The URL can be used to link to this page

Home My WebLink About197-029MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 1-09A DUCK IS UNIT MPI 1-09A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 1-09A 50-029-21743-01-00 197-029-0 G SPT 9838 1970290 4700 4133 4096 4088 4069 2 2 5 4 REQVAR P Bob Noble 8/19/2024 MIT-IA as per AIO 1.016 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:DUCK IS UNIT MPI 1-09A Inspection Date: Tubing OA Packer Depth 1810 4996 4932 4901IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240820140704 BBL Pumped:13 BBL Returned:13 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 9 AIO 1.016 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 12:42:32 -08'00' From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Gas Injector DIU MPI 1-09A (PTD# 197-029): Gas Injection Monitoring and Diagnostics Date:Thursday, April 6, 2023 11:48:12 AM Attachments:image002.png image003.pngimage001.png From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, October 14, 2022 10:37 AM To: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Subject: Re: UNDER EVALUATION: Gas Injector DIU MPI 1-09A (PTD# 197-029): Gas Injection Monitoring and Diagnostics Jerimiah, Thank you for the call and discussion this morning. You are approved for continued injection while the administrative approval is being processed. Regards, Chris From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Friday, October 14, 2022 9:59:03 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: FW: UNDER EVALUATION: Gas Injector DIU MPI 1-09A (PTD# 197-029): Gas Injection Monitoring and Diagnostics Mr. Wallace, Per our conversation, END1-09 (PTD# 197-029) has been on injection for its evaluation period (Expires 10/16/2022). Hilcorp requests to continue injection while the Administrative Approval is in the approval process. Please respond if you have any questions or concerns. Jerimiah Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, September 13, 2022 7:46 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Subject: RE: UNDER EVALUATION: Gas Injector DIU MPI 1-09A (PTD# 197-029): Gas Injection Monitoring and Diagnostics Mr. Wallace, END1-09 (PTD# 197-029) has been on injection for a period of 28 days. Below is a TIO plot for that period of time. At this time, Hilcorp requests to continue to injection for the remainder of the 60 day period. An MIT-IA passed on 8/27/2022 and the IA pressure appears to remain stable once the well is up to injection pressure. Plan forward is to stabilize injection after the plant upset and bleed the IA pressure to ~300-500 psi and monitor for any repressurization. Please respond if you have any questions or concerns. I will follow up with you this morning. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From: Jerimiah Galloway Sent: Wednesday, August 10, 2022 10:19 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: 'melvin.rixse@alaska.gov' <melvin.rixse@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector DIU MPI 1-09A (PTD# 197-029): Gas Injection Monitoring and Diagnostics Mr. Wallace, The surface work has been completed for this project and the well is ready to be brought on injection for the UNDER EVALUATION period. Per previous agreement below, TIO plots and an update will be sent after 28 days. The well is now classified as UNDER EVALUATION and will be placed on injection for a period not to exceed 60 days. Please respond if you have any questions. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Tuesday, January 4, 2022 12:46 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: Not Operable: Gas Injector DIU MPI 1-09A (PTD# 197029) AOGCC witnessed offline pressure test Oliver, Looking back over the well history it appears gas lift mandrels had issues in the past. You are approved for gas injection for monitoring and diagnostics. Please send a TIO plot after 28 days with a thorough path forward for the remaining monitoring period. 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, January 4, 2022 10:50 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Not Operable: Gas Injector DIU MPI 1-09A (PTD# 197029) AOGCC witnessed offline pressure test Mr. Wallace, Gas Injector DIU MPI 1-09A (PTD# 197029) is currently Not Operable due to showing slow TxIA communication while on gas injection in late 2016. On 12/15/2021 a non-state witnessed MIT-T passed to 4550 psi and a CMIT-TxIA passed to 4693 psi in preparation for a state witnessed MIT-T and CMIT-TxIA. Hilcorp requests permission to place 1-09A on gas injection Under Evaluation for up to 60 days to evaluate the IA repressurization rate and determine if an AA request is appropriate for continued operation of the well pending the results of the state witnessed MIT-T and CMIT. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,072 feet 11,885 feet true vertical 10,257 feet unknown feet Effective Depth measured 12,585 feet 7,892, 11,447, 11,870 feet true vertical 10,170 feet 7,329, 9,837, 10,070 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 11,506' 9,879' 9-5/8" Bkr ZXP LTP Packers and SSSV (type, measured and true vertical depth) 7" Baker S-3, 4- 1/2" TIW 4-1/2" HXO SVLN See Above 1,541' MD / 1,540' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: ENDICOTT OIL 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: NA Sr Pet Eng: 7,500psi Sr Pet Geo: Sr Res Eng: WINJ WAG 54707 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jerimiah Galloway jerimiah.galloway@hilcorp.com 907-564-5005 N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 183 Gas-Mcf MD 1120 Size 131' 59 121252031 193 175454 1742 measured TVD 9-5/8" 8,430psi 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 179-029 50-029-21743-01-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0312828 ENDICOTT / ENDICOTT OIL DUCK IS UNIT MPI 1-09A Plugs Junk measured Length Intermediate Liner 8,081' 4,041' 715' Casing 7,469' 10,087' 4-1/2" 8,081' 11,933' 12,585' 10,170' 2,510' 131'Conductor Surface Intermediate 30" 13-3/8" 131' 4,760psi 5,410psi 5,020psi 6,870psi 7,240psi 2,510' 2,508' Burst Collapse 2,260psi PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Meredith Guhl at 9:11 am, Feb 08, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.02.08 07:46:23 -09'00' Torin Roschinger (4662) RBDMS JSB 021423 197-029 MGR03MAR2023 DSR-2/8/23 Well Name Rig API Number Well Permit Number Start Date End Date END 1-09A Slickline 50-029-21743-01-00 197-029 1/14/2023 1/17/2023 PULLED 4-1/2" MCX W/ CARRIER FROM SSSV NIP @ 1,504' SLM (1,541' MD), ALL PACKING & PINS RECOVERED.(ser# NM-23). RAN KJ, 4-1/2" TEL, 3.62" CENT, 3'x1-7/8" STEM, 3.68" CENT, 3" LIB, UNABLE TO PASS 7,491' SLM /~7,526' MD (LIB has fill impression on face). RAN KJ, 3' x 1-7/8" STEM, 4-1/2" BRUSH, 2.50" SAMPLE BAILER & SD 7,491' SLM (very little recovery). RAN 10' x 2.50" PUMP BAILER TO 7491' SLM (1 cup white powder / possibly scale). RAN KJ, 4-1/2" OM-1 & 1.75" LIB LOC & SD IN STA.# 4 @ 6,500' SLM (6,541' MD) LOC & SD IN. STA# 6 @ 3,534' SLM (3,575' MD) (verify 41' corr and mandrel). RAN 3.65" CENT, 10' x 1.75" DD BAILER, MSBB, BREAK BRIDGE AT 7,491' SLM, S/D AGAIN AT 8,227' SLM, UNABLE TO PASS. T-BIRD PUMPED 58bbls DIESEL DOWN TUBING. RAN 10'x2.5" DRIVE DOWN BAILER W/ MULE SHOE FLAPPER, S/D @ 11,868' SLM TOOLS BOBBLE PAST, S/D @ 11,882' SLM, UNABLE TO WORK PAST, RECOVERED ~4 CUPS SHMOO. 1/14/2022 - Saturday RAN 10' x 2.50" DRIVE DOWN BAILER, MSFB DOWN TO 11,891' SLM (unable to work deeper). RAN KJ, 3.68" CENT, 1-7/8" STEM, 3.70 LIB, S/D @ 11,882' SLM, HAVE IMPRESSION OF LINER TOP (from 11827' slm). RAN KJ, KJ, XO, 2.25" CENT, 4-1/2" BOW SPRING (4 springs), XO, 4-1/2" BOW SPRING (5 springs), XO, 1-3/4" SAMPLE BAILER & S/D @ 11,893' SLM, UNABLE TO WORK PAST, BAILER EMPTY, HAVE METAL MARK ON BOTTOM. RAN KJ, KJ, XO, 2.25" CENT, 4-1/2" BOW SPRING, (4 spring), XO, 4-1/2" BOW SPRING, (5 spring), 3.50" LIB & SD @ 11,887, UNABLE TO WORK PAST, HAVE IMPRESSION EDGE OF LINER TOP.(from 11,827 no WRP). RAN 10 x 3.70" DMY WHIP STOCK DRIFT, UNABLE TO WORK PAST 11,836' SLM.(EVO Drift, dog leg / dev). RAN KJ, 8' x 2-1/8" STEM, QC, XO 3.63" CENT, 6' x 1-1/2" STEM, 3.68" CENT, SD @ 11,891' SLM & WORK TOOLS DOWN TO 11,893' SLM (EVO Drif)t . RAN KJ, HES 40 ARM CALIPER DOWN TO 11,890' SLM, & LOG UP THROUGH TUBING TAIL (good data capture lower liner ). 1/15/2023 - Sunday RAN KJ, 4-1/2" TEL, 3.62" CENT, 3'x1-7/8" STEM, 3.68" CENT, 2.25" LIB, LOC TUBING TAIL @ 11,462' SLM (11,506' MD 44'corr), S/D PACKER @ 11,827' SLM (11,870' MD / 365' impression of packer). RAN 10'x2.5" PUMP BAILER W/ MULE SHOE BALL & S/D @ 11,882' SLM, MAKE IT TO ~11,884' SLM, RECOVERED SMALL AMOUNT OF SHMOO & MULTIPLE SMALL PIECES OF V- PACKING. RAN 10' x 2.5" PUMP BAILER, W/ 4-1/2" WRP EQ SLV, S/D @ 11,882' SLM, TATTLE TAIL PINS NOT SHEARED. B&F TBG W/ 4-1/2" BRUSH, 3.50" G-RING W/ T-BIRDS ASSISTANCE, PUMPED A TOTAL OF 180bbls OF DIESEL TO 11882 SLM. RAN 2.5" PUMP BAILER 2 TIMES DOWN TO 11,882" SLM, (dev 77). RAN HES 40 CALIPER DOWN TO 11,827' SLM( 11,870'MD Top of Paker, unable to enter paker & liner) & LOGGED TO SURFACE(good data) W/ tie in appears WRP blew down +44' from set depth. 1/16/2023 - Monday Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 1-09A Slickline 50-029-21743-01-00 197-029 1/14/2023 1/17/2023 Hilcorp Alaska, LLC Weekly Operations Summary RAN 4-1/2" 45KB PACKER DRIFT, S/D @ 11,857' SLM, WORK TOOLS DOWN TO 11,882' SLM, UNABLE TO WORK PAST. SET 4- 1/2" EVO TRIEVE PLUG IN LINER @ 11,841' SLM, 11,885' MD (middle first full joint below packer)(oal-73", 2-3/8" g-f/n to eq and pull). SET 4-1/2" MCX IN SVLN @ 1,501' SLM / 1,541 MD (ser.# NM-23, stl sec. lockdown installed, 1.55 bean). PERFORMED PASSING 400psi DRAW DOWN TEST ON MCX (pad-op witnessed). 1/17/2023 - Tuesday _____________________________________________________________________________________ Updated By: DH 2/6/2023 SCHEMATIC Endicott Well: END 1-09A Last Completed: 3/24/1997 PTD: 197-029 TD =13,072’ (MD) / TD =10,257’(TVD) 20” KB Elev.: 55.85’/ BF Elev.: 18.2’ 7” 3 5 6 8 9 10 11 12 13 9-5/8” 1 2 14 15 16 WRP depth unknown PBTD =12,585’(MD) / PBTD = 10,170’(TVD) 4 Kek K2A Sands 4-1/2” 13-5/8” 7 Kek K1 Sands CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 30" Conductor N/A / N/A / N/A N/A Surface 131’ 13-3/8” Surface 68/ L-80/ Btc 12.415 Surface 2,510’ 9-5/8" Intermediate 47 / L-80 / Btc-M. 8.681 Surface 8,081’ 7" Production 26/ L-80/ Hydril 521 6.276 7,892’ 11,933’ 4-1/2” Liner 12.6/ L-80/ NSCT 3.958 11,870’ 12,585’ 4-1/2" Tubing 12.6/ L-80/ NSCT 3.958 Surface 11,506’ JEWELRY DETAIL No Depth Item 1 1,541’ 4-1/2”HXO SVLN, ID= 3.813” 2 2,850’ 4-1/2” L-80 NSCT XO to BTC-M 33,575’Sta #6 GLM – MMGM Dummy w/ RK Latch, DEV=7 Set DMY w/ Campack Packing 12/4/18 4 5,348’ Sta #5 GLM – MMGM Dummy w/ RK Latch, DEV=15 5 6,541’ Sta #4 GLM – MMGM Dummy w/ RK Latch, DEV=43 67,526’Sta #3 GLM – MMGM Dummy w/ RK Latch, DEV=45 Set DMY w/ Campack packing on 12/4/18 7 7,892’ 9-5/8” x 7” Bkr ZXP LTP w/ HMC Liner Hanger 8 8,469’ Sta #2 GLM – KGB2 Dummy w/ INT Latch, DEV=46 9 9,456’ Sta #1 GLM – KGB2 Dummy w/ INT Latch, DEV=44 10 11,437’ 4-1/2” HES X Nipple, ID=3.813” (11447’ elm – logged on 9/8/98) 11 11,447’ 7” x 4-1/2” BKR S-3 Packer, ID= 3.875” 12 11,471’4-1/2” HES X Nipple, ID= 3.813” (11504’ elm logged on 9/8/98) 13 11,493’ 4-1/2” HES XN Nipple,ID= 3.725” 14 11,506’ 4-1/2” WLEG, ID=3.958 (11515’ elm logged on 9/8/98) 15 11,870’ 4-1/2” TIW Horizontal Packer, ID= 4.00 16 11,885’ 4-1/2” EVO-Trieve Plug set on 1/17/2023 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kekiktuk K2A 11,819 11,824’ 10,052’ 10,054’ 5 6/13/2012 Open Kekiktuk K1 11,976’ 12,562’ 10,096’ 10,167’ 86 3/20/1997 Isolated OPEN HOLE / CEMENT DETAIL 13-3/8” 4,185 c.f. Class ‘G’ in 17-1/2” Hole 9-5/8" 575 c.f. ‘G’ in a 12-1/4” Hole 7” 314 c.f. Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL Max Hole Angle = 84deg. @ 12,544’ Angle at Top Perf = 20 Deg. @ 16,775’ TREE & WELLHEAD Tree 4-1/16 CIW 6.5K Wellhead FMC GENERAL WELL INFO API: 50-029-21743-01-00 Initial Completion – 9/11/1987 Sidetrack – 3/24/1997 Set WRP – 4/7/2012 GLV C/O – 5/9/2012 Add Perfs – 6/13/2012 Set WRP – 5/9/2012 GLV C/O – 12/4/2013 Set Downhole Choke – 3/15/2014 Pull/ Set Downhole Choke – 3/28/2014 Set EVO-Trieve Plug – 1/17/2023 Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 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: 01/23/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230123 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 1-09A 50029217430100 197029 1/15/2023 HALLIBURTON MFC40 END 1-09A 50029217430100 197029 1/16/2023 HALLIBURTON MFC40 MPU C-41 50029230140000 201078 1/16/2023 HALLIBURTON COILFLAG PBU W-06B 50029218220200 222099 1/6/2023 BAKER MRPM Please include current contact information if different from above. By Meredith Guhl at 7:48 am, Jan 24, 2023 T37460 T37460 T37461 T37462 END 1-09A 50029217430100 197029 1/15/2023 HALLIBURTON MFC40 END 1-09A 50029217430100 197029 1/16/2023 HALLIBURTON MFC40 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.24 07:55:44 -09'00' From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Gas Injector DIU MPI 1-09A (PTD# 197-029): Gas Injection Monitoring and Diagnostics Date:Wednesday, October 19, 2022 8:46:17 AM Attachments:image003.png image004.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Friday, October 14, 2022 9:59 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: FW: UNDER EVALUATION: Gas Injector DIU MPI 1-09A (PTD# 197-029): Gas Injection Monitoring and Diagnostics Mr. Wallace, Per our conversation, END1-09 (PTD# 197-029) has been on injection for its evaluation period (Expires 10/16/2022). Hilcorp requests to continue injection while the Administrative Approval is in the approval process. Please respond if you have any questions or concerns. Jerimiah Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, September 13, 2022 7:46 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Subject: RE: UNDER EVALUATION: Gas Injector DIU MPI 1-09A (PTD# 197-029): Gas Injection Monitoring and Diagnostics Mr. Wallace, END1-09 (PTD# 197-029) has been on injection for a period of 28 days. Below is a TIO plot for that period of time. At this time, Hilcorp requests to continue to injection for the remainder of the 60 day period. An MIT-IA passed on 8/27/2022 and the IA pressure appears to remain stable once the well is up to injection pressure. Plan forward is to stabilize injection after the plant upset and bleed the IA pressure to ~300-500 psi and monitor for any repressurization. Please respond if you have any questions or concerns. I will follow up with you this morning. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From: Jerimiah Galloway Sent: Wednesday, August 10, 2022 10:19 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: 'melvin.rixse@alaska.gov' <melvin.rixse@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector DIU MPI 1-09A (PTD# 197-029): Gas Injection Monitoring and Diagnostics Mr. Wallace, The surface work has been completed for this project and the well is ready to be brought on injection for the UNDER EVALUATION period. Per previous agreement below, TIO plots and an update will be sent after 28 days. The well is now classified as UNDER EVALUATION and will be placed on injection for a period not to exceed 60 days. Please respond if you have any questions. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Tuesday, January 4, 2022 12:46 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: Not Operable: Gas Injector DIU MPI 1-09A (PTD# 197029) AOGCC witnessed offline pressure test Oliver, Looking back over the well history it appears gas lift mandrels had issues in the past. You are approved for gas injection for monitoring and diagnostics. Please send a TIO plot after 28 days with a thorough path forward for the remaining monitoring period. 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, January 4, 2022 10:50 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Not Operable: Gas Injector DIU MPI 1-09A (PTD# 197029) AOGCC witnessed offline pressure test Mr. Wallace, Gas Injector DIU MPI 1-09A (PTD# 197029) is currently Not Operable due to showing slow TxIA communication while on gas injection in late 2016. On 12/15/2021 a non-state witnessed MIT-T passed to 4550 psi and a CMIT-TxIA passed to 4693 psi in preparation for a state witnessed MIT-T and CMIT-TxIA. Hilcorp requests permission to place 1-09A on gas injection Under Evaluation for up to 60 days to evaluate the IA repressurization rate and determine if an AA request is appropriate for continued operation of the well pending the results of the state witnessed MIT-T and CMIT. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Gas Injector DIU MPI 1-09A (PTD# 197-029): Gas Injection Monitoring and Diagnostics Date:Tuesday, September 13, 2022 9:57:17 AM Attachments:image003.png From: Wallace, Chris D (OGC) Sent: Tuesday, September 13, 2022 9:56 AM To: 'Jerimiah Galloway' <Jerimiah.Galloway@hilcorp.com> Subject: RE: UNDER EVALUATION: Gas Injector DIU MPI 1-09A (PTD# 197-029): Gas Injection Monitoring and Diagnostics Jerimiah, Your request to continue injection up to the remainder of the 60 days 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: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Tuesday, September 13, 2022 7:46 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: UNDER EVALUATION: Gas Injector DIU MPI 1-09A (PTD# 197-029): Gas Injection Monitoring and Diagnostics Mr. Wallace, END1-09 (PTD# 197-029) has been on injection for a period of 28 days. Below is a TIO plot for that period of time. At this time, Hilcorp requests to continue to injection for the remainder of the 60 day period. An MIT-IA passed on 8/27/2022 and the IA pressure appears to remain stable once the well is up to injection pressure. Plan forward is to stabilize injection after the plant upset and bleed the IA pressure to ~300-500 psi and monitor for any repressurization. Please respond if you have any questions or concerns. I will follow up with you this morning. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Wednesday, August 10, 2022 10:19 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: 'melvin.rixse@alaska.gov' <melvin.rixse@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector DIU MPI 1-09A (PTD# 197-029): Gas Injection Monitoring and Diagnostics Mr. Wallace, The surface work has been completed for this project and the well is ready to be brought on injection for the UNDER EVALUATION period. Per previous agreement below, TIO plots and an update will be sent after 28 days. The well is now classified as UNDER EVALUATION and will be placed on injection for a period not to exceed 60 days. Please respond if you have any questions. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Tuesday, January 4, 2022 12:46 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: Not Operable: Gas Injector DIU MPI 1-09A (PTD# 197029) AOGCC witnessed offline pressure test Oliver, Looking back over the well history it appears gas lift mandrels had issues in the past. You are approved for gas injection for monitoring and diagnostics. Please send a TIO plot after 28 days with a thorough CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. path forward for the remaining monitoring period. 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, January 4, 2022 10:50 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Not Operable: Gas Injector DIU MPI 1-09A (PTD# 197029) AOGCC witnessed offline pressure test Mr. Wallace, Gas Injector DIU MPI 1-09A (PTD# 197029) is currently Not Operable due to showing slow TxIA communication while on gas injection in late 2016. On 12/15/2021 a non-state witnessed MIT-T passed to 4550 psi and a CMIT-TxIA passed to 4693 psi in preparation for a state witnessed MIT-T and CMIT-TxIA. Hilcorp requests permission to place 1-09A on gas injection Under Evaluation for up to 60 days to evaluate the IA repressurization rate and determine if an AA request is appropriate for continued operation of the well pending the results of the state witnessed MIT-T and CMIT. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, September 15, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 1-09A DUCK IS UNIT MPI 1-09A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2022 1-09A 50-029-21743-01-00 197-029-0 G SPT 9838 1970290 2500 3957 3960 3954 3952 106 106 106 107 OTHER P Bob Noble 8/27/2022 MIT-IA to 2500 psi for eval 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:DUCK IS UNIT MPI 1-09A Inspection Date: Tubing OA Packer Depth 1454 2762 2716 2705IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220827140152 BBL Pumped:4.2 BBL Returned:4.1 Thursday, September 15, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 for eval James B. Regg Digitally signed by James B. Regg Date: 2022.09.15 12:33:48 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20220810 1020 Notify UNDER EVALUATION_ Gas Injector DIU MPI 1-09A (PTD# 197-029)_ Gas Injection Monitoring and Diagnostics Date:Wednesday, August 10, 2022 10:33:46 AM Attachments:image001.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Wednesday, August 10, 2022 10:19 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector DIU MPI 1-09A (PTD# 197-029): Gas Injection Monitoring and Diagnostics Mr. Wallace, The surface work has been completed for this project and the well is ready to be brought on injection for the UNDER EVALUATION period. Per previous agreement below, TIO plots and an update will be sent after 28 days. The well is now classified as UNDER EVALUATION and will be placed on injection for a period not to exceed 60 days. Please respond if you have any questions. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Tuesday, January 4, 2022 12:46 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: Not Operable: Gas Injector DIU MPI 1-09A (PTD# 197029) AOGCC witnessed offline pressure test Oliver, Looking back over the well history it appears gas lift mandrels had issues in the past. You are approved for gas injection for monitoring and diagnostics. Please send a TIO plot after 28 days with a thorough path forward for the remaining monitoring period. 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, January 4, 2022 10:50 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Not Operable: Gas Injector DIU MPI 1-09A (PTD# 197029) AOGCC witnessed offline pressure test Mr. Wallace, Gas Injector DIU MPI 1-09A (PTD# 197029) is currently Not Operable due to showing slow TxIA communication while on gas injection in late 2016. On 12/15/2021 a non-state witnessed MIT-T passed to 4550 psi and a CMIT-TxIA passed to 4693 psi in preparation for a state witnessed MIT-T and CMIT-TxIA. Hilcorp requests permission to place 1-09A on gas injection Under Evaluation for up to 60 days to evaluate the IA repressurization rate and determine if an AA request is appropriate for continued operation of the well pending the results of the state witnessed MIT-T and CMIT. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have receivedthis message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if thesender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will notadversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, February 3, 2022 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 1-09A DUCK IS UNIT MPI 1-09A Sre: Inspector Reviewed By: P.I. Supry 3 Comm Well Name DUCK IS UNIT MPI 1-09A API Well Number 50-029-21743-01-00 Inspector Name: Matt Herrera Permit Number: 197-029-0 Inspection Date: 1/8/2022 Insp Num: mitMFH220112070952 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 1-09A PTD 1970290 ypTest7NTIV D 9838 Tubin zo79 2790 2819 - 2835 - 4soo IA Well T e Ing1ss 4735- 4643 4604st st Typep — 12.4 OA 88 87 88 88 - BBL Pumped. 12 ,BBL Returned L P/F P OTHER - ' Interval Notes: MIT -IA performed. MIT due 12/2019; well SI since 12/2016 v Thursday, February 3, 2022 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, February 3, 2022 TO: Jim Regg P.I. Superyisor�(q Z( 7c�l�Zi SUBJECT: Mechanical Integrity Tests (( Hilcorp Alaska, LLC 1-09A FROM: Matt Herrera DUCK IS UNIT MPI 1-09A Petroleum Inspector Sre: Inspector Reviewed By: P.I. Suprv.- NON -CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 1-09A API Well Number 50-029-21743-01-00 Inspector Name: Matt Herrera Permit Number: 197-029-0 Inspection Date: 1/8/2022 - Insp Num: mitMFH220112065920 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-09A Type Inj N. TVD 9838 Tubing 37 4703 -- 4552 4500 - PTD 1970290 Type Test SPT Test psi 4500 IA 120 _ 282 - 290 - 284 - BBL Pumped: 3 - BBL Returned: 2 OA 85 85- 87 - s7 - Interval OTHER P/F P Notes: MIT -T performed. MIT due 12/2019; well SI since 12/2016. Tubing pressure bled down to 2000PSI for subsequent MIT -IA Thursday, February 3, 2022 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Not Operable: Gas Injector DIU MPI 1-09A (PTD# 197029) AOGCC witnessed offline pressure test Date:Tuesday, January 4, 2022 1:35:42 PM Attachments:image001.png From: Wallace, Chris D (OGC) Sent: Tuesday, January 4, 2022 12:46 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: Not Operable: Gas Injector DIU MPI 1-09A (PTD# 197029) AOGCC witnessed offline pressure test Oliver, Looking back over the well history it appears gas lift mandrels had issues in the past. You are approved for gas injection for monitoring and diagnostics. Please send a TIO plot after 28 days with a thorough path forward for the remaining monitoring period. 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, January 4, 2022 10:50 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Not Operable: Gas Injector DIU MPI 1-09A (PTD# 197029) AOGCC witnessed offline pressure test Mr. Wallace, Gas Injector DIU MPI 1-09A (PTD# 197029) is currently Not Operable due to showing slow TxIA communication while on gas injection in late 2016. On 12/15/2021 a non-state witnessed MIT-T passed to 4550 psi and a CMIT-TxIA passed to 4693 psi in preparation for a state witnessed MIT-T and CMIT-TxIA. Hilcorp requests permission to place 1-09A on gas injection Under Evaluation for up to 60 days to evaluate the IA repressurization rate and determine if an AA request is appropriate for continued operation of the well pending the results of the state witnessed MIT-T and CMIT. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will notadversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. • II Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, December 07, 2016 9:54 AM To: Wallace, Chris D (DOA) Cc: Regg,James B (DOA) Subject: RE: END 1-09A (PTD# 1970290) Shut In for IA Pressurization Attachments: MPI 1-09A TIO.XLSX Chris, Endicott gas injector 1-09A(PTD# 1970290) returned to injection on 11/22/16 for monitoring following a GLV changeout.The well appeared to stabilize initially and on 11/26/16 five bbls of diesel were pumped to fluid pack the IA in support of an upcoming MIT. Following the fluid pack, the IA began pressurizing with fluid bleeds on 11/28 and 12/1. However pressurization continued and most recently the IA was bled on 12/6/16 with some gas returns. Pressurization appears to be greater and of a longer duration than thermal effects therefore the well was shut in last night, 12/6/16. A TIO plot is attached for reference. Going forward, a differential will be placed between the TBG and IA and the IA will be monitored with the well to remain shut-in. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 �lilcorp Ala ka SCANNED MAY 0 12017 From: Wyatt Rivard t: Friday, November 18, 2016 9:30 AM To: ' ce, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Regg,JameOA)<jim.regg@alaska.gov>; Brooks, Phoebe L(DOA)<phoebe.brooks@alaska.gov> Subject: RE: END 1-0' • 'TD# 1970290) Request to Return to Injection Chris, The last witnessed MIT-IA was on 7/4/2015 passin: • 2464 psi.We can plan to notify for witnessed MIT-IA as soon as we have a few days of stable injection with no initial in•i : ors of IA pressurization. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 II Hilcorp Alaska • TOZ/90/ZT -- 9T0Z/170/ZT - 9TOZ/Z0/ZT - 9TOZ/0£/TT - 9t0Z/8Z/TT - 9T0Z/9Z/TT 9TOZ/17Z/TT 9TOZ/ZZ/TT c 0.01••••.-- 9TOZ/OZ/TT ' - 9TOZ/8T/TT 9TOZ/9T/TT 9TOZ/17T/TT 9TOZ/ZT/TT - 9T0Z/OT/TT - 9TOZ/80/TT - 9TOZ/90/TT - 9T0Z/170/TT - 9T0Z/ZO/TT < - 9TOZ/T£/OT - 9T0Z/6Z/OT I - 9T0Z/LZ/OT - 9TOZ/SZ/OT 9TOZ/£Z/OT o _ 9T0Z/TZ/OT 9T0Z/6T/OT 9T0Z/LT/OT 2 - 9TOZ/ST/OT _ 9TOZ/£T/OT 9TOZ/TT/OT - 910Z/60/01 - 9T0Z/L0/0T - 9TOZ/SO/OT - 9TOZ/£0/OT - 9TOZ/TO/OT - 910Z/6Z/60 - 9T0Z/LZ/60 en - 9TOZ/SZ/60 6 - 9TOZ/£Z/60 F- 9T0Z/TZ/60 910Z/61/60 - 9-10Z/LT/60 - 9TOZ/ST/60 - 9TOZ/£T/60 - 9T0Z/TT/60 - 910Z/60/60 9T0Z/L0/60 00 0 0 0 0 0 0 0 0 0 0 l0 Lr V Cr; aJnssaad S • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, November 18, 2016 8:35 AM To: Wallace, Chris D (DOA) Cc: Regg,James B (DOA); Brooks, Phoebe L(DOA) Subject: END 1-09A (PTD# 1970290) Request to Return to Injection Attachments: MIT END MPI 1-09A 11-13-16.xls; END 1-09A SCHEMATIC 10-8-2015.pdf; END 1-09A TIO.xlsx; LDL Summary END1-09A 10-30-16.pdf Chris, Endicott gas injector 1-09A(PTD# 1970290) has been shut-in since 12/15/15 for TxIA communication. An acoustic leak detect log run on 10/30/16 observed a leak under gas in GLM #6 at 3575'.The GLV was subsequently changed out on 11/7/16 and the well was left with a ^'3000 psi gas differential on the tubing for monitoring. A diagnostic MIT-IA to 2500 psi passed with diesel on 11-13-16.There has been no additional IA pressurization observed since the GLV change out. The MIT form,TIO,Schematic and LDL summary are attached for reference. Going forward, Hilcorp requests permission to return END 1-09A to injection for a 28 day monitoring period. Monitoring results will be provided at 28 days with the well shut-in at any indication of further TxIA communication. Please call with any questions. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com SCAN NOV 2 22016 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Hilcorp Alaska From:Wyatt Rivard N"--„Sent: Monday, December 21, 2015 1:03 PM To 'Wallace, Chris D (DOA)'<chris.wallace@alaska.gov> Cc: Regg,James B(DOA)<jim.regg@alaska.gov> Subject: RE: MPI 1-09A(PTD#1970290)Shut In For Continued IA Pressurization Chris, Gas injector MPI 1-09A(PTD# 1970290)was.placed on injection on 12/11/15 for monitoring following the reset of a damaged gas lift valve at 7526'.The well was subsequently shut-in on 12/15/15 for injection valve troubleshooting.After the well had been shut-in, inner annulus pressurizatio`T.ras observed at roughly—500 psi/day(TIO attached, note tubing pressure while SI is above the swab valve).A plug was then -t below the packer on 12/19/15 and on 12/20/15 the gas lift valve at 7526'was reset with extended packing. Going forward, a differential will be placed between the TBG and IA and the : will be monitored for further pressurization with the well shut-in.A new request will be made prior to any ret • to injection for additional monitoring. 1 • • • A4 cow) ( q.A /q70-2_10, Regg, James B (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, December 21, 2015 1:03 PM P � (*/�iS To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA) Subject: RE: MPI 1-09A (PTD# 1970290) Shut In For Continued IA Pressurization Attachments: 1-09A TIO.xlsx Chris, Gas injector 11"1-09A(PTD# 1970290) was placed on injection on 12/11/15 for monitoring following the reset of a damaged gas lift valve at 7526'.The well was subsequently shut-in on 12/15/15 for injection valve troubleshooting.After the well had been shut-in, inner annulus pressurization was observed at roughly"'500 psi/day(TIO attached, note tubing pressure while SI is above the swab valve). A plug was then set below the packer on 12/19/15 and on 12/20/15 the gas lift valve at 7526' was reset with extended packing. Going forward, a differential will be placed between the TBG and IA and the IA will be monitored for further pressurization with the well shut-in. A new request will be made prior to any return to injection for additional monitoring. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 j C: (509)670-8001 I wrivard@hilcorp.com 3800 Center point Drive,Suite 1400 I Anchorage,AK 99 503 SCANNED . ilii.wp k1 , L14 From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Friday, December 04, 2015 1:17 PM To: Wyatt Rivard Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: RE: MPI 1-09A (PTD # 1970290) Request to Return to Injection Wyatt, Your request to return to injection is approved. Please ensure you send a follow up TIO at the 28 day point and let us know if there is any anomaly seen earlier. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue • Anchorage,AK 99501 1 • • (907)7934250(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: Wyatt Rivard [mailto:wrivardhilcorp.com] Sent: Friday, December 04, 2015 12:16 PM To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA); Brooks, Phoebe L(DOA) Subject: MPI 1-09A (PTD # 1970290) Request to Return to Injection Chris, Endicott injector MPI 1-09A(PTD# 1970290)was shut-in on 8/17/15 for confirmed inner annulus pressurization under gas injection. Follow-up diagnostics indicated a TxIA leak attributed to a damaged dummy gas lift valve.The GLV was replaced and passing diagnostic MIT-IA obtained, demonstrating two competent barriers. Going forward, we would like to return the well to injection. Monitoring results will be provided at 28 days with the well shut-in if there is any further indication of annular pressurization over the monitoring period. Diagnostics performed to Date: - 8/30/15: Tubing Hanger void test passed to 6000 psi for 30 minutes. - 10/13/15:TTP set in XN nipple at 11,493'.Tubing and IA pressure bled and monitored (TIO plot attached). Please note, plotted tubing pressure reflects pressure above closed swab valve only. No further pressurization was observed in the Inner Annulus, confirming leak is TxIA and not packer. - 11/26-11/28/15: Dummy GLV reset at 7526'. Old valve packing showed damage.TTP pulled, well left with 2750 psi differential on the tubing T/I/0 = 2850/100/0 - 12/3/15:Tubing maintaining differential with IA.Obtain passing MIT-IA to 2593 psi (attached for reference). Please call with any questions. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-85471C: (509)670-8001 I wrivarclPhilcorp.com 3800 Centerpornt Drive,Suite 140{) 1 Anchorage,AK 99503 11. 1Iik Grp .'1/4144a* Elk 2 • • aWnlo,\ v- a 0 0 0 0 0 0 00 r` m m NLri vi o �' 1 1 1 I . . , i . . . ! StOz/tZ/zt Stoz/6t/zt StOZ/Lt/Zt StOZ/St/Zt StOZ/£t/Zt stoz/tt/zt StOZ/60/Zt _ SEOZ/LO/Zt c stoz/so/Zt SIOZ/£0/Zt stoZ/t0/zt StOZ/6Z/tt StOZ/LZ/tt Stoz/Sz/tt STOZ/£Z/tt SIOZ/tZ/tT StOZ/6t/tt SIOZ/Lt/tt Q SIOZ/St/tt I -, STOZ/£t/tt El= StoZ/tt/tt 0_ STOZ/60/tt P' STOZ/LO/tt rn sioZ/so/tt 0 il stoz/£o/tt stoz/to/tt Stoz/o£/ot < 4 SIOZ/8Z/ot SIOZ/9Z/Ot stoz/bz/ot STOZ/ZZ/ot stoz/oz/ot sTOZ/8t/OT SIOZ/9t/Ot SIOZ/bt/Ot SIOZ/Zt/Ot ou SIOZ/Ot/Ot 3 r SIOZ/80/OtI- -SIOZ/90/0t I FF St Oz/b0/ot sioz/z0/Ot - SIOZ/O£/60 E SIOZ/8Z/60 SIOZ/9Z/60 SIOZ/bZ/60 ; SIOZ/ZZ/60 0 0 0 0 0 0 0 0 0 0 0 L 00 8 Ln V ni cri N N N .-i aanssaad • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Friday, December 04, 2015 1:17 PM To: 'Wyatt Rivard' Cc: Regg,James B (DOA); Brooks, Phoebe L (DOA) Subject: RE: MPI 1-09A (PTD# 1970290) Request to Return to Injection Wyatt, Your request to return to injection is approved. Please ensure you send a follow up TIO at the 28 day point and let us know if there is any anomaly seen earlier. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission p AUG 1 0 ZQ16 333 West 7`"Avenue SCAMS 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: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Friday, December 04, 2015 12:16 PM To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: MPI 1-09A (PTD # 1970290) Request to Return to Injection Chris, Endicott injector MPI 1-09A (PTD# 1970290)was shut-in on 8/17/15 for confirmed inner annulus pressurization under gas injection. Follow-up diagnostics indicated a TxIA leak attributed to a damaged dummy gas lift valve.The GLV was replaced and passing diagnostic MIT-IA obtained, demonstrating two competent barriers. Going forward, we would like to return the well to injection. Monitoring results will be provided at 28 days with the well shut-in if there is any further indication of annular pressurization over the monitoring period. Diagnostics performed to Date: - 8/30/15: Tubing Hanger void test passed to 6000 psi for 30 minutes. - 10/13/15:TTP set in XN nipple at 11,493'.Tubing and IA pressure bled and monitored (TIO plot attached). Please note, plotted tubing pressure reflects pressure above closed swab valve only. No further pressurization was observed in the Inner Annulus, confirming leak is TxIA and not packer. - 11/26-11/28/15: Dummy GLV reset at 7526'. Old valve packing showed damage. TTP pulled,well left with 2750 psi differential on the tubing T/I/O = 2850/100/0 - 12/3/15: Tubing maintaining differential with IA.Obtain passing MIT-IA to 2593 psi (attached for reference). 1 • • Please call with any questions. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 !Warp .%ta.ka.1.1A: 2 • Milne Point Unit Well: END 1-09A SCHEMATIC Last Completed: 3/24/1997 • Nikon)AlaRke,LLC PTD: 197-029 CASING DETAIL KB Elev.:55.85'/BF Elev.:18.2' Size Type Wt/Grade/Conn ID Top Btm 30" Conductor N/A/N/A/N/A N/A Surface 131' 20'a!., 13-3/8" Surface 68/L-80/Btc 12.415 Surface 2,510' 9 5/8" Intermediate 47/L-80/Btc-M. 8.681 Surface 8,081' 1 7" Production 26/L-80/Hydril 521 6.276 _ 7,892' 11,933' 4-1/2" Liner 12.6/L-80/NSCT 3.958 11,870' 12,585' ® 2 4-1/2" Tubing 12.6/L-80/NSCT 3.958 Surface 11,506' `1 3 JEWELRY DETAIL 5/8" No Depth Item 1 1,541' 4-1/2"HXO SVLN,ID=3.813" 2 2,850' 4-1/2"L-80 NSCT XO to BTC-M 3 3,575' GLM-MMGM Dummy w/RK Latch,DEV=7 4 4 5,348' GLM-MMGM Dummy w/RK Latch,DEV=15 5 6,541' GLM-MMGM Dummy w/RK Latch,DEV=43 6 7,526' GLM-MMGM Dummy w/RK Latch,DEV=45 7 7,892' 9-5/8"x 7"Bkr ZXP LTP w/HMC Liner Hanger 8 8,469' GLM-KGB2 Dummy w/INT Latch,DEV=46 9 9,456' GLM-KGB2 Dummy w/INT Latch,DEV=44 1 5 10 11,437' 4-1/2"HES X Nipple,ID=3.813" 11 11,447' 7"x 4-1/2"BKR S-3 Packer,ID=3.875" 12 11,471' 4-1/2"HES X Nipple,ID=3.813" 13 11,493' 4-1/2"HES XN Nipple,ID=3.725" 1 6 14 11,506' 4-1/2"WLEG,10=3.958 ® 7 15 11,870' 4-1/2"TIW Horizontal Packer,ID=4.00 I 8 PERFORATION DETAIL I 9 • Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 9-5/8"A I. Kekiktuk K2A 11,819 11,824' 10,052' 10,054' 5 6/13/2012 Open Kekiktuk K1 11,976' 12,562' 10,096' 10,167' 86 3/20/1997 Isolated WELL INCLINATION DETAIL 10 Max Hole Angle=84deg. @ 12,544' Angle at Top Perf=20 Deg.@ 16,775' ..11 12 s' OPEN HOLE/CEMENT DETAIL 13-3/8" 4,185 c.f.Class'G'in 17-1/2"Hole 13 9-5/8" 575 c.f.'G'in a 12-1/4"Hole a 7" 314 c.f.Class"G"in 8-1/2"Hole 14 TREE&WELLHEAD Tree 4-1/16 CIW 6.5K }KekK2A Sands Wellhead FMC GENERAL WELL INFO b '15 API:50-029-21743-01-00 Initial Completion-9/11/1987 7"' • Sidetrack-3/24/1997 Set W R P-4/7/2012 GLV C/O-5/9/2012 Add Perfs-6/13/2012 I Set W RP-5/9/2012 Kele K1 Sands GLV C/O-12/4/2013 ISet Downhole Choke-3/15/2014 Pull/Set Downhole Choke-3/28/2014 4-1/2" A ..[ TD=16,865'(MD)/TD=11,117'(TVD) PBTD=16,856'(MD)/PBTD=11,109'(TVD) Revised By:TDF 10/8/2015 STATE OF ALASKA ' AIIKA OIL AND GAS CONSERVATION COMM SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well Li Plug Perforations ❑ Perforate ❑ Other U Convert to Injector Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska, LLC Development E Exploratory ❑ (" Vi 1 .1.79r-029 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic[l Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-21743-01-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312828 R DUCK IS UNIT MPI 1-09A/L21 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Endicott Field/Endicott Oil Pool ' 11.Present Well Condition Summary: ECEIVED Total Depth measured 13,072 ' feet Plugs measured N/A feet true vertical 10,258 . feet Junk measured N/A feet 0 C T 0 9 2015 Effective Depth measured 12,585 feet Packer measured feet vv®G�1C true vertical 10,170 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 131' 30" 131' 131' Surface 2,510' 13-3/8" 2,510' 2,508' 5,020psi 2,260psi Intermediate 8,081' 9-5/8" 8,081' 7,469' 6,870psi 4,760psi Intermediate 4,041' 7" 11,933' 10,087' 7,240psi 5,410psi Liner 715' 4-1/2" 12,585' 10,170' fl 8,4300psi 7,500psi Perforation depth Measured depth See Attached Schematic y�BNNEQ JAN 2 0 201E True Vertical depth See Attached Schematic ■� Tubing(size,grade,measured and true vertical depth) 4-1/2" L-80/12.6/BTC 11,506' 9,879' 7"Baker ZXP Top Pk 7,892MD/7,329TVD 7"Baker S-3 Pkr 11,477MD/9,837TVD Packers and SSSV(type,measured and true vertical depth) 4-1/2"TIW SS Horiz. 4-1/2"HXO SVLN 11,870MD/10,070TVD 1,541 MD/1,540TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1000 0 Subsequent to operation: 0 0 0 2000 100 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development❑ Service E Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ L SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 315-081 &315-253 Contact Taylor Wellman Email twellman@hilcorp.com Printed Name Taylor Wellman Title Operations Engineer Signature ---� , ' Phone 907-777-8449 Date 10/8/2015 Form 10-404 Revised 10/2012 it.)-1'.7./.) A //3 3—RBDMS* UL 113 2015 Submit Original Only B � H . • Milne Point Unit Well: END 1-09A SCHEMATIC Last Completed: 3/24/1997 Hilcorp Alaska,LLC PTD: 197-029 CASING DETAIL KB Elev.:55.85'/BF Elev.:18.2' Size Type Wt/Grade/Conn ID Top Btm 30" Conductor N/A/N/A/N/A N/A Surface 131' i%..4�y� r� } ,b, 13-3/8" Surface 68/L-80/Btc 12.415 Surface 2,510' ,J 9-5/8" Intermediate 47/L-80/Btc-M. 8.681 Surface 8,081' ,I 1 r 7" Production 26/L-80/Hydril 521 6.276 7,892' 11,933' 4-1/2" Liner 12.6/L-80/NSCT 3.958 11,870' 12,585' a 2 ,f ill4-1/2" Tubing 12.6/L-80/NSCT 3.958 Surface 11,506' 3 JEWELRY DETAIL 13-5/8" /g :p No Depth Item 1 1,541' 4-1/2"HXO SVLN,ID=3.813" Ny 2 2,850' 4-1/2"L-80 NSCT XO to BTC-M a' 4 3 3,575' GLM-MMGM Dummy w/RK Latch,DEV=7 { 4 5,348' GLM-MMGM Dummy w/RK Latch,DEV=15 it 5 6,541' GLM-MMGM Dummy w/RK Latch,DEV=43 t0 6 7,526' GLM-MMGM Dummy w/RK Latch,DEV=45 7 7,892' 9-5/8"x 7"Bkr ZXP LTP w/HMC Liner Hanger `" 8 8,469' GLM-KGB2 Dummy w/INT Latch,DEV=46 of 1t 9 9,456' GLM-KGB2 Dummy w/INT Latch,DEV=44 5 10 11,437' 4-1/2"HES X Nipple,ID=3.813" 11 11,447' 7"x 4-1/2"BKR S-3 Packer,ID=3.875" 12 11,471' 4-1/2"HES X Nipple,ID=3.813" t 13 11,493' 4-1/2"HES XN Nipple,ID=3.725" 6 14 11,506' 4-1/2"WLEG,ID=3.958 � 1r .ter 7 15 11,870' 4-1/2"TIW Horizontal Packer,ID=4.00 .SSI,,: 8 ; PERFORATION DETAIL '71„ B 9 9 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 9-5/g Kekiktuk K2A 11,819 11,824' 10,052' 10,054' 5 6/13/2012 Open Kekiktuk K1 11,976' 12,562' 10,096' 10,167' 86 3/20/1997 Isolated WELL INCLINATION DETAIL 10 Mngle 84deg. @ 12,544' AngleaxHole at Top APerf==20 Deg.@ 16,775' 12 . c-� S OPEN HOLE/CEMENT DETAIL s4 `S) 13-3/8" 4,185 c.f.Class'G'in 17-1/2"Hole �13 Y n 9-5/8" 575 c.f.'G'in a 12-1/4"Hole 1 t �N 7" 314 c.f.Class"G"in 8-1/2"Hole 14 TREE&WELLHEAD Tree 4-1/16 CIW 6.5K 3-KekK2ASands / Wellhead FMC 14 11,,, C�13 I) GENERAL WELL INFO 15 API:50-029-21743-01-00 Initial Completion-9/11/1987 7" & Sidetrack-3/24/1997 Set WRP-4/7/2012 GLV C/O-5/9/2012 I I Add Perfs-6/13/2012 Set WRP-5/9/2012 Kek K1 Sarxis GLV C/O-12/4/2013 II Set Downhole Choke-3/15/2014 Pull/Set Downhole Choke-3/28/2014 41/2" 11 TD=16,865'(MD)/TO=11,117'(TVD) PBTD=16,856'(MD)/PBTD=11,109'(TVD) Revised By:TDF 10/8/2015 • • Hilcorp Alaska, LLC l►i►eurp:l laska,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date END 1-09A 50-029-21743-01-00 197-029 3/10/2015 7/7/2015 Daily Operations: 3/4/15-Wednesday No operations to report. 3/5/15-Thursday No operations to report. 3/6/15-Friday No operations to report. 3/7/15-Saturday No operations to report. 3/8/15-Sunday No operations to report. 3/9/15-Monday No operations to report. 3/10/15-Tuesday MIRU Slickline. Pressure test lubricator to 300psi low/3,200psi high. RIH w/4-1/2" GS. Pull BBE of SLVN @ 1,507' slm/1,541' md. POOH and hang up at 99'slm.Shear off of BBE. BBE left in hole and paraffin on tools.Secure well and lay down for night. Ongoing. • • Hilcorp Alaska, LLC !fa,.,,r,,:,l:u.ka.LU. Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date END 1-09A 50-029-21743-01-00 197-029 3/10/2015 7/4/2015 Daily Operations: 3/11/15-Wednesday PRESSURE TEST LUBRICATOR TO 300PSI LOW/3,200PSI HIGH. PULL BBE FROM 98'SLM (serial#BB-490, recovered all packing,top stack damaged). DRIFT TO DH CHOKE AT 11456'SLM/11493' MD. PULL DH CHOKE FROM 11456'SLM/11493' MD. 3/12/15-Thursday PRESSURE TEST LUBRICATOR TO 300PSI LOW/3,200PSI HIGH.SET PXN-PLUG BODY AT 11,459'SLM/11,493' MD(OAL lock open=28",4X3/16" ports).SET P-PRONG IN PLUG BODY @ 11,456'SLM (OAL=85', 1-3/4" FN). BLEED TBG TO 1,900psi AND PERFORM DRAW DOWN TEST(watch for 30min,good).SET CATCHER AT 11,449'SLM. PULL RK-OGLV FROM STA#3 @ 7,502'SLM/7,526' MD. 3/13/15-Friday PRESSURE TEST LUBRICATOR TO 300PSI LOW/3200PSI HIGH. PULL RK-LGLV FROM STA#6 AT 3,550'SLM/3,575' MD.SET RK DGLV IN STA#6 AT 3,550'SLM/3,575' MD. PULL CATCHER FROM 11,450'SLM (empty). 3/14/15-Saturday No operations to report. 3/15/15-Sunday No operations to report. 3/16/15-Monday No operations to report. 3/17/15-Tuesday No operations to report. • i Hilcorp Alaska, LLC 'tiied.",Ahiska.LEA. Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date END 1-09A 50-029-21743-01-00 197-029 3/10/2015 7/4/2015 Daily Operations: 4/15/15-Wednesday No operations to report. 4/16/15-Thursday No operations to report. ,N. 4/17/15-Friday Load TBG and IA with produced water from 1-11, F/P TBG and IA with 3000 Gal diesel,Combo MIT to 2500 PSI * PASSED 4/18/15-Saturday '~ No operations to report. 4/19/15-Sunday No operations to report. 4/20/15-Monday No operations to report. 4/21/15-Tuesday No operations to report. • ! Hilcorp Alaska, LLC IIile,,rpAlaska.LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date END 1-09A 50-029-21743-01-00 197-029 3/10/2015 7/4/2015 Daily Operations: 4/22/15-Wednesday No operations to report. 4/23/15-Thursday PRESSURE TEST PCE TO 300PSI LOW/2,100PSI HIGH. "SET CATCHER ON TOP OF PXN PRONG @ 11,451'SLM 11,493' MD. SET 1-1/2" RK DGLV IN STATION#3 7,502'SLM 7,526' MD. PULLED CATCHER. RIG DOWN. 4/24/15-Friday No operations to report. 4/25/15-Saturday No operations to report. 4/26/15-Sunday No operations to report. 4/27/15-Monday Initial T/I/0=900/855/50psi. MIT-IA to 2400psi-Passed. Connect to IA w/triplex pumping diesel.Test start T/I/0=925/2412/50. 15 min IAP=2402psi (10psi loss). 30 min IAP=2397psi (5psi loss).Test is a Pass. Bleed down IA. 4/28/15-Tuesday No operations to report. • • Hilcorp Alaska, LLC xi,t.oipAI.,.ka. LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date END 1-09A 50-029-21743-01-00 197-029 3/10/2015 7/4/2015 Daily Operations: 4/29/15-Wednesday No operations to report. 4/30/15-Thursday No operations to report. 5/1/15-Friday No operations to report. 5/2/15-Saturday No operations to report. 5/3/15-Sunday No operations to report. 5/4/15-Monday No operations to report. 5/5/15-Tuesday Set BPV. ND tree and adapter. Clean groove, replace neck seals and ring gasket. Replace tubing adapter to uprated 6,5001b adapter. Install uprated 44/16" 6,5001b tree from well 1-21. P� -3l ro�; • • Hilcorp Alaska, LLC liil DrpAlxskaa,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date END 1-09A 50-029-21743-01-00 197-029 3/10/2015 7/4/2015 Daily Operations: 5/6/15-Wednesday Pressure test tree against TWC to 6,300psi for 30 min-passed. Bleed pressure to 0 psi.Test tubing hanger,test void to 6,000psi- passed. Bleed pressure from void. pull TWC and RD from well. 5/7/15-Thursday No operations to report. 5/8/15-Friday Pressure test lubricator to 2,100psi. Run#1-ran a 3.6 bell guide,2.5 RS. Pulled prong at 11,493md (14,436's/I) Run#2-ran a 4.5gs, pulled plug body at 11,493md (14,442s/I). Secure well. Plug missing 5 pieces of packing,one nubbing missing as well. 5/9/15-Saturday No operations to report. 5/10/15-Sunday No operations to report. 5/11/15-Monday No operations to report. 5/12/15-Tuesday No operations to report. S Hilcorp Alaska, LLC Hikali'Alaska',LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date END 1-09A 50-029-21743-01-00 197-029 3/10/2015 7/4/2015 Daily Operations: 6/10/15-Wednesday No operations to report. 6/11/15-Thursday No operations to report. 6/12/15-Friday No operations to report. 6/13/15-Saturday No operations to report. 6/14/15-Sunday PRESSURE TEST LUBRICATOR TO 300PSI LOW/2500PS1 HIGH.RAN 3.25 LIB.TOOLS S/D @ 11830'SLM. POP SPANGS AND TOOLS CONTINUE TO FALL TO 11889'SLM. NO CONCLUSIVE MARKSRAN 2.25" PUMP BAILER S/D @ 11896'SLM. BAD ACTION. DEPTHS UNCLEAR NO RETURNS.RAN 3.25" LIB.SAME RESULTS AS FIRST RUN.RAN 3" PUMP BAILER W/WRP EQ SUB. NO RETURNS AND TELLTALE PINS UNTOUCHED. 6/15/15-Monday PRESSURE TEST LUBRICATOR TO 3,00PSI LOW/2,500PSI HIGH. RAN TEL AND S-BAILER. LOCATED TUBING TAIL @ 11,463' SLM, (CORRECTION MD=SLM+43') S/D @ 11,889'SLM. NO RETURNS RAN 2.25 LIB S/D @ 11,889'SLM. NO CONSLUSIVE MARKS.RAN 1.75 LIB WORKED TOOLS TO 11,930' PUH TO 11,870' UNABLE TO GO BACK PAST 11,889'. PURGED CONTROL AND BALANCE LINES W/4 GAL HYDRO EACH.SET MCX(SER#M-12 W/1.56 BEAN ON CARRIER OAL 59") 6/16/15-Tuesday No operations to report. v . • t ' Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date END 1-09A 50-029-21743-01-00 197-029 3/10/2015 7/4/2015 Daily Operations: 7/1/15-Wednesday PULL MCX FROM 1,509'SLM,SERIAL#M-12. RAN 4.5"A-1 INJ VALVE&CARRIER W/2 SETS OF STD. PACKING AND NO EQUALIZING DEVICE SERIAL#HACS-0016.SET @ 1,509'SLM,OAL FROM TOP OF LOCK TO FLAPPER 61", PERFORM 300 PSI CLOSURE TEST.GOOD TEST. 7/2/15-Thursday No operations to report. 7/3/15-Friday No operations to report. 7/4/15-Saturday Initial T/I/0=900/855/50psi.AOGCC witnessed MIT-IA to 2,400psi - Passed.Connect to IA w/triplex pumping diesel.Test start T/I/0=3700/2700/40. 15 min IAP=2,620psi (80psi loss).30 min IAP=2,532psi (88psi loss).45 min IAP=2,465psi (68psi loss).Test is a Pass. Bleed down IA. 7/5/15-Sunday No operations to report. 7/6/15-Monday No operations to report. 7/7/15-Tuesday No operations to report. 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,September 03,2015 TO: Jim Regg SUBJECT: Mechanical Integrity Tests P.I.Supervisor 15 HILCORP ALASKA LLC 1-09A/L21 FROM: Jeff JonesDUCK IS UNIT MPI 1-09A/L21 Petroleum Inspector %GAINED i"_l i- 6. 5 i,`, r; Src: Inspector Reviewed By: P.I.Supry i�./— NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 1-09A/L21 API Well Number 50-029-21743-01-00 Inspector Name: Jeff Jones Permit Number: 197-029-0 Inspection Date: 7/4/2015 Insp Num: mitJJ150706110542 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-09A/L21 Type Inj 1 N 'TVD 9838 Tubing 3700 - 37003700 j 3700 - 3700- PTD 1970290 1Type Testi SPT Test psi 2459.5 - IA 2100 2700 - 2620 - 2532 - 2464 - Interval INITAL P/F P ✓ OA 40 . 40 40 40 40 . Notes: Producer converted to injector.Modified tree;operator indicates that this 5K tree is now rated to 6500 psi by the manufacturer. • Thursday,September 03,2015 Page 1 of 1 Loepp, Victoria T (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, August 17, 2015 4:53 PM To: Regg, James B (DOA); Loepp, Victoria T(DOA) Cc: Wallace, Chris D (DOA); Taylor Wellman Subject: END 1-09A (PTD #1970290) Shut-In for Inner Annulus Pressurization Attachments: END1-09A TIO.xlsx; END1-09A Trend.jpg Follow Up Flag: Follow up Flag Status: Flagged %AIMED 'MAR 1 6 2016 Jim, Gas injector END 1-09A(PTD#1970290)was shut-in today, 8/17/15,for inner annulus pressurization. Wellhead pressure and gas injection temperature trends indicate that annular pressurization began with the Endicott A main gas ............ compressor shut down on 8/8/15.The shutdown resulted in a 60%decrease in END1-09A's injection rate,an increase of gas injection temperature from^218 degF to-238 degF and a decrease in tubing pressure from-4600 psi to 3600 psi. Diagnostic monitoring indicates a consistent IA buildup of"'350 psi per day. IA pressurization continued despite a return to higher injection rates with the restart of the Endicott A main gas compressor on 8/15/15 .The well will remain SI until further diagnostics and/or remediation is completed. Diagnostic Steps Going Forward : 1) Test wellhead packoff seals 2) Test control & balance line integrity Thank You, Wyatt Rivard Well Integrity Engineer 0: (907) 777-8547 C: (509)670-8001 ( wrivard@ihilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Nilr.►ri► tl:� x. l.l,t: From: Taylor Wellman Sent: Friday, August 14, 2015 4:43 PM To: 'Regg, James B (DOA)'; Loepp, Victoria T(DOA) Cc: Wyatt Rivard; Wallace, Chris D (DOA) Subject: RE: END 1-09A (PTD #1970290) Possible Tbg x IA Communication Jim, You are absolutely correct on the sustained casing pressure limit on injectors,that was my mistake in including that sentence. For the timeline for the diagnostics, I have included some notes below. Over the next 2-3 days the plant will 1 • have resumed higher injection rates"nd we will be able to provide an update on Monday(17 Aug) if the wellhead testing and/or SSSV will be required. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907)777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, August 14, 2015 4:24 PM To: Taylor Wellman; Loepp, Victoria T(DOA) Cc: Wyatt Rivard; Wallace, Chris D (DOA) Subject: RE: END 1-09A (PTD #1970290) Possible Tbg x IA Communication There is no sustained casing pressure limit for injectors. Injection wells are not covered by the Sustained Casing Pressure rules in CO 501 (producers only). You should append some time limits to the diagnostic steps. AOGCC typically has not allowed injectors to continue injecting gas; we have allowed some time from diagnostic work to identify the communication path and to help facilitate repairs. Admin approvals have allowed water only injection to continue. 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.regg@alaska.gov. From: Taylor Wellman [mailto:twellm=n@hilcorp.com] Sent: Friday, August 14, 2015 4:16 PM To: Loepp, Victoria T(DOA) Cc: Regg, James B (DOA); Wyatt Rivard Subject: END 1-09A (PTD #1970290) Possible Tbg x IA Communication Victoria, END 1-09A(PTD#1970290) is gas injection well that was recently converted from a production well under Sundry(#315- 253). The well appears to be exhibiting TbgxlA communication with the IA requiring 3 bleeds in the past week. The IA has not exceeded the 2500 psi sustained casing pressure limit. Starting on 8/8/15 the Endicott A Main Gas Compressor was shut down and the injection rates to all gas injectors was reduced. At this time the plan is to diagnose the cause of the communication beginning with the proposed plan below before shutting in injection. Also please note that if at any time the communication rate becomes unmanageable the well will be shut in immediately and a subsequent notification will be sent. 2 Diagnostics Steps • • 1. Collect diagnostic data to determine if this can be attributed to temperature (ambient or injection gas temp),or injection rates 'Currently being pulled together) 2. Resume higher injection rates and monitor IA build up rate response ;Plant is coming back online and the build up rate will be monitored over the next 2-3 days) 3. Test the wellhead pack-off seals (currently scheduled for early to mid-week if needed) 4. Pull & re-set SSSV (slickline will be out at Endicott and can be moved over if needed) 1-09A Bleeds during past week DATE START PRESSURE END PRESSURE FLUID 8/8/15 2250 1400 Diesel 8/11/15 2200 1200 Diesel 8/13/15 2200 850 Diesel w/gas If this course of action is unacceptable or if you would like any further information please let us know and we will make the needed actions happen. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907) 777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com 3 O 0 0 CD CD 0 0 0 0 CD �^ CD CD 0 CD CD r" In M N .-+ O O N 1 CO O r° .4"114 lf) O N O A CO O _4..fti 4: '. :11 41 i 335 Ac '''°'' \ ''''\\N ,. �t... Figure 2: K2A Map Illustrating AOR Please contact me with any questions or concerns regarding this, Taylor Taylor Wellman Hilcorp Energy Company-Operations Engineer Office: (907)777-8449 Endicott: (907) 777-8449 Cell: (907)947-9533 Email: twellman(Whiicorp.com 3 pro i9- -° Z Loepp, Victoria T (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Monday,June 15, 2015 5:23 PM To: Loepp,Victoria T(DOA) Cc: Tom Fouts Subject Duck Island Unit 1-09 (PTD#1970290) Sundry#315-253 Plan Forward Follow Up Flag: Follow up Flag Status: Flagged Victoria, As part of Sundry#315-253 for DIU well#1-09(PTD#1970290)there was listed the removal of 2 wireline retrievable plugs at 11,895'and&11,905'md. These plugs isolate the K2A perforations at 11,819'—11,824' and from a slotted liner in the Kl. During the course of operations,the plugs have been found to not be in place of where they were set and diagnosing for fishing options has indicated no fishing neck and no fill while setting down in the production liner. At this time,the plan is to cease fishing operations of these plugs,set an injection SSSV and place the well on injection(witnessed MIT-IA to follow after stabilization). If injection rates are insufficient to provide a replacement gas injector,the well will have additional perforations shot into the K2A as outlined in the original sundry. All operations will be summarized in the submission of the 10-404. Thank you, Taylor Taylor Wellman Hilcorp Energy Company-Operations Engineer Office:(907)777-8449 Endicott: (907)777-8449 Cell: (907)947-9533 %MeE© JUL .1 Z01 Email:twellman@hilcorp.com 1 ti OF Ty s, THE STATE Alaska Oil and Gas ��►..T- ��, of/� T A K A Conservation Commission 333 West Seventh Avenue ��* GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 OFALAS1 Fax' 907.276 7542 tiMc© MAY 1 4 2015 www aogcc.alaska.gov sa Taylor WellmanQ 0 $9-011 Operations Engineer I I Hilcorp Alaska, LLC F 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, Duck Island Unit MPI 1-09A/L21 Sundry Number: 315-253 Dear Mr. Wellman: 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, Cathy Foerster Chair DATED this day of May, 2015 Encl. RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 8 nth APPLICATION FOR SUNDRY APPROVALS � $ 1 S 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill D Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate 0 • Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ • Other. Convert to 1nlectoi0 2.Operator Name. 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development Ea 197-029 • — 3.Address: Stratigraphic ❑ Service El6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-21743-01-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 Will planned perforations require a spacing exception? Yes ❑ No ❑., DUCK IS UNIT MPI 1-09A/L21 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312828 • Endicott Field/Endicott Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13,072 10,258 • 11,895 10,078 11,895'&11,905' N/A Casing Length Size MD ND Burst Collapse Structural Conductor 131' 30" 131' 131' Surface 2,510' 13-3/8" 2,510' 2,508' 5,020psi 2,260psi Intermediate 8,081' 9-5/8" 8,081' 7,469' 6,870psi 4,760psi Intermediate 4,041' 7" 11,933' 10,087' 7,240psi 5,410psi Liner 715' 4-1/2" 12,585' 10,170' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" L-80/12.6/BTC 11,506 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 7"Baker ZXP Top Pkr,7"Baker S-3 Pkr&4-1/2"TIW SS Horiz.Pkr and 7,892MD/7,329TVD,11,477MD/9,837TVD&11,870MD/10,070TVD 4-1/2"HXO SVLN and 1,541MD/1,540TVD 12.Attachments: Description Summary of Proposal 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/30/2015 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A WINJ ❑ GINJ 0 • WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Wellman Email twellman@hilcorp.com Printed Name Taylor Wellman [ Title Operations Engineer 3. 4If Signature Phone 777-8449 Date 4/28/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '-2) ''' 2_, S Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test [] Location Clearance ❑ Other: __i-a, t t w,to r 5 S r c/ AA,6 7--_ /f} fl ct v/ ---cCJ a-fl-t✓ i----A-b , 1 c ci /%-J c cPr- t . Spacing Exception Required? Yes ❑ No P Subsequent Form Required: `c — 4 6 4- APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:5 .' ! 5 auomlt conn ana Form 10-403(Re used 10/2012) p e lI a oni1 v dor 12 months rom the date of approval. Attachments in Duplicate Fermi/7_10-4Z ¢!�o// - L I V �BDMS- MAY - 6 10 1/�l//r- 11' ms'''s Conversion • Well: 1-09 PTD: 1970290 Hileorp Alaska,LL, API: 50-029-21743-01 Well Name: 1-09 API Number: 50-029-21743-01 Current Status: SI Rig: SL Estimated Start Date: April 30, 2015 Estimated Duration: 2 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 1970290 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907)947-9533 (M) Second Call Engineer: Mike Dunn (907)777-8382 (0) (907) 351-4191 (M) Current Bottom Hole Pressure: 4119psi @ 10,000'ND (Based on SBHPS on 4-10 04/22/14) Maximum Expected BHP: 4119psi @ 10,000'ND (Based on SBHPS on 4-10 04/22/14) Max.Anticipated Surface Pressure: 3,200psi (Based on 0.1 psi/ft. gas gradient) Brief Well Summary: Endicott 1-09 is a production well open to the K1 and K2A. The well's bottom hole location is near the crest of the formation in the gas cap. Due to this, the well has an extremely high GOR and is not a competitive cycle well. Well 1-09 is located in a good location to be used as a potential Gas Injection well. Well 1-21 has an uprated 6500psi tree on it. Currently there are operational steps in approved Sundry(#315-081)for swapping the tree. The steps listed here are to follow the operations outlined in the above listed Sundry. Objective: To complete the conversion to a Gas Injection well. 1. f 20/2 1-4(- co Procedure: f on GV!'. r,;or TO i,,,eit rr9��cfy <'jo �6//2 (or lev.rot y• '^'/ (��.. Slickline Work The ,lew Pew CP/64'►a r, -4/6 ' r!c(e ie'q' rye OVe t0 U-P/l d we, 100 mCF/S71 & -1 ei, 74e -Peke t v,% e 50 m`gsre 1. MIRU SL unit. The 1/i.-el! 4 4) ls'�''f�/e ,) c. p /G141,'/4, wave 9f �0i�er. 2. Pressure test to 300psi low and 2200psi high. 1 3. Pull SC WRP from 11,895' md. Len herr/Ay ,'r ro Qn ,'i J eCior fA04 4. Pull SC WRP from 11,905' md. 4 ( "Alpo rL r e(Co ver, fro^ i de toe 5. Set 4-1/2" MCX SSSV at 1541' md. � Of i„,-- RDMO. Operations 7. Complete surface connections and injection line from injection header. 8. Place well on injection. 9. Conduct an AOGCC witnessed MIT-IA to 2500psi. • Notify AOGCC inspector once well is online with stable injection. • 0.25 x 9874' tvd of packer= 2469psi Contingency—If injection rates are insufficient Conversion . 14 Well: 1-09 PTD: 1970290 Hilcorp Alaska,LL, API: 50-029-21743-01 E-Line 10. Spot and RU E-Line unit: 11. Pressure test lubricator to 300psi low and 2200psi high. 12. MU perforating toolstring and perforate the following intervals in the K2A: • 11,535'—11,560' and • 11,570' —11,630' and 13. RD E-Line. Operations 14. Place well on injection. 15. Conduct an AOGCC witnessed MIT-IA to 2500psi. • Notify AOGCC inspector once well is online with stable injection. • 0.25 x 9874'tvd of packer = 2469psi Attachments: Schematic,Proposed,Tree Diagram&Area of Review Milne Point Unit • Well: END 1-09 SCHEMATIC Last Completed: 3/24/1997 llilcurp Alaska,LLC PTD: 197-029 CASING DETAIL KB Elev.:55.85'/BF Elev.:18.2' Size Type Wt/Grade/Conn ID Top Btm CI„,,, ;; i 30" Conductor= N/A/N/A/N/A N/A Surface 131' 20 ; 13-3/8" Surface 68/L-80/Btc 12.415 Surface 2,510' �. v! 9-5/8" Intermediate 47/L-80/Btc-M. 8.681 Surface 8,081' ft 14 1 1,1 7" Production 26/L-80/Hydril 521 6.276 7,892' 11,933' rh 4-1/2" Liner 12.6/L-80/NSCT 3.958 11,870' 12,585' i. 2 v 4-1/2" Tubing 12.6/L-80/NSCT 3.958 Surface 11,506' " 3 A JEWELRY DETAIL l 1:1-5/8" a No Depth Item 1 1,541' 4-1/2"HXO SVLN,ID=3.813" 2 2,850' 4-1/2"L-80 NSCT XO to BTC-M l' 3 3,575' GLM-MMGM Dummy w/RK Latch,DEV=7 t 4, 4 4 5,348' GLM-MMGM Dummy w/RK Latch,DEV=15 i, H 5 6,541' GLM-MMGM Dummy w/RK Latch,DEV=43 6 7,526' GLM-MMGM Empty w/RK Latch,DEV=45 7 7,892' 9-5/8"x 7"Bkr ZXP LTP w/HMC Liner Hanger 8 8,469' GLM-KGB2 Dummy w/INT Latch,DEV=46 9 9,456' GLM-KGB2 Dummy w/INT Latch,DEV=44 "+ 5 10 11,437' 4-1/2"HES X Nipple,ID=3.813" 11 11,447' 7"x 4-1/2"BKR S-3 Packer,ID=3.875" 12 11,471' 4-1/2"HES X Nipple,ID=3.813" t� 13 11,493' 4-1/2"HES XN Nipple,ID=3.725" 6 4, 14 11,493 PXN Plug ii3" 7 15 11,506' 4-1/2"WLEG,10=3.958 !, r3Z 16 11,870' 4-1/2"TIW Horizontal Packer,ID=4.00 �' 8 17 11,895' 4-1/2"SC WRP III 9 18 11,905 4-1/2"SC WRP 9-5/8 PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status Kekiktuk K2A 11,819 11,824' _ 10,052' 10,054' 5 6/13/2012 Open III 10 Kekiktuk K1 11,976' 12,562' 10,096' 10,167' 86 3/20/1997 Isolated 11 WELL INCLINATION DETAIL s; I /12 Max Hole Angle=84deg. @ 12,544' ; Angle at Top Perf=20 Deg.@ 16,775' I 113 14 it 4 OPEN HOLE/CEMENT DETAIL 15 13-3/8" 4,185 c.f.Class'G'in 17-1/2"Hole '' 9-5/8" 575 c.f.'G'in a 12-1/4"Hole }KekK2A sands 7" 314 c.f.Class"G"in 8-1/2"Hole TREE&WELLHEAD Ogl ,r7cez 16 Tree 4-1/16 CIW 5K Wellhead FMC y,y 18 GENERAL WELL INFO API:50-029-21743-01-00 Initial Completion-9/11/1987 I Sidetrack-3/24/1997 Set WRP-4/7/2012 Kek K1 Sands GLV C/O-5/9/2012 IAdd Perfs-6/13/2012 Set WRP-5/9/2012 GLV C/O-12/4/2013 Set Downhole Choke-3/15/2014 4]/2" te.J1Pull/Set Downhole Choke-3/28/2014 TD=16,865'(MD)/TD=11,117(TVD) PBTD=16,856'(ND)/PBTD=11,109'(TVD) Revised By:TDF 4/28/2015 Milne Point Unit Well: END 1-09 PROPOSED Last Completed: 3/24/1997 Ililcury Alaska,LLC PTD: 197-029 CASING DETAIL KB Elev.:55.85'/BF Elev.:18.2' _ Size Type Wt/Grade/Conn ID Top Btm A +P ' r• 30" Conductor N/A/N/A/N/A N/A Surface, 131' 1 13-3/8" Surface 68/L-80/Btc 12.415 Surface 2,510 jL 9-5/8" Intermediate 47/L-80/Btc-M. 8.681 Surface 8,081' t1 1 41 7" Production 26/L-80/Hydril 521 6.276 7,892' 11,933' 4 u 4-1/2" Liner 12.6/L-80/NSCT 3.958 11,870' 12,585' r 2 v $4 $4: 4-1/2" Tubing 12.6/L-80/NSCT 3.958 Surface 11,506' 3 '1 JEWELRY DETAIL JP 13-5/ p No Depth Item 1 1,541' 4-1/2"HXO SVLN,ID=3.813" 2 2,850' 4-1/2"L-80 NSCT XO to BTC-M a a 3 3,575' GLM-MMGM Dummy w/RK Latch,DEV=7 a, 4 w 4 5,348' GLM-MMGM Dummy w/RK Latch,DEV=15 5 6,541' GLM-MMGM Dummy w/RK Latch,DEV=43 i, z' t, 6 7,526' GLM-MMGM Empty w/RK Latch,DEV=45 el/ t4s 7 7,892' 9-5/8"x 7"Bkr ZXP LTP w/HMC Liner Hanger " 1 88,469' GLM-KGB2 Dummy w/INT Latch,DEV=46 _9 9,456' GLM-KGB2 Dummy w/INT Latch,DEV=44 <e " 10 11,437' 4-1/2"HES X Nipple,I0=3.813" p 5 11 11,447' 7"x 4-1/2"BKR S-3 Packer,ID=3.875" 1+ TI 12 11,471' 4-1/2"HES X Nipple,ID=3.813" 13 11,493' 4-1/2"HES XN Nipple,ID=3.725" 4 6 14 11,506' 4-1/2"WLEG,10=3.958 t' .�,,.�,,�pp" 15 11,870' 4-1/2"TIW Horizontal Packer,10=4.00 033i I Mi 7 8 x PERFORATION DETAIL Ili h 1 9 Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status 9-5/8'1 4 ±11,535' ±11,560' ±9,899' ±9,917' 25 Future Future Kekiktuk K2A ±11,570' ±11,630' ±9,924' _ ±9,962' 60 Future Future 11,819 11,824' 10,052' 10,054' 5 6/13/2012 Open Kekiktuk K1 11,976' 12,562' 10,096' 10,167' 86 3/20/1997 Isolated 1 110 'r rp, ;'r 11 WELL INCLINATION DETAIL v I 112 4 Max Hole Angle=84deg. @ 12,544' Angle at Top Perf=20 Deg.@ 16,775' °+ 1 131 4 ,Il" d OPEN HOLE/CEMENT DETAIL ,..,, 13-3/8"14 -_ 4,185 c.f.Class'G'in 17-1/2"Hole +' 'KePROPOSED k OPO 9-5/8" 575 c.f.'G'in a 12-1/4"Hole K2A Sands i -Sr 7" 314 c.f.Class"G"in 8-1/2"Hole a } `1QA Sands TREE&WELLHEAD �r ;:t .vt: Tree 4-1/16 CIW 5K i� � ;15 Wellhead FMC 7': END 1-09 135/8X4Y2 tubing hanger 4"BPV profile 41/16"5M Otis,Tree cap OLT ilLFil -rrP'1 [J •ra 410� '�' 41/16"CIW valve HWO ►:621/ 00 G�:u u� rtw MI—Tiuur l' 41/16"5M CIW Valve,Wing, Baker actuator Iwo g=rm■r 4 1/16"CIW SM valve SSV Baker actuator O l Mt lire MI ,,l a r Att'. 4 1/16"CIW Master valve .?,, z4 Of HWOr:—,,d C\�1 MI tie Mt a�pl�aQco .,5y1 2' T 1 L _, I op #,)'''....÷111M ilir�llllrr �� ';4°°III n WKM HI/6"SM WO . , Tr....... . , WKM 2 1/16"5M 13 5/8 9 5/8 4 1/2 1-09A Injector Conversion April, 2015 1-09A Well Integrity History • 12/16/05:TIFL Failed,tubing tracked IA during bleed • 01/06/06: OGLV C/O in Sta#2 • 01/10/06:TIFL Passed • 11/22/06:Tightened leaking LDS on TBG& IC hanger that were reported by WT • 02/03/07:Tightened leaking gland nuts • 03/24/07: PPPOT-T Passed to 5000 psi, PPPOT-IC Passed to 3000 psi, all LDS Functioned-no leaks • 05/21/07:TTP Set @ 11493'MD • 05/25/07: CMIT-TxIA Passed • 06/01/07: Tree changed • 06/12/07: PT Tree Passed to 5000 psi • 06/13/07: Pull TTP set OGLV&SSSV • 06/14/07: PPPOT-IC to 3000 Passed • 05/23/08:TBG hanger LDS leaking • 07/21/10:Tightened LDS • 09/23/10:Treat conductor w/3.4 gals of RG-2401 • 04/07/12: Set WRP @ 11905' ELM • 04/30/12: Set DGLVs • 05/01/12: Set TTP, MIT-T Inconclusive to 2500 psi • 05/08/12: Set WRP @ 11895' ELMD • 05/09/12: MIT-T to 2500 psi Passed, Set LGLVs 6,4, &2 • 06/04/12: CMIT-TxIA to 2500 psi Passed, MIT-T to 2500 psi Passed • 09/17/12:TIFL Passed • 10/01/12:TIFL Passed • 02/28/13:TIFL Passed • 06/30/13:TIFL Passed • 07/1/13: Caliper:4.5"tbg< 17% pen, 7"Inr> 16% pen, no significant metal loss • 07/19/13: Pulled SSSV from 1541'MD, set DGLV's in sta#2&4, sta#6 • 08/03/13: Set DGLV @ sta#2 • 08/05/13: Set XN Plug @ 11493' MD MIT-IA Failed • 08/06/13: Pull reset XN plug MIT-T Passed to 3000, MIT-IA Passed to 3000 psi • 11/23/13: Pulled XXN From 11493' MD • 11/03/13: Set sta#6 • 12/04/13: Set OGLV in sta#3&SSSV @ 1541' MD Steps to Conversion: Steps covered in Sundry 315-081. 1) Dummy GLVs 2) Pull DH Choke 3) Set PXN plug at 11,493' and 4) Replace tree 5) Pull PXN plug from 11,493' and Steps not covered by any Sundry and applicable to this operation. 6) Pull WRP's from 11,895' and & 11905' and 7) Convert surface piping 8) Start injection 9) State witnessed MIT-IA to 2500 psi after injection stabilizes 10) Contingency-Add Perfs 11,535'-60' & 11,570'-630' MD 't Minilog for Well Techlog . .ENDICOTT 1-09A_L-21 —. LAURA J.IAN SON - '2000 -.J:-Nt7l20I2 Producer Well: 1-09A_L-21 er.010.,: 3•141175.14...1 x:3•141175.14. 111.0209 i7at.:* 7.0010 . 00/Otis 50.00,,:WA .,.. 00*//1.21 01....00 datum:NO V.sM)Y1.00 Co.tpl.IWO a.:Is07.03-3300*tSS F...2:ieiCOT1 �. , ,• 1.0103,1.21 n.*3072 Iw0*.10 -147.005107 $1...:*bolo ,. �..•....r.. IND2)YT 5.5*vf. 70.)52)05 _. ., 1e*A C..t*.wr'.WILL p :G . "''HOr IVDSS MD PE Notes G1 (10(1) (I/It) 00055 p .. 1:1000 1:2000 -_. �,, .-.. ,-11150. .J _ �lailli ' %50 O r.0 ".- WAIN - 0SW ! NM l 'Aim ..„,..c Irmo law_ lOMU �� _.,o,....____ -0.1001 IE. -11000 lt,n- SDr• . 10x0 l 1 .100"0.1 ...111111.111 .101011 1 r u•.on- . tr- 1 101/0 —r .1 10110 0. - — `_ tot./ ' -10100 -10100 1 ..._ 10,01 i Figure 1: 1-09A Mini Log Area of Review — Endicott DIU 1-09A (1970290) Prior to the conversion of well 1-09A from producer to gas injector, an Area of Review (AOR) must be conducted. This AOR found no other wells within 1/4 mile of 1-09A's entry point into the Kekiktuk Formation. Table 1: Wells within AOR Well Name PTD Distance, Ft. Annulus Integrity 1-09A 1970290 0' MIT-IA on 8/6/13 passed to 3000 psi Table 2: Completion Detail Well Name Casing Size Hole Size Vol Cement Kekiktuk Depth 1-09A 7" 8-1/2" 314 c.f. Class G 11,259' MD Evaluation: 08Sept87 CBL In well 1-09, a 7" liner was run to 11,933' MD and hung at 7892' MD. The completion enters the Kekiktuk formation at 11,259' MD. The 7" liner was cemented with 314 c.f. of class G cement. A cement bond log indicates the primary cement is good at the injection zone and extends up to at least 11404' MD, above the packer at 11447'. The completion includes a 4-1/2" slotted liner hung at 11870' MD but isolated with two WRPs at 11895' MD and 11905' MD. v y ( ( . 335 Ac \ ,naa rM.o,EiroK -:.' _ -,amu • A \'''m x E� \ ;%."7,77 I � 14 Figure 2: K2A Map Illustrating AOR Loepp, Victoria T (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Wednesday, March 11, 2015 3:45 PM To: Loepp, Victoria T (DOA) Cc: Tom Fouts Subject: Endicott 1-09 (PTD#1970290) Sundry#315-081 Procedure Change Attachments: 1-09 Tree Swap Sundry Procedure Rev1 03-11-15.docx Follow Up Flag: Follow up Flag Status: Flagged Victoria, Enclosed is a revised procedure for the work on Endicott 1-09. The scope of the work is to set downhole barriers to be able to conduct a tree swap. The original procedure had the removal of 2 wireline retrievable plugs from the production liner(the plugs were set to isolate different zones but did not isolate the wellbore from all formations). The elimination of these steps makes the overall operation safer by eliminating runs. Please give me a call if you wish to discuss further. Thank you, Taylor Taylor Wellman Hilcorp Energy Company-Operations Engineer Office: (907)777-8449 Endicott: (907) 777-8449 Cell: (907) 947-9533 SCANNED MAR 1 9 Email: twellman@hiicorp.com 10)5 1 Tree Swap Well: 1-09 PTD: 1970290 Hileorn Alaska,LL API: 50-029-21743-01 Well Name: 1-09 API Number: 50-029-21743-01 Current Status: SI Rig: SL&Tree/WH Crew Estimated Start Date: February 17, 2015 Estimated Duration: 5 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 1970290 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Chris Kanyer (907)777-8377 (0) (907) 250-0374(M) Current Bottom Hole Pressure: 4119psi @ 10,000' TVD (Based on SBHPS on 4-10 04/22/14) Maximum Expected BHP: 4119psi @ 10,000' TVD (Based on SBHPS on 4-10 04/22/14) Max. Anticipated Surface Pressure: 3,200psi (Based on 0.1 psi/ft. gas gradient) Brief Well Summary: Endicott 1-09 is a production well open to the K1 and K2A. The well's bottom hole location is near the crest of the formation in the gas cap. Due to this,the well has an extremely high GOR and is not a competitive cycle well. Well 1-09 is located in a good location to be used as a potential Gas Injection well. Well 1-21 has an uprated 6500psi tree on it. In order to save the option to convert well 1-09 to an injection well,the trees on 1- 21 & 1-09 need to be swapped. Objective: To prepare the well for tree change out. For downhole work,the GLV's in the well will need to be dummied off and the IA liquid packed. The surface requirements are a tree swap which will require a downhole plug and BPV to establish barriers. Procedure: Slickline and Pumping 1. MIRU SL unit. 2. Pressure test to 300psi low and 3500psi high. 3. Pull 4-1/2" BBE SSSV from 1541' md. 4. Pull 4-1/2" DH Choke Assembly from 11,493' md. 5. Set PXN plug at 11,493' md. 6. Bleed tubing and inflow test the plug to ^'1800 psi for 15 minutes. a. If inflow test indicates a good set, move to next step. If not, pull and re-set plug. 7. Pull GLV's from station station #6 (3575' md) &#3 (7526' md). 8. Set DGLV in station #6 (3575' md). 9. Circulate seawater down the IA while taking returns to the flowline (580 bbls total). Follow with 70 bbls of diesel. 10. Attach jumper line from the IA to the tubing and allow pressure to equalize. 11. Set DGLV in station #3 (7526' md). 12. Conduct an MIT-IA to 2500psi and MIT-T to 2500psi. a. Passing criteria: Less than 10% overall loss in 30 min and demonstrating a stabilizing pressure trend. Record 15 min and 30 min pressure reads of the tubing, IA, and OA. Tree Swap Well: 1-09 PTD: 1970290 Hilcorp Alaska,LL API: 50-029-21743-01 13. Bleed tubing and IA pressures to 0 psi. Tree&Wellhead Work 1. Verify that tubing above the SSSV and IA pressures have been bled to 0 psi and that the BUR is 0 psi. a. The tubing and IA are both full with seawater and 1000' tvd of diesel. Both the tubing and IA are —400psi overbalanced. 2. Set 4" H Profile BPV in the tubing hanger. 3. Attach lifting sub to the tree and pick up tree as per Cameron recommendation. 4. Nipple down and pick up tree. 5. Stack back tree in preparation for swap with tree from well 1-21. 6. Inspect ring groove and replace ring gasket and seals as needed. 7. Unbolt 13-5/8" x 4-1/16" CIW 5M adapter from the well. 8. Replace neck seals as needed and install new 13-5/8"x 4-1/16" CIW 5M (Uprated to 6500psi) adapter. 9. Install tree from well 1-21:4"CIW 5M (Uprated to 6500psi). 10. Pull BPV from the tree hanger. Install TWC. 11. Rig up the BPV lubricator and pressure test to 6000psi. 12. Pull the TWC and RD from the well. Slickline Work 1. MIRU SL unit. 2. Pressure test to 300psi low and 2200psi high. 3. Pull PXN Plug from 11,493' md. 4. RDMO. Attachments: As-built Well Schematic, Deviation Survey,Tubing Tally,Wellhead &Tree Diagram oFTH 0" //j, s THE STATE Alaska Oil and Gas gcl °fALA KA. Conservation Commission ___ __ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 OA,ALAS*P. Fax' 907.276.7542 t4E© 1\11 www.aogcc.alaska www.aogcc.alaska gov SCwN Taylor Wellman 00--6T©� Operations Engineer 1 a Hilcorp Alaska, LLC 9 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU MPI I-09A/L21 Sundry Number: 315-081 Dear Mr. Wellman: 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, 731 P. oerster Chair, Commissioner DATED this 3 day of March, 2015 Encl. RECEIVED STATE OF ALASKA FEB 13 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION 3 311 5— APPLICATION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well 0 Change Approved Program 0 Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing❑ Time Extension ❑ Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate❑ Alter Casing❑ Other. Remove and Replace Tree 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 2 197-029 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-21743-01-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 • Will planned perforations require a spacing exception? Yes ❑ No 0 1 DUCK IS UNIT MPI 1-09A/L21 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312828 • Endicott Field/Endicott Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 13,072 • 10,258 • 11,895 10,078 11,895'&11,905' N/A Casing Length Size MD ND Burst Collapse Structural Conductor 131' 30" 131' 131' Surface 2,510' 13-3/8" 2,510' 2,508' 5,020psi 2,260psi Intermediate 8,081' 9-5/8" 8,081' 7,469' 6,870psi 4,760psi Intermediate 4,041' 7" 11,933' 10,087' 7,240psi 5,410psi Liner 729' 4-1/2" 12,585' 10,170' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" L-80/12.6/BTC 11,506 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 7"Baker ZXP Top Pkr,7"Baker S-3 Pkr&4-1/2"TIW SS Horiz.Pkr and 7,892MD/7,329ND,11,477MD/9,837ND&11,870MD/10,070TVD 4-1/2"HXO SVLN and 1,541MD/1,540ND 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 2 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/20/2015 Oil ❑✓ • Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: GSTOR ❑ SPLUG 0 1 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Wellman Email twellman@hilcorp.com Printed Name ,-Taylor Wellman /�/ ^ Title Operations Engineer Signature T / .�/^�/�"* Phone 777-8449 Date 2/13/2015 PCOMMISSION USE ONLY ' Conditions of appr. .. Notify Commission so that a representative may witness Sundry Number: Lin Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ N Other: `r' -12 Spacing Exception Required? Yes 0 No © Subsequent Form Required: /d 4-0 4 u) 2 Ii APPROVED BY � m Approved by: / ` COMMISSIONER THE COMMISSION Date: 3 - 3 JIX 4164+ AdEr auomrt Dorm ana Form 10-403(Re sed 10/2012) Q, 12 months from the date of approval. Attachments� /�ttachments in Dupli e Z./17/s" VTL 2/26//S Ai; 3•.t-1,K /, 7 `vb Tree Swap Well: 1-09 . • PTD: 1970290 Hileorp Alaska,LL API: 50-029-21743-01 Well Name: 1-09 API Number: 50-029-21743-01 Current Status: SI Rig: SL&Tree/WH Crew Estimated Start Date: February 17, 2015 Estimated Duration: 5 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 1970290 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Chris Kanyer (907) 777-8377 (0) (907) 250-0374(M) Current Bottom Hole Pressure: 4119psi @ 10,000' TVD (Based on SBHPS on 4-10 04/22/14) Maximum Expected BHP: 4119psi @ 10,000' ND (Based on SBHPS on 4-10 04/22/14) Max.Anticipated Surface Pressure: 3,200psi (Based on 0.1 psi/ft. gas gradient) Brief Well Summary: Endicott 1-09 is a production well open to the K1 and K2A. The well's bottom hole location is near the crest of the formation in the gas cap. Due to this,the well has an extremely high GOR and is not a competitive cycle well. Well 1-09 is located in a good location to be used as a potential Gas Injection well. Well 1-21 has an uprated 6500psi tree on it. In order to save the option to convert well 1-09 to an injection well,the trees on 1- 21& 1-09 need to be swapped. ✓ Objective: To prepare the well for tree change out. For downhole work,the GLV's in the well will need to be dummied off and the IA liquid packed. The surface requirements are a tree swap which will require a downhole plug and BPV to establish barriers. Procedure: Slickline and Pumping 1. MIRU SL unit. 2. Pressure test to 300psi low and 3500psi high. 3. Pull 4-1/2" BBE SSSV from 1541' md. 4. Pull 4-1/2" DH Choke Assembly from 11,493' md. 5. Pull 4-1/2" Special Clearance WRP from 11,895' md. 6. Pull 4-1/2" Special Clearance WRP from 11,905' md. 7. Drift to deviation into the slotted liner with 2.5" centralizer. 8. Set PXN plug at 11,493' md. 9. Bleed tubing and inflow test the plug to "'1800 psi for 15 minutes. a. If inflow test indicates a good set, move to next step. If not, pull and re-set plug. 10. Pull GLV's from station station #6 (3575' md) & #3 (7526' md). 11. Set DGLV in station #6 (3575' md). 12. Circulate seawater down the IA while taking returns to the flowline (580 bbls total). Follow with 70 bbls of diesel. 13. Attach jumper line from the IA to the tubing and allow pressure to equalize. 14. Set DGLV in station #3 (7526' md). Tree Swap Well: 1-09 PTD: 1970290 lhkorp Alaska,LLQ API: 50-029-21743-01 15. Conduct an MIT-IA to 2500psi and MIT-T to 2500psi. a. Passing criteria: Less than 10% overall loss in 30 min and demonstrating a stabilizing pressure trend. Record 15 min and 30 min pressure reads of the tubing, IA, and OA. 16. Bleed tubing and IA pressures to 0 psi. Tree &Wellhead Work 1. Verify that tubing above the SSSV and IA pressures have been bled to 0 psi and that the BUR is 0 psi. a. The tubing and IA are both full with seawater and 1000' tvd of diesel. Both the tubing and IA are —400psi overbalanced. 2. Set 4" H Profile BPV in the tubing hanger. 3. Attach lifting sub to the tree and pick up tree as per Cameron recommendation. 4. Nipple down and pick up tree. 5. Stack back tree in preparation for swap with tree from well 1-21. 6. Inspect ring groove and replace ring gasket and seals as needed. 7. Unbolt 13-5/8" x 4-1/16" CIW 5M adapter from the well. 8. Replace neck seals as needed and install new 13-5/8" x 4-1/16" CIW 5M (Uprated to 6500psi) adapter. 9. Install tree from well 1-21: 4" CIW 5M (Uprated to 6500psi). 10. Pull BPV from the tree hanger. Install TWC. 11. Rig up the BPV lubricator and pressure test to 6000psi. 12. Pull the TWC and RD from the well. Slickline Work 1. MIRU SL unit. 2. Pressure test to 300psi low and 2200psi high. 3. Pull PXN Plug from 11,493' md. 4. RDMO. Attachments: As-built Well Schematic, Deviation Survey,Tubing Tally,Wellhead &Tree Diagram llaLC .. END1 -09A VrD . nU CJ:AGE20-20� N L - S izz LLHEAD= FMC .DINGS AVERAGE 230-260 PPM ON A/L 8 GAS TUMOR BAKER _ _ECTORS"" WELL REQUIRES A SSSV"•'41/2" 1,A,L KB.aE 55' I j I (CHROME NIPPLES(9CR)"" 1AL BF.aE 182 P= 1541' J-j4-1/2"HXO SVLN,ID=3.813" ( Angie= 84°@ 12544' O um MD= 11830' um TVD= 10000 SS 13-3/8"CSG,68#,NT80 CY HE BUTT, H 2546' D=12.415" GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT LLAT -1/2"LNR, 12-6#,L-80 NSCT XO TO BTC-M, — 2850' '--x x 6 3575 3563 7 (MGM DOME RK 16 12/04/ I 5 5348 5321 15 MMGM DMY RK 0 06/16/ 9-5/8"X 7"BKR ZXP LTP —� 7892" L 4 6541 6361 43 MMGM DMY RK 0 07/19/ w/HMC LNR HGP El=? ` 3 7526 7064 45 MMGM SO RK 20 12/04/ 2 8469 7738 46 KGB2 DMY INT 0 08/031 9-5/8"CSG,4/#,NT95HS,IU=8.681" H 8081' 1 9456 8438 44 KGB2 DMY INT 0 03/23, Minimum ID = .50" @ 11493' 1 , 11437' H4-112"HESX NP,D=3.813" 4-1/2" XN-LOCK CHOKE z X 11447' —17•X 4-1/2"BKR S-3 PKR,D=3.875" I II 11471' —14-1/2"HES X NP,D=3.813" I11493' H4-1/2"HES XN NP,D=3.725" 11493' -H4-1/2"XN LOCK,DH CHOKE ASSEMBLY, D=.05"(03/28/14) 4-1/2"LNR, 12.6#, L-80 BTC-M, —I 11506' J----/ `--I 11506' H4-112"WLEG,ID=3.958" .0152 bpf,D=3-958" — 11515' H EI.MD TT LOGGED ON 09/08/88 — TOP OF4-1/2"LNHR 11870' 11870' H4-112"TNVHOW FiR,D=4.00" 10.14 11895'ELM —14-1/2"SC WRP(05/09/12) DIN-1 11905' ELM —141/2"SC WRP(04/07/12) LNR,26#,L-80 BTC-M,.0383 bpf,0=6.276" — 11933' 1--4 PERFORATION SUMMARY REF LOG:SPERY DUAL GR ON 03/12/97 ANGLE AT TOP PERF: 69°@ 11819' Note:Refer to Production DB for historical perf data I I SIZE SFF INTERVAL Opn/Sqz SHOT SQZ 2-7/8" 6 11819- 11824 0 06/13/12 4-1/2" SLID 11976- 12562 03/20/97 I I 4-1/2"SLTD LNR,12.6#,L-80 NSCT, JI 12585' ii, .0152 bpf,D=3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS ETDICOTT UNIT 9/11/87 D15 INITIAL COMPLETION 06/27/12 VVEC/JMD SET VVRP(05/09/12) WELL: 1-09A/L-21 13/24/97 D15 SIDETRACK(END1-09A) 12/04/13 DLW/JMD GLV C/O(12/04/13) PERMIT No: 1970290 4/10/12 LECIJMD SET WRP(04/07/12) 03/20/14 VVKFVJMD SET DH CHOKE(03/15/14) AR No: 50-029-21743-01 15/27/12 MSS/PJC GLV CIO 05/09/12) 04/10/14 RKT/PJC PULU SET DH CHOKE(03/28/14) SEC 36,T12N,R16E,1961'FNL&2050'FE 15/27/12 PJC 4.5"LNR CORRECTION IHilcorp ALaska LLC 16/15/12 JCM/JMD ADR�F(06/13/12) END 1-09 13 5/8 X 4''A tubing hanger 4"BPV profile 4 1/16"5M Otis,Tree cap •i r•UT' WHIM 41/16"CIW Swab valve HWO 000 rnia G G rcn 0/1.1 N l 1� 41!~ 41/16"SM CIW Valve,Wing, L� Baker actuator N re_ 4 1/16"CIW 5M valve SSV Baker actuator • % •) 4 1/16"CIW Master valve `a&¢ HWO 11411110G0 4 1 rou 16 a ME L ��,� � 11 ,_.. WKM 2 1/16"5M �'�� HWO I 1)1 t.... WKM HW06"5M 13 5/8 ' 9 5/8 4 1/2 STATE OF ALASKA • RECEI\s� 2, AllKA OIL AND GAS CONSERVATION COMMISSION 2 3 I AUG REPORT OF SUNDRY WELL OPERATIONS Al 1. ((�� as , ,,;0510n 1. Operations Abandon L Repair WEL Plug Perforations L Perforate U �It�e �5� �rltig`s Performed: Alter Casing El Pull Tutit❑ Stimulate - Frac ❑ Waiver El Time Extension[ flchorage Change Approved Program ❑ Operat. Shutdot❑ Stimulate - Other ❑ Re -enter Suspended WeIG 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Developmer t al Exploratory ❑ ~ 197 -029 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 21743 -01 -00 7. Property Designation (Lease Number): .. 8. Well Name and Number: f ADL0312828 1- 09A/L -21 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted ENDICOTT, ENDICOTT OIL 11. Present Well Condition Summary: Total Depth measured 13072 feet Plugs measured See Attachment feet true vertical 10257.68 feet Junk measured None feet Effective Depth measured 11895 feet Packer measured See Attachment feet true vertical 10078.15 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 93 20" 94# 1-1-40 38 - 131 37.99 - 130.99 1530 520 Surface 2470 13 -3/8" 68# NT -80 40 - 2510 39.99 - 2508.14 5020 2260 Intermediate None None None None None None Production 8043 9 -5/8" 47# L -80 38 - 8081 37.99 - 7469.55 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11819 - 11824 feet 11976 - 12562 feet :14 .. PO41. - : : -' N; t r i) 'T i l l True Vertical depth 10052.06 - 10054.02 feet 10096.07 - 10167.2 feet M Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 37 - 11506 36.99 - 9878.52 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 21 18 194 1142 261 Subsequent to operation: 845 22312 619 2124 1285 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratorl❑ Development 0 - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0. is Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Gar ry Catron Title PDC PE aa �/ /// Signature d t - Phone 564 -4424 Date 8/23/2012 jr 1.- f, , `e g . 4 �DMS AUG 2 4 1011 ell 4117' ORIGINAL. Form 10-404 Revised 10/2010 Submit Original Only • • 1 -09A/L -21 197 -029 -0 Plugs Attachement SW Name Date MD Description 1- 09A/L -21 5/9/2012 11895 4 -1/2" WRP 1- 09A/L -21 4/7/2012 11905 4 -1/2" WRP • • Packers and SSV's Attachment ADL0312828 SW Name Type MD TVD Depscription 1- 09A/L -21 PACKER 7892 7273.05 7" Baker ZXP Top Packer 1- 09A/L -21 PACKER 11447 9780.99 7" Baker S -3 Packer 1- 09A/L -21 PACKER 11870 10014.3 4 -1/2" TIW SS Horiz Packer Casing / Tubing Attachment ADL0312828 Casing Length Size MD TVD Burst Collapse CONDUCTOR 93 20" 94# H -40 38 - 131 37.99 - 130.99 1530 520 LINER 4041 7" 26# L -80 7892 - 11933 7329.46 - 10087.5 7240 5410 LINER 715 4 -1/2" 12.6# L -80 11870 - 12585 10070.71 - 10169.8 8430 7500 PRODUCTION 8043 9 -5/8" 47# L -80 38 - 8081 37.99 - 7469.55 6870 4760 SURFACE 2470 13 -3/8" 68# NT -80 40 - 2510 39.99 - 2508.14 5020 2260 TUBING 11469 4 -1/2" 12.6# L -80 37 - 11506 36.99 - 9878.52 8430 7500 • • • • Daily Report of Well Operations ADL0312828 ** *WSR CONT. FROM 4- 6 -12 * ** HES DPU, WFD 4 1/2" SPECIAL CLEARANCE WRP HUNG UP @ 11,481' SLM. PULL HES DPU, WFD SETTING SLEEVE FROM 11,493' SLM.(setting sleeve missing 1 -set screw) RUN 3.625" CENT, TEL, 3.70" CENT, 3.25" LIB TO 11,835' SLM/11,876' ELM(lib has impression of packer) RUN 3.625" CENT, TEL, 3.70" CENT, 3.25" CENT, 2.25" LIB TO 4 1/2" WFD WRP @ 11,863' SLM/11,905' ELM(impression of shear stub on lib) PERFORM DRAW DOWN TEST.(results inconclusive) * ** *WELL LEFT S/I ON DEPARTURE, WELL TENDER ON SITE FOR 4/7/2012 WALKTHROUGH * * ** T /I /O= 350/350/40. Temp= SI. WHPs & T FL. (Full -Bore call in). AL shut in at casing valve. ALP= 2250 psi. T FL @ 7406' (120' above sta #3; 113 bbls). 4/8/2012 SV & WV= C. SSV & MV= O. IA & OA= OTG. NOVP. 13:30 T /I /O 347/362/29 Temp = S1 Load tubing (pre perf) . Pump 5 bbls meth, 15 bbls 100 *f diesel, 72 bbls 100 *f 1% KCL down tbg to load. Pump 100 bbls diesel in attempt to catch pressure, well remained on a vac. Obtain a LLR of 2 bpm at 0 psi. FWHP 4/14/2012 vac/388/28 SW,WV= closed, SSV,MV =open, IA and OA =OTG ** *WELL S/I ON ARRIVAL** *(gas -lift integrity) SET WHIDDON CATCHER SUB ON XN NIP @ 11460' SLM/11493' MD MADE MULTIPLE RUNS TO STA. #2 @ 8469' MD PULLED STA. #2 INT -OGLV @ 8447' SLM/ 8469' MD, MISSING COLLETS & NOSE CONE FROM PORTS DOWN RAN POCKET POKER TO STA. #2, TT PINS INDICATE CLEAR POCKET 4/29/2012 ** *CONT. ON 4/30/12 WSR * ** * * *CONT. FROM 4/29/12 WSR ** *(gas -lift integrity) SET INT -DGLV IN STA. #2 @ 8447' SLM/ 8469' MD RAN 1.25" LIB TO STA# 2 @ 8447' SLM/8469' MD(impression of int-dglv) PULLED RK- LGLV's FROM STA# 4 @ 6521' SLM/6541' MD & STA# 6 @ 3552' SLM/3575' MD SET RK -DGLV IN STA# 6 @ 3552' SLM/3575' MD LRS LOADED IA W/ 529bb1s 1% KCL & FREEZE PROTECT W/ 26bbls DIESEL SET RK -DGLV IN STA# 4 @ 6521' SLM/6541' MD LRS PERFORM MIT -IA @ 1000psi, 30 BBLS AWAY, IA STILL ON VAC PULLED WCS FROM 11,460' SLM/ 11493' MD (pieces of int-oglv in catcher) 4/30/2012 ** *CONT. ON 5/1/12 WSR * ** ** *CONT. FROM 4/30/12 WSR** *(gas -lift integrity) SET 4 -1/2" PXN PLUG BODY @ 11,465' SLM/ 11,471' MD SET PRONG IN PLUG BODY @ 11,457' SLM (TOP) LRS PERFORM MIT -T (a) 2500psi, FIRST TEST PASSED BUT WAS NOT CHARTED PULLED PRONG MADE COUPLE ATTEMPTS TO PULL PLUG BODY RAN 5' x 2.25" PUMP BAILER, RECOVERED SEVERAL SMALL PIECES OF SCALE 5/1/2012 ** *CONT. ON 5/2/12 WSR * ** • • Daily Report of Well Operations ADL0312828 ** *Continued WSR from previous day 04 -30- 2012 * ** Assist Slickline, MIT -T * *FAILED ** to 2500 psi, Pumped 65 bbls 100* 1% KCL followed by 31.9 bbls 70* deisel down TBG to reach test pressure. ( 3rd attempt ): 1st 15 minutes Tbg lost 80 psi. 2nd 15 minutes Tbg lost 96 psi. 3rd 15 minutes Tbg lost 96 psi. Total loss in 45 minutes= 272 psi. Bled TP (— 2 bbls ). FWHP's= 170/170/0 Slickline in control of 5/1/2012 well upon departure. IA & OA= OTG. Tags hung & Well tender notified. * * *CONT. FROM 5/1/12 WSR ** *(Gas -Lift integrity) RAN 10' x 1 -3/4" HYDROSTATIC BAILER TO 11,470' SLM (empty) PULLED PXN PLUG BODY FROM 11,465' SLM/ 11,493' MD 5/2/2012 ***WELL LEFT S /I, WELL TENDER NOTIFIED * ** ** *WSR CONT FROM 5- 7 -12 ** *(profile mod) RAN TEL, 3.7" CENT., 1.7 LIB TAGGED TT @11,480" SLM ( +35' CORRECTION) TAGGED WRP @ 11,870' SLM / 11,905 ELM SET4 1/2" WRP @ 11,860'SLM/11,895'ELM 5/8/2012 ** *WSR CONT. ON 5- 9 -12 * ** 5/8/2012 SET 4 1/2" WRP @ 11,860'SLM/11,895'ELM ** *WSR CONT. FROM 5- 8 -12 * ** LRS LOADED TBG W/5 BBLS. METH, 40 BBLS DIESEL, 52 BBLS KCL LRS PERFORMED PASSING MIT -T TO 2,500 PSI. SET WHIDDON C -SUB @ 11,458' SLM PULLED STA.# 2 INT -DGLV © 8,442' SLM (8,469' MD) PULLED STA.# 4 RK-DGLV @ 6,515' SLM (6,541' MD) PULLED STA.# 6 RK -DGLV © 3,550' SLM (3,575' MD) SET STA.# 6 RK -LGLV (16/64" ports, 1,741# tro) @ 3,575' MD SET STA.# 4 RK -LGLV (16/64" ports, 1,784# tro) @ 6,541' MD SET STA.# 2 INT -OGLV (24/64" ports) @ 8,469' MD PULLED EMPTY WHIDDON C -SUB @ 11,458' SLM 5/9/2012 ** *WELL S/1 ON DEPARTURE, DSO NOTIFIED OF STATUS * ** ** *WSR continued * ** T /I /0= 110/37/0 Temp =S /I Assist slickline MIT T * *PASSED ** to 2500 psi (Gas Lift Integrity) Pumped 5 bbls neat methanol,followed by 40 bbls dsl, followed by 52 bbls 1 %kcl, followed by 4 bbls neat methanol to reach test pressure. 15 min T lost 161 psi 30 min T lost 43 psi. Total loss of 204 psi in 30 mins. Bled psi back 5/9/2012 to 500 psi. SSL still on well at LRS departure. FWHP= 500/37/0 T /1 /0= 34/67/37 Temp =ST OMIT -TxIA to 2500 psi (PASSED) MIT -T to 2500 psi (PASSED) (Integrity) Pump 267 bbls 40* diesel down IA to pressure up TBG /IA. Lost 7 psi on TBG, gained 1 psi on IA in first 15 min. Gained 1 psi on TBG and 4 psi on IA in second 15 min. Bled back - 5bbls. Pumped 1 bbls 40* diesel down tbg to reach test pressure. 1st 15 min lost 1 psi. 2nd 15 min gained 10 psi for a total gain of 9 psi in 30 min. Valve positions upon departure= SV WV= closed. SSV MV IA OA =open Tags 6/4/2012 hung DSO notified. FWHP's 500/500/25 ***WELL SHUT-IN ON ARRIVAL*** (SLB E -LINE AD 5' PERF) INITIAL T /I /0 = 800/750/0 RAN 5' X 2 -7/8" 2906 PJ OMEGA HMX GUN (PERFORATED INTERVAL @ 11827'- 11832') DSO NOTIFIED NOTIFIED OF WELL STATUS FINAL T /I /O = 130/430/0 PSI 6/13/2012 ** *JOB COMPLETE -- WELL SHUT -IN UPON DEPARTURE * ** 4110 • Daily Report of Well Operations ADL0312828 ***WELL S/I ON ARRIVAL * ** ( perforating ) BRUSHED SVLN @ 1508' SLM SET BBE (SER # NBB -04) @ 1508' SLM TIGHT SPOTS @ 2' & 10' SLM(see log) RAN CHECK SET TO BBE @ 1508' SLM (sheared) 6/15/2012 ** *WELL LEFT S/I WELL TENDER NOTIFIED OF STATUS * ** 4 ■ TREE = OW ill S NOTES: WELL ANGLE > 70° @ 11862"" H2S WELLHEAD = E N D ND 1 -09 A READINGS AVERAGE 239 - 260 PPM ON A/L & GAS ACTUATOR = BAKER C INJECTORS "" WELL REQUIRES A SSSV " *4 -1/2" - INITIAL KB. ELE 55' I I (CHROME NIPPLES (9CR) "' INITIAL BE ELE 18.2' KOP= I 1541' H4-1/2" HXO SVLN (9-CR), ID = 3 813" I Max Angle = 84° @ 12544' Datum MD = 11830' Datum 1VD = 10000 SS 13 -3/8" CSG, 68 #, NT80 CYHE BUTT, H 2546' , 10=12415" GAS LIFT MANDRELS ST l MD TVD DEV TYPE VLV LATCH PORT DATE 4-1/2" LNR, 12 6 #, L -80 NSCT XO TO BTC -M, H 2850' I 6 3575 3563 7 MMGM DOME RK 16 05/09/12 5 5348 5321 15 MMGM DMY RK 0 06/16/97 4 6541 6361 43 MMGM DOME RK 16 05/09/12 3 7526 7064 45 MMGM DMY RK 0 03/23/97 2 8469 7738 46 KGB2 SO INT 24 05/09/12 Minimum ID = 3.725" 11493' 1 9456 8438 44 KGB2 OW INT 0 03/23/97 4 -1/2" XN OTIS NIP 7892' IH9 -5/8" X 7" BKR ZXP LTP w / I1 IC LNR HGR, ID = I I 19 -5/8" CSG, 47 #, NT95HS, ID = 8.681" I--{ 8081' 11437' H4-1/2" HES X NIP (9 -CR), ID = 3.813" z 1.1 { 11447' —17" X 4-1/2" BKR S -3 PKR, ID = 3.875" I 11471' H4-1/2" HES X NIP (9 -CR.), ID = 3 813" 11493' — 14 -1/2" HES XN NIP (9 -CR), ID = 3.725" 4-1/2" LNR, 12.6 #, L -80 BTC -M, —I 11506' J / 11506' —14 -112" WLEG, ID = 3.958" .0152 bpf, ID = 3.958" , 11515' HELM) TT LOGGED ON 09/08/88 I TOP OF 4-1/2" LNR I— 11870' 11870' 1-14-1/7 TIW HORIZ PKR, ID = 4 00" 1 11895' ELM — 4-1/7 SC WRP (05/09/12) 11905' ELM — 14-1/2" SC WRP (04/07/12) IT LNR, 26 #, L -80 BTC-M, .0383 bpf, ID= 6.276" —I 11933' I - A PERFORATION SUMMARY REF LOG SPERY DUAL GR ON 03/12/97 ANGLE AT TOP PERF. 69 °@ 11819' Note. Refer to Production DB for historical perf data I I SIZE SPF INTERVAL OpnlSgz DATE 2 -718" 6 11819 - 11824 0 06/13/12 I I 4 -1/2" SLTD 11976 - 12562 C 03/20/97 J L 4-1/2" SLTD LNR, 12.6 #, L -80 NSCT, --I 12585' 0152 bpf, ID = 3 958" DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 09/11187 D15 INITIAL COM PLETION 04/10/12 LEC/JMD SET WRP (04/07/12) WELL 1 -09A / L -21 03/24/97 D15 SIDETRACK (END1 -09A) 05/27/12 MSS/ PJC GLV GO 05 /09/12) PERMIT No ' 1970290 02/16/11 MB /JMD ADDED SSSV SAFETY NOTE 05/27/12 PJC 4.5" LNR CORRECTION API No 50- 029 - 21743 -01 08/12/11 DW /JMD ADDED H2S SAFETY NOTE 06/15/12 JCMIJMD ADPERF (06/13/12) SEC 36, T12N, R16E, 1961' FNL & 2050' FEL 02 /03/12 PJC LEGEND CORRECTION 06/17/12 PJC REF LOG / PERF ANGLE 02/28/12 TJWJMD REFORMATTED(01 /14/11) .06/27/12 WECJJMD SET WRP(05/09 /12) BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wel F-48 G-19A NGI-13 MPE-30A F-11 B W-12A 11-27 02-22A 01-16 01-14 L5-05 D-21 14-15 D-18A 14-05A 1-23/0-15 S-03 1-09A1L-21 P2-19A OWDW-NW K-01 11-32 3-25B/L-27 Job # 11846815 11890315 11890313 11855817 11649954 11418301 11637127 11216214 11630486 11801086 11767129 11626119 11221550 11695074 11813055 11846802 11223120 11849930 11649963 11211370 11695073 11630498 11630490 ~~NED OCT 312007 Loa Descriotion USIT ,"1 1- ()f( ~ usn /'-'ìu, - tl)~ USIT I), f' I ~ -r? I USIT ..;)0 I - 0 I ( MCNL .:>cf-I - ID¡'-( -: 1.")51:~ MCNL )'17r -1'5fg .. I~Ç-:¡'-I RST i~(¡" - ~'Í{ ¢ ) ~.ç--::}G:, MCNL .:Jf'¡["\ - {, ~CI, "1t <:-<:: -:J.-:+- RST I ~5r - QOSr 11-, &:::::.<.- j.:;? RST /0. '1- _ ~"'¡.? tt ¡ '" -:"\~'4 MCNL /7f -:} J')(,.,C:; ~, .c:::-:~ 0 RST ,7r;::) - n~":::> '*- ,,\., X I RST l"';r I - Ó"ðL( "]t I ~,,'X;. RST ::)h/- l()~ ¢ ,""" '7S" -< RST / D¡;:) - (1U I .. I L.,-=;-'7{ (~ RST I )Ï"I' o,LI-/~'5r 'It ~~~ RST /70I-CjJ',11:. /';')<\"1,(..( RST I Q, ':} - ,,;::J q 11: I ~S- -:+ ::<) MCNL _1/)'+-- (')j;,) iP 155-+d RST lJT.J' ~"'" --VI...... J:I- I~~~I RST I ~7., - I;:::) I ';F I ó-S7-ò RST I ~ I..{- /3 *" I J"S (",c¡ RST ,::)¡,,\Q - /"\;::) I .... I .ç:<:7~ 51" PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2·1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: - Date 10/12/07 09/30/07 09/30/07 10/01/07 03/22/07 09/10/06 06/05/07 10/02/06 06/28/07 07/07/07 06/17/07 09/12/07 03/07/06 08/28/07 06/11/07 08/11/07 06/13/06 08/04/07 04/22/07 02/28/06 08/27/07 09/03/07 07/26/07 NO. 4459 Company: State of Alaska Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Aurora, Miln!! Pt.,LisburnE BL Color 1 1 1 1 CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~';',~m~:;:' ""~lL Received by: (! d 10/23/07 . . 08/30/07 Schlumberger NO. 4396 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 . L ATTN: Beth 'í \rJ ,¡. Vl~~c,. ~' SCANNED SEP I 8 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay E d' tt ~ n ICO Job# Log Description Date BL Color CD \. MPC-08 ) N/A RSTIWFL 08/10/07 1 l1IJ"I"õT-ro 11767136 MEM INJ PROFILE I J T l', I ~ 1<1-J^~ 08/12/07 1 P2-16 11856185 INJECTION PROFILE U::r:t'_ Ie. ,.-; - l;J~ 08/02/07 1 07 -02A 11649983 MEM PROD PROFILE j ~ r. - N1 7< 08/07/07 1 R-13 11856186 INJECTION PROFILE I 1,1'1 ,. ~ - d-I~ 08/02/07 1 D-11A 11649982 MEM PROD PROFILE I q,"'- - !-$(~ 07/26/07 1 S-42 11686773 LDL Iq~ -('Ü<"¡ 08/02/07 1 S-43 11855804 LDL J C 4 -t"ì~:J 08/02/07 1 16-07 11855806 STATIC PRESSURE SURVEY I '"i( S- - .G-o 4 08/04/07 1 16-21 11855805 STATIC PRESSURE SURVEY 11):'<;- -~l~ 08/04/07 1 1-09A1L-21 11849930 SBHP SURVEY J'1~ - I'"J!JQ 08/04/07 1 2-68/S-17 11630491 LDL L~_ f'Aq. 07/27/07 1 1-23/0-15 11846802 STATIC PRESSURE SURVEY u:rr, 1'1¿¡ -/t:)."K 08/11/07 1 Z-46 11057080 CH EDIT PDC GR (USIT);)D."')-/~I 'It t...... ',:...]d 12/14/05 1 A-09A 11216203 MCNL .QðD-I-:}t{" '~(/f:J'1 06/29/06 1 1 L3-11 11801065 RST i '7s'5'""" ::)';:t, .... IIN. -uv " 05/31/07 1 1 PLEASE ACKNOWLEDGE RECEIP~~ é§J".~"~~AN,D R~~~NING ONE COpy EACH TO: BP Exploration (Alaska) Inc. I("'{ ,~,,~ \1 .~ II·'" ~ \ l~."" Petrotechnical Data Center LR2-1' "-, \.../ ¡h., "k ¡L~ 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ""''''''''''' AK ""'D~ A TTN: Beth Received byt¡- .~_........-- p i1 Z007 Date Delivered: iyr',:); f·c:::; ~-:..,m /l: (3,!:');~ . . MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission ,i; e Heusser ~%\~~ ~)~nmissione; FROM: John Crisp, SUBJECT: Petroleum Inspector. DATE: May 20, 2001 Safety Valve Tests Duck Island Unit Endicott MPI 1 & 2 May 20,2001: I traveled to BP's Duck Island Unit Endicott Field to witness Safety Valve System tests. Mark Souve was BP's Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, the SSSV on well 1-19 failed to pass the DP test. The AOGCC test report is attached for reference. ! inspected 25 well houses on MPI Row 1 & 2 w/no problems witnessed. SUMMARY: ! witnessed SVS testing in BP's Endicott Field. 17 wells, 51 components tested. 1 failure witnessed. 1.96% failure rate. 25 well houses inspected. A..ttachmen.ts: SVS DIU 5-20-01jc CC; NON-CONFIDENTIAL SVS DIU 5-20-01jc Alaska Oil and Gas Conservation Commlss,on Safety Valve System Test Report Operator: BPX Operator Rep: Mark Souve AOGCC Rep: John Cr~. Submitted By: John Crisp Field/Unit/Pad: Endicott DIU MPI Pad Separator psi: LPS 235 HPS Date: 5/20/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLr 1-01/J'l~ i880370 235 150 125 p p p , , OIL 1-03/P16 1951500 235 150 135 p p p OIL ~ , :1-05/O20 1861060 , 1-09A/L2 1970290 235 150 130 p p p OIL 1-15/P25 1930560 , , 1-17MI1 1961990 1-19/i18 ' 1950930 '235: 150: 125 P' P 9 oil , ,. 1-21/K25 1900020 l'25A/K2' 1970750 235 150 150 p e e 0I~ 1-27/1720' 1870090 235 150 ' 135 P e p OIL , '1.29/M25 '1'86181o ' 1-31/M21 1950720~ 235 150 125 P p p 0IL" 1-33B/L2 1982550 235 150 145 p p p ' 1'3~/O25 1861840 '235 150 '135 p p p OIL 1-39/P17 ' 1880630 , 1-45/Q26 1891240 l~47A/M2 1972030 1-49/P21 1880780 235 150 130 P p p , , oIL: 1-55/R25 1880210 235 150 145 p p p OIL 1-57/R23 1881140 235 150 140 P p P OIL 1-61/Q20 1941420 235 150 135 P P P' 'OIL 1-63/T22 1890060 235 150 1451 P P P , · OIg 1-65/N25 1951880 235 150 150 p p p OIL , ,, :2-04/M19 1860820 , , '2-06/J22 1870180 , , i 2-08/K16 1880040 2-,1.2/Q16 1921170 , , 2-14/O16 1861490 , , 2-18/L16 1900430 2-20/Li5 1960600 " 2-26/N14 1880550 , 2-28/P19 1880860 5-~oA/E1 1981880 ..... . , . , 2-32/SN3 1901190 , 2-36/Oi4 1900240 ,, 2'38/sN1 1901290 , 2-fiq/~S¢Tnn/i~1941520 ~o~, 1 ,~c9 SVS FlIT Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number psi. PSI T~P Code Co,de Code Passed,, GAS or,,CYCLE 2-42/P13 1881450 2-44,A/Q1, 1970710 ........ , ......... " 2-46B/S1 1971370 2-48/O13' 1951666 ..... 2'-50h308 1930670 2~'5 150 ' 145 P P P '" DIL 2-52/S14 1870920 , 2-56A/EI 1980580 2-58/S09 1900520 2-60FU13 1930830 '235 150 ' 130 P 'P" 'P ...... OIL ,2762/Q1'7 '186i'580 ' ' , , ",, ' ' ,, " 2-68/S17 1880970 5-01/SD7 1801200 . _ Wells: 17 Components: 51 Failures: 1 Failure Rate: 1.96% [3 9o var Remarks: RJF 1/16/01 Page 2 of 2 SVS DIU 5-20-01jc AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA PLUS .............. 97-029 GR/CCL /7800-8300 97-029 DIR SRL~/ ~k~BPX 8066.-13009.79 97-029 DIR SRVY c~/SPERRY 8022.3-13072 97-029 DGR/EWR4-MD ~'/11517-13072 97-029 DGR/CNP/SLD-MD ~ 11517-11933 97-029 DGR/EWR4-TVD ~9887-10258 - [~'9887 97 029 DGR/CNP/SLD-TVD -10087 97-029 8065 ~PERRY MPT/GR/EWR4/CNP/SLD 97-029 CNTD ~11220-11930 97-029 8908 ~/SCHLUM CNTD Page: 1 Date: 04/07/99 RUN RECVD FINAL 07/18/97 06/30/97 06/30/97 FINAL 08/13/97 FINAL 08/13/97 FINAL 08/13/97 FINAL 08/13/97 4-5 08/13/97 FINAL 11/13/98 i 11/18/98 DAILY WELL OPS R ©Aid)I??/ TO 3 /~/~/ Are dry ditch samples required? yes ~ And received? Was the well cored? yes ~_Analysis & description received? Are well tests required?~/yes ~_~Received? Well is in compliance Iditial COMMENTS T D BOX -- ~ALASKA~ ieare.d rvioes tilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: February 26, 1999 Fro m: Subject: Terrie Hubble Technical Assistant Miscellaneous Surveys Enclosed, in duplicate, are a number of directional surveys that I have come across while clearing out Ms. Campoamor's desk. I have verified that these surveys do not affect the previously calculated TVD's and below surface locations.of these wells, so it was not necessary to correct the 10-407's. They are simply being submitted for your records. If they are duplicates, please discard them. Thank you. /tlh Endicott MPI 1-09A/L-21 Milne Point MPC-09 Milne Point MPF-21 Milne Point MPF-37 Milne Point MPF-45 Milne Point MPF-69 Milne Point MPF-79 Permit ¢97-29 Permit ¢85-36 Permit ¢96-135 Permit ¢96-25 Permit ¢95-58 Permit ¢95-125 Permit ¢97-180 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING ENDICOTT / NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 031897 MWD SURVEY JOB NUMBER: AK-MM-70058 KELLY BUSHING ELEV. = 56.41 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8022.30 7426.49 7370.08 8066.00 7458.81 7402.40 8096.49 7481.02 7424.61 8132.44 7506.48 7450.07 8164.61 7528.99 7472.58 42 7 42 28 44 1 45 47 45 26 N 32.79 E .00 1797.88N 913.91E N 32.68 E .80 1822.62N 929.81E N 35.21 E 7.63 1839.94N 941.48E N 38.12 E 7.54 1860.29N 956.64E N 40.66 E 5.75 1878.05N 971.22E 561.85 572.85 581.07 592.16 603.17 8195.33 7550.56 7494.15 8228.40 7573.69 7517.28 8258.70 7594.61 7538.20 8291.15 7616.81 7560.40 8325.69 7640.31 7583.90 45 20 45 54 46 45 46 55 47 21 N 43.03 E 5.50 1894.34N 985.81E N 45.51 E 5.61 1911.26N 1002.31E N 47.73 E 6.01 1926.31N 1018.24E N 52.72 E 11.23 1941.44N 1036.42E N 56.36 E 7.83 1956.12N 1057.04E 614.46 627.50 640.34 655.37 672.88 8356.82 7661.35 7604.94 8386.39 7681.30 7624.89 8420.50 7704.53 7648.12 8453.92 7727.59 7671.18 8484.00 7748.54 7692.13 47 34 47 35 46 37 46 6 45 35 N 59.81 E 8.19 1968.24N 1076.50E N 63.39 E 8.94 1978.62N 1095.69E N 68.13 E 10.56 1988.88N 1118.47E N 72.11 E 8.76 1997.11N 1141.20E N 75.57 E 8.43 2003.12N 1161.92E 689.74 706.66 727.11 747.91 767.14 8518.23 7772.60 7716.19 8549.78 7794.99 7738.58 8580.23 7816.76 7760.35 8613.85 7840.76 7784.35 8646.26 7863.78 7807.37 45 9 44 24 44 20 44 31 44 57 N 80.24 E 9.79 2008.22N 1185.73E N 83.83 E 8.36 2011.31N 1207.73E N 84.65 E 1.90 2013.44N 1228.92E N 87.93 E 6.85 2014.96N 1252.40E S 89.02 E 6.75 2015.18N 1275.20E 789.58 810.61 831.03 853'.81 876.17 8676.04 7884.84 7828.43 8774.18 7954.23 7897.82 8869.64 8021.65 7965.24 8966.45 8089.69 8033.28 9060.30 8155.35 8098.94 45 2 44 57 45 10 45 31 45 40 S 88.84 E .54 2014.79N 1296.26E S 87.69 E .83 2012.68N 1365.62E S 86.93 E .60 2009.51N 1433.12E S 85.71 E .97 2005.09N 1501.85E S 85.39 E .29 1999.89N 1568.71E 896.93 965.46 1032.37 1100.71 1167.36 9155.08 8222.45 8166.04 9250.84 8291.02 8234.61 9347.16 8360.20 8303.79 9444.15 8430.30 8373.89 9540.97 8500.33 8443.92 44 10 44 21 43 49 43 37 43 43 S 85.44 E 1.59 1994.54N 1635.42E S 83.24 E 1.62 1987.94N 1701.92E S 86.77 E 2.61 1982.10N 1768.65E S 85.62 E .84 1977.65N 1835.53E S 84.25 E .98 1971.75N 1902.12E 1233.90 1300.46 1367.11 1433.64 1500.16 9629.94 8564.81 8508.40 9723.38 8631.99 8575.58 9821.29 8701.54 8645.13 9918.00 8769.87 8713.46 10011.95 8835.80 8779.39 43 23 44 40 44 49 45 16 45 34 S 83.31 E .82 1965.11N 1963.06E S 85.63 E 2.20 1958.87N 2027.69E N 89.58 E 3.45 1956.50N 2096.54E N 89.35 E .49 1957.14N 2164.98E S 89.16 E 1.18 1957.03N 2231.89E 1561.27 1625.92 1694.00 1761.12 1826.88 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING ENDICOTT / 109A/L-21 500292174301 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 031897 MWD SURVEY JOB NUMBER: AK-MM-70058 KELLY BUSHING ELEV. = 56.41 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10106.88 8901.94 8845.53 10202.95 8968.85 8912.44 10299.05 9036.63 8980.22 10396.38 9106.77 9050.36 10491.55 9175.67 9119.26 46 45 44 43 44 5 37 39 7 5 S 89.42 E .57 1956.18N 2299.98E S 88.10 E 1.10 1954.69N 2368.91E S 87.43 E 1.13 1952.04N 2436.97E S 85.45 E 2.10 1947.87N 2504.30E S 88.65 E 2.53 1944.51N 2569.84E 1893.93 1961.91 2029.27 2096.20 2161.21 10585.85 9242.50 9186.09 10679.78 9308.92 9252.51 10776.85 9377.05 9320.64 10873.09 9444.19 9387.78 10970.25 9512.97 9456.56 45 37 44 21 46 28 45 2 44 49 N 89.18 E 2.29 1944.22N 2636.34E N 89.52 E 1.38 1944.97N 2702.75E N 88.59 E 2.28 1946.12N 2771.86E N 89.19 E 1.55 1947.46N 2840.78E N 89.66 E .40 1948.15N 2909.40E 2226.59 2291.69 2359.36 2426.82 2494.11 11064.75 9577,.92 9521.51 11161.75 9642.75 9586.34 11256.97 9707.04 9650.63 11352.88 9772.65 9716.24 11449.12 9839.01 9782.60 48 19 47 50 47 12 46 28 46 20 N 89.54 E 3.70 1948.63N 2978.03E S 83.88 E 5.07 1945.09N 3050.05E S 80.68 E 2.57 1935.67N 3119.62E S 79.59 E 1.13 1923.69N 3188.55E S 79.78 E .20 1911.20N 3257.12E 2561.43 2632.85 2702.96 2772.91 2842.61 11543.07 9904.92 9848.51 11576.60 9928.31 9871.90 11608.33 9949.22 9892.81 11639.51 9968.17 9911.76 11672.89 9986.58 9930.17 44 32 46 56 50 35 54 32 58 28 S 80.23 E 1.94 1899.58N 3323.04E S 79.56 E 7.27 1895.37N 3346.68E S 78.85 E 11.63 1890.89N 3370.11E S 79.15 E 12.72 1886.17N 3394.41E S 78.95 E 11.78 1880.88N 3421.74E 2909.54 2933.55 2957.40 2982.16 3009.99 11704.89 10002.58 9946.17 61 30 11735.87 10017.08 9960.67 62 42 11766.74 10030.77 9974.36 64 37 11798.69 10044.08 9987.67 66 7 11831.78 10057.18 10000.77 67 15 S 79.74 E 9.68 1875.77N 3448.97E S 79.32 E 4.09 1870.79N 3475.89E S 78.19 E 7.03 1865.39N 3503.02E S 77.52 E 5.04 1859.28N 3531.42E S 76.66 E 4.17 1852.49N 3561.03E 3037.70 3065.08 3092.74 3121.77 3152.14 11862.48 10068.34 10011.93 70 6 11903.29 10080.45 10024.04 75 20 11935.69 10088.21 10031.80 76 56 11967.09 10094.63 10038.21 79 28 11999.95 10099.82 10043.41 82 19 S 75.71 E 9.75 1845.66N 3588.80E S 73.76 E 13.60 1835.40N 3626.38E S 72.26 E 6.70 1826.20N 3656.46E S 70.84 E 9.17 1816.48N 3685.61E S 69.37 E 9.73 1805.44N 3716.11E 3180.69 3219.52 3250.79 3281.25 3313.28 12031.60 10103.81 10047.40 83 13 12061.05 10107.33 10050.92 83 3 12157.71 10118.35 10061.94 83 51 12254.33 10129.58 10073.17 82 46 12350.78 10141.94 10085.53 82 30 S 70.16 E 3.77 1794.58N 3745.57E S 69.72 E 1.59 1784.55N 3773.04E S 67.96 E 1.99 1749.89N 3862.58E S 68.87 E 1.46 1714.59N 3951.81E S 68.01 E .93 1679.44N 4040.77E 3344.25 3373.10 3467.55 3561.80 3655.76 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING ENDICOTT / 109A/L-21 500292174301 NORTH SLOPE BOROUGH COMPUTATION DATE- 4/25/97 DATE OF SURVEY: 031897 MWD SURVEY JOB NUMBER: AK-MM-70058 KELLY BUSHING ELEV. = 56.41 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 12447.95 10154.42 100 12543.85 10165.48 101 12637.33 10176.01 101 12734.61 10188.75 101 12831.58 10204.28 101 98.01 82 44 S 66.12 E 1.94 1641.89N 4129.50E 09.07 84 1 S 64.79 E 1.92 1602.32N 4216.14E 19.60 83 2 S 65.05 E 1.08 1562.95N 4300.27E 32.34 81 54 S 61.83 E 3.48 1519.84N 4386.52E 47.87 79 39 S 61.28 E 2.39 1474.25N 4470.67E 3749.95 3842.46 3932.45 4025.24 4116.43 12928.61 10223.17 101 13009.79 10242.00 101 13072.00 10257.80 102 66.76 77 52 S 62.05 E 1.99 1429.09N 4554.42E 85.59 75 17 S 61.30 E 3.31 1391.63N 4623.93E 01.39 75 17 S 61.30 E .03 1362.73N 4676.71E 4207.15 4282.43 4339.68 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4871.20 FEET AT NORTH 73 DEG. 45 MIN. EAST AT MD = 13072 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 100.77 DEG. TIE- IN SURVEY AT 8,022.30' MD WINDOW POINT AT 8,066.00' MD PROJECTED SURVEY AT 13,072.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SI-LARED SERVICES DRILLING ENDICOTT / 109A/L-21 500292174301 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 031897 JOB NUMBER: AK-MM-70058 KELLY BUSHING ELEV. = 56.41 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8022.30 7426.49 7370.08 1797.88 N 913.91 E 9022.30 8128.80 8072.39 2002.07 N 1541.61 E 10022.30 8843.05 8786.64 1956.92 N 2239.29 E 11022.30 9549.26 9492.85 1948.40 N 2946.71 E 12022.30 10102.71 10046.30 1797.71 N 3736.89 E 595.81 893.50 297.69 1179.25 285.75 1473.04 293.79 1919.59 446.55 13022.30 10245.18 10188.77 1385.82 N 4634.54 E 13072.00 10257.80 10201.39 1362.73 N 4676.71 E 2777.12 857.53 2814.20 37.08 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING ENDICOTT / 109A/L-21 500292174301 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 031897 JOB NUMBER: AK-MM-70058 KELLY BUSHING ELEV. = 56.41 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8022.30 7426.49 7370.08 1797.88 N 913.91 E 8062.74 7456.41 7400.00 1820.77 N 928.63 E 8203.66 7556.41 7500.00 1898.66 N 989.88 E 8349.49 7656.41 7600.00 1965.51 N 1071.83 E 595.81 606.33 10.52 647.25 40.92 693.08 45.83 8495.21 7756.41 7700.00 2004.93 N 1169.71 E 8635.86 7856.41 7800.00 2015.21 N 1267.87 E 8777.26 7956.41 7900.00 2012.60 N 1367.80 E 8918.96 8056.41 8000.00 2007.58 N 1468.07 E 9061.82 8156.41 8100.00 1999.80 N 1569.79 E 738.80 45.72 779.45 40.65 820.85 41.40 862.55 41.70 905.41 42.86 9202.43 8256.41 8200.00 1991.91 N 1668.31 E 9341.90 8356.41 8300.00 1982.31 N 1765.01 E 9480.21 8456.41 8400.00 1975.75 N 1860.34 E 9618.38 8556.41 8500.00 1966.04 N 1955.17 E 9757.73 8656.41 8600.00 1957.40 N 2051.80 E 946.02 40.61 985.49 39.47 1023.81 38.31 1061.97 38.16 1101.32 39.35 9898.88 8756.41 8700.00 1956.99 N 2151.39 E 10041.39 8856.41 8800.00 1956.72 N 2252.92 E 10185.16 8956.41 8900.00 1955.12 N 2356.20 E 10326.85 9056.41 9000.00 1951.16 N 2456.49 E 10464.73 9156.41 9100.00 1944.95 N 2551.18 E 1142.47 41.15 1184.98 42.51 1228.75 43.77 1270.44 41.69 1308.32 37.88 10605.74 9256.41 9200.00 1944.42 N 2650.56 E 10746.88 9356.41 9300.00 1945.59 N 2750.14 E 10890.38 9456.41 9400.00 1947.64 N 2853.01 E 11032.80 9556.41 9500.00 1948.45 N 2954.41 E 11182.11 9656.41 9600.00 1943.48 N 3065.06 E 1349.33 41.01 1390.47 41.14 1433.97 43.50 1476.39 42.43 1525.70 49.30 11329.31 9756.41 9700.00 1926.77 N 3171.74 E 11474.33 9856.41 9800.00 1907.97 N 3275.07 E 11619.89 9956.41 9900.00 1889.16 N 3379.00 E 11829.88 10056.41 10000.00 1852.88 N 3559.34 E 12463.72 10156.41 10100.00 1635.56 N 4143.81 E 1572.90 47.20 1617.92 45.02 1663.48 45.57 1773.47 109.99 2307.31 533.84 13072.00 10257.80 10201.39 1362.73 N 4676.71 E 2814.20 506.89 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 12042 Company Field: Alaska OII & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) 11 / 10/98 Well Job # Log Description Date BL Sepia LIS Tape 1'-27/P-20 MPI ~ ~c~ i~-.. 98529 CNTD 980925 ! 1 .....1--""I { 03-43/P-36 "~ ~iJH 98577 RST-SlGMA 980806 1 1 1 1-09A/L-21~:~"~ ~ 98524 CNTD 980908 1 I 1 1-29/M-25 MPI -~ ~11 98530 CNTD 980925 1 1 ~ ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. ' Anchorage, Alaska 99519-6612 RECEIVED Date Delivered: I~OV 17'~ 1998 .. Alaska Oil & Gas Co[lsl Commission ~nnhnr~e Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN: Sherrie(~~ Received b~)~ ~ D I::! I Cl--I N G S I::: I:! ~J I C E S _ WELL LOG TRANSMIITAL To: State of Alaska August 13, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive _ Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1-09A/L-21, AK-MM-70171 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of] Tun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1-09A/L-21: 2" x 5" MD Resistivity & CcJnma Ray Logs: 50-029-21743-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-21743-01 2" x 5" 1MD Neutron & Density Logs: 50-029-21743-01 2" x 5" TVD Neutron & Density Logs: 50-029-21743-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia ;,.-~'," '.~;k 5 k:.a:: '- ......... "'"' 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I::! i L-I-- I I~1G S ~ I::! ~-/I I-- Ec: WELL LOG TRANSMITTAL -- To: State of Alaska August 13, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3 001 Porcupine Drive. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - 1-09A/L-21, AK-MM-70058 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.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. A~#: 50-029-21743-01 __ 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563~3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company __ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11163 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Endicott (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 3 - 49 A / M - 40 RETAINER SET RECORD 970402 I 1 -- 3 - 49 A ! M - 40 STATIC PRESSURE SURVEY 970424 1 1 3 - 49 A / M - 40 PERFORATION RECORD 970425 1 1 3 - 49 A ! M- 40 ~ PERFORATION RECORD 970426 I 1 4-44/M-44 [_~. t ~ TUBING PUNCHER RECORD 970313 I 1 :2-24/M-12 (~ I ~ INJECTION PROFILE 970326 I 1 2-46AIR-10 PRODUCTION LOG 97041 6 I 1 2 - 26 / N - 14 PRODUCTION PROFILE 970402 1 1 2-08/K-1 6 GAS LIFT SURVEY 970308 I 1 2 - 08 / K- 1 6 PRODUCTION PROFILE 970308 I 1 1-25A/Ko22 CHEMICAL CUT RECORD 97041 9 1 1 1 - 25 A/K-22 PLUG SET RECORD 970423 I 1 3- 29/J - 32 PRODUCTION PROFILE W/DEFT 970329 I 1 1-09A/L-21 GAMMA RAY/CCL 970301 I 1 1 - 1 7 A / 1 - 17 COMPLETION RECORD 970306 I 1 4- 50/K- 41 CHEMICAL CUTTER 970321 1 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 7/18/97 BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN 1. Status of Well Classification of ~J~r~e [~ Oil [] Gas [--I Suspended i--I Abandoned [~] Service 2. Name of Operator 7. Perrr~i~ ~ L~a',; .u'.. . BP Exploration (Alaska)Inc. 97-29 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21743-01 4. Location of well at surface 9. Unit or Lease Name 1962' SNL, 2049' WEb, SEC. 36, T12N, R16E: Duck Island Unit/Endicott At top of productive interval { ~)-":'.: ~ ~ 10. Well Number 108' SNL, 1506' EWL, SEC. 31, T12N, R17E 1-09A/L-21 At total depth i V.,-~;'-:~':~;%'-'~! 11. Field and Pool 599' SNL, 2628' EWL, SEC. 31, T12N, R17E. ~7~. .... 77"'~ ..... - .... :---:¢' Endicott Field / Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 56'I ADb 312828 12. Date Spudded3/2/97 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband115' Water depth' if °fish°re 116' N°' °f c°mpleti°ns3/18/97 3/23/97 N/A MSL One 17. Total Depth (MD+TVD)13072 10258 FT,118' Plug Back Depth (MD+TVD)I19' Directi°nal SurveY 120' Depth where SSSV set 121' Thickness °f Permafr°st12585 10170 FT, [~Yos E~No 1541' MD 1465' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, CCL 23. CASlNG~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP Be'FI-OM SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Pipe Surface 131' - Driven 13-3/8" 68# L-80 Surface 2510' 17-1/2" 4185 c.f. Class 'G' 9-5/8" 47# iNT80S/NT95HS Surface 8081' 12-1/4" 575 ¢.f. Class 'G' 7" 26# L-80 7892' 11933' 8-1/2" 314 c.f. Class 'G' 4-1/2" 12.6# L-80 11856' 12585' 6" LJncemented Slotted Liner , 24. Perforations open to Production (MD+TVD of Top and 25. TUBING REc~) [ \ [ ~J L Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Slotted Liner 4-1/2", 12.6#, L-80 11506' 11447' MD TVD MD 'I-VD 11976'-12562' 10096'-10168' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. ,,, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 35 bbls diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) March 26, 1997 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF WATER-BBb CHOKE SIZE I GAs-OIL RATIO 1'EST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBb GAS-MCF WATER-BBb iOIL GRAViTY-APl (CORR) Press. 24-HOUR RATE 28, CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers '30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. (subsea) Kekiktuk 11258' 9652' K1 11825' 9998' S1B 12015' 10045' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the f~r g~ing is tr~/~nd co~ec~t to the best of my knowledgesigned Steve Shultz ,~_-~ ~- ~..~ ~; .A...~" ~ '~.,Ct~-J ~ Title Senior Drilling Engineer Date 1-09A/L-21 "-- ' - ~ 97-29 ~'"~ Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. ~NSTRUCTIONS GENERAL.' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 27 Feb 97 28 Feb 97 01 Mar 97 02 Mar 97 03 Mar 97 End MPI Progress Report Well 1-09A/L-21 Page 1 Rig Doyon 15 Date 18 June 97 Duration Activity 12:00-15:00 15:00-18:00 18:00-18:30 18:30-21:30 21:30-22:00 22:00-23:00 23:00-01:00 01:00-01:30 01:30-02:00 02:00-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-13:00 13:00-17:30 17:30-18:00 18:00-18:30 18:30-19:00 19:00-20:00 20:00-20:30 20:30-01:30 01:30-02:00 02:00-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-14:30 14:30-15:00 15:00-16:00 16:00-18:30 18:30-19:00 19:00-21:30 21:30-22:00 22:00-22:30 22:30-02:30 02:30-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-10:30 10:30-11:00 11:00-13:00 13:00-23:00 23:00-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-10:00 10:00-12:30 12:30-14:00 14:00-14:30 14:30-17:00 3 hr 3hr 1/2 hr 3hr 1/2 hr lhr 2hr 1/2hr 1/2 hr 3hr 1/2 hr 1/2hr 1/2 hr 1/2 hr 6hr 4-1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 5hr 1/2 hr 3hr 1/2 hr 1/2 hr 1/2 hr lhr 7hr 1/2 hr lhr 2-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 4hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 4hr 1/2 hr 2hr 10hr 7hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 2-1/2 hr Rig moved 50.00 % Rig waited: Other delays Held safety meeting Rig moved 100.00 % Rigged up Service lines Fill pits with Brine Rigged up Lubricator Removed Hanger plug Rigged down Lubricator Circulated at 10448.0 ft Installed Hanger plug Removed Surface tree Held safety meeting Rigged down Xmas tree Rigged up BOP stack Tested All functions Rigged up Lubricator Held safety meeting Retrieved Hanger plug Rigged up Completion string handling equipment Retrieved Tubing hanger Rigged up Logging/braided cable equipment Held safety meeting Conducted electric cable operations Rigged down Logging/braided cable equipment Retrieved Tubing hanger Held safety meeting Circulated at 10448.0 ft Laid down 10448.0 ft of Tubing Installed Wear bushing Rigged up Logging/braided cable equipment Conducted electric cable operations Held safety meeting Set downhole equipment (wireline) Rigged down Logging/braided cable equipment Tested Casing Made up BHA no. 1 R.I.H. to 2512.0 ft Tested M.W.D. tool - Via string Singled in drill pipe to 4600.0 ft Held safety meeting Singled in drill pipe to 8061.0 ft Set tool face Circulated at 8081.0 ft Repaired Kelly/top drive hose Milled Casing at 8081.0 ft Held safety meeting Circulated at 8099.0 ft Flow check Serviced Top drive Pulled out of hole to 1500.0 ft Pulled BI-IA Worked on BOP - BOP stack Made up BHA no. 1 Facility Date/Time 04 Mar 97 05 Mar 97 06 Mar 97 07 Mar 97 08 Mar 97 09 Mar 97 10 Mar 97 End MPI 17:00-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-21:30 21:30-22:00 22:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-09:00 09:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-17:30 17:30-18:30 18:30-21:30 21:30-23:00 23:00-23:30 23:30-02:30 02:30-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-08:30 08:30-09:30 09:30-11:00 11:00-11:30 11:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-23:00 23:00-00:30 00:30-04:00 04:00-05:30 05:30-06:00 06:00-06:30 06:30-08:30 Duration lhr 1/2 hr 1-1/2 hr lhr 1/2 hr 1/2hr 8hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr lhr lhr 1/2 hr 9hr 1/2 hr 11-1/2 hr 1/2 hr llhr lhr 3hr 1-1/2 hr 1/2 hr 3hr 1/2 hr 2hr lhr 1/2hr 1/2hr lhr 1/2 hr lhr 1-1/2 hr 1/2 hr 6-1/2 hr 1/2 hr 11-1/2 hr 1/2hr 9-1/2 hr lhr lhr 1/2 hr 11-1/2 hr 1/2hr 11-1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 2hr Progress Report Well 1-09A/L-21 Rig Doyon 15 Page Date Activity R.I.H. to 3000.0 ft Held safety meeting Singled in drill pipe to 6697.0 ft Serviced Block line R.I.H. to 8039.0 ft Set tool face Drilled to 8296.0 ft Held safety meeting Drilled to 8581.0 ft Held safety meeting Drilled to 8871.0 ft Held safety meeting Pulled out of hole to 8040.0 ft Singled in drill pipe to 8810.0 ft Washed to 8887.0 ft Drilled to 9099.0 ft Held safety meeting Drilled to 9382.0 ft Held safety meeting Drilled to 9642.0 ft Circulated at 9642.0 ft Pulled out of hole to 1546.0 fl Pulled BHA Retrieved Wear bushing Tested BOP stack Installed Wear bushing Made up BHA no. 2 R.I.H. to 1546.0 ft Held safety meeting R.I.H. to 2500.0 ft Serviced Block line R.I.H. to 5500.0 ft Singled in drill pipe to 6439.0 ft R.I.H. to 9547.0 fl Washed to 9642.0 ft Drilled to 9795.0 ft Held safety meeting Drilled to 10084.0 ft Held safety meeting Drilled to 10475.0 ft Pulled out of hole to 9642.0 ft R.I.H. to 10475.0 ft Held safety meeting Drilled to 10914.0 ft Held safety meeting Drilled to 11348.0 fl Held safety meeting Drilled to 11517.0 ft Circulated at 11517.0 ft Pulled out of hole to 1545.0 ft Pulled BHA Made up BHA no. 3 Held safety meeting Made up BHA no. 3 2 18 June 97 Facility Date/Time 11 Mar 97 12 Mar 97 13 Mar 97 14 Mar 97 15 Mar 97 16 Mar 97 End MPI Progress Report Well 1-09A/L-21 Page 3 Rig Doyon 15 Date 18 June 97 08:30-15:00 15:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-15:00 15:00-16:30 16:30-17:30 17:30-18:30 18:30-20:30 20:30-00:30 00:30-02:00 02:00-03:30 03:30-06:00 06:00-06:30 06:30-09:00 09:00-10:00 10:00-13:00 13:00-14:00 14:00-16:00 16:00-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-06:00 06:00-08:00 08:00-12:00 12:00-13:30 13:30-14:30 14:30-17:30 17:30-18:00 18:00-18:30 18:30-21:30 21:30-22:30 22:30-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-10:30 10:30-18:00 18:00-18:30 18:30-20:30 20:30-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:00 09:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 Duration 6-1/2 hr 3hr 1/2 hr 11-1/2 hr 1/2hr 8-1/2 hr 1-1/2 hr lhr lhr 2hr 4hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr lhr 3hr lhr 2hr 2hr 1/2 hr 2hr 1/2 hr 9hr 2hr 4hr 1-1/2 hr lhr 3hr 1/2 hr 1/2 hr 3hr lhr 4-1/2 hr 2hr lhr 1/2 hr lhr lhr 2hr 7-1/2 hr 1/2 hr 2hr 9-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2hr 9hr 1/2hr 11-1/2 hr 1/2 hr Activity R.I.H. to 11200.0 ft Logged hole with LWD: Formation evaluation (FE) from 11200.0 ft to 11517.0 ft Held safety meeting Drilled to 11805.0 ft Held safety meeting Drilled to 11934.0 ft Circulated at 11934.0 ft Pulled out of hole to 10175.0 ft R.I.H. to 11934.0 ft Circulated at 11934.0 ft Pulled out of hole to 2246.0 ft Pulled BHA Downloaded MWD tool Ran Liner to 1800.0 ft (7in OD) Held safety meeting Ran Liner to 4052.0 ft (7in OD) Circulated at 4052.0 ft Ran Drillpipe on landing string to 8061.0 ft Circulated at 8061.0 ft Ran Drillpipe on landing string to 11933.0 ft Circulated at 11933.0 ft Held safety meeting Mixed and pumped slurry - 56.000 bbl Reverse circulated at 7891.0 ft Circulated at 7892.0 ft Circulated at 7892.0 ft Pulled Drillpipe in stands to 0.0 ft Ran HWDP in stands to 3906.0 ft Serviced Block line Laid down 3906.0 ft of 5in OD drill pipe Retrieved Wear bushing Held safety meeting Tested BOP stack Made up BHA no. 4 Singled in drill pipe to 5653.0 ft R.I.H. to 11848.0 ft Circulated at 11848.0 ft Held safety meeting Circulated at 11484.0 ft Tested Liner Drilled cement to 11933.0 ft Drilled to 12031.0 ft Held safety meeting Circulated at 12039.0 ft Drilled to 12250.0 ft Held safety meeting Drilled to 12310.0 ft Pulled out of hole to 11933.0 ft R.I.H. to 12310.0 ft Drilled to 12412.0 ft Held safety meeting Drilled to 12530.0 ft Held safety meeting Facility Date/Time 17 Mar 97 18 Mar 97 19 Mar 97 20 Mar 97 End MPI Progress Report 06:30-08:30 08:30-09:00 09:00-09:30 09:30-10:30 10:30-11:30 11:30-14:00 14:00-15:00 15:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-01:00 01:00-03:00 03:00-04:00 04:00-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-11:30 11:30-13:30 13:30-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-00:00 00:00-00:30 00:30-01:00 01:00-02:00 02:00-02:30 02:30-03:00 03:00-04:30 04:30-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-13:30 13:30-16:00 16:00-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-19:30 19:30-01:30 01:30-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-12:00 Duration 2hr 1/2hr 1/2hr lhr lhr 2-1/2 hr lhr 3hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 6-1/2 hr 2hr lhr 1/2 hr 1/2 hr lhr 1/2 hr lhr 1/2 hr 3-1/2 hr 2hr 2-1/2 hr 1/2hr 1-1/2 hr 1/2hr lhr lhr 3-1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr lhr 1-1/2 hr 2-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr lhr 6hr 4-1/2 hr 1/2 hr 1-1/2 hr lhr 3hr Well 1-09A/L-21 Rig Doyon 15 Activity Drilled to 12605.0 ft Pulled out of hole to 11933.0 ft Serviced Top drive R.I.H. to 12605.0 ft Circulated at 12605.0 ft Drilled to 12648.0 ft Circulated at 12648.0 ft Drilled to 12680.0 ft Held safety meeting Drilled to 12850.0 ft Held safety meeting Drilled to 13005.0 ft Held safety meeting Drilled to 13072.0 fl Circulated at 13072.0 ft Pulled out of hole to 11933.0 ft R.I.H. to 12608.0 ft Pulled out of hole to 12415.0 ft Reamed to 12540.0 ft Held safety meeting Pulled out of hole to 11933.0 ft Circulated at 11933.0 ft Pulled out of hole to 5629.0 fl Pulled BHA Downloaded MWD tool Serviced Drillfloor / Derrick Fished at 12540.0 ft Held safety meeting Fished at 12540.0 ft Made up BHA no. 5 R.I.H. to 11933.0 ft Circulated at 11933.0 ft R.I.H. to 11974.0 ft Circulated at 11933.0 ft Pulled out of hole to 11450.0 ft R.I.H. to 11933.0 ft Circulated at 11933.0 ft Pulled out of hole to 10000.0 ft Held safety meeting Pulled out of hole to 410.0 ft Pulled BHA Made up BHA no. 6 R.I.H. to 6700.0 ft Serviced Block line R.I.H. to 7892.0 ft Circulated at 7892.0 ft Held safety meeting R.I.H. to 11862.0 ft Reamed to 12588.0 ft Circulated at 12588.0 ft Held safety meeting Circulated at 12588.0 ft Pulled out of hole to 11920.0 ft Circulated at 11920.0 ft Page Date 4 18 June 97 Facility Date/Time 21 Mar 97 22 Mar 97 23 Mar 97 End MPI Progress Report Well 1-09A/L-21 Page 5 Rig Doyon 15 Date 18 June 97 Duration Activity 12:00-12:30 12:30-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-19:30 19:30-22:00 22:00-00:00 00:00-01:00 01:00-01:30 01:30-03:30 03:30-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-12:30 12:30-13:30 13:30-18:00 18:00-18:30 18:30-19:30 19:30-22:00 22:00-22:30 22:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-09:00 09:00-11:00 11:00-11:30 11:30-12:30 1/2 hr 3-1/2 hr lhr lhr 1/2hr lhr 2-1/2 hr 2hr lhr 1/2 hr 2hr 2-1/2 hr 1/2hr 4-1/2 hr lhr 1/2 hr lhr 4-1/2 hr 1/2 hr lhr 2-1/2 hr 1/2 hr 7-1/2 hr 1/2 hr lhr lhr 1/2 hr 2hr 1/2 hr lhr R.I.H. to 12588.0 ft Circulated at 12588.0 ft Pulled out of hole to 11920.0 ft Circulated at 11920.0 ft Held safety meeting Circulated at 11920.0 ft Pulled out of hole to 5844.0 ft Pulled out of hole to 400.0 ft Pulled BHA Rigged up Casing handling equipment Ran Liner to 715.0 ft (4-1/2in OD) Ran Liner on landing string to 12588.0 ft Held safety meeting Ran Liner on landing string to 11920.0 ft Circulated at 11920.0 ft Ran Liner on landing string to 12585.0 ft Set Liner hanger at 11870.0 ft with 2300.0 psi Circulated at 12585.0 ft Held safety meeting Circulated at 12585.0 ft Filter Brine Flow check Laid down 11870.0 ft of Drillpipe Held safety meeting Laid down 750.0 ft of Tubing Laid down 960.0 ft of 3-1/2in OD drill pipe Ran Drillpipe in stands to 5.0 ft Laid down 2090.0 ft of Drillpipe Removed Wear bushing Rigged up Completion string handling equipment 12:30-18:00 18:00-18:30 18:30-00:30 00:30-01:00 01:00-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-09:00 09:00-09:30 09:30-13:30 13:30-14:30 14:30-15:30 15:30-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-21:30 21:30-22:00 5-1/2 hr 1/2 hr 6hr 1/2 hr 2-1/2 hr 1/2 hr 2hr 1/2 hr 1/2 hr lhr lhr 1/2 hr 4hr lhr lhr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr lhr lhr lhr 1/2 hr Ran Tubing to 4996.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 9965.0 ft (4-1/2in OD) Tested Dual control line Ran Tubing to 11469.0 ft (4-1/2in OD) Tested Dual control line Reverse circulated at 11469.0 ft Held safety meeting Reverse circulated at 11585.0 ft Set packer at 11447.0 ft with 4000.0 psi Tested Tubing Installed Hanger plug Removed BOP stack Installed Adapter spool Installed Surface tree Tested Xmas tree Removed Hanger plug Freeze protect well - 35.000 bbl of Diesel Held safety meeting Freeze protect well - 35.000 bbl of Diesel Cleared Trip tank Installed Hanger plug Removed ESD system Directional Survey Calculator Report Well: 1-09A/L-21 Access Date and Time: Thu Jun 26 00:37:52 1997 Facility: End MPI Operator: BP Exploration Ail Depths relative to RKB . Listing contains: 76 points. Vertical Section Details: Origin North Origin East Section Azimuth (ft) (ft) (deg) 0.00 0.00 100.77 Max Depth(TVD) (ft) Applied to TD Tie In Details: MD Inc Azi North (ft) (deg) (deg) (ft) 8022.30 42.130 32.790 1797.88 East (ft) 913.91 TVD (ft) 7426.49 Survey Instrument Depth Range Summary: Instrument MWD - Standard (declination corrected) Start(ft) End(ft) 8066.00 13009.79 Corrected Survey Data Stn Measured Drl Grid No Depth Inc Azi (ft) (deg) (deg) 1 8066.00 42.470 32.680 2 8096.49 44.020 35.210 3 8132.44 45.790 38.120 4 8164.61 45.440 40.660 5 8195.33 45.350 43.030 Computed Positional Information Local 3-D Co-ordinates North East (ft) (ft) 1822.62 929.81 1839.94 941.48 1860.29 956.64 1878.05 971.23 1894.34 985.81 Vertical TVD DLS Section (ft) (deg/100ft) (ft) 7458.81 0.796 572.85 7481.02 7.626 581.07 7506.49 7.542 592.16 7528.99 5.746 603.17 7550.56 5.500 614.46 Travelling Cylinder Co-ords Relative Radial Relative Depth Dist Azimuth (ft) (ft) (deg) 8065.50 0.770 259.412 8095.98 0.215 237.317 8131.90 1.662 71.434 8164.01 3.849 60.355 8194.66 6.056 54.247 6 8228.40 45.900 45.510 7 8258.70 46.760 47.730 8 8291.15 46.520 52.720 9 8325.69 47.360 56.360 10 8356.82 47.570 59.810 1911.27 1002.31 1926.32 1018.24 1941.40 1036.36 1956.03 1056.92 1968.16 1076.38 7573.69 5.612 627.51 8227.58 8.835 48.639 7594.62 6.012 640.34 8257.63 12.024 44.382 7616.90 11.203 655.32 8289.71 15.810 42.656 7640.49 8.074 672.78 8323.77 20.081 43.006 7661.54 8.194 689.64 8354.38 24.218 43.730 11 8386.39 47.590 63.390 12 8420.50 46.630 68.130 13 8453.92 46.110 72.110 14 8484.00 45.590 75.570 15 8518.23 45.160 80.240 1978.53 1095.58 1988.80 1118.35 1997.02 1141.09 2003.03 1161.81 2008.14 1185.62 7681.49 8.937 706.56 8383.42 28.128 44.698 7704.71 10.561 727.01 8416.94 32.137 46.101 7727.78 8.758 747.81 8449.82 35.346 47.486 7748.73 8.432 767.04 8479.45 37.707 48.511 7772.78 9.790 789.48 8513.18 39.685 49.558 16 8549.78 44.410 83.830 17 8580.23 44.340 84.650 18 8613.89 44.530 87.930 19 8646.26 44.950 90.980 2011.22 1207.62 2013.36 1228.81 2014.88 1252.32 2015.09 1275.10 7795.18 8.360 810.52 8544.30 40.746 50.284 7816.94 1.897 830.93 8574.30 41.460 50.047 7840.98 6.845 853.74 8607.37 42.200 48.837 7863.98 6.758 876.08 8639.69 42.524 47.198 Stn No 2O Corrected Survey Data Measured Drl Grid Depth Inc Azi (ft) (deg) (deg) 8676.04 45.050 91.160 Computed Positional Information Travelling Cylinder Co-ords Local 3-D Co-ordinates Vertical Relative Radial Relative North East TVD DLS Section Depth Dist Azimuth (ft) (ft) (ft) (deg/100ft) (ft) (ft) (ft) (deg) 2014.70 1296.15 7885.04 0.544 896.84 8669.46 42.540 46.357 21 22 23 24 25 8774.18 44.960 92.310 8869.64 45.170 93.070 8966.45 45.530 94.290 9060.30 45.680 94.610 9155.08 44.170 94.560 2012.60 1365.52 7954.43 0.834 965.38 8767.59 42.063 44.332 2009.43 1433.02 8021.85 0.605 1032.28 8863.04 40.862 43.446 2005.01 1501.75 8089.89 0.971 1100.62 8959.83 39.061 44.147 1999.80 1568.60 8155.54 0.291 1167.27 9053.64 36.936 46.299 1994.45 1635.32 8222.65 1.594 1233.81 9148.37 33.950 47.579 26 27 28 29 30 9250.84 44.360 96.760 9347.16 43.820 93.260 9444.15 43.620 94.380 9540.97 43.720 95.750 9629.94 43.390 96.690 1987.86 1701.82 8291.23 1.616 1300.38 9244.01 29.276 49.323 1982.00 1768.56 8360.42 2.589 1367.04 9340.22 24.909 49.988 1977.53 1835.44 8430.52 0.824 1433.58 9437.12 21.079 47.016 1971.63 1902.03 8500.55 0.982 1500.10 9533.82 16.174 45.754 1964.99 1962.98 8565.03 0.817 1561.21 9622.62 10.629 47.113 31 32 33 34 35 9723.38 44.670 94.370 9821.29 44.830 89.580 9918.00 45.270 89.350 10011.95 45.580 90.840 10106.88 46.090 90.580 1958.75 2027.61 8632.22 2.203 1625.87 9715.93 5.927 51.342 1956.38 2096.46 8701.77 3.448 1693.95 9813.81 4.990 33.519 1957.02 2164.90 8770.10 0.485 1761.06 9910.45 7.737 11.310 1956.90 2231.82 8836.04 1.177 1826.83 10004.36 10.214 5.155 1956.06 2299.91 8902.18 0.572 1893.87 10099.27 12.090 4.664 36 37 38 39 4O 10202.95 45.630 91.900 10299.05 44.650 92.570 10396.38 43.130 94.550 10491.55 44.100 91.350 10585.85 45.630 89.180 1954.57 2368.83 8969.08 1.096 1961.86 10195.33 13.357 4.608 1951.92 2436.90 9036.87 1.133 2029.23 10291.42 13.429 359.651 1947.75 2504.24 9107.01 2.104 2096.16 10388.68 12.567 344.061 1944.38 2569.78 9175.92 2.533 2161.18 10483.77 13.549 328.013 1944.09 2636.30 9242.76 2.295 2226.57 10578.02 16.421 327.978 41 42 43 44 45 10679.78 44.360 89.560 10776.85 46.470 88.590 10873.09 45.040 89.190 10970.25 44.830 89.660 11064.75 48.330 89.540 1944.83 2702.70 9309.18 1.382 2291.67 10671.87 20.037 330.058 1945.95 2771.82 9377.32 2.287 2359.36 10768.86 23.784 333.463 1947.29 2840.75 9444.47 1.552 2426.83 10865.01 27.530 337.189 1947.98 2909.37 9513.25 0.404 2494.11 10962.09 31.306 337.236 1948.46 2978.00 9578.19 3.705 2561.44 11056.52 33.812 341.371 46 47 48 49 5O 11161.75 47.850 96.120 11256.97 47.210 99.320 11352.88 46.470 100.410 11449.12 46.340 100.220 11543.07 44.500 99.770 1944.92 3050.02 9643.02 5.071 2632.85 11153.41 32.021 347.212 1935.50 3119.61 9707.33 2.568 2702.97 11248.36 24.954 348.985 1923.51 3188.53 9772.93 1.132 2772.92 11343.81 15.718 345.732 1911.03 3257.10 9839.30 0.197 2842.62 11439.56 6.662 325.506 1899.41 3323.00 9905.24 1.988 2909.53 11533.07 6.252 236.682 51 52 53 54 11576.60 46.940 100.440 11608.33 50.590 101.150 11639.51 54.550 100.850 11672.89 58.480 101.050 1895.20 3346.63 9928.65 7.416 2933.53 11566.44 8.708 219.810 1890.73 3370.07 9949.56 11.626 2957.39 11597.93 11.131 202.628 1886.01 3394.37 9968.50 12.723 2982.14 11629.02 13.791 188.755 1880.72 3421.69 9986.92 11.784 3009.98 11662.62 16.534 178.457 Stn No 55 Corrected Survey Data Measured Drl Grid Depth Inc Azi (ft) (deg) (deg) 11704.88 61.500 100.260 Computed Positional Information Travelling Cylinder Co-ords Local 3-D Co-ordinates Vertical Relative Radial Relative North East TVD DLS Section Depth Dist Azimuth (ft) (ft) (ft) (deg/100ft) (ft) (ft) (ft) (deg) 1875.60 3448.92 10002.91 9.680 3037.68 11695.14 18.667 171.308 56 11735.87 62.710 100.680 1870.62 3475.85 10017.41 4.084 3065.06 11726.91 19.934 167.208 57 11766.74 64.630 101.810 1865.23 3502.98 10031.11 7.032 3092.73 11758.71 20.537 166.012 58 11798.69 66.120 102.480 1859.11 3531.37 10044.42 5.038 3121.76 11791.67 20.446 167.258 59 11831.78 67.250 103.200 1852.36 3561.00 10057.51 3.957 3152.13 11825.70 19.405 171.899 60 11862.48 70.110 104.290 1845.56 3588.78 10068.68 9.886 3180.69 11857.06 18.019 179.112 61 11903.29 75.340 106.240 1835.30 3626.35 10080.79 13.603 3219.52 11898.48 16.590 190.448 62 11935.69 76.950 107.740 1826.11 3656.44 10088.55 6.700 3250.79 11931.08 16.053 201.432 63 11967.09 79.470 109.160 1816.38 3685.59 10094.97 9.165 3281.25 11962.58 16.254 209.288 64 11999.95 82.320 110.630 1805.34 3716.09 10100.17 9.733 3313.28 11995.61 16.782 211.678 65 12031.60 83.220 109.840 1794.48 3745.56 10104.15 3.771 3344.25 12027.43 16.929 210.570 66 12061.05 83.050 110.280 1784.45 3773.02 10107.67 1.592 3373.10 12057.04 16.661 209.118 67 12157.71 83.860 112.040 1749.78 3862.57 10118.69 1.994 3467.56 12154.19 15.704 201.824 68 12254.35 82.780 111.130 1714.47 3951.82 10129.93 1.457 3561.83 12251.21 12.744 192.414 69 12350.78 82.500 111.990 1679.33 4040.76 10142.28 0.931 3655.78 12347.72 7.224 173.145 70 12447.95 82.740 113.880 1641.78 4129.51 10154.76 1.945 3749.97 12444.68 5.361 104.451 71 12543.85 84.020 115.210 1602.21 4216.15 10165.82 1.918 3842.49 12540.08 11.798 70.705 72 12637.33 83.040 114.950 1562.84 4300.28 10176.35 1.084 3932.49 12632.61 21.193 60.853 73 12734.61 81.910 118.170 1519.72 4386.53 10189.10 3.481 4025.28 12728.54 31.134 54.599 74 12831.58 79.660 118.720 1474.14 4470.69 10204.62 2.387 4116.47 12823.84 40.527 48.374 75 12928.61 77.880 117.950 1428.96 4554.46 10223.52 1.993 4207.20 12918.29 53.195 40.960 76 13009.79 75.290 118.700 1391.50 4623.96 10242.35 3.315 4282.49 12996.38 66.796 34.899 SPERRY-SUN DRILLING SERVICES SURVEY DATA Customer ... : BP-EXPLORATION Platform ... : ENDICOTT Slot/Well .. : 1 /1-09A/L-21 MEASURED ANGLE DIRECTION DEPTH DEG DEG TVD 8022.30 42.13 32.79 7426.49 8066.00 42.47 32.68 7458.81 8096.49 44.02 35.21 7481.02 8132.44 45.79 38.12 7506.49 8164.61 45.44 40.66 7528.99 NORTHINGS EASTINGS VERTICAL FEET FEET SECTION 1797.88 N 913~91 E 1822.62 N 929.82 E 1839.94 N 941.48 E 1860.29 N 956.64 E 1878.05 N 971.23 E 561.85 572.85 581.08 592.16 603.17 DOG LEG 0.00 0.80 7.63 7.54 5.75 8195.33 45.35 43.03 7550.56 8228.40 45.90 45.51 7573.69 8258.70 46.76 47.73 7594.62 8291.15 46.52 52.72 7616.90 8325.69 47.36 56.36 7640.49 1894.35 N 985.82 E 1911.27'N 1002.32 E 1926.32 N 1018.25 E 1941.40 N 1036.37 E 1956.03 N 1056.92 E 614.46 627.51 640.34 655.33 672.78 5.50 5. 1 6.01 11.20 8.07 8356.82 47.57 59.81 7661.54 8386.39 47.59 63.39 7681.49 8420.50 46.63 68.13 7704.71 8453.92 46.11 72.11 7727.78 8484.00 45.59 75.57 7748.73 1968.16 N 1076.38 E 1978.54 N 1095.58 E 1988.80 N 1118.35 E 1997.02 N 1141.09 E 2003.03 N 1161.81 E 689.64 706.56 727.01 747.81 767.05 8.19 8.94 10.56 8.76 8.43 8518.23 45.16 80.24 7772.78 8549.78 44.41 83.83 7795.18 8580.23 44.34 84.65 7816.94 8613.89 44.53 87.93 7840.98 8646.26 44.95 90.98 7863.98 2008.14 N 1185.62 E 2011.22 N 1207.62 E 2013.36 N 1228.81 E 2014.88 N 1252.32 E 2015.10 N 1275.10 E 789.48 810.52 830.93 853.75 876.08 9.79 8.36 1.90 6.85 6.76 8676.04 45.05 91.16 7885.04 8774.18 44.96 92.31 7954.43 8869.64 45.17 93.07 8021.85 8966.45 45.53 94.29 8089.89 9060.30 45.68 94.61 8155.54 2014.70 N 1296.15 E 2012.60 N 1365.52 E 2009.43 N 1433.02 E 2005.01 N 1501.75 E 1999.80 N 1568.60 E 896.84 965.38 1032.28 1100.63 1167.28 0.54 0.83 0.61 0.97 0.29 9155.08 44.17 94.56 8222.65 9250.84 44.36 96.76 8291.23 9347.16 43.82 93.23 8360.42 9444.15 43.62 94.38 8430.52 9540.97 43.72 95.75 8500.55 9629.94 43.39 96.69 8565.03 9723.38 44.67 94.37 8632.22 9821.29 44.83 89.58 8701.77 9918.00 45.27 89.35 8770.09 10011.95 45.58 90.84 8836.04 1994.45 N 1635.32 E 1987.86 N 1701.82 E 1982.02 N 1768.56 E 1977.57 N 1835.45 E 1971.67 N 1902.04 E 1965.03 N 1962.98 E 1958.78 N 2027.61 E 1956.41 N 2096.46 E 1957.05 N 2164.90 E 1956.94 ~ 2231.82 E 1233.82 1300.38 1367.04 1433.57 1500.09 1561.21 1625.87 1693.94 1761.06 1826.82 1.59 1.62 2.61 0.85 0.98 0.82 2.20 3.45 0.49 1.18 10106.88 46.09 90.58 8902.17 10202.95 45.63 91.90 8969.08 10299.05 44.65 92.57 9036.87 1956.10 N 2299.91 E 1954.61 N 2368.84 E 1951.95 N 2436.90 E 1893.87 1961.86 2029.22 0.57 1.10 1.13 SPERRY-SUN DRILLING SERVICES SURVEY DATA Customer ... : BP-EXPLORATION Platform ... : ENDICOTT Slot/Well .. : 1 /1-09a/L-a1 MEASURED AI{GLE DIRECTION DEPTH DEG DEG NORTHINGS EASTINGS VERTICAL FEET FEET SECTION DOG LEG 10396.38 43.13 94.55 9107.01 10491.55 44.10 91.35 9175.92 10585.85 45.63 89.18 9242.76 10679.78 44.36 89.56 9309.18 10776.85 46.47 88.59 9377.32 1947.78 1944.42 1944.13 1944.86 1945.99 N 2504.24 E 2096.16 N 2569179 E 2161.17 N 2636.30 E 2226.57 N 2702.71 E 2291.67 N 2771.83 E 2359.36 2.10 2.53 2.29 1.38 2.29 10873.09 45.04 89.19 9444.47 10970.25 44.83 89.66 9513.25 11064.75 48.33 89.54 9578,19 11161.75 47.85 96.12 ~9643.02 11256.97 47.21 99.32 9707.33 1947.33 1948.02 1948.50 1944.95 1935.53 N 2840.75 E 2426.82 N 2909.37 E 2494.11 N 2978.00 E 2561.43 N 3050.03 E 2632.85 N 3119.61 E 2702.97 1.55 0.40 3.70 5.07 2.57 11352.88 46.47 100.41 9772.93 11449.12 46.34 100.22 9839.30 11543.07 44.50 99.77 9905.24 11576.60 46.94 100.44 9928.64 11608.33 50.59 101.15 9949.56 1923.55 1911.07 1899.45 1895.24 1890.76 N 3188.53 E 2772.92 N 3257.11 E 2842.62 N 3323.01 E 2909.53 N 3346.64 E 2933,53 N 3370.07 E 2957.39 1.13 0.20 1.99 7.42 11.63 11639.51 54.55 100.85 9968.50 11672.89 58.48 101.05 9986.92 11704.88 61.50 100.26 10002.91 11735.87 62.71 100.68 10017.41 11766.74 64.63 101.81 10031.10 1886.04 1880.75 1875.64 1870.66 1865.26 N 3394.37 E 2982.14 N 3421.70 E 3009.98 N 3448.92 E 3037.67 N 3475.85 E 3065.06 N 3502.99 E 3092.73 12.72 11.78 9.68 4.08 7.03 11798.69 66.12 102.48 10044.42 11831.78 67.25 103.30 10057.51 11862.48 70.11 104.29 10068.67 11903.29 75.34 106.24 10080.79 11935.69 76.95 107.74 10088.55 1859.15 1852.37 1845.55 1835.28 1826.09 N 3531.38 E 3121.76 N 3561.00 E 3152.13 N 3588.77 E 3180.68 N 3626.35 E 3219.52 N 3656.43 E 3250.79 5.04 4.10 9.79 13.60 6.70 11967.09 79.47 109.16 11999.95 82.32 110.63 12031.60 83.22 109.84 12061.05 83.05 110.28 12157.71 83.86 112.04 10094.96 10100.16 10104.15 10107.67 10118.69 1816.36 1805.32 1794.46 1784.43 1749.77 N 3685.58 E 3281.24 N 3716.09 E 3313.27 N 3745.55 E 3344.24 N 3773.01 E 3373.10 N 3862.56 E 3467.55 9.17 9.73 3.77 1.59 1.99 12254.35 82.78 111.13 10129.93 12350.78 82.50 111.99 10142.28 12447.95 82.74 113.88 10154.76 12543.85 84.02 115.21 10165.82 12637.33 83.04 114.95 10176.35 1714.46 1679.32 1641.77 1602.19 1562.82 N 3951.81 E 3561.83 N 4040.76 E 3655.77 N 4129.50 E 3749.97 N 4216.15 E 3842.48 N 4300.27 E 3932.49 1.46 0.93 1.94 1.92 1.08 12734.61 81.91 118.17 10189.10 12831.58 79.66 118.72 10204.62 12928.61 77.88 117.95 10223.52 1519.71 1474.12 1428.95 N 4386.53 E 4025.28 N 4470.68 E 4116.47 N 4554.45 E 4207.20 3.48 2.39 1.99 SPERRY-SUN DRILLING SERVICES SURVEY DATA Customer ... : BP-EXPLORATION Platform... : ENDICOTT Slot/Well .. : 1 /1-09A/L-21 MEASURED ANGLE DIRECTION TVD NORTHINGS EASTINGS DEPTH DEG DEG FEET FEET VERTICAL SECTION DOG LEG 13009.79 75.29 118.70 10242.35 1391.49 N 4623.95 E 13072.00 75.00 118.70 10258.30 1362.61 N 4676~70 E 4282.48 4339.69 3.31 0.47 THE DOGLEG SEVERITY IS IN DEGREES PER 100.00 FEET. N/E COORDINATE VALUES GIV[] RELATIVE TO WELL SYST~ REFERE}ICE POINT. TVD COORDINATE VALUES GIV~ RELATIVE TO WELL HFS. THE VERTICAL SECTION ORIGIN IS WELL HEAD. THE VERTICAL SECTION WAS COMPUTED ALONG 100.77 (TRUE). CALCULATION METHOD: MINIh~ CURVATURE. MEI IO NDL TO: David Jo~ Chairmah ~ State Alaska Alaska Oil and Gas Conservation Commission DATE: February 28. 1997 THRU: Blair Wondzell, ~ FILE NO' P. !. Supervisor FROM: Bobby Fos'Ce~"-~ SUBJECT: Petroleum lns~'ctor AKHIB2EE.doc BOPE Test- Doyon 15 BPX- DIU - 1-09N L2~ PTD # 97-0029 Friday, February 28, 1997: I traveled this date to BPX's DIU well 1-09A / L23 and witnessed the BOPE test on Doyon rig 15. As the attached AOGCC BOPE Test Report shows there was 1 failure. The sensor unit on the choke manifold that senses the pressure for the casing pressure gauge on the hydraulic control panel was inoperable. The crew pumped the unit full of hydraulic oil and the gauge showed the correct pressure. This has happen several times in the past and I have discussed this issue with the rig reps. and the company reps. but the problem still occurs. I discussed this issue with John Welsh, Doyon Toolpusher, and told him that is on going problem would have to be fixed ASAP. John and i discussed the possibility of using a electronic gauge and I told John that Nabors had these type gauges on most of their rigs and the units seemed to be working fine and were very accurate. The unit on this rig is not reliable and could very easily create a major problem during a "kick mode" if the casing pressure coulc~ ,,,_,- ,, ~ not be read. John said he would discuss this with the company rep. and his superintendent. Summary: I witnessed the BOPE test on Doyon rig 15 sidetracking BPX's DIU 1- 09A /'L23. 3 hours test time - 1 failure. Attachment: AKHIB2EE.XLS X Unclassified Confidential (Unclassified if doc. removed ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Workover: Ddg Contractor: DOYON Rig No. Operator: BPX Well Name: MPt - 1-OgA /.L--rz3' ~ --~1 Casing Size: 9 5/8" Set @ Test: Initial X Weekly Other I5 PTD # Rep,: Rig Rep.: ~cocation: Sec. 96-0185 DATE: 2/28/97 Rig Ph.# 65g-6770 / 72 JAMES CARLILE JOHN WELSH 32 T. 11N R. 15E Meridian Urn/at MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign OK Drl. Rig OK Hazard Sec. Yes FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Bali Type Inside BOP Test Quan. Pressure P/F 1 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Press. P/F 250/3,000 P 5, oo/5,ooo 500/5,000 I 50O/5,000 2 500/5,000 I 500/5,000 N/A P MUD SYSTEM: Usual Alarm Tdp Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 500/5,000 ! P 500/5,000 P Functioned P Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 1 System Pressure Attained .... 4 Blind Switch Covers: Master: Nitgn. Btl's: 4 (~ 2700 3,000 J P 1,250 P minutes 0 sec. minutes 16 sec. Yes Remote: Yes Psig. Number of Failures: I ,Test Time: 3.0 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: FAILURE: The sensor unit on the choke manifold that controls the casin~7 pressure ~lau~le was inoperative. The cre, w pumped .~, e sensor full of hydralic fluid and it worked OK but this has been an on going problem for th® p~st year anct it has been brought to the attention of. the rig rep. an, d. the, BPX rep. but the problem is still on ~oincj. , , THIS PROBLEM MUST BE CORRECTED ASAP. THIS tS NOTA RELIABLE INDICATOR OF THE CDASlNG PRESSURE.. Distribution: or/g-Well File c - Oper./Rig c- Database c -Tdp Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Wrtnessed By: BOBBY D. FOSTER FI-021L (Rev. 12/94) AKHIB2EE.XLS MEMORANDUM TO: Alas David Johnsto.~ Chairman ' "' THRU' Blair Wondzell, ~ P. !. Supervisor ~/'? State of Alaska ka Oil and Gas Conservation Commission DATE: March 13, 1997 FILE NO: akhkcmee.doc FROM' Chuck Scheve,~d.~ SUBJECT: Petroleum Inspector BOPE Test Doyon 15 DIU 1-09A/L-21 PTD # 97-29 Thursday March 13, 1997' I traveled to BPX's DIU 1-09A/L21 Well being drilled by Doyon Rig 15 and witnessed the weekly BOPE test. _ As the attached AOGCC BOPE test report shows the test lasted 3 hours with no failures. The casing pressure gauge, that had been a problem on previous tests, worked well with the new sensor that has been installed. The test went well with good test procedures being employed by the Doyon crews. The rig was clean and all related equipment appeared to be in good working order. The location was well organized allowing good access to the rig. Summary' I witnessed the weekly BOPE on Doyon Rig 15 test time 3 hours with no failures. Attachment: akhkcmee.xis X Unclassified Confidential Confidential (Unclassified if doc. removed ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Doyon Rig No. '/5 PTD # BPX Rep.: 1-09A/L-21 Rig Rep.: 7" Set @ 11,933 Location: Sec. Weekly X Other DATE: 3/13/97 97-29 Rig Ph.# 659~6510 Ed Vaughn Roland James 36 T. 'I2N R. 16E Meridian UM TEST DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign OK Drl. Rig OK Hazard Sec. OK BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F '1 250/2500 P ? 250/5,000 P I 250/5,000 P I 250/5,0O0 P I 250/5,000 P 2 250/5,000 P 1 250/5,0O0 P N/A N/A N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250/5, 000 P 250/5,000 P 250/5,00O P 250/5, O0O P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 18 Test Pressure P/F 250/5, 000 P 36 250/5,000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4@2600 3000 1400 minutes 15 sec. minutes 25 sec. OK Remote: OK Psig. TEST RESULTS Number of Failures: 0 ,Test Time: 3.0 Hours. Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good Test Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X' NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve FI-021L (Rev. 12/94) AKH KCMEE.XLS CONSERVATION COMMISSION / .TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 25, 1997 Steve Shultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island unit 1-09A/L-21 BP Exploration (Alaska) Inc. Permit No. 97-29 Sur. Loc. 33182qSL, 2049'WEL, Sec. 36, T12N, R16E, UM Btmnhole Loc. 45702qSL, 2230'WEL, Sec. 31, T12N, R17E, UM Dear Mr. Shultz: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Commissioner BY ORDER OF TIlE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb' Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type°fw°rk i-iRe. Entry i-iDeepen~ []Service []Development Gas []Single Zone []Multiple Zone ..... 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE - 56' Endicott Field / Endicott Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 312828 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3318' NSL, 2049' WEL, SEC. 36, T12N, R16E Duck Island At top of productive interval 8. V~ell Number Number 2S100302630-277 4616' NSL, 2285' WEL, SEC. 31, T12N, R17E 1-09A/L-21 At total depth 9. Approximate spud date Amount $200,000.00 4570' NSL, 2230' WEL, SEC. 31, T12N, R17E 03/01/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 034633, 2634'I No Close Approach 4299.74 13128' MD / 10256' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8100' Maximum Hole Angle 82.04 ° Maximum surface 3372 psig, At total depth (TVD) 10030' / 4375psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 IBM 4128' 8000' 7383' 11919' 10086' 175 sx Class 'G' 8-1/2" 7" Slotted L-80 IBM 1000' 11919' 10086' 13128' 10256' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production "/~ ~ I G [ I~ A L ~'~ ~ C ~ i '~'" ~' ~) Liner ': Perforation depth: measured true vertical 20'. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Chris West, 564-5089 Prepared By Name/Number: Kathy Campoamor, 564-5122 21.1Signedhereby cert/~/'that the~/VX~xcL' fo~~nd(~.¢~~ correct to the best of my knowledge Stef.~u'~2---- Title Senior Drilling Engineer Date Commission Use Only Permit Number I APl Number Approval Date _ I See cover letter ¢,,~--.~----- ?t 50- c:~ ~ ---' ~ ,,/.~/--//,.~ -- ~ / ~ "~6:~ ~,~-- '" Y ~I for other requirements , Conditions of Approval: Samples Required [] Y~es "~ No Mud Log Required [] Yes ~,~No., Hydrogen Sulfide Measures /,~,Yes [] No Directional Survey Required ,~Yes [] No Required Working Pressure for BOPE [] 2M; []3M; ,j~ 5M; [] 1OM; [] 15M Other: Original $igr~ By by order of Approved By ~P.~ £..M2mhh;;m. Commissioner the commission Data~ Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: 11-09a/L-21 Well Plan Summary I Type of Well (producer or injector): I Producer Surface Location: Tie in survey Location: Target Start Location: Target End Location' Bottom Hole Location: 3318 FSL 2049 FEL S36 T12N R16E UM 5160 FSL 1105 FEL S36 T12N R16E UM 5161 FSL 3260 FEL S31 T12N R17E UM 4616 FSL 2285 FEL S31 T12N R17E UM 4570 FSL 2230 FEL S31 T12N R17E UM I AFE Number: 1727008 IEstimated StartDate- I1/Mar/97 I Rig' I DOYON 15 and Operating complete: days to drill 120+5 IMD' 113,128 I ITVD' 110,256 I IKBE: 156 I Well Design (conventional, slimhole, etc.)' Formation Markers Well Bore: I SIDETRACK Formation Tops M D TVD SS RESERVOIR PRESSURE TOP SEABEE/AYLYAK 8100 7650 KOP 10,000 MD / 7,372 TVDSS TOP SHALE 10176 8900 WALL/TUFFS TOP HRZ 10879 9390 BASE HRZ 11230 9635 TOP PUT RIVER NA (LCU) 11230 9635 KEKIKTUK- Top Zone 3C NA Top Zone 3B NA Top Zone 3A 11230 9635 4190 - 4690 psi @ 9640 TVDSS Top Zone 2B 9713 4350 - 4650 psi @ 9710 TVDSS Top Zone 2M 9798 Top Zone 2A 11525 9840 4350 - 4375 psi @ 9840 TVDSS Top Zone 1C 11919 10030 3000 - 4375 psi @ 10,030 TVDSS 'Fop ZonelB 12305 10080 Top ZonelA 12990 10180 Logging Program: Logs' 8.5" Hole Tangent and Curve 8.5" Hole from LCU to TD Cased Hole: MWD GR Only MWD GR/Directional/Resistivity Density & Neutron Porosity Optional SBT 24 hours after CIP Casing/Tubing Program: Hole bsg/ Wt/i=t Grade Conn Length Top Btm Size Tbg MD/TVD MD/TVD O.D. 8.5 7" 29 L-80 IBM 4,128 8,000/7,383 11,919/10086 7" Slotted 1,000 11,919/10086 13,128/10,256 TBG 4.5" 12.6 L-80 NSCT 11,102 38 11,230/9,391 1-09a/L-21 Drilling Permit 2117107 Cementing Program: Hole Section Liner Size Depth Volume Cement Production 7" Solid & 10,919 300 Sxs Class 'G' Slotted Bonzi to 0.5% CFR 2 with 11,919 0.7% Halad 344 7" x 9-5/8" liner 0.1% HR-5 hanger 2 pps Super CBL Mud Program: Production Mud Properties: 18.5" hole section: LSND Depth Density Marsh Yield 10 sec LSRV pH Fluid CI- (PPG) Viscosity Point 10 Min YP Loss Gel Milling 9.4 65-95 30-40 8-16 8.5- <6 11 - 24 9.5 Intermediate 9.4- 40 - 55 10 - 18 4 - 10 4 - 9 9 - 9.5 <6 30k - 10.1 40k LSND 9.4 - 48 - 62 26 - 48 45k - 55k 8.5 - <6 35k - 10.1 9.0 45k Hazards/Concerns Pore pressure (___8- 9.4 ppg EMW) based on offset SIBHP. Lost Circulation due to overbalance in Flow sands. Differential sticking with overbalance situation. Excessive Torque to be combated with lubricant additions after testing. Directional: IKOP' Maximum Hole Angle: Tangent Angle I Close Approach Well: Drilling Hazards 8,100 MD 82.01 o 45.83° There are several close approach wells above the kickoff. DRILLING CLOSE APPROACH WELL SHUT-INS There are no drilling close approach wells after the sidetrack of the original 1-09/SN-02 wellbore. PORE PRESSURE /LOST CIRCULATION Production Interval (8.5"): The Kekiktuk Sands reservoir pressure may be slightly higher than normal AND VARIES VERY GREATLY, but the offset pore pressure (based on nearby 3A BHP of 4190 - 4690 psi at 9,640 TVDss) should range from _+ 8.4 to 9.4 ppg EMW. The formation also has the potential for lost circulation (see Geologic Prognosis for faulting details). Lubricant additions (see above) should be utilized if torque and drag become troublesome, and after extensive testing of mud on location. Flex collars should be utilized in the BHA to minimize potential differential sticking. Liquid casing and OM seal should be on location to help combat severe lost circulation. NOTE: See the Geologic locations and sizes. MPI history. Prognosis for a detailed description of the expected fault Review the Pad Data Sheet for trouble highlights throughout Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Disposal Cuttings Handling- Fluid Handling- CC2A /'-',las!<a 0il & 0a~ Cons. Commissioa Annular injection is not available at £ndicott for this well. 1-09a/L-21 Drilling Permit 2/17/97 General Drilling Discussion The 1-09aiL-21 well on MPI at Endicott will target the Kekiktuk in the MPI 3A3 in accordance with the 1996 development plan. We will have to abandon the existing perforation in the 1- 09a/J-18 well, pumping cement down tubing, cut tubing, circulate KWM, pull tubing with the rig, set a whipstock, cut a window, and kick off through the 9-5/8" casing to the new 1-09 BHL utilizing the 7" liner design. We will not pull the existing production packer or tailpipe in this well. The liner length will be _ 5100 feet, with the top of the liner hanger back into the 9-5/8" casing. There have been problems with sidetrack wells especially keeping the metal cuttings from sticking the BHA. The milling fluid is designed to clean the hole if flow rates are kept high and the ditch magnets are closely monitored for recovery. A standard 6 valve slimhole (4.5" x 1" for 7" casing and 4.5" x 1.5" for 9-5/8" casing) GLM design will be run for the completion on a 4.5" L-80 tubing design with a X/X/XN nipple profile and production packer. Directional Plan: The directional plan for the 1-09a/L-21 well consists of kicking off via whipstock and conventional BHA's for the Kekiktuk Flow sands. Current plans call for 6°/100' doglegs below the whipstock, but this may be adjusted pending results during the drilling process. After sidetracking off the cement plug and steering directionally back into the Sands with 22° of inclination, the well will be dropped down through the Zone 3C thru the Zone 2A drilled to +_13,459' MD (10,416' TVD). THE DIRECTIONAL TARGET CAN BE INTERSECTED ANYWHERE WITHIN THE TARGET BOUNDRY OF +_ 10 FEET VERTICAL AND 100 FEET HORIZONTAL. THUS UNNECESSARY AND VERY EXPENSIVE SLIDING SHOULD BE AVOIDED TO KEEP THE WELL EXACTLY ON THE WELLPATH. THERE IS LIMITED GEOSTEERING APPLICATION FOR THIS WELL. Ensure that any and all tolerance lines are not crossed to avoid policy violations. Please coordinate this through both the Operations Drilling Engineer and the Endicott Drilling Superintendent. There are not any known close approaches which require wells be shut in. Any BHA's indicating less than required BUR should immediately be pulled for a more aggressive assembly, Recommended BHA's All motors should be jetted properly to account for the proposed flowrates. Hole conditions and directional objectives should dictate actual flowrates. As mentioned previously, flex collars should be utilized in the 8.5" hole sections to minimize potential differential sticking. We will be using bent housing motors with either 7/8 or 5/6 rotor/stator configurations. Sperry proposed BHA's are attached, however the actual BHA with motor design, MWD/LWD tool configuration, MWD battery life, bit hydraulics should be discussed at the daily wellsite meeting. Survey Program The survey program for 1-09a/L-21 calls for use of Sperry'~ DWD MWD surveys the entire well. Because of Sperry's standard practice of changing the MWD probes after every bit run, an electronic single shot (ESS) will not be needed, and a gyro is not warranted. Close attention to JORPS is required, with the use of checkshots and survey data validation. Bit Program We will kick off the in the Seabee Shale with a conventional directional BHA, which should make it to the Kekiktuk. After milling off the whipstock window, a 8.5" tangent section is planned to the Kekiktuk. The penetration rate will vary due to the variable lithology, but these bits have proven durable enough to drill through most of this interval. However, if there is any indication of bit failure such as torque spikes, the bit should be pulled at the descretion of the rigsite team. It remains the Endicott Doyon 15 wellsite TEAM's resposibility to confirm these 1-09a/L-21 Drilling Permit 2/17/97 bits are the best choice beTore running based on actual u,,,ling conditions and bit performance. We have had a problem with bit grading on recent wells when the bits grade change after they are returned to town, indicating we could have run more aggressive bits. It is recommended that the bit company, toolpusher, directional driller, company representative jointly grade bits before they are entered on the DEAP report. Recommended Jet Sizes Expected Interval Bit Type Flowrate HSI Whipstock and Standard Window Mills 500 - 550 gpm window 8.5" Kickoff -Tangent ATJ-09 550 - 600 gpm 3 x 12 2.9 - 4.8 8.5" Reservoir ATJ-P18HD or PDC 550 - 600 gpm 3 x 15 2.9 - 4.8 NOTE: Real time rigsite information such as condition of bits previously pulled, hole conditions, drilling fluids, downhole motor constraints (if any) will be instrumental in actual final bit selection. PDC bits will be run in the 8.5" hole section only if Sperry 6-3/4" performance motors are available. Mud Program: Because of the problems with Sheardril, we will use LSND on this well. The problems of lubricant additions in a (high weight - high calcium carbonate - high chloride) system severely hampered the drilling process on the both SDI wells Sheardrill was used on. There should not be any additions of any lubricants in this well without extensive testing of the actual fluid on location. A new Gel/Biszan polymer will be used for milling the window. Ditch Magnets should be used and WEIGHED to ensure metal cuttings removal. Rheology control can be maintained using Gel and Biozan polymer. A lower YP should be sufficient until the start of the kick off. At this time raise the LSR YP to the recommended range using Biozan. Biozan sweeps should be pumped to assist in hole cleaning and to prevent the build up of cuttings beds. Additions of Baranex should begin around 10500 MD and should result in an HPHT of <15 which is our target. Maintain the pH in the 9-9.5 range using caustic soda. Additions of 3#/BBL each of Baranex and Barotrol should begin around 8500~ TVD.This treatment should be maintained to the end of this interval. This treatment should result in an HPHT of <14 which is our target. Maintain the pH in the 9-9.5 range using caustic soda. If torque problems arise, a treatment of 1- 2% Lubetex should be used. If the torque persists, the additions should be increased to 3% Lubetex. The LSND mud will be taken to TD on this well. Maintain the weight at the density required in the intermediate section. The Barotrol and Baranex treatments should be maintained at 3#/bbl. The APl filtrate should be reduced to the 4 cc range with PAC and starch. This will reduce the chances of differential sticking and reduce filtration invasion. Tripping Practices / Stuck Pipe / Hole Cleaning Tripping in the 8.5" hole interval should be undertaken with caution due to swabbing possibilities with high viscosity fluids. The bottom hole pressure varies from 4180 psi to 4890 psi (8 to 9.4 ppg ). It is recommended that mud weights be maintained in the 9.5 ppg range to control the hydrocarbon intervals, maintain shale stability and minimize the possibility of differential sticking. Faulted intervals may require additions of LCM prior to tripping to insure that the hole remains full at all times. Keep the pipe moving and have an ample supply of lost circulation materials on hand. Baroid recommends utilization of Iow viscosity sweeps to assist with hole cleaning and to minimize the formation of cuttings beds on the Iow side of the hole. No potential hazardous levels of H2S are anticipated in the 1-09a/L-21 well. There been H2S reading on offset MPI wells of over 1000 ppm, Ensure rig detectors are calibrated prior to N/D tree and/or circulating to kill the well. have gas Logging Program: I Logs: 8.5" Hole Tangent and Curve 8.5" Hole Lateral MVVD MWD GR/Directional/Resistivity Density & Neutron Porosity 1-09a/L-21 Drilling Permit 2/17/97 IWireline Logs - TD to HRZ I DIL/LDT/CNL/GR, RFT Based on OH Log~ Cased Hole: I SBT 24 hours after CIP The following summarizes logging evaluation needs: MWD MWD only should be used until just above the LCU. GR/EWD "real-time" Resistivity and recorded Density /Neutron should be picked up for only 8.5" reservoir intervals. Wireline Wireline logs are planned do provide enhanced formation evaluation of this fault block. Aisc a cement bond Icg will be run to evaluate the cement job. Sample catchers and a wellsite Geologist are planned to be used while drilling reservoir. Casing and Cementing This sidetrack well will require a single 7" 29# L-80 liner to be run across the entire interval. This will be hung off in the 9-5/8" casing at 9800 feet. Ensure that prior to running liner that the hole is in good condition and that the mud has been conditioned to run pipe. In the past before POH to run liner additional lubricant has been spotted across the open hole section. If this is considered essential to getting the pipe to bottom ensure that adequate lubricant testing has been performed prior to doing this. Aisc, consideration must be given to a hole opener trip prior to running liner if hole conditions suggest that there may be problems running pipe. The liner should be filled every 5 joints, and circulated prior to going into open hole. Any problem intervals identified while drilling, such as ledges in the Tuffs, will require special care while running casing through. The liner will require 2 straight blade centralizers on every joint to the 200 feet above the top of the Kekituk at + 13,148'. If the liner starts to packoff in the open hole, establish circulation and try to wash through. Do not continue to run casing without circulation. If necessary, we will pull casing and make a wiper trip prior to running the liner. The liner running procedure in the detail section should be reviewed. The cementing program is designed place cement 1000 feet above the top of the Kekiktuk formation. The approximate volume will be 300 sacks of Class 'G' with additives as speficied in the casing detail section. Cementing operations at Endicott are becoming more important with the advancement of the waterflood and gas fronts. Close attention to detail for this part of the well is critical for the economical success of our drilling program. Through Tubing Conveyed Perforating This well will require TTCP perforating after running the completion across the pay as identified by MWD and Wireline logs. It is therefore critical these FINAL Field Prints logs are sent to town after a QNQC procedure insures the data is adequate to pick the perforated interval. 1-09a/L-21 Drilling Permit 2/17/97 SUMMARY PROCEDURE COMMENTS 1. The 9-5/8 "x 4-1/2" production packer is a TIW permanent packer with a tubing seal assembly above. The 7 "x 3-1/2" production packer is a TIW permanent packer with a tubing seal assembly above. Neither packer will be recovered. 2. Tihis well will be sidetracked at appx 8100 feet. PRE-RIG OPERATIONS 1. RU wireline, Pull the WL SSSV. Drift and dummy off gas lift mandrels. 2. Perforate 100 feet above straddled perforation at _ 11,500. 3. Establish bullhead rate down tubing and into perforations. 4. Pump 100 sx of class G cement and circulate down the tubing. Displace to a 11,500' MD. Squeeze cement into perforations up to 1500 psi. 5. RU wireline and cut tubing with chemical cutter above 9-5/8" packer at 10,861' MD. 8. Circulate the 4.5" tubing with 1.5 volumes of 9.5 ppg brine or milling fluid. Check that the well is dead. Freeze protect the top 200' with diesel. Set BPV. Note: Maintain contact with Drilling. If rig move is delayed to more than four days after the well kill, a deeper freeze protect will need to be done by the PE's. 7. Dig out the cellar and level the pad. Inspect the wellhead and tree. Replace the 9-5/8" packoff and function test the LDS's. RIG OPERATIONS (SUMMARY) 1. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. 2. Check that the well is dead. If not circ well w/brine or milling fluid until dead. 3. ND the tree, and NU the BOPE. Test the BOPE and pull BPV. (1/2 day) 4. Screw into the landing joint. Pull and LD the tubing. (1 day) 5. Run and set 9-5/8" wireline bridge plug at 8,100 MD with CCL to set BP 3 feet below collar. (1/2 day). 6. P/U 9-5/8" whipstock and milling BHA and TIH to cut window from 8,100' - 8,112' MD. (2 days) 7. POOH w/mills. (1/2 day) 8. Pick up Sperry 6.75" directional BHA to turn and build @ 8°/100 feet to 46° at appx 8,609' MD. Drill ahead as specified by the rig supervisor to TD at 13,128'MD. POOH. (15 days) 9. If hole conditions dictate, run HO over hole interval and spot lubricant in OH section. POOH. 10. Run a combination 7" solid and slotted liner from 8,100 to 13,128' MD, reciprocate for as long as possible and cement as per plan. (2 days) 11. RIH w/7" x 4-1/2" packer, 4-1/2" L-80 tubing, and 6 GLM to expected setting depth at 11,500 MD. Drift packer, tubing and all jewlery before running. (1 day) 12. Pump Corrosion inhibitor. Set the 7" packer. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. (1/2 day) 13. Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. (1/2 day). 14. Turn the well over to Production. 1-09a/L-21 Drilling Permit 2/17/97 7" CASING CEMENT PROGRAM - Halliburton CASING SIZE' 7" SPACERS' 20 bbls 2% water 50 bbls Spacer @ 1 ppg over MW CIRC. TEMP' STAT. TEMP: 140° F 220° F CEMENT TYPE TAIL: Class G + 0.5% CFR-3 + 0.7% Halad 344 + 0.1% HR5 + 2 pps Super CBL TAIL SLURRY Density: 15.8 ppg Yield: 1.15 ft3/sk Volume: _ 175 sx Pump Time: _ 4 hours TOC: ___11,919' MD Fluid Loss' <30 cc Free Water: 0.0 cc Excess: 30% in open hole Comp. Strength: 1,800 PSI 3,000 PSI Compressive Strengths at 12 and 24 hours respectively. SLURRY PLACEMENT TOC @ 10,919' equivalent to the > 1000 above ECP at the top of the Kekituk Cl(assumes Kekituk Cl at _+11,919 MD). OTHER CONSIDERATIONS' Perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8 BPM MINIMUM. Temperatures estimated by Halliburton and are representative of those encountered in the region around MPI. CEMENT NOTES' . , 4. 5. 6. 7. 30% excess (based on gauge hole). Centralization: Run 2 straight blade per joint from TD to 200 feet above top Kekituk. Run 1 st. blade rigid centralizers above window in 9.625" casing Hook up flow meter and have Halliburton generate rate vs. pressure plots. Pumping order: Fresh water, spacers, tail slurry (on the fly), Liner wiper dart. Displace with mud at 6 - 8 BPM. Calculated ECD's show max of 12.65 ppg EMW. Reciprocate casing as long as hole conditions allow; land on hanger if sticky. Slow pumps 5-10 bbls before plug bump; bump plug to maximum 3,000 psi. 1-09a/L-21 Drilling Permit 2/17/97 7000 7500 8OOO 85OO 9000I 9500 10000 10500 1-09A/L-21 Pore Pressure/MW/Frac Grad Plot PPG (EMW) 10 11 12 13 14 15 I ,I I I KOP IN SEEBEE TUFFS ~ --Mud Weight - -e- - Pore Press -' Frac Gradient KEKIKTtJK ., A/L-21 WP8 Vertical Section 98.91 RKB 56' MD Inc. Azi. TVDss TVDrkb Rect. Coordinates Northing Easting 8100.00 42.78 32.66 7427.83 7483.83 1842.00n 942.24e 8200.00 40.82 44.31 7502.49 7558.49 1894.06n 983.47e 8300.00 40.10 56.61 7578.70 7634.70 1935.24n 1033.27e 8400.00 40.70 68.93 7654.98 7710.98 1964.73n 1090.67e 8500.00 42.55 80.66 7729.84 7785.84 1981.97n 1154.56e 8600.00 45.51 91.36 7801.83 7857.83 1986.62n 1223,70e 8609.14 45.83 92.29 7808.22 7864.22 1986.41n 1230.24e 8700.00 45.83 92.29 7871.53 7927.53 1983.81n 1295.36e 8800.00 45,83 92.29 7941.21 7997.21 1980.95n 1367.03e 8900.00 45.83 92.29 8010.89 8066.89 1978.09n 1438.70e 9000.00 45.83 92.29 8080.57 8136.57 1975.23n 1510.37e 9100.00 45.83 92.29 8150.25 8206.25 1972.37n 1582.04e 9200.00 45.83 92.29 8219.93 8275.93 1969.51n 1653.71e 9300.00 45.83 92.29 8289.61 8345.61 1966.65n 1725.38e 9400.00 45.83 92.29 8359.28 8415.28 1963.79n 1797.04e 9500.00 45.83 92.29 8428.96 8484.96 1960.93n 1868.71e 9600.00 45.83 92.29 8498,64 8554.64 1958.07n 1940.38e 9700.00 45.83 92.29 8568.32 8624.32 1955.21n 2012.05e 9800.00 45.83 92.29 8638.00 8694.00 1952.35n 2083.72e 9900.00 45.83 92.29 8707.68 8763.68 1949.49n 2155.39e 10000.00 45.83 92.29 8777.36 8833.36 1946.63n 2227.06e 10100.00 45.83 92.29 8847.04 8903.04 1943.77n 2298.73e 10176.00 45.83 92.29 8900.00 8956.00 1941.59n 2353.21e 10200.00 45.83 92.29 8916.72 8972.72 1940.91n 2370.40e 10300.00 45.83 92.29 8986.40 9042.40 1938.05n 2442.07e 10400.00 45.83 92.29 9056.08 9112.08 1935.19n 2513.74e 10500.00 45.83 92.29 9125.76 9181.76 1932.33n 2585.41e 10600.00 45.83 92.29 9195.44 9251.44 1929.47n 2657.08e 10700.00 45.83 92.29 9265.12 9321.12 1926.61n 2728.75e 10800.00 45.83 92.29 9334.80 9390.80 1923.75n 2800.42e 10879.22 45.83 92.29 9390.00 9446.00 1921.48n 2857.20e 10900.00 45.83 92.29 9404.48 9460.48 1920.89n 2872.09e 11000.00 45.83 92.29 9474.16 9530.16 1918.03n 2943.76e 11100.00 45.83 92.29 9543.84 9599.84 1915.17n 3015.43e 11200.00 45.83 92.29 9613.52 9669.52 1912.31n 3087.10e 11230.83 45.83 92.29 9635.00 9691.00 1911.42n 3109.20e 11300.00 45.83 92.29 9683.20 9739.20 1909.45n 3158.77e 11400.00 45.83 92.29 9752.88 9808.88 1906.59n 3230.44e 11500.00 45.83 92.29 9822.56 9878.56 1903.73n 3302.1 le Grid Coordinates DLS Easting Northing deg/100ft 260159.30 5984259.99 0.00 260202.19 5984310.68 8.00 260253.30 5984350.22 8.00 260311.63 5984377.84 8.00 260376.05 5984392.99 8.00 260445.30 5984395.39 8.00 260451.82 5984394.97 8.00 260516.82 5984390.26 0.00 260588.36 5984385.08 0.00 260659.89 5984379.89 0.00 260731.43 5984374.71 0.00 260802.97 5984369.52 0.00 260874.50 5984364.34 0.00 260946.04 5984359.15 0.00 261017.58 5984353.97 0.00 261089.11 5984348.78 0.00 261160.65 5984343.60 0.00 261232.19 5984338.41 0.00 261303.73 5984333.23 0.00 261375.26 5984328.04 0.00 261446.80 5984322.86 0.00 261518.34 5984317.67 0.00 261572.71 5984313.73 0.00 261589.87 59843¢2.49 0.00 261661.41 59843~7.30 0.00 261732.95 59843{~ .12 261804.48 59842.~.93 w~ ~ ~0~0 261876.02 598,~ .~ .75 ~i ¢.':1~ 261947.56 598~.56 .~ ~0 262019.09 598~¢~ .38 c,~ 262075.77 5984~,27 262090.63 598427~19 2~21 ~2.17 5~8427~01 2~2233.70 5~842~82 0.00 2~2305.24 5~842~0.~4 0.00 2~2327.30 5~8425~.04 0.00 2~237~.78 5~84255.45 0.00 2~2448.31 5~84250.27 0.00 2~251~.85 5~84245.08 0.00 Vertical Section 645.58 678.24 721.06 773.21 833.66 901,24 907.73 972.47 1043.71 1114.96 1186.21 1257.46 1328.71 1399.95 1471.20 1542.45 1613.70 1684.95 1756.20 1827.44 1898.69 1969.94 2024.09 2041.19 2112.44 2183.68 2254.93 2326.18 2397.43 2468.68 2525.12 2539.92 2611.17 2682.42 2753.67 2775.63 2824.92 2896.16 2967.41 Comment KOP/Start Dir 8/100 · 8100 MD End of Dir · 8609 MD Top Tuffs · 10176 MD Top HRZ · 10879 MD BHRZ/LCUrrop Kekiktuk - 11230 MD 12/13/96 10:53 AM Page 1 of 2 · WP8 Vertical Section 98.91 RKB 56' MD Inc. Azi. 11525.03 45.83 92.29 11596.68 45.83 92.29 11600.00 46.19 92.52 11700.00 57.22 98.58 11800.00 68.47 103.27 11900.00 79.84 107.28 11919.04 82.01 108.00 12000.00 81.97 109.57 12100.00 81.93 111.52 12200.00 81.90 113.46 12300.00 81.88 115.41 12400.00 81.87 117.35 12500.00 81.86 119.30 12600.00 81.87 121.24 12700.00 81.88 123.19 12800.00 81.91 125.13 12900.00 81.94 127.08 13000.00 81.99 129.02 13056.40 82.01 130.12 13066.34 82.01 130.12 13128.38 82.01 130.12 TVDss TVDrkb Rect. Coordinates Grid Coordinates Northing Easting Easting No~hing 9840.00 9896.00 1903.01n 3320.06e 262537.76 5984243.79 9889.92 9945.92 1900.96n 3371.41e 262589.01 5984240.07 9892.23 9948.23 1900.86n 3373.79e 262591.40 5984239.89 9954.14 10010.14 1892.97n 3451.69e 262668.99 5984229.48 9999.73 10055.73 1875.96n 3538.84e 262755.55 5984209.66 10027.00 10083.00 1850.58n 3631.45e 262847.28 5984181.28 10030.00 10086.00 1844.88n 3649.37e 262865.00 5984175.00 10041.28 10097.28 1819.06n 3725.26e 262940.01 5984146.73 10055.28 10111.28 1784.31n 3817.97e 263031.55 5984109.00 10069.35 10125.35 1746.44n 3909.44e 263121.74 5984068.18 10083.46 10139.46 1705.49n 3999.57e 263210.48 5984024.32 10097.60 10153.60 1661.51n 4088.25e 263297.69 5983977,48 10111.75 10167.75 1614.54n 4175.39e 263383.25 5983927.71 10125.90 10181.90 1564.64n 4260.88e 263467.08 5983875.07 10140.03 10196.03 1511.86n 4344.63e 263549,07 5983819.60 10154.13 10210.13 1456.27n 4426.55e 263629.13 5983761.39 10168.17 10224.17 1397.93n 4506.54e 263707.18 5983700.48 10182,15 10238.15 1336.90n 4584.51e 263783.13 5983636.96 10190.00 10246.00 1301.32n 4627.56e 263825.00 5983600.00 10191.38 10247.38 1294.98n 4635.09e 263832.32 5983593.42 10200.00 10256.00 1255.39n 4682.07e 263877.99 5983552.33 DLS deg/100ft 0.00 0.00 12.00 12.00 12.00 12.00 12.00 1.93 1.93 1.93 1.93 1.93 1.93 1.93 1.93 1.93 1.93 1.93 1.93 0.00 0.00 Vertical Section 2985.25 3036.30 3O38.67 3116.85 3205.59 3301.00 3319.59 3398.57 3495.54 3591,77 3687.16 3781.58 3874.94 3967.13 4058.04 4147.58 4235.64 4322.12 4370.16 4378.58 4431.13 Comment Zone 2A: 11525 MD Start of Dir 12/100: 11597 MD Target/Dir 1.93/100/TZIC:11919MD End Dir ! End Target · 13056 MD TD/7" Casing Pt.' 13128 MD 12/13/96 10:53 AM Page 2 of 2 Sha d Services Drilling Structure MPI Well: 1-09a/L-21 Wp8 Field ' Endicott Location 'Alaska o 6400 - 0 0 0 -d- 6800 - 7200 - - 7600 8o00 8400 88oo 9200 ~eoo WELL PROFILE DATA .... Point .... MD !nc Oir TYD Horth East DLS (deg/100ft) KOP / Start Dir 8/I00 8100 42.78 32.66 7484 1842 942 O.O0 End of Build 8609 45.83 92.29 7864 1986 1230 8,00 Start of Dir 12/1 O0 1 1597 45.83 92.29 9946 1901 3371 0,00 forgct/StortOirl.95/lO011919 82.01 108.00 10086 1845 3649 12.00 End target / End of Oir. 1.3056 82.01 130.12 10246 1501 4628 1.93 TO / 7' Casing Pt13128 82.01 130.12 10256 1255 4682 0.00 -- TARGET DATA MD inc Dir H0 North East -- Nam, .... Position -- 15056 8,2.01150.1210246 1301 4-628 £r~ Torqtt265825 . 5985600 11919 82.01 108.0010086 1845 3649 Start f~rget 262865.5984-175 KOP/Stort Oir 8/1 O0 ' 81 O0 MD End of Dir ' 8609 MD 10400 - 10800 11200 11600 -400 0 400 800 1200 1600 2000 2400 2800 3200 5600 4000 4400 4800 52 400.00 Vertical Secti .... 98.91 azimuth with r.ference 0.00 N, 0.00 E from 1-09o/L-21 N TRUEHORTH I.... TARG£ T DATA MD Inc Oir I'VO North Eost --- ~me --- ? ~ ? 9721 17~ 4~5 · ~ ~ 9666 2043 2057 Fou~l-Errer 13~56 B2:01130.12102~ 13OI 462~ Er~ T~t ? ' ~ 9721 1899 4558 F~lt 12 ~ ? ? ~ 9666 2243 2031 F~[t I1 251260. 5984625 Shared Services Structure: EndMPI Field ' Endicott Well'l-O9a/L-21 Wp8 Location 'Alaska WELL PROFILE DATA .... Point .... MD Inc Bit TVD North E~Jst DLS (deg/lOOf~) FOP / Start, Oir 8/1 O0 81 O0 42.78 32.68 7484 1842 942 0.00 End of Dir 8609 45.83 92.29 7864 1986 1230 B.O0 -- PapUan -- Start of Oir 12/100 11597 263775,5984000 261260,5984425 45,8`392.29 9946 1901 5,371 0.00 263825,5983600 262865,5984175 26.3775,5984200 Target/Start Oir 1.9,3/1001 19 19 82.01 108.00 1008 6 1845 5649 12.00 l end Target/End Oir. 13056 82.01 130.12 10246 1301 4628 1.95 l TD / 7' Casing Pt. 15128 82,01 130.12 10256 1255 4682 0,00 Scale 1 ' 400.00 Easf 400 800 1200 1600 2000 2400 2800 5200 3600 4000 4400 4800 5200 2400 2000 It ~ 6oo ~- 1 200 0 Z - ~. 800 - ,, _ 400I FOP / 8100 MD/7484 . r~kb Fault #1 ~ Fault#I-Error .... . ............ --- Fault ~2 x......x;, a, ,x end Target 2400 -2000 - -~, ~oo II - ~h [~ ~, 0 ~oo .-. g 400 400 800 1200 1600 2000 2400 2800 3200 .5600 4000 4400 4800 5200 Scale 1 ' 400.00 East RT. ELEV = 55.0' BF. FI EV = 17.0' MAX. DEV. = 47:00 10600' MD 13-3/8', 68#/ft, L-80, BTRS. CSG. 9-5/8", 47#/ft, NT80SXOTO I 9,334' I~ NT95HS TOP OF 7' I 10'935' I LINER 9-5/8", 47#/ft, NT95HS, I 11'223' I~ NSCC PERFORATION SUMMARY F{~: LOG: DLL CO. SIZE ~PF INTI~RVAL SCHL 5" 5 11,664' to 11,?04' below 7" pkr 11,776' to 11,810' 11,822' to 11,836' 11,870' to 11,896' 11,902' to 11,928' NOTE: COMPLETION EQuIpMENT DEPTHS ARE DRILLER'S DEPTHS, PERFORATING DEPTHS ARE WIRELINE MEASUREMENTS. 0NLM) PBTD I 12,197' I . 7" -- 29 #/f,, sM-110,I 12,280' BTRS-TKC DATE 10/22/87 FEV. BY MDM JLH 9/09/88 1 1 / 23/88 WRB 7 ' P~R DEPTH 1 1/4/93 JLH Update Info COMP. & PERF - IREF. LOG C~ANGE TI:El=. 4-1/16' / bo00 psi/ CIW WELLFEAD: 13-5/8' / 5000 psi / CIW SSSV LANDIN~ NIFPLE I 3.813' MN. ID)W/SSSV I 1,533' MN I.D. 2.0' 4-1/2', 12.6#/ft, L-80, TDS TUBII',G GAS LIFT MANDFELS ( 4,164' 6,497' 8,485' 9,798' 10,544' 10,685' CAMCO. SLIDING SLEEVE OTIS "XA" I 10,789' (3.813" MIN. ID) TUBING SEAL ASSY. I 10,846' 9-5/8" PACKER J -- (TIW "HB-BPR") 10,861' 3-1/2", 9.2#/ft, L-80 TDS, TBG PORTED NIPPLE J (I.D.= 2.666'/2.350') 11,645' BLAST JOINTS OD = 4.5', ID=- 2.992' J 11,655'to11,714' J . (TOP 7" PKR SET @ 11,715' WLM) 7" TIW "HB-BP" PKR J 11,721' W/2-7/8" 'X' NIPPLES (2.313" MIN. ID) 2-7/8" WLEG Alaska Oil & Gas Cons. NOTE: DIAGRAM WAS FEVlSED FEELECT THE 7' PACKER SE'I-I-IN~ DEPTH CF 11,721' (E-LINE) IVEASUFEIVF_NT. V~RB 11-23-88 Tbg Vol = 165 Bbls. Straddle Vol = 7.5 Bbls. Tailpipe Vol = .14 Bbls. Liner to Perf Vol = 1.15 Bbls. ENDICOTT WELL 1-09 / J-18 APl NO: 50-029-21743 COMPLETION DIAGRAM BP EXPLORATION, INC. OiliiT,'iS$iorl RT. ELEV =' ~ ~ BF. ELEV = i 17.0 ~-,,'.~ad: 13-5/8', 5000 psi, ClW SSSV LANDING NIPPLE I 1600'! ( 3.813' MIN. ID) W/SSSV MIN I.D. is 2.00" 3-3/8" Surf Csg I 2510' Abandoned 1-09/J Liner Top Packer & Hanger Sidetracked 1-09A/L-21 Wellbore ~ 9-5/8' Csg Top of Cement 1000' MD above Kekiktuk (30% ~ excess). 7' Uner Zone 3 Zone 2 Zone1 [~ Exact location of jewelry to be determined from open-hole logs. - Set packer @ maximum 55 - 60°, to facilitate slickline operations. - 100' two nipple tailplpe assembly. WLEG set at least 350' above top 3A. - Drill-Out Joint located to access Zone 1 or 2A' targets. - ECP set between 2A and Zone 1. '. - 7" Drilling liner set in top of zone 1. - 4-1/2' Liner top packer, landing nipple & blank pipe to allow abandonment of Zone 1 & recompletion to uphole subzones. II I I 4-1/2' L-80 Tbg Tubing Drift = 3.833' Minimum Drift thru stdng = 3,725' GAS LIFT MANDRELS 1-1/2' & Slimhole 1' pockets NO. MD-BKB TVD-SS #6 3500' #5 5250' #4 6300' #3 7000' #2 7700' #1 8400' 4-1/2" 'X' NIPPLE ( 3.813" ID) Production Packer 4-1/2' L-80 Tailpipe 4-1/2" 'X' NIPPLE ( 3.813' ID) 4-1/2" 'XN' NIPPLE (3.725" ID) ~ 7' solid liner ~ ECP 7' slotted liner or crossover to 4-1/2' slotted liner, depending on availability '~-- High angle (sub-horizontal) thru Zone 1. DATE REV. BY COMMENT. S ENDICOTT WELL 1-09A/L-21 APl NO: PROPOSED DRILLING DIAGRAM BP EXPLORATION, INC. FIELD & POOL WELL PERMIT CHECKLISTco Y ~- ~-~:~/~ O INI~ CLASS ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING REMARKS APPR 14. Conductor string provided ................ Y N 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17 CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ....... Y 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved.~ N 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... .-q--~--N- 24. Drilling fluid program schematic & equip list adequate ~ N 25. BOPEs adequate .................... 4~3 N 26. BOPE press rating adequate; test to ~ psig. Y~ N (Ma'~ 27. Choke manifold complies w/API RP-53 84) ...... ~ N~V 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ....... ~/Y N ' ' ' 34. Contact name/phone for weekly progress reports . ./. . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMI SS ION: JDH_~_ mca Comments/Instructions: HOW/dlf- A:\FORMS\cheklist rev 01/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Wed Aug 06 14:31:59 1997 Reel Header Service name ............. LISTPE Date ..................... 97/08/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 97/08/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Comment Record TAPE HEADER ENDICOTT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 4 AK-MM-70058 M. WORDEN E. VAUGHN ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1-09A/L-21 500292174301 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 06-AUG-97 MWD RUN 5 AK-MM-70058 E. CRIBBS E. VAUGHN 36 12N 16E 3318 2049 .00 56.40 14.50 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 8061.0 8.500 7.000 11933.0 6.000 13072.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. TOP OF THE WHIPSTOCK IS SET AT 8061'MD, 7455'TVD AND WINDOW POINT IS AT 8066'MD, 7459'TVD. 4. MWD RUNS 1 THROUGH 3 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 5. DATA FROM ll,169'MD, 9648'TVD TO ll,517'MD, 9886'TVD IS ACQUIRED ON A MEASURED AFTER DRILLING (MAD) PASS TRIPPING INTO THE HOLE ON MWD RUN 4. 6. MWD RUN 4 IS DIRECTIONAL, DUAL GAMMA RAY (DGR), COMPENSATED NEUTRON POROSITY (CNP), STABILIZED LITHO-DENSITY (SLD), AND ELECTRO-MAGNETIC WAVE RESISTIVITY (EWR-4). 7. MWD RUN 5 IS DIRECTIONAL, DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY SLIM PHASE-4 (EWR-4). 8. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM D. DOUGLAS FOR BRENT VOORHEES OF BP EXPLORATION (ALASKA), INC. ON 07/17/97. 9. MWD RUNS 1, 2, 3, 4, AND 5 REPRESENT WELL 1-09A/L-21 WITH API #: 50-029-21743-01. THIS WELL REACHED A TOTAL DEPTH(TD) OF 13072'MD, 10258'TVD SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM S PACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (FROM RESISTIVITY SENSOR). SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY(SANDSTONE MATRIX-FIXED HOLE SIZE) SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR LOG PROCESSING: HOLE SIZE = 8.5" MUD FILTRATE SALINITY = 11500 PPM MUD WEIGHT = 10.2 PPG FORMATION WATER SALINITY = 16000 PPM. FLUID DENSITY = 1.0 G/CC. MATRIX DENSITY = 2.65 G/CC. LITHOLOGY = SANDSTONE. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 DEPTH INCREMENT: FILE SUMY~RY PBU TOOL CODE START DEPTH PEF 11169.0 DRHO 11169.0 RHOB 11169.0 FCNT 11169.0 NCNT 11169.0 NPHI 11169.0 FET 11169.0 RPD 11169.0 RPM 11169.0 RPS 11169.0 RPX 11169.0 GR 11169.0 ROP 11169.5 $ Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 11897 5 11897 5 11897 5 11888 5 11888 5 11888 5 13032 0 13032 0 13032.0 13032.0 13032.0 13025.0 13071.5 EQUIVALENT UNSHIFTED DEPTH -- Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 4 11517.0 11933.0 5 11933.0 13072.0 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 NPHI MWD P.U. 4 1 FET MWD HOUR 4 1 NCNT MWD CNTS 4 1 RPX MWD OHF94 4 1 FCNT MWD CNTS 4 1 RHOB MWD G/CC 4 1 DRHO MWD G/CC 4 1 PEF MWD BARN 4 1 ROP MWD FT/H 4 1 RPS MWD OHMM 4 1 GR MWD AAPI 4 1 RPM MWD OHMM 4 1 RPD MWD OHMM 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name Min Max Mean DEPT 11169 13071.5 12120.2 NPHI 7.7926 81.7622 26.7121 FET 0.7884 72.021 8.7223 NCNT 2064 4448 3382.74 RPX 0.6426 2000 54.435 FCNT 402 1763 957.748 RHOB 1.1506 2.7291 2.12871 DRHO -0.421 0.2273 -0.0622499 PEF 1.0368 2.5197 1.38758 ROP 2.1584 478.125 33.9857 RPS 0.8354 2000 98.2648 GR 6.2121 272.261 80.2916 RPM 0.1586 2000 205.506 RPD 0.1036 2000 299.944 First Last Nsam Reading Reading 3806 11169 13071.5 1440 11169 11888.5 3727 11169 13032 1440 11169 11888.5 3727 11169 13032 1440 11169 11888.5 1458 11169 11897.5 1458 11169 11897.5 1458 11169 11897.5 3805 11169.5 13071.5 3727 11169 13032 3713 11169 13025 3727 11169 13032 3727 11169 13032 First Reading For Entire File .......... 11169 Last Reading For Entire File ........... 13071.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11169.0 RPX 11169.0 RPS 11169.0 RPM 11169.0 RPD 11169.0 FET 11169.0 NPHI 11169.0 NCNT 11169.0 FCNT 11169.0 RHOB 11169.0 DRHO 11169.0 PEF 11169.0 ROP 11169.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : STOP DEPTH 11908 5 11881 0 11881 0 11881 0 11881 0 11881 0 11888.5 11888.5 11888.5 11897.5 11897.5 11897.5 11933.0 Il-MAR-97 ISC 4.88 CIM 5.46/5.03 MEMORY 11933.0 11517.0 11933.0 44.6 70.1 TOOL NUMBER P0659CRNDG6 P0659CRNDG6 P0659CRNDG6 P0659CRNDG6 8.500 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 10.20 54.0 9.0 11500 4.6 1.200 .539 .900 1.700 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPX 'MWD 4 OHMM 4 1 68 4 2 RPS MWD 4 OHMM 4 1 68 8 3 FET MWD 4 HOUR 4 1 68 12 4 GR MWD 4 AAPI 4 1 68 16 5 RPM MWD 4 OHMM 4 1 68 20 6 NPHI MWD 4 P.U. 4 1 68 24 7 FCNT MWD 4 CNTS 4 1 68 28 8 NCNT MWD 4 CNTS 4 1 68 32 9 RHOB I~FWD 4 G/CC 4 1 68 36 10 DRHO MWD 4 G/CC 4 1 68 40 11 PEF MWD 4 BARN 4 1 68 44 12 ROP MWD 4 FT/H 4 1 68 48 13 RPD MWD 4 OHMM 4 1 68 52 14 72.2 First Name Min Max Mean Nsam Reading DEPT 11169 11933 11551 1529 11169 RPX 2.5663 225.14 48.8876 1425 11169 RPS 2.8857 2000 128.466 1425 11169 Last Reading 11933 11881 11881 FET 1.5514 71.2423 12.9801 1425 GR 10.7998 272.261 50.9316 1480 RPM 3.0574 2000 318.223 1425 NPHI 7.7926 81.7622 26.7121 1440 FCNT 402 1763 957.748 1440 NCNT 2064 4448 3382.74 1440 RHOB 1.1506 2.7291 2.12871 1458 DRHO -0.421 0.2273 -0.0622499 1458 PEF 1.0368 2.5197 1.38758 1458 ROP 3.2329 478.125 41.3844 1528 RPD 3.1478 2000 423.993 1425 11169 11169 11169 11169 11169 11169 11169 11169 11169 11169.5 11169 11881 11908.5 11881 11888.5 11888.5 11888.5 11897.5 11897.5 11897.5 11933 11881 First Reading For Entire File .......... 11169 Last Reading For Entire File ........... 11933 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11790.0 FET 11797.0 RPD 11797.0 RPM 11797.0 RPS 11797.0 RPX 11797.0 ROP 11838.0 $ LOG HEADER DATA DATE LOGGED: STOP DEPTH 13025.0 13032.0 13032.0 13032.0 13032.0 13032.0 13071.5 18-MAR-97 S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 ISC 4.88 CIM 5.46/5.03 MEMORY 13072.0 11933.0 13072.0 75.3 84.0 TOOL NUMBER P0617SP4 P0617SP4 6.000 6.0 LSND 10.20 63.0 8.9 8000 3.4 .400 .193 .420 .490 72.8 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 GR MWD 5 AAP I 4 1 68 RPX MWD 5 OHFR~ 4 1 68 RP S MWD 5 OHN~ 4 1 68 RPM MWD 5 OHMM 4 1 68 RPD MWD 5 O PHv~4 4 1 68 ROP MWD 5 FT/H 4 1 68 FET MWD 5 HOUR 4 1 68 4 8 12 16 20 24 28 Name Min Max Mean Nsam DEPT 11790 13071.5 12430.8 2564 GR 6.2121 244.39 93.1754 2471 RPX 0.63 2000 53.9588 2471 RPS 0.7812 2000 74.9979 2471 RPM 0.0859 2000 128.13 2471 RPD 0.1036 2000 322.151 2471 ROP 2.1584 600 33.2419 2468 FET 0.7884 75.1719 10.6601 2471 First Reading 11790 11790 11797 11797 11797 11797 11838 11797 Last Reading 13071.5 13025 13032 13032 13032 13032 13071.5 13032 First Reading For Entire File .......... 11790 Last Reading For Entire File ........... 13071.5 File Trailer · Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/08/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File ge.t.e._O_b.O_3 o l, * ALASKA COMPUTING CENTER * . . * ....... SCHLUMBERGER ....... . *_ ......... . COMPANY NAME : BP EXPLORATION WELL NAi~iE : 1-09ALL-21 FIELD NAME : ENDICOTT MPI BOROUGH : NORTH SLOPE STATE : ALASKA API~ER : 500292174301 REFERENCE NO : 98524 LIS, Tape V~rification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 98/10/22 ORIGIN : FLIC REEL NAM~ : 98524 CONTINUATION # : PREVIOUS REEL : CO~4~NT : BP EXPLORATION, ENDICOTT, 1-09A/L-21, API #50-029-21743-01 **** TAPE HEADER **** SERVICE NAFIE : EDIT DATE : 98/10/22 ORIGIN : FLIC TAPE NAME : 98524 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, ENDICOTT, 1-09A/L-21, API #50-029-21743-01 TAPE HEADER ENDICOTT MPI CASED HOLE WIRELINE LOGS WELL NAME: 1 - 09A/L-21 API NUMBER: 500292174301 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLOWBERGER WELL SERVICES TAPE CREATION DATE: 22-0CT-98 JOB NUMBER: 98524 LOGGING ENGINEER: D. PALMER OPERATOR WITNESS: DON BARBA SURFACE LOCATION SECTION: 3 6 TOWNSHIP: 12N RANGE: 16E FNL: FSL: 3318 FEL: 318 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 56.41 DERRICK FLOOR: 56.41 GROUND LEVEL: 14.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 11920.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS, Tape Vekification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUMBER: PASS NUFi~ER : DATE LOGGED: 18-MAR-97 LOGGING COMPANY: SPERRY SUN BASELINE DEPTH 88888.0 11857.5 11853.5 11835.5 11830.0 11811.5 11717.5 11703.5 11698.0 11676.0 11644.0 11635.5 11616.0 11574.0 11567.5 11549.5 11544.0 11540.5 11535.5 11533.5 11528.5 11519.0 11514.0 11505.0 11479.5 11464.5 11457.5 11441.0 11432.5 11363.0 11325.5 11303.0 11294.5 11283.0 11256.5 11249.0 11233.5 100.0 $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH 88885.0 11854 5 11850 5 11834 5 11828 5 11807 5 11715 0 11700 0 11696.0 11674 0 11643 0 11636 0 116170 11577 5 11570 0 11551.5 11546.5 11541.5 11535.5 11533.5 11528.5 11519.0 11514.5 11503.5 11478.0 11463.0 11456.0 11440.0 11431.0 11361.5 11324.0 11301.0 11292.5 11280.5 11254.5 11246.0 11231.5 98.0 88885.0 11854.5 11850.5 11834.5 11828.5 11807.5 11715.0 11700.0 11696.0 11674.0 11643.0 11636.0 11617.0 11577.5 11570.0 11551.5 11546.5 11541.5 11535.5 11533.5 11528.5 11519.0 11514.5 11503.5 11478.0 11463.0 11456.0 11440.0 11431.0 11361.5 11324.0 11301.0 11292.5 11280.5 11254.5 11246.0 11231.5 98.0 CONTAINED HEREIN IS THE CNTD DATA ACQUIRED ON BP EXPLORATION WELL 1-09A/L-21 ON 8-SEP-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTD PASS #4 GRCH TO THE BASELINE GAMMA RAY PROVIDED BY THE CLIENT (GR.MWD) ; AND CNTD PASS #4 NPHI TO GR.MWD. ALL OTHER CNTD CURVES WERE PAGE LIS'Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 CARRIED WITH THE NPHI SHIFT. **NOTE: ONLY PASSES 4,5 & 6 ARE PRESENTED ON THE BLUELINE. THE DIGITAL DATA IN THISLDWGEDIT IS ALSO ONLY FROM PASSES 4,5 & 6. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE S~,~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11890.0 11220.0 CNTD 11914.0 11220.0 $ CURVE SHIFT DATA - PASS TO PASS (MEAStrRED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NU~BER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD .............. REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTD PASS #4. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA LIS, Tape VePification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NU?,IB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189339 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTD PU-S 1189339 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTD 1189339 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTD 1189339 O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNTD CPS 1189339 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTD CPS 1189339 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTD CPS 1189339 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTD CPS 1189339 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTD GAPI 1189339 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTD LB 1189339 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTD V 1189339 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11911,000 NPHI.CNTD 35.179 NRAT. CNTD 4.597 CRAT. CNTD NCNT. CNTD 1722,567 FCNT. CNTD 374.745 CFTC. CNTD 332.553 CNTC. CNTD GRCH. CNTD -999,250 TENS.ClTTD 1293.000 CCL. CNTD 0.000 DEPT. 11218.000 NPHI.CNTD 51.062 NRAT. CNTD 5.771 CRAT. CNTD NCNT. CNTD 1433.809 FCNT. CNTD 248.447 CFTC. CNTD 220.475 CNTC. CNTD GRCH. CNTD 72,164 TENS.CNTD 1427.000 CCL. CNTD 0.000 5. 655 1905. 930 7.446 1644. 269 LIS. Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILEN[k4~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUAiBER : 5 DEPTH INCREMENT: O . 5000 FILE SUFk~LRY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11896.0 11232.0 CNTD 11920.0 11232.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 4 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH CNTD 88888.0 88884.5 88887.5 11908.5 11908.0 11902.0 11899.0 11883.0 11880.0 11879.0 11875.0 LIS, Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 11878.0 11868.0 11858.5 11854.5 11853.0 11846.0 11833.5 11825.0 11811.5 11789.5 11775.0 11770.0 11752.0 11745.5 11732.5 11732.0 11724.5 11704.5 11699.0 11691.5 11676.0 11675.0 11665.5 11655.5 11636.5 11636.0 11591 0 11575 5 11568 5 11567 5 11545 5 11545 0 11536 0 11528 5 11524.5 11522.0 11514.0 11506.5 11498.5 11498.0 11480.0 11475.5 11474.5 11468.5 11459.0 11458.5 11432.5 11418.0 11394.0 11393.5 11391.0 11364.5 11328.0 11327.5 11316.5 11874.5 11854.5 11851.0 11843.5 11823.0 11807.5 11786.0 11769.5 11749.5 11742.0 11729.5 11700.5 11696.0 11688.5 11674.5 i1664.5 11656.0 11636.0 11592.5 11577.5 11570.0 11546.5 11535.0 11528.5 11524.0 11521.5 11503.5 11496.0 11478.0 11472.5 11466.0 11456.5 11416.5 11391.0 11388.0 11361.5 11324.0 11865.5 11851.0 11833.0 11767.0 11729.0 11721.0 11696.5 11673.0 11636.0 11569.5 11547.0 11523.5 11514.5 11496.0 11473.0 11455.5 11429.0 11391.0 11325.5 11313.0 LIS, Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 11307.5 11304.0 11304.0 11301.0 11296.0 11292.5 11284.5 11280.5 11284.0 11279.5 11264.0 11261.5 11257.5 11255.0 11249.5 11245.5 100.0 96.0 97.5 $ REMARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTH CORRECTED DATA FOR CNTD PASS #5. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #5 GRCH TO PASS #4 GRCH, AND PASS #5 SIGM TO PASS #4 SIGM. ALL OTHER CNTD CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORe, AT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189339 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 1189339 O0 000 O0 0 2 1 1 4 68 0000000000 ArRAT CNTD 1189339 O0 000 O0 0 2 I 1 4 68 0000000000 LIS' Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 8 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELM CODE (HEX) CRAT CNTD 1189339 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTD CPS 1189339 O0 000 O0 0 2 1 1 4 68 0000000000 FCNTCNTD CPS 1189339 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 1189339 O0 000 O0 0 2 1 1 4 68 0000000000 ClTTCCNTD CPS 1189339 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 1189339 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTD LB 1189339 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTD V 1189339 O0 000 O0 0 2 1 1 4 68 0000000000 * * DA TA * * DEPT, 11919.500 NPHI.CNTD 37.228 NRAT. CNTD 4.828 CRAT. CNTD 5.887 NCNT, CNTD 1672.584 FCNT. CNTD 346.457 CFTC. CNTD 307.449 CNTC. CNTD 1930.051 GRCH, CNTD -999.250 TENS.CNTD 1261.000 CCL.CNTD 0.000 DEPT, 11228.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD -999.250 NCNT, CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 C;.'TC.CNTD -999.250 GRCH. CNTD 71.309 TENS. CNTD -999,250 CCL.CNTD -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: EDITED CURVES LIS, Tape Vetification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: Depth shifted and clipped curves for each pass in separate files. PASS N[bIBER : 6 DEPTH INCREblENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11892.0 11222.0 CNTD 11916.0 11222.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 4 BASELINE DEPTH 88888 0 11909 5 11897 0 11868 5 11857 5 11857 0 11854 0 11846 5 11845 0 11844 5 11827. 0 11824. 0 11812,5 11811.0 11790.0 11765.5 11745.0 11721.0 11704.0 11703.5 11698.5 11691.0 11675.0 11674,5 11664,0 11656.5 11636.0 11635 5 11620 0 11595 0 11567 5 11567 0 11545. 0 11543.5 11533,5 11532.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD 88885.0 88886.5 11854.5 11845.0 11843.5 11822.5 11807.5 11786.5 11700.5 11674.0 11664.0 11636.0 11597.5 11570.0 11546.5 11533.0 11532.0 11908.0 11894.5 11~5.5 11855.0 11851.0 11844.0 11825.0 11809.5 11762.0 11742.5 11717.0 11700.0 11696.5 11690.0 11673.0 11655.0 11636.0 11620.0 11569.5 11547.0 LIS'Tape Ve'rification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 10 11528.5 11528.5 11527.5 11528.5 11526.0 11526.0 11524.0 11524.0 11514.0 11514.5 11510.5 11511.0 11507.5 11505.5 11503.5 11497.5 11496.0 11495.5 11490.0 11488.0 11481.0 11478.5 11474.5 11472.5 11469.0 11467.0 11468.5 11465.5 11458.0 11456.5 11455.5 11438.5 11437.5 11438.0 11437.0 11433.5 11431.0 11406.0 11404.0 11393.5 11390.5 11392.0 11390.5 11363.5 11361.5 11361.0 11329.5 11328.0 11326.0 11324.0 11305.5 11304.5 11303.5 11301.0 11295.0 11292.5 11290.5 11287.5 11283.0 11279.5 11277.5 11275.0 11267.5 11264.5 11257.0 11255.0 11248.5 11245.5 11242.5 11239.0 11239.5 11233.5 11231.5 11229.0 11225.0 11227.0 11224.0 100.0 97.0 96.0 $ REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTD PASS #6. THE DEPTH SHIFTS SHOWN ABOVEREFLECT PASS #6 GRCH TO PASS #4 GRCH, AND PASS #6 SIGM TO PASS #4 SIGM. ALLOTHER CNTD CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA LIS~ Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHARY * * NAME SERVUNIT SERVICE API API API API FILE NU~4B NU~.IB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELF~¥ CODE (HEX) DEPT FT 1189339 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTD PU-S 1189339 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTD 1189339 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTD 1189339 O0 000 O0 0 3 1 1 4 68 0000000000 NCNTCNTD CPS 1189339 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTD CPS 1189339 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTD CPS 1189339 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTD CPS 1189339 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTD GAPI 1189339 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTD LB 1189339 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTD V 1189339 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11914.500 NPHI.CNTD 41.921 NRAT. CNTD 5.377 CRAT. CNTD NCNT. CNTD 1603.207 FCNT. CNTD 298.137 CFTC. CNTD 264.569 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD 1314.000 CCL. CNTD 0.000 DEPT. 11218.000 NPHI.CNTD 47.276 NRAT. CNTD 7.391 CRAT. CNTD NCNT. CNTD 1472.000 FCNT. CNTD 199.170 CFTC. CNTD 176.746 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD 1315.000 CCL.CNTD 0.000 6.401 1788.465 7.012 1654.234 LIS. Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 12 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAIWiE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 PILE TYPE : LAST FILE : FILE HEADER FILE ArUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 4, 5, 6, CNTD THE ARITHFIETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA LIS' Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHA3~ ** N~'4E SERV UNIT SERVICE API API API API FILE NU?.I~ NO?':~ SIZE REPR PKCCESS ID ORDER # LOG TYPE CLASS MOD Nt~B SAMP EL£¥3 CODE (tiEX) DEPT FT 1189339 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1189339 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1189339 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1189339 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1189339 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1189339 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1189339 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1189339 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 1189339 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 1189339 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11911.000 NPHI.CNAV 40.171 NRAT. CNAV 4.982 CRAT. CNAV NCNT. CNAV 1708.256 FCNT. CNAV 346.146 CFTC. CNAV 307.173 CNTC. CNAV GRCH. CNTD -999.250 TENS.CNTD 1293.000 6.205 1908.598 ** END OF DATA ** LIS'~ Tape Ve'rification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 14 **** FILE TRAILER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAIVE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FiLE HE_~E_u. FILE NL?,ISER 5 PASS i,I~¥iBER : 4 DEPTH INCRE,fEi~'T: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11929.0 11170.0 CNTD $ LOG H~ER DATA DATE LOGGED: 8-SEP-98 SOFTWARE VERSION: 8Cl-205 TIME LOGGER ON BOTTOM: 1757 8-SEP-98 TD DRILLER (FT) : 12585.0 TD LOGGER (FT) : 11870.0 TOP LOG INTERVAL (FT) : 11220.0 BOTTOM LOG INTERVAL (FT) : 11930.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAi~VARAY CNTD COMP. NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER CGRS-A CNT-D 8.500 LIS-Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 15 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 11920.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WAT/PROD. FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORS~LIZATION IN OIL TOP NOP~.IALIZINE ?.?33g~',~ (Fi] : BASE NORMALIZING ~Wi3~E£~'.~ (F?) : F~LR COUJIT RATE LO?I SCALE (CPS): 0 FAR COUNT R~TE HIGH SCALE (CPS): 2550 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 12500 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO SPERRY SUN LOG OF 12-MAR-1997 AT DEPTH OF 11630 NOTE DEPTH SHIFT ON MWD ACROSS THIS INTERVAL GAS LIFT SHUT IN PRIOR TO LOGGING. PUMPED TOTAL OF:1200 BBLS GAS ENTRY FROM HORIZONTAL SECTION CAUSING PROBLEMS ON FIRST 3 PASSES. FINALLY REQUIRED A RATE OF 4 BPM TO KEEP FLUID PACKED. MADE 3 PASSES AT 30 FPM, RAN 2 3/4" CNTD W/CPLC & 1 11/16" WEIGHT. NOISE ON COLLAR LOCATOR DUE TO SWIVEL. THIS FILE CONTAINS THE RAW CNTD DATA FOR PASS #4. $ LIS FORMAT DATA LIS 'Tape Vetification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 16 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 O 66 1 * * SET TYPE - CH_~£! * * ~4D_¥E SERV L?:iF SE~EVISE API API API A5£ WiLE :,'l?.:.E' i.'~%.-~ ,~Ti~E F:CE?~ 2,:', '_':'_.:.: ID OP~ER ~ LOG TYPE CLASS MOD I~.l~ S~2,iP EL211 COE~ t'i:','z,"ij ..................... = ................................................................. DEPT FT 1189339 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1189339 O0 000 O0 0 $ 1 1 4 68 0000000000 RTNR PS1 1189339 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1189339 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS1 CPS 1189339 O0 000 O0 0 $ 1 1 4 68 0000000000 RCFT PS1 CPS 1189339 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1189339 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1189339 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1189339 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1189339 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1189339 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11929.000 NPHI.PS1 78371.719 RTNR.PS1 -999.250 TNRA. PS1 RCNT. PS1 2000.000 RCFT. PS1 0.000 CNTC. PS1 2185.506 CFTC. PSi GR.PS1 0.000 TENS.PSi 672.000 CCL.PS1 0.029 DEPT. 11169.500 NPHI.PSl 47.250 RTNR.PS1 6.403 TNRA.PS1 RCNT. PS1 1460.581 RCFT. PS1 199.170 CNTC. PS1 1596.770 CFTC.PSl GR.PS1 103.394 TENS.PSi 1427.000 CCL.PS1 -999.250 -1139.127 0.000 7.009 176.746 LIS 'Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 17 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 0 O1 CO 1 DATE : 98/10/22 ~,~a_\~ REC SiEE : 1024 z__Z i-'_.'>i : L3 LAS2' FiLE : FILE HEADER FILE~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUPk~%RY VENDOR TOOL CODE START DEPTH STOP DEPTH 11932.5 11185.0 CNTD LOG HEADER DATA DATE LOGGED: 8-SEP-98 SOFTWARE VERSION: 8Cl-205 TIFiE LOGGER ON BOTTOM: 1757 8-SEP-98 TD DRILLER (FT) : 12585.0 TD LOGGER (FT) : 11870.0 TOP LOG INTERVAL (FT) : 11220.0 BOTTOM LOG INTERVAL (FT): 11930.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LIS .Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 18 GR GAM~IA RAY CNTD COMP. NEUTRON $ CGRS-A CNT- D BORE~OLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8.500 11920.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WAT/PROD. FLUIDS BLUELi2.IE COre'ii? RATE 21QfiU.iALIZATICgl Ii,I OIL ZJ.'3£ TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELI1VE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 12500 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO SPERRY SUN LOG OF 12-MAR-1997 AT DEPTH OF 11630 NOTE DEPTH SHIFT ON MWD ACROSS THIS INTERVAL GAS LIFT SHUT IN PRIOR TO LOGGING. PUMPED TOTAL OF:1200 BBLS GAS ENTRY FROM HORIZONTAL SECTION CAUSING PROBLEMS ON FIRST 3 PASSES. FINALLY REQUIRED A RATE OF 4 BPM TO KEEP FLUID PACKED. MADE 3 PASSES AT 30 FPM. RAN 2 3/4" CNTD W/CPLC & 1 11/16" WEIGHT. NOISE ON COLLAR LOCATOR DUE TO SWIVEL. THIS FILE CONTAINS THE RAW CNTD DATA FOR PASS #5. $ LIS FORMAT DATA LIS 'Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 19 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 6~ 0 66 i NAME SERV UNIT SERVICE API API API APi FILE NUMB Nt~.i~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) DEPT FT 1189339 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1189339 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1189339 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1189339 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 1189339 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1189339 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1189339 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1189339 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1189339 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1189339 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1189339 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11932.500 NPHI.PS2 78371.719 RTNR.PS2 -999.250 TNRA.PS2 RCNT. PS2 1777.778 RCFT. PS2 0.000 CNTC. PS2 1942.672 CFTC. PS2 GR.PS2 0.000 TENS.PS2 885.000 CCL.PS2 0.029 DEPT. 11184.500 NPHI.PS2 42.065 RTNR.PS2 4.372 TNRA.PS2 RCNT. PS2 1378.758 RCFT. PS2 176.353 CNTC. PS2 1563.687 CFTC. PS2 GR.PS2 69.721 TE1VS.PS2 1327.000 CCL.PS2 -999.250 -1139.127 0.000 6.416 156.497 LIS'Tape Ve~rification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 20 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION · O01CO1 DATE : 98/10/22 LAST FILE : CNTD LOG HEADER DATA FILE HEADER FILE AUu~qBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCPI~4~lVT: 0.5000 FILE SUPmlARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11930.0 11198.5 DATE LOGGED: 8-SEP- 98 SOFTWARE VERSION: 8Cl-205 TI~iE LOGGER ON BOTTOM: 1757 8-SEP-98 TD DRILLER (FT) : 12585.0 TD LOGGER (FT) : 11870.0 TOP LOG INTERVAL (FT) : 11220.0 BOTTOM LOG INTERVAL (FT) : 11930.0 LO~GING SPEED (FPHR) : 1800.0 DEPTH COITTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL ArUMBER LIS ~'Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 21 GR GA~4MA RAY CNTD COMP. NEUTRON $ CGRS-A CNT-D BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 8.500 11920.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FI): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SF_~ WAT/PROD. FLUIDS BL-JELZZiS CCL7;/- P. AiS 2.:J?,J.JALZ'ZAiiiA~ ii.: EEL Zi.'.£' TOP NOP~,~=ALIZING WI;ZDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 12500 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO SPERRY SUN LOG OF 12-MAR-1997 AT DEPTH OF 11630 NOTE DEPTH SHIFT ON MWD ACROSS THIS INTERVAL GAS LIFT SHUT IN PRIOR TO LOGGING. PUMPED TOTAL OF:1200 BBLS GAS ENTRY FROM HORIZONTAL SECTION CAUSING PROBLEMS ON FIRST 3 PASSES. FINALLY REQUIRED A RATE OF 4 BPM TO KEEP FLUID PACKED. MADE 3 PASSES AT 30 FPM. RAN 2 3/4" CNTD W/CPLC & 1 11/16" WEIGHT. NOISE ON COLLAR LOCATOR DUE TO SWIVEL. THIS FILE CONTAINS THE RAW CNTD DATA FOR PASS #6. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 22 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT l%~ak, iE SEP, V 0%¥i~ SERVICE API API API A~i FiLE ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189339 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1189339 O0 000 O0 0 7 1 1 4 68 0000000000 RTiFR PS3 1189339 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1189339 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 1189339 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1189339 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1189339 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1189339 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1189339 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1189339 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1189339 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11930.000 NPHI.PS3 9.178 RTNR.PS3 2.000 TNRA.PS3 RCNT. PS3 2000.000 RCFT. PS3 1000.000 CNTC.PS3 2185.506 CFTC. PS3 GR.PS3 0.000 TENS.PS3 867.000 CCL.PS3 0.029 DEPT. 11198.000 NPHI.PS3 52.960 RTNR.PS3 5.867 TNRA.PS3 RCNT. PS3 1433.809 RCFT. PS3 228.106 CNTC. PS3 1646.369 CFTC. PS3 GR.PS3 111.239 TENS.PS3 1315.000 CCL.PS3 -999.250 2.280 887.410 7. 663 202. 423 LIS 'Tape Ve.~'ification Listing Schlumberger Alaska Computing Center 22-0CT-1998 10:38 PAGE: 23 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TP~AILER **** SERVICE A%AUE : EDIT ~_~TE . 9S/1~/22 ORIGi>! : FLIC TAPE >i~£:E · 9~524 Z~:S · 9~'/2J/22 ORIGIN : FLIC REEL N~ : 98524 CONTI~ATION ~ : PREVIOUS REEL : CO~4E~ : BP ~PLO~TION, E~ICOTT, 1-09A/L-21, API $50-029-21743-01