~CHANIC?_I., 1NTEGRTT~ -PART #2 ~~~hh~5 Cement Volumes : r~.mt. miner lip. ; Csg ~3~5~ DV ~[~ . Cwt Jol to cove^ ~eris ~ ~hZt,`1C,~ `'1b h~5 ~vC.C~-C T' ~`--~ "'~-S~~ heo4 e tical TCC ~ 3~ Z c: X ~ t'G ~. `'lC-~~ Cement Bond Log (Yes or No) ~~5 In AOGCC ~'ile~~ CBL Evaluation, gone abo~ perfs l.,~<;~ t~r~..•\~ `'~~ ~ ~ Production i.og: Type CON~LJSi0i1S ax t :1 . ~ar~ r~ ~,~• y\S ~ - ~~~t~ ~ ~-~ . Evaluation 06/25/08 ~chlumbcr~er NO.4750 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wa_II .Inh # Inn 1lasrri ntinn rlafo RI r`nlnr !`r1 P1-12 11978462 STATIC PRESS & TEMP _ lv7 ~f' ~' ~ ~ 08/01/08 1 1 X-12 11978466 PRODUCTION PROFILE -- ~`~', J ~' 06/04/08 1 1 G-05 12017499 PRODUCTION PROFILE j .- ~' .,,- ~~ °'°~ •^- ~ 06/12/08 1 1 E-14A 12034899 SCMT j ~9"?• .a ~%`~ 06/10/08 1 1 MPH-17 12066526 MEM INJ PROFILE !, '7 "'"},° ~2 ~ ~ ~ ~" 05/26/08 1 1 L-220 11975763 CH EDIT PDC GR (USIT) REVISED CD'S ONLY, , ~ r r°t_ 04/22/08 1 ` L-220 40016915 OH MWD/LWD EDIT ~ •° _ °-i-;r. ~"`° ~- 04/18!08 3 ,~1'=~. )~~. ' -~,, ~ ~~ ' L-221 40016787 OH MWD/LWD EDIT 04/03/08 3 1 01-01C 40015644 OH MWD/LWD EDIT •m~°~-}- "~'~,~) ~ (~, P`° ~°~. 08/15/07 2 1 G-19B 40015844 OH MWD/LWD EDIT~ty""r~ -- ~ ~~ ""°~"s,;;, 10/20/07 2 1 X-17 12057619 RST t..._ ~;! ~/ _<~~~)~, ~ 05/24/08 1 1 L3-11 11966254 RST " ''r'~ .- ""'i~ ~l' ~"^ i^I"~'° 05/01/08 1 1 Y-36 12014013 RST 1 -'°? >- `? d +` ~-_~ ~'.` 05/11/08 1 1 P2-37A 11216182 MCNL :_ ~°-•- ~rn='+~~`,,_ 03/17/08 1 1 05-34A 40016888 OH MWD/LWD EDIT " ~ ~'~ .-. ~^='- /° `'°!''- 04/27/08 2 1 r'i..GNJG MV n.1YV YYLCUl7C ACV CIrI Di .71L1IVIrvu AIVU CfCI VFf IVIIVU VIVC Gl1YT CHVI'1 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 - - 900 E. Benson Blvd. Anchorage, Alaska 99508 ~, " _ II Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 40A Anchorage, AK 99503-28,x8 ATTN: Beth ` , ° Received b . '' Y _- •I t5 os/oa/os ~chCum~erg~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wc+ll _Inh ~ N0.4736 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 n. L-220 11975963 CH EDIT PDC GR (USIT) / 04/22/08 1y L-221 11962592 CH EDIT PDC GR (USIT) 04/07/08 1 V-223 40016679 OH MWD/LWD EDIT ^ 03/20!08 2 1 W-30 12034892 RST ~ -/ [/ 04/11/08 1 1 G-11B 11963085 MCNL ~~- / 04/01/08 1 1 05-28B 11649987 MCNL (,e- 08/17/07 1 1 P2-36A 11209594 MCNL - 03/26/06 1 1 07-018 12021155 MCNL `jj~ 04/28/08 1 1 05-34 11966251 CH EDIT PDC GR (USIT) 04/13/08 1 17-12 12057613 PRODUCTION PROFILE - ~ 05/23/08 1 1 W-31 11999015 LDL 05/25/08 1 1 GNI-02A 12057618 PRESS/TEMP SURVEY (o - 3 $ 05/24/08 1 1 13-12 11982434 USIT _ L ~~ 05/29/08 1 1 DI CACG Al~Il AIA~nII cnn~ n BP Exploration (Alaska) Inc.---__~~ ~ _. _._....._ ....-. „_.,,.......~ ,,.,",,,, ",~., ,.,. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ii i~~i ¢ i Date Delivered: - Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ATTN: Beth Received by: 04/25/08 ~~ii11~~U~i~~r~ NO.4673 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Joh # 1 nn r)ascrintinn n~to a~ rnb., rn 2-52/S-14 11846807 PRODUCTION PROFILE (REDO) 08/18/07 1 1 F-22 12005209 MEM TEMP SURVEY 04/08/08 1 1 MPB-09 11963093 MEM PROD PFOFILE ~ 04/13/08 1 1 MPL-33 11963090 MEM INJECTION PROFILE ~ 04/11/08 1 1 MPF-89 11963092 MEM TEMP SURVEY 04/12/08 1 1 L5-29 11963087 MEM TEMP SURVEY ^`Q 04/04/08 1 1 S-26 12071843 SBHP SURVEY ~ 04/03/08 1 1 06-15 11962594 LDL ~ _ (0 04/09/08 1 1 W-30 12034892 PROD PROFILE Itt~tf~l3L J~,~.~, 04/11/08 1 1 L-221 11962592 USIT/CBL ~ZC ~a~ _ ~ ( ~(~~ 04/07/08 1 1 4-14A/S-37 11970818 CH EDIT PDC GR JEWELRY 'br_ / 03/24/08 1 18-328 11978442 MCNL - at C 02/26/08 1 1 G-24A 11660525 MCNL 4C' 02/02/07 1 1 ~~.+.+~ .... \.\...... ~\.,v~a a- nwur \ v \ JIVIY\IYbI NIYY nGl Vn1Y11Y1P VIYG liVr'i CNVri 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 - 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ ~ ~;j Z~~ • • Alaska Data & Consulting Service 2525 Gambell Street, Suite 40 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~~- ~~ ~ ~ Schlumberger Private a ~g- ~3r /~ t~~ g w a ~- z ~ O w ~ ~ ~ ~ O ~ = z m w a w O c N N a Z O v N J m T L C ~ r~ O a o ~a ~ E m° ~ ~ ~ U 50-029 2 3385-0 Logging Date 7- r-; Run Number 1 Depth Driller 5953 fi Schlumberger Depth 5924 fl Bottom Log Interval 5900 fl Top Log Interval 200 tt Casing Fluid Type BRINE Satin' Dens' 9 Ibml Fluid Level 0 ft BIT/CASING/TUBING STRING Bit Size 8.750 From To Casin /Tubin Size 7.000 Wei ht 261br Grade L-80 From 0 ft To 6040 Maximum Recorded Temperatures Logger On Bottom Time 7-Api Unit Number Location Recorded B 2128 A. SF Witnessed By M. M USIT/CBL CEMENT LOG CCUGR/USIT 07 -APRIL-2008 2404' FSL &3617' FEL AT SURFACE Permanent Datum: MEAN SEA LEVEL Log Measured From: KELLY BUSHING Measured From: Drillin KELLY BUSHING g API Serial No. Section 0 ~ ;008 In in t -2008 4:45 PRUDHOE BAY CHIVICHIK/B. DICKINSON Elev.: K.B. n•4 ~ G.L D.F. Elev.: 0.00 tt 77.4 RT above Perm: Datum Township I Range 12N 11E 7`, J'~~~~'d ~ u !~ ~I~,^, ~~Q'SG~ ALASSA OIL A1~TD GA5 CO1~T5ERYATIOI~T COMA'II5SIOI~T Robert Tirpack Engineering Team Leader BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Orion Oil Pool, PBU L-221 BP Exploration (Alaska) Inc. Permit No: 208-031 SARAH PAt/N, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Surface Location: 2404' FSL, 3617' FEL, SEC. 34, T12N, R11E, UM Bottomhole Location: 666' FNL, 3316' FEL, SEC. 03, T11N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. '"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). Sincerely, Daniel T. Seamount, Jr. ry f~ Chair DATED this' o day of March, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL ~~C,~ 20 AAC 25.005 FEB ~ '~ ~~ Alaska ail ~t Ces Cans Cotr~i3~~~n w,~..L.. 1 a. Type of work ® Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is propose o ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU L-221 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD ~~ 5984 TVD, 4740 12. Field /Pool(s): ,* Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 3617' FEL 2404' FSL SEC 34 T12N R11 E UM 7. Property Designation: ~ ADL 028241 Schrader Bluff ; , . , , , Top of Productive Horizon: 97' FNL, 3309' FEL, SEC. 03, T11N, R11E, UM 8. Land Use Permit: 13. Approximate Spud Date: March 20, 2008 Total Depth: 666' FNL, 3316' FEL, SEC. 03, T11 N, R11 E, UM 9. Acres in Property: ~ 2560 14. Distance to Nearest Property: 7240' 4b. Location of Well (State Base Plane Coordinates): Surface: x-583299 y-5978127 Zone-ASP4 10. KB Elevation Plan (Height above GL): 77.3 feet 15. Distance to Nearest Well Within Pool: 808' 16. Deviated Wells: Kickoff Depth: ' 900 feet Maximum Hole An le: ~ 47.5 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole:~ 2100 Surface: °^ 1626 18. Casn P ram: S cificatio n To - Se in De th -Bo ttom uanti of C merit c.f. or ks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 91.5# A-53 Weld 80' Surface Surface 109' 109' 260 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 3006' Surface Surface 3034' 2712' 706 sx Dee Crete sx Class'G' 8-3/4" 7" 26# L-80 TC-II 45 6' Surface urface 4534' 3727 ee Below ~ ~ - 8-3/4" 7" 26# L-80 BTC-M 1450' 4534' 3727' 5984' 4740' 341 sx Class 'G' 1g. PRESE NT WELCCONDITION SUMMARY (To be completed for Redrill aqd Re-entry Operatiortis) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing length Size Cement Volume MD D Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Printed Name Robert Tir ack Si nature Contact Adrienne Mcyey, 564-4184 Title Engineering Team Leader Prepared By Name/Number: Phone 564-4166 Date -~ S° ~ ~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number O O /~ API Number: 50-Cb?~o? SG?~OD Permit r I 0 See cover letter for Date: other re uirements Conditions of Approval: r./~~~ C~N~Ci.'~~ ~~~~` `~ ~ i....`®©® ~S ~ ~~ 'A'CS ~ ,--,/ If box is checke well may not be us (~,to exploore r, test, produce coalb d me_th/ane, gas hydrates, or gas contained shales:U~/ ~ ~~ MCx ~C t%pCc-rG~fs ~S~Z~ C~CLC7Q"t~ W / Samples Req'd: ^ Yes LrJ No Mud Log Req'd: ^ Yes lJ No ,~`O ~~ ~ c~ HZS Measures: [1~Yes ^ No Directional Survey Req'd: Yes ^ No Other: Pt~cl~~~C1'~. ouO~.K:3 ~GCCL~~~~~ C \OO~Q Et, cab P`t?4C. ~Ss~ ~ ~`a~ J ~ v ~ Date APPROVED. BY T COMMM SIONER \\ l`~ Form 10-401 Revised 12/2005 /1 n I ~ I ~ ~ ~ //Submit In Duplicate U K ~~'oT Well Name: L-221 Drill and Complete Plan Summary T e of Well service / roducer / injector : Injector Surface Location: 2404' FSL, 3617' FEL, Sec. 34, T12N, R11 E, Umiat Slot S-P As Staked X = 583,299 Y = 5,978,127 Target 1 (Nb): 5183' FSL, 3308' FEL, Sec. 3, T11 N, R11 E, Umiat X = 583,640 Y = 5,975,630 Z = 4085' TVDss Target 2 (OBd): 4833' FSL, 3313' FEL, Sec. 3, T11 N, R11 E, Umiat X = 583,640 Y = 5,975,280 Z = 4430' TVDss BHL: 4614' FSL, 3316' FEL, Sec. 3, T11 N, R11 E, Umiat X = 583,640 Y = 5,975,061 Z = 4430' TVDss API NUMBER: TBD Estimated Start Date: March 20, 2008 MD: 5984' TVD: 4740' Ri Nabors 9ES O eratin Da s to com lete: 13.7 RT/G L: 28.5' RTE: 77.3' Well Design: USH Grassroots Schrader Bluff Injector 3'/z" TC-II completion, 5 packers for zonal isolation. Ob'ective: Multi-zonal injector into Schrader Bluff Nb, OA, OBa, OBb/OBc and OBd sands. O erations Drillin En ineer: Adrienne McVey O erations Geolo ist: Bob Dawson Pad En ineer: Egor Makarov Directional Plan Version: Schlumberger P5 KOP: 900' MD Maximum Hole An le: 47.5° Close A roach Wells: All wells pass Major Risk criteria. Reference anti-collision report. Distance to Nearest Property Line• 7240' to PBU boundary. Nearest well within Pool: 808' from L-109 at top Na sand. L-221 Drilling Permit Application 1 '/a Mile Wellbore Mechanical Integrity Summary Well Name Dist. ft Annulus Inte rit Comments 2-stage cement job with ES cementer at 5420' MD. First attempt at ~~` ~ao ` 2"d stage job was unsuccessful (USIT log from 6/10/2002 showed poor cement across Schrader). Went ahead and perforated; when L-1091 gOg freeze protecting OA, discovered had communication between OA and 7" via the perfs. Performed a squeeze job (35 bbl 15.8 ppg Class `G') and bullheaded 20 bbl 15.7 ppg AS1 down OA. USIT (6/14/2002) shows good cement across the Schrader (Top Na sand at 4579' MD; TOC at 4010' MD . ~'~~ 2-stage cement job with ES cementer at 5629' MD. On 2 stage, ~ pumped 61.5 bbl 15.6 ppg Class 'G'. Based on 30% excess, should L-108i 1182 have cement from 3862-5629'. USIT (6/30/2002) shows good cement across the Schrader (Top Na sand at 4743' MD; TOC at 4350' MD . ~` _, ~~~ Pumped 109 bbl 12.0 ppg LiteCRETE. Based on 30% excess, TOC a at 4189' MD. Top Na sand at 5138' MD; should have good cement L-110 1275 isolation across Schrader roducer; no USIT to ~~ sue.-.~~~ ~~ ~~=,~~~~~ e~h~~~~ Logging Program ~~'~ Surface Interval Drilling, MWD: GR Open Hole: None Cased Hole• None Production Interval Drilling, MWD: GR/RES/NEU/Azimuthal Density/PWD Open Hole: None Cased Hole: CBUUSIT Primar De th Control mode Mud Program 12'/a" Surface Hole: Fresh Water Spud Mud Interval Density Funnel Vis PV (cP) YP_(Ib/100ft2) API FL pH sec/ t mV30 min Surface to BPRF 8.8 - 9.2 +400 initial, 55-30 70 -55 NC - 8.0 9.0 - 9.5 300 final BPRF to TD 9.2 - 9.5 250 initial, 225 55-30 60-45 8.0 9.0 - 9.5 final 8 3/a" Production Hole: LSND Interval Density (ppg) PV (cP) YP (Ib/100ft2) API FL (mV30 min) HTHP FL (mU30 min) pH MBT Cs Shoe to TD 8.8-9.2 12-18 18-24 <6.0 N/C 9-10 <18 L-221 Drilling Permit Application 2 Casina/Tubina Program L~ Hole Size Csg/ Tb O.D. WUFt Grade Connection Length Top MDlTVD RTE Btm MDlTVD RTE 42" Insulated 20" 91.5 A-53 Weld 80' Surface 109'/ 109' 12'/a" 9 /a" 40 L-80 BTC 3006' Surface 3034'/2712' 8 3/a" 7" 26 L-80 TC-II 4506' Surface 4534' / 3727' 8 3/a" 7" 26 L-80 BTC-M 1450' 4534' / 3727' 5984' / 4740' Tubin 3'/i" 9.2 L-80 TC-II 5716' Surface 5747' / 4597' Comments: Tubin crossover to 4'/z" 'ust below tree. Inte rit Testin Test Point Depth Test Type 9 5/e" Surface Casin 20' - 50' from surface shoe LOT Cement Calculations Surface Casin Casing Size 9 /8" Basis: Lead: Based on 2034' 12-1/4" open hole with 250% excess above BPRF (1787') and 40% excess below BPRF. TAM port collar used if necessary. Lead TOC: Surface Tail: Based on 85' shoe track volume and 1000' of 12'/a" open hole with 40% excess. Last 15 bbl DuraSTONE. Tail TOC: 1000' MD above the Casin shoe Total Cement Volume: Lead 468 bbl / 2625 ft / 706 sks of DeepCrete at 10.7 ppg and 3.72 ft3/sk Tail 69.5 bbl / 390 ft / 86 sks of Du 84.2 ft / 73 sks at 16.3 ppg and 1.16 ft3/sk Production Casin Casing Size 7" Basis: Tail: Based on 85' shoe track volume and 1950' of 8-3/4" open hole with 30% excess. TOC: 1000' from surface shoe Total Cement Volume: Tail 71.1 bbl / 399 ft / 341 sks of Class `G' at 15.8 ppg and 1.17 ft3/sk. L-221 Drilling Permit Application 3 ~ ~ Estimated Formation Tops (TVDss) and Pore Pressures Formation Top TVDss Uncertaint ft Commercial Hydrocarbon- Bearin ? Est. Pore Pressure si Est. Pore Pressure EMW G1 -255 +/- 50' no 115 8.7 SV6 -880 +/- 50' no 396 8.7 Fault #1 - L Pad Fault -1225 +/-100' M.D. EOCU -1350 +/- 50' no 608 8.7 SV5 -1470 +/- 50' no 662 8.7 SV4 -1610 +/- 50' Gas hydrates 725 8.7 BPRF -1685 +/- 50' - 758 8.7 SV3 -1945 +/- 50' Gas hydrates 875 8.7 SV2 -2100 +/- 50' Gas hydrates 945 8.7 SV1 -2425 +/- 50' Gas hydrates 1091 8.7 UG4 -2715 +/- 50' Thin coal 1222 8.7 UG4A -2745 +/- 50' Heavy Oil - 2745' - 2820' SS 1235 8.7 UG3 -3070 +/- 50' Thin coals 1382 8.7 UG1 -3525 +/- 50' Heavy Oil - 3680'-3780' SS 1586 8.7 UG_Ma -3820 +/- 50' No -wet 1719 8.7 UG_Mbi -3860 +/- 50' No -wet 1737 8.7 UG_Mb2 -3920 +/- 50' 20' Hvy oil 1764 8.7 UG_Mc -3995 +/- 50' No -wet 1798 8.7 SB_Na -4050 +/- 25' No -wet 1823 8.7 SB_Nb -4075 +/- 25' No -wet 1860 8.8 SB_Nc -4105 +/- 25' No -wet 1850 8.7 SB_Ne -4114 +/- 25' Oil 1855 8.7 SB_OA -4205 +/- 25' Oil 1880 8.6 SB_OBa -4270 +/- 25' Oil 1910 8.6 SB_OBb -4310 +/- 25' Oil 1920 8.6 SB_OBc -4365 +/- 25' Oil 1950 8.6 SB_OBd -4415 +/- 25' Oil 1960 8.5 SB_OBe -4480 +/- 25' Poss. Oil 1990 8.5 SB_OBf -4520 +/- 25' Poss. Oil 2005 8.5 Base_SB_OBf -4565 +/- 25' Poss. Oil 2030 8.6 TD -4662 No 2100 8.7 Comments: Formation pressures in the O and N sands and are extrapolated from L-106 and L-116 RFT formation pressures. Ugnu M sands and shallower pressure data is extrapolated from regional Schrader Bluff MDT pressure trends. L-221 Drilling Permit Application 4 ~ ~ Well Control 12 ~/a" hole will be drilled with diverter. The 8 3/a" intermediate hole will use well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer. Annular preventer will be tested to 2500 psi. Rams will be tested to 4000 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may affect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Diverter, BOPE and drilling fluid system schematics are on file with the AOGCC. Production Interval: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • Annular Preventer • Rams • Planned completion fluid: 2100 psi C«~ 4740' TVD, 8.7 ppg EMW (at TD, 5984' MD) 1626 psi @ surface (based on BHP and a full column of gas from TD C~3 0.10 psi/ft) 250 / 2500 psi 250 / 4000 psi 9.0 ppg brine / 6.8 ppg diesel Kick Tolerance/Integrity Testing Summary Table Casing and Casing Test Maximum - ----------- Mud Weight - ------ Exp Pore LOT / Interval Pressure Influx: Press FIT Volume 95/8" Surface 3500 psi 50.1 bbl 9.2 8.7 LOT Casin 7" Production 4000 psi NA NA NA NA Casin Disposal • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids disposal. Haul all Class I wastes to Pad 3 for disposal. operations will be hauled to grind and and other Class II wastes to DS-04 for Variance Request • To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, .the flow paddle will be put back in the flow line. P ~~-~~ ~ C c~ L-221 Drilling Permit Application 5 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up and function test diverter. 3. MU 12'/4" drilling assembly with MW D/GR and directionally drill surface hole to TD with one BHA. The surface hole TD will be approximately 340' below the top of the SV1. 4. Run and cement 9 5/$" surface casing. A TAM port collar may be run at 1000' as a contingency. Use Durastone in the last 15 bbls of tail cement. Pressure test casing to 3500 psi for 30 minutes at plug bump. 5. ND diverter and NU casing /tubing head. NU BOPE and test. 6. Make up 8 3/4" drilling BHA with MWD/GR/RES/Azi-Den/NEU/PWD and RIH to float collar. Drill out shoe track and displace well to LSND drilling fluid. Drill 20' - 50' of new formation and perform LOT. 7. Drill ahead to production hole target TD (approx. 6000' MD, 250' below OBe). Circulate one BU, back-ream out of hole until the ghost reamer is inside the surface shoe, then POOH to run casing. 8. Run and cement the 7" production casing. Displace with 8.6 ppg seawater. Pressure test casing to 4000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9 5/8" annulus. 9. PU DPC guns and RIH w/ -200' of 4.5" Power Jet 4505 5 spf, pert guns with Anadrill LWD GR for gun correlation. 10. Space out pert guns by tagging PBTD and utilizing GR and RA tags in 7" casing. Once correlated correctly, circulate over to 9.0 ppg brine. Confirm cement compressive strength is at least 1000 psi before firing. Perforate Nb, OA, OBa, OBb, OBc, and OBd. POOH LD DP and guns. 11. RU Schlumberger E-line. RIH with gauge ring and junk basket to recover any pert debris. Repeat until clean to at least 50' below the bottom perforation. 12. Run USIT log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 13. Run the 3-~h", 9.2# completion with a 7" x 3-'/z" straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II threaded tubing. Top packer must be within 200' of Nb perfs. 14. Confirm that packers are on depth using E-line. 15. Run in lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and tubing to 4000 psi each. Shear the DCR valve and pump both ways to confirm circulation ability. 16. Install and test TWC. Nipple down the BOPE. Nipple up and test the double master valves to 5000 psi. 17. Freeze protect the well to 2500' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oil truck, taking clean brine returns to surface. Allow diesel to u-tube into tubing. 18. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-'h" annulus valve and secure the well. Ensure that IA/OA are protected with two barriers. 19. RDMO. Post-Rip Work: 1. Install tree with electric SSV actuator. 2. MIRU slickline. Pull the ball and rod / RHC plug. 3. Pull shear valve from top mandrel and replace with a dummy GLV. 4. Pull dummy valves from injection mandrels and replace with injection valves. 5. Pull VR plug. 6. Install wellhouse and flowlines. L-221 Drilling Permit Application 6 • Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control The Schrader in the Polygon 5S fault block is expected to be normally to sub-normally pressured at 8.5-8.7 ppg EMW. II. Hydrates and Shallow Gas Gas hydrates and/or free gas will be present in the SV4 through SV1 below BPRF. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. III. Faults/Lost Circulation/Breathing A. "L-Pad Fault": L-221 will penetrate this fault in the SV6 interval at a high angle and move quickly away from the fault. Lost circulation is not anticipated (nearly all previously-drilled L-pad wells have intersected this fault without experiencing losses). If LC does occur, follow LCM decision tree. B. No faults are expected in the reservoir interval. C. Breathing is not expected on this well. IV. Kick Tolerance/Integrity Testing A. The kick tolerance for the surface casing is 92 bbl with 9.2 ppg mud, 12.5 LOT, and an 8.7 ppg pore pressure. B. Integrity Testing: Test Point Test De th Test t e EMW 9 5/e" shoe 20-50' from shoe LOT >12.5 expected V. Hydrogen Sulfide L Pad is not designated as an H2S site, but Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time; however, all L Pad gas lift wells will likely have H2S levels in the 10-250 ppm range as a result of using PBU lift gas. Well Name H2S Level Date of Readin #1 Closest SHL Well H2S Level L-03 15 m 11 /26/2007 #2 Closest SHL Well H2S Level L-107 20 m 11 /22/2007 #1 Closest BHL Well H2S Level L-110 70 m 10/11 /2007 #2 Closest BHL Well H2S Level L-121 A 15 m 8/28/2007 VI. Anti-Collision Issues All wells pass Major Risk criteria. The following wells are less than 100' center-to-center from L-221 P5: Well Name Ctr-Ctr Distance (ft) Reference MD (ft) Allowable Deviation (ft) Comment L-Ot 53.15 1885.49 21.75 Use traveling cylinder L-03 15.97 314.14 10.04 Use traveling cylinder L-104 89.11 493.77 81.29 Use traveling cylinder L-105 48.57 503.71 39.42 Use traveling cylinder L-106 57.31 668.29 46.40 Use traveling cylinder L-107 18.47 513.92 8.32 Use traveling cylinder L-108 24.12 713.75 11.73 Use traveling cylinder L-204 79.09 458.89 71.32 Use traveling cylinder L-213 15.17 384.20 8.79 Use traveling cylinder CONSULT THE L-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. L-221 Drilling Permit Application 7 TREE = 41/16" C WELLHEAD= FMC ACTUATOR = .. Electric ~~ KB. BF. ELEV = KOP = 300' Max Angle = 47.5 deg Datum MD = Datum TV D = L -2 Z~ Proposed ~~~EX ®C4300 PSIO TT~ST~PRB®RE P~ S~ RATING =5415 PSI (4332 PSI IS 80% OF PF02 RATING)"` 29' 4-1 /2" XO 3-1 /2". ~ = 2.992" iu = ~4-1 /2" TBG, 12.fi#, L-80, TC-II, .0152 bpf, ~=3.958" ~ 9-5/8" CSG, 40#, L-80, TGII, ID = 8.835" 303 T' CSG, 26//, L-80, TGG, .0383 bpf, ID = 6.275' Minimum ID = 2.75" aGa xxxx' 3-1/2" HES XN NIPPLE MARKER JOINTw/ RA TAG Nb 5148 MARKER JOINT w / RA TAG Nc 520Z GAS LIFT MANDRELS 5109' ~-~ 3-1 /2" HES X NIP, ID = 2.813" ~ 4534' 5130' 7" HES AHR PKR w / 1 /4" FEED THRU, ID = 2.920" 5144' SGM FOR NDPG GAUGE, ID=2.910" 5243' 3-1/2" HES X Nom, ID = 2.813" 5254' 7" HES AHR PKR w / 1/4" FEED THRU, ~ = 2.920" ST MD TVD DEV TYPE VLV LATCH PORT DATE 10 5080 MMG DCR RK WATER INJECTION MANDRELS ST MD TV D DEV TYPE VLV LATCH PORT DATE 9 5156 MMG-W DMY RK 8 5215 MMG-W DMY RK 7 5290 MMG-W DMY RK 6 5382 MMG-W DMY RK 5 5435 MMG-W DMY RK 4 5466 MMG-W DMY RK 3 5527 MMG-W DMY RK 2 5596 MMG-W DMY RK 1 5676 MMG-W DMY RK PERFORATION SUMMARY REF LOG: SLB ReaRime LWD A NGLE AT TOP PERF: Note: Refer to Production DB for historical pert data SQE SPF INTERVAL OpNSgz DATE 4-1/2" 5 Nb xxxx'-xxxx' O 4-1/2" 5 OA xxxx'-xxxx' O 4-1/2" 5 OBa xxxx'-xxxx' O 4-1/2" 5 OBb xxxx'-xxxx' O 4-1/2" 5 OBc xxxx'-xxxx' O 4-1/2" 5 OBd xxxx'-xxxx' 13-1/2" TBG, 9.2#, L-80, TGB, 7" CSG, )087 bpf, ID = 2.992" 5747' PBTD 5899' .0383 bpf, ID = 6.276 ~-~ 59$4' 5278' --SGM FOR NDPG GAUGE, ID=2.910" ~ 5401' 3-1/2" HES X NP ~ = 2.813" 5412' 7" HES AHR PKR w/ 1/4" FEED THRU, ID = 2.920" 5426' SGM FOR NDPG GAUGE, ID=2.910" T' HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" 5499' SGM FOR NDFG GAUGE, ID--'2.910" 5511' 3-112" HES X Nom, ®= 2.813" 5625' T' HES AHR PKR w / 1/4" FEED THRU, ID = 2.920" 5639' SGM FOR NDPG GAUGE, ID=2.910" 5655' 3-1/2" HES X N~? ~ = 2.813" 5705' 3-1/2" HES X Nom, ~ = 2.813" 5725' 3-112" HES XN N~ ~ = 2.75" 5747' ~ 3-112" WLEG, ID = 2.992" I DWTE REV BY COMMENTS DIATE REV BY COMMENTS 12/12/07 ALM Proposed WBD(wp03) 02/25/08 ALM Update to wp05 ORION UNIT WELL: V-220i PERMIT No: xxxxx API No: 50-029-xxxxx BP Exploration (Alaska) ~ PLANT - N~15'00'00" rte- - - - - - - - - - - - - - - - - - I i L-PAD ~ ^ N-L(NWE-1) I o~ 00 I L-111i ^ g ^ N-A (NWE-2) L-51 ^ ^ L-218i L-114 ^ ^ L-124 L-50 ^ ^ L-112i ^ L-02 L-121 ^ L-123i L-205 ^ L-122 L-110 ^ L-211i L-220 ^ ^ L-1151 L-116 ^ ^ L-117 L-109 ^ ^ L-118 L-04i ^ ^ L-250 L-01 ^ ^ L-200 L-107 ^ ^ L-202 L-03 su io soz ^ L-212i L-221 i . L-z17i L-2131 a ^ L-203 L-1081 ^ ^ L-216i L-105i ^ - ~ ^ L-103i L-106 ^ ~ ^ L-215i L-204 ^ ^ L-201 L-104 ^ ^ L-1191 L-2141 ^ ^ L-210i L-102 ^ n ^ L-120 I la ^ L-2191 I SNIO 506 1 I SKID 51.5 ~, ,~ 34 L-PAD PROJECT ~BEA_____ r 3 i 35 -N I _ T12N T11 N w 2 VICINITY MAP N.T.S. LEGEND NOTES AS-STAKED CONDUCTOR 1. DATES OF SURVEY: JANUARY 29 & 31, 2008. 2. REFERENCE FIELD BOOK: W008-02 PAGES 39-43. ~ EXISTING CONDUCTOR 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD 27. 4. BASIS OF HORIZONTAL LOCATION IS OPERATOR MONUMENTS, WOA L-PAD MONUMENTATION. 5. BASIS OF ELEVATION IS OPERATOR MONUMENTS PER F.R. BELL & ASSOCIATES. ELEVATIONS ARE BPX MEAN SEA LEVEL DATUM. 6. MEAN PAD SCALE FACTOR IS 0.999907827. LOCATED WITHIN PROTRACTED SEC. 34. T. 12 N.. R. 11 E.. UMIAT MERIDIAN. AI ASKA WELL A.S.P. PLANT GEODETIC GEODETIC PAD SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) ELEVATION OFFSETS L-205 Y= 5,978,082.17 N= 9,820.00 70'21'00.328" ' " 70.3500911' 47 4 2,361' FSL ' X= 583,130.34 E= 5,090.00 149'19 30.288 149.3250800' ' 3,786 FEL L-2211 Y= 5,978,127.46 N= 9,820.00 70'21'00.755" ' " 70.3502097' 48 8' 2 404' FSL ' X= 583,299.37 E= 5,265.00 149'19 25.333 149.3237036° 3,617 FEl F. Robert DRAWN: BARNHART CHECKED: {1n Q MSF -JN ~° DA 02/01/08 DRAWING: WOA L-PAD e FR808 WOL 01-00 SHEET: d JOB NO: ~ ~~~OO ~o AS-STAKED CONDUCTORS scA~e 1 aF 1 0 02 01 OS ISSUED FOR INFORMA710N 7FB 44R 1°- 1so~ WELL L-205 AND L-221 i N0. DA7E REVISION BY CHK by Schlumberger L-221 (P5) Proposal Report Date: February 5, 2008 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 174.300° Field: Prudhoe Bay Unit - WOA /~ Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: L-PAD / L-221 ~~' ~~ s u~/y TVD Reference Oatum: Rotary Table Well: Plan L-221 (S-P) S~ TVD Reference Elevation: 77.30 ft relative to MSL Borehole: Plan L-221 ~e~ Sea Bed 1 Ground Level Elevation: 48.80 ft relative to MSL UWIIAPI#: 50029 Magnetic Declination: 23.032° Survey Name 1 Date: L-221 (P5) I February 5, 2008 Total field Strength: 57645.620 nT Tort 1 AHD / DDI 1 ERD ratio: 62.615° / 3114.53 ft 15.391 / 0.657 Magnetic Dip: 80.882° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: March 18, 2008 Location LaUlong: N 70.35020964, W 149.32370360 Magnetic Declination Model: BGGM 2007 Location Grid NIE YIX: N 5978127.460 ftUS, E 583299.370 ftUS North Reference: True North Grid Convergence Angle: +0.63691603° Total Corr Mag North -> True North: +23.032° Grid Scale Factor. 0.99990788 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth SutrSea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 100 ft Index ftUS ftUS Klt U.UU U.VV U.UU -//.3U U.VU U.UU U.UU U.VV --- U.VU U.VV b`J/tSIZ/.4b OtSJZ`J`J.6/ N /U.SOVLU`Jb4 VV "14`9. 3Z3/U3bU Ndg 1/100 300.00 0.00 0.00 222.70 300.00 0.00 0.00 0.00 O.OOM 0.00 0.00 5978127.46 583299.37 N 70.35020964 W 149. 32370360 G1 332.30 0.32 0.00 255.00 332.30 -0.09 0.09 0.00 O.OOM 1.00 0.00 5978127.55 583299.37 N 70.35020989 W 149. 32370360 400.00 1.00 0.00 322.69 399.99 -0.87 0.87 0.00 O.OOM 1.00 0.00 5978128.33 583299.36 N 70.35021203 W 149. 32370360 500.00 2.00 0.00 422.66 499.96 -3.47 3.49 0.00 O.OOM 1.00 0.84 5978130.95 583299.33 N 70.35021918 W 149. 32370360 Drp 1/100 550.00 2.50 0.00 472. 62 549.92 -5.43 5.45 0.00 O.OOM 1.00 1.13 5978132.91 583299.31 N 70.35022454 W 149.32370360 600.00 2.00 0.00 522. 58 599.88 -7.38 7.42 0.00 O.OOM 1.00 1.35 5978134.88 583299.29 N 70.35022990 W 149.32370360 700.00 1.00 0.00 622. 55 699.85 -9.98 10.03 0.00 O.OOM 1.00 1.60 5978137.49 583299.26 N 70.35023706 W 149.32370360 End Drp 800.00 0.00 0.00 722. 54 799.84 -10.85 10.91 0.00 --- 1.00 1.74 5978138.36 583299.25 N 70.35023944 W 149.32370360 KOP Bld 1/100 900.00 0.00 169.31 822. 54 899.84 -10.85 10.91 0.00 169.31M 0.00 1.74 5978138.36 583299.25 N 70.35023944 W 149.32370360 SV6 957.46 0.57 169.31 880. 00 957.30 -10.57 10.62 0.05 169.31M 1.00 1.80 5978138.08 583299.31 N 70.35023867 W 149.3237 Bld 3/100 1000.00 1.00 169.31 922. 54 999.84 -9.98 10.05 0.16 169.31 M 1.00 1.85 5978137.51 583299.42 N 70.35023710 W 149.3237 1100.00 4.00 169.31 1022. 43 1099.73 -5.64 5.76 0.97 169.31 M 3.00 2.16 5978133.23 583300.28 N 70.35022539 W 149.32369572 1200.00 7.00 169.31 1121. 96 1199.26 3.91 -3.65 2.75 HS 3.00 2.49 5978123.84 583302.16 N 70.35019966 W 149.32368129 1300.00 10.00 169.31 1220. 85 1298.15 18.63 -18.18 5.49 HS 3.00 2.78 5978109.35 583305.06 N 70.35015999 W 149.32365903 Fault Crossing 1304.22 10.13 169.31 1225.00 1302.30 19.37 -18.90 5.63 HS 3.00 2.80 5978108.62 583305.21 N 70.35015801 W 149.32365792 1400.00 13.00 169.31 1318. 83 1396.13 38.49 -37.77 9.19 HS 3.00 3.04 5978089.80 583308.98 N 70.35010647 W 149.32362902 1500.00 16.00 169.31 1415. 63 1492.93 63.43 -62.37 13.83 HS 3.00 3.26 5978065.26 583313.89 N 70.35003927 W 149.32359132 SV5 1556.81 17.70 169.31 1470. 00 1547.30 79.84 -78.55 16.89 HS 3.00 3.37 5978049.11 583317.13 N 70.34999506 W 149.32356652 1600.00 19.00 169.31 1510. 99 1588.29 93.38 -91.91 19.41 HS 3.00 3.45 5978035.78 583319.80 N 70.34995855 W 149.32354604 1700.00 22.00 169.31 1604. 65 1681.95 128.27 -126.32 25.90 HS 3.00 3.61 5978001.45 583326.67 N 70.34986455 W 149.32349331 SV4 1705.77 22.17 169.31 1610. 00 1687.30 130.43 -128.45 26.31 HS 3.00 3.62 5977999.32 583327.10 N 70.34985872 W 149.32349005 WeIlDesign Ver SP 2.1 Bld( doc40x_ 100) L-221\Plan L-221 (S-P)\Plan L-221\L-221 (P5) Generated 2/5/2008 8:54 AM Page 1 of 3 Comments Measured Inclination Azimuth Sub-Sea TVD ND Vertical NS EW Mag I Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ff ff ff ff ff de de 100 h Index BUS ffUS tnaGN 1/bb.bb Z3.`J/ 1by.31 lbbS.UU 1/4L.3V "153.// -1b1.4/ 3U.bb --- S.uu 3./1 oy//y/o.JD ~OJJJI./U IV/V.J4~/yJ04 VV 147.JLJ4A4// Base Perm 1787.44 23.97 169.31 1685.00 1762.30 162.62 -160.21 32.30 --- 0.00 3.74 5977967.64 583333.45 N 70.34977197 W 149.32344139 CN 3/100 1809.33 23.97 169.31 1705.00 1782.30 171.48 -168.94 33.95 5.88R 0.00 3.76 5977958.92 583335.19 N 70.34974810 W 149.32342800 1900.00 26.67 169.93 1786.95 1864.25 210.13 -207.09 40.93 5.32R 3.00 3.88 5977920.86 583342.59 N 70.34964391 W 149.32337137 2000.00 29.66 170.49 1875.10 1952.40 257.21 -253.60 48.94 4.82R 3.00 4.00 5977874.44 583351.12 N 70.34951683 W 149.32330633 SV3 2081.45 32.10 170.88 1945.00 2022.30 298.93 -294.85 55.70 4.49R 3.00 4.09 5977833.27 583358.34 N 70.34940414 W 149.32325145 2100.00 32.65 170.96 1960.66 2037.96 308.84 -304.66 57.27 4.42R 3.00 4.11 5977823.49 583360.02 N 70.34937735 W 149.32323872 2200.00 35.64 171.36 2043.41 2120.71 364.88 -360.12 65.89 4.09R 3.00 4.21 5977768.13 583369.25 N 70.34922583 W 149.32316875 SV2 2270.58 37.76 171.60 2100.00 2177.30 407.01 -401.83 72.14 3.90R 3.00 4.28 5977726.49 583375.96 N 70.34911187 W 149.32311805 2300.00 38.64 171.70 2123.12 2200.42 425.18 -419.83 74.78 3.82R 3.00 4.31 5977708.53 583378.80 N 70.34906270 W 149.323 2400.00 41.63 172.00 2199.57 2276.87 489.57 -483.63 83.91 3.59R 3.00 4.40 5977644.84 583388.64 0 N 70.34888841 W 149.3230 2500.00 44.63 172.27 2272.54 2349.84 557.88 -551.34 93.26 3.40R 3.00 4.49 5977577.24 583398.74 N 70.34870342 W 149.3229 End CN 2594.87 47.47 172.50 2338.38 2415.68 626.13 -619.03 102.31 --- 3.00 4.56 5977509.66 583408.54 N 70.34851851 W 149.32287314 SV1 2723.00 47.47 172.50 2425.00 2502.30 720.50 -712.64 114.64 --- 0.00 4.63 5977416.21 583421.91 N 70.34826278 W 149.32277306 9-5/8" Csg Pt 3033.64 47.47 172.50 2635.00 2712.30 949.29 -939.58 144.53 --- 0.00 4.76 5977189.63 583454.32 N 70.34764278 W 149.32253045 UG4 3151.98 47.47 172.50 2715.00 2792.30 1036.45 -1026.04 155.92 --- 0.00 4.80 5977103.31 583466.67 N 70.34740660 W 149.32243802 UG4A 3196.36 47.47 172.50 2745.00 2822.30 1069.14 -1058.46 160.19 --- 0.00 4.81 5977070.95 583471.30 N 70.34731802 W 149.32240337 UG3 3677.11 47.47 172.50 3070.00 3147.30 1423.22 -1409.68 206.46 --- 0.00 4.95 5976720.29 583521.46 N 70.34635851 W 149.32202793 UG1 4350.17 47.47 172.50 3525.00 3602.30 1918.94 -1901.40 271.22 --- 0.00 5.09 5976229.37 583591.69 N 70.34501518 W 149.32150239 CN 4/100 4683.74 47.47 172.50 3750.51 3827.81 2164.62 -2145.10 303.33 100.57R 0.00 5.15 5975986.06 583626.49 N 70.34434941 W 149.32124194 4700.00 47.35 173.37 3761.51 3838.81 2176.58 -2156.98 304.80 99.98R 4.00 5.16 5975974.21 583628.10 N 70.34431696 W 149.32122999 Crv 0.5/100 4785.90 46.85 178.01 3820.00 3897.30 2239.46 -2219.69 309.54 HS 4.00 5.20 5975911.56 583633.53 N 70.34414564 W 149.32119153 Ma 4785.92 46.85 178.01 3820.01 3897.31 2239.47 -2219.70 309.54 95.15R 0.50 5.20 5975911.55 583633.53 N 70.34414561 W 149.32119153 4800.00 46.84 178.10 3829.64 3906.94 2249.72 -2229.97 309.89 95.09R 0.50 5.20 5975901.28 583634.00 N 70.34411755 W 149.32118870 4844.13 46.82 178.40 3859.83 3937.13 2281.83 -2262.14 310.87 -- 0.50 5.21 5975869.13 583635.34 N 70.34402967 W 149.32118075 Mb1 4844.37 46.82 178.40 3860.00 3937.30 2282.01 -2262.32 310.88 --- 0.00 5.21 5975868.95 583635.34 N70.34402918 W149.32118071 4844.86 46.82 178.40 3860.33 3937.63 2282.36 -2262.67 310.89 96.82R 0.00 5.21 5975868.60 583635.36 N 70.34402822 W 149.32118063 4900.00 46.79 178.78 3898.08 3975.38 2322.45 -2302.86 311.87 96.56R 0.50 5.22 5975828.43 583636.79 N 70.34391842 W 149.32117262 Mb2 4932.02 46.77 179.00 3920.00 3997.30 2345.71 -2326.19 312.33 96.41R 0.50 5.22 5975805.11 583637.50 N 70.34385469 W 149.3211t~ 5000.00 46.74 179.46 3966.58 4043.88 2395.04 -2375.70 312.99 96.09R 0.50 5.24 5975755.61 583638.72 N 70.34371942 W 149.32116356 Mc 5041.46 46.71 179.74 3995.00 4072.30 2425.10 -2405.89 313.20 95.90R 0.50 5.24 5975725.43 583639.26 N 70.34363696 W 149.32116188 5100.00 46.68 180.14 4035.15 4112.45 2467.50 -2448.49 313.24 95.62R 0.50 5.25 5975682.83 583639.78 N 70.34352057 W 149.32116156 Na 5121.65 46.67 180.29 4050.00 4127.30 2483.16 -2464.24 313.18 95.52R 0.50 5.26 5975667.09 583639.89 N 70.34347755 W 149.32116205 Nb 5158.08 46.66 180.54 4075.00 4152.30 2509.51 -2490.74 312.99 95.35R 0.50 5.27 5975640.59 583640.00 N 70.34340516 W 149.32116363 5172.15 46.65 180.64 4084.66 4161.96 2519.68 -2500.97 312.88 -- 0.50 5.27 5975630.36 583640.00 N 70.34337721 W 149.32116448 L-221 Tgt 1 Nb 5172.65 46.65 180.64 4085.00 4162.30 2520.04 -2501.33 312.88 180.00E 0.00 5.27 5975630.00 583640.00 N 70.34337622 W 149.32116452 5200.00 46.51 180.64 4103.80 4181.10 2539.79 -2521.20 312.66 180.00E 0.50 5.27 5975610.13 583640.00 N 70.34332194 W 149.32116632 Nc 5201.74 46.50 180.64 4105.00 4182.30 2541.04 -2522.46 312.64 180.00E 0.50 5.27 5975608.87 583640.00 N 70.34331849 W 149.32116644 Ne 5214.81 46.44 180.64 4114.00 4191.30 2550.46 -2531.93 312.54 180.00E 0.50 5.27 5975599.39 583640.00 N 70.34329261 W 149.32116729 5300.00 46.01 180.64 4172.94 4250.24 2611.59 -2593.44 311.85 180.00E 0.50 5.29 5975537.89 583640.00 N 70.34312458 W 149.32117287 WeIlDesign Ver SP 2.1 Bld( doc40x_100) L-221\Plan L-221 (S-P)\Plan L-221\L-221 (PS) Generated 2/5/2008 8:54 AM Page 2 of 3 Comments Measured Inclination Azimuth SutrSea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 100 ft Index ftUS ftUS VH b34b.U/ 4b./tJ 7t3U.b4 4ZUb.UU 4LtSZ.3U Zb44.4/ -ZbZb.bZ 377.4`) 72JU. UUL U.bU D.3U 0`J/bOV4.iJ7 bb304U.UU IV /U.34JV34LL W 74`J.SL77 /OtS/ 5400.00 45.51 180.64 4242.71 4320.01 2682.80 -2665.08 311.06 180. 00E 0.50 5.31 5975466.25 583640.00 N 70.34292887 W 149.32117936 OBa 5438.88 45.31 180.64 4270.00 4347.30 2710.31 -2692.76 310.75 180. 00E 0.50 5.31 5975438.57 583640.00 N 70.34285324 W 149.32118187 OBb 5495.61 45.03 180.64 4310.00 4387.30 2750.30 -2733.00 310.30 180. 00E 0.50 5.32 5975398.34 583640.00 N 70.34274332 W 149.32118551 5500.00 45.00 180.64 4313.10 4390.40 2753.39 -2736.10 310.27 180. 00E 0.50 5.32 5975395.23 583640.00 N 70.34273485 W 149.32118579 OBc 5573.17 44.64 180.64 4365.00 4442.30 2804.65 -2787.67 309.70 180. 00E 0.50 5.33 5975343.66 583640.00 N 70.34259396 W 149.32119045 5600.00 44.50 180.64 4384.11 4461.41 2823.36 -2806.50 309.49 180. 00E 0.50 5.34 5975324.84 583640.00 N 70.34254252 W 149.32119215 OBd 5643.22 44.28 180.64 4415.00 4492.30 2853.42 -2836.74 309.15 180. 00E 0.50 5.34 5975294.60 583640.00 N 70.34245992 W 149.32119488 L-221 Tgt 2 OBd 5664.16 44.18 180.64 4430.00 4507.30 2867.93 -2851.34 308.99 LS 0.50 5.35 5975280.00 583640.00 N 70.34242003 W 149.32119620 5700.00 44.00 180.64 4455.74 4533.04 2892.72 -2876.28 308.71 LS 0.50 5.35 5975255.06 583640.01 N 70.34235190 W 149.32119845 5733.67 43.83 180.64 4480.00 4557.30 2915.93 -2899.63 308.45 LS 0.50 5.36 5975231.71 583640.01 N 70.34228810 W 149.3212 OBe 5733.69 43.83 180.64 4480.01 4557.31 2915.94 -2899.64 308.45 LS 0.50 5.36 5975231.70 583640.01 N 70.34228807 W 149.3212 OBf 5788.99 43.56 180.64 4520.00 4597.30 2953.91 -2937.85 308.03 LS 0.50 5.36 5975193.50 583640.01 N 70.34218370 W 149.32120401 5800.00 43.50 180.64 4527.98 4605.28 2961.45 -2945.42 307.95 LS 0.50 5.37 5975185.92 583640.01 N 70.34216300 W 149.32120469 OBf Base 5850.93 43.25 180.64 4565.00 4642.30 2996.21 -2980.40 307.56 LS 0.50 5.37 5975150.95 583640.01 N 70.34206745 W 149.32120785 5900.00 43.00 180.64 4600.82 4678.12 3029.55 -3013.94 307.19 LS 0.50 5.38 5975117.41 583640.01 N 70.34197582 W 149.32121088 TD / 7" Csg 5983.67 42.58 180.64 4662.22 4739.52 3086.04 -3070.78 306.56 --- 0.50 5.39 5975060.57 583640.01 N 70.34182055 W 149.32121601 WeIlDesign Ver SP 2.1 Bld(doc40x_100) L-221\Plan L-221 (S-P)\Plan L-221\L-221 (P5) Generated 2/5/2008 8:54 AM Page 3 of 3 by • Schlumberger WE`L L-221 (P5) FIE`D Prudhoe Bay Unit - WOA BTRUDTURE L-PAD Mag,retic Paramalers Burtace LOration NAD2]Alasha Slade Planes. Zone 00. US FaeI Miscellaneous Mortel-. BGGM 200] Dip 00.802" Dale: March t9. 2008 NID 21 o.1S6 Northing 59]6!2]bfi ftUS Gnd Gonv. .063fi9t603° Slo,. NO Rey Rolary Table,!)30ttabova MBLI Mag Dec: -2303Y FB'. 6]6<66 nT Lon: Wi491926333 Easling 683298 J]IIUS Scale Fact: D.99990]0623 Plan. L22'I (P6j Grvy Oata February 95.2098 0 600 1200 1800 2400 3000 0 600 1200 1800 O O C u 2400 m H 3000 3600 4200 4800 RTE Ndg 11100 Drp 11100 End Drp KOP Bld 11100 Bld 31100 ................................. ..................................j..................................<..................................y..................................y.................................. i................ Fault Crossing .._.._.._.._.._.._.._..:.._ 3~._.._.._.._.._.._....._.._.._..~._.._.._.._.._.._.._.._.._.._.._.._.._ _ ._.._.._.._.._.._.._.._ _.._.._.._.._..-.._.._. _ _.._.._.._ End Crv ._.._..-.._..-..-..-. _ .Crv 3I700~ _.._..~..~..-..-..~.. ..1..._.._.._..-.._.._.._.._.t_ ._..~..-..~.._..-..-..- -..-..-..-.._.._.._.._. -.._.. _.._ ._.._..-..-..-.._..-. _.._.._.._ ~%3 ._.._ _..-..-..~..-..-..~.. ..-..-.._..-..-.._.._..- .-..-..-..~..-..-..-..- ..-.._..-..-..-..-..-. -..-..-..- ._.._.._..~.._.._.._. ~ -.._.._.._..-. . 2._ _ _.._.._.._.._.._..-.._ ..-.._..-..-..-..-.._..- _ .-..-.._..~.._.._.._.. .._.._.._..-..-..-..-. -..-.._.._ End Crv /8 ~sg P~ ..*.. ._.. _.._.._.._.._.. ~. _ ~..~..~..~..~..~..~..- - -..~..~.._. ~.._ .ails .~..~..~..~..~..~..~..- _ .-.._.._. _. -. ~..~..~ ~..~. ~..~..~. ~..~..~.. ~..~..~..~ .................................j..................................j.................................. ~.. ..............................i...................................j.................................. j................ ._.._.._.._.._.._.._. _ _..-.._.._..~.._..-.._ ~..-..~..~.._..-..~.. .._.._. 3._.._..-.._ _ ._..-..-..~..-..-..-..- -..-..-.._.._..~.._..-. _.._.._.._ 1 Crv 4f100 Crv o.s/1oo ._.._.._.._.._.._.._. _.._.._.._.._.._.._.._..r. _.._.._.._.._.._.._.._ .._.._.._.._.._.._.._.._ _ ._.._.._.._.._ _ _.._.._.._.._.._.._.._. _.._.._.._ .._.. 1: ~2 ~ L-221 Tg[ 1 Nb~~ ..~.._..-..-..-.._..-..i..-..-..-..-..-..-.._..-..i..-..-.._..~..-.._.._..-..-..-..-..-..-..-..-..-..-.i-..-..-.._.. _.. _.._.._.._ ..-.. _. .._.._.. _.. _...y.-.. _.. _.. _. xwu~wuaNw~taAawtit~ iwNwua~urrw~ i.~.ai+uwlu ._..-.._..-.._.._.. _..i.. .._.._.._.._.._.. _.. _..i.._.._.._.. ~..-.._..~.. ._..-.. _.._..-.._..-.. .-..-..-..~..-.._.. _.. .. _.. _.._ .._ . ~•. 1.Sgt1.. b~ .._..-.._..-.._.._..-...j..-..-.._..-..~.._.._..-..~...-..-.._..~..-.._.._.._..„..-..-..-..-..-..-.._..-.i-..-..-.._..-.._.._..-.._t.-.._.._.._.._.. _.. ._:._..-.._.. _. ._.._.._.._.._.._..-..N..-..-..-..-..-..-..-..-..~.._. ~.._..~ .-..-..-.._..~.._.._.._..-.._.._.._.._.j_.._.._.._.._.._.._.._.._~._.._.._.._.. _.. _.. _.. ._.. _.. _.._. .: .. (Base TD :~ 221 (PS) 600 1200 1800 2400 3000 3600 4200 T' Csg 4800 0 600 1200 1800 2400 3000 Vertical Section (ft) Azim = 174.3°, Scale = 1(in):600(ft) Origin = 0 N/-S, 0 E/-V by • Schlumberger i WELL L-221 (P5) FIELD Prudhoe Bay Unit - WOA STRUCTURE L-PAD MagnelK Parameters Gurlace Louallon Nn02] Alaska Slale Planes. Zone Oa, US Feet Miscellaneous Model: BGGM 200] DIV. 60 862" Dale: March 16. 2606 LN N]0 21 0 ]55 Nortninq. 59]6 t 2].46 flUS GnE Conv'. ~0.6369tfi03' 6bt L~221 ND Rei. Rotary Table I]] 30 it above MSLI Mag Dec: ~23.C32' F5: 5]fi45.6 nT Lon: W149 X925.333 Easbng: SB32993)flUS Scale Fad: 099990]662) Plan L~2211P51 my Date: FebrurV05. 2008 -800 -400 0 400 800 1200 0 -400 -800 n -1200 n Z 0 0 c -1600 m m U V V V -2000 -2400 -2800 800 -400 0 400 800 1200 c« W Scale = 1(in):400(ft) E »> 0 -400 -800 -1200 -1600 -2000 -2400 -2800 BP Alaska Anticollision Report ' Company: BP Amoco Date: 2/5/2008 Time: 09:06:36 Page: Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate(NE) Reference: Well: Plan L-221 (S-P), True North Reference Well: Pfan L-221 (S-P) .Vertical (TVD) Reference: L-221 Plan 77.3 Reference Wcllpath: Plan L-221 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are 1<b@li~>ioeells in thisRliNdApal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 5983.67 ft Scan Method: Tray Cylinder North Maximum Radius: 795.52 ft p----- Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 11/19/2007 Validated: No Version: 5 Planned From To Survey Toolcode Tool Name ft ft - - -_ ', 28.50 1000.00 Planned: Plan #5 V1 GYD-GC-SS Gyrodata gyro single shots ' 1000.00 2400.00 Planned: Plan #5 V1 MWD MWD -Standard 1000.00 2960.00 Planned: Plan #5 V1 MWD+IFR+MS MWD +IFR + Multi Station 2960.00 5983.67 Planned: Plan #5 V1 MWD+IFR+MS MWD +IFR + Multi Station ' Casing Points MD TVD Diameter Hole Size Name ft ft in in ~' 3033.64 2712.30 9.625 12.250 9 5/8" ~, 5983.67 4739.52 7.000 8.750 7" Summary ------=----- -----Oi'fset Wellpath - -_------> Reference '' Offset- Ctr-Ctr No-Go Allowable ' " Site ' Well Wel}path MD MD .` Distance Area Deviation .Warning ft ft ft ft ft PB L Pad L-01 L-01 V14 1885.49 1865.00 53.15 31.40 21.75 Pass: Major Risk PB L Pad L-02 L-02 V1 815.07 820.00 259.65 12.26 247.39 Pass: Major Risk ', PB L Pad L-02 L-02A VS 815.87 815.00 259.65 12.37 247.28 Pass: Major Risk ', PB L Pad L-02 L-02APB1 V2 815.87 815.00 259.65 12.37 247.28 Pass: Major Risk ', PB L Pad L-02 L-02P61 V21 815.07 820.00 259.65 12.37 24728 Pass: Major Risk PB L Pad L-03 L-03 V5 314.14 315.00 15.97 5.93 10.04 Pass: Major Risk ', PB L Pad L-04 L-04 V5 549.57 550.00 101.00 9.52 91.48 Pass: Major Risk PB L Pad L-101 L-101 V4 1088.49 1110.00 296.04 17.47 278.57 Pass: Major Risk ', PB L Pad L-102 L-102 V2 273.30 275.00 120.56 4.43 116.13 Pass: Major Risk PB L Pad L-102 L-102PB1 V10 273.30 275.00 120.56 4.52 116.04 Pass: Major Risk ' PB L Pad L-102 L-102PB2 V2 273.30 275.00 120.56 4.52 116.04 Pass: Major Risk ', PB L Pad L-103 L-103 V23 750.47 750.00 175.55 11.54 164.01 Pass: Major Risk PB L Pad L-104 L-104 V7 493.77 495.00 89.11 7.82 81.29 Pass: Major Risk PB L Pad L-105 L-105 V4 503.71 505.00 48.57 9.15 39.42 Pass: Major Risk ', PB L Pad L-106 L-106 V14 668.29 670.00 57.31 10.91 46.40 Pass: Major Risk PB L Pad L-107 L-107 V14 513.92 515.00 18.47 10.15 8.32 Pass: Major Risk PB L Pad L-108 L-108 V18 713.75 715.00 24.12 12.39 11.73 Pass: Major Risk ~ PB L Pad L-109 L-109 V12 504.47 505.00 115.87 10.17 105.70 Pass: Major Risk PB L Pad ~ L-110 L-110 V11 443.88 445.00 161.15 8.18 152.97 Pass: Major Risk I PB L Pad L-112 L-112 V8 701.47 705.00 279.32 13.14 266.18 Pass: Major Risk i PB L Pad L-114 L-114 V15 935.96 935.00 236.72 13.52 223.21 Pass: Major Risk PB L Pad L-114 L-114A V4 935.96 935.00 236.72 13.52 223.21 Pass: Major Risk ', PB L Pad L-115 L-115 V7 900.04 900.00 205.44 13.53 191.91 Pass: Major Risk ~ PB L Pad L-116 L-116 V10 969.80 970.00 131.68 13.97 117.72 Pass: Major Risk PB L Pad L-117 L-117 V11 702.63 700.00 220.81 10.90 209.92 Pass: Major Risk PB L Pad L-118 L-118 V9 644.26 640.00 216.32 11.74 204.58 Pass: Major Risk j PB L Pad L-119 L-119 V9 605.10 600.00 201.87 10.17 191.71 Pass: Major Risk PB L Pad L-120 L-120 V8 561.51 555.00 222.33 9.68 212.65 Pass: Major Risk ~ PB L Pad L-121 L-121 V14 384.76 385.00 191.47 7.00 184.47 Pass: Major Risk PB L Pad L-121 L-121A V1 384.76 385.00 191.47 7.00 184.47 Pass: Major Risk PB L Pad L-122 L-122 V6 463.98 460.00 253.30 8.42 244.88 Pass: Major Risk ', PB L Pad L-200 L-200 V7 219.69 220.00 186.88 3.90 182.98 Pass: Major Risk PB L Pad L-200 L-200L1 V3 219.69 220.00 186.88 3.90 182.98 Pass: Major Risk PB L Pad L-200 L-200L2 V6 219.69 220.00 186.88 3.90 182.98 Pass: Major Risk ~ PB L Pad L-201 L-201 V6 248.60 250.00 195.59 4.39 191.20 Pass: Major Risk PB L Pad L-201 L-201 L1 V9 248.60 250.00 195.59 4.39 191.20 Pass: Major Risk PB L Pad L-201 L-201 L1 PB1 V10 248.60 250.00 195.59 4.39 191.20 Pass: Major Risk PB L Pad L-201 L-201 L2 V5 248.60 250.00 195.59 4.39 191.20 Pass: Major Risk PB L Pad L-201 L-201 L3 V2 248.60 250.00 195.59 4.39 191.20 Pass: Major Risk PB L Pad L-201 L-201 L3PB1 V6 248.60 250.00 195.59 4.39 191.20 Pass: Major Risk ' PB L Pad L-201 L-201 PB1 V12 248.60 250.00 195.59 4.39 191.20 Pass Major Risk ' BP Alaska Anticollision Report Company: BP Amoco Field: Prudhoe Bay Reference Site: f='B L Pad Reference Well: Plan L=221 (SrP) Reference N ellpatp: Plan L-221 Summary Date: 2!5/2008 Co-ordi~nate(NE) Reference: Vertical (TW) Reference: <-----=- ---~--- gffset Wellpath --- ----------> ~ Reference Offset Site Wel! Wellpat6 MA Mll ft ft PB L Pad L-201 L-201 P62 V3 248.60 250.00 PB L Pad L-202 L-202 V6 741.76 740.00 PB L Pad L-202 L-202L1 V8 741.76 740.00 PB L Pad L-202 L-202L2 V7 741.76 740.00 PB L Pad L-202 L-202L3 V8 741.76 740.00 PB L Pad L-204 L-204 V8 458.89 460.00 PB L Pad L-204 L-204L1 V5 458.89 460.00 PB L Pad L-204 L-204L2 V7 458.89 460.00 PB L Pad L-204 L-204L3 V5 458.89 460.00 PB L Pad L-204 L-204L4 V5 458.89 460.00 PB L Pad L-210 L-210 V6 554.35 550.00 PB L Pad L-210 L-210PB1 V8 554.35 550.00 PB L Pad L-211 L-211 V6 692.75 690.00 ', PB L Pad L-211 L-211 PB1 V6 692.75 690.00 ', PB L Pad L-212 L-212 V11 381.95 380.00 ', PB L Pad L-212 L-212P61 V9 381.95 380.00 PB L Pad L-212 L-212PB2 V2 381.95 380.00 I, PB L Pad L-213 L-213 V9 384.20 385.00 ', PB L Pad L-214 L-214 V9 338.56 340.00 PB L Pad L-214 L-214A V4 338.56 340.00 ', PB L Pad L-215 L-215 V7 371.35 370.00 i PB L Pad L-215 L-215PB1 V4 371.35 370.00 PB L Pad L-215 L-215PB2 V2 371.35 370.00 PB L Pad L-216 L-216 V7 243.90 245.00 PB L Pad L-217 L-217 V5 765.23 765.00 PB L Pad L-218 L-218 V5 721.75 720.00 ~, PB L Pad L-219 L-219 V10 194.23 195.00 PB L Pad L-250 L-250 V4 571.26 565.00 ', PB L Pad L-250 L-250L1 V14 571.26 565.00 PB L Pad L-250 L-250L2 V10 576.12 570.00 PB L Pad L-250 L-250P61 V4 571.26 565.00 PB L Pad L-50 L-50 V1 1454.65 1455.00 '~ PB L Pad L-50 L-50P61 V4 1454.65 1455.00 PB L Pad L-51 L-51 V6 449.26 450.00 '~~ PB L Pad Plan L-203 (N-O) Plan L-203 V6 Plan: PI 1014.31 1020.00 PB L Pad Plan L-205 (S-G) Plan L-205 OBb V6 Plan 469.09 470.00 PB L Pad Plan L-205 (S-G) Plan L-205L1 OBc V9 PI 469.09 470.00 PB L Pad Plan L-205 (S-G) Plan L-205L2 OBd V7 PI 469.09 470.00 ~~ PB L Pad Plan L-205 (S-G) Plan L-205L3 OBa V5 PI 469.09 470.00 PB L Pad Plan L-205 (S-G) Plan L-205L4 OA V4 Pla 469.09 470.00 PB L Pad Plan L-205 (S-G) Plan L-205L5 Nc V3 Pla 469.09 470.00 PB L Pad Plan L-205 (S-G) Plan L-205P61 V5 Plan: 469.09 470.00 ', PB L Pad Plan L-220 (S-I) Plan L-220 V4 Plan: PI 543.58 545.00 PB L Pad Plan L-52 (S-E) Plan L-52 V1 Plan: Pla 1111.76 1115.00 Time: 09:06:36 Page: Well: Plan L-221 (S-P), True North L-221 Plan 77.3 Db: Oracle Clr-Ctr -No-Go :111owablc Distance, Area Deviation ft ft ft __ _ 195.59 __ 4.39 _ 191.20 176.45 11.88 164.57 176.45 11.88 164.57 176.45 11.88 164.57 176.45 11.88 164.57 79.09 7.77 71.32 79.09 7.77 71.32 79.09 7.77 71.32 79.09 7.77 71.32 79.09 7.77 71.32 204.21 9.61 194.60 204.21 9.61 194.60 231.31 11.58 219.73 231.31 11.58 219.73 181.98 6.47 175.52 181.98 6.47 175.52 181.98 6.47 175.52 15.17 6.38 8.79 104.43 6.31 98.12 104.43 6.31 98.12 191.52 6.84 184.68 191.52 6.84 184.68 191.52 6.84 184.68 182.56 4.55 178.01 170.84 13.03 157.81 295.05 13.40 281.65 225.95 4.14 221.80 185.99 10.92 175.07 185.99 10.92 175.07 186.05 10.23 175.82 185.99 10.98 175.01 226.88 20.38 206.50 226.88 20.38 206.50 250.21 7.27 242.94 139.10 16.36 122.74 176.33 9.00 167.33 176.33 9.00 167.33 176.33 9.00 167.33 176.33 8.89 167.44 176.33 8.89 167.44 176.33 8.89 167.44 176.33 8.89 167.44 146.65 10.35 136.30 199.74 17.63 182.11 Warning Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk FieldPrudhoe Bay Site PB L Pad Well:Plan L-221 (S-P) WellpathElan L-221 From Surface to TD Scan interval 100 ft 157 150 100 50 0 2 50 100 150 157 0 Travelling Cylinder Azimuth (TFO+AZI) [degJ vs Centre t Target: L-221 Tgt 1 Nb ~ Site: PB L Pad ell: Plan L-221 (S-P) Drilling Target Conf.: 95% Based on: Planned Program Description: Vertical Depth: 4085.00 ft below Mean Sea Level Map Northing: 5975630.00 ft Loca] +N/-S: -2501.32 ft Map Easting : 583640.00 ft Local +E/-W: 312.88 ft Latitude: 70°20'36.154N Longitude: 149° 19' 16.192W Shape: Circle Radius: 100 ft • ~ Target: L-221 Tgt 2 OBd Site: PB L Pad Drilling Target Conf.: 95% Description: Map Northing: 5975280.00 ft Map Easting :583640.00 ft Latitude: 70°20'32.712N Shape: Circle V~ell: Plan L-221 (S-P) Based on: Planned Program Vertical Depth: 4430.00 ft below Mean Sea Level Local +N/-S: -2851.33 ft Local +E/-W: 308.98 ft Longitude: 149° 19' 16.306W Radius: 100 ft • Maunder, Thomas E {DOA) From: McVey, Adrienne [Adrienne.McVey@bp.com] Sent: Monday, March 17, 2008 10:23 AM To: Maunder, Thomas E (DOA) Subject: RE: L-221 Tom, I should also mention that I anticipate we'll be moving onto L-221 next Tuesday, March 25. Thanks, Adrienne Page 1 of 2 From: McVey, Adrienne Sent: Monday, March 17, 2008 9:27 AM To: 'Maunder, Thomas E (DOA)' Cc: Tirpack, Robert B Subject: RE: L-221 Tom, Please see responses below, and let me know if you have any further questions. Thanks, Adrienne From: Maunder, Thomas E (DOA) [maittoaom.maunder@alaska.gov] Sent: Sunday, March 16, 2008 4:06 PM To: McVey, Adrienne Cc: Tirpack, Robert B Subject: L-221 Adrienne, I am in reviewing the permit application and have some questions: 1. Could you clarify the surface cementing mixes? The lead is pretty straightforward, but are there two tail slurries? The entire tail is the same base slurry, but we add DuraSTONE as well as a viscosifier to the last 15 bbl while we are pumping. Also, I noticed that the yield and number of sacks I included for the 15.8 'G' (without DuraSTONE) was incorrect; it should be 335 sacks at 1.16 ft3/sk. 2. Regarding the paddle request, you have not included what mitigation steps will be to compensate for the lack of the paddle. I believe such steps have been included previously. Sorry for this omission. I have included these steps in the detailed well program as follows: 3/17/2008 Page 2 of 2 "While the flow paddle is removed from the flow line, ensure PVT alarms are used and the pit levels are accurately monitored for any pit gain. Visually look down the riser during connections to ensure the well is not flowing. Install the flow paddle after returned debris that could plug the flow line diminishes". 3. Although it is likely well understood by all personnel, it is probably appropriate to include the requirement for 24 hour notice on the diverter and initial BOP tests. I've noted this in the detailed well program, but will be sure to include it in future permit applications. 4. I have not noticed it previously, but "BP Amoco" is listed as the company on the anti-collision report. 5. Also, on page 1 of that report there is an overtype in the section below the header. 4 & 5: Our directional planner is making a minor tweak to the plan, and I anticipate having that final version by Wednesday. I'll request that he correct both of these errors, and can then send you an electronic copy. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 3/17/2008 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 n u 6000000 5950000 5900000 5850000 400000 500000 600000 700000 8000001 n ~~ ` ,,Alaska Department of Natural Resources Land Administration System Page 1 of 3 ~ i . ._. ~~~ ~.~ .. _ , . -~-~~~ts Flats ~?ecor~ier's S~,1rch State Cabins ~~tu~l ~'311C£+~S Alaska DNR base Summary File Type ADS File Number: 28241„ ~ Printable Case Fife. Summary See Township, Range, Section and Acreage? New search _ ~' Yes ~"'; No ___.. _._ . _._ __~ [_AS Mer~s.~ ~ Case Ahstrart I Case Detail l Banc! Abstract ~, Frle: ;~DL 2R24T '''''~ 5earcPi for Status Plat Updates ~~ ~,~ 02 ,,!BOOS Czrstonzer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 1 966 1 2/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: ~~~ OTL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/11/1965 Total Acres: 2560.000 Date Initiated: OS/28/196~ Office of P~~iinary Responsibility: DOG DIV OIL AND GAS Last TrarrsactionDate: 12/04/2006 Case Subtype: ;~;~ NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED lt-I~~riclic~n.~ li Tvtitrnship: OI1N Rrnage~ O1IE S~~r~i~>n~ 0 ,S'c~cucul,lc~res:640 Search Pints aIe~rr~lr~ul: l! 7~cni~r~.t~hi/~: O11N Range: UI l1. ,~'<<c(icur: 0~ ,S'~~ct~uu_Icrc~s: (iO0 a~l~r•r~/i<<ii.~ l~ %uirrt.e/ri~~: Ol 1N Range: Ol I F, S'~-c~~iuit: U9 ti'~~~~rc~n .Ic~r~c~~: 6-10 Mrrrclru~i: i f Ii~ir~r~~{arl,: O 11N Rur1,,c~: O l l E Section: 10 ~'crtinu .lc~~rs: 6~0 Legal Description 0~-28-1965 *'~` *S_9LE NOTICE LEUAL DESCRIPTION*"* C1 ~-20 T11N, RILE, Uti13, ~, 9, 10 2560.00 0~-01-1977 *'~`UNITIZED,LEASEANDPARTICIPATINGAREALEGALDESCRIPTION** LEASE COMMITTED IN ENTIRETY TO PR UDHOE ]3A Y UNIT AND OIL RIM UAS CAP PA PRlJrDHOE BAY ZTNIT http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28241 &... 2/27/2008 ` Alaska Department of Natural Resources Land Administration System Page 2 of 3 TRACT 51 OIL. RIMAND GAS CAP PARTICIPATING AREAS Z 11 N, R. 11 E., UMIATMERIDIAN, ALASKA SECTION 3: ALL, 6.10.00 ACRES: SECTION ~: ALL, 6=10.00 ACRES; SECTION 9: ALL, 610.00 ACRES,' SECTION 10: ALL, 6=10.00 ACRES; CONTAINING APPROXIMATEL Y 2, 560.00 ACRES, MORE OR LESS. 11-01-2001 * *FORMA PION OF BOREALIS PARTICIPATING AREA LEGAL DESCRIPTION LEASE INCORPORATED IN PART INTO THE I3PA PR UDNOF,I3AY UNIT BOREALIS PARTICIPATING AREA TR4 CT J 1 T.11 N., R.IIE., UMIAT 1LIERIDIAN, ALASKA SECTION 3: ALL, 6.10.00 ACRES: SECTION ~: NE4, N2SE4, 240.00 ACRES; SECTION 10: NE4, N2SE~, N?NW=I, 320.00 ACRES; THIS TRACT CONTAINS 1, 200.00 ACRES. MORE OR LESS. 02-01-2004 * *FORIL~ITION OF ORLON PARTICIPATING _AREA LEGAL DESCRIPTION* LEASE COMMITTED IN PART TO ORLON PARTICIPATING AREA PR UDHOE BA Y UNIT TRACT ~ 1 .ORLON PARTICIPATING AREA T. 11 1U., R. 11 ~.. UMIAT MERIDIAN, ALASKA http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28241 &... 2/27/2008 ,Alaska Department of Natural Resources Land Administration System Page 3 of 3 • SECTION 3: N2, N2S2, X80.00 ACRES; SECTION 4: NE~1, N2SE-l, 20.00 ACRES: CONTAINING APPROXIMATELY ?20.00 ACRES, MORE OR LESS. ~k x;gKMx~ ~ KY*~:;k~~*;~*~**#x*~k~*~*~=k~k*~~k*x~~**~=k*# <*#*x**~k ~kx#;~~#*#x#*~*~=~* Last updated on 02/27/2008. Not sure who to contact? Have a question about DNR? Visit the Put~lic ~..„fr~~-n~s~tc~n C:ent~r. Report technical problems with this page to the V'Ueb ~r,=`r Site optimized for Netscape 7, IE 6 or above. This site also requires that all QC3KZF must be accepted. Mate of Alaska Natural.._esources LLOS Home Copyright Privacy System_Status http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28241 &... 2/27/2008 r ~ TRANSMITTAL LETTER CHECKLIST WELL NAME /~,~~/ ~-~v~, PTD# o?O~'D~c'lC] Development _~ Service Exploratory Stratigraphic Test Non-Conventional Well d~1 ~ ~®~ , FIELD: ~,E'!/a~DE- ~iqy POOL: 0~.°/G?~ ~~~~f~ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS} TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH} and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _(Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/11/2008 ~o~ ~r,unc anv i w oRIN L-221 Program SFR Well bore seg ^ Well Name: ~ ~[(~~~ PERMIT CHECKLfST Reid & Pool PRUDHOE BAY, ORION SCHR BL OIL -640135 SER i PEND GeoArea 890______----- Unit ~~~ 0 ONOff Shore Qn _ Annular Disposal Initial ClasslType PTD#:2080310 Company BP X T A KA INC - - - - - - - - - - - - - - - - - - - NA- - -- -- -------------------------------------- Permitfeeattached- - - - - - - - - - - - - - - - - - - - Administration 1 2 Lease n9mber appropriate- - - - - - - - - - - - - - - - eS - - - - - - - - -- Yes--- - ----- - -- -- -- -- -- - - - -- - - - - -Yes _ _ . Prudhoe Bay - On9n!$chrader Bluff:_ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - 3 tlmique wellnameand numbs[ _ _ _ _ _ - - - - - - - - 4 Well located in a_defined_p9ol- - - - - - - - - - - - - - - - - - _ _ ro r distance fr9m drilling urn b9undary - - - - - - - - - - - _Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 5 Weil located p _ pe - - Yes- - --2569 acres--- - -- - - ----- -- -- -- - - -- - - - ---- 6 Well located proper distance from other wells- - - - -- - - - - - - - - - - - - - - 7 Sufficientacreags available in drilling unit- - - - - - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ----- -- K°-- ------- - - -- -- --------- -- --- ---- - - - - - - - - 8 If deviaiad, is welibore Dlai included - - - - - - - - - - - - - - - - - - - ------------------------------- 9 Operatorgnlyeff_e4tedparb+--------------- - - -- -Yes----..-BianketBond#6194193------- - ----- -- 10 Operato! has_appr9priate-bond in force . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - ~ - ---- Yes ------- - -- -- 11 Pe[mit r~l+ be issued without conservati9norder- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - • •• rover - ------Yes-- -- -- - ----- ---------- -- -- --- --- - -- - - Appr Date 12 PetmiteaD be issued without admmisttative-aAP - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ACS 212712008 13 Can permit be approved bef9re 15-daY-wait- - - - - - - - - - - - - ------------------------------ 14 Well located within area andstrata authgrized i)Y-Injeoii9n 0[der # (pert 19# in-comments)_ (F4r- Yes _ _ _ . _ .. WO-~ L-109, L-108, L-110- - - - - - - - - - - - - - - - - - - • iJA - -- -- - - ----- - - - -- - -- -- - -- - 15 Ali wells within 1f4_mile else-of review rdentlfied (F9[ seNieewell gnly) - - - - - - - - - - - - - ----------- 16 P!e-pr9duced inlector, duration of pre producti9n less than 3 montbs_ (For service well only- - -~ - - - - " " " - - - - - _ - - 17 Noncolwen, gas_c9nfgrms to A5$1,05.030ij~t.A),O.2.A-D1 _ - - - - - - Yes - - - - - - - - - - - - - --------------------- Engineering 18 Conductor string_provided _ _ _ - - - - - - - - - - - - - - - - Nq _ - - _ - - All a4uifers exempt-ed, 40 CFR_147.192_(bk3) aid AE01-- - - - - - - - - - - - - - - - - - - - - - - - - 19 Surface casia9 RrgtBCts all kno~m U&DWS - - - - - - - - - - - - - - _ Yes - - - - - - - - - - ------ No- --- - - - -- -- --- - --- -- - -- -- - 20 CMT-v91 adequate to circulate on_c9nduct9r ~ sud-cgg - - - - - - - - - - - - - - I21 CMT-vol adequate-tg fie-in Tong string to surf 9s~ _ _ - - - - - - - - - - " - - 22 CMT_wiifcovecallknown_prodpctiyeborizors_frot ---------------- --_----Yes_-- ----- -- --- ------ --- -- - --- - - -- - - - Yes _ _ _ _ - ..Rig equipped with steel pits, No reserve pd planned.- All wasfe_tg apRroved disposalwell(s _ _ _ _ _ _ _ _ _ _ _ _ _ 23 Casing des~ns adequate for C, T ~ &_perma _ s _ ' 24 Adequate iankage_or reserve pit - - - - - - - - - - - - - - - - - _ - -Yes - _ _ _ , Proximity analysis perf9rroed, Traveling cYlinde! path calculaied_ Gyros fikey,in surface hole, - _ _ - _ _ - _ _ 25 If a_ re-d[ilt has-a 10.403 for Abandgnment been approved - - - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - 26 Adequate wellbole geparakionplopg5ed- - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - 27 If diverterlequired, does it meetregulatigns_ - - - - - - - - - - - - - - - - - - - Dnllin fluid. prggram sohematic-& e4uip list adequate_ _ - - - . - - - - - Yes _ _ _ _ _ - Maximum eXpected formation R~ssure 8,7_ EMw,_ Mw Alarmed uR to 9, ppg-- - - - - - - - - - - - - - - - - Appr Date 28 9 TEM 311812008 29 80P1s,-do they meet ragirlatign _ _ - - - - - - - - - - - - - - - - ~ • 30 BOPS-press rating appropriate; test to-(put prig to comments)- - - - - - - - - - - - - - - -Yes - - - _ _ MASK calculated at 9626 psi: 41100-psi80P testplanne - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes-- - --- --- -- - -- - -- - -- - --- -- -- - ---Yes-- - - ----- -- - --- ----- - --- --- - - - - - -- - 31 Chgke-manifgid complieswfAPi_RP-53 (May a4)- - - - - - - - - - - - - - - • ration shutdown_ _ _ _ _ - _ _ _ " - - R has sersors and alarms_ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work will 9ccut with9trt ope . - _ _ _ - - - - - - - - - - - - - - Yes _ _ _ _ _ _ _ 112S is rep9rted-ai L pad. Mud shguld preclude H2$ on rg.- i9 _ 33 Is presence of H2S gas probable _ _ _ - - - - - - - int rit issues• - - - - - - - - - - - - - - - - - - - - - - - - " YeS - - _ File review_did not reveal any_ - e9 _Y- • _ m L 107=20ppm ~ 4-110=70ppm; t.121A=15ppm- - - - - - - - - - - - - - - - - - - - - - 34 Mechanical conditron 9f w?ils within AQR venfed (f9rsennce well on~J - - - - - - - - - - - - - No Max H2$well L-03-15pp _ : -- - - - NA--- - - - - -- --- - -- - -- - - -- - -- - - -- - - - - Geology 35 Rermitcan fie issued wlo hydrogensuifidemsasures _ . - - - - - - - - - ------------------------------------------- 36 Oatapresentedorpofential9verpressurezgres___----- -- ~---- - --NA--------- - ---------------- PJft.- - ------ --- ------ - -- -- - -- - - - Appr Date 37 Seismic analysis of shallow gas-z9nes_ _ - _ _ _ _ - - - - - - - - - - - - - - - - - - ACS 212712008 38 Seabed cgnditl9n survey_(if gff_-shore) _ _ _ _ _ - - - - - - - - - - -Yes - - - - - - Adrienre McVey -564-4184 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 39 Contact namefphonefor week_y-progress rep9ds [exploratory 9nhi1 - - - - - - - - - - - - - - rc Date Geologic Engineering Date C m er ~' ~ e ~ O Dale: Commissioner: /Uf Commissioner: